Filed pursuant to Rule 424(b)(3)
File No. 333-124147

PROSPECTUS

3,500,000 Shares

COMMON STOCK

James River Coal Company is offering 1,500,000 shares of its common stock and the selling shareholder identified in this prospectus is offering 2,000,000 shares. We will not receive any of the proceeds from the sale of the shares being sold by the selling shareholder.

Our common stock is listed on the Nasdaq National Market under the symbol “JRCC”. On May 24, 2005, the reported last sale price of our common stock on the Nasdaq National Market was $32.99 per share.

Concurrent with this offering of shares of our common stock, we are also offering under a separate prospectus $150 million aggregate principal amount of our senior notes due 2012. The offering of shares of our common stock under this prospectus is not contingent on the consummation of the concurrent note offering.

Investing in our common stock involves risks. See “Risk Factors” beginning on page 11.

PRICE $32.50 A SHARE

	Price to Public	Underwriting Discounts and Commissions	Proceeds, before Expenses, to James River Coal Company	Proceeds to Selling Shareholder
Per share	$32.50	$2.1125	$30.3875	$30.3875
Total	$113,750,000	$7,393,750	$45,581,250	$60,775,000

 

James River Coal Company has granted the underwriters the right to purchase up to an additional 525,000 shares to cover over-allotments.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved these securities, or determined if this prospectus is truthful or complete. Any representation to the contrary is a criminal offense.

Morgan Stanley & Co. Incorporated expects to deliver the shares of common stock to purchasers on or about May 31, 2005.

MORGAN STANLEY

BEAR, STEARNS & CO. INC.

WACHOVIA SECURITIES RAYMOND JAMES

May 24, 2005

The below map shows the locations of our mining complexes (shown as shaded areas).

 

The below map shows the locations of the coal mines of Triad Mining, Inc. (“Triad”) (shown as red circles). We have entered into an agreement to acquire Triad, however, the Triad acquisition has not been completed, and we cannot assure you that we will acquire these properties. For information about the Triad acquisition, including the conditions to which the acquisition is subject, see “The Triad Acquisition.”

 

TABLE OF CONTENTS

	Page
Prospectus Summary		1
Risk Factors		11
Forward Looking Statements		28
Market for Our Common Stock		29
Use of Proceeds		30
Dividend Policy		30
Capitalization		31
Unaudited Pro Forma Condensed Consolidated Financial Statements		32
Selected Historical Financial Data		40
Management’s Discussion and Analysis of Financial Condition and Results of Operations		44
The Coal Industry		62
Business		67
The Triad Acquisition		77
Government Regulation		82
Management		88
Executive Compensation		91
Principal and Selling Shareholders		101
Related Party Transactions		103
Description of Capital Stock		104
Description of Indebtedness		110
Shares Eligible for Future Sale		112
Underwriting		115
Legal Matters		118
Experts		118
Where You Can Find More Information		118
Index to Our Consolidated Financial Statements		F-1
Index to Triad Mining, Inc. Consolidated Financial Statements		T-1

 

No dealer, sales person or other individual has been authorized to give any information or to make any representations not contained in this prospectus. If given or made, such information or representations must not be relied upon as having been authorized by us. This prospectus does not constitute an offer to sell, or a solicitation of an offer to buy, the shares in any jurisdiction where, or to any person to whom, it is unlawful to make such offer or solicitation. Neither the delivery of this prospectus nor any sale made hereunder shall, under any circumstances, create an implication that there has not been any change in the facts set forth in this prospectus or in our affairs since the date hereof. This prospectus includes trademarks of ours. All other trademarks appearing in this prospectus are the property of their respective holders.

All share and per share information in this prospectus relating to periods after our emergence from Chapter 11 bankruptcy proceedings (which shares are also referred to in this prospectus as the common stock of the “Successor Company”) reflects a two-for-one stock split effected as of October 22, 2004, in the form of a 100% stock dividend.

Until 25 days after the effective date of this registration statement, all dealers that effect transactions in these securities, whether or not participating in this offering, may be required to deliver a prospectus. This is in addition to the dealers’ obligation to deliver a prospectus when acting as underwriters and with respect to their unsold allotments or subscriptions.

MARKET AND INDUSTRY DATA AND FORECASTS

In this prospectus, we refer to information regarding the coal industry that is available from the the U.S. Department of Energy, the National Energy Technology Laboratory, the U.S. Energy Information Administration, Platts Research and Consulting, Bloomberg L.P., the Bureau of Economic Analysis, BP Statistical Review and the National Mining Association. These organizations are not affiliated with us. They are not aware of and have not consented to being named in this prospectus. Although we have not independently verified it, we believe that this information is reliable. In addition, in many cases we have made statements in this prospectus regarding our industry and our position in the industry based on our experience in the industry and our own investigation of market conditions.

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PROSPECTUS SUMMARY

This summary does not contain all of the information you should consider in making your investment decision. Before investing in our common stock, you should carefully read this entire document, including our combined historical and pro forma financial statements and accompanying notes included elsewhere in this prospectus. You should also carefully consider, among other things, the matters discussed under “Risk Factors” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations.”

Unless the context otherwise indicates, as used in this prospectus, the terms “James River,” “we,” “our,” “us” and similar terms refer to James River Coal Company and its consolidated subsidiaries. In certain sections of this prospectus, we have combined our operating results for the eight months ended December 31, 2004 with our operating results for the four months ended April 30, 2004. Because we were under bankruptcy protection during the four months ended April 30, 2004, the operating results of these accounting periods are not comparable. The combining of these accounting periods is not permitted by generally accepted accounting principles.

The Company

We mine, process and sell bituminous, low sulfur, steam and industrial-grade coal through five operating subsidiaries (“mining complexes”) located throughout Eastern Kentucky. Our five mining complexes include 18 mines and seven preparation plants, five of which have integrated rail loadout facilities and two of which use a common loadout facility at a separate location. In 2004, our mines produced 8.5 million tons of coal, and we purchased another 330,000 tons for resale. Of the 8.5 million tons produced, approximately 96.5% was produced at underground mines, while the remaining 3.5% was produced at surface mines. Approximately 83.4% of our revenues were generated from coal sales to electric utility companies and 16.6% came from coal sales to industrial and other companies or from synfuel handling fees. We generated revenues of $345.6 million in 2004 and Adjusted EBITDA of $30.2 million for the eight months ended December 31, 2004 and $20.0 million for the four months ended April 30, 2004. We define Adjusted EBITDA and reconcile it to net income in note (2) under “—Summary Historical and Unaudited Pro Forma Financial Data.”

The majority of our coal is sold to customers in the Southeast region of the United States. According to the U.S. Energy Information Administration, or EIA, the Southeast region accounts for 33% of coal-generated electricity production in the United States, more than any other U.S. region. We believe the long term outlook for coal demand in the Southeast is favorable, as coal-generated electricity production in that region is expected to grow at a rate of 1.8% per year. In addition, the Southeast region is projected by the EIA to account for 36% of the expansion of coal-generated electricity production in the United States between 2003 and 2025. We or our predecessors have been providing coal to coal-generated electricity producers in the Southeast for over 40 years. In 2004, Georgia Power and South Carolina Public Service Authority were our largest customers, representing approximately 30% and 20% of our revenues, respectively. No other customer accounted for more than 10% of our revenues.

We believe that coal-fired electric utilities value the high energy, low sulfur coal that comprises the majority of our reserves. Low sulfur coal is coal which has a sulfur content of 1.5% or less. As of March 31, 2004, based upon our most recent independent reserve report, we estimate that we controlled approximately 207 million tons of proven and probable coal reserves. As of March 31, 2005, we believe that we controlled approximately 222 million tons of proven and probable coal reserves. We believe these reserves have an average heat content of approximately 13,300 Btu per pound and an average sulfur content of approximately 1.3%. At 2004 production levels, we believe these reserves would support in excess of 25 years of production.

In March 2005, we signed a definitive agreement to acquire Triad Mining, Inc. (“Triad”), for $75.0 million, consisting of $64.0 million in cash and $11.0 million of our common stock. Triad operates six surface mines and one underground mine in Southern Indiana, and in 2004 produced approximately 3.4 million tons of coal. Of the 3.4 million tons produced, approximately 87% came from surface mines, while the remaining 13% came from underground mines. In 2004, Triad generated revenues of approximately $81.6 million and EBITDA of approximately $18.6 million. As of February 1, 2005, based upon an independent reserve report, we believe

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that Triad controlled approximately 17.6 million tons of proven and probable coal reserves. We define Triad’s EBITDA and reconcile it to Triad’s net income under “The Triad Acquisition—Selected Historical Consolidated Financial Information.”

Competitive Strengths

We believe the following competitive strengths distinguish us from our competitors:

Electric utilities prefer the high-energy, low sulfur characteristics that our coal reserves exhibit

We believe the coal we produce is attractive to utilities due to its high energy and low sulfur content. According to a study of our reserves completed by Marshall Miller & Associates, Inc., our reserves have an average heat content of approximately 13,300 Btu per pound, and an average sulfur content of approximately 1.3%. Steam coal customers value high Btu coal because it fuels electricity generation more efficiently than lower Btu coal. Demand for clean burning, low sulfur (1.5% or less) coal has also grown significantly since the implementation of sulfur emission restrictions mandated by the Clean Air Act.

We operate in areas with producer-favorable supply and demand dynamics for the types of coal we produce

The majority of our coal is sold to customers in the Southeast region of the United States. According to the EIA, the Southeast region accounts for 33% of coal-generated electricity production in the United States, more than any other U.S. region. We believe the long term outlook for coal demand in the Southeast is favorable, as coal-generated electricity production in that region is expected to grow at a rate of 1.8% per year. In addition, the Southeast region is projected by the EIA to account for 36% of the expansion of coal-generated electricity production in the United States between 2003 and 2025.

This growing demand for coal has coincided with a decline in the region’s production of coal, which has decreased 13% between 2000 and 2004, according to Platts. The decline in the region’s production of coal is driven primarily by the depletion of existing reserves and challenging operating conditions, while the increase in demand comes from the desire for a cheap, reliable energy source to fuel the continued growth in electricity needs. In addition to these market characteristics, customers in the Southeast region pay lower transportation costs for Central Appalachian coal as a result of their proximity to suppliers. These factors, matched with the desirable characteristics of Central Appalachian coal, create favorable pricing dynamics that we believe provide us with an advantage over producers from other regions.

We believe our favorable geographic position will be further enhanced by the acquisition of Triad, which will provide us with a strategic position in the Illinois basin, a region with limited suppliers and increasing demand for coal. We believe demand for Illinois basin coal will be driven by the installation of sulfur dioxide reduction technologies (commonly referred to as scrubbers) by regional utilities, so as to comply with the Clean Air Act. Based on information from Platts, we believe utilities in the Illinois basin region and surrounding areas have announced investments of approximately $13.2 billion in scrubbers since 2000. We believe these investments will support strong demand for the region’s coal.

We have highly productive, low cost operations

We operate highly productive mines, and we believe we are among the lowest cost miners in the region. This position is driven by (1) our experienced miners, (2) our use of an incentive-based compensation structure, and (3) our efficient mining operations. This productivity serves to reduce our operating costs per ton of production, thereby increasing our gross margins. Our cost position is further enhanced by our (1) flat management and organizational structure and (2) relatively low legacy liabilities. Our cost per ton of coal sold (excluding depreciation, depletion and amortization) was $31.55, $27.67 and $24.72 in 2004, 2003 and 2002, respectively. Triad also pursues a high productivity and low cost strategy. Triad’s cost per ton of coal sold (excluding depreciation, depletion and amortization) was $17.48, $15.71 and $17.03 in 2004, 2003 and 2002, respectively.

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We have extensive experience in thin seam mining

Given the long history of mining in the Eastern United States, easily accessible thicker coal seams are being rapidly depleted. Therefore, the ability to mine thin seams cost effectively is growing in importance. This type of mining requires experienced personnel and, in some cases, specialized equipment. Our ability to mine thin seams enables us to pursue growth opportunities that we believe cannot be profitably pursued by many of our competitors.

Our balance sheet enhances our financial flexibility

After giving effect to the Triad acquisition and the related financings on a pro forma basis, we will have $150.9 million in outstanding debt as of March 31, 2005, relative to our pro forma 2004 Adjusted EBITDA of $64.7 million. Our relatively low level of leverage gives us the flexibility to pursue our growth and productivity objectives as well as to enhance our profitability. In addition to low financial debt, the amount of our long-term employee- and mining-related liabilities is among the lowest in our publicly-traded peer group. As of March 31, 2005, we had workers compensation liabilities of $50.5 million, black lung liabilities of $26.0 million, and long-term pension obligations of $15.2 million. We believe our balance sheet will provide us with financial flexibility throughout industry cycles.

We have assembled a strong, experienced team of senior managers with a track record of successful operations

Over the last 18 months, we have attracted a new senior management team with significant experience in operating public, growth and coal companies. Our management team collectively has a proven record of increasing productivity, developing and maintaining long-standing customer relationships and reducing costs. Our senior and operating management have an average of approximately 20 years of experience in the coal industry, and we believe they have the capability to successfully operate and expand our business.

Business Strategy

We intend to focus on the key components of our strategy, described below:

Capitalizing on industry conditions through the opportunistic contracting of our coal

We seek to maximize our average realized sales price by optimizing our mix of coal sold under long-term contracts with that sold on spot markets. This approach provides us with adequate short-term price certainty, while giving us the ability to capitalize on potentially higher prices in the spot market. We seek to have 70–90% of one-year forward production committed pursuant to long-term contracts, as of the end of the prior calendar year. During periods of high prices, such as the current period, we may seek to lengthen the average remaining term of our contracts and reduce the open tonnage for future periods. We believe that our low financial leverage provides us flexibility to be opportunistic about coal sales.

Maintaining our position as a low-cost producer

We believe our culture of seeking to maximize productivity and minimize costs will enable us to maintain our position as a low-cost producer:

• Productivity:  High productivity is a key area of focus for all of our employees and is a core component of the James River culture. We compare our five mining complexes on tonnage, Linear Feet (of mine advance) Per Man Hour (LFPMH) and other metrics, which helps us to assess the relative performance of our operations. We employ an incentive-based compensation structure for our mine-level employees based in part on tonnage produced and on efficiency.

• Costs:  We actively monitor our spending and fixed-cost base by continuously assessing our cost per ton produced. We selectively use our capital to enhance our cost structure and overall productivity by, for example, investing in preparation plants and conveyors. Furthermore, we focus on minimizing non-mining costs, such as administrative overhead.

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Maximizing the consistency and profitability of our mining operations through diversification and balance

In order to minimize volatility inherent in mining operations, we will continue to strive for balanced exposure to the following aspects of our business:

• Mining methods:  While maintaining our strength in underground mining, we intend to expand our surface mining operations. Triad currently operates six surface mines and one underground mine, which will significantly enhance the balance between our underground and surface mining operations. We expect that adding surface mines to our operations will reduce the overall costs per ton and volatility of the production at our mining operations.

• Coal basins:  In addition to expanding our production in the Central Appalachian basin, we plan to expand our operations in other coal basins. Through the Triad acquisition, we will begin operating in the Illinois basin, thereby diversifying our operations into an area with supply/demand dynamics and mining conditions that differ from those in Central Appalachia.

• Other diversification opportunities:  In addition to seeking balance between mining methods and coal basins, we will seek opportunities in other energy-related areas within our existing regions of operation.

Pursuing growth opportunities via the efficient use of capital

We plan to continue to increase our production, grow our reserve base, and enhance productivity in a manner consistent with our capital discipline. In making capital allocation decisions, we will focus on projects that we expect will generate a rate of return significantly in excess of our cost of capital. We seek to grow our annual production through internal production additions as well as acquisitions. We are currently considering internal growth projects that are expected to add approximately 1.25 million tons of annual production for a total cost of approximately $26 million. Additionally, we recently announced an agreement to acquire Triad for $75.0 million, consisting of $64.0 million in cash and $11.0 million of our common stock. In 2004, Triad produced approximately 3.4 million tons and generated EBITDA of $18.6 million. We define Triad’s EBITDA and reconcile it to Triad’s net income under “The Triad Acquisition—Selected Historical Consolidated Financial Information.” In evaluating other expansion opportunities, we will seek to pursue opportunities that provide meaningful synergies, including the mining of properties adjacent to our existing operations.

Demand for Coal

According to the EIA, coal is the primary source of fuel for electricity generation in the United States; coal fuels more electricity generation than all other energy sources combined. According to the EIA, in 2003, coal-fueled plants generated an estimated 50% of the nation’s electricity, followed by nuclear (20%) and natural gas (18%). This is primarily a result of coal’s cost advantage relative to other fuel sources.

We believe that growth in coal consumption will be driven primarily by three factors. First, competition for cost efficient energy should cause more utilities to use coal as their primary source of fuel. Second, growth in electricity demand will drive demand for coal. Third, as aggregate emissions from U.S. coal-fueled plants continue to decline, the appeal of coal as a source of fuel will increase further.

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Additional Information

We were incorporated in the Commonwealth of Virginia in June 1991. Our principal executive offices are located at 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219 and our telephone number is (804) 780-3000. Our web site is http://www.jamesrivercoal.com. The information contained on our web site is not incorporated in this prospectus.

Risk Factors

Investing in our common stock involves substantial risks. You should carefully consider the information in the “Risk Factors” section and all other information included in this prospectus before investing in our common stock.

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Summary Historical and Unaudited Pro Forma Financial Information

Upon emergence from bankruptcy in May 2004, we adopted “fresh start” accounting as contained in the American Institute of Certified Public Accountant’s Statement of Position 90-7, Financial Reporting by Entities in Reorganization Under the Bankruptcy Code (“SOP 90-7”). In connection with the implementation of fresh start accounting, we recorded a gain of approximately $178.0 million from the extinguishment of our debt. Other adjustments were made to reflect the provisions of the Plan of Reorganization and to adjust the assets of the reorganized company to their estimated fair value and liabilities to their estimated present value. The estimated fair value of our fixed assets was based on an appraisal performed for one of our lenders in connection with our reorganization. For financial reporting purposes, these transactions were reflected in our operating results before emergence.

Our consolidated financial statements after emergence are those of a new reporting entity (the “Successor Company”) and are not comparable to the financial statements of the pre-emergence company (the “Predecessor Company”). For a complete discussion of our application of fresh start accounting, including the impact on historical results of operations, cash flows and financial position, please refer to our December 31, 2004 consolidated financial statements and related notes included elsewhere in this prospectus.

The following table presents our selected consolidated financial and operating data as of and for each of the periods indicated. The selected condensed consolidated financial data for the three months ended March 31, 2005 (successor period) and the three months ended March 31, 2004 (predecessor period) are derived from our unaudited condensed consolidated financial statements, and in the opinion of management include all adjustments, consisting only of normal recurring accruals, that are necessary for a fair presentation of our financial position and operating results for these periods. The selected consolidated financial and operating data are not necessarily indicative of the results that may be expected for the entire year. The selected consolidated financial data as of and for each of the years ended December 31, 2001 through December 31, 2003 and the four months ended April 30, 2004 (predecessor periods) and the eight months ended December 31, 2004 (successor period) are derived from our consolidated financial statements. The following unaudited pro forma consolidated financial data as of and for the three months ended March 31, 2005 and the year ended December 31, 2004 have been prepared to give effect to the completion of this offering and the concurrent notes offering and the application of the net proceeds therefrom to refinance our debt and finance the Triad acquisition, as described under “Use of Proceeds” and “The Triad Acquisition,” and the application of fresh start accounting as of January 1, 2004 as described under “Business—Recent Reorganization.” The Triad financial data for the periods ended March 31, 2005 and March 31, 2004 are derived from Triad’s unaudited condensed consolidated financial statements, and in the opinion of Triad’s management include all adjustments, consisting only of normal recurring accruals, that are necessary for a fair presentation of Triad’s financial position and operating results for these periods. The selected consolidated financial and operating data are not necessarily indicative of the results that may be expected for the entire year.

The selected consolidated financial and operating data should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations”, the “Unaudited Pro Forma Condensed Consolidated Financial Statements,” our consolidated financial statements and related notes and the consolidated financial statements and related notes of Triad included in this prospectus.

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													Predecessor Company
																			Year Ended December 31,
	Pro Forma Three Months Ended 3/31/05			Successor Company Three Months Ended 3/31/05			Pro Forma Twelve Months Ended 12/31/04			Successor Company Eight Months Ended 12/31/04			Four Months Ended 4/30/04			Three Months Ended 3/31/04			2003			2002			2001
	(All amounts in thousands, except per ton amounts)
Statement of Operations Data:
Revenues	$	121,271			97,875			427,250			231,698			113,949			80,858			304,052			397,599			384,248
Cost of coal sold		98,145			80,942			339,511			190,926			89,294			65,707			278,939			344,222			328,408
Depreciation, depletion, and amortization		12,214			9,478			42,572			21,765			12,314			9,272			40,427			46,393			43,175
Gross profit (loss)		10,912			7,455			45,167			19,007			12,341			5,879			(15,314	)		6,984			12,665
Selling, general, and administrative expenses		6,259			5,035			24,226			11,412			5,023			3,561			19,835			19,994			15,725
Other operating expenses		—			—			—			—			—			—			—			26,554			—
Operating income (loss)		4,653			2,420			20,941			7,595			7,318			2,318			(35,149	)		(39,564	)		(3,060	)
Interest expense		3,832			2,186			15,433			5,733			567			403			18,536			29,883			23,923
Interest income		(21	)		(21	)		(72	)		(72	)		—			—			(144	)		(1,003	)		(662	)
Miscellaneous income, net		(52	)		(123	)		(1,221	)		(833	)		(331	)		(53	)		(1,519	)		(1,222	)		206
Reorganization items, net		—			—			—			—			(100,907	)		1,557			7,630			—			—
Income tax expense (benefit)		198			69			1,701			791			—			—			(2,891	)		(8,125	)		(10,318	)
Income (loss) before cumulative effect of accounting change		696			309			5,100			1,976			107,989			411			(56,761	)		(59,097	)		(16,209	)
Cumulative effect of accounting change		—			—			—			—			—			—			(3,045	)		—			—
Net income (loss)		696			309			5,100			1,976			107,989			411			(59,806	)		(59,097	)		(16,209	)
Preferred dividends		—			—			—			—			—			—			(340	)		(680	)		(595	)
(Increase) decrease in redemption amount of redeemable common stock		—			—			—			—			—			—			—			8,798			45,831
Net income (loss) attributable to common shareholders		696			309			5,100			1,976			107,989			411			(60,146	)		(50,979	)		29,027
Consolidated Balance Sheet Data (at end of period):
Working capital (deficit) (1)		48,610			4,213						10,046			5,896			12,227			9,009			(263,146	)		(241,857	)
Property, plant, and equipment, net		308,120			260,781						255,575			254,259			254,646			257,156			270,989			310,643
Total assets		473,716			341,133						327,826			332,589			327,241			318,289			340,311			393,411
Long term debt, including current portion		150,885			95,000						95,000			6,400			6,400			—			252,876			249,576
Liabilities subject to compromise		—			—						—			319,451			319,813			319,595			—			—
Total shareholders’ equity (deficit)		120,973			66,342						65,585			(127,837	)		(123,189	)		(123,601	)		(68,726	)		(9,034	)
Consolidated Statement of Cash Flow Data:
Net cash provided by (used in)
Operating activities					12,689						14,098			1,513			(3,071	)		23,033			28,899			30,793
Investing activities					(14,711	)					(21,744	)		(9,463	)		(6,796	)		(15,660	)		(33,522	)		(43,640	)
Financing activities					(133	)					10,224			4,361			6,299			(2,489	)		3,347			14,119
Capital expenditures		16,446			14,690			40,037			25,811			9,521			6,815			20,116			22,925			43,694
Other Financial Data:
Adjusted EBITDA (2)		16,919			12,021			64,734			30,193			19,963			11,643			6,797			8,051			39,909
Long term debt, including current portion (3)		150,885			95,000						95,000			325,851			326,213			319,595			252,876			249,576
Interest expense		3,832			2,186			15,433			5,733			567			403			18,536			29,883			23,923
Ratio of earnings to fixed charges (4)		1.2			1.2			1.4			1.5			160.3			2.2			—			—			—
Supplemental Operating Data:
Tons sold		3,128			2,228			12,273			5,775			3,107			2,287			10,083			13,926			14,065
Tons produced		3,206			2,301			12,235			5,770			3,081			2,400			9,294			12,350			13,134
Revenue per ton sold (excluding synfuel)	$	38.30			43.27			34.21			39.21			35.98			34.65			29.53			28.26			27.29

 

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(1) Working capital is current assets less current liabilities.

(2) Adjusted EBITDA is a measure used by management to measure operating performance. We define Adjusted EBITDA as net income plus interest expense (net), income tax expense (benefit) and depreciation, depletion and amortization (EBITDA), as thereafter adjusted by management for items related to our reorganization and the cumulative effect of accounting changes, to better measure our operating performance. We regularly evaluate our performance as compared to other companies in our industry that have different financing and capital structures and/or tax rates by using Adjusted EBITDA. In addition, we use Adjusted EBITDA in evaluating acquisition targets.

Adjusted EBITDA is not a recognized term under GAAP and is not an alternative to net income, operating income or any other performance measures derived in accordance with GAAP or an alternative to cash flow from operating activities as a measure of operating liquidity. Because not all companies use identical calculations, this presentation of Adjusted EBITDA may not be comparable to other similarly titled measures of other companies. Additionally, Adjusted EBITDA is not intended to be a measure of free cash flow for management’s discretionary use, as it does not reflect certain cash requirements such as tax payments, interest payments and other contractual obligations. The amounts presented for Adjusted EBITDA differ from the amounts calculated under the definition of EBITDA used in our debt covenants. The definition of EBITDA used in our debt covenants is further adjusted for certain cash and non-cash charges and is used to determine compliance with financial covenants and our ability to engage in certain activities such as incurring additional debt and making certain payments.

Our pro forma Adjusted EBITDA for the three months ended March 31, 2005 and the year ended December 31, 2004 and our Adjusted EBITDA for the three months ended March 31, 2005, the three months ended March 31, 2004, the eight months ended December 31, 2004, the four months ended April 30, 2004 and the years ended December 31, 2003, 2002 and 2001 is calculated and reconciled to net income in the table below:

													Predecessor Company
																		Year Ended December 31,
	Pro Forma Three Months Ended 3/31/05			Successor Company Three Months Ended 3/31/05			Pro Forma Twelve Months Ended 12/31/04			Successor Company Eight Months Ended 12/31/04			Four Months Ended 4/30/04			Three Months Ended 3/31/04		2003			2002			2001
	(All amounts in thousands)
Net income (loss)	$	696			309			5,100			1,976			107,989			411		(59,806	)		(59,097	)		(16,209	)
Income tax expense (benefit)		198			69			1,701			791			—			—		(2,891	)		(8,125	)		(10,318	)
Interest expense		3,832			2,186			15,433			5,733			567			403		18,536			29,883			23,923
Interest income		(21	)		(21	)		(72	)		(72	)		—			—		(144	)		(1,003	)		(662	)
Depreciation, depletion, and amortization		12,214			9,478			42,572			21,765			12,314			9,272		40,427			46,393			43,175
EBITDA		16,919			12,021			64,734			30,193			120,870			10,086		(3,878	)		8,051			39,909
Cumulative effect of accounting change		—			—			—			—			—			—		3,045			—			—
Reorganization items, net		—			—			—			—			(100,907	)		1,557		7,630			—			—
Adjusted EBITDA	$	16,919			12,021			64,734			30,193			19,963			11,643		6,797			8,051			39,909

 

(3) During the predecessor period, debt includes liabilities subject to compromise.

(4) For purposes of this computation, “earnings” consist of pre-tax income from continuing operations plus fixed charges. “Fixed charges” consist of interest expense on all indebtedness plus amortization of deferred costs of financing and the interest component of lease rental expense. Earnings were insufficient to cover fixed charges by $59.7 million, $67.2 million and $26.5 million for the years ended December 31, 2003, 2002 and 2001, respectively. Excluding the effect of the Triad acquisition, the pro forma ratio of earnings to fixed charges is 37.0 for the four months ended April 30, 2004 (Predecessor Company). The amount of the pro forma deficiency of earnings to fixed charges for the three months ended March 31, 2005 (Successor Company) and the eight months ended December 31, 2004 (Successor Company) is $1,585 and $4,376, respectively.

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The Offering

Common stock offered:
By James River Coal Company	1,500,000 shares
By selling shareholder	2,000,000 shares
Total	3,500,000 shares
Common stock to be outstanding after this offering	16,240,694 shares
Over-allotment option	The underwriters have an option to purchase 525,000 additional shares of our common stock from us to cover any over-allotments.
Use of proceeds	We estimate that we will receive gross proceeds of approximately $48.7 million from our sale of the common stock in this offering and $150.0 million from our sale of the notes in the concurrent offering. If the underwriters exercise their over-allotment option in full, we estimate that we will receive gross proceeds of approximately $65.8 million from our sale of common stock. We will not receive any of the proceeds from the sale of common stock by the selling shareholder.
	We intend to use the gross proceeds of this offering and the concurrent notes offering in the following manner:
	•approximately $95.0 million (without giving effect to payments since March 31, 2005) to repay amounts outstanding under our Senior Secured Credit Facility and our Term Credit Facility;
	•approximately $58.7 million to finance the Triad acquisition;
	•approximately $11.4 million for offering expenses, including underwriting discounts, and for the pre-payment penalty under our existing debt facilities; and
	•approximately $33.6 million for general corporate purposes, which may be used to fund internal growth projects or to reduce the underfunded portion of our pension plan.
	If the Triad acquisition is not consummated, the amount of the net proceeds of this offering and the concurrent notes offering available for general corporate purposes will increase commensurately. Completion of this common stock offering is not contingent upon completion of the notes offering. If the concurrent notes offering is not completed, proceeds of this offering will first be used to finance the Triad acquisition. See “Use of Proceeds.”
Dividend policy	We currently do not anticipate paying cash dividends on our shares of common stock in the near future.
Nasdaq National Market symbol	JRCC

 

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Concurrent Financings

Concurrently with this offering, we are also offering by separate prospectus $150 million aggregate principal amount of senior notes due 2012. Completion of this common stock offering is not contingent upon completion of the notes offering. We cannot assure you that we will complete the concurrent notes offering.

We also intend to enter into a proposed new $100 million senior secured credit facility. The proposed new senior secured credit facility is contingent upon completion of the Triad acquisition. See “Description of Indebtedness” for a description of the proposed new senior secured credit facility.

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RISK FACTORS

An investment in the shares offered hereby involves a significant degree of risk. You should carefully consider the risks described below and all other information contained in this prospectus before you decide to buy our common stock. While we have described all risks and uncertainties that we believe to be material to our business, it is possible that other risks and uncertainties that affect our business will arise or become material in the future.

Risks Related to the Coal Industry

Because the demand and pricing for coal is greatly influenced by consumption patterns of the domestic electricity generation industry, a reduction in the demand for coal by this industry would likely cause our profitability to decline significantly.

We derived 83% of our total revenues (contract and spot) in 2004, and 88% of our total revenue in 2003, from our electric utility customers. Fuel cost is a significant component of the cost associated with coal-fired power generation, with respect to not only the price of the coal, but also the costs associated with emissions control and credits (i.e., sulfur dioxide, nitrogen oxides, etc.), combustion by-product disposal (i.e., ash) and equipment operations and maintenance (i.e., materials handling facilities). All of these costs must be considered when choosing between coal generation and alternative methods, including natural gas, nuclear, hydroelectric and others.

Weather patterns also can greatly affect electricity generation. Extreme temperatures, both hot and cold, cause increased power usage and, therefore, increased generating requirements from all sources. Mild temperatures, on the other hand, result in lower electrical demand, which allows generators to choose the lowest-cost sources of power generation when deciding which generation sources to dispatch. Accordingly, significant changes in weather patterns could reduce the demand for our coal.

Overall economic activity and the associated demands for power by industrial users can have significant effects on overall electricity demand. Robust economic activity can cause much heavier demands for power, particularly if such activity results in increased utilization of industrial assets during evening and nighttime periods. The economic slowdown experienced during the last several years significantly slowed the growth of electrical demand and, in some locations, resulted in contraction of demand.

Any downward pressure on coal prices, whether due to increased use of alternative energy sources, changes in weather patterns, decreases in overall demand or otherwise, would likely cause our profitability to decline.

Deregulation of the electric utility industry may cause our customers to be more price-sensitive in purchasing coal, which could cause our profitability to decline.

Electric utility deregulation is expected to provide incentives to generators of electricity to minimize their fuel costs and is believed to have caused electric generators to be more aggressive in negotiating prices with coal suppliers. To the extent utility deregulation causes our customers to be more cost-sensitive, deregulation may have a negative effect on our profitability.

Changes in the export and import markets for coal products could affect the demand for our coal, our pricing and our profitability.

We compete in a worldwide market. The pricing and demand for our products is affected by a number of factors beyond our control. These factors include:

• currency exchange rates;

• growth of economic development; and

• ocean freight rates.

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Any decrease in the amount of coal exported from the United States, or any increase in the amount of coal imported into the United States, could have a material adverse impact on the demand for our coal, our pricing and our profitability.

Increased consolidation and competition in the U.S. coal industry may adversely affect our revenues and profitability.

During the last several years, the U.S. coal industry has experienced increased consolidation, which has contributed to the industry becoming more competitive. According to Platts, the world’s largest energy information provider, although there are more than 600 coal producers in the United States, the ten largest coal companies accounted for approximately 63% of total domestic coal production in 2003. Consequently, many of our competitors in the domestic coal industry are major coal producers who have significantly greater financial resources than us. The intense competition among coal producers may impact our ability to retain or attract customers and may therefore adversely affect our future revenues and profitability.

Fluctuations in transportation costs and the availability and dependability of transportation could affect the demand for our coal and our ability to deliver coal to our customers.

Increases in transportation costs could have an adverse effect on demand for our coal. Customers choose coal supplies based, primarily, on the total delivered cost of coal. Our coal is generally shipped via rail systems (CSX and Norfolk Southern), although we also transport a small portion of our coal by truck. During 2004, we shipped in excess of 95% of our coal via CSX. Any increase in transportation costs would cause an increase in the total delivered cost of coal. That could cause some of our customers to seek less expensive sources of coal or alternative fuels to satisfy their energy needs. In addition, significant decreases in transportation costs from other coal-producing regions, both domestic and international, could result in increased competition from coal producers in those regions. For instance, coal mines in the western U.S. could become more attractive as a source of coal to consumers in the eastern U.S. if the costs of transporting coal from the West were significantly reduced.

We depend primarily upon railroads, and, in particular, the CSX railroad, to deliver coal to our customers. Disruption of railroad service due to weather-related problems, strikes, lockouts, bottlenecks and other events could temporarily impair our ability to supply coal to our customers, resulting in decreased shipments. Decreased performance levels over longer periods of time could cause our customers to look elsewhere for their fuel needs, negatively affecting our revenues and profitability.

During 2004, the major eastern railroads (CSX and Norfolk Southern) experienced significant service problems. These problems were caused by an increase in overall rail traffic from the expanding economy and shortages of both equipment and personnel. The service problems had an adverse effect on our shipments during several months in 2004. If these service problems persist, they could have an adverse impact on our financial results in 2005 and beyond.

Also during 2004, both the State of West Virginia and the Commonwealth of Kentucky began to vigorously enforce loaded weight limits for trucks hauling coal on state and local roads. This has caused a disruption of service for several mining companies in our geographic area. These enforcement programs could disrupt our coal hauling service and/or impact hauling costs in the future.

Shortages or increased costs of skilled labor in the Central Appalachian coal region may hamper our ability to achieve high labor productivity and competitive costs.

Coal mining continues to be a labor-intensive industry. As the demand for coal has increased, many producers have attempted to increase coal production, which has resulted in a competitive market for the limited supply of trained coal miners in the Central Appalachian region. In some cases, this market situation has caused compensation levels to increase, particularly for “skilled” positions such as electricians and mine foremen. To maintain current production levels, we may be forced to respond to these increases in wages and other forms of compensation, and

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related recruiting efforts by our competitors. Any future shortage of skilled miners, or increases in our labor costs, could have an adverse impact on our labor productivity and costs and on our ability to expand production.

Government laws, regulations and other requirements relating to the protection of the environment, health and safety and other matters impose significant costs on us, and future requirements could limit our ability to produce coal.

We are subject to extensive federal, state and local regulations with respect to matters such as:

• employee health and safety;

• permitting and licensing requirements;

• air quality standards;

• water quality standards;

• plant, wildlife and wetland protection;

• the management and disposal of hazardous and non-hazardous materials generated by mining operations;

• the storage of petroleum products and other hazardous substances;

• reclamation and restoration of properties after mining operations are completed;

• discharge of materials into the environment, including air emissions and wastewater discharge;

• surface subsidence from underground mining; and

• the effects of mining operations on groundwater quality and availability.

Complying with these requirements, including the terms of our permits, has had, and will continue to have, a significant effect on our costs of operations. We could incur substantial costs, including clean up costs, fines, civil or criminal sanctions and third party claims for personal injury or property damage as a result of violations of or liabilities under these laws and regulations.

The coal industry is also affected by significant legislation mandating specified benefits for retired miners. In addition, the utility industry, which is the most significant end user of coal, is subject to extensive regulation regarding the environmental impact of its power generating activities. Coal contains impurities, including sulfur, mercury, chlorine and other elements or compounds, many of which are released into the air when coal is burned. Stricter environmental regulations of emissions from coal-fired electric generating plants could increase the costs of using coal thereby reducing demand for coal as a fuel source, the volume of our coal sales and price or could make coal a less attractive fuel alternative in the planning and building of utility power plants in the future.

New legislation, regulations and orders adopted or implemented in the future (or changes in interpretations of existing laws and regulations) may materially adversely affect our mining operations, our cost structure and our customers’ operations or ability to use coal.

The majority of our coal supply agreements contain provisions that allow the purchaser to terminate its contract if legislation is passed that either restricts the use or type of coal permissible at the purchaser’s plant or results in too great an increase in the cost of coal. These factors and legislation, if enacted, could have a material adverse effect on our financial condition and results of operations.

The passage of legislation responsive to the Framework Convention on Global Climate Change or similar governmental initiatives could result in restrictions on coal use.

The United States and more than 160 other nations are signatories to the 1992 Framework Convention on Global Climate Change, commonly known as the Kyoto Protocol, which is intended to limit or capture emissions of greenhouse gases, such as carbon dioxide. In December 1997, the signatories to the convention established a

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potentially binding set of emissions targets for developed nations. Although the specific emissions targets vary from country to country, the United States would be required to reduce emissions to 93% of 1990 levels over a five-year budget period from 2008 through 2012. The U.S. Senate has not ratified the treaty commitments, and the Bush administration has officially opposed the Kyoto Protocol and has proposed an alternative to reduce the intensity of United States emissions of greenhouse gases. With Russia’s ratification of the Kyoto Protocol in 2004, it became binding on all ratifying countries. The implementation of the Kyoto Protocol in a number of countries, and other emissions limits, such as those adopted by the European Union, could affect demand for coal outside the United States. If the Kyoto Protocol or other comprehensive legislation focusing on greenhouse gas emissions is enacted by the United States, it could have the effect of restricting the use of coal. Other efforts to reduce emissions of greenhouse gases and federal initiatives to encourage the use of natural gas also may affect the use of coal as an energy source.

We are subject to the federal Clean Water Act and similar state laws which impose treatment, monitoring and reporting obligations.

The federal Clean Water Act and corresponding state laws affect coal mining operations by imposing restrictions on discharges into regulated waters. Permits requiring regular monitoring and compliance with effluent limitations and reporting requirements govern the discharge of pollutants into regulated waters. New requirements under the Clean Water Act and corresponding state laws could cause us to incur significant additional costs that adversely affect our operating results.

New regulations have expanded the definition of black lung disease and generally made it easier for claimants to assert and prosecute claims, which could increase our exposure to black lung benefit liabilities.

In January 2001, the United States Department of Labor amended the regulations implementing the federal black lung laws to give greater weight to the opinion of a claimant’s treating physician, expand the definition of black lung disease and limit the amount of medical evidence that can be submitted by claimants and respondents. The amendments also alter administrative procedures for the adjudication of claims, which, according to the Department of Labor, results in streamlined procedures that are less formal, less adversarial and easier for participants to understand. These and other changes to the federal black lung regulations could significantly increase our exposure to black lung benefits liabilities.

In recent years, legislation on black lung reform has been introduced but not enacted in Congress. It is possible that this legislation will be reintroduced for consideration by Congress. If any of the proposals included in this or similar legislation is passed, the number of claimants who are awarded benefits could significantly increase. Any such changes in black lung legislation, if approved, may adversely affect our business, financial condition and results of operations.

Extensive environmental laws and regulations affect the end-users of coal and could reduce the demand for coal as a fuel source and cause the volume of our sales to decline.

The Clean Air Act and similar state and local laws extensively regulate the amount of sulfur dioxide, particulate matter, nitrogen oxides, mercury and other compounds emitted into the air from electric power plants, which are the largest end-users of our coal. Compliance with such laws and regulations, which can take a variety of forms, may reduce demand for coal as a fuel source because they require significant emissions control expenditures for coal-fired power plants to attain applicable ambient air quality standards, which may lead these generators to switch to other fuels that generate less of these emissions and may also reduce future demand for the construction of coal-fired power plants.

The U.S. Department of Justice, on behalf of the EPA, has filed lawsuits against several investor-owned electric utilities and brought an administrative action against one government-owned utility for alleged violations of the Clean Air Act. We supply coal to some of the currently-affected utilities, and it is possible that other of our customers will be sued. These lawsuits could require the utilities to pay penalties, install pollution control equipment or undertake other emission reduction measures, any of which could adversely impact their demand for our coal.

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A regional haze program initiated by the EPA to protect and to improve visibility at and around national parks, national wilderness areas and international parks restricts the construction of new coal-fired power plants whose operation may impair visibility at and around federally protected areas and may require some existing coal-fired power plants to install additional control measures designed to limit haze-causing emissions.

The Clean Air Act also imposes standards on sources of hazardous air pollutants. For example, the EPA has announced that it would regulate hazardous air pollutants from coal-fired power plants. Under the Clean Air Act, coal-fired power plants will be required to control hazardous air pollution emissions by no later than 2009, which likely will require significant new investment in controls by power plant operators. These standards and future standards could have the effect of decreasing demand for coal.

Other so-called multi-pollutant bills, which could regulate additional air pollutants, have been proposed by various members of Congress. If such initiatives are enacted into law, power plant operators could choose other fuel sources to meet their requirements, reducing the demand for coal.

The characteristics of coal may make it difficult for coal users to comply with various environmental standards related to coal combustion. As a result, they may switch to other fuels, which would affect the volume of our sales.

Coal contains impurities, including sulfur, nitrogen oxide, mercury, chlorine and other elements or compounds, many of which are released into the air when coal is burned. Stricter environmental regulations of emissions from coal-fired electric generating plants could increase the costs of using coal thereby reducing demand for coal as a fuel source, the volume of our coal sales and price. Stricter regulations could make coal a less attractive fuel alternative in the planning and building of utility power plants in the future.

For example, in order to meet the federal Clean Air Act limits for sulfur dioxide emissions from electric power plants, coal users may need to install scrubbers, use sulfur dioxide emission allowances (some of which they may purchase), blend high sulfur coal with low sulfur coal or switch to other fuels. Each option has limitations. Lower sulfur coal may be more costly to purchase on an energy basis than higher sulfur coal depending on mining and transportation costs. The cost of installing scrubbers is significant and emission allowances may become more expensive as their availability declines. Switching to other fuels may require expensive modification of existing plants.

On March 15, 2005, the U.S. Environmental Protection Agency adopted a new federal rule to cap and reduce mercury emissions from both new and existing coal-fired power plants. The reductions will be implemented in stages, primarily through a market-based cap-and-trade program. Nevertheless, the new regulations will likely require some power plants to install new equipment, at substantial cost, or discourage the use of certain coals containing higher levels of mercury.

Other new and proposed reductions in emissions of sulfur dioxides, nitrogen oxides, particulate matter or greenhouse gases may require the installation of additional costly control technology or the implementation of other measures, including trading of emission allowances and switching to other fuels. For example, the Environmental Protection Agency recently proposed separate regulations to reduce the interstate transport of fine particulate matter and ozone through reductions in sulfur dioxides and nitrogen oxides through the eastern United States. The Environmental Protection Agency continues to require reduction of nitrogen oxide emissions in 22 eastern states and the District of Columbia and will require reduction of particulate matter emissions over the next several years for areas that do not meet air quality standards for fine particulates. In addition, Congress and several states are now considering legislation to further control air emissions of multiple pollutants from electric generating facilities and other large emitters. These new and proposed reductions will make it more costly to operate coal-fired plants and could make coal a less attractive fuel alternative to the planning and building of utility power plants in the future. To the extent that any new or proposed requirements affect our customers, this could adversely affect our operations and results.

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We must obtain governmental permits and approvals for mining operations, which can be a costly and time consuming process and result in restrictions on our operations.

Numerous governmental permits and approvals are required for mining operations. Our operations are principally regulated under permits issued by the Kentucky Environmental and Public Protection Cabinet pursuant to the Surface Mining Control and Reclamation Act of 1977 (“SMCRA”). Regulatory authorities exercise considerable discretion in the timing and scope of permit issuance. Requirements imposed by these authorities may be costly and time consuming and may result in delays in the commencement or continuation of exploration or production operations. In addition, we often are required to prepare and present to federal, state and local authorities data pertaining to the effect or impact that proposed exploration for or production of coal might have on the environment. Further, the public may comment on and otherwise engage in the permitting process, including through intervention in the courts. Accordingly, the permits we need may not be issued, or, if issued, may not be issued in a timely fashion, or may involve requirements which restrict our ability to conduct our mining operations or to do so profitably.

Prior to placing excess fill material in valleys, coal mining companies are required to obtain a permit from the U.S. Army Corps of Engineers under Section 404 of the Clean Water Act. The permit can be either a simplified Nation Wide Permit #21 (“NWP 21”) or a more complicated individual permit. On July 8, 2004, U.S. District Judge Joseph R. Goodwin of the Southern District of West Virginia, Huntington Division found that NWP 21 is in violation of the Clean Water Act. This ruling applies only to certain counties in southern West Virginia (where we do not now operate) and does allow permits to continue to be issued under the more costly and time consuming individual permit process. It is possible that in the future, a similar ruling could be made for our operating areas.

In January 2005, a virtually identical claim to that filed in West Virginia was filed in Kentucky. The plaintiffs in this case, Kentucky River Keeper, Inc., et al. v. Colonel Robert A. Rowlette, Jr., et al., Civil Action No 05-CV-36-JBC, seek the same relief as that sought in West Virginia. Though the matter has just been initiated, it is possible that an adverse ruling could be made in this matter, which would have an adverse effect on our operations.

Litigation or regulatory changes resulting in restrictions on underground mining activities could impact our operations.

In the future, we intend to conduct underground mining activities on properties that are within federally protected lands or national forests or other potentially protected areas. Litigation challenging, or any future regulatory changes restricting, underground mining activities in such areas could impact our operations and/or lead to additional costs. For example, on March 29, 2002, the United States District Court for the District of Columbia issued a ruling that could restrict underground mining activities conducted in the vicinity of public roads, within a variety of federally protected lands, within national forests and within a certain proximity of occupied dwellings. The lawsuit, Citizens Coal Council v. Norton, was filed in February 2000 to challenge regulations issued by the Department of Interior providing, among other things, that subsidence and underground mining activities that may lead to subsidence are not surface mining activities within the meaning of SMCRA. SMCRA generally contains restrictions and certain prohibitions on the locations where surface mining activities can be conducted. The District Court entered summary judgment on the plaintiffs’ claims that the Secretary of the Interior’s determination violated SMCRA. This decision was later reversed by the United States Court of Appeals for the Fourth Circuit, which upheld the regulation. In February 2004, the U.S. Supreme Court denied a petition for a writ of certiorari filed by the Citizens Coal Council and others requesting U.S. Supreme Court review.

Any future litigation of this issue resulting in rulings similar to that of the above District Court decision, or future regulatory changes otherwise limiting the exceptions to surface mining activities under SMCRA discussed above, would pose a potential restriction on underground mining activities, such as those within 100 feet of a public road as well as other areas where we may conduct such activities. While, even if that occurs, it could remain possible to obtain permits for underground mining operations in these areas, the time and expense of that permitting process would be likely to increase significantly and any such restrictions placed on the mining of those properties could adversely affect our costs.

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We have significant reclamation and mine closure obligations. If the assumptions underlying our accruals are materially inaccurate, we could be required to expend greater amounts than anticipated.

The SMCRA establishes operational, reclamation and closure standards for all aspects of surface mining as well as many aspects of underground mining. We accrue for the costs of current mine disturbance and of final mine closure, including the cost of treating mine water discharge where necessary. Effective January 1, 2003, we adopted Statement of Financial Accounting Standards No. 143 (SFAS 143) to account for the costs related to the closure of mines and the reclamation of the land upon exhaustion of coal reserves. This statement requires the fair value of an asset retirement obligation to be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. At March 31, 2005, we had accrued $16.2 million related to estimated mine reclamation costs. These amounts recorded are dependent upon a number of variables, including the estimated future retirement costs, estimated proven reserves, assumptions involving profit margins, inflation rates, and the assumed credit-adjusted risk-free interest rates. Furthermore, these obligations are unfunded. If these accruals are insufficient or our liability in a particular year is greater than currently anticipated, our future operating results could be adversely affected.

Terrorist attacks and threats, escalation of military activity in response to such attacks or acts of war may negatively affect our business, financial condition and results of operations.

Terrorist attacks and threats, escalation of military activity in response to such attacks or acts of war may negatively affect our business, financial condition and results of operations. Our business is affected by general economic conditions, fluctuations in consumer confidence and spending, and market liquidity, which can decline as a result of numerous factors outside of our control, such as terrorist attacks and acts of war. Future terrorist attacks against U.S. targets, rumors or threats of war, actual conflicts involving the United States or its allies, or military or trade disruptions affecting our customers could cause delays or losses in transportation and deliveries of coal to our customers, decreased sales of our coal and extension of time for payment of accounts receivable from our customers. Strategic targets such as energy-related assets may be at greater risk of future terrorist attacks than other targets in the United States. In addition, disruption or significant increases in energy prices could result in government-imposed price controls. It is possible that any, or a combination, of these occurrences could have a material adverse effect on our business, financial condition and results of operations.

Risks Related to Our Operations

The loss of, or significant reduction in, purchases by our largest customers could adversely affect our revenues.

For 2004, we generated approximately 71% of our total revenues from several long-term contracts with electrical utilities, including 30% from our largest customer, Georgia Power Company, and 20% from South Carolina Public Service Authority. At December 31, 2004, we had coal supply agreements with these customers that expire at various times from 2005 to 2007. In addition, in 2004, Triad generated virtually all of its revenue from long-term contracts with four customers, including 49% from Indianapolis Power and Light, 20% from Vectren Fuels, 20% from Hoosier Energy Rural Electric Cooperative and 11% from Alcoa Power Generating. The execution of a substantial coal supply agreement is frequently the basis on which we undertake the development of coal reserves required to be supplied under the contract.

Many of our coal supply agreements contain provisions that permit adjustment of the contract price upward or downward at specified times. Failure of the parties to agree on a price under those provisions may allow either party to either terminate the contract or reduce the coal to be delivered under the contract. Coal supply agreements also typically contain force majeure provisions allowing temporary suspension of performance by the customer or us during the duration of specified events beyond the control of the affected party. Most coal supply agreements contain provisions requiring us to deliver coal meeting quality thresholds for certain characteristics such as:

• British thermal units (Btu’s);

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• sulfur content;

• ash content;

• grindability; and

• ash fusion temperature.

In some cases, failure to meet these specifications could result in economic penalties, including price adjustments, the rejection of deliveries or termination of the contracts. In addition, all of our contracts allow our customers to renegotiate or terminate their contracts in the event of changes in regulations or other governmental impositions affecting our industry that increase the cost of coal beyond specified limits. Further, we and Triad have been required in the past to purchase sulfur credits or make other pricing adjustments to comply with contractual requirements of our customers relating to the sulfur content of coal sold to them, and may be required to do so in the future.

The operating profits we realize from coal sold under supply agreements depend on a variety of factors. In addition, price adjustment and other provisions may increase our exposure to short-term coal price volatility provided by those contracts. If a substantial portion of our coal supply agreements are modified or terminated, we could be materially adversely affected to the extent that we are unable to find alternate buyers for our coal at the same level of profitability. The current strength in the coal market may not continue. As a result, we might not be able to replace existing long-term coal supply agreements at the same prices or with similar profit margins when they expire.

Our profitability will be negatively impacted if we are unable to balance our mix of contract and spot sales.

We have implemented a sales plan that includes long-term contracts (greater than one year) and spot sales/short-term contracts (less than one year). We have structured our sales plan based on the assumptions that demand will remain adequate to maintain current shipping levels and that any disruptions in the market will be relatively short-lived. If we are unable to maintain a balance of contract sales with spot sales, or our markets become depressed for an extended period of time, our volumes and margins could decrease, negatively affecting our profitability.

Our ability to operate our company effectively could be impaired if we lose senior executives or fail to employ needed additional personnel.

The loss of senior executives could have a material adverse effect on our business. There may be a limited number of persons with the requisite experience and skills to serve in our senior management positions. We may not be able to locate or employ qualified executives on acceptable terms. In addition, as our business develops and expands, we believe that our future success will depend greatly on our continued ability to attract and retain highly skilled and qualified personnel. We might not continue to be able to employ key personnel, or to attract and retain qualified personnel in the future. Failure to retain senior executives or attract key personnel could have a material adverse effect on our operations and financial results.

Unexpected increases in raw material costs could significantly impair our operating results.

Our coal mining operations use significant amounts of steel, petroleum products and other raw materials in various pieces of mining equipment, supplies and materials, including the roof bolts required by the room and pillar method of mining described below. Scrap steel prices have risen significantly in recent months, and historically, the prices of scrap steel and petroleum have fluctuated. If the price of steel or other of these materials increase, our operational expenses will increase, which could have a significant negative impact on our operating results.

Coal mining is subject to conditions or events beyond our control, which could cause our quarterly or annual results to deteriorate.

Our coal mining operations are conducted, in large part, in underground mines and, to a lesser extent, at surface mines. These mines are subject to conditions or events beyond our control that could disrupt operations, affect

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production and the cost of mining at particular mines for varying lengths of time and have a significant impact on our operating results. These conditions or events have included:

• variations in thickness of the layer, or seam, of coal;

• variations in geological conditions;

• amounts of rock and other natural materials intruding into the coal seam;

• equipment failures and unexpected major repairs;

• unexpected maintenance problems;

• unexpected departures of one or more of our contract miners;

• fires and explosions from methane and other sources;

• accidental minewater discharges or other environmental accidents;

• other accidents or natural disasters; and

• weather conditions.

Mining in Central Appalachia is complex due to geological characteristics of the region.

The geological characteristics of coal reserves in Central Appalachia, such as depth of overburden and coal seam thickness, make them complex and costly to mine. As mines become depleted, replacement reserves may not be available when required or, if available, may not be capable of being mined at costs comparable to those characteristic of the depleting mines. These factors could materially adversely affect the mining operations and cost structures of, and customers’ ability to use coal produced by, operators in Central Appalachia, including us.

Our future success depends upon our ability to acquire or develop additional coal reserves that are economically recoverable.

Our recoverable reserves decline as we produce coal. Since we attempt, where practical, to mine our lowest-cost reserves first, we may not be able to mine all of our reserves as profitably as we do at our current operations. Our planned development and exploration projects might not result in significant additional reserves, and we might not have continuing success developing additional mines. For example, our construction of additional mining facilities necessary to exploit our reserves could be delayed or terminated due to various factors, including unforeseen geological conditions, weather delays or unanticipated development costs. Our ability to acquire additional coal reserves in the future also could be limited by restrictions under our existing or future debt facilities, competition from other coal companies for attractive properties, or the lack of suitable acquisition candidates.

In order to develop our reserves, we must receive various governmental permits, as discussed in “Government Regulation” below. We have not yet applied for the permits required or developed the mines necessary to mine all of our reserves. In addition, we might not continue to receive the permits necessary for us to operate profitably in the future. We may not be able to negotiate new leases from the government or from private parties or obtain mining contracts for properties containing additional reserves or maintain our leasehold interests in properties on which mining operations are not commenced during the term of the lease.

Our financial performance may suffer if we do not successfully develop our new mine at the McCoy Elkhorn mining complex.

We are currently developing a new underground mine at our McCoy Elkhorn mining complex. This mine will be below drainage; in other words, because the coal seam does not intersect the surface in the vicinity of the mining area, it must be accessed through excavated passageways from the surface. Accordingly, we were required to construct a slope and a shaft for the transportation of miners, equipment and supplies to the mine. The time, expense and risk of developing such a below drainage mine may be greater than those of a drift mine. The capital expenditures

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required for this mine and the related preparation plant upgrade are expected to be approximately $23 million in 2005.

If our actual capital expenditures exceed forecasted levels, if mining conditions are less favorable than expected or if we are unable to successfully implement our planned development and production schedule for this new mine (including potential delays caused by weather, unforeseen geological conditions or otherwise), our financial performance could be negatively affected.

Factors beyond our control could impact the amount and pricing of coal supplied by our independent contractors and other third parties.

In addition to coal we produce from our Company-operated mines, we have mines that typically are operated by independent contract mine operators, and we purchase coal from third parties for resale. For 2005, we anticipate approximately 11% of our total production will come from mines operated by independent contract mine operators and that almost 2% of our total coal sold will come from third party purchased coal sources. Operational difficulties, changes in demand for contract mine operators from our competitors and other factors beyond our control could affect the availability, pricing and quality of coal produced for us by independent contract mine operators. The demand for contract mining companies has increased significantly due to the current strong market prices for coal from central Appalachia. Due to our bankruptcy and the current strong market conditions, we lost the services of several contract mining companies beginning in 2003 and continuing in 2004. We are actively recruiting replacements for these operators lost in 2004. Disruptions in supply, increases in prices paid for coal produced by independent contract mine operators or purchased from third parties, or the availability of more lucrative direct sales opportunities for our purchased coal sources could increase our costs or lower our volumes, either of which could negatively affect our profitability.

We face significant uncertainty in estimating our recoverable coal reserves, and variations from those estimates could lead to decreased revenues and profitability.

Forecasts of our future performance are based on estimates of our recoverable coal reserves. Estimates of those reserves are based on studies conducted by Marshall Miller & Associates, Inc. in accordance with industry-accepted standards. A number of sources of information were used to determine recoverable reserves estimates, including:

• currently available geological, mining and property control data and maps;

• our own operational experience and that of our consultants;

• historical production from similar areas with similar conditions;

• previously completed geological and reserve studies;

• the assumed effects of regulations and taxes by governmental agencies; and

• assumptions governing future prices and future operating costs.

Reserve estimates will change from time to time to reflect, among other factors:

• mining activities;

• new engineering and geological data;

• acquisition or divestiture of reserve holdings; and

• modification of mining plans or mining methods.

Therefore, actual coal tonnage recovered from identified reserve areas or properties, and costs associated with our mining operations, may vary from estimates. These variations could be material, and therefore could result in decreased profitability. For a further discussion of our coal reserves, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Estimates” and “Business—Reserves.”

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Our operations could be adversely affected if we are unable to obtain required surety bonds.

Federal and state laws require bonds to secure our obligations to reclaim lands used for mining, to pay federal and state workers’ compensation and to satisfy other miscellaneous obligations. As of March 31, 2005, we had outstanding surety bonds with third parties for post-mining reclamation totaling $26.6 million. Furthermore, we have surety bonds for an additional $42.8 million in place for our federal and state workers’ compensation obligations and other miscellaneous obligations. Insurance companies have informed us, along with other participants in the coal industry, that they no longer will provide surety bonds for workers’ compensation and other post-employment benefits without collateral. We have satisfied our obligations under these statutes and regulations by providing letters of credit or other assurances of payment. However, letters of credit can be significantly more costly to us than surety bonds. The issuance of letters of credit under our senior secured credit facility also reduces amounts that we can borrow under our senior secured credit facility for other purposes. If we are unable to secure surety bonds for these obligations in the future, and are forced to secure letters of credit indefinitely, our profitability may be negatively affected.

We have significant unfunded obligations for long-term employee benefits for which we accrue based upon assumptions, which, if incorrect, could result in us being required to expend greater amounts than anticipated.

We are required by law to provide various long-term employee benefits. We accrue amounts for these obligations based on the present value of expected future costs. We employed an independent actuary to complete estimates for our workers’ compensation and black lung (both state and federal) obligations. At March 31, 2005, the current and non-current portions of these obligations included $26.0 million for coal workers’ black lung benefits and $50.5 million for workers’ compensation benefits.

We use a valuation method under which the total present and future liabilities are booked based on actuarial studies. Our independent actuary updates these liability estimates annually. However, if our assumptions are incorrect, we could be required to expend greater amounts than anticipated. All of these obligations are unfunded. In addition, the federal government and the governments of the states in which we operate consider changes in workers’ compensation laws from time to time. Such changes, if enacted, could increase our benefit expenses and payments.

We may be unable to adequately provide funding for our pension plan obligations based on our current estimates of those obligations.

We provide pension benefits to eligible employees. As of December 31, 2004, we estimated that our pension plan was underfunded by approximately $21.9 million. As of the same date, we had long-term pension obligations of $15.7 million, with the difference between that amount and the underfunded amount due to unamortized actuarial losses. As of March 31, 2005, we had long-term pension obligations of $15.2 million. If future payments are insufficient to fund the pension plan adequately to cover our future pension obligations, we could incur cash expenditures and costs materially higher than anticipated. The pension obligation is calculated annually and is based on several assumptions, including then prevailing conditions, which may change from year to year. In any year, if our assumptions are inaccurate, we could be required to expend greater amounts than anticipated.

As a result of our adoption of “fresh start” accounting in connection with our emergence from bankruptcy, you will not be able to compare our financial statements for periods before our emergence from bankruptcy with our financial results for periods after our emergence from bankruptcy.

As a result of the consummation of our Plan of Reorganization and the transactions contemplated thereby, we are operating our business under a new capital structure. In addition, we became subject to the fresh start accounting rules upon emerging from bankruptcy. Accordingly, our financial condition and results of operations disclosed for periods after our emergence from bankruptcy differ significantly from the financial condition or results of operations reflected in our financial statements for periods before our emergence from bankruptcy.

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Substantially all of our assets are subject to security interests.

Substantially all of our cash, receivables, inventory and other assets are subject to various liens and security interests, including a first lien held by Wells Fargo Foothill, Inc. securing our existing senior secured credit facility and a second lien held by our pre-bankruptcy senior secured lenders securing our restructured term debt. Assuming we refinance these obligations with the proceeds of this offering and our concurrent notes offering and enter into our proposed new senior secured credit facility, substantially all of our assets, including the capital stock of our subsidiaries, and, following the Triad acquisition, the capital stock of Triad and substantially all of its assets will be pledged to secure our obligations under our proposed new senior secured credit facility. If one of these security interest holders becomes entitled to exercise its rights as a secured party, it would have the right to foreclose upon and sell, or otherwise transfer, the collateral subject to its security interest, and the collateral accordingly would be unavailable to us and our other creditors, except to the extent, if any, that other creditors have a superior or equal security interest in the affected collateral or the value of the affected collateral exceeds the amount of indebtedness in respect of which these foreclosure rights are exercised.

We may be unable to comply with restrictions imposed by the terms of our indebtedness, which could result in a default under these agreements.

Our existing loan agreements impose, and our proposed new senior secured credit facility and the notes will impose, a number of restrictions on us. A failure to comply with these restrictions could adversely affect our ability to borrow under our senior secured credit facility or, following the refinancing transactions, our proposed new senior secured credit facility, or result in an event of default under these agreements and our other debt. Our credit facilities contain financial and other covenants that create limitations on our ability to, among other things, borrow the full amount under the revolver component of our senior secured credit facility or incur additional debt, and require us to maintain various financial ratios and comply with various other financial covenants. These covenants, under our existing loan agreements, include the following requirements:

• minimum fixed charge coverage ratio;

• maximum total leverage ratio;

• minimum levels of consolidated tangible net worth;

• minimum levels of Consolidated Total EBITDA (as defined in our credit facilities); and

• maximum limits on capital expenditures.

We expect our proposed new senior secured credit facility to have similar financial covenants.

In the event of a default, our lenders could terminate their commitments to us and declare all amounts borrowed, together with accrued interest and fees, immediately due and payable. If this were to occur, we might not be able to pay these amounts or we might be forced to seek an amendment to our debt agreements which could make the terms of these agreements more onerous for us and require the payment of amendment or waiver fees. Failure to comply with these restrictions, even if waived by our lenders, also could adversely affect our credit ratings, which could increase the costs of debt financings to us and impair our ability to obtain additional debt financing.

Changes in our credit ratings could adversely affect our costs and expenses.

Any downgrade in our credit ratings could adversely affect our ability to borrow and result in more restrictive borrowing terms, including increased borrowing costs, more restrictive covenants and the extension of less open credit. This, in turn, could affect our internal cost of capital estimates and therefore impact operational decisions.

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Defects in title or loss of any leasehold interests in our properties could limit our ability to mine these properties or result in significant unanticipated costs.

We conduct substantially all of our mining operations on properties that we lease. The loss of any lease could adversely affect our ability to mine the associated reserves. Because we generally do not obtain title insurance or otherwise verify title to our leased properties, our right to mine some of our reserves has been in the past, and may again in the future, be adversely affected if defects in title or boundaries exist. In order to obtain leases or rights to conduct our mining operations on property where these defects exist, we have had to, and may in the future have to, incur unanticipated costs. In addition, we may not be able to successfully negotiate new leases for properties containing additional reserves. Some leases have minimum production requirements. Failure to meet those requirements could result in losses of prepaid royalties and, in some rare cases, could result in a loss of the lease itself.

Inability to satisfy contractual obligations may adversely affect our profitability.

From time to time, we have disputes with our customers over the provisions of long-term contracts relating to, among other things, coal quality, pricing, quantity and delays in delivery. In addition, we may not be able to produce sufficient amounts of coal to meet our commitments to our customers. Our inability to satisfy our contractual obligations could result in our need to purchase coal from third party sources to satisfy those obligations or may result in customers initiating claims against us. We may not be able to resolve all of these disputes in a satisfactory manner, which could result in substantial damages or otherwise harm our relationships with customers.

The disallowance or early termination of Section 29 tax credits for synfuel plants by the Internal Revenue Service could decrease our revenues.

We supply coal to a third party synfuel plant and receive fees for the handling, shipping and marketing of the synfuel product. Synfuel is a synthetic fuel product that is produced by chemically altering coal. In 2004, 2% of our total revenues came from synfuel handling, shipping and marketing revenues. Sales of the fuel processed through these types of facilities are eligible for non-conventional fuels tax credits under Section 29 of the Internal Revenue Code. The owner of the facility that we supply with coal has obtained a Private Letter Ruling (“PLR”) from the Internal Revenue Service confirming that the facility produces a qualified fuel eligible for Section 29 tax credits. The Section 29 tax credit program is scheduled to expire on December 31, 2007. There is a risk that the IRS could modify or disallow the Section 29 tax credit, or (in certain circumstances related to the market price of oil), terminate the credit earlier than expected, making operation of the synfuel plant unprofitable. If the synfuel plant ceases operations, we will no longer receive the handling, shipping and marketing fees for our services, which may negatively affect our profitability.

Our auditors have previously identified material weaknesses in our internal controls. Although we have remediated these material weaknesses, if additional internal control issues develop, we may be unable to accurately report our financial results, detect fraud or comply with the requirements of Section 404 of the Sarbanes-Oxley Act.

In August 2004, our independent auditors advised our Audit Committee that they had identified material weaknesses in our internal controls in connection with the audit of our 2003 financial statements. First, our auditors identified a material weakness related to our controls around the data provided to our actuaries that was used in the actuarial valuation of our workers’ compensation and black lung benefit obligations. This material weakness led to a restatement of our 2002 and 2001 financial statements. Second, our auditors identified a material weakness related to the lack of controls over our year-end financial closing process and our ability to produce accurate consolidated financial statements. This weakness resulted in a significant number of audit adjustments that materially changed our preliminary 2003 consolidated financial statements. Our independent auditors also identified a need to add to the staff and strengthen the overall skills of our accounting department. We undertook remedial actions related to these material weaknesses. During the audit of our 2004 consolidated financial statements, our independent auditors did not identify any material weaknesses; however, their audit was not designed for the purpose of forming an opinion on the assessment or effectiveness of our internal controls over financial reporting.

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Beginning with our annual report for the year ending December 31, 2005, Section 404 of the Sarbanes-Oxley Act of 2002, or Section 404, will require us to include an internal control report of management with our annual report on Form 10-K. That report must include management’s assessment of the effectiveness of our internal control over financial reporting as of the end of the fiscal year and will also include our independent auditors’ evaluation of management’s assessment and effectiveness of our internal control over financial reporting.

Achieving compliance with Section 404 within the prescribed period, and remedying any deficiencies, significant deficiencies or additional material weaknesses that we or our auditors may identify, will require us to incur significant costs and expend significant time and management resources. We cannot assure you that any of the measures we implement to remedy any such deficiencies will effectively mitigate or remediate such deficiencies. In addition, we cannot assure you that we will be able to complete the work necessary for our management to issue its management report in a timely manner, or that we will be able to complete any work required for our management to be able to conclude that our internal control over financial reporting is effective. If we fail to timely remedy any deficiencies, significant deficiencies or additional material weaknesses that we or our auditors may identify, we may be unable to accurately report our financial results, detect fraud or comply with the requirements of Section 404. In addition, we can give no assurance that our independent auditors will agree with our management’s assessment or conclude that our internal control over financial reporting is effective.

We may be unable to exploit opportunities to diversify our operations.

Our future business plan may consider opportunities other than underground and surface mining in eastern Kentucky and, if the Triad acquisition is completed, Southern Indiana. We will consider opportunities to further increase the percentage of coal that comes from surface mines. We may also consider opportunities to expand both surface and underground mining activities in areas that are outside of eastern Kentucky and, if the Triad acquisition is completed, Southern Indiana. We may also consider opportunities in other energy-related areas, which are not prohibited by the Indenture governing our proposed new senior notes due 2012. If we undertake these diversification strategies and fail to execute them successfully, our financial condition and results of operations may be adversely affected.

There are risks associated with our acquisition strategy, including our inability to successfully complete acquisitions, our assumption of liabilities, dilution of your investment, significant costs and additional financing required.

We intend to expand our operations through strategic acquisitions of other coal mining companies, although we have no agreement, other than with respect to Triad, and no understanding for any other acquisition. Risks associated with our current and potential acquisitions include the disruption of our ongoing business, problems retaining the employees of the acquired business, assets acquired proving to be less valuable than expected, the potential assumption of unknown or unexpected liabilities, costs and problems, the inability of management to maintain uniform standards, controls, procedures and policies, the difficulty of managing a larger company, the risk of becoming involved in labor, commercial or regulatory disputes or litigation related to the new enterprises and the difficulty of integrating the acquired operations and personnel into our existing business.

We may choose to use shares of our common stock or other securities to finance a portion of the consideration for future acquisitions, either by issuing them to pay a portion of the purchase price or selling additional shares to investors to raise cash to pay a portion of the purchase price. If shares of our common stock do not maintain sufficient market value or potential acquisition candidates are unwilling to accept shares of our common stock as part of the consideration for the sale of their businesses, we will be required to raise capital through additional sales of debt or equity securities, which might not be possible, or forego the acquisition opportunity, and our growth could be limited. In addition, securities issued in such acquisitions may dilute the holdings of our current or future shareholders.

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The proceeds of our proposed financing transactions may not be sufficient to finance any additional acquisitions.

We believe that the estimated net proceeds from this offering and the concurrent notes offering, and available borrowings under our proposed new senior secured credit facility, will be adequate to refinance our existing debt and satisfy our cash costs of the Triad acquisition and our operating and capital requirements for at least the next 12 months. However, such proceeds likely will not provide sufficient cash to fund any acquisitions beyond the Triad acquisition. Accordingly, we may need to conduct additional debt or equity financings in order to fund any such additional acquisitions, unless we issue shares of our common stock as consideration for those acquisitions. If we are unable to obtain any such financings, we may be required to forego future acquisition opportunities.

Because we do not have a combined operating history with Triad, historical financial information is not necessarily a good indicator of future results of operations or financial condition, and we may be unable to successfully integrate those operations.

The financial information regarding Triad included in this prospectus reflects Triad’s operations as an independent entity, and may not be indicative of Triad’s future results of operation or financial condition as a part of our combined operations. In addition, we may be unable to successfully integrate Triad’s operations, or to operate those operations profitably. Our failure to successfully integrate Triad’s operations would have a material adverse effect on our results of operations and financial conditions.

Allocation of the excess of the purchase price we expect to pay for Triad over the book value of Triad’s fixed assets may impact our future earnings.

Information in certain sections of this prospectus, including adjustments made in “Unaudited Pro Forma Condensed Consolidated Financial Statements,” reflects our preliminary estimate of the allocation of the purchase price in the Triad acquisition. This allocation will likely change after we receive and further analyze additional information (including third party appraisals we intend to obtain) about the fair value of Triad’s assets and liabilities. Any increases in the purchase price allocated to mineral rights, property, plant and equipment, favorable coal supply agreements or other identifiable intangible assets would result in additional depreciation, depletion and amortization expense that is not included in our current estimate. That amount could be significant, and could have a material impact on our future earnings. In addition, while the amount allocated to goodwill is not amortized into earnings, we will be required to assess the carrying amount of goodwill for possible impairment at least annually—any such impairment could have a material impact on our future earnings.

Our company could be less valuable if we are unable to close the Triad acquisition.

The Triad acquisition would significantly increase our surface mining operations, thereby creating more balance between our surface and underground operations. However, the Triad acquisition is subject to certain conditions, including obtaining financing on terms and conditions approved by our Board of Directors, and will not close unless we and other relevant parties satisfy or waive all of these conditions. We cannot assure you that we or any relevant party will be able to satisfy the conditions required to close the acquisition. The completion of this offering and the concurrent notes offering is not conditioned upon the completion of the Triad acquisition.

A failure to close the Triad acquisition, or a substantial delay in closing, could have a material adverse effect upon our business prospects, financial condition and results of operations. We would possess significantly more limited surface mining operations, as well as fewer reserves. For information about the Triad acquisition, including the conditions to which the acquisition is subject, see “The Triad Acquisition.” For information about Triad’s operations, see “Business—Triad.” For information about the effect of the acquisition on our financial condition and results of operations, see “Unaudited Pro Forma Condensed Consolidated Financial Statements.”

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Triad’s current reserve base is limited.

Triad’s mines currently have rights to proven and probable reserves that we believe will be exhausted in four years at 2004 levels of production, compared to our current mining complexes, which have reserves that we believe will last in excess of 25 years, on average, at 2004 levels of production. If we complete the Triad acquisition, we intend to increase Triad’s reserves by acquiring rights to additional exploitable reserves that are either adjacent to or nearby Triad’s current reserves. If we are unable to successfully acquire such rights on acceptable terms, or if our exploration or acquisition activities indicate that such coal reserves or rights do not exist or are not available on acceptable terms, our production and revenues will decline as our reserves in that region are depleted. Exhaustion of reserves at particular mines also may have an adverse effect on our operating results that is disproportionate to the percentage of overall production represented by such mines. For information about the Triad acquisition, including the conditions to which the acquisition is subject, see “The Triad Acquisition.”

Surface mining is subject to increased regulation, and may require us to incur additional costs.

Our surface mining operations will increase significantly if we acquire Triad. Surface mining is subject to numerous regulations related to blasting activities that can result in additional costs. For example, when blasting in close proximity to structures, additional costs are incurred in designing and implementing more complex blast delay regimens, conducting pre-blast surveys and blast monitoring, and the risk of potential blast-related damages increases. Since the nature of surface mining requires ongoing disturbance to the surface, environmental compliance costs can be significantly greater than with underground operations. In addition, the U.S. Army Corps of Engineers imposes stream mitigation requirements on surface mining operations. These regulations require that footage of stream loss be replaced through various mitigation processes, if any ephemeral, intermittent, or perennial streams are in-filled due to mining operations. These regulations may cause us to incur significant additional costs, which could adversely impact our operating performance.

Risks Relating to our Common Stock

The market price of our common stock has been volatile and difficult to predict, and may continue to be volatile and difficult to predict after the offering, and the value of your investment may decline.

The market price of our common stock has been volatile in the past and may continue to be volatile after the offering. The market price of our common stock will be affected by, among other things:

• variations in our quarterly operating results;

• changes in financial estimates by securities analysts;

• changes in general conditions in the economy or the financial markets;

• changes in accounting standards, policies or interpretations;

• other developments affecting us, our industry, clients or competitors; and

• the operating and stock price performance of companies that investors deem comparable to us.

Any of these factors could have a negative effect on the price of our common stock on the Nasdaq National Market, make it difficult to predict the market price for our common stock after the offering and cause the value of your investment to decline.

Dividends are prohibited by our existing loan agreements and will be limited by our proposed new senior secured credit facility and senior notes.

We do not anticipate paying any cash dividends on our common stock in the near future. In addition, covenants in our proposed new senior secured credit facility and senior notes will restrict our ability to pay cash dividends and may prohibit the payment of dividends and certain other payments.

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Provisions of our articles of incorporation, bylaws and shareholder rights agreements could discourage potential acquisition proposals and could deter or prevent a change in control.

Some provisions of our articles of incorporation and bylaws, as well as Virginia statutes, may have the effect of delaying, deferring or preventing a change in control. These provisions may make it more difficult for other persons, without the approval of our Board of Directors, to make a tender offer or otherwise acquire substantial amounts of our common stock or to launch other takeover attempts that a shareholder might consider to be in such shareholder’s best interest. These provisions could limit the price that some investors might be willing to pay in the future for shares of our common stock.

On May 25, 2004, our shareholders approved a rights agreement which, in certain circumstances, including a person or group acquiring, or the commencement of a tender or exchange offer that would result in a person or group acquiring, beneficial ownership of more than 15% of the outstanding shares of our common stock, would entitle each right holder, other than the person or group triggering the plan, to receive, upon exercise of the right, shares of our common stock having a then-current fair value equal to twice the exercise price of a right. This shareholder rights agreement provides us with a defensive mechanism that decreases the risk that a hostile acquirer will attempt to take control of us without negotiating directly with our board of directors. The shareholder rights agreement may discourage acquirers from attempting to purchase us, which may adversely affect the price of our common stock.

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FORWARD LOOKING STATEMENTS

From time to time, we make certain comments and disclosures in reports and statements, including this prospectus, or statements made by our officers, which may be forward-looking in nature. These statements are known as “forward-looking statements,” as that term is used in Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Examples include statements related to our future outlook, anticipated capital expenditures, future cash flows and borrowings, and sources of funding. These forward-looking statements could also involve, among other things, statements regarding our intent, belief or expectation with respect to:

• our cash flows, results of operation or financial condition;

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

• governmental policies and regulatory actions;

• legal and administrative proceedings, settlements, investigations and claims;

• weather conditions or catastrophic weather-related damage;

• our production capabilities;

• availability of transportation;

• market demand for coal, electricity and steel;

• competition;

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

• employee workforce factors;

• our assumptions concerning economically recoverable coal reserve estimates;

• future economic or capital market conditions;

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

• the closing or successful integration of the Triad acquisition.

Any forward-looking statements are subject to the risks and uncertainties that could cause actual cash flows, results of operations, financial condition, cost reductions, acquisitions, dispositions, financing transactions, operations, expansion, consolidation and other events to differ materially from those expressed or implied in such forward-looking statements. Any forward-looking statements are also subject to a number of assumptions regarding, among other things, future economic, competitive and market conditions generally. These assumptions would be based on facts and conditions as they exist at the time such statements are made as well as predictions as to future facts and conditions, the accurate prediction of which may be difficult and involve the assessment of events beyond our control.

We wish to caution readers that forward-looking statements, including disclosures which use words such as “believe,” “intend,” “expect,” “may,” “should,” “anticipate,” “could,” “estimate,” “plan,” “predict,” “project,” or their negatives, and similar statements, are subject to certain risks and uncertainties which could cause actual results to differ materially from expectations. These risks and uncertainties include, but are not limited to, the following: a change in the demand for coal by electric utility customers; the loss of one or more of our largest customers; our dependency on one railroad for transportation of our products; failure to exploit additional coal reserves; failure to diversify our operations; increased capital expenditures; increased compliance costs; lack of availability of financing sources; the effects of regulation and competition; the failure to close or successfully integrate the Triad acquisition; and the risk factors set forth in the section of this prospectus called “Risk Factors.” Those are representative of factors that could affect the outcome of the forward-looking statements. These and the other factors discussed elsewhere in this prospectus are not necessarily all of the important factors that could cause our results

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to differ materially from those expressed in our forward-looking statements. Forward-looking statements speak only as of the date they are made and we undertake no obligation to update them.

MARKET FOR OUR COMMON STOCK

On January 25, 2005, our common stock commenced trading on the Nasdaq National Market under the symbol “JRCC”. Following our emergence from bankruptcy on May 6, 2004, our common stock was quoted on the Pink Sheets Electronic Quotation Service, and, commencing on November 15, 2004, on the Over-the-Counter Bulletin Board, before trading on the Nasdaq National Market. The table below sets forth the high and low sales prices for our common stock for the periods indicated, as reported by Nasdaq or quoted through the OTC Bulletin Board. The per share quotations for the periods in which our common stock was traded in the over-the-counter market represent inter-dealer prices without adjustment for retail mark-ups, mark-downs or commissions and may not necessarily represent actual transactions.

	Price Range of Common Stock
	High		Low
Year Ended December 31, 2004
Fourth Quarter	$	59.00	$	34.25
Year Ending December 31, 2005
First Quarter	$	45.75	$	37.41
Second Quarter (through May 24, 2005)	$	40.50	$	28.64

 

As of February 24, 2005, there were approximately 104 record holders of our common stock (excluding individual participants in nominee security position listings). The closing price of our common stock as reported by the Nasdaq National Market on May 24, 2005 was $32.99.

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USE OF PROCEEDS

We estimate that we will receive gross proceeds of approximately $48.7 million from our sale of the common stock in this offering, and $150.0 million from our sale of the notes in the concurrent offering. If the underwriters exercise their over-allotment option in full, we estimate that we will receive gross proceeds of approximately $65.8 million from our sale of common stock. We will not receive any of the proceeds from the sale of common stock by the selling shareholder.

We intend to use the aggregate gross proceeds of approximately $198.7 million from this offering and the concurrent notes offering in the following manner:

• approximately $95.0 million (without giving effect to payments since March 31, 2005) to repay amounts outstanding under our Senior Secured Credit Facility and our Term Credit Facility;

• approximately $58.7 million to finance the Triad acquisition;

• approximately $11.4 million for offering expenses, including underwriting discounts, and for the pre-payment penalty under our existing debt facilities; and

• approximately $33.6 million for general corporate purposes, which may be used to fund internal growth projects or to reduce the underfunded portion of our pension plan.

If the Triad acquisition is not consummated, the amount of the net proceeds of this offering available for general corporate purposes will increase commensurately. If the notes offering is not completed, proceeds of the common stock offering will first be used to finance the Triad acquisition.

Of the $95 million in existing debt that we intend to refinance from the net proceeds of this offering and the concurrent notes offering, $20 million is currently borrowed under our Senior Secured Credit Facility. That facility was used to repay outstanding amounts and replace letters of credit under our $20.0 million debtor-in-possession facility, to fund expenses associated with our emergence from bankruptcy and to provide liquidity for general corporate purposes. The Senior Secured Credit Facility is comprised of a $30 million revolver component and a $20 million term component. Borrowings under the revolver component bear interest at LIBOR + 2.5% or the Base Rate (as defined in the credit agreement) + 1.0%. Borrowings under the term component bear interest at LIBOR + 5.25% or the Base Rate + 3.85%. The Senior Secured Credit Facility matures in May 2009. The Senior Secured Credit Facility will be terminated upon completion of the refinancing transactions discussed above.

We also intend to refinance $75 million currently borrowed under our Term Credit Facility. We entered into that facility with our pre-petition secured lenders in partial satisfaction of our pre-petition obligations, pursuant to our Plan of Reorganization. The Term Credit Facility bears interest at a rate of 9% per year, and matures in May 2011. The Term Credit Facility will be terminated upon completion of the refinancing transactions discussed above.

DIVIDEND POLICY

We have not paid any cash dividends on our common stock during the last two completed fiscal years. We intend to retain our earnings and do not anticipate paying cash dividends in the near future. Any future determination as to the payment of cash dividends will depend upon such factors as earnings, capital requirements, our financial condition, restrictions in financing agreements and other factors deemed relevant by the Board of Directors. The payment of cash dividends is also restricted by our current credit facilities and will be restricted by our proposed new senior secured credit facility and by the indenture governing the notes.

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CAPITALIZATION

The following table sets forth our cash and capitalization as of March 31, 2005 (1) on an actual basis, (2) on an as adjusted basis to give effect to the completion of this offering, based on the public offering price of $32.50 per share, and the concurrent notes offering, and the use of proceeds therefrom assuming the Triad acquisition is not completed and (3) on a pro forma as adjusted basis to give further effect to completion of the Triad acquisition and the entering into of our proposed new senior secured credit facility. You should read this table together with the historical consolidated financial statements and related notes of (i) the Company and (ii) Triad appearing elsewhere in this prospectus, “Unaudited Pro Forma Condensed Consolidated Financial Statements” and the related notes, and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included elsewhere in this prospectus.

	As of March 31, 2005
	Actual			As Adjusted			Pro Forma, as adjusted
	(dollars in thousands)
Cash and cash equivalents	$	1,724			94,035			35,299
Debt
Existing Senior Secured Credit Facility
Term Loan Component		20,000			—			—
Revolver Component		—			—			—
Existing Term Credit Facility		75,000			—			—
Proposed New Senior Secured Credit Facility (1)		—			—			—
% Senior Notes due 2012		—			150,000			150,000
Other		—			—			885
Total Debt		95,000			150,000			150,885
Shareholders’ Equity (2)
Common Stock		147			162			166
Additional Paid in Capital		73,592			119,158			130,154
Deferred Stock Based Compensation		(8,900	)		(8,900	)		(8,900	)
Retained Earnings (Deficit) (3)		1,460			(490	)		(490	)
Accumulated Comprehensive Income		43			43			43
Total Shareholders’ Equity		66,342			109,973			120,973
Total Capitalization	$	161,342			259,973			271,858

 

(1) Availability under our proposed new $100 million senior secured credit facility will be reduced on a dollar for dollar basis by the amount of letters of credit issued under the facility. See “Description of Indebtedness” for a description of the proposed new senior secured credit facility. As of March 31, 2005, we had $32.7 million of letters of credit outstanding under our existing Senior Secured Credit Facility and Triad had letters of credit outstanding of $6.9 million, and we expect that such letters of credit will be replaced with letters of credit issued under our proposed new senior secured credit facility.

(2) Excludes the impact of the contingent issuance of shares of our common stock with an aggregate value of up to $5,000,000 in connection with the Triad acquisition.

(3) Reflects a prepayment penalty of $0.8 million on our existing debt and the write-off of $1.8 million of unamortized debt issuance costs associated with the payment of our existing debt, net of taxes.

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UNAUDITED PRO FORMA CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The following unaudited pro forma condensed consolidated financial statements have been prepared by our management and are based on (a) the historical financial statements of (i) the Company, and (ii) Triad; and (b) the assumptions and adjustments described below.

The unaudited pro forma condensed consolidated balance sheet gives effect to the following transactions, as if such transactions had taken effect on March 31, 2005:

• the completion of this offering and the concurrent notes offering and the application of the net proceeds therefrom to refinance our debt and finance the Triad acquisition, as described under “Use of Proceeds;”

• the completion of our proposed new senior secured credit facility; and

• the Triad acquisition as described under “The Triad Acquisition.”

The unaudited pro forma condensed consolidated statements of operations for the three months ended March 31, 2005 and the twelve months ended December 31, 2004 give effect to such transactions, as well as application of fresh start accounting as described under “Business—Recent Reorganization” to the Predecessor Company, as if they had occurred on January 1, 2004.

The unaudited pro forma adjustments are based upon available information and certain assumptions that we believe are reasonable. However, as of the date of this prospectus, we have not received the appraisals necessary to allocate the purchase price for the Triad acquisition to the fair values of the assets we will acquire and the liabilities we will assume, nor have we identified the adjustments, if any, necessary to conform Triad’s historical accounting policies to ours.

The acquisition of Triad will be accounted for, and is presented in the unaudited pro forma condensed consolidated financial information, under the purchase method of accounting prescribed in Statement of Financial Accounting Standards (SFAS) No. 141 “Business Combinations,” with intangible assets recorded in accordance with SFAS No. 142, “Goodwill and Other Intangible Assets.” The pro forma adjustments reflect our preliminary estimate of the purchase price allocation. These estimates will likely change upon finalization of our analysis of the fair value of the assets and liabilities we will acquire, including the impact of appraisals that we have arranged to obtain. The unaudited pro forma condensed consolidated balance sheet does not include any fair value adjustments for inventories, property, plant and equipment, coal supply agreements or other intangible assets since we have not completed the appraisal process for these assets. Ultimately, a portion of the purchase price may be allocated to these assets and to deferred tax assets and liabilities, and such amounts may be significant. Our preliminary allocation of the purchase price in our pro forma financial statements resulted in an increase of $22.1 million over the historical book value of property, plant and equipment and mineral rights, which was offset by the allocation of $9.1 million to deferred tax liabilities for identified basis differences. The remaining excess purchase price of $31.2 million was assigned to goodwill. Additional purchase price allocated to inventory would impact cost of coal sales subsequent to the acquisition date. Any increase in the fair value adjustment to mineral rights, property, plant and equipment, favorable coal supply agreements or other intangible assets would result in additional depreciation, depletion and amortization expense which is not included in the pro forma statement of operations and may be significant.

The unaudited pro forma condensed consolidated financial statements do not purport to represent what our results of operations or financial position actually would have been if the transactions set forth above had occurred on the dates indicated or what our results of operations or financial position will be for future periods.

The unaudited pro forma condensed consolidated financial statements should be read in conjunction with the historical financial statements of the Company and Triad, and the related notes, which are included elsewhere in this prospectus. See “Notes to Unaudited Pro Forma Condensed Consolidated Balance Sheet” and “Notes to Unaudited Pro Forma Condensed Consolidated Statement of Operations” for a discussion of assumptions made.

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UNAUDITED PRO FORMA CONDENSED CONSOLIDATED BALANCE SHEET
AS OF MARCH 31, 2005
(dollars in thousands)
(Unaudited)

	Historical James River Coal		Financing Adjustments			Pro Forma for Financing		Historical Triad		Acquisition Adjustments			Pro Forma
						(a)
Cash and marketable securities	$	1,724		188,111	(b)		94,035		23,546		(17,782	)(g)		35,299
				(95,800	)(c)						(64,500	)(h)
Trade receivables		37,496		—			37,496		10,317		—			47,813
Other receivables		2,928		—			2,928		—		—			2,928
Total receivables		40,424					40,424		10,317		—			50,741
Coal inventories		5,500		—			5,500		1,179		—			6,679
Materials and supplies inventories		4,446		—			4,446		1,052		—			5,498
Total inventories		9,946					9,946		2,231		—			12,177
Other current assets		8,041		—			8,041		1,082		—			9,123
Total current assets		60,135		92,311			152,446		37,176		(82,282	)		107,340
Property, plant and equipment, net		260,781		—			260,781		25,207		22,132	(h)		308,120
Goodwill		—		—			—		—		31,188	(h)		31,188
Restricted cash		8,425		—			8,425		—		—			8,425
Other assets		11,792		6,320	(d)		18,112		531		—			18,643
Total assets	$	341,133		98,631			439,764		62,914		(28,962	)		473,716

 

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UNAUDITED PRO FORMA CONDENSED CONSOLIDATED BALANCE SHEET
AS OF MARCH 31, 2005
(dollars in thousands)
(Unaudited)

	Historical James River Coal		Pro Forma Financing Adjustment			Pro Forma for Financing		Historical Triad		Pro Forma Acquisition Adjustments			Pro Forma
						(a)
Current maturities of long-term debt	$	3,600		(3,600	)(e)		—		885		—			885
Accounts payable		25,043		—			25,043		3,561		—			28,604
Other current liabilities		27,279		—			27,279		1,962		—			29,241
Total current liabilities		55,922		(3,600	)		52,322		6,408		—			58,730
Long-term debt, less current maturities		91,400		58,600	(e)		150,000		—		—			150,000
Noncurrent portion of workers’ compensation benefits		38,381		—			38,381		—		—			38,381
Noncurrent portion of black lung benefits		23,421					23,421		—		—			23,421
Pension obligations		15,206		—			15,206		—		—			15,206
Asset retirement obligations		15,129		—			15,129		7,488		—			22,617
Other		35,332		—			35,332		—		9,056	(h)		44,388
Total other liabilities		127,469		—			127,469		7,488		9,056			144,013
Total liabilities		274,791		55,000			329,791		13,896		9,056			352,743
Total shareholders’ equity		66,342		45,581	(b)		109,973		49,018		(17,782	)(g)		120,973
				(1,950	)(f)						(20,236	)(i)
Total liabilities and shareholders’ equity	$	341,133		98,631			439,764		62,914		(28,962	)		473,716

 

Notes to Unaudited Pro Forma Condensed Consolidated Balance Sheet Data

(a)  The pro forma financing adjustments include the impact of the refinancing of our existing long term debt through the issuance of 1,500,000 shares of common stock, $150 million of senior notes due 2012 and the completion of our proposed new $100 million senior secured credit facility. As of March 31, 2005, we had $32.7 million of letters of credit outstanding under our existing Senior Secured Credit Facility and Triad had letters of credit outstanding of $6.9 million, and we expect that such letters of credit and letters of credit issued subsequently will be replaced with letters of credit issued under our proposed new senior secured credit facility. The common stock and notes offerings are not contingent upon each other or completion of the Triad acquisition. The proposed new senior secured credit facility is contingent upon completion of the Triad acquisition.

(b)  Represents the proceeds from the issuance of $150.0 million of senior notes due 2012 and the issuance of 1,500,000 shares of common stock at a price of $32.50 per share, net of total fees and expenses on the various financings of approximately $10.6 million.

(c)  Represents the repayment of our existing senior secured credit facility and term credit facility, including prepayment penalties of $0.8 million.

(d)  Represents the net adjustment to other assets based on the elimination of $1.8 million of deferred financing costs associated with the debt to be repaid, the recording of $7.5 million of deferred financing costs on the new senior notes and the proposed new senior secured credit facility and the tax impact of the items discussed in note (f).

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(e)  Represents the net increase in long-term debt, less current maturities based on the following:

	(dollars in thousands)
Repayment of senior secured credit facility	$	(75,000	)
Repayment of term credit facility		(20,000	)
New senior notes		150,000
		55,000
Repayment of current maturities of long-term debt		3,600
Net increase in long-term debt net of current maturities	$	58,600

 

(f)  Represents net adjustment to our equity as a result of prepayment penalties of $0.8 million and the elimination of $1.8 million of deferred financing costs, net of taxes.

(g)  Reflects a distribution by Triad to its shareholders prior to the close of the acquisition and a preliminary estimate of the working capital adjustment based on Triad’s March 31, 2005 balance sheet. The distribution and working capital adjustment estimate total approximately $17.8 million. For purposes of our pro forma financial statements, we assume that all of Triad’s marketable securities will be converted to cash or cash equivalents. See “The Triad Acquisition.”

(h)  Reflects the purchase of Triad and allocation of purchase price. The pro forma adjustment does not reflect the contingent issuance to certain Triad shareholders of up to $5.0 million in shares of our common stock if we obtain the right to additional reserves, or potential working capital adjustments to the purchase price (see “The Triad Acquisition”).

A summary of the gross purchase price follows:

Cash	$	64,000
Equity		11,000
Acquisition Costs		500
Total Purchase Price	$	75,500

 

The pro forma adjustments reflect our preliminary estimate of the purchase price allocation. These estimates will likely change upon finalization of our analysis of the fair value of the assets and liabilities we will acquire, including the impact of appraisals that we have arranged to obtain. The unaudited pro forma condensed consolidated balance sheet does not include any fair value adjustments for inventories, property, plant and equipment, coal supply agreements or other intangible assets since we have not completed the appraisal process for these assets. Ultimately, a portion of the purchase price may be allocated to these assets and to deferred tax assets and liabilities, and such amounts may be significant. Our preliminary allocation of the purchase price in our pro forma financial statements resulted in an increase of $22.1 million over the historical book value of property, plant and equipment and mineral rights, which was offset by the allocation of $9.1 million to deferred tax liabilities for identified basis differences. The remaining excess purchase price of $31.2 million was assigned to goodwill. Additional purchase price allocated to inventory would impact cost of coal sales subsequent to the acquisition date. Any increase in the fair value adjustment to mineral rights, property, plant and equipment, favorable coal supply agreements or other intangible assets would result in additional depreciation, depletion and amortization expense which is not included in the pro forma statement of operations and may be significant.

(i)  Represents the elimination of Triad’s historical shareholders’ equity as adjusted for the distribution and working capital adjustments in (g) and the issuance of $11.0 million of our common stock as part of the Triad purchase price (338,462 shares based on an assumed price of $32.50 per share).

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UNAUDITED PRO FORMA CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS
FOR THE YEAR ENDED DECEMBER 31, 2004
(dollars in thousands, except share data)
(Unaudited)

	James River Coal
	Predecessor Four Months April 30, 2004			Successor Eight Months December 31, 2004			(a) Pro Forma Fresh Start Adjustments			Pro Forma Twelve Months December 31, 2004			(b) Pro Forma Financing Adjustments			Pro Forma			Triad Year Ended December 31, 2004			Pro Forma Acquisition Adjustments			Pro Forma Triad Acquisition
Revenues	$	113,949			231,698			—			345,647			—			345,647			81,603			—			427,250
Cost of sales
Cost of coal sold		89,294			190,926			—			280,220			—			280,220			59,291			—			339,511
Depreciation, depletion and amortization		12,314			21,765			(1,431	)		32,648			—			32,648			5,500			4,424	(f)		42,572
Total cost of sales		101,608			212,691			(1,431	)		312,868			—			312,868			64,791			4,424			382,083
Gross profit		12,341			19,007			1,431			32,779			—			32,779			16,812			(4,424	)		45,167
Sales, general and administrative expenses		5,023			11,412			—			16,435			4,055	(c)		20,490			3,736			—			24,226
Operating income (loss)		7,318			7,595			1,431			16,344			(4,055	)		12,289			13,076			(4,424	)		20,941
Interest expense		567			5,733			2,300			8,600			6,659	(d)		15,259			174			—			15,433
Interest income		—			(72	)		—			(72	)		—			(72	)		(567	)		567	(g)		(72	)
Miscellaneous income, net		(331	)		(833	)		—			(1,164	)		—			(1,164	)		(57	)		—			(1,221	)
Total other expense (income)		236			4,828			2,300			7,364			6,659			14,023			(450	)		567			14,140
Income (loss) before reorganization costs and income taxes		7,082			2,767			(869	)		8,980			(10,714	)		(1,734	)		13,526			(4,991	)		6,801
Reorganization gain, net		(100,907	)		—			100,907			—			—			—			—			—			—
Income loss before income tax		107,989			2,767			(101,776	)		8,980			(10,714	)		(1,734	)		13,526			(4,991	)		6,801
Income tax provision (benefit)		—			791			1,454			2,245			(2,678	)(e)		(433	)		—			2,134	(h)		1,701
Net income (loss)	$	107,989			1,976			(103,230	)		6,735			(8,036	)		(1,301	)		13,526			(7,125	)		5,100

 

Earnings per share
	Basic		Diluted
Weighted average shares used to calculate earnings per share at December 31, 2004		13,799,994		14,622,620
Shares issued to Triad (i)		338,462		338,462
Shares issued in financing (i)		1,500,000		1,500,000
Pro forma shares		15,638,456		16,461,082
Pro forma earnings per share	$	0.33		0.31

 

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UNAUDITED PRO FORMA CONDENSED CONSOLIDATED STATEMENT OF OPERATIONS
FOR THE THREE MONTHS ENDED MARCH 31, 2005
(dollars in thousands, except share data)
(Unaudited)

	James River Coal Three Months March 31, 2005			(b) Pro Forma Financing Adjustments			Pro Forma			Triad Three Months Ended March 31, 2005			Pro Forma Acquisition Adjustments			Pro Forma Triad Acquisition
Revenues	$	97,875			—			97,875			23,396			—			121,271
Cost of sales
Cost of coal sold		80,942			—			80,942			17,203			—			98,145
Depreciation, depletion and amortization		9,478			—			9,478			1,630			1,106	(f)		12,214
Total cost of sales		90,420			—			90,420			18,883			1,106			110,359
Gross profit		7,455			—			7,455			4,563			(1,106	)		10,912
Sales, general and administrative expenses		5,035			338	(c)		5,373			886			—			6,259
Operating income (loss)		2,420			(338	)(c)		2,082			3,677			(1,106	)		4,653
Interest expense		2,186			1,625	(d)		3,811			21			—			3,832
Interest income		(21	)		—			(21	)		(149	)		149	(g)		(21	)
Miscellaneous income, net		(123	)		—			(123	)		71			—			(52	)
Total other expense (income)		2,042			1,625			3,667			(57	)		149			3,759
Income loss before income tax		378			(1,963	)		(1,585	)		3,734			(1,255	)		894
Income tax provision (benefit)		69			(491	)(e)		(422	)		—			620	(h)		198
Net income (loss)	$	309			(1,472	)		(1,163	)		3,734			(1,875	)		696

 

Earnings per share
	Basic		Diluted
Weighted average shares used to calculate earnings per share at March 31, 2005		13,799,994		14,751,672
Shares issued to Triad (i)		338,462		338,462
Shares issued in financing (i)		1,500,000		1,500,000
Pro forma shares		15,638,456		16,590,134
Pro forma earnings per share	$	0.04		0.04

 

Notes to Unaudited Pro Forma Condensed Consolidated Statement of Operations

(a)  In order to provide a basis to display the pro forma amounts for the year ended December 31, 2004, the operating results of the Successor Company for the eight months ended December 31, 2004 have been combined with the operating results for the Predecessor Company for the four months ended April 30, 2004 and the April 30, 2004 amounts have been adjusted to be on a comparable basis to the Successor Company. The combining of the predecessor and successor accounting periods is not permitted by generally accepted accounting principles. Additionally, as explained above, the operating results of the Successor Company and the Predecessor Company are not comparable. The adjustments to the four months ended April 30, 2004 include: (1) the elimination of the reorganization gain; (2) an adjustment to depreciation, depletion and amortization and interest expense to make them comparable to the eight months ended December 31, 2004 by assuming that the debt and amortizable assets in place during the predecessor period were in place at January 1, 2004; and (3) the application of a 25% tax rate to the four months ended December 31, 2004 results.

(b)  The pro forma financing adjustments include the impact of the refinancing of our existing long term debt through the issuance of 1,500,000 shares of common stock, $150 million of senior notes due 2012 and the

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completion of our proposed new $100 million senior secured credit facility. The common stock and notes offerings are not contingent upon each other or completion of the Triad acquisition. The proposed new senior secured credit facility is contingent upon completion of the Triad acquisition. As of March 31, 2005, we had $32.7 million of letters of credit outstanding under our existing Senior Secured Credit Facility and Triad had letters of credit outstanding of $6.9 million, and we expect that such letters of credit and letters of credit issued subsequently will be replaced with letters of credit issued under our proposed new senior secured credit facility.

(c)  Represents the following (in thousands)

	Three Months Ended March 31, 2005		Twelve Months Ended December 31, 2004
Write off of deferred financing costs associated with debt to be refinanced	$	—		1,800
Prepayment penalty associated with the refinancing		—		800
Incremental fees associated with our new senior secured credit facility		338		1,455
	$	338		4,055

 

(d)  The net adjustment to interest expense represents the elimination of historical interest expense associated with the debt to be repaid and the recording of interest expense for the senior notes as if they had been issued as of January 1, 2004. The interest expense for the new senior notes is based on an outstanding principal amount of $150.0 million and an interest rate of 9.375%. The following table summarizes the pro forma interest expense adjustment (in thousands):

	Three Months Ended March 31, 2005			Twelve Months Ended December 31, 2004
Eliminates historical interest expense	$	(2,157	)		(8,471	)
Interest on senior notes		3,515			14,063
Amortization of financing costs		267			1,067
Pro forma interest adjustment	$	1,625			6,659

 

(e)  Income tax effects of the items discussed in notes (c) and (d) at an effective tax rate of 25%.

(f)  Reflects the amortization of a portion of the excess of the purchase price over assets acquired. The pro forma adjustments reflect our preliminary estimate of the purchase price allocation. These estimates will likely change upon finalization of our analysis of the fair value of the assets and liabilities we will acquire, including the impact of appraisals that we have arranged to obtain. The unaudited pro forma condensed consolidated balance sheet does not include any fair value adjustments for inventories, property, plant and equipment, coal supply agreements or other intangible assets since we have not completed the appraisal process for these assets. Ultimately, a portion of the purchase price may be allocated to these assets and to deferred tax assets and liabilities, and such amounts may be significant. Our preliminary allocation of the purchase price in our pro forma financial statements resulted in an increase of $22.1 million over the historical book value of property, plant and equipment and mineral rights, which was offset by the allocation of $9.1 million to deferred tax liabilities for identified basis differences. The remaining excess purchase price of $31.2 million was assigned to goodwill. Additional purchase price allocated to inventory would impact cost of coal sales subsequent to the acquisition date. Any increase in the fair value adjustment to mineral rights, property, plant and equipment, favorable coal supply agreements or other intangible assets would result in additional depreciation, depletion and amortization expense which is not included in the pro forma statement of operations and may be significant. We have assigned a five year amortization life to the mineral rights based on our preliminary estimate of the life of the remaining reserves. The remaining depreciable assets are being depreciated at their historical rates. A $1.0 million reduction in the amount assigned to goodwill to an asset that has a five year life would result in an annual increase in our depreciation, depletion and amortization of $200,000.

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(g)  Excludes historical interest income earned by Triad on its marketable securities. The adjustment assumes that the existing marketable securities owned by Triad as of March 31, 2005 will be liquidated and the proceeds will be used to pay the distribution to Triad shareholders prior to the close of the acquisition.

(h)  Income tax effects of the items discussed in notes (f) and (g) and Triad operating results at an effective tax rate of 25%.

(i)  Adjusts the outstanding shares for equity issuances. The diluted shares issued in the Triad acquisition do not include the contingent issuance to certain Triad shareholders of up to $5.0 million in shares of our common stock if we obtain the right to additional reserves (see “The Triad Acquisition”).

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SELECTED HISTORICAL FINANCIAL DATA

Recent Reorganization

In March 2003, we and all of our subsidiaries filed voluntary petitions with the United States Bankruptcy Court for the Middle District of Tennessee for reorganization under Chapter 11. On May 6, 2004, we emerged from bankruptcy. On that date, we:

• exchanged approximately $266 million in debt under various existing credit facilities for (1) restructured term debt of approximately $75 million, which is secured by a second lien on substantially all of our assets, and (2) a total of 13,799,994 shares of our new common stock, par value $0.01 per share, issued on a pro rata basis to the holders of the existing debt;

• distributed interests in an unsecured creditor liquidating trust (which trust initially held life insurance policies with cash surrender values of approximately $3.1 million, the right to receive certain refunds and the right to pursue certain derivative claims) to our general unsecured creditors in exchange for their claims, which were estimated to be valued at approximately $44.9 million;

• entered into a new senior secured credit facility allowing borrowings up to $50 million, which is secured by a first lien on substantially all of our assets;

• satisfied and discharged all of our obligations under our $20 million debtor-in-possession credit facility;

• rejected (i.e., terminated) certain agreements that we had entered into before the bankruptcy that were found to be unduly burdensome to us, and discharged the claims of creditors related to those agreements;

• canceled our existing equity securities;

• acknowledged that all intercompany debt was deemed to be extinguished;

• acknowledged that pre- and post-petition (i) environmental and regulatory obligations; (ii) obligations with respect to workers’ compensation and black lung programs; and (iii) regulatory obligations related to our employees would be unaffected by the Plan of Reorganization and would survive effectuation of the Plan of Reorganization; and

• elected and installed a new Board of Directors.

Fresh Start Accounting

Upon emergence from bankruptcy, we adopted “fresh start” accounting as contained in the American Institute of Certified Public Accountant’s Statement of Position 90-7, Financial Reporting by Entities in Reorganization Under the Bankruptcy Code (“SOP 90-7”). Entities that adopt fresh start accounting apply the following principles:

• The reorganization value of the entity should be allocated to the entity’s assets in conformity with SFAS No. 141 Business Combinations.

• Each liability existing at the plan confirmation date, other than deferred taxes, should be stated at present values of amounts to be paid as determined at appropriate current interest rates.

• Deferred taxes should be reported in conformity with generally accepted accounting principles. Benefits realized from pre-reorganization net operating loss carryforwards should first reduce reorganization value in excess of amounts allocable to identifiable assets and other intangibles until exhausted and thereafter be reported as a direct addition to paid-in capital.

In connection with the implementation of fresh start accounting, we recorded a gain of approximately $178.0 million from the extinguishment of our debt. Other adjustments were made to reflect the provisions of the Plan of Reorganization and to adjust the assets of the reorganized company to their estimated fair value and liabilities to their estimated present value. The estimated fair value of our fixed assets was based on an appraisal performed

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for one of our lenders in connection with our reorganization. For financial reporting purposes, these transactions were reflected in our operating results before emergence.

Our consolidated financial statements after emergence are those of a new reporting entity (the “Successor Company”) and are not comparable to the financial statements of the pre-emergence company (the “Predecessor Company”). For a complete discussion of our application of fresh start accounting, including the impact on historical results of operations, cash flows and financial position, please refer to our December 31, 2004 consolidated financial statements and related notes included elsewhere in this prospectus.

The following table presents our selected consolidated financial and operating data as of and for each of the periods indicated. The selected condensed consolidated financial data for the three months ended March 31, 2005 (successor period) and the three months ended March 31, 2004 (predecessor period) are derived from our unaudited condensed consolidated financial statements, and in the opinion of management include all adjustments, consisting only of normal recurring accruals, that are necessary for a fair presentation of our financial position and operating results for these periods. The selected consolidated financial and operating data are not necessarily indicative of the results that may be expected for the entire year. The selected consolidated financial data as of and for each of the years ended December 31, 2000 through December 31, 2003 and the four months ended April 30, 2004 (predecessor periods) and the eight months ended December 31, 2004 (successor period) are derived from our consolidated financial statements. The selected consolidated financial and operating data should be read in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements and related notes included in this prospectus.

James River Coal Company and Subsidiaries
Selected Historical Financial Data

	Successor Company						Predecessor Company
													Year Ended December 31,
	Three Months Ended 3/31/05			Eight Months Ended 12/31/04			Four Months Ended 4/30/04			Three Months Ended 3/31/04			2003			2002			2001			2000
	(in thousands, except share information)
Consolidated Statement of Operations:
Revenues	$	97,875			231,698			113,949			80,858			304,052			397,599			384,248			416,756
Cost of coal sold		80,942			190,926			89,294			65,707			278,939			344,222			328,408			341,092
Depreciation, depletion, and amortization		9,478			21,765			12,314			9,272			40,427			46,393			43,175			43,272
Gross profit (loss)		7,455			19,007			12,341			5,879			(15,314	)		6,984			12,665			32,392
Selling, general, and administrative expenses		5,035			11,412			5,023			3,561			19,835			19,994			15,725			15,281
Other operating expenses		—			—			—			—			26,554			—			—
Operating income (loss)		2,420			7,595			7,318			2,318			(35,149	)		(39,564	)		(3,060	)		17,111
Interest expense		2,186			5,733			567			403			18,536			29,883			23,923			17,706
Interest income		(21	)		(72	)		—			—			(144	)		(1,003	)		(662	)		—
Miscellaneous income, net		(123	)		(833	)		(331	)		(53	)		(1,519	)		(1,222	)		206			(3,977	)
Reorganization items, net		—			—			(100,907	)		1,557			7,630			—			—			—
Income tax expense (benefit)		69			791			—			—			(2,891	)		(8,125	)		(10,318	)		(2,503	)
Income (loss) before cumulative effect of accounting change		309			1,976			107,989			411			(56,761	)		(59,097	)		(16,209	)		5,885
Cumulative effect of accounting change		—			—			—			—			(3,045	)		—			—			—
Net income (loss)		309			1,976			107,989			411			(59,806	)		(59,097	)		(16,209	)		5,885
Preferred dividends		—			—			—			—			(340	)		(680	)		(595	)		(714	)
Decrease in redemption amount of redeemable common stock		—			—			—			—			—			8,798			45,831			14,311
Net income (loss) attributable to common shareholders	$	309			1,976			107,989			411			(60,146	)		(50,979	)		29,027			19,482

 

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James River Coal Company and Subsidiaries
Selected Historical Financial Data

	Successor Company				Predecessor Company
									Year Ended December 31,
	Three Months Ended 3/31/05		Eight Months Ended 12/31/04		Four Months Ended 4/30/04		Three Months Ended 3/31/04		2003			2002			2001		2000
	(in thousands, except per share information)
Basic earnings (loss) per common share:
Income (loss) before cumulative effect of accounting change	$	0.02		0.14		6,393.67		24.33		(3,380.78	)		(3,018.31	)		1,718.56		1,153.46
Cumulative effect of accounting change		—		—		—		—		(180.28	)		—			—		—
Net income (loss)		0.02		0.14		6,393.67		24.33		(3,561.06	)		(3,018.31	)		1,718.56		1,153.46
Shares used to calculate basic earnings (loss) per common share		13,800		13,800		17		17		17			17			17		17
Diluted earnings (loss) per common share:
Income (loss) before cumulative effect of accounting change		0.02		0.14		6,393.67		24.33		(3,380.78	)		(3,018.31	)		1,718.56		1,153.46
Cumulative effect of accounting change		—		—		—		—		(180.28	)		—			—		—
Net income (loss)	$	0.02		0.14		6,393.67		24.33		(3,561.06	)		(3,018.31	)		1,718.56		1,153.46
Shares used to calculate diluted earnings (loss) per share		14,752		14,623		17		17		17			17			17		17

 

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	Successor Company				Predecessor Company
											December 31,
	3/31/05		12/31/04		4/30/04			3/31/04			2003			2002			2001			2000
	(in thousands)
Consolidated Balance Sheet Data:
Working capital (deficit)	$	4,213		10,046		5,896			12,227			9,009			(263,149	)		(241,857	)		(17,505	)
Property, plant, and equipment, net		260,781		255,575		254,259			254,646			257,156			270,989			310,643			306,399
Total assets		341,133		327,826		332,589			327,241			318,289			340,311			393,411			382,534
Long term debt, including current portion		95,000		95,000		6,400			6,400			—			252,876			249,576			232,734
Liabilities subject to compromise		—		—		319,451			319,813			319,595			—			—			—
Total shareholders’ equity (deficit)		66,342		65,585		(127,837	)		(123,189	)		(123,601	)		(68,726	)		(9,034	)		(29,786	)

 

	Successor Company						Predecessor Company
													Year Ended December 31,
	Three Months Ended 3/31/05			Eight Months Ended 12/31/04			Four Months Ended 4/30/04			Three Months Ended 3/31/04			2003			2002			2001			2000
	(in thousands, except per ton information and number of employees)
Consolidated Statement of Cash Flow Data:
Net cash provided by (used in) operating activities	$	12,689			14,098			1,513			(3,071	)		23,033			28,899			30,793			46,038
Net cash used in investing activities		(14,711	)		(21,744	)		(9,463	)		(6,796	)		(15,660	)		(33,522	)		(43,640	)		(34,061	)
Net cash provided by (used in) financing activities		(133	)		10,224			4,361			6,299			(2,489	)		3,347			14,119			(11,981	)
Supplemental Operating Data:
Tons sold		2,228			5,775			3,107			2,287			10,083			13,926			14,065			15,961
Tons produced		2,301			5,770			3,081			2,400			9,294			12,350			13,134			15,599
Revenue per ton sold (excluding synfuel)	$	43.27			39.21			35.98			34.65			29.53			28.26			27.29			26.11
Number of employees		1,141			1,070			984			972			1,127			1,145			1,319			1,172
Capital expenditures	$	14,690			25,811			9,521			6,815			20,116			22,925			43,694			35,927

 

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION
AND RESULTS OF OPERATIONS

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our financial statements and the accompanying notes and “Selected Historical Financial Data” included elsewhere in this prospectus. This discussion contains forward-looking statements that involve risks and uncertainties. Our actual results could differ materially from those anticipated in the forward-looking statements as a result of numerous factors, including the risks discussed in “Risk Factors” in this prospectus.

Overview

We mine, process and sell bituminous, low sulfur, steam and industrial-grade coal through five operating subsidiaries (“mining complexes”) located throughout Eastern Kentucky. Our five mining complexes include 18 mines and seven preparation plants, five of which have integrated rail loadout facilities and two of which use a common loadout facility at a separate location. In 2004, our mines produced 8.5 million tons of coal, and we purchased another 330,000 tons for resale. Of the 8.5 million tons produced, approximately 96.5% was produced at underground mines, while the remaining 3.5% was produced at surface mines. Approximately 83.4% of our revenues were generated from coal sales to electric utility companies and 16.6% came from coal sales to industrial and other companies or from synfuel handling fees. In 2004, we generated revenues of $345.6 million and income before reorganization items and income taxes of $9.8 million.

The majority of our coal is sold to customers in the Southeast region of the United States. According to the U.S. Energy Information Administration, or EIA, the Southeast region accounts for 33% of coal-generated electricity production in the United States, more than any other U.S. region. We believe the long term outlook for coal demand in the Southeast is favorable, as coal-generated electricity production in that region is expected to grow at a rate of 1.8% per year. In addition, the Southeast region is projected by the EIA to account for 36% of the expansion of coal-generated electricity production in the United States between 2003 and 2025. We or our predecessors have been providing coal to coal-generated electricity producers in the Southeast for over 40 years. In 2004, Georgia Power and South Carolina Public Service Authority were our largest customers, representing approximately 30% and 20% of our revenues, respectively. No other customer accounted for more than 10% of our revenues.

We believe that coal-fired electric utilities value the high energy, low sulfur coal that comprises the majority of our reserves. Low sulfur coal is coal which has a sulfur content of 1.5% or less. As of March 31, 2004, based upon our most recent independent reserve report, we estimate that we controlled approximately 207 million tons of proven and probable coal reserves. As of March 31, 2005, we believe that we controlled approximately 222 million tons of proven and probable coal reserves. We believe these reserves have an average heat content of 13,300 Btu per pound and an average sulfur content of 1.3%. At 2004 production levels, we believe these reserves would support in excess of 25 years of production.

In March 2005, we signed a definitive agreement to acquire Triad Mining, Inc., for $75.0 million, consisting of $64.0 million in cash and $11.0 million of our common stock. Triad operates six surface mines and one underground mine in Southern Indiana, and in 2004 produced approximately 3.4 million tons of coal. Of the 3.4 million tons produced, approximately 87% came from surface mines, while the remaining 13% came from underground mines. In 2004, Triad generated revenues of approximately $81.6 million. As of February 1, 2005, based upon an independent reserve report, we believe that Triad controlled approximately 17.6 million tons of proven and probable coal reserves.

Demand for coal increased significantly in 2004, and it continued to increase during the first quarter of 2005, due to a combination of conditions in the U.S. and worldwide that caused a shortage of certain grades of coal. Consequently, prices for the grades of coal we sell have risen significantly since mid-2003. Due to the fixed prices in the contractual commitments with utility customers that we renegotiated during the bankruptcy, we have seen only a limited benefit from the current market environment since our emergence from bankruptcy.

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Our revenues are impacted by the level of coal available for sale by us. That availability level decreased during 2003 and 2004, for the reasons discussed in “Results of Operations.” Those reasons include the filing of our bankruptcy petition (which led to termination of certain of our mine operator relationships); the loss of a supplier at our Blue Diamond complex; closure of higher-cost mines; and delays and other railroad services problems.

As compared to the prior year, we experienced a significant increase in mining costs during 2004 and the first quarter of 2005. The increased costs were primarily due to higher royalties and severance taxes, lower operating productivity from our deep mines and preparation plants, an increase in roof support costs due to an increase in steel costs, and increased trucking costs resulting from vigorous enforcement of weight limits in Kentucky. We are focused on reducing our operating costs at each mine and improving miner productivity. We continue to make capital expenditures to upgrade our equipment, facilities, and infrastructure. We are also focused on enhancing our training programs to help our personnel be safer and more productive.

Reserves

Marshall Miller & Associates, Inc. (“MM&A”) prepared a detailed study of our reserves as of March 31, 2004 based on all of our geologic information, including our updated drilling and mining data. The coal reserve study conducted by MM&A was planned and performed to obtain reasonable assurance of our subject demonstrated reserves. In connection with the study, MM&A prepared reserve maps and had certified professional geologists develop estimates based on data supplied by us and using standards accepted by government and industry. MM&A completed their report in June 2004.

There are numerous uncertainties inherent in estimating quantities and values of economically recoverable coal reserves as discussed in “Critical Accounting Estimates—Coal Reserves”.

Based on the MM&A reserve study and the foregoing assumptions and qualifications, and after giving effect to our operations from March 31, 2004 through March 31, 2005, we estimate that, as of March 31, 2005, we controlled approximately 222 million tons of proven and probable coal reserves. MM&A has not conducted a coal reserve study on our March 31, 2005 reserve estimate. The following table provides additional information regarding changes to our reserves since March 31, 2004 (in millions of tons):

	Three Months Ended March 31, 2005			Nine Months Ended December 31, 2004
Proven and Probable Reserves beginning of period (1)		207.4			207.2
Coal Extracted		(2.2	)		(6.3	)
Acquisitions (2)		15.4			3.7
Adjustments (3)		1.0			2.8
Proven and Probable Reserves end of period		221.6			207.4

 

(1)   Calculated in the same manner, and based on the same assumptions and qualifications, as described above. Proven reserves have the highest degree of geologic assurance and are reserves for which (a) quantity is computed from dimensions revealed in outcrops, trenches, workings, or drill holes; grade and/or quality are computed from the results of detailed sampling and (b) the sites for inspections, sampling and measurement are spaced so closely and the geologic character is so well defined that size, shape, depth and mineral content of reserves are well-established. Probable reserves have a moderate degree of geologic assurance and are reserves for which quantity and grade and/or quality are computed from information similar to that used for proven reserves, but the sites for inspection, sampling and measurement are farther apart or are otherwise less adequately spaced. The degree of assurance, although lower than that for proven reserves, is high enough to assume continuity between points of observation. This reserve information reflects recoverable tonnage on an as-received basis with 5.5% moisture.

(2)   Represents estimated reserves on properties acquired during the relevant period. We calculated the reserves in the same manner, and based on the same assumptions and qualifications, as described above, but such estimates were not covered by the MM&A report.

(3)   Represents changes in reserves due to additional information obtained from exploration activities, production activities or discovery of new geologic information. We calculated the reserves in the same manner, and based on the same assumptions and qualifications, as described above, but such estimates were not covered by the MM&A report.

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Key Performance Indicators

We manage our business through several key performance metrics that provide a summary of information in the areas of sales, operations, and general/administrative costs.

In the sales area, our long-term metrics are the volume-weighted average remaining term of our contracts and our open contract position for the next several years. During periods of high prices, such as the current period, we may seek to lengthen the average remaining term of our contracts and reduce the open tonnage for future periods. In the short-term, we closely monitor the Average Selling Price per Ton (ASP), and the mix between our spot sales and contract sales.

In the operations area, we monitor the volume of coal that is produced by each of our principal sources, including company mines, contract mines, and purchased coal sources. For our company mines, we focus on both operating costs and operating productivity. Our operating costs are measured by our operating costs per ton produced. Our operating productivity is measured by Linear Feet (of mine advance) Per Man Hour (LFPMH). LFPMH gives us a good indication of labor productivity across a number of different mines.

In the selling, general and administrative area, we closely monitor the gross dollars spent per mine operation and in support functions. We also regularly measure our performance against our internally-prepared budgets.

Trends In Our Business

We expect the current strong pricing environment for coal to weaken somewhat during the next one to two years. This is due to increased incremental production that has historically come into the markets during periods of strong pricing. We believe that the impact of this potentially increased production will be offset by the need of utilities to rebuild diminished coal inventories resulting from service difficulties that the major railroads experienced in 2004. According to the Energy Information Administration (EIA), coal stockpiles at utilities are currently below normal levels. Any effort by the utilities to rebuild their inventory positions should absorb a portion of any increased coal production. Any recurrence of the difficulties with rail transportation experienced during 2004 may also have an impact on increased production and market pricing. If marginal increases in the production of coal cannot be delivered to the utility customers by rail in a timely manner, the depressing effect of the increased production on market prices will be reduced. In addition, any new coal production would likely require additional permits, labor and equipment, which are currently difficult and time consuming to obtain.

Although the current pricing environment for U.S. coal is strong, coal prices are subject to change based on a number of factors beyond our control, including:

• the supply of domestic and foreign coal;

• the demand for electricity;

• the demand for steel and the continued financial viability of the domestic and foreign steel industries;

• the cost of transporting coal to the customer;

• domestic and foreign governmental regulations and taxes;

• air emission standards and other environmental requirements for coal-fired power plants; and

• the price and availability of alternative fuels for electricity generation.

As discussed previously, our costs of production have recently increased. We expect the higher costs to continue for the next several years, due to a highly competitive market for a limited supply of skilled mining personnel and higher costs in worldwide commodity markets. We are actively recruiting and training new personnel to staff our mines. However, we expect the strong market pricing for coal to increase turnover of existing personnel and potentially lead to higher costs for employees that we retain. Our costs have also increased for steel and other commodities used in our mining operations. We believe these increases are the result of economic development in the Pacific Rim (notably China) and an expanding economy in the United States. We do not anticipate a change in these circumstances during the next one to two years.

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Plan of Reorganization

In March 2003, we and all of our subsidiaries filed voluntary petitions with the United States Bankruptcy Court for the Middle District of Tennessee for reorganization under Chapter 11. In January 2004, we filed a Plan of Reorganization for the Chapter 11 cases. The plan was subsequently accepted by the required percentage of creditors entitled to vote on the plan and was confirmed by the bankruptcy court in April 2004.

On May 6, 2004, after securing a new senior secured line of credit and term loan facility, our Plan of Reorganization became effective, and we emerged from Chapter 11 bankruptcy proceedings, as more fully described under “Business—Recent Reorganization.” Our implementation of fresh start accounting pursuant to SOP 90-7 resulted in material changes to our consolidated financial statements, including the valuation of our assets and liabilities at fair value in accordance with principles of purchase accounting, and the valuation of our equity based on a valuation of our business prepared by our independent financial advisors.

As a result of the reorganization transactions and the implementation of fresh start accounting, our results of operations after our emergence from bankruptcy are those of a new reporting entity (the “Successor Company”), and are not comparable to the results of operations of the pre-emergence Company (the “Predecessor Company”) for prior periods described in this management’s discussion and analysis and reported in our consolidated financial statements.

Financial statements for periods after March 25, 2003 and prior to April 30, 2004 include the effects of our bankruptcy proceedings. These include the classification of certain liabilities as “liabilities subject to compromise,” the classification of certain expenses, and gains and losses as reorganization items, and other matters described in the notes to our consolidated financial statements.

Workers’ Compensation Cost and Accrued Liabilities

Our cost and accrued liabilities for workers’ compensation and other employee benefits have risen dramatically during the past several years.

Our accrued liability for workers’ compensation as of March 31, 2005 was $50.5 million. Our expense for workers’ compensation was $9.3 million in 2004 and $2.7 million in the three months ended March 31, 2005. Our expense in 2004 was impacted by favorable actuarial changes that resulted in a $3.5 million decrease in our workers’ compensation reserves during 2004. Our workers’ compensation expense has ranged from $9.3 million in 1999 to $14.5 million in 2003. Generally, we have experienced an increase over time in our workers’ compensation expense due to factors that impact the entire coal industry as well as factors that are unique to us.

For the coal industry, workers’ compensation costs have increased due to changes in laws, changes in the interpretation of the laws by the courts and an overall increase in both the number and amounts of disability awards. According to the 2003 Annual Report of the Kentucky Office of Workers’ Claims, for 1999–2003, the number of claims filed increased by 31%, and the total system cost of the workers’ compensation programs increased by 25%.

During the 1990s, we completed several acquisitions that included the assumption of all historical liabilities associated with workers’ compensation. These liabilities were greater than originally projected. In addition, our financial condition began to deteriorate in 1999. This caused us to reduce our spending for new equipment and for major repairs. We were also seeking a merger with or sale to other large firms in our industry. This caused a great deal of uncertainty for our employees. We believe that both of these facts led to a higher rate of reported accidents than would have otherwise been the case.

During the bankruptcy period, we stopped paying interest on our pre-petition secured debt and were able to negotiate interim price adjustments with our customers. The additional funds provided by these items have been used to purchase new equipment and complete major repairs to our equipment fleet, thereby improving the safety of our workplace. Since emerging from bankruptcy, we have begun to hire management and staff to assist us in managing our exposure to workers’ compensation claims. These employees have focused on improving our hiring practices, implementing new safety training procedures and better managing our workers’ compensation claims process.

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Results of Operations

Three Months Ended March 31, 2005 Compared with the Three Months Ended March 31, 2004

The following compares the three months ended operating results for the Predecessor Company with that of the Successor Company. However, as a result of the reorganization transaction and the implementation of fresh start accounting, the results of operations of the Successor Company and the Predecessor Company are not comparable.

The following table shows selected operating results for the three months ended March 31, 2005 compared to the three months ended March 31, 2004 (in 000’s):

	Three Months Ended March 31,
	2005		2004		Total
Volume (tons)		2,228		2,287		(3	%)
Revenues
Coal sales	$	96,401		79,239		22	%
Synfuel handling		1,474		1,619		(9	%)
Cost of coal sold		80,942		65,707		23	%
Depreciation, depletion and amortization		9,478		9,272		2	%
Gross Profit		7,455		5,879		27	%
Selling, general and administrative		5,035		3,561		41	%

 

Volume and revenues

For the three months ended March 31, we shipped 2.2 million tons of coal in 2005 and 2.3 million tons in 2004. We experienced a reduction during the three months ended March 31, 2005 of 102,000 tons from contract mining operations as compared to the three months ended March 31, 2004. This reduction was primarily due to delays in the commencement of operations at one of our contract surface mines and delays in obtaining production equipment. That contract surface mine began producing coal in April 2005 and is expected to reach normalized production levels during the second quarter of 2005.

Coal sales revenue for the three months ended March 31, increased from $79.2 million in 2004 to $96.4 million in 2005. This increase was due to an increase in the average sales price per ton for sales under long-term contracts and spot sales. For the three months ended March 31, 2005, we sold 1.9 million tons of coal under long-term contracts (87% of total sales volume) at an average selling price of $40.46 per ton. For the three months ended March 31, 2004, we sold 1.9 million tons of coal (82% of total sales volume) under long-term contracts at an average selling price of $33.51 per ton. The increase in average selling price from contract sales from 2004 to 2005 was due to the renegotiation of below-market contract prices as part of our bankruptcy proceedings. For the three months ended March 31, 2005, we sold 296,000 tons of coal (13% of total sales volume) to the spot market at an average selling price of $61.63 per ton. For the three months ended March 31, 2004, we sold approximately 405,000 tons (18% of total sales volume) to the spot market at an average selling price of $39.92 per ton.

Operating costs

For the three months ended March 31, the cost of coal sold, excluding depreciation, depletion and amortization, increased from $65.7 million in 2004 to $80.9 million in 2005. Our cost per ton of coal sold increased from $28.70 per ton in the 2004 period to $36.33 per ton in the 2005 period. This $7.63 increase in cost per ton of coal sold was due to several factors. Sales related costs (primarily royalties and severance taxes) increased by $1.30 per ton as a result of increased sales prices. Labor and benefit costs increased by $1.24 per ton in the 2005 period due to a wage increase to all production employees, effective January 1, 2005. The competitive job market in the coal industry necessitated this increase. Variable costs increased by $3.41 per ton, primarily due to a per ton increase in roof support materials and mining bits costs due to the increase in worldwide steel prices. Trucking costs increased by $1.16 per ton in the 2005 period due to tonnage restrictions and higher fuel costs.

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For the three months ended March 31, depreciation, depletion and amortization, increased from $9.3 million in 2004 to $9.5 million in 2005. On a per ton basis, depreciation, depletion and amortization was $4.05 for the three months ended March 31, 2004 and $4.25 for the three months ended March 31, 2005. These results are not comparable due to the impact of fresh start accounting on our asset base.

Selling, general and administrative expenses increased from $3.6 million for the three months ended March 31, 2004 to $5.0 million for the months ended March 31, 2005. This increase was primarily due to $447,000 of charges in 2005 for stock related compensation, a $256,000 increase in salaries, a $261,000 increase in other administrative costs associated with being a public company and a $213,000 increase in bank fees for our asset backed credit facilities.

Income taxes

Our effective tax rate for the three months ended March 31, 2005 was 18.3%. Our effective income tax rate is impacted by percentage depletion. Percentage depletion is an income tax deduction that is limited to a percentage of taxable income from each of our mining properties. Because percentage depletion can be deducted in excess of cost depletion, it creates a permanent difference and directly impacts the effective tax rate. Fluctuations in the effective tax rate may occur due to the varying levels of profitability (and thus, taxable income and percentage depletion) at each of our mine locations.

Year Ended December 31, 2004 Compared with the Year Ended December 31, 2003

In order to provide a basis for comparing the year ended December 31, 2004 with the year ended December 31, 2003, the operating results of the Successor Company for the eight months ended December 31, 2004 have been combined with the operating results for the Predecessor Company for the four months ended April 30, 2004, for purposes of the following table and discussion. The combining of the predecessor and successor accounting periods is not permitted by generally accepted accounting principles. Additionally, as explained above, the operating results of the Successor Company and the Predecessor Company are not comparable.

The following table shows selected operating results for the year ended December 31, 2004 compared to the year ended December 31, 2003:

	Year Ended December 31,
	2004		2003		Change
Volume (millions of tons)		8.9		10.1		(12	%)
Revenues (000)
Coal sales	$	338,297	$	297,713		14	%
Synfuel handling		7,350		6,339		16	%
Cost of coal sold (000)		280,220		278,939		1	%

 

Volume and revenues

We shipped 10.1 million tons of coal in 2003 and 8.9 million tons in 2004. Production from our company mines decreased by approximately 138,000 tons in 2004 as compared to 2003. This decrease in production from our company mines was due to adverse geological conditions at several of our mines and several major moves of mining equipment and personnel in the third and fourth quarters of 2004. In addition, there was a reduction during the year of 54% or 635,000 tons from contract mining operations. This reduction in coal obtained from contract mining operations is attributed to several underground mine contractors terminating our contract mine agreements to seek higher-priced opportunities with our competitors or closing operations due to depletion of reserves. We also experienced a decrease of 57%, or 448,000 tons, in coal purchased by us for resale. The reduction in coal purchased for resale from third parties is the result of the increased competition for purchased coal. We continue to be challenged in replacing contract mine operators and purchased coal sources due to the continued strong coal market.

Coal sales revenue increased from $297.7 million in 2003 to $338.3 million in 2004. This increase was due to an increase in spot coal sales, which commanded a higher price in 2004 than in 2003, as well as an increase

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in the average sales price per ton for sales under long-term contracts. For the year ended December 31, 2004, we sold 7.2 million tons of coal under long-term contracts (81% of total sales volume) at an average selling price of $35.22. For 2003, we sold 9.3 million tons of coal under long-term contracts (92% of total sales volume) at an average selling price of $28.91. The increase in average selling price from 2003 to 2004 was due to the renegotiation of below-market contract prices as part of our bankruptcy proceedings. For the year ended December 31, 2004, we sold 1.7 million tons of coal (19% of total sales volume) to the spot market at an average selling price of $50.09 per ton. For 2003, we sold 772,000 tons of coal (8% of total sales volume) to the spot market at an average selling price of $36.91 per ton.

Revenues related to the handling, loading and shipping of synfuel increased from $6.3 million for the year ended December 31, 2003 to $7.4 million for the year ended December 31, 2004. We processed and shipped 6% less coal as synfuel in 2004 than we processed and shipped in 2003. However, our fees, on a per ton basis, increased during the same period.

Operating costs

The cost of coal sold, excluding depreciation, depletion and amortization, increased from $278.9 million in 2003 to $280.2 million in 2004, even though the amount of coal we shipped decreased by 1.2 million tons. Our cost per ton of coal sold increased from $27.67 per ton in 2003 to $31.55 per ton in 2004. This $3.88 increase in cost per ton of coal sold was due to several factors. For production from our company-operated mines, sales related costs (primarily royalties and severance taxes) increased by $1.42 per ton as a result of increased sales prices. Labor and benefit costs for those tons increased by $1.00 per ton in 2004 primarily due to lower productivity at several mines. The labor and benefit costs were partially offset by a reduction in workers compensation costs of $3.5 million, or $0.40 per ton, during the fourth quarter of 2004, reflecting improved actuarial trends. Variable costs increased by $1.12 per ton, primarily due to higher roof support and machine parts costs primarily related to the increased cost of steel. In addition, the cost of coal produced by independent contract mine operators (6% of our 2004 tonnage) increased by $2.89 per ton while the cost of coal purchased from outside parties for resale (4% of our 2004 tonnage) increased by $3.39 per ton for the period. The application of fresh start accounting required that we increase the value of our inventory by approximately $1.1 million on April 30, 2004. This adjustment increased our cost of coal sold and reduced gross profit during the eight months ended December 31, 2004 by a corresponding amount.

For the year ended December 31, depreciation, depletion and amortization decreased from $40.4 million in 2003 to $34.1 million in 2004. On a per ton basis, depreciation, depletion and amortization was $4.01 in 2003 and $3.84 in 2004. This decrease was primarily due to the impact of fresh start accounting on our asset base.

Selling, general and administrative expenses decreased from $19.8 million in 2003 to $16.4 million in 2004. This decrease was primarily due to a $4.2 million reduction in certain costs due to our exit from bankruptcy. This decrease was offset by approximately $1.1 million of stock-based compensation expense recorded in 2004. We had no stock based compensation expense in 2003.

Year Ended December 31, 2003 Compared with the Year Ended December 31, 2002

The following table shows selected operating results for the years ended December 31, 2003 and December 31, 2002:

	Year Ended December 31,
	2003			2002			Change
Volume (millions of tons)		10.1			13.9			(27	%)
Revenues (000)
Coal sales	$	297,713			393,512			(24	%)
Synfuel handling		6,339			4,087			55	%
Cost of coal sold (000)		278,939			344,222			(19	%)
Depreciation, depletion and amortization		40,427			46,393			(13	%)
Selling, general and administrative expenses		19,835			19,994			(1	%)
Other operating expenses		—			26,554
Operating loss		(35,149	)		(39,564	)

 

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Volume and revenues

We shipped 13.9 million tons of coal in 2002 and 10.1 million tons in 2003. The decrease was due to the closure of higher-cost Company-operated mines (2.4 million tons), reduced purchased coal tonnage (749,000 tons) and reduced tonnage from contract mining operations (662,000 tons). The decrease in purchased coal tonnage was primarily due to the loss of a supplier of purchased coal for our Blue Diamond operation. The filing of our bankruptcy petition on March 25, 2003 adversely impacted our outside sources of coal, and resulted in several contract mine operators terminating their relationship with us. The majority of this adverse impact was felt in the months after our bankruptcy filing.

Coal sales revenue for the year ended December 31 declined from $393.5 million in 2002 to $297.7 million in 2003. The decrease in revenue was due to fewer tons being available for sale, including coal produced from our Company-operated mines, coal produced by our independent contract mine operators and coal purchased by us for resale. For 2003, we sold 9.3 million tons of coal under long-term contracts (92% of total sales volume) at an average selling price of $28.91. For 2002, we sold 12.4 million tons of coal under long-term contracts (89% of total sales volume) at an average selling price of $27.42. The increase in average selling price was due to interim contract price increases during 2003. For 2003, we sold 772,000 tons of coal (8% of total sales volume) to the spot market at an average selling price of $36.91 per ton. For 2002, we sold 1.5 million tons (11% of total sales volume) to the spot market at an average selling price of $34.92 per ton. The change in the average selling price per ton of spot coal was due to an overall strengthening in the coal and energy markets during the fourth quarter of 2003.

Revenues related to the handling, loading and selling of synfuel increased from $4.1 million for 2002 to $6.3 million for 2003. This change was due to more coal being processed and shipped as synfuel. We processed and shipped 56% more coal as synfuel in 2003 than we processed and shipped in 2002.

Operating costs

For the year ended December 31, the cost of coal sold, excluding depreciation, depletion and amortization, decreased from $344.2 million in 2002 to $278.9 million in 2003. This decrease was due to a change in the volume of coal mined and shipped. Costs per ton of coal sold increased approximately $2.95, or 12%, to $27.67 in 2003 compared with $24.72 in 2002. The increase in per ton costs was primarily caused by higher variable costs at the mines for supplies, maintenance items and repairs of $0.83 per ton, higher costs at preparation plants and loadout facilities of $0.57 per ton due to fixed costs being spread over fewer tons and from the increased cost of contract miners (labor) of $0.30 per ton. We also experienced difficult geologic conditions at one of our mine complexes during the fourth quarter of 2003, which increased our costs by approximately $0.67 per ton. Our Linear Feet per Man Hour (LFPMH) decreased from 1.66 in 2002 to 1.57 in 2003. Our Clean Tons per Linear Foot (CTPLF) decreased from 2.53 in 2002 to 2.49 in 2003. Both of these changes increased our operating costs per ton by spreading fixed costs over fewer tons.

Depreciation, depletion and amortization decreased from $46.4 million in 2002 to $40.4 million in 2003. The decrease was caused by the reduction in tons sold offset by an increase in the per ton cost. On a per ton basis, depreciation, depletion and amortization was $3.33 in 2002 and $4.01 in 2003. A portion ($0.10) of this increase was due to us lowering our estimate of remaining reserves in 2003, which increased the amortization expense per ton mined in 2003. See “Business—Reserves” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Estimates—Coal Reserves” for a discussion of how we estimate our mineral reserves.

Selling, general and administrative expenses decreased from $20.0 million in 2002 to $19.8 million in 2003.

Other operating expenses were $26.6 million in 2002. These expenses represent adjustment for loss on abandoned mining fixed assets ($9.1 million), mine development costs ($7.7 million), prepaid royalties on abandoned properties ($4.2 million), capitalized debt issuance costs ($4.1 million) and other items ($1.5 million). In 2002, as part of our efforts to eliminate unprofitable operations, several mines and a preparation plant were idled. We determined that those operations could not be operated profitably, due to uneconomical or depleted reserves,

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so the preparation plant and certain assets associated with the mines (i.e., mine development costs, certain equipment and prepaid royalties) were abandoned.

Interest expense

Interest expense decreased to $18.5 million for 2003, compared with $29.9 million for 2002. The decrease was primarily due to our Chapter 11 bankruptcy filing on March 25, 2003 and the automatic stay from accruing and paying interest on our pre-petition debt. In the first quarter 2003, an interest rate swap agreement that we had previously entered into was terminated due to an event of default. As a result, the balance of $9.3 million that was recorded in accumulated other comprehensive loss was charged to interest expense. The higher interest cost for 2002 was primarily due to the increased interest rate in 2002 on our outstanding debt due to defaults under our loan and note agreements.

Miscellaneous income

Miscellaneous income increased from a $1.2 million gain in 2002 to a $1.5 million gain in 2003. In 2002, we received a royalty settlement of $1.1 million, and, in 2003, we had a $1.0 million gain from the sale of an investment.

Reorganization items, net

Reorganization items were $7.6 million in 2003. These costs represented the reorganization professional costs incurred in connection with our bankruptcy filing. There were no reorganization items incurred in 2002.

Income taxes

Income tax benefit was $2.9 million for 2003, compared with $8.1 million for 2002. The $2.9 million benefit for 2003 resulted from recording a deferred tax benefit on a loss on an interest rate swap that was previously recorded in other comprehensive loss. We had no other income tax expense or benefit for 2003 as we continued to record a valuation allowance against all of our net deferred tax assets.

Due to continuing losses from operations, 2002 was the first year in which we recorded a full valuation allowance against net deferred tax assets. The tax benefit of $8.1 million is lower than the “expected” tax benefit, calculated at 34%, of $22.9 million due to the recording of a $14.2 million valuation allowance against our net deferred tax assets and a $0.6 million net adjustment primarily for percentage depletion and state income taxes.

Cumulative effect of accounting change

We adopted Statement No. 143 effective January 1, 2003, and the adoption changed our accounting for reclamation. The cumulative effect of the accounting change was a charge to operations of $3.0 million. We also increased total reclamation liability by $6.8 million. We recorded the related capitalized asset retirement cost by increasing property, plant and equipment, net of accumulated depreciation, by $3.8 million.

Liquidity and Capital Resources

Although our cash from operations has changed significantly in the periods discussed below, we do not believe that those periods are comparable due to our emergence from bankruptcy. We experienced unusual swings in working capital leading up to and entering bankruptcy. We also were able to renegotiate our coal contracts due to the bankruptcy, which increased our revenues. Our liquidity going forward will be generated by our gross profit on coal sales. The gross profit will be driven by the price of coal and our operating costs. Our capital expenditure payments for existing operations are expected to be paid out of the cash generated by the gross profit.

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As of March 31, 2005, we had available liquidity of approximately $6.8 million. This consisted of unrestricted cash on hand of approximately $1.7 million and availability under the revolver component of our Senior Secured Credit Facility of approximately $5.1 million.

After the refinancing of our existing debt as described elsewhere in this prospectus, we expect to have availability under our proposed new senior secured credit facility of approximately $25 million.

Excluding the financings we are undertaking in connection with the proposed Triad acquisition, our primary source of cash will be sales of coal to our utility and industrial customers. The price of coal received can change dramatically based on supply and demand and will directly affect this source of cash. Our primary uses of cash include the payment of ordinary mining expenses to mine coal, capital expenditures and benefit payments. Ordinary mining expenses are driven by the cost of supplies, including steel prices and diesel fuel. Benefit payments include payments for workers’ compensation and black lung benefits paid over the lives of our employees. We are required to pay these when due, and are not required to set aside cash for these payments. We have posted surety bonds with state regulatory departments to guarantee these payments and have secured letters of credit as further security for these obligations. Recently, surety bond costs have increased, while the market terms of surety bonds have generally become less favorable. To the extent that surety bonds become unavailable, we would seek to secure obligations with letters of credit, cash deposits, or other suitable forms of collateral. The benefit payments for workers’ compensation and black lung benefits will be paid as the claims are submitted over the lives of our employees. We believe that these benefit payments are reasonably predictable and we have reflected them in the contractual obligations table below.

Excluding the financings we are undertaking in connection with the proposed Triad acquisition, we expect that our secondary source of cash will be the revolver component of our proposed new senior secured credit facility. We believe that cash on hand, cash generated from our operating activities, and availability under the revolver component of our proposed new senior secured credit facility will be sufficient to meet our working capital needs, to fund our capital expenditures for existing operations and to meet our debt service obligations for the next twelve months, excluding the Triad acquisition. Nevertheless, there are many factors beyond our control, including general economic and coal market conditions, that could have a material adverse impact on our ability to meet our liquidity needs.

In the event that the sources of cash described above are not sufficient to meet our future cash requirements, we will need to reduce certain planned expenditures or seek additional financing, or both. If debt financing is not available on favorable terms, we may seek to raise funds through the issuance of our equity securities. If such actions are not sufficient, we may need to limit our growth or reduce or curtail some of our operations to levels consistent with the constraints imposed by our available cash flow, or both. Our ability to seek additional debt or equity financing may be limited by our existing and any future financing arrangements and/or economic and financial conditions. In particular, our Senior Secured Credit Facility restricts our ability to incur additional indebtedness. We cannot provide assurance that any reductions in our planned expenditures or in our expansion and personnel would be sufficient to cover shortfalls in available cash or that additional debt or equity financing would be available on terms acceptable to us, if at all.

Other than ordinary course of business expenses and capital expenditures for existing mines during the next several years and the proposed Triad acquisition, our only large expected use of cash will be the development of a new mine at our McCoy Elkhorn complex. We expect to invest approximately $23 million during 2005 in the development of the new McCoy Elkhorn mine and the related preparation plant upgrade. We expect that such developments will be funded through cash on hand, cash generated by operations and from the revolver component of our Senior Secured Credit Facility and proposed new senior secured credit facility.

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The following chart reflects the components of our debt as of December 31, 2004 on an actual basis and as adjusted to give effect to the refinancing of our existing credit facilities and the Triad acquisition, as if such events had occurred as of December 31, 2004:

	Actual		As adjusted
	(in thousands)
Senior Secured Credit Facility:
Term loan component	$	20,000		—
Revolver component		—		—
Term Credit Facility		75,000		—
Proposed New Senior Secured Credit Facility		—		—
Senior Notes due 2012		—		150,000
Other		—		1,712
Total long term debt		95,000		151,712
Less amounts classified as current		2,700		1,712
Total long term debt, less current maturities	$	92,300		150,000

 

Effective May 6, 2004, we closed a $50 million senior secured credit facility with Wells Fargo Foothill, Inc. (the “Senior Secured Credit Facility”). This facility was used to repay outstanding amounts and replace letters of credit under our $20.0 million debtor-in-possession facility, to fund expenses associated with our exit from bankruptcy and to provide liquidity for general corporate purposes. The Senior Secured Credit Facility is comprised of a $30 million revolver component and a $20 million term component. The term loan was fully funded at closing. Borrowings under the revolver component bear interest at LIBOR + 2.5% or the Base Rate (as defined in the credit agreement) + 1.0%. Borrowings under the term component bear interest at LIBOR + 5.25% or the Base Rate + 3.85%. The term of the Senior Secured Credit Facility is five years. Principal payments on the term component of $900,000 per quarter commence on April 1, 2005 and continue through April 1, 2009, with the remaining principal balance due on May 6, 2009. Interest is payable in arrears, on the first day of each month on Base Rate borrowings while interest on LIBOR Rate borrowings is due on the last day of the LIBOR interest period. Advances under the Senior Secured Credit Facility are secured by a first priority lien on substantially all of our assets, and, except for the Term Credit Facility, we may not incur additional debt on the assets securing the Senior Secured Credit Facility. Advances under the revolver component may not exceed a borrowing base calculation derived as a percentage of eligible assets. The Senior Secured Credit Facility can be terminated with 90 days written notice by paying all outstanding principal, interest and making any prepayment premium payments due. The $30 million revolver component has a prepayment premium of 2.5% of the total revolver commitment for the first year, declining to 2.0% for the second year, 1.5% for the third year and 0.5% for the fourth year. There is not a prepayment premium for the fifth year of the facility. The $20 million term loan component has a prepayment premium of $200,000 (1.0%) if paid prior to April 30, 2007. There is no prepayment premium after April 30, 2007.

We also entered into a $75 million restructured term credit facility with our pre-petition secured lenders (the “Term Credit Facility”) in partial satisfaction of our prepetition obligations, pursuant to the Plan of Reorganization. The term of the Term Credit Facility is seven years, and our repayment of the Term Credit Facility is secured by a second priority lien on substantially all of our assets. Except for the Senior Secured Credit Facility, we may not incur additional debt on the assets securing the Term Credit Facility. In addition, we may not incur any unsecured debt (other than normal trade payables) and may not incur more than $5 million of recourse debt (including the Senior Secured Credit Facility and the Term Credit Facility). The Term Credit Facility provides for an annual interest rate of 9%. There is no scheduled amortization of this facility for the first two years. The notes are payable over seven years with principal repayments of $1.5 million per quarter beginning June 30, 2006 and increasing to $2.5 million per quarter beginning June 30, 2008. All remaining principal and interest is due May 6, 2011. Borrowings under the Term Credit Facility may be prepaid without penalty.

The Senior Secured Credit Facility and the Term Credit Facility contain financial covenants for fixed charge coverage, total leverage, minimum consolidated tangible net worth, minimum Consolidated Total EBITDA (as defined in each of the credit facilities), and maximum capital expenditures. We were in compliance with all of the

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financial covenants for the Senior Secured Credit Facility and the Term Credit Facility as of December 31, 2004. As of such date, the covenants included a minimum fixed charge ratio of .75 to 1.0, minimum leverage ratio of 2.75 to 1.0, minimum consolidated tangible net worth of $20 million, minimum Consolidated Total EBITDA of $44.0 million and maximum annual limits on capital expenditures of $35.3 million for all projects other than the new underground mine under development at our McCoy Elkhorn mining complex, and $27.3 million for capital expenditures at that new mine during 2005.

As described above, we expect to refinance all amounts outstanding under the Senior Secured Credit Facility and Term Credit Facility with the proceeds of our concurrent common stock and notes offerings. We also expect to enter into our proposed new senior secured credit facility. Our proposed new senior secured credit facility is described under “Description of Indebtedness.” After giving effect to these transactions, our total debt and interest expense will increase significantly. See “Unaudited Pro Forma Condensed Consolidated Financial Statements” and “Capitalization.” The concurrent offerings of common stock and notes are not conditioned upon each other. We cannot assure you that we will be able to complete either or both of the concurrent offerings or enter into our proposed new senior secured credit facility.

Net cash provided by or used in operating activities reflects net income or loss adjusted for non-cash charges and changes in net working capital (including non-current operating assets and liabilities). Net cash provided by operating activities was $12.7 million for the three months ended March 31, 2005, and net cash used by operating activities was $3.1 million for the three months ended March 31, 2004. For the three months ended March 31, 2005, our net income, as adjusted for non cash charges, was increased by $2.1 million due to changes in our working capital. This change in net working capital was primarily caused by changes in accounts receivable due to increased sales and an increase in accounts payable due to timing. Net cash provided by operating activities was $15.6 million for the year ended December 31, 2004, and net cash provided by operating activities was $23.0 million for the year ended December 31, 2003. For the year ended December 31, 2004, our net income, as adjusted for non cash charges, was offset by a $30.2 million decrease in cash from operations due to changes in our working capital. This change in net working capital was primarily caused by changes in accounts receivable, due to increased sales prices of coal and a decrease in accounts payable due to increased liquidity upon emergence from bankruptcy.

Net cash used by investing activities increased from $6.8 million to $14.7 million for the three months ended March 31, 2005 as compared to the three months ended March 31, 2004. The increase was primarily due to additional capital expenditures for the three months ended March 31, 2005 on Mine 15 of $5.5 million. The remaining capital expenditures primarily consisted of new and replacement mine equipment and various projects to improve the efficiency of our mining operations. Net cash used by investing activities increased $15.5 million to $31.2 million for the year ended December 31, 2004 as compared to the year ended December 31, 2003. The change was primarily due to a $15.2 million increase in capital expenditures in 2004 to $35.3 million as compared to 2003, offset by a $4.0 million increase in proceeds on sales of property in 2004. Capital expenditures primarily consisted of new and replacement mine equipment and various projects to improve the efficiency of our mining operations. The cash used in investing activities in 2003 also included a $2.3 million reduction in restricted cash and $2.0 million from the sale of investments. Our cash used by investing activities in 2002 was $33.5 million and included $22.9 million of capital expenditures and a $10.6 million change in restricted cash.

Net cash provided by or used in financing activities primarily reflects changes in short- and long-term financing. Net cash used in financing activities was $0.1 million for the three months ended March 31, 2005 and net cash provided by financing activities was $6.3 million for the three months ended March 31, 2004. During the three months ended March 31, 2004, we borrowed $6.4 million under a debtor in possession credit facility. Net cash provided by or used in financing activities primarily reflects changes in short- and long-term financing. Net cash provided by financing activities was $14.6 million for the year ended December 31, 2004 and net cash used in financing activities was $2.5 million for the year ended December 31, 2003. During 2004, we received $20.0 million in proceeds, less $2.2 million capitalized debt issuance costs, from the Senior Secured Credit Facility in May 2004. During 2004, we also borrowed and repaid $6.4 million under the debtor in possession credit facility. We had no proceeds from borrowings and had $1.9 million in principal payments during the year ended December 31, 2003. Net cash provided by financing activities in 2002 was $3.3 million, primarily due to the issuance of $3.4 million of debt under our pre-petition credit agreements in 2002.

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Contractual Obligations

The following is a summary of our contractual obligations and commitments as of December 31, 2004:

	Payment Due by Period (in thousands)
Contractual Obligations	Total		Less than 1 year		1–3 years		3–5 years		More than 5 years
Long term debt (1)	$	95,000	$	2,700	$	17,700	$	29,100	$	45,500
Interest on long term debt (2)		51,469		11,158		21,491		14,214		4,606
Capital lease obligations (3)		1,142		459		683		—		—
Operating lease obligations (3)		1,239		605		552		82		—
Royalty obligations (4)		141,732		14,705		31,233		28,414		67,380
Purchase obligations (5)		603		603		—		—		—
	$	291,185	$	30,230	$	71,659	$	71,810	$	117,486

 

(1) All existing long term debt will be repaid and replaced with the notes and the proposed new senior secured credit facility. Assuming our refinancing transactions are consummated as contemplated, subsequent to the refinancing, we will have $150 million of new senior notes outstanding, which will mature in 2012.

(2) Includes interest payments on variable rate debt that is based on the interest rate in effect as of December 31, 2004. All such debt will be repaid with proceeds from the concurrent notes offering and the proposed new senior secured credit facility. Assuming interest on the senior notes of 9.375%, we will be contractually obligated to pay approximately $14.1 million of interest annually on such notes.

(3) Capital lease obligations include the amount of imputed interest over the terms of the leases. See Note 13 in the notes to the consolidated financial statements for additional information on capital and operating leases.

(4) Royalty obligations include minimum royalties payable on leased coal rights. Certain coal leases do not have set expiration dates but extend until completion of mining of all merchantable and mineable coal reserves. For purposes of this table, we have generally assumed that minimum royalties on such leases will be paid for a period of ten years.

(5) Purchase obligations include agreements to purchase coal that include fixed quantities or minimum amounts and a fixed price provision. They do not include agreements to purchase coal with vendors that do not include quantities or minimum tonnages, or monthly purchase orders.

Additionally, we have liabilities relating to pension, workers compensation, black lung and mine reclamation and closure. As of December 31, 2004, payments related to these items are estimated to be:

Payments Due by Years (in thousands)
Within 1 Year	2–3 Years	4–5 Years
$17,700	$25,938	$21,318

 

Our determination of these noncurrent liabilities is calculated annually and is based on several assumptions, including then prevailing conditions, which may change from year to year. In any year, if our assumptions are inaccurate, we could be required to expend greater amounts than anticipated. Moreover, in particular for periods after 2004, our estimates may change from the amounts included in the table, and may change significantly, if our assumptions change to reflect changing conditions. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Critical Accounting Estimates” and the notes to the Consolidated Financial Statements.

Off-Balance Sheet Arrangements

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

We use surety bonds to secure reclamation, workers’ compensation and other miscellaneous obligations. At March 31, 2005, we had $69.4 million of outstanding surety bonds with third parties. These bonds were in place to secure obligations as follows: post-mining reclamation bonds of $26.6 million, workers’ compensation bonds of $40.3 million, wage payment, collection bonds, and other miscellaneous obligation bonds of $2.5 million.

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Recently, surety bond costs have increased, while the market terms of surety bonds have generally become less favorable. To the extent that surety bonds become unavailable, we would seek to secure obligations with letters of credit, cash deposits, or other suitable forms of collateral.

We also use bank letters of credit to secure our obligations for workers’ compensation programs, various insurance contracts and other obligations. At March 31, 2005, we had $32.7 million of letters of credit outstanding, including $7.8 million of letters of credit outstanding collateralized by $8.4 million of cash deposited in restricted, interest-bearing accounts pledged to issuing banks.

Critical Accounting Estimates

Overview

Our discussion and analysis of our financial condition, results of operations, liquidity and capital resources are based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. Generally accepted accounting principles require estimates and judgments that affect reported amounts for assets, liabilities, revenues and expenses. The estimates and judgments we make in connection with our consolidated financial statements are based on historical experience and various other factors we believe are reasonable under the circumstances. Note 1 of the notes to the consolidated financial statements lists and describes our significant accounting policies. The following critical accounting policies have a material effect on amounts reported in our consolidated financial statements.

Workers’ Compensation

Our most significant long-term obligation is the obligation to provide workers’ compensation benefits. We are liable under various state statutes for providing workers’ compensation benefits. To fulfill these obligations, we have used self-insurance programs with varying excess insurance levels, and, since June 7, 2002, a high-deductible, fully insured program. The high-deductible, fully insured program is comparable to a self-insured program where the excess insurance threshold equals the deductible level.

We accrue for the present value of certain workers’ compensation obligations as calculated by an independent actuary based upon assumptions for work-related injury and illness rates, discount rates and future trends for medical care costs. The discount rate is based on interest rates on bonds with maturities similar to the estimated future cash flows. The discount rate used to calculate the present value of these future obligations was 5.25% at December 31, 2004. Significant changes to interest rates result in substantial volatility to our consolidated financial statements. If we were to decrease our estimate of the discount rate from 5.25% to 4.25%, all other things being equal, the present value of our workers’ compensation obligation would increase by approximately $3.5 million. A change in the law, through either legislation or judicial action, could cause these assumptions to change. If the estimates do not materialize as anticipated, our actual costs and cash expenditures could differ materially from that currently estimated. Our estimated workers’ compensation liability as of March 31, 2005 was $50.5 million.

Coal Miners’ Pneumoconiosis

We are required under the Federal Mine Safety and Health Act of 1977, as amended, as well as various state statutes, to provide pneumoconiosis (black lung) benefits to eligible current and former employees and their dependents. We provide these benefits through self-insurance programs and, for those claims incurred with last exposure after June 6, 2002, a high-deductible, fully insured program.

An independent actuary has calculated the estimated pneumoconiosis liability based on assumptions regarding disability incidence, medical costs, mortality, death benefits, dependents and interest rates. The discount rate is based on interest rates on bonds with maturities similar to the estimated future cash flows. The discount rate used to calculate the present value of these future obligations was 5.25% at December 31, 2004. Significant changes to interest rates result in substantial volatility to our consolidated financial statements. If we were to decrease our estimate of the discount rate from 5.25% to 4.25%, all other things being equal, the present value of our black lung

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obligation would increase by approximately $3.3 million. A change in the law, through either legislation or judicial action, could cause these assumptions to change. If these estimates prove inaccurate, the actual costs and cash expenditures could vary materially from the amount currently estimated. Our estimated pneumoconiosis liability as of March 31, 2005 was $26.0 million.

Defined Benefit Pension

The estimated cost and benefits of our non-contributory defined benefit pension plans are determined by independent actuaries, who, with our review and approval, use various actuarial assumptions, including discount rate, future rate of increase in compensation levels and expected long-term rate of return on pension plan assets. In estimating the discount rate, we look to rates of return on high-quality, fixed-income investments. At December 31, 2004, the discount rate used to determine the obligation was 5.5%. Significant changes to interest rates result in substantial volatility to our consolidated financial statements. If we were to decrease our estimate of the discount rate from 5.5% to 4.5%, all other things being equal, the present value of our pension liability would increase by approximately $11.0 million. The rate of increase in compensation levels is determined based upon our long-term plans for such increases. The rate of increase in compensation levels used was 4.0% for the year ended December 31, 2004. The expected long-term rate of return on pension plan assets is based on long-term historical return information and future estimates of long-term investment returns for the target asset allocation of investments that comprise plan assets. The expected long-term rate of return on plan assets used to determine expense in each period was 8.0% for the year ended December 31, 2004. Significant changes to these rates would introduce substantial volatility to our pension expense. Our pension obligation as of March 31, 2005 was $15.2 million.

Reclamation and Mine Closure Obligation

The SMCRA establishes operational, reclamation and closure standards for all aspects of surface mining as well as many aspects of underground mining. Our total reclamation and mine-closing liabilities are based upon permit requirements and our engineering estimates related to these requirements. Statement No. 143 requires that asset retirement obligations be recorded as a liability based on fair value, which is calculated as the present value of the estimated future cash flows. Our management and engineers periodically review the estimate of ultimate reclamation liability and the expected period in which reclamation work will be performed. In estimating future cash flows, we considered the estimated current cost of reclamation and applied inflation rates and a third party profit, as necessary. The third party profit is an estimate of the approximate markup that would be charged by contractors for work performed on our behalf. The discount rate is based on interest rates of bonds with maturities similar to the estimated future cash flow. The estimated liability can change significantly if actual costs vary from assumptions or if governmental regulations change significantly. The actual costs could be different due to several reasons, including the possibility that our estimates could be incorrect, in which case our liabilities would differ. If we perform the reclamation work using our personnel rather than hiring a third party, as assumed under Statement No. 143, then the costs should be lower. If governmental regulations change, then the costs of reclamation will be impacted. Statement No. 143 recognizes that the recorded liability will be different than the final cost of the reclamation and addresses the settlement of the liability. When the obligation is settled, and there is a difference between the recorded liability and the amount of cash paid to settle the obligation, a gain or loss upon settlement is included in earnings. Our asset retirement obligation as of March 31, 2005 was $16.2 million.

Contingencies

We are the subject of, or a party to, various suits and pending or threatened litigation involving governmental agencies or private interests. We have accrued the probable and reasonably estimable costs for the resolution of these claims based upon management’s best estimate of potential results, assuming a combination of litigation and settlement strategies. Unless otherwise noted, management does not believe that the outcome or timing of current legal or environmental matters will have a material impact on our financial condition, results of operations, or cash

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flows. See “Business—Legal Proceedings” and the notes to the consolidated financial statements for further discussion on our contingencies.

Income Taxes

We account for income taxes in accordance with FASB Statement No. 109, Accounting for Income Taxes (“Statement No. 109”), which requires that deferred tax assets and liabilities be recognized using enacted tax rates for the effect of temporary differences between the book and tax bases of recorded assets and liabilities. Statement No. 109 also requires that deferred tax assets be reduced by a valuation allowance if it is more likely than not that some portion of the deferred tax asset will not be realized. In evaluating the need for a valuation allowance, we take into account various factors, including the expected level of future taxable income. We have also considered, but not relied upon, tax planning strategies in determining the deferred tax asset that will ultimately be realized. If actual results differ from the assumptions made in the evaluation of the amount of our valuation allowance, we record a change in valuation allowance through income tax expense in the period such determination is made.

At December 31, 2004, we had a net deferred tax liability of $34.6 million, which consisted of a total gross deferred tax asset of $107.4 million, a valuation allowance of approximately $61.1 million and a gross deferred tax liability of $80.9 million. The valuation allowance, which includes approximately $14.6 million that was recorded as part of our fresh start entries, provides a reserve for our net operating loss and alternate minimum tax credit carryforwards.

Coal Reserves

There are numerous uncertainties inherent in estimating quantities and values of economically recoverable coal reserves. Many of these uncertainties are beyond our control. As a result, estimates of economically recoverable coal reserves are by their nature uncertain. Information about our reserves consists of estimates based on engineering, economic and geological data assembled by our staff and analyzed by Marshall Miller & Associates, Inc. A number of sources of information were used to determine accurate recoverable reserves estimates, including:

• all currently available data;

• our own operational experience and that of our consultants;

• historical production from similar areas with similar conditions;

• previously completed geological and reserve studies;

• the assumed effects of regulations and taxes by governmental agencies; and

• assumptions governing future prices and future operating costs.

Reserve estimates will change from time to time to reflect, among other factors:

• mining activities;

• new engineering and geological data;

• acquisition or divestiture of reserve holdings; and

• modification of mining plans or mining methods.

Each of these factors may in fact vary considerably from the assumptions used in estimating reserves. For these reasons, estimates of the economically recoverable quantities of coal attributable to a particular group of properties, and classifications of these reserves based on risk of recovery and estimates of future net cash flows, may vary substantially. Actual production, revenue and expenditures with respect to reserves will likely vary from estimates, and these variances could be material. In particular, a variance in reserve estimates could have a material adverse impact on our annual expense for depreciation, depletion and amortization and our annual calculation for potential impairment. For a further discussion of our coal reserves, see “Business—Reserves.”

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Recent Accounting Pronouncements

On December 16, 2004, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standards No. 123 (revised 2004), “Share-Based Payment” (FAS 123R), which requires all public companies to measure compensation cost in the income statement for all share-based payments (including employee stock options) at fair value for fiscal years beginning after June 15, 2005. We intend to adopt FAS 123R on January 1, 2006 using the modified-prospective method. We have not completed our assessment of the impact of the adoption of this statement on our financial statements. FAS 123R also requires the benefits of tax deductions in excess of recognized compensation cost be reported as a financing cash flow, rather than as an operating cash flow as required under current literature. This requirement will reduce net operating cash flows and increase net financing cash flows in periods after adoption.

Other Supplemental Information

Labor and Turnover

Recruiting, hiring, and retaining skilled mine production personnel has become challenging during the past several years. This is due to the aging of the industry workforce and the availability of other suitable positions for potential employees. The current strong market prices have also contributed to a higher level of turnover as competing coal mining companies attempt to increase production.

Based on average employment of production personnel, our gross turnover has been approximately 18.3% during the twelve months ended March 31, 2005. Our net turnover during this period, after considering employees that have left and been rehired, is approximately 7.9%. We believe that our retention of employees is equal to, or better than, other coal mining companies in our operating area.

We are actively working to improve our results in this area including the development of safety and incentive plans that we believe will further reduce our employee turnover and improve employee relations.

Sales Commitments

As of March 31, 2005, we had the following contractual commitments (including long term and short term contracts) to ship coal at a fixed and known price during the period indicated:

	Nine Months Ending December 31, 2005				2006				2007
	Average Price Per Ton		Tons		Average Price Per Ton		Tons		Average Price Per Ton		Tons
Total Sales Commitments	$	41.87		6,665,600	$	40.21		4,694,000	$	38.37		1,630,000

 

Project Development

We undertake projects to add and replace production, improve productivity and efficiency, and add reserves. Currently, we have several projects underway, including the development of Mine 15 at our McCoy Elkhorn complex, and several projects under consideration, including certain projects described below.

Mine 15 Project

The Mine 15 project involves construction of a mine at our McCoy Elkhorn complex to access what we estimate to be approximately 14 million tons of controlled reserves in the Glamorgan, or Millard, seam. Included in the Mine 15 project are construction of a slope and shaft along with related surface facilities and an upgrade to the adjacent Bevins Branch preparation plant. During 2004, capital expenditures for the Mine 15 project were $3.7 million. We expect the total budget cost for this project to increase modestly from the original budget of $22 million due to

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higher costs of steel and cement. The excavation has progressed to the point that both the slope and the shaft have now reached the coal seam. The fabrication and installation of the remaining mine infrastructure is expected to be completed before December 31, 2005, and the mine is expected to have very limited production beginning in the fourth quarter of 2005, before ramping up to full annualized production levels of approximately 1.4 to 1.5 million tons by the end of 2006. Due to the flexibility of shipping locations in all of the Company’s non-synfuel coal supply agreements, all coal from Mine 15 is considered uncommitted and unpriced.

Test results for coal samples taken from Mine 15 indicate that the coal can be sold as a high quality utility steam coal with average heat content of 13,000 Btu and average sulfur content of less than 1%, during the initial years of mining. We may also use the coal to blend with higher sulfur coal at the McCoy Elkhorn complex. Depending on market conditions, and in certain limited circumstances, we may also sell the coal as a low quality metallurgical coal for blending purposes by other suppliers. We have not determined the percentage of coal that will be allocated to each end-market. We continue to negotiate with mineral owners to add additional contiguous reserves to the project.

Potential Surface Mining Projects

Our operations and engineering teams have identified 41 surface mining projects that merit further review. We currently control more than 75% of these reserves. Sixteen of these projects have current state mine permits, and the Army Corps of Engineers permitting process has already begun on these properties. Our management team expects six projects from this list to be presented for board consideration and potential near-term development.

Potential Preparation Plant Projects

Our operations and engineering teams have developed a list of projects intended to improve the yield of existing preparation plants. These projects are concentrated in the screening and separation areas of the plants. Our management team expects to present the project analysis for board consideration during the second quarter of 2005. If approved, and we proceed, these projects will likely be completed during the first quarter of 2006.

Market Risk

Our $75 million Term Credit Facility has a fixed interest rate and is not sensitive to changes in the general level of interest rates. Our Senior Secured Credit Facility has floating interest rates based on LIBOR or the Base Rate as defined in the credit agreement. We expect that our proposed new senior secured credit facility also will have floating interest rates.

As of March 31, 2005, we had $20 million outstanding under the term component of the Senior Secured Credit Facility. We do not expect to use interest rate swaps to manage this risk. A 100 basis point (1.0%) increase in the average interest rate for our floating rate borrowings would increase our annual interest expense by approximately $0.2 million.

We manage our commodity price risk through the use of long-term coal supply agreements, which we define as contracts with a term of one year or more, rather than through the use of derivative instruments. The percentage of our sales pursuant to long-term contracts was approximately 73% for the year ended December 31, 2004.

All of our transactions are denominated in U.S. dollars, and, as a result, we do not have material exposure to currency exchange-rate risks.

We are not engaged in any foreign currency exchange rate or commodity price-hedging transactions and we have no trading market risk.

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THE COAL INDUSTRY

Coal is a major contributor to the world’s energy supply. According to BP Statistical Review, in 2003, coal represented approximately 26% of the world’s primary energy consumption and was also the fastest growing energy source in the world. The ratio of the worldwide coal reserves to production is approximately five times that of oil, and more than three times that for natural gas, according to BP Statistical Review. The primary use for coal is to fuel electric power generation. In 2004, coal generated 50% of the electricity produced in the United States, according to the EIA.

The United States is the second largest coal producer in the world, exceeded only by China, according to BP Statistical Review. Other leading coal producers include Australia, India, South Africa and Russia. According to BP Statistical Review, the United States is the largest holder of coal reserves in the world, with over 250 years of supply at current production rates.

U.S. Coal Production Regions

According to the EIA, U.S. coal production has increased by 82% during the last 30 years. In 2004, total U.S. coal production, according to the EIA, was 1.11 billion short tons. The Powder River basin accounted for 38% of the total volume of U.S. coal production in 2004, with Central Appalachia accounting for 21%, the Midwest accounting for 13%, the West (other than the Powder River basin) accounting for 14%, Northern Appalachia accounting for 12% and Southern Appalachia accounting for 2%, according to Platts. All of our coal production comes from the Central Appalachian region, and all of Triad’s coal production comes from the Midwest region.

According to Platts, Central Appalachia, including eastern Kentucky, Virginia and southern West Virginia, is the second largest coal producing region in the United States (21% of 2004 production). Coal from this region generally has a high heat content of between 12,000 and 14,000 Btus per pound and a low sulfur content ranging from 0.7% to 1.5%. From 2000 to 2004, according to Platts, the Central Appalachian region experienced a decline in production from 263 million tons to 229 million tons, or a 13% decline, primarily as a result of the depletion of economically attractive reserves, permitting issues and increasing costs of production, which was partially offset by production increases in Southern West Virginia due to the expansion of more economically attractive surface mines. Platts estimates that Central Appalachian operators marketed approximately 80% of their 2004 coal sales directly to electric generators, principally in the southeastern U.S., with the remainder of their sales going to synfuel plants, industrial customers and steel producers in the U.S. and internationally. Central Appalachia is the primary source of U.S. coal exports.

The Midwest region consists of coal reserves in the Illinois basin (Western Kentucky, Illinois, and Indiana), the Gulf Coast (Texas, Louisiana and Mississippi), and the Western Interior (Oklahoma and Missouri). It comprises 13% of the coal production in the United States, making it the third largest U.S. region. Within the Midwest, the Illinois basin has large reserves of bituminous coal, which generally have sulfur content higher than that found in Central Appalachia. According to the EIA, production has declined from 365 million short tons in 1990 to 139 million short tons in 2004, a decrease of 63%, primarily as a result of sulfur emission restrictions implemented as a result of the Clean Air Act. Based on information from Platts, we believe utilities in the Illinois basin region and surrounding areas have made investments of approximately $13.2 billion in scrubbers since 2000. According to the EIA, by 2025, power generators are projected to add between 85 gigawatts and 99 gigawatts of SO2 scrubber capacity. With approximately 90 gigawatts of SO2 scrubbers on existing plants as of 2001, approximately two-thirds of all coal capacity will have SO2 scrubbers by 2025. These investments are expected to drive a significant increase in demand for the region’s coal reserves.

Demand for U.S. Coal Production

Coal produced in the United States is primarily consumed domestically by utilities to generate electricity, by steel companies to produce coke for use in blast furnaces, and by a variety of industrial users to heat and power foundries, cement plants, paper mills, chemical plants and other manufacturing and processing facilities. According to the EIA, 98% of coal consumed in the United States in 2004 was from domestic production sources. Coal

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produced in the United States is also exported, primarily from east coast terminals. The breakdown of 2004 U.S. coal consumption by end user, as estimated by the EIA, is as follows:

End Use	Tons		% of Total
	(In millions)
Electricity generation		1,015.1		91.92	%
Industrial		84.9		7.69	%
Commercial		3.8		0.34	%
Residential		0.5		0.05	%
Total		1,104.3		100	%

 

As reflected in the above table, the dominant use for coal in the United States is for electricity generation. Coal used as fuel to generate electricity and for use by industrial consumers is commonly referred to as “steam coal,” and it accounted for approximately 90% of our coal sales revenue in 2004. Coal has long been favored as an electricity generating fuel by regulated utilities because of its low cost compared to other fuels. The largest cost component in electricity generation is fuel. This fuel cost is typically lower for coal than competing hydrocarbon-based fuels such as oil and natural gas, on a Btu-comparable basis. Platts has recently estimated the average total production costs of electricity, using coal and competing generation alternatives in the first nine months of 2004 as follows:

Electrical Generation Type	Cents per Kilowatt Hour
Natural Gas		6.161
Oil		6.217
Coal		1.898
Nuclear		1.703
Hydroelectric		0.548

 

Platts estimates that, excluding hydroelectric plants, 17 of the 25 lowest operating cost, primary fuel-powered utility power plants in the United States during 2004 were primarily fueled by coal. Factors other than fuel cost that influence each utility’s choice of the type of electricity generation include, among others, facility construction cost, access to fuel transportation infrastructure and environmental restrictions. The breakdown of U.S. electricity generation by fuel source in 2004, according to EIA, is as follows:

Electricity Generation Source	% of Total Electricity Generation
Coal		50.1	%
Nuclear		20.0	%
Natural Gas		17.7	%
Hydroelectric		6.6	%
Oil and Other		5.6	%
Total		100	%

 

The EIA projects that generators of electricity will increase their demand for coal as demand for electricity increases. Because coal-fired generation is used in most cases to meet “base load” requirements, which are the minimum amounts of electric power delivered or required over a given period of time at a steady rate, coal consumption has generally grown at the pace of electricity demand growth. Demand for electricity has historically grown in proportion to U.S. economic growth as measured by Gross Domestic Product. Based on estimates compiled by the EIA as of February 2005, electricity consumption is expected to grow 1.4% per year through 2025.

In 2004, approximately 10% of our coal sales revenue was stoker coal. Stoker coal is typically sold to industrial users, who typically purchase high Btu products with the same type of quality focus as utility coal buyers. The primary goal is to maximize heat content, with other specifications like ash content, sulfur content, and size varying

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considerably among different customers. Because most industrial coal consumers use considerably less tonnage than electric generating stations, they typically prefer to purchase coal that is screened and sized to specifications that streamline coal handling processes. Due to the more stringent size and quality specifications, industrial customers often pay a premium above utility coal pricing. According to the EIA, in 2004, industrial users consumed 85 million tons of coal.

Coal produced in the United States that is shipped for North American consumption is typically sold at the mine loading facility, with transportation costs being borne by the purchaser. Offshore export shipments are normally sold at the ship-loading terminal, with the producer paying for the transportation costs to the port and the purchaser paying the ocean freight.

While delivery to coal consumers often involves more than one mode of transportation, according to the EIA, approximately two-thirds of U.S. coal production is shipped via railroads. In addition, coal is also shipped via trucks, barges, overland conveyors and ocean vessels loaded at export terminals.

Industry Trends

In recent years, the U.S. coal industry has experienced several significant trends, including:

Growth in Coal Consumption.    According to the EIA, from 1990 to 2004 coal consumption in the United States increased from 904 million tons to 1,104 million tons, or 22%. The largest driver of increased coal consumption during this period was increased demand for electricity, as electricity production by domestic electric power producers increased 30% and coal consumption by electric power producers also increased 30%. Based on information from Platts, as coal remains one of the lowest cost fuel sources for domestic electric power producers, we believe coal consumption should continue to expand as demand for electricity continues to increase.

Increased Utilization of Excess Capacity at Existing Coal-Fired Power Plants.    We believe that existing coal-fired plants will supply much of the near-term projected increase in the demand for electricity because they possess excess capacity that can be utilized at low incremental costs. According to the EIA, in 2003, the estimated average utilization of existing coal-fired power plants was 72%, significantly below the 83% utilization rate that the EIA estimates coal-fired plants will operate at by 2025. If U.S. coal-fueled plants operate at utilization rates of 83%, we believe, based on information from Platts, they would consume approximately 165 million additional tons of coal per year, which represents an increase of approximately 15% over current coal consumption. In comparison, in 2004, the average utilization of existing nuclear-fired power plants was estimated by EIA to be 90.5%.

Construction of New Coal-Fired Power Plants.    The National Energy Technology Laboratory (the “NETL”), an arm of the U.S. Department of Energy, projects that 87 gigawatts of new coal-fired electric generation capacity will be constructed by 2025. The NETL has identified 114 coal-fired plants, representing 70 gigawatts of electric generation capacity, that have been proposed and are currently in various stages of development. The DOE projects that more than half of these proposed coal-fired plants will be completed and begin consuming coal to produce electricity by the end of 2010.

Industry Consolidation.    The U.S. coal industry has recently experienced significant consolidation. In 2003, the five largest coal producers controlled over 53% of coal produced in the United States, compared to just 39% in 1997 and 26% in 1991, according to the National Mining Association. Weaker coal prices in the late 1990s forced many smaller operators to sell or shut down their operations. In addition, a number of large international oil and gas companies decided to exit the domestic coal industry. Despite increased consolidation, the industry still remains relatively fragmented, with more than 600 coal producers in the United States in 2003, according to Platts.

Increasingly Stringent Air Quality Laws.    The coal industry has witnessed a shift in demand to low sulfur coal production driven by regulatory restrictions on sulfur dioxide emissions from coal-fired power plants. In 1995, Phase I of the Clean Air Act’s Acid Rain regulations required high sulfur coal plants to reduce their emissions of sulfur dioxide to 2.5 pounds or less per million Btu, and in 2000, Phase II tightened these sulfur dioxide restrictions further to 1.2 pounds of sulfur dioxide per million Btu. Sulfur dioxide and other emissions may be restricted even

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further by some currently proposed laws and regulations. Currently, electric power generators operating coal-fired plants can comply with these requirements by:

• burning lower sulfur coal, either exclusively or mixed with higher sulfur coal;

• installing pollution control devices, such as scrubbers, that reduce the emissions from high sulfur coal;

• reducing electricity generating levels; or

• purchasing or trading emission credits to allow them to comply with the sulfur dioxide emission compliance requirements.

Additional current and proposed air emission requirements are discussed in “Government Regulation.”

Recent Coal Market Conditions

According to traded coal indices and reference prices, U.S. and international coal demands are currently at historically high levels, and coal pricing has increased year-over-year in Central Appalachia. We believe that the current strong fundamentals in the U.S. coal industry result primarily from:

• stronger industrial demand following a recovery in the U.S. manufacturing sector, evidenced by the most recent estimate of 3.9% real GDP growth in the fourth quarter of 2004 (from the fourth quarter of 2003), as reported by the Bureau of Economic Analysis;

• relatively low customer stockpiles, estimated by the EIA to be approximately 147 million tons at the end of 2004, down 11% from the prior year;

• declining coal production in Central Appalachia, including a decline of 13% in Central Appalachian coal production volume in 2004 as compared to 2000, according to Platts;

• capacity constraints of U.S. nuclear-powered electricity generators, which operated at an average utilization rate of 88.4% in 2003, up from 70.5% in 1993, as estimated by the EIA;

• high current and forward prices for natural gas and oil, important fuels for electricity generation, with spot prices as of April 12, 2005 for natural gas and heating oil at $7.34 per million Btu (Henry Hub) and $51.86 per barrel (WTI crude), respectively, as reported by Bloomberg L.P.; and

• increased international demand for U.S. coal for steelmaking, driven by global economic growth, high ocean freight rates and the weak U.S. dollar.

Steam Coal Pricing.    U.S. spot steam coal prices have experienced significant volatility over the past few years. Starting in late 2000 and continuing through mid-2001, U.S. spot steam coal prices began to rise as a result of reduced supply, higher demand from utility and industrial consumers, and rising natural gas and oil prices. Beginning in the middle of 2001, U.S. spot steam coal prices declined due to the weakening domestic economy, higher utility consumer inventories and increases in supply as the coal production market reacted to the stronger prices during the late 2000/early 2001 period. Spot prices for U.S. steam coal remained relatively low through the end of 2001 and during all of 2002.

U.S. spot steam coal prices have steadily increased since mid-2003, particularly for coal sourced in the eastern United States. Between January 1, 2004 and April 12, 2005, coal prices have risen 62% in Central Appalachia and 42% in the Illinois basin, according to Bloomberg.

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The following chart sets forth historical steam coal prices (in dollars/ton) in various U.S. markets for the period from January 1, 2001 to April 15, 2005.

    

 

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BUSINESS

General Business

We mine, process and sell bituminous, low sulfur, steam and industrial-grade coal through five operating subsidiaries (“mining complexes”) located throughout Eastern Kentucky. Our five mining complexes include 18 mines and seven preparation plants, five of which have integrated rail loadout facilities and two of which use a common loadout facility at a separate location. In 2004, our mines produced 8.5 million tons of coal, and we purchased another 330,000 tons for resale. Of the 8.5 million tons produced, approximately 96.5% was produced at underground mines, while the remaining 3.5% was produced at surface mines. Approximately 83.4% of our revenues were generated from coal sales to electric utility companies and 16.6% came from coal sales to industrial and other companies or from synfuel handling fees. In 2004, we generated revenues of $345.6 million and income before reorganization items and income taxes of $9.8 million.

The majority of our coal is sold to customers in the Southeast region of the United States. According to the U.S. Energy Information Administration, or EIA, the Southeast region accounts for 33% of coal-generated electricity production in the United States, more than any other U.S. region. We believe the long term outlook for coal demand in the Southeast is favorable, as coal-generated electricity production in that region is expected to grow at a rate of 1.8% per year. In addition, the Southeast region is projected by the EIA to account for 36% of the expansion of coal-generated electricity production in the United States between 2003 and 2025. We or our predecessors have been providing coal to coal-generated electricity producers in the Southeast for over 40 years. In 2004, Georgia Power and South Carolina Public Service Authority were our largest customers, representing approximately 30% and 20% of our revenues, respectively. No other customer accounted for more than 10% of our revenues.

We believe that coal-fired electric utilities value the high energy, low sulfur coal that comprises the majority of our reserves. Low sulfur coal is coal which has a sulfur content of 1.5% or less. As of March 31, 2004, based upon our most recent independent reserve report, we estimate that we controlled approximately 207 million tons of proven and probable coal reserves. As of March 31, 2005, we believe that we controlled approximately 222 million tons of proven and probable coal reserves. We believe these reserves have an average heat content of 13,300 Btu per pound and an average sulfur content of 1.3%. At 2004 production levels, we believe these reserves would support in excess of 25 years of production.

In March 2005, we signed a definitive agreement to acquire Triad Mining, Inc., for $75.0 million, consisting of $64.0 million in cash and $11.0 million of our common stock. Triad operates six surface mines and one underground mine in Southern Indiana, and in 2004 produced approximately 3.4 million tons of coal. Of the 3.4 million tons produced, approximately 87% came from surface mines, while the remaining 13% came from underground mines. In 2004, Triad generated revenues of approximately $81.6 million. As of February 1, 2005, based upon an independent reserve report, we believe that Triad controlled approximately 17.6 million tons of proven and probable coal reserves.

The coal that we sell is obtained from three sources: our Company-operated mines, mines that are operated by independent contract mine operators, and other third parties from whom we purchase coal for resale. Contract mining and coal purchased from other third parties provide flexibility to increase or decrease production based on market conditions. The table below reflects the amount and percentage of coal obtained from those sources in 2004:

	Tons (000)		Percentage of total coal obtained by the Company
Coal produced from Company-operated mines		7,987		90	%
Coal obtained from mines operated by independent contractors		534		6	%
Coal purchased from other third parties		330		4	%
		8,851		100	%

 

We also supply coal to a third party synfuel plant and receive fees for the handling, shipping and marketing of the synfuel product. Synfuel is a synthetic fuel product that is produced by chemically altering coal. In 2004, 2% of our total operating revenues came from synfuel handling, shipping and marketing.

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Our principal executive offices are located at 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219, and our telephone number is (804) 780-3000.

Mining Operations

All of our coal production is conducted through our operation of five mining complexes:

• Bell County Coal Corporation;

• Bledsoe Coal Corporation;

• Blue Diamond Coal Corporation;

• Leeco, Inc.; and

• McCoy Elkhorn Coal Corporation.

We obtained rights to these mining complexes as follows: McCoy Elkhorn and Bell County were the original operating companies that made up James River Coal Company when we were formed through the purchase of General Energy Corp. In 1992, we acquired the operations of Johns Creek Coal Company and the Bevins Branch Preparation Plant, both of which operations are now included within the McCoy Elkhorn complex. The Leeco and Bledsoe operating companies were both acquired in our acquisition of Transco Coal Company in 1995. The Blue Diamond operating company was purchased in 1998. In 1999, we acquired Shamrock Coal Company, which added mines, reserves, a preparation plant and the Clover loadout facility to the Bledsoe complex.

We generally do not own the land on which we conduct our mining operations; instead, approximately 97% of our coal reserves are controlled pursuant to leases from third party landowners. These leases typically convey mining rights to the coal producer in exchange for a per ton or a percentage of gross sales price royalty payment to the lessor. The average royalties for coal reserves from our producing properties was approximately 7.9% of produced coal revenue for the year ended December 31, 2004.

All of our operations are located on or near public highways and receive electrical power from commercially available sources. Existing facilities and equipment are maintained in good working condition and are continuously updated through capital expenditure investments.

The following summarizes information concerning each of our five mining complexes:

Bell County.    The Bell County complex is located in Bell County in eastern Kentucky, and consists of two Company-operated underground mines and one contract surface mine. We use room and pillar mining to mine the Buckeye Springs seam of coal, and our contract mine operator uses the contour and auger method to mine multiple seams, including the Red Springs, the Hignite and the Stray seams. Coal is processed at our preparation plant and loaded into railcars via an integrated four-hour unit train loadout that is serviced by both the CSX and Norfolk Southern railroads. Shipments from this complex totaled approximately 0.8 million tons in 2004 and approximately 1.3 million tons in 2003. Coal shipped from this complex in 2004 had average sulfur content of 1.37%, an average ash content of 8.82% and an average Btu content of 12,750, all on an as-received basis. As of March 31, 2005, we employed 97 mining and support personnel at this complex. As of March 31, 2005, based on the report prepared by MM&A and adjustments for subsequent production, acquisitions, divestures and exploration activities, we estimate this complex contains approximately 13.2 million tons of proven and probable reserves, which we believe will support approximately 16 years of operations at 2004 levels of production.

Bledsoe.    The Bledsoe complex is located in Leslie, Harlan and Letcher counties in eastern Kentucky, and consists of three Company-operated underground mines. We use room and pillar mining to mine the Hazard #4 seam of coal at this complex. Coal is processed at one of two preparation plants and loaded into railcars at a separate location via a four-hour unit train loadout on the CSX railroad. Shipments from this complex totaled approximately 2.4 million tons in 2004 and approximately 2.9 million tons in 2003. Coal shipped from this complex in 2004 had average sulfur content of 1.20%, an average ash content of 8.73% and an average Btu content of 12,704, all on an as-received basis. As of March 31, 2005, we employed 325 mining and support personnel at this complex. As of March 31, 2005, based on the report prepared by MM&A and adjustments for subsequent production,

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acquisitions, divestures and exploration activities, we estimate this complex contains approximately 57.2 million tons of proven and probable reserves, which we believe will support approximately 24 years of operations at 2004 levels of production.

Blue Diamond.    The Blue Diamond complex is located in Leslie, Perry, Letcher and Harlan counties in eastern Kentucky, and consists of four Company-operated mines and one contract mine, all of which are underground mines. We use room and pillar mining to mine the Hazard #4 and Alma seams of coal and our contract mine operator uses the same method to mine the Leatherwood seam. Coal is processed at our preparation plant, and loaded into railcars via an integrated four-hour unit train loadout on the CSX railroad. Shipments from this complex totaled approximately 1.8 million tons in 2004 and approximately 1.4 million tons in 2003. Coal shipped from this complex in 2004 had average sulfur content of 0.84%, an average ash content of 9.28% and an average Btu content of 12,652, all on an as-received basis. As of March 31, 2005, we employed 222 mining and support personnel at this complex. As of March 31, 2005, based on the report prepared by MM&A and adjustments for subsequent production, acquisitions, divestures and exploration activities, we estimate this complex contains approximately 64.8 million tons of proven and probable reserves, which we believe will support in excess of 25 years of operations at 2004 levels of production.

Leeco.    The Leeco complex is located in Knott and Perry counties in eastern Kentucky, and consists of one Company-operated underground mine and one contract surface mine. Our Company mine uses room and pillar mining to mine the Amburgy seam of coal and the contract mine operator uses the contour and auger method to mine the Hazard #8 seam. Coal is processed at our preparation plant and loaded into railcars via an integrated four-hour unit train loadout on the CSX railroad. Shipments from this complex totaled approximately 1.3 million tons in 2004 and approximately 1.4 million tons in 2003. Coal shipped from this complex in 2004 had average sulfur content of 0.79%, an average ash content of 8.66% and an average Btu content of 12,883, all on an as-received basis. As of March 31, 2005, we employed 146 mining and support personnel at this complex. As of March 31, 2005, based on the report prepared by MM&A and adjustments for subsequent production, acquisitions, divestures and exploration activities, we estimate this complex contains approximately 50.4 million tons of proven and probable reserves, which we believe will support in excess of 25 years of operations at 2004 levels of production.

McCoy Elkhorn.    The McCoy Elkhorn complex is located in Pike and Floyd counties in eastern Kentucky, and consists of five Company-operated mines. All of the mines at this complex are underground mines. We use room and pillar mining to mine the Williamson, Elkhorn #2, Elkhorn #3, and Pond Creek seams of coal. Coal is processed at one of two preparation plants and loaded into railcars via integrated four-hour unit train loadouts on the CSX railroad. Shipments from this complex totaled approximately 2.6 million tons in 2004 and approximately 3.2 million tons in 2003. Coal shipped from this complex in 2004 had average sulfur content of 1.48%, an average ash content of 8.49% and an average Btu content of 12,756, all on an as-received basis. As of March 31, 2005, we employed 307 mining and support personnel at this complex. As of March 31, 2005, based on the report prepared by MM&A and adjustments for subsequent production, acquisitions, divestures and exploration activities, we estimate this complex contains approximately 36.1 million tons of proven and probable reserves, which we believe will support approximately 14 years of operations at 2004 levels of production.

Contract mining represented approximately 6% of our coal production in the year ended December 31, 2004. Each mining complex monitors its contract mining operations and provides geological and engineering assistance to the contract mine operators. The contract mine operators generally provide their own equipment and operate the mines using their employees. They are generally responsible for all needed supplies, equipment repairs and maintenance. We generally own the infrastructure associated with the mine, including beltlines, ventilation systems and electrical systems. If the contract mine operator provides this infrastructure, the contract governing the relationship typically mandates a process for our valuation and purchase of those items if the contractor terminates the contract. Independent contract mine operators are paid a fixed rate for each ton of saleable product. We are primarily responsible for the reclamation activities involved with all contractor-operated mines. Contractors that operate surface mines, however, typically are contractually obligated to perform, on our behalf, the reclamation activities associated with the mines they operate. To enforce our contractual rights, we typically withhold a portion of the per ton amount otherwise due to the surface mine contractor until certain thresholds in the reclamation process, typically based on thresholds set by regulatory authorities, are met by the contractor. Contractors that operate

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underground mines typically have no obligation to perform reclamation activities on the mines they operate. Our relationships with contract mine operators typically can be cancelled by either party without penalty by giving between 30 and 60 days notice.

Reserves

Beginning in late 2003 and continuing into 2004, we increased our ongoing mineral development drilling and exploration program on our coal properties. The purpose of the drilling and exploration program is to assist us with planning our mining activities and to better assess our coal reserves. In April 2004, we asked Marshall Miller & Associates, Inc. (“MM&A”) to prepare a detailed study of our reserves as of March 31, 2004 based on all of our geologic information, including our updated drilling and mining data. The coal reserve study conducted by MM&A was planned and performed to obtain reasonable assurance of our subject demonstrated (proven plus probable) reserves. In connection with the study, MM&A prepared reserve maps and had certified professional geologists develop estimates based on data supplied by us and using standards accepted by government and industry. MM&A completed their report in June 2004.

After reviewing the maps and information we supplied, MM&A prepared an independent mapping and estimate of our demonstrated reserves using methodology outlined in U.S. Geological Survey Circular 891 and SEC Industry Guide 7. MM&A developed reserve estimation criteria to assure that the basic geologic characteristics of the reserves (e.g., minimum coal thickness and wash recovery, interval between deep mineable seams, mineable area tonnage for economic extraction, etc.) are in reasonable conformity with present and recent mine operation capabilities on our various properties.

As a result of this study, we reduced our reserve estimate from 285 million tons to 207 million tons as of March 31, 2004. MM&A has not conducted a coal reserve study on our March 31, 2005 reserve estimate. We expect to continue with our drilling program and to update our reserve study from time to time. Any future negative changes in our reserves could have a material adverse impact on our depreciation, depletion and amortization expense. A material adverse impact could also lead to a charge for impairment against the value of our coal property assets.

We estimate that, as of March 31, 2005, we controlled approximately 222 million tons of proven and probable coal reserves, with an estimated weighted average quality of approximately 6.3% ash, 1.3% sulfur and 13,300 British thermal units per pound (“Btu/lb.”), all on an as-received basis at 5.5% moisture. Reserves are defined by SEC Industry Guide 7 as that part of a mineral deposit which could be economically and legally extracted or produced at the time of the reserve determination. The vast majority of our coal reserves are concentrated in eastern Kentucky, with the remaining amount located in north central Tennessee.

The reserve estimates have been prepared using industry-standard methodology to provide reasonable assurance that the reserves are recoverable, considering technical, economic and legal limitations. Although MM&A has reviewed our reserves and found them to be reasonable (not withstanding unforeseen geological, market, labor or regulatory issues that may affect the operations), by assignment, MM&A has not performed an economic feasibility study for our reserves. In accordance with standard industry practice, we have performed our own economic feasibility analysis for our assigned reserves. It is not generally considered to be practical, however, nor is it standard industry practice, to perform a feasibility study for a company’s entire reserve portfolio. In addition, MM&A did not independently verify our control of our properties, and has relied solely on property information supplied by us. Reserve acreage, average seam thickness, average seam density and average mine and wash recovery percentages were verified by MM&A to prepare a reserve tonnage estimate for each reserve.

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The following table sets forth reserve information, as of March 31, 2004, at each of our mining complexes, based on the independent reserve study conducted by MM&A:

			Approximate Overall Reserve Quality (2)
Mining Complex	Proven & Probable Reserves (1) (millions of tons)		Ash Content (%)		Sulfur Content (%)		Heat Value (Btu/lb.)
Bell County		12.5		5.1		1.0		13,500
Bledsoe		59.1		7.8		1.2		13,000
Blue Diamond		66.2		4.7		1.1		13,700
Leeco		35.7		7.0		1.2		13,200
McCoy Elkhorn		33.8		5.7		1.6		13,300
Total/Average		207.3		6.3		1.3		13,300

 

(1) Proven reserves have the highest degree of geologic assurance and are reserves for which (a) quantity is computed from dimensions revealed in outcrops, trenches, workings, or drill holes; grade and/or quality are computed from the results of detailed sampling and (b) the sites for inspections, sampling and measurement are spaced so closely and the geologic character is so well defined that size, shape, depth and mineral content of reserves are well-established. Probable reserves have a moderate degree of geologic assurance and are reserves for which quantity and grade and/or quality are computed from information similar to that used for proven reserves, but the sites for inspection, sampling and measurement are farther apart or are otherwise less adequately spaced. The degree of assurance, although lower than that for proven reserves, is high enough to assume continuity between points of observation. This reserve information reflects recoverable tonnage on an as-received basis with 5.5% moisture.

(2) Ash and sulfur content is expressed as the percent by weight of those constituents in the coal sample compared to the total weight of the sample being tested. Heat value is expressed as Btu per pound in the coal based on laboratory testing of coal samples. The samples are typically obtained from exploratory core borings placed at strategic locations within the coal reserve area. Approximately 82% of the reserve tons have representative samples (degree of representation varies from area to area) and 18% of the reserve tons have no site-specific samples (and are therefore not included in the overall quality estimate). The samples are sent to accredited laboratories for testing under protocols established by the American Society of Testing and Materials (ASTM). The estimated overall quality values are derived by a multiple step process, including: a) for each mine or reserve area, an arithmetic average quality (dry basis) was prepared to represent the coal tons within the area, based on samples from the area; b) the overall quality of reserves for each mine complex was determined by performing a tonnage-weighted average of the average quality of all mine and reserve areas within the division; and c) the resulting dry basis overall quality was converted to wet product basis to reflect its anticipated moisture content at the time of sale. The actual quality of the shipped coal may vary from these estimates due to factors such as: a) the particle size of the coal fed to the plant; b) the specific gravity of the float media in use at the preparation plant; c) the type of plant circuit(s); d) the efficiency of the plant circuit(s); e) the moisture content of the final product; and f) customer requirements.

Estimates of Triad’s reserves were prepared using the same industry-standard methodology described above with respect to our reserves, and MM&A conducted a reserve study of Triad’s reserves, which was completed in March 2005. See “The Triad Acquisition.”

Mining Methods

In our 15 Company-operated mines, the three mines operated by independent contractors and the seven mines operating by Triad, three different mining methods are used. These methods are:

• Room and pillar underground mining;

• Contour and auger surface mining; and

• Area mining (also known as mountaintop removal).

These three methods are described in more detail below.

Room and Pillar.    We use the room and pillar mining method at all of our Company-operated mines. The four underground mines operated by contractors also use this method. In the underground room and pillar method of mining, continuous mining machines cut three to nine entries into the coal seam and connect them by driving crosscuts, leaving a series of rectangular pillars, or columns of coal, to help support the mine roof and control the flow of air. Generally, openings are driven 20 feet wide and the pillars are 40 to 100 feet wide. As mining advances, a grid-like pattern of entries and pillars is formed. When mining advances to the end of a panel, or section of the mine, retreat mining may begin. In retreat mining, as much coal as is feasible is mined from the pillars that were

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created in advancing the panel, allowing the roof to cave. When retreat mining is completed to the mouth of the panel, the mined panel is abandoned.

The coal face is cut with continuous mining machines and the coal is transported from the continuous mining machine to the mine conveyor belts using either a continuous haulage system or shuttle cars. The mine conveyor system consists of a series of conveyor belts, which transport the coal from the active face areas to the surface. Once on the surface, the coal is transported to the preparation plants where it is processed to remove any impurities. The coal is then transported to the clean coal stockpiles or silos from which it is loaded for shipment to our customers. Reserve recovery, a measure of the percentage of the total coal in place that is ultimately produced, using this method of mining typically ranges from less than 50% to more than 70%, depending on the shape of the reserve, the amount of low-cover areas, and the geological characteristics of the reserve body.

Contour and Auger.    Our contract surface mine operators use the contour and auger method as well as area mining or mountaintop removal where appropriate. Contour mining is used where removal of all the overburden overlying a coal seam is either uneconomical or impossible due to property control or other issues. With contour mining, a contour cut is taken along the outcrop of the seam and the coal is removed from the exposed pit. Augering can then take place where the seam is exposed in the highwall. An auger machine, which resembles a large, horizontal drill, drills into the seam with an auger of from less than 20″ in diameter to more than 40″ in diameter, depending on seam thickness and other conditions. The auger is drilled into the seam to an average depth of 150 feet. The coal is transported to the surface through the auger and loaded into trucks using a loader. The contour area is then reclaimed by returning overburden to the pit and restoring the mountainside to its approximate original contour. Reserve recovery using this method of mining is typically approximately 35%.

Area.    The area mining, or mountaintop removal, method is used where the seam is sufficiently close to the surface to allow removal of the overburden above an area of the coal seam. The overburden is removed and either placed in a valley fill or returned to the top of the mountain after the coal is extracted. With both area mining and mountaintop removal, coal can be removed across the entire breadth of the mountain. Reserve recovery is typically approximately 80%.

Mine Characteristics

Underground mines are characterized as either “drift” mines or “below drainage” mines. Drift mines are mines that are developed into the coal seam at a point where the seam intersects the surface. The area where the seam intersects the surface is commonly known as the “outcrop.” Multiple entries are developed into the coal seam and are used as airways for mine ventilation, passageways for miners and supplies, and entries for conveyor belts that transport coal from the active production areas of the mine to the surface.

In below drainage mines, the coal seam does not intersect the surface in the vicinity of the mining area. Therefore, the coal seam must be accessed through excavated passageways from the surface. These passageways typically consist of vertical shafts and angled slopes. The shafts are constructed with diameters ranging from 12 to 24 feet and are used as airways for mine ventilation and passageways for miners and supplies via elevators. The slopes, when used to house conveyor belts to transport the mined coal from the active production areas of the mine to the surface, are typically driven at an angle of less than 17 degrees from the horizontal. In addition, the slopes provide passageways for miners and supplies, and airways for mine ventilation.

All of our Company-operated mines are underground mines. Of these 15 Company-operated mines currently in operation, 13 are drift mines, and the remaining two are below drainage mines.

Processing and Transportation

Coal from each of our mine complexes is transported by conveyor belt or by truck to one of our seven preparation plants, all of which are in close proximity to our mining operations. These preparation plants remove impurities from the run-of-mine coal (the raw coal that comes directly from the mine) and offer the flexibility to blend various coals and coal qualities to meet specific customer needs. We regularly upgrade and maintain all of our preparation plants to achieve a high level of coal cleaning efficiency and maintain the necessary capacity.

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Substantially all of our coal is sold f.o.b. the railcar at the point of loading; transportation costs are normally borne by the purchaser. In addition to our well-positioned unit train loadout facilities on the CSX Corporation railroad, our Bell County mining complex has dual service provided by the CSX and Norfolk Southern Corporation railroads in Bell County, Kentucky.

Our mining complexes are supported by James River Coal Service Company, located in London, Kentucky, which provides engineering and permitting assistance, project management, land management and lease administration, coal quality control and quality reporting, accounting and purchasing support, and railroad transportation scheduling services.

Customers and Coal Contracts

As is customary in the coal industry, we regularly enter into long-term contracts (which we define as contracts with terms of more than one year) with many of our customers. These arrangements allow customers to secure a supply for their future needs and provide us with greater predictability of sales volume and sales prices. In 2004, we generated approximately 71% of our total revenues from seven long-term contracts to sell coal to electric utilities.

For the year ended December 31, 2004, Georgia Power (30%) and South Carolina Public Service Authority (20%) were our largest customers by revenues. No other customer accounted for more than 10% of revenues. Our Senior Secured Credit Facility contains a covenant that no single customer may represent more than 35% of our annual revenues.

The terms of our contracts result from a bidding and negotiation process with our customers. Consequently, the terms of these contracts often vary significantly in many respects. Our long-term supply contracts typically contain one or more of the following pricing mechanisms:

• Fixed price contracts;

• Annually negotiated prices that reflect market conditions at the time; or

• Base-price-plus-escalation methods that allow for periodic price adjustments based on fixed percentages or, in certain limited cases, pass-through of actual cost changes.

A limited number of our contracts have features of several contract types, such as provisions that allow for renegotiation of prices on a limited basis within a base-price-plus-escalation agreement. Such re-opener provisions allow both the customer and us an opportunity to adjust prices to a level close to then current market conditions. Each contract is negotiated separately, and the triggers for re-opener provisions differ from contract to contract. Some of our existing contracts with re-opener provisions adjust the contract price to market price at the time the re-opener provision is triggered. Re-opener provisions could result in early termination of a contract or in a reduction in the volume to be purchased if the parties were to fail to agree on price.

Our long-term supply contracts also typically contain force majeure provisions allowing for the suspension of performance by the customer or us for the duration of specified events beyond the control of the affected party, including labor disputes. Some contracts may terminate upon continuance of an event of force majeure for an extended period, which are generally three to six months. Contracts also typically specify minimum and maximum quality specifications regarding the coal to be delivered. Failure to meet these conditions could result in substantial price reductions or termination of the contract, at the election of the customer. Although the volume to be delivered under a long-term contract is stipulated, we, or the buyer, may vary the timing of delivery within specified limits.

The terms of our long-term coal supply contracts also vary significantly in other respects, including: coal quantity parameters, flexibility and adjustment mechanisms, permitted sources of supply, treatment of environmental constraints, options to extend, suspension, termination and assignment provisions, and provisions regarding the allocation between the parties of the cost of complying with future government regulations.

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Properties

As of December 31, 2004, we controlled approximately 212,200 acres of land, of which approximately 204,900 acres is leased and the remainder is owned. In a mining context, control of a property is typically divided into three categories:

(1) mineral rights, which allows the controlling party to remove the minerals on the property;

(2) surface rights, which allows the controlling party to use and disturb the surface of the property; and

(3) fee control, which includes both mineral and surface rights.

Our rights with respect to properties that we lease vary from lease to lease, but encompass mineral rights, surface rights, or both. Our rights with respect to our owned properties are categorized as follows: fee ownership (100 acres), mineral rights ownership (1,200 acres) and surface rights ownership (6,000 acres).

Our coal properties are located in the Big Sandy, Hazard and Upper Cumberland coal districts of the Central Appalachian coal basin in eastern Kentucky and north central Tennessee. These three coal districts are located in the Appalachian Plateau structural and physiographic province. We hold over 300 leases, the terms of which vary significantly, including in the following provisions:

• length of term;

• renewal requirements;

• minimum royalties;

• recoupment provisions;

• tonnage royalty rates;

• minimum tonnage royalty rates;

• wheelage rates;

• usage fees; and

• other factors.

Our leases typically provide for periodic royalty payments, subject to specified annual minimums. The annual minimums are typically based on the forecasted tonnage of coal to be produced on the leased property over the term of the lease. Payments made pursuant to these minimums for years in which periodic royalty payments do not meet the minimums are typically recoupable against future periodic production royalties paid within a fixed period of time. We typically are responsible for the payment of property taxes due on the properties we have under lease.

Our corporate headquarters are located in Richmond, Virginia and are occupied pursuant to a lease that expires in June 2008.

Competition

The U.S. coal industry is highly competitive, with numerous producers in all coal producing regions. We compete against various large producers and hundreds of small producers. According to the U.S. Department of Energy, the largest producer produced approximately 18.9% (based on tonnage produced) of the total United States production in 2003, the latest year for which government statistics are available. The U.S. Department of Energy also reported 1,316 active coal mines in the United States in 2003. Demand for our coal by our principal customers is affected by:

• the price of competing coal and alternative fuel supplies, including nuclear, natural gas, oil and renewable energy sources, such as hydroelectric power;

• coal quality;

• transportation costs from the mine to the customer; and

• the reliability of supply.

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Continued demand for our coal and the prices that we obtain are affected by demand for electricity, environmental and government regulation, technological developments and the availability and price of competing coal and alternative fuel supplies.

Legal Proceedings

We are parties to a number of legal proceedings incidental to our normal business activities, including a large number of workers’ compensation claims. While we cannot predict the outcome of these proceedings, in our opinion, any liability arising from these matters individually and in the aggregate should not have a material adverse effect on our consolidated financial position, cash flows or results of operations.

Employees

At March 31, 2005, we had 1,141 employees. None of our employees are currently represented by collective bargaining agreements. Relations with our employees are generally good.

Recent Reorganization

On May 6, 2004, we emerged from Chapter 11 bankruptcy proceedings under our Joint Plan of Reorganization confirmed by the U.S. Bankruptcy Court presiding over our Chapter 11 case (the “Plan of Reorganization”). On that date, we:

• exchanged approximately $266 million in debt under various existing credit facilities for (1) restructured term debt of approximately $75 million, which is secured by a second lien on substantially all of our assets, and (2) a total of 13,799,994 shares of our new common stock, par value $0.01 per share, issued on a pro rata basis to the holders of the existing debt;

• distributed interests in an unsecured creditor liquidating trust (which trust initially held life insurance policies with cash surrender values of approximately $3.1 million, the right to receive certain refunds and the right to pursue certain derivative claims) to our general unsecured creditors in exchange for their claims, which were estimated to be valued at approximately $44.9 million;

• entered into a new senior secured credit facility providing borrowings of up to $50 million, which is secured by a first lien on substantially all of our assets;

• satisfied and discharged all of our obligations under our $20 million debtor-in-possession credit facility;

• rejected (i.e., terminated) certain agreements that we had entered into before the bankruptcy that were found to be unduly burdensome to us, and discharged the claims of creditors related to those agreements;

• canceled our existing equity securities;

• acknowledged that all intercompany debt was deemed to be extinguished;

• acknowledged that pre- and post-petition (i) environmental and regulatory obligations; (ii) obligations with respect to workers’ compensation and black lung programs; and (iii) regulatory obligations related to our employees would be unaffected by the Plan of Reorganization and would survive effectuation of the Plan of Reorganization; and

• elected and installed a new Board of Directors.

Fresh Start Accounting

Upon emergence from bankruptcy, we adopted “fresh start” accounting as described in the American Institute of Certified Public Accountant’s Statement of Position 90-7, Financial Reporting by Entities in Reorganization Under the Bankruptcy Code (“SOP 90-7”). Entities that adopt fresh start accounting apply the following principles:

• The reorganization value of the entity should be allocated to the entity’s assets in conformity with SFAS No. 141 Business Combinations.

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• Each liability existing at the plan confirmation date, other than deferred taxes, should be stated at present values of amounts to be paid as determined at appropriate current interest rates.

• Deferred taxes should be reported in conformity with generally accepted accounting principles. Benefits realized from pre-reorganization net operating loss carryforwards should first reduce reorganization value in excess of amounts allocable to identifiable assets and other intangibles until exhausted and thereafter be reported as a direct addition to paid-in capital.

Fresh start accounting principles require that we determine the reorganization value of the reorganized Company. We developed an enterprise value of the reorganized Company with our financial advisor during the bankruptcy case. Together, we worked closely with our pre-petition secured lenders, the Official Committee of Unsecured Creditors and their respective financial advisors. This enterprise value was based on a calculation of the present value of the free cash flows under our financial projections. The valuation and the projections underlying the valuation were submitted to the bankruptcy court and to our secured and unsecured creditors for review and objection as part of our disclosure statement accompanying the Plan of Reorganization. The enterprise value of the reorganized Company as contained in our disclosure statement accompanying the Plan of Reorganization was determined to be between $145 million and $165 million. For purposes of applying fresh start accounting, we have used an enterprise value for the reorganized Company of $155 million.

The reorganization value was derived from the enterprise value for the reorganized Company as follows (amounts in thousands):

Estimated enterprise value of the reorganized company	$	155,000
Borrowings under credit agreement		(6,400	)
Capital leases assumed		(1,396	)
Cash balance excluded from enterprise value		1,301
Administrative claims payable excluded from enterprise value		(10,214	)
		138,291
Less: new secured debt issued to extinguish prepetition debt		75,000
Fair value of common shares issued to extinguish prepetition debt	$	63,291

 

In connection with the implementation of fresh start accounting, we recorded a gain of approximately $178 million from the extinguishment of our debt. Other adjustments were made to reflect the provisions of the Plan of Reorganization and to adjust the assets of the reorganized Company to their estimated fair value and liabilities to their estimated present value. The estimated fair value of our fixed assets was based on an appraisal performed for one of our lenders in connection with our reorganization. For financial reporting purposes, these transactions were reflected in our operating results before emergence.

The consummation of the Plan of Reorganization has been reflected as of April 30, 2004, which was the end of our most recent month preceding the effective date of the Plan of Reorganization of May 6, 2004. The results of operations for the period from April 30, 2004 through May 5, 2004 were not material.

Our consolidated financial statements after emergence are those of a new reporting entity (the “Successor Company”) and are not comparable to the financial statements of the pre-emergence company (the “Predecessor Company”). See note 3 to our December 31, 2004 consolidated financial statements for our unaudited condensed balance sheets presenting our historical consolidated balance sheet as of April 30, 2004 before the application of fresh start accounting (Predecessor Company) and after the application of fresh start accounting and other adjustments to reflect the provisions of the Plan of Reorganization (Successor Company). The unaudited condensed balance sheets of the Predecessor Company and the Successor Company as of April 30, 2004 should be read in conjunction with our consolidated financial statements and related notes.

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THE TRIAD ACQUISITION

General

On March 30, 2005, we entered into an agreement to acquire all of the outstanding capital stock of Triad Mining, Inc. The Triad acquisition will allow us to diversify our operations into the Illinois coal basin, a region that we believe has favorable supply and demand dynamics. It also will allow us to expand our surface mining operations, and to diversify our customer base and modes of transportation. In addition, although Triad’s current reserve base is limited, we believe that there is a substantial amount of additional exploitable reserves that are either adjacent to or near Triad’s current reserves, and we plan to increase Triad’s reserves by acquiring rights to additional reserves.

Triad’s Business

Summary Financial and Other Information

Triad, together with its wholly-owned subsidiary, Triad Underground Mining, LLC, owns and operates six surface mines and one underground mine in Southern Indiana. In 2004, Triad produced approximately 3.4 million tons of coal. As of February 1, 2005, based upon an independent reserve report, we believe that Triad controlled approximately 17.6 million tons of proven and probable coal reserves. We believe these reserves have an average heat content of 11,177 Btu per pound, an average sulfur content of 2.7%, and an average ash content of 8.8%. As of March 31, 2005, Triad had approximately 240 employees.

In the three months ended March 31, 2005, Triad generated revenues of approximately $23.4 million. Revenues for the three months ended March 31, 2005 reflect a reduction of approximately $500,000 from the results reflected in the preliminary prospectus. That reduction was associated with the purchase of a sulfur credit as a result of a contract adjustment attributable to coal delivered during this period with higher than expected sulfur content.

In 2004, Triad generated revenues of approximately $81.6 million and EBITDA of approximately $18.6 million. We define Triad’s EBITDA and reconcile it to Triad’s net income under “—Selected Historical Consolidated Financial Information of Triad Mining, Inc.”

In 2004, Triad’s cost of coal sold (excluding depreciation, depletion and amortization) was $17.48 per ton; depreciation, depletion and amortization was $5.5 million; and sales, general and administrative expenses were $3.7 million. Triad made $4.7 million in capital expenditures in 2004.

For the year ended December 31, 2004, Triad’s largest customers (measured by revenue) were Indianapolis Power and Light (49%), Vectren Fuels (20%), Hoosier Energy Rural Electric Cooperative (20%) and Alcoa Power Generating (11%).

As of December 31, 2004, Triad had the following contractual commitments to ship coal at a fixed and known price:

	2005					2006					2007
	Average Price Per Ton		Tons			Average Price Per Ton		Tons			Average Price Per Ton		Tons
Total Sales Commitments	$	23.77		3.4	million	$	23.51		3.1	million	$	24.77		1.3	million

 

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Mining Operations

The following chart provides information on each of Triad’s operating mines:

Name	Type of Mine	County (Indiana)	2004 Shipments (tons)		Employees (December 31, 2004)		Proven and Probable Reserves (February 1, 2005) (tons)	Projected Years of Operation*
Augusta	Surface	Pike		676,000		35	1.9 million		2.8
Freelandville Central	Surface	Knox		311,000		15	1.3 million		4.1
Freelandville	Surface	Knox		408,000		54	5.8 million		14.2
Freelandville East	Surface	Knox		462,000		16	870,000		1.9
Freelandville Underground	Underground	Knox		444,000		40	2.4 million		5.4
Patoka River	Surface	Pike		799,000		33	1.2 million		1.5
South Augusta	Surface	Pike		N/A**		N/A**	4.1 million		N/A**

 

* Based on 2004 levels of production.

** Mining operations at South Augusta mine began in January 2005.

Marshall Miller & Associates, Inc. (“MM&A”) prepared a detailed study of Triad’s reserves as of February 1, 2005 based on all of Triad’s geologic information, including their updated drilling and mining data. The Triad coal reserve study conducted by MM&A was planned and performed to obtain reasonable assurance of Triad’s subject demonstrated reserves. In connection with the study, MM&A prepared reserve maps and had certified professional geologists develop estimates based on data supplied by Triad and using standards accepted by government and industry. MM&A completed their report on Triad’s reserves in March 2005. For a full description of the industry-standard methodology used by MM&A in preparing the Triad reserve study, see “Business—Reserves.”

Triad currently has four operating preparation plants, and one rail load out facility. Triad transports approximately 70% of its coal via truck, and the remainder by rail.

Terms of Acquisition Agreement

The following description of the material provisions of the Triad purchase agreement is a summary and is subject to the provisions of that agreement. The Triad purchase agreement is filed as an exhibit to the registration statement of which this prospectus is a part.

Purchase Price

The consideration to be paid by us for the Triad stock consists of a combination of cash and shares of our common stock, as follows:

• $64.0 million in cash will be paid to Triad’s shareholders as of the closing date; and

• the remainder of the purchase price will be paid by issuing to Triad’s shareholders shares of our common stock having a market value equal to $11.0 million, based on the average closing price of our common stock on The Nasdaq Stock Market for the 15 consecutive trading days ending two trading days prior to the closing date.

The cash portion of the purchase price will be increased or decreased based on changes in Triad’s net working capital, less agreed upon distributions, between December 31, 2004 and the closing date.

See “Risk Factors—Allocation of the excess of the purchase price we expect to pay for Triad over the book value of Triad’s fixed assets may impact our future earnings” for a discussion of the allocation of the Triad purchase price.

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Conditions, Termination and Indemnification

The Triad acquisition is subject to various conditions, including, but not limited to, the following:

• our having obtained financing for the acquisition on terms and conditions approved by our Board of Directors;

• the material accuracy of the representations and warranties of each party to the purchase agreement as of the closing date;

• receipt of all consents and regulatory approvals required to consummate the acquisition; and

• receipt by each party of certain legal opinions and other documents.

The Triad acquisition will not close unless we and the sellers satisfy or waive all of the conditions. However, this offering and the concurrent notes offering are not conditioned on the closing of the Triad acquisition. We cannot assure you that we or the sellers will be able to satisfy the conditions required to close the acquisition. See “Risk Factors” for a discussion of certain risks related to our potential acquisition of Triad.

The stock purchase agreement may be terminated by us or by Triad if the transaction does not close on or before June 30, 2005 (which date may be extended in certain limited circumstances).

We intend to finance the cash portion of the consideration for the Triad acquisition with proceeds of this offering and the concurrent notes offering.

The sellers are generally obligated, on a joint and several basis, to indemnify us for damages resulting from any seller’s breach of its representation, warranty, covenant or other obligation under the purchase agreement, as well as for damages associated with certain other matters specified in the stock purchase agreement. With limited exceptions, the sellers will have no indemnification obligations until our damages have exceeded an aggregate of $2 million, and sellers’ total indemnification obligations will not exceed $20 million.

Consulting Agreements

In connection with the Triad acquisition, we will also enter into consulting agreements with two of Triad’s principals. Under those agreements, we would pay each of those individuals an aggregate performance bonus of up to $2.5 million, payable in shares of our common stock if, prior to the second anniversary of the closing date, we obtain the right to own, lease, or mine certain proven and probable reserves. Each bonus would be payable in increments of $50,000 for every 1.0 million tons of such secured reserves, up to the $2.5 million maximum amount. Any such bonus would be payable in shares of our common stock, based on the average closing price of our common stock on The Nasdaq Stock Market for the 15 consecutive trading days ending two trading days prior to the applicable payment date.

Registration Rights

In connection with the Triad acquisition, we will also enter into a registration rights agreement with the holders of Triad stock giving those holders the right to require us to register the shares of our common stock received by them in the acquisition (and pursuant to the consulting agreements). The holders will generally have the right to make one demand, but to the extent that the two Triad principals receive additional shares pursuant to their consulting agreements summarized above, those two individuals will have the right to make one additional demand. In addition, if we conduct a public offering (with certain limited exceptions), the Triad holders will have the right to register their shares in the same offering, subject to certain cutback rights.

Pursuant to the registration rights agreement, we will not be required to file a registration statement with the SEC covering the shares of our common stock to be issued to the holders of Triad stock until 180 days after the closing of the Triad acquisition. Such holders collectively will be prohibited from selling, within any 90-day period commencing on such 180^th day, more than 33.3% of the total number of shares issued to them. To the extent that

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the holders sell less than 33.3% in a given 90-day period, they would have the right to carry over and sell such additional amount in a subsequent period.

Selected Historical Consolidated Financial Information of Triad Mining, Inc.

The following table presents Triad’s selected consolidated financial and operating data as of and for each of the periods indicated. The selected condensed consolidated financial data for the three months ended March 31, 2005 are derived from Triad’s unaudited condensed consolidated financial statements, and in the opinion of Triad’s management include all adjustments, consisting only of normal recurring accruals, that are necessary for a fair presentation of Triad’s financial position and operating results for these periods. The selected consolidated financial and operating data are not necessarily indicative of the results that may be expected for the entire year. The selected consolidated financial data as of and for the year ended December 31, 2004 are derived from Triad’s consolidated financial statements. The Triad financial information for the period ended March 31, 2005 is derived from Triad’s unaudited condensed consolidated financial statements, and in the opinion of Triad’s management include all adjustments, consisting only of normal recurring accruals, that are necessary for a fair presentation of Triad’s financial position and operating results for that period. The selected condensed consolidated financial and operating data are not necessarily indicative of the results that may be expected for the entire year.

The selected consolidated financial and operating data should be read in conjunction with the consolidated financial statements and related notes of Triad included in this prospectus.

	Twelve Months Ended 12/31/04			Three Months Ended 3/31/05
	(amounts in thousands, except per ton amounts)
Consolidated Statement of Operations:
Revenues	$	81,603		23,396
Cost of coal sold		59,291		17,203
Depreciation, depletion and amortization		5,500		1,630
Gross profit		16,812		4,563
Selling, general and administrative expenses		3,736		886
Operating income		13,076		3,677
Interest expense		174		21
Interest income		(567	)	(149	)
Other, net		(57	)	71
Net income (a)		13,526		3,734
Consolidated Balance Sheet Data:
Working capital	$	27,551		30,768
Property, plant and equipment, net		26,368		25,207
Total assets		62,191		62,914
Long term debt, including current portion		1,712		885
Total shareholders’ equity		47,054		49,018
Consolidated Statement of Cash Flow Data:
Net cash provided by operating activities	$	20,413		3,055
Net cash used in investing activities		(6,965	)	(2,034	)
Net cash used in financing activities		(14,387	)	(2,478	)
Supplemental Operating Data:
Tons sold		3,391		900
Tons produced		3,384		905
Revenue per ton sold	$	24.06		26.00
Capital expenditures		4,705		1,756

 

(a)   Triad is an S-Corporation and therefore does not have income tax expense.

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Triad’s EBITDA, a measure used by management to measure operating performance, is defined as net income plus interest expense, interest income, and depreciation, depletion and amortization. We regularly evaluate our performance as compared to other companies in our industry that have different financing and capital structures and/or tax rates by using EBITDA, and have evaluated Triad on this basis as well. We believe that EBITDA allows for meaningful company-to-company performance comparisons by adjusting for the factors described above, which often vary from company to company. In addition, we use EBITDA in evaluating acquisition targets such as Triad.

EBITDA is not a recognized term under GAAP and is not an alternative to net income, operating income or any other performance measures derived in accordance with GAAP or an alternative to cash flow from operating activities as a measure of operating liquidity. Because not all companies use identical calculations, this presentation of EBITDA may not be comparable to other similarly titled measures of other companies. Additionally, EBITDA is not intended to be a measure of free cash flow for management’s discretionary use, as it does not reflect certain cash requirements such as tax payments, interest payments and other debt service requirements. The amounts presented for Triad’s EBITDA differ from the amounts calculated under the definition of EBITDA used in our debt covenants. The definition of EBITDA used in our debt covenants is further adjusted for certain cash and non-cash charges and is used to determine compliance with financial covenants and our ability to engage in certain activities such as incurring additional debt and making certain payments.

Triad’s EBITDA is calculated and reconciled to net income in the table below (in thousands):

	Twelve Months Ended 12/31/04			Three Months Ended 3/31/05
Net income	$	13,526		3,734
Interest expense		174		21
Interest income		(567	)	(149	)
Depreciation, depletion and amortization		5,500		1,630
EBITDA	$	18,633		5,236

 

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GOVERNMENT REGULATION

The coal mining industry is subject to extensive regulation by federal, state and local authorities on matters such as:

• employee health and safety;

• permitting and licensing requirements regarding environmental and safety matters;

• air quality standards;

• water quality standards;

• plant and wildlife and wetland protection;

• blasting operations;

• the management and disposal of hazardous and non-hazardous materials generated by mining operations;

• the storage of petroleum products and other hazardous substances;

• reclamation and restoration of properties after mining operations are completed;

• discharge of materials into the environment, including air emissions and wastewater discharge;

• surface subsidence from underground mining; and

• the effects of mining operations on groundwater quality and availability.

Complying with these requirements, including the terms of our permits, has had, and will continue to have, a significant effect on our costs of operations. We could incur substantial costs, including clean up costs, fines, civil or criminal sanctions and third party claims for personal injury or property damage as a result of violations of or liabilities under these laws and regulations.

In addition, the utility industry, which is the most significant end-user of coal, is subject to extensive regulation regarding the environmental impact of its power generation activities, which could affect demand for our coal. The possibility exists that new legislation or regulations may be adopted which would have a significant impact on our mining operations or our customers’ ability to use coal and may require us or our customers to change operations significantly or incur substantial costs.

Numerous governmental permits and approvals are required for mining operations. In connection with obtaining these permits and approvals, we are, or may be, required to prepare and present to federal, state or local authorities data pertaining to the effect or impact that any proposed exploration for or production of coal may have upon the environment, the public, historical artifacts and structures, and our employees’ health and safety. The requirements imposed by such authorities may be costly and time-consuming and may delay commencement or continuation of exploration or production operations. Future legislation and administrative regulations may emphasize the protection of the environment and health and safety and, as a consequence, our activities may be more closely regulated. Such legislation and regulations, as well as future interpretations of existing laws, may require substantial increases in our equipment and operating costs and delays, interruptions or a termination of operations, the extent of which cannot be predicted.

While it is not possible to quantify the costs of compliance with all applicable federal and state laws, those costs have been and are expected to continue to be significant. We estimate that we will make capital expenditures of approximately $150,000 per year for environmental control facilities in 2005 and 2006. These costs are in addition to reclamation and mine closing costs and the costs of treating mine water discharge, when necessary. Compliance with these laws has substantially increased the cost of coal mining, but is, in general, a cost common to all domestic coal producers.

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Mine Health and Safety Laws

Stringent health and safety standards were imposed by federal legislation when the Federal Coal Mine Safety and Health Act of 1969 was adopted. The Federal Mine Safety and Health Act of 1977, which significantly expanded the enforcement of safety and health standards of the Coal Mine Safety and Health Act of 1969, imposes safety and health standards on all mining operations. Regulations are comprehensive and affect numerous aspects of mining operations, including training of mine personnel, mining procedures, blasting, the equipment used in mining operations and other matters. The Federal Mine Safety and Health Administration monitors compliance with these federal laws and regulations and can impose penalties ranging from $60 to $60,000 per violation, as well as closure of the mine. In addition, as part of the Coal Mine Safety and Health Act of 1969 and the Federal Mine Safety and Health Act of 1977, the Black Lung Benefits Revenue Act of 1977 and the Black Lung Benefits Reform Act of 1977, as amended in 1981, requires payments of benefits to disabled coal miners with black lung disease and to certain survivors of miners who die from black lung disease.

In 2001, Kentucky made significant changes to its mining laws. A new independent agency, the Kentucky Mine Safety Review Commission, was created to assess penalties against anyone, including owners or part owners (defined as anyone owning one percent or more shares of publicly traded stock), whose intentional violations or order to violate mine safety laws place miners in imminent danger of serious injury or death. Mine safety training and compliance with state statutes and regulations related to coal mining is monitored by the Kentucky Office of Mine Safety and Licensing. The Commission can impose a penalty of up to $10,000 per violation, as well as suspension or revocation of the mine license.

It is our responsibility to our employees to provide a safe and healthy environment through training, communication, following and improving safety standards and investigating all accidents, incidents and losses to avoid reoccurrence. The combination of federal and state safety and health regulations in the coal mining industry is, perhaps, the most comprehensive system for protection of employee safety and health affecting any industry. Most aspects of mine operations are subject to extensive regulation. This regulation has a significant effect on our operating costs. However, our competitors are subject to the same level of regulation.

Black Lung Legislation

Under the federal Black Lung Benefits Act (as amended) (the “Black Lung Act”), each coal mine operator is required to make black lung benefits or contribution payments to:

• current and former coal miners totally disabled from black lung disease;

• certain survivors of a miner who dies from black lung disease or pneumoconiosis; and

• a trust fund for the payment of benefits and medical expenses to any claimant whose last mine employment was before January 1, 1970, or where a miner’s last coal employment was on or after January 1, 1970 and no responsible coal mine operator has been identified for claims, or where the responsible coal mine operator has defaulted on the payment of such benefits.

Federal black lung benefits rates are periodically adjusted according to the percentage increase of the federal pay rate.

In addition to the Black Lung Act, we also are liable under various state statutes for black lung claims. To a certain extent, our federal black lung liabilities are reduced by our state liabilities. Our total (federal and state) black lung benefit liabilities, including the current portions, totaled approximately $26.0 million at March 31, 2005. These obligations were unfunded at March 31, 2005.

The United States Department of Labor issued a final rule, effective January 19, 2001, amending the regulations implementing the Black Lung Act. The amendments give greater weight to the opinion of the claimant’s treating physician, expand the definition of black lung disease and limit the amount of medical evidence that can be submitted by claimants and respondents. The amendments also alter administrative procedures for the adjudication of claims, which, according to the Department of Labor, results in streamlined procedures that are less formal, less adversarial

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and easier for participants to understand. These and other changes to the black lung regulations could significantly increase our exposure to federal black lung benefits liabilities. Experience to date related to these changes is not sufficient to determine the impact of these changes. The National Mining Association challenged the amendments but the courts, to date, with minor exception, affirmed the rules. However, the decision left many contested issues open for interpretation. Consequently, we anticipate increased litigation until the various federal District Courts have had an opportunity to rule on these issues.

The Kentucky Supreme Court has taken discretionary review of a Kentucky Court of Appeals decision, Bartrum v. Hunter Excavating, which rendered unconstitutional a 2002 statute governing black lung claims. The Court of Appeals held that to the extent the statute limited evidence, it violated due process rights. The effect upon future black lung claims, if any, is dependent upon the Kentucky Supreme Court’s review.

In recent years, proposed legislation on black lung reform has been introduced in, but not enacted by, Congress and the Kentucky legislature. It is possible that legislation on black lung reform will be reintroduced for consideration by these legislative bodies. If any of the proposals that have been introduced is passed, the number of claimants who are awarded benefits could significantly increase. Any such changes in black lung legislation, if approved, or in state or federal court rulings, may adversely affect our business, financial condition and results of operations.

Workers’ Compensation

We are required to compensate employees for work-related injuries. Our accrued workers’ compensation liabilities, including the current portion, were $50.5 million at March 31, 2005. These obligations are unfunded. Our expense for workers’ compensation was $9.3 million in 2004, and $2.7 million in the three months ended March 31, 2005. Both the federal government and the states in which we operate consider changes in workers’ compensation laws from time to time. Such changes, if enacted, could adversely affect us.

Environmental Laws and Regulations

We are subject to various federal environmental and mining laws, including:

• the Surface Mining Control and Reclamation Act of 1977;

• the Clean Air Act;

• the Clean Water Act;

• the Toxic Substances Control Act;

• the Comprehensive Environmental Response, Compensation and Liability Act;

• the U.S. Army Corps of Engineers; and

• the Resource Conservation and Recovery Act.

We are also subject to state laws of similar scope in each state in which we operate.

These environmental laws require reporting, permitting and/or approval of many aspects of coal operations. Both federal and state inspectors regularly visit mines and other facilities to ensure compliance. We have ongoing compliance and permitting programs designed to ensure compliance with such environmental laws.

Given the retroactive nature of certain environmental laws, we have incurred and may in the future incur liabilities, including clean-up costs, in connection with properties and facilities currently or previously owned or operated as well as sites to which we or our subsidiaries sent waste materials.

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Surface Mining Control and Reclamation Act

The SMCRA, and its state counterparts, establish operational, reclamation and closure standards for all aspects of surface mining as well as many aspects of underground mining. The Act requires that comprehensive environmental protection and reclamation standards be met during the course of and following completion of mining activities. Permits for all mining operations must be obtained from the Federal Office of Surface Mining Reclamation and Enforcement or, where state regulatory agencies have adopted federally approved state programs under the Act, the appropriate state regulatory authority. Kentucky has achieved primary jurisdiction for enforcement of the Act through approved state programs.

The SMCRA and similar state statutes, among other things, require that mined property be restored in accordance with specified standards and approved reclamation plans. The mine operator must submit a bond or otherwise secure the performance of these reclamation obligations. The earliest a reclamation bond can be fully released is five years after reclamation has been achieved. All states impose on mine operators the responsibility for repairing or compensating for damage occurring on the surface as a result of mine subsidence, a possible consequence of underground mining. In addition, the Abandoned Mine Reclamation Fund, which is part of the SMCRA, imposes a tax on all current mining operations, the proceeds of which are used to restore unreclaimed mines closed before 1977. The maximum tax is $0.35 per ton on surface-mined coal and $0.15 per ton on underground-mined coal.

Effective January 1, 2003, we adopted Statement of Financial Accounting Standards No. 143 (“Statement No. 143”) to account for the costs related to the closure of mines and the reclamation of the land upon exhaustion of coal reserves. This statement requires the fair value of an asset retirement obligation be recognized in the period in which it is incurred if a reasonable estimate of fair value can be made. The present value of the estimated asset retirement costs is capitalized as part of the carrying amount of the long-lived asset. Asset retirement obligations primarily relate to the closure of mines and the reclamation of the land upon exhaustion of coal reserves. At December 31, 2004 and December 31, 2003, we had accrued $16.0 million and $14.7 million, respectively, related to estimated mine reclamation costs. The amounts recorded are dependent upon a number of variables, including the estimated future retirement costs, estimated proven reserves, assumptions involving profit margins, inflation rates, and the assumed credit-adjusted risk-free interest rate.

Our future operating results would be adversely affected if these accruals were determined to be insufficient. These obligations are unfunded. The amount that was expensed for the year ended December 31, 2004 was $1.2 million, while the related cash payment for such liability during the same period was $585,000.

We also lease some of our coal reserves to third-party operators. Under the SMCRA, responsibility for unabated violations, unpaid civil penalties and unpaid reclamation fees of independent contract mine operators can be imputed to other companies which are deemed, according to the regulations, to have “owned” or “controlled” the contract mine operator. Sanctions against the “owner” or “controller” are quite severe and can include being blocked, nationwide, from receiving new permits and revocation of any permits that have been issued since the time of the violations or, in the case of civil penalties and reclamation fees, since the time such amounts became due.

Clean Air Act

The federal Clean Air Act and similar state laws and regulations, which regulate emissions into the air, affect coal mining and processing operations primarily through permitting and/or emissions control requirements. In addition, the Environmental Protection Agency (the “EPA”) has issued certain, and is considering further, regulations relating to fugitive dust and particulate matter emissions that could restrict our ability to develop new mines or require us to modify our operations. In July 1997, the EPA adopted new, more stringent National Ambient Air Quality Standards for particulate matter, which may require some states to change existing implementation plans for particulate matter. Because coal mining operations and plants burning coal emit particulate matter, our mining operations and utility customers are likely to be directly affected when the revisions to the National Ambient Air Quality Standards are implemented by the states. Regulations under the Clean Air Act may restrict our ability to develop new mines or could require us to modify our existing operations, and may have a material adverse effect on our financial condition and results of operations.

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The Clean Air Act also indirectly affects coal mining operations by extensively regulating the air emissions of coal-fired electric power generating plants. Coal contains impurities, such as sulfur, mercury and other constituents, many of which are released into the air when coal is burned. New environmental regulations governing emissions from coal-fired electric generating plants could reduce demand for coal as a fuel source and affect the volume of our sales. For example, the federal Clean Air Act places limits on sulfur dioxide emissions from electric power plants. In order to meet the federal Clean Air Act limits for sulfur dioxide emissions from electric power plants, coal users need to install scrubbers, use sulfur dioxide emission allowances (some of which they may purchase), blend high sulfur coal with low sulfur coal or switch to low sulfur coal or other fuels. The cost of installing scrubbers is significant and emission allowances may become more expensive as their availability declines. Switching to other fuels may require expensive modification of existing plants.

On March 15, 2005, the U.S. Environmental Protection Agency adopted a new federal rule to cap and reduce mercury emissions from both new and existing coal-fired power plants. The reductions will be implemented in stages, primarily through a market-based cap-and-trade program. Nevertheless, the new regulations will likely require some power plants to install new equipment, at substantial cost, or discourage the use of certain coals containing higher levels of mercury.

Other new and proposed reductions in emissions of sulfur dioxides, nitrogen oxides, particulate matter or various greenhouse gases may require the installation of additional costly control technology or the implementation of other measures, including trading of emission allowances and switching to other fuels. For example, the EPA recently proposed separate regulations to reduce the interstate transport of fine particulate matter and ozone through reductions in sulfur dioxides and nitrogen oxides throughout the eastern United States. The EPA continues to require reduction of nitrogen oxide emissions in 22 eastern states and the District of Columbia and will require reduction of particulate matter emissions over the next several years for areas that do not meet air quality standards for fine particulates and for certain major sources contributing to those exceedances. In addition, the EPA has issued draft regulations, and Congress and several states are now considering legislation, to further control air emissions of multiple pollutants from electric generating facilities and other large emitters. These new and proposed reductions will make it more costly to operate coal-fired plants and could make coal a less attractive fuel alternative in the planning and building of utility power plants in the future. To the extent that any new and proposed requirements affect our customers, this could adversely affect our operations and results.

Along with these regulations addressing ambient air quality, a regional haze program initiated by the EPA to protect and to improve visibility at and around national parks, national wilderness areas and international parks may restrict the construction of new coal-fired power plants whose operation may impair visibility at and around federally protected areas and may require some existing coal-fired power plants to install additional control measures designed to limit haze-causing emissions. These requirements could limit the demand for coal in some locations.

The United States Department of Justice, on behalf of the EPA, has filed lawsuits against several investor-owned electric utilities and brought an administrative action against one government-owned utility for alleged violations of the Clean Air Act. Some of these lawsuits have settled, requiring the utilities to pay penalties, install pollution control equipment and/or undertake other emission reduction measures, and the remaining lawsuits or future lawsuits could require the utilities involved to take similar steps, which could adversely impact their demand for coal.

Any reduction in coal’s share of the capacity for power generation could have a material adverse effect on our business, financial condition and results of operations. The effect such regulations, or other requirements that may be imposed in the future, could have on the coal industry in general and on us in particular cannot be predicted with certainty.

We believe we have obtained all necessary permits under the Clean Air Act. We monitor permits required by operations regularly and take appropriate action to extend or obtain permits as needed. Our permitting costs with respect to the Clean Air Act are typically less than $25,000 per year.

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Framework Convention On Global Climate Change

The United States and more than 160 other nations are signatories to the 1992 United Nations Framework Convention on Climate Change, commonly known as the Kyoto Protocol, which is intended to reduce or offset emissions of greenhouse gases such as carbon dioxide. In December 1997, the signatories to the convention established a binding set of emissions targets for developed nations. Although the specific emissions targets vary from country to country, the United States would be required to reduce emissions to 94% of 1990 levels over a five-year budget period from 2008 through 2012. The U.S. Senate has not ratified the treaty commitments, and the Bush administration has officially opposed the Kyoto Protocol and has proposed an alternative to reduce the intensity of United States emissions of greenhouse gases. With Russia’s ratification of the Kyoto Protocol in 2004, it became binding on all ratifying countries. The implementation of the Kyoto Protocol in a number of countries, and other emissions limits, such as those adopted by the European Union, could affect demand for coal outside the United States. If the Kyoto Protocol or other comprehensive regulations focusing on greenhouse gas emissions are implemented by the United States, it could have the effect of restricting the use of coal. Other efforts to reduce emissions of greenhouse gases and federal initiatives to encourage the use of coal bed methane gas also may affect the use of coal as an energy source.

Clean Water Act

The federal Clean Water Act and corresponding state laws affect coal mining operations by imposing restrictions on discharges into regulated effluent waters. Permits requiring regular monitoring and compliance with effluent limitations and reporting requirements govern the discharge of pollutants into regulated waters. We believe we have obtained all permits required under the Clean Water Act and corresponding state laws and are in substantial compliance with such permits. However, new requirements under the Clean Water Act and corresponding state laws may cause us to incur significant additional costs that could adversely affect our operating results.

In addition, the U.S. Army Corps of Engineers imposes stream mitigation requirements on surface mining operations. These regulations require that footage of stream loss be replaced through various mitigation processes, if any ephemeral, intermittent, or perennial streams are in-filled due to mining operations. These regulations may also cause us to incur significant additional operating costs.

Comprehensive Environmental Response, Compensation and Liability Act

The Comprehensive Environmental Response, Compensation and Liability Act (commonly known as Superfund) and similar state laws create liabilities for the investigation and remediation of releases of hazardous substances into the environment and for damages to natural resources. Our current and former coal mining operations incur, and will continue to incur, expenditures associated with the investigation and remediation of facilities and environmental conditions, including underground storage tanks, solid and hazardous waste disposal and other matters under these environmental laws. We also must comply with reporting requirements under the Emergency Planning and Community Right-to-Know Act and the Toxic Substances Control Act.

The magnitude of the liability and the cost of complying with environmental laws with respect to particular sites cannot be predicted with certainty due to the lack of specific information available, the potential for new or changed laws and regulations and for the development of new remediation technologies and the uncertainty regarding the timing of remedial work. As a result, we may incur material liabilities or costs related to environmental matters in the future and such environmental liabilities or costs could adversely affect our results and financial condition. In addition, there can be no assurance that changes in laws or regulations would not result in additional costs and affect the manner in which we are required to conduct our operations.

Resource Conservation and Recovery Act

The RCRA and corresponding state laws and regulations affect coal mining operations by imposing requirements for the treatment, storage and disposal of hazardous wastes. Facilities at which hazardous wastes have been treated, stored or disposed of are subject to corrective action orders issued by the EPA and other potential obligations, which could adversely affect our results and financial condition.

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MANAGEMENT

Executive Officers and Directors

The following table sets forth the names, ages and positions of our executive officers, directors and certain significant employees as of the date of this prospectus:

Name	Age		Position
Peter T. Socha		46	Chairman, President and Chief Executive Officer
Coy K. Lane, Jr.		44	Senior Vice President and Chief Operating Officer
Samuel M. Hopkins, II		48	Vice President and Chief Accounting Officer
Richard L. Douthat		54	Vice President—Risk Management
James T. Ketron		54	Vice President, General Counsel and Secretary
Jeffrey A. Wilson		54	Vice President—Business Development
William R. Beasley		64	President of James River Coal Sales, Inc.
Joseph G. Evans		47	President of Leeco, Inc.; President of Blue Diamond Coal Company
D. Brian Patton, III		38	President of James River Coal Service Company
Charles G. Snavely		49	President of Bell County Coal Corporation; President of Bledsoe Coal Corporation
Randall K. Taylor		45	President of McCoy Elkhorn Coal Corporation
Alan F. Crown		57	Director
Leonard J. Kujawa		72	Director
Paul H. Vining		50	Director
James F. Wilson		47	Director

 

Biographical information relating to the executive officers, directors and significant employees is set forth below:

Peter T. Socha.  Mr. Socha is our President and Chief Executive Officer. He joined the Company in March 2003. In May 2004, he was named Chairman of our Board of Directors. From 1999 through June 2001, he served as a Senior Vice President of National Vision, Inc. (“NVI”), a retailer of optical products. NVI filed for protection under Chapter 11 of the United States Bankruptcy Code on April 5, 2000 and emerged from bankruptcy on May 31, 2001. Mr. Socha has served as a director of NVI since 1999 and as Chairman of the Board of Directors of NVI since May 2002. From June 2001 until March 2003, he was an independent consultant to distressed businesses. Mr. Socha has a B.S. in Mineral Engineering and a M.A. in Corporate Finance, both from the University of Alabama.

Coy K. Lane, Jr.  Mr. Lane is our Senior Vice President and Chief Operating Officer. He joined the Company in January 2005. Before joining the Company, Mr. Lane served as Senior Vice President of Operations for International Coal Group, Inc., following that company’s acquisition in September 2004 of the core assets of Horizon Natural Resources Company. Mr. Lane had served in various positions for Horizon and its predecessor companies since 1993. Mr. Lane holds a B.S. degree in Mining Engineering from Virginia Polytechnic Institute.

Samuel M. Hopkins, II.  Mr. Hopkins is our Vice President and Chief Accounting Officer. He joined the Company in September 2003. Mr. Hopkins served as Vice President, Treasurer and Controller from 1997 to 2001 and as Vice President and Controller from 2001 to June 2002 for Progress Fuels Corporation, a coal-mining, natural gas producer, rail reconditioning/manufacturing subsidiary of Progress Energy. He served as an independent financial consultant from July 2002 through September 2003. Mr. Hopkins holds a B.A. degree in Accounting from the University of Alabama and is a Certified Public Accountant.

Richard L. Douthat.  Mr. Douthat is Vice President—Risk Management of James River Coal Company. He joined the Company in May 2004. From 1974 to May 2004, he worked for Alliance Coal, LLC and its predecessor companies. From 1997 to 2004, Mr. Douthat served as Alliance’s General Manager—Disability Benefits. Mr. Douthat holds a B.S. in Business Administration from the University of Tennessee.

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James T. Ketron.  Mr. Ketron is Vice President, General Counsel and Secretary of James River Coal Company. He joined the Company in February 2005. Before joining the Company, Mr. Ketron served as Vice President and General Counsel for International Coal Group, Inc., following that company’s acquisition in September 2004 of the core assets of Horizon Natural Resources Company, where he had served as counsel since 2002. From 1998 to 2001, Mr. Ketron was in private legal practice as a solo practitioner. Mr. Ketron received his B.B.A. and J.D. degrees from the University of Kentucky.

Jeffrey A. Wilson.  Mr. Wilson joined the Company in 1999. From 1999 through April 2003, he served as Vice President—Administration. In April 2003, he was named President of James River Coal Service Company, our technical services subsidiary located in London, Kentucky, and in February 2005 he became our Vice President—Business Development. From 1981 to 1999, Mr. Wilson worked for Massey Energy. At the time that he left Massey in 1999, Mr. Wilson was Vice President. Mr. Wilson holds a B.S. in Mining Engineering from West Virginia University and a B.S. and M.B.A. from Marshall University.

William R. Beasley.  Mr. Beasley, President of James River Coal Sales, Inc., has been employed by James River Coal Sales or its predecessor since 1965. He began his career in coal sales with Randall Fuel Company, Inc. in 1965, and remained head of the sales organization of Interstate Coal Company during the period that it was owned by Transco Energy Company, the predecessor of James River. He was appointed President of James River Coal Sales, Inc. in June 2000. Mr. Beasley received his B.B.A. from Georgia State University in 1970.

Joseph G. Evans.  Mr. Evans joined the Company in October 1998 as President of Leeco, Inc. In March 2003, he was also named President of Blue Diamond Coal Company. Prior to joining the Company, Mr. Evans was employed by subsidiary companies of Massey Energy, a coal mining company with operations in Central Appalachia. Mr. Evans holds a B.S. and a M.S. in Mining Engineering from the University of Kentucky.

D. Brian Patton, III.  Mr. Patton joined the Company in February 2005. Prior to joining the Company, Mr. Patton was President of Operations for International Coal Group, Inc.’s Hazard operations, following that company’s acquisition in September 2004 of the core assets of Horizon Natural Resources Company, where he had served as chief engineer and general manager since July 2001. From 2000 until July 2001, he served as general manager of operations for Southern Site Prep, LLC. Mr. Patton holds a B.S. degree in Mining Engineering from the University of Kentucky.

Charles G. Snavely.  Mr. Snavely joined the Company in February 1995 as President of Bell County Coal Corporation. He became President of Bledsoe Coal Corporation in February 2003. Prior to joining the Company, Mr. Snavely held various positions with Martin County Coal Corporation, Sidney Coal Company and Rawl Sales & Processing. Most recently, he was President of Martin County Coal Corporation from February 1994 to February 1995. Mr. Snavely holds a B.S. degree in Mining Engineering from Virginia Polytechnic Institute.

Randall K. Taylor.  Mr. Taylor, President of McCoy Elkhorn Coal Corporation, has been employed by the Company or its predecessors since 1988, when he became Chief Engineer of Johns Creek Coal Company. In 1992, he became Chief Engineer of McCoy Elkhorn, and in 1997, he became its Vice President. He became President of McCoy Elkhorn in May 2001. Mr. Taylor holds a B.S. in Mining Engineering from the University of Kentucky.

Alan F. Crown.  Mr. Crown has been a Director since May 2004. He has served since January 2004 as President and Chief Operating Officer of Transload America, LLC, a waste haulage company. Mr. Crown was previously employed by CSX Transportation, a major eastern railroad, from 1966 until he retired in September 2003. From 1999–2003, he served as Vice President—Central Region (1999–2000), Senior Vice President—Transportation (2000–2002), and Executive Vice President (2002–2003). Mr. Crown attended the University of Baltimore.

Leonard J. Kujawa.  Mr. Kujawa has been a Director since May 2004. Mr. Kujawa previously served as a partner at Arthur Andersen & Co. from 1965 to 1995. When he retired in 1995, he had worldwide management responsibility for services to audit clients in the utility, energy and telecommunications fields. Over the past ten years, Mr. Kujawa has participated extensively in the restructuring and privatization of energy companies around the world. Mr. Kujawa was a Senior Advisor to Cambridge Energy Research Associates, leading their program for Chief Financial Officers and Chief Risk Officers. Mr. Kujawa currently serves as the utility industry expert for Accenture in Asia. He also serves on the Board of Directors of American Electric Power Company, Inc. (AEP)

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and Schweitzer-Mauduit International, Inc. Mr. Kujawa has a B.B.A. (with distinction) and a M.B.A. from the University of Michigan. Mr. Kujawa is a Certified Public Accountant, and has been designated by the Board of Directors as an audit committee financial expert.

Paul H. Vining.  Mr. Vining has been a Director since May 2004. Mr. Vining has delivered notice that he will be taking a senior management position with another publicly traded coal company, which will not allow him to continue to serve on our Board of Directors. He has therefore resigned his position, effective May 31, 2005. Mr. Vining currently serves as President of Ellett Valley CC, Inc., a coal industry consulting company he formed in December 2002. From 1995 to November 2002, Mr. Vining was employed by Peabody Energy, the largest coal mining company in the United States. His positions at Peabody included Executive Vice President of Sales and Trading (1999–2002) and President of Peabody CoalTrade (1996–1999). Mr. Vining has a B.S. in Chemistry from William & Mary, and a B.S. in Mineral Engineering and a M.S. in Extractive Metallurgy from Columbia University.

James F. Wilson.  Mr. Wilson has been a Director since May 2004. He has served since January 2001 as a General Partner of Carl Marks Management Company, L.P. (“CMMC”). CMMC manages funds that invest in distressed securities. From 1992 through December 2000, Mr. Wilson served as a Partner at Jacobson Partners, a firm specializing in private equity investing. Mr. Wilson has a B.A. in Economics from Dartmouth College and a M.B.A. from the Harvard Graduate School of Business Administration.

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EXECUTIVE COMPENSATION

Summary Compensation Table

The following table sets forth information for the fiscal years ended December 31, 2004, 2003 and 2002 concerning compensation paid by us and our subsidiaries to our Chief Executive Officer and to each of our other most highly compensated executive officers as of December 31, 2004 who earned in excess of $100,000 in salary and bonus during 2004 or any of the two previous fiscal years who are no longer executive officers (collectively, the “Named Executive Officers”). As of December 31, 2004, we did not have any executive officers other than those listed below.

							Long-Term Compensation Awards
	Annual Compensation (1)
Name and Principal Position	Year		Salary($)		Bonus($)		Restricted Stock Award(s) ($)(2)		Securities Underlying Options/ SARs		All Other Compensation($)
Peter T. Socha (3)		2004		409,798		601,000		1,377,000		150,000		—
President and Chief Executive Officer		2003		312,559		—		—		—		—
Samuel M. Hopkins, II (4)		2004		145,799		50,000		315,563		—		—
Vice President and Chief Accounting		2003		31,334		—		—		—		—
Officer
James B. Crawford (5)		2004		—		—		—		—		—
Former President and Chief Executive		2003		101,315		—		—		—		678,689
Officer		2002		499,733		—		—		—		—
William T. Sullivan (6)		2004		—		—		—		—		—
Former Vice President		2003		146,227		45,000		—		—		180,836	(6)
		2002		135,942		67,500						85,666	(7)

 

(1) Excludes perquisites and other personal benefits aggregating less than $50,000 or 10% of the Named Executive Officer’s annual salary and bonus.

(2) Based on our reorganization value of $4.59 per share, as determined in connection with our Plan of Reorganization. Mr. Socha’s shares of restricted stock vest as follows: 68.75% of the shares vest in five equal annual installments, beginning on May 25, 2005, the first anniversary of the date of the grant, and the remaining 31.25% of the shares will vest upon the achievement of designated corporate performance criteria. Mr. Hopkins’ shares vest in five equal annual installments, beginning on May 25, 2005.

(3) Mr. Socha joined the Company in March 2003.

(4) Mr. Hopkins joined the Company in September 2003.

(5) Mr. Crawford resigned from all positions with the Company in March 2003. All Other Compensation represents the 2003 payments to Mr. Crawford in connection with his Settlement Agreement described below.

(6) This amount represents payments related to Mr. Sullivan leaving the Company in 2003.

(7) This payment was a bonus payment used to partially repay loans to purchase common stock.

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Option Grants in Fiscal 2004

The following table sets forth option grants to Named Executive Officers during fiscal 2004.

	Individual Grants
										Potential Realizable Value at Assumed Annual Rates of Stock Price Appreciation for Option Term (1)
Name	Shares Underlying Options (#)		Percent of Total Options Granted to Employees in Fiscal Year (2)			Exercise Price ($/share)		Expiration Date		5% ($)		10% ($)
Peter T. Socha		150,000		55.6	%		10.80		5/7/2014		0		165,792
Samuel M. Hopkins, II		—		—			—		—		—		—
James B. Crawford		—		—			—		—		—		—
William T. Sullivan		—		—			—		—		—		—

 

(1) Based on our reorganization value of $4.59 per share as of May 7, 2004, as determined in connection with our Plan of Reorganization.

(2) Based on options for 270,000 shares granted to directors and employees in fiscal 2004.

Fiscal Year-End Option Values

No Company-granted options were exercised by any Named Executive Officers during fiscal 2004. The following table sets forth the year-end value of unexercised options held by the Named Executive Officers at December 31, 2004.

	Number of Securities Underlying Unexercised Options at December 31, 2004				Value of Unexercised In-the-Money Options at December 31, 2004(1)
Name	Exercisable		Unexercisable		Exercisable		Unexercisable
Peter T. Socha		—		150,000	$	—	$	4,762,500
Samuel M. Hopkins, II		—		—		—		—
James B. Crawford		—		—		—		—
William T. Sullivan		—		—		—		—

 

(1) Represents aggregate excess of market value of shares under option as of December 31, 2004, using the closing price of $42.55 at such date, over the exercise price of the options.

Retirement Benefits

Our pension plan is a “defined benefit” plan. The pension plan provides a monthly annuity to all regular, full-time employees when they retire. An employee must have at least five years of service to be vested in the pension plan. The normal retirement age under the plan is 65, but a full benefit is available to a retiree at age 62. A retiree can begin receiving a benefit as early as age 55 (provided they have at least ten years of service at the time); however, a 3% reduction factor applies for each year a retiree receives a benefit prior to age 62. Pension benefits are based on an employee’s final average monthly earnings, years of employment and retirement age. “Final average monthly earnings” for this purpose means basic monthly earnings, excluding overtime, bonuses and commissions, based on the employee’s average salary for the three highest consecutive years of service during the employee’s last ten years of employment. This amount is capped by the $205,000 annual limit imposed by the Internal Revenue Service for the 2004 calendar year. The Internal Revenue Code limits the amount of annual benefits which may be payable from the pension trust.

The following table illustrates the straight life annuity amounts payable under the pension plan to our employees retiring at age 65 in 2004. Amounts shown are not subject to reduction for Social Security benefits.

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Pension Plan Table

Final Average Salary	Years of Service
	15		20		25		30		35
$125,000	$	21,010	$	28,014	$	35,017	$	42,020	$	49,024
$150,000	$	25,698	$	34,263	$	42,829	$	51,395	$	59,961
$175,000	$	30,385	$	40,513	$	50,642	$	60,770	$	70,899
$200,000	$	35,073	$	46,764	$	58,454	$	70,145	$	81,836
$205,000*	$	36,010	$	48,013	$	60,017	$	72,020	$	84,024

 

* There is a $205,000 cap on compensation under our pension plan; accordingly, each remuneration level greater than $205,000 provides the same level of benefits.

The years of service credited for retirement benefits for the Named Executive Officers as of October 1, 2004, the last valuation date under the plan, are as follows:

Peter T. Socha	1.00
Samuel M. Hopkins, II	1.00
James B. Crawford*	21.67
William T. Sullivan*	16.00

 

* These officers left the Company in 2003, and therefore were not active participants in our pension plan as of October 1, 2004.

For additional information concerning our pension plan, see “Risk Factors—We may be unable to adequately provide funding for our pension plan obligations based on our current estimates of those obligations.”

Employment Contracts, Termination of Employment, Severance and Change-in-Control Arrangements

Settlement Agreement with Mr. Crawford.  On March 17, 2003, James B. Crawford resigned all positions with the Company. In connection with Mr. Crawford’s resignation, the Company, Mr. Crawford and J.R. Coal Associates (a Virginia partnership in which Mr. Crawford was a partner) entered into a Settlement Agreement, pursuant to which Mr. Crawford received, among other things:

(i) rights under two life insurance contracts, one of which represented the vested amount in Mr. Crawford’s account in our Supplemental Savings and Profit Sharing Plan of $535,021, and the other of which was a life insurance policy with a cash value of $143,668;

(ii) the right to receive $1,383,002 in cash from us upon our consummation of a Chapter 11 plan of reorganization or the sale of all or substantially all of our assets (which amount was paid on May 6, 2004); and

(iii) welfare benefit continuation until the payment under (ii) above was made.

In the event Mr. Crawford is engaged by us or any purchaser of us, or any successor to either, as Chairman, Chief Executive Officer, Chief Operations Officer or any similar position within the 12 months from the payment under (ii) above, Mr. Crawford is obligated to repay the amount received under (ii) above. Additionally, pursuant to the settlement agreement:

(iv) Mr. Crawford sold all of his equity interests in the Company to J.R. Coal Associates in exchange for the transfer by J.R. Coal Associates to the Company of certain life insurance policies;

(v) each of the Company and Mr. Crawford released the other from certain claims; and

(vi) Mr. Crawford agreed not to compete with us for a period that ended October 31, 2003.

Employment Agreement with Mr. Socha.  The Company and Mr. Socha entered into an employment agreement effective May 6, 2004. The agreement provides that Mr. Socha will serve as President and Chief Executive Officer of the Company for an initial three-year term of employment. The term may be extended by mutual agreement

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of the parties in one-year increments, beginning on the first anniversary of the agreement. The employment agreement provides for a base salary of $375,000 per year, subject to annual review, and that Mr. Socha will participate in our annual cash bonus program. Pursuant to the 2004 Equity Incentive Plan described below, on May 25, 2004, Mr. Socha was granted 300,000 restricted shares of common stock, 206,250 shares of which will vest in five equal annual installments, beginning on the first anniversary of the date of the grant, and the remaining 93,750 shares of which will vest upon the achievement of designated corporate performance criteria. The performance criteria include achieving EBITDA results for 2004 and 2005, as contained in our disclosure statement accompanying the Plan of Reorganization, of approximately $126.3 million for the two year period (80% of vesting) and the successful development of the new mine at McCoy Elkhorn (20% of vesting). The performance criteria will not be measured, and therefore no stock will vest, prior to the completion of the annual audit for the year ended December 31, 2005. Mr. Socha also was granted options to acquire 150,000 shares of common stock for $10.80 per share. The options will vest in five equal annual installments, beginning on the first anniversary of the date of grant. Upon termination without good reason or a change in control (as those terms are defined in the agreement) all of the restricted shares and options will immediately vest and the options will become exercisable. Following the recommendation of the secured creditors from the Chapter 11 reorganization process, the Board of Directors awarded Mr. Socha a one-time restructuring bonus of $800,000. Mr. Socha requested, and the Board of Directors approved, a reduction in the bonus to $601,000. We distributed the remaining bonus of $199,000 to other individuals in the organization not otherwise eligible for bankruptcy-related bonus payments, primarily operating level managers at the individual mine and preparation plant levels.

In addition, Mr. Socha is entitled to participate in all other benefit plans to which our other senior executives are entitled, including medical, dental and other welfare plans. The employment agreement further provides that if Mr. Socha’s employment is terminated without good reason, as defined in the employment agreement, before expiration, he will receive the greater of (i) his remaining salary due under the employment agreement or (ii) 12 months of salary. The agreement also provides that as long as Mr. Socha is employed as President and Chief Executive Officer of the Company, he will serve as a member of our Board of Directors.

Indemnification Agreements

We have entered into Indemnification Agreements with our directors and certain of our officers (the “Indemnified Parties”). Under the terms of the Indemnification Agreements, we are required to indemnify the Indemnified Parties against certain liabilities arising out of their services for us. The Indemnification Agreements require us to:

(i) indemnify each Indemnified Party to the fullest extent permitted by law;

(ii) provide coverage for each Indemnified Party under our directors and officers liability insurance policy; and

(iii) to advance certain expenses incurred by an Indemnified Party.

The Indemnification Agreements provide limitations on the Indemnified Parties’ rights to indemnification in certain circumstances. To the extent that indemnification provisions contained in the Indemnification Agreements purport to include indemnification for liabilities arising under the Securities Act of 1933, we have been informed that in the opinion of the Securities and Exchange Commission, such indemnification is contrary to public policy and therefore unenforceable.

2004 Equity Incentive Plan

Our Board of Directors adopted the 2004 Equity Incentive Plan (the “2004 Incentive Plan”) on May 7, 2004, and our shareholders approved the 2004 Incentive Plan on May 25, 2004. The objectives of the 2004 Incentive Plan are to:

(i) attract, motivate and retain employees, directors, consultants, advisors and other persons who perform services for us by providing compensation opportunities that are competitive with other companies;

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(ii) provide incentives to those individuals who contribute significantly to our long-term performance and growth and that of our affiliates; and

(iii) align the long-term financial interests of employees and other individuals who are eligible to participate in the 2004 Incentive Plan with those of shareholders.

The following description of the material features of the 2004 Incentive Plan is a summary and is subject to the provisions of the 2004 Incentive Plan. The 2004 Incentive Plan is incorporated by reference as an exhibit to the registration statement of which this prospectus is a part.

General.  The 2004 Incentive Plan is administered by the Compensation Committee of the Board of Directors (the “Committee”), and may be administered by such other committee consisting of two or more members as may be appointed by the Board to administer the 2004 Incentive Plan. If any member of the Committee does not qualify as (i) a “Non-Employee Director” within the meaning of Rule 16b-3 of the Securities Exchange Act of 1934, as amended and (ii) an “outside director” within the meaning of Section 162(m) of the Internal Revenue Code of 1986, as amended (the “Code”), a subcommittee of the Committee will be appointed to grant Awards to Named Executive Officers and to officers who are subject to Section 16 of the Securities Exchange Act of 1934, and each member of such subcommittee will satisfy the requirements of (i) and (ii) above. References to the Committee in this summary shall include and, as appropriate, apply to any such subcommittee. Subject to the requirement that shareholder approval be obtained for certain amendments, the 2004 Incentive Plan may be amended by the Committee in whole or in part, but no such action shall adversely affect any rights or obligations with respect to any awards previously granted under the 2004 Incentive Plan, unless the participants affected by such amendment provide their written consent.

Under the 2004 Incentive Plan, participants may be granted stock options (qualified and nonqualified), stock appreciation rights (“SARs”), restricted stock, restricted stock units, and performance shares, provided that non-employee directors are not eligible for grants of qualified stock options or performance shares. The total number of shares that may be awarded under the 2004 Incentive Plan is 1,650,000. Not more than 1,000,000 of the shares reserved under the 2004 Incentive Plan may be granted in the form of incentive stock options.

Shares awarded or subject to purchase under the 2004 Incentive Plan that are not delivered or purchased, or revert to us as a result of forfeiture or termination, expiration or cancellation of an award or that are used to exercise an award or for tax withholding, will be again available for issuance under the 2004 Incentive Plan.

Eligibility.  The Committee will determine the individuals to whom awards will be granted, the number of shares subject to an award, and the other terms and conditions of an award. To the extent provided by law, the Committee may delegate to one or more persons the authority to grant awards. As applicable, when used in this description of the 2004 Incentive Plan, the Committee also refers to any such individual to whom the Committee has delegated some of its authority to grant awards. The Committee may provide in the agreements relating to awards under the 2004 Incentive Plan for automatic accelerated vesting and other rights upon the occurrence of a change in control or upon the occurrence of other events as may be specified in such agreements.

Stock Options.  The number of shares subject to a stock option, the type of stock option (i.e., incentive stock option (“ISO”) or nonqualified stock option (“NQSO”)), the exercise price of a stock option (which shall be not less than the fair market value of a share on the date of grant) and the period of exercise (including upon termination of employment) will be determined by the Committee and set forth in an option agreement; provided that no option will be exercisable more than ten years after the date of grant.

Options granted under the 2004 Incentive Plan shall be exercisable at such times and be subject to restrictions and conditions as the Committee shall in each instance approve, including conditions related to the employment of or provision of services by a participant. The Committee shall determine and set forth in the option agreement the extent to which options are exercisable after termination of employment. The Committee may provide for deferral of option gains related to an exercise. The option price upon exercise shall be paid to us in full, either (a) in cash, (b) cash equivalent approved by the Committee, (c) if approved by the Committee, by tendering (or attesting to the ownership of) previously acquired shares having an aggregate fair market value at the time of exercise equal to the total exercise option price, or (d) by a combination of (a), (b) and (c). The Committee may also allow cashless exercises as permitted under the Federal Reserve Board’s Regulation T, subject to applicable securities law

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restrictions, or by any other means which the Committee determines to be consistent with the 2004 Incentive Plan’s purpose and applicable law.

SARs. SARs granted under the 2004 Incentive Plan entitle the grantee to receive an amount payable in shares and/or cash, as determined by the Committee, equal to the excess of the fair market value of a share on the day the SAR is exercised over the specified exercise price, which will not be less than the fair market value of a share on the grant date of the SAR. The exercise period of a SAR may not exceed ten years. SARs may be granted in tandem with a related stock option or independently. If a SAR is granted in tandem with a stock option, the grantee may exercise the stock option or the SAR, but not both. The Committee shall determine and set forth in the award agreement the extent to which SARs are exercisable after termination of employment.

Restricted Stock/Restricted Stock Units.  Restricted stock awards may be current grants of restricted stock or deferred grants. The terms of restricted stock awards, including the restriction period, any performance targets applicable to the award and the extent to which the grantee will have the right to receive unvested restricted stock following termination of employment or other events, will be determined by the Committee and be set forth in the agreement relating to such award. Unless otherwise set forth in an agreement relating to a restricted stock award, the grantee of restricted stock shall have all of the rights of a shareholder of ours, including the right to vote the shares and the right to receive dividends, provided however that the Committee may require that any dividends on such shares of restricted stock be automatically deferred and reinvested in additional restricted stock or may require that dividends on such shares be paid to us to be held for the account of the grantee.

A restricted stock unit is an unsecured promise to transfer an unrestricted share at a specified future date, such as a fixed number of years, retirement or other termination of employment (which date may be later than the vesting date of the award at which time the right to receive the share becomes nonforfeitable). Restricted stock units represent the right to receive a specified number of shares at such times, and subject to such restriction period and other conditions, as the Committee determines. A participant to whom restricted stock units are awarded has no rights as a shareholder with respect to the shares represented by the restricted stock units unless and until shares are actually delivered to the participant in settlement of the award. However, restricted stock units may have dividend equivalent rights if provided for by the Committee.

Performance Shares.  Performance shares are awards granted in terms of a stated potential maximum number of shares, with the actual number and value earned to be determined by reference to the satisfaction of performance targets established by the Committee. Such awards may be granted subject to any restrictions, in addition to performance conditions, deemed appropriate by the Committee. Except as otherwise provided in an agreement relating to performance shares, a grantee shall be entitled to receive any dividends declared with respect to shares earned that have not yet been distributed to the grantee and shall be entitled to exercise full voting rights with respect to such shares.

Performance Measures.  If awards granted or issued under the 2004 Incentive Plan are intended to qualify under the performance-based compensation provisions of Section 162(m) of the Code, the performance measure(s) to be used for purposes of such awards shall be chosen by the Committee from among the following: earnings, earnings per share, consolidated pre-tax earnings, net earnings, operating income, EBIT (earnings before interest and taxes), EBITDA (earnings before interest, taxes, depreciation and amortization), gross margin, revenues, revenue growth, market value added, economic value added, return on equity, return on investment, return on assets, return on net assets, return on capital employed, return on incremental equity, total shareholder return, profit, economic profit, capitalized economic profit, after-tax profit, pre-tax profit, cash flow measures, cash flow return, sales, sales volume, revenue per employee, stock price, cost goals, budget goals, growth expansion goals, or goals related to acquisitions or divestitures.

The Committee can establish other performance measures for awards granted to participants.

Adjustment of Shares.  The share limitation of 1,650,000 shares and the terms of outstanding awards shall be adjusted, as the Committee deems appropriate, in the event of a stock dividend, stock split, combination, reclassification, recapitalization or other similar event.

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Nontransferability.  Any options, SARs or performance shares granted under the 2004 Incentive Plan are nontransferable except by will or by the laws of descent and distribution. Shares of Restricted Stock and Restricted Stock Units are nontransferable during the restriction period. Unless otherwise provided in the specific award agreement, during the lifetime of a participant, options or SARs may only be exercised by such participant. Notwithstanding the foregoing, to the extent allowed in the specific award agreement, a participant may transfer an option or SAR (other than an ISO or its corresponding SAR) with respect to all or part of the shares of common stock subject to such option or SAR to the participant’s spouse, children or grandchildren, to a trust for the benefit of such family members or to a partnership in which such family members are the only partners.

Assumption of Awards.  The 2004 Incentive Plan provides that its terms shall be binding on any of our successors and assigns (whether by purchase, merger, consolidation or otherwise).

Termination and Amendment.  No option, SAR or stock award may be granted and no performance shares may be awarded under the 2004 Incentive Plan after May 25, 2014. The Board of Directors may amend or terminate the 2004 Incentive Plan at any time, but certain amendments will not become effective without shareholder approval.

Awards.  We have granted or authorized the following awards under the 2004 Incentive Plan:

• Each non-employee director received a grant of options to purchase 10,000 shares of common stock at a strike price of $15.00 per share and a grant of 1,000 restricted shares of common stock. These grants will vest in three equal annual installments, beginning on the first anniversary of the date of grant. Upon a change in control (as defined in the 2004 Incentive Plan) all of the restricted shares and options will immediately vest and the options will become immediately exercisable.

• Peter T. Socha received a grant of 300,000 restricted shares of common stock, 206,250 shares of which will vest automatically in five equal annual installments, beginning on the first anniversary of the date of the grant, and the remaining 93,750 shares of which will vest upon the achievement of designated performance criteria. The performance criteria include achieving EBITDA results for 2004 and 2005, as contained in our disclosure statement accompanying the Plan of Reorganization, of approximately $126.3 million for the two year period (80% of vesting) and the successful development of the new mine at McCoy Elkhorn (20% of vesting). The performance criteria will not be measured, and therefore no stock will vest, prior to the completion of the annual audit for the year ended December 31, 2005. Upon a change in control (as defined in the employment agreement between the Company and Mr. Socha) all of the restricted shares will immediately vest.

• Other members of our operating and senior management have received or will receive, in the aggregate, grants of 716,700 restricted shares of common stock and options for common stock, of which, 710,450 shares and options will vest automatically in five equal annual installments, beginning on the first anniversary of the date of the grant, and the remaining 6,250 shares and options of which will vest upon the achievement of performance criteria to be approved by the Committee.

Miscellaneous Provisions.  The 2004 Incentive Plan prohibits us from decreasing the option price of any outstanding option, other than in connection with a change in corporate capitalization, without first receiving shareholder approval of such repricing.

Federal Income Tax Consequences

The following is a brief summary of the current U.S. federal income tax consequences of awards made under the 2004 Incentive Plan. This summary is general in nature and is not intended to cover all tax consequences that may apply to participants and us. Further, the provisions of the Code and the regulation and rulings thereunder relating to these matters may change.

Stock Options.  A participant will not recognize any income upon the grant or purchase of a stock option. A participant will recognize income taxable as ordinary income (and subject to income tax withholding for Company employees) upon exercise of a non-qualified stock option equal to the excess of the fair market value of the shares purchased over the sum of the exercise price and the amount, if any, paid for the option on an after-tax basis, and

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we will be entitled to a corresponding deduction. A participant will not recognize income (except for purposes of the alternative minimum tax) upon exercise of an incentive stock option provided that the incentive stock option is exercised either while the participant is our employee or within three months (one year if the participant is disabled within the meaning of Section 22(c)(3) of the Code) following the participant’s termination of employment. If shares acquired by such exercise of an incentive stock option are held for the longer of two years from the date the option was granted and one year from the date it was exercised, any gain or loss arising from a subsequent disposition of such shares will be taxed as long-term capital gain or loss, and we will not be entitled to any deduction. If, however, such shares are disposed of within the above-described period, then in the year of such disposition the participant will recognize income taxable as ordinary income equal to the excess of (i) the lesser of the amount realized upon such disposition and the fair market value of such shares on the date of exercise over (ii) the exercise price, and we will be entitled to a corresponding deduction.

SARs.  A participant will not recognize any income upon the grant of a SAR. A participant will recognize income taxable as ordinary income (and, subject to income tax withholding for Company employees) upon exercise of a SAR equal to the fair market value of any shares delivered and the amount of cash paid by us upon such exercise, and we will be entitled to a corresponding deduction.

Restricted Stock Awards.  A participant will not recognize taxable income at the time of the grant of a restricted stock award, and we will not be entitled to a tax deduction at such time, unless the participant makes an election under a special Code provision to be taxed at the time such restricted stock award is granted. If such election is not made, the participant will recognize taxable income at the time the restrictions on such restricted stock award lapse in an amount equal to the excess of the fair market value of the shares at such time over the amount, if any, paid for such shares. The amount of ordinary income recognized by a participant making the above-described special election or upon the lapse of the restrictions is deductible by us, as compensation expense, except to the extent the limit of Section 162(m) applies. In addition, a participant receiving dividends with respect to shares subject to a restricted stock award for which the above-described election has not been made and prior to the time the restrictions lapse will recognize taxable compensation (subject to income tax withholding for Company employees), rather than dividend income, in an amount equal to the dividends paid and we will be entitled to a corresponding deduction.

Restricted Stock Units.  A participant will not recognize taxable income at the time of the grant of a restricted stock unit, and we will not be entitled to a tax deduction at such time. When the participant receives shares pursuant to a restricted stock unit, the federal income tax consequences applicable to restricted stock awards, described above, will apply.

Performance Share Awards.  A participant will not recognize taxable income upon the grant of a performance share award, and we will not be entitled to a tax deduction at such time. Upon the settlement of a performance share award, the participant will recognize compensation taxable as ordinary income (and subject to income tax withholding for Company employees) in an amount equal to the cash paid and the fair market value of the shares delivered to the participant, and we will be entitled to a corresponding deduction.

Compliance with Section 162(m).  Section 162(m) of the Code denies an income tax deduction to an employer for certain compensation in excess of $1 million per year paid by a publicly traded corporation to the Chief Executive Officer or any of the four most highly compensated executive officers other than the Chief Executive Officer. Compensation realized with respect to stock options awarded under the 2004 Incentive Plan, including upon exercise of a non-qualified stock option or upon a disqualifying disposition of an incentive stock option, as described above, will be excluded from this deductibility limit if it satisfies certain requirements, including a requirement that the 2004 Incentive Plan be approved by our current shareholders. In addition, other types of awards under the 2004 Incentive Plan may be excluded from this deduction limit if they are conditioned on the achievement of one or more of the performance measures described above, as required by Section 162(m). To satisfy the requirements that apply to “performance-based” compensation, those performance measures must be approved by our current shareholders, and approval of the 2004 Incentive Plan will also constitute approval of those measures.

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Board of Directors

Our Board of Directors is comprised of five directors, divided into three classes. Alan F. Crown is the sole Class I director, with a term expiring at the annual meeting of shareholders to be held in 2005, Paul H. Vining and James F. Wilson are Class II directors, with terms expiring at the annual meeting of shareholders to be held in 2006, and Leonard J. Kujawa and Peter T. Socha are Class III directors, with terms expiring at the annual meeting of shareholders to be held in 2007. Once elected, our directors serve until the expiration of their respective term or until their successors are elected and qualified. Mr. Vining has delivered notice that he will be taking a senior management position with another publicly traded coal company, which will not allow him to continue to serve on our Board of Directors. He has therefore resigned his position, effective May 31, 2005. The current members of our Board of Directors were selected in accordance with the terms of our Plan of Reorganization. The Board of Directors appoints our executive officers who serve at the Board of Directors’ discretion.

Board Committees

Our Board of Directors has an audit committee, a compensation committee and a corporate governance committee.

Audit Committee.  The audit committee recommends the appointment of our independent auditors, reviews our internal accounting procedures and financial statements, and consults with and reviews the services provided by our internal and independent auditors. The audit committee currently consists of Alan F. Crown, Leonard J. Kujawa (committee chair) and Paul H. Vining.

Compensation Committee.  The compensation committee reviews and recommends to the Board of Directors the compensation and benefits of all of our executive officers, administers our stock option plans and establishes and reviews general policies relating to compensation and benefits of our employees. The compensation committee currently consists of Alan F. Crown, Paul H. Vining (committee chair) and James F. Wilson.

Governance Committee.  The governance committee assists the Board of Directors by identifying individuals qualified to become members of our Board of Directors consistent with criteria set by our Board of Directors and by developing our corporate governance principles. The governance committee currently consists of Alan F. Crown (committee chair), Leonard J. Kujawa, Paul H. Vining and James F. Wilson.

Compensation of Directors

Directors who are employees of the Company or any of its subsidiaries are not compensated for service on the Board of Directors or on any of its committees. Directors who are not employees of the Company or any of its subsidiaries receive an annual Board of Directors membership fee of $35,000, which is paid in four equal quarterly installments. The chairperson of our audit committee will receive additional annual compensation of $10,000, also paid in four equal quarterly installments. We do not pay separate meeting fees.

All directors are reimbursed for their reasonable out-of-pocket expenses incurred in attending meetings of the Board of Directors and committees.

Directors also are eligible to receive and have received equity awards under our 2004 Equity Incentive Plan. See “Executive Compensation—2004 Equity Incentive Plan.” On May 7, 2004, subject to obtaining shareholder approval of the 2004 Equity Incentive Plan, which we secured on May 25, 2004, we granted 1,000 restricted shares of our common stock and options to acquire 10,000 shares of our common stock for $15.00 per share to each of our non-employee directors. The restricted shares and options all vest in three equal annual installments, beginning on the first anniversary of the date of grant. Upon a change of control of the Company, all of the restricted shares and options will immediately vest and the options will become exercisable.

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Compensation Committee Interlocks and Insider Participation

Our compensation committee was formed on May 7, 2004, and currently consists of Alan F. Crown, Paul H. Vining (committee chair) and James F. Wilson. None of these committee members is employed by us. None of our executive officers serves as a member of the compensation committee of any entity that has one or more executive officers who serve on our compensation committee. No interlocking relationship exists between our compensation committee and the compensation committee of any other company, nor has any interlocking relationship existed in the past.

In February 2004, we sold 10,000 tons of coal to Ellett Valley CC, Inc., the coal industry consulting company that is 100% owned and controlled by Mr. Vining, a Company director. The total price of the coal was $500,000, which was consistent with then-prevailing market rates for comparable coal. Ellett Valley CC, Inc., acting as a broker, then resold the coal. This transaction took place before Mr. Vining was considered for service as a director of the Company.

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PRINCIPAL AND SELLING SHAREHOLDERS

The following table sets forth information, as of February 14, 2005 or such other date as is indicated below, regarding shares of our common stock held by (1) persons known to us to be the beneficial owners of more than five percent of our common stock, (2) the selling shareholder in this offering, (3) our executive officers and directors and (4) our executive officers and directors as a group. This table was prepared solely based on information supplied to us, any Schedules 13D or 13G and Forms 3 and 4, and other public documents filed with the Securities and Exchange Commission. The below information does not reflect shares that may be issued in connection with the Triad acquisition.

	Shares Beneficially Owned Prior to Offering							Shares Beneficially Owned After Offering
								Without Over-allotment Exercise					With Over-allotment Exercise
Name	Number(1)		%(2)			Number of Shares Offered(3)		Number(4)		%(2)(4)			Number(4)		%(2)(4)
Carl Marks Group (5)		2,755,318		18.69	%		2,000,000		755,318		4.65	%		755,318		4.50	%
Harbert Group (6)		2,210,205		14.99	%		—		2,210,205		13.61	%		2,210,205		13.18	%
Glencore Finance AG (7)		2,208,948		14.99	%		—		2,208,948		13.60	%		2,208,948		13.18	%
Merrill Lynch PCG, Inc. (8)		985,000		6.68	%		—		985,000		6.07	%		985,000		5.88	%
Triage Group (9)		813,426		5.52	%		—		813,426		5.01	%		813,426		4.85	%
Peter T. Socha (10)		71,250		*			—		71,250		*			71,250		*
Alan F. Crown (11)		3,666		*			—		3,666		*			3,666		*
Leonard J. Kujawa (12)		3,666		*			—		3,666		*			3,666		*
Paul H. Vining (13)		3,666		*			—		3,666		*			3,666		*
James F. Wilson (5)(14)		2,755,318		18.69	%		2,000,000		755,318		4.65	%		755,318		4.50	%
Samuel M. Hopkins, II (15)		13,750		*			—		13,750		*			13,750		*
Coy K. Lane, Jr. (16)		0		*			—		0		*			0		*
James B. Crawford (17)		0		*			—		0		*			0		*
William T. Sullivan (18)		0		*			—		0		*			0		*
Executive Officers and Directors as a Group (9 persons)		2,851,316		19.29	%		2,000,000		851,316		5.23	%		851,316		5.06	%

 

* Less than 1%

(1) This column lists all shares of common stock beneficially owned, whether or not registered hereunder, including all restricted shares of common stock that vest, and all shares of common stock that can be acquired through option exercises, within 60 days of the date of this prospectus.

(2) In calculating the percentage owned, we assumed that any options for the purchase of common stock that are exercisable by that shareholder within 60 days of the date of this prospectus are exercised by that shareholder (and the underlying shares of common stock issued). The total number of shares outstanding used in calculating the percentage owned assumes a base of 14,740,694 shares of common stock outstanding as of the date of this prospectus and no exercise of options held by other shareholders.

(3) Only the shares of common stock shown in this column are being offered by the selling shareholder pursuant to this prospectus. Before our emergence from bankruptcy, the selling shareholder was a secured creditor in our bankruptcy proceedings, as a holder of a portion of our pre-petition secured debt. Pursuant to the Plan of Reorganization, the selling shareholder’s pre-petition secured claims were converted into new secured notes (governed by the Term Credit Facility) and common stock. Accordingly, the selling shareholder may continue to have a secured lending relationship with us.

(4) Assumes all shares of common stock registered hereunder are sold by the selling shareholder.

(5) As of April 14, 2005, based on information supplied to us by the Carl Marks Group. Includes the following securities owned by James F. Wilson individually: 333 shares of restricted stock that will vest within 60 days of the date of this prospectus and 3,333 shares subject to presently exercisable stock options and options that will vest within 60 days of the date of this prospectus. The Carl Marks Group consists of Carl Marks Strategic Investments, L.P. (2,600,898 shares), Carl Marks Strategic Investments III, L.P. (150,754 shares) and James F. Wilson, one of our directors. The business address of the Carl Marks Group is 900 Third Avenue, 33^rd Floor, New York, New York 10022. Only shares held by Carl Marks Strategic Investments, L.P. and Carl Marks Strategic Investments III, L.P. are being registered hereby and offered in this offering, which shares were issued upon the conversion of our pre-petition secured debt in connection with our emergence from bankruptcy. James F. Wilson is one of three individual general partners of Carl Marks Management Company, L.P., a Delaware limited partnership and registered investment advisor, which is the sole general partner of (i) Carl Marks Strategic Investments, L.P., a Delaware limited partnership and private investment partnership, and (ii) Carl Marks Strategic Investments III, L.P., a Delaware limited partnership and private investment partnership. The shares of common stock which are owned by Carl Marks Strategic Investments, L.P. and Carl Marks Strategic Investments III, L.P. may be deemed to be beneficially owned indirectly, on a shared basis, by Mr. Wilson and the other individual general partners of Carl Marks Management Company, L.P., who share the power to direct the vote or dispose of such securities.

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(6) As of April 14, 2005, based upon information supplied to us by the Harbert Group, which consists of Harbert Distressed Investment Master Fund, Ltd. (“Master Fund”) and Alpha US Sub Fund VI, LLC (“Alpha”), and the Form 4 filed by the Master Fund, HMC Distressed Investment Offshore Manager, L.L.C. (“Offshore Manager”) and HMC Investors, L.L.C. (“HMC Investors”) with the SEC on April 18, 2005. The Offshore Manager and the Master Fund share voting and dispositive power over 2,155,760 shares of our common stock (the “HMC Shares”). In addition to the HMC Shares, HMC Investors, Raymond J. Harbert, Michael D. Luce and Philip A. Falcone may also be deemed to have shared voting and dispositive power over an additional 54,445 shares of our common stock owned by Alpha (the “Alpha Shares”). We have been informed by the Master Fund and Alpha that each disclaims beneficial ownership of the HMC Shares and the Alpha Shares except to the extent of their actual pecuniary interest. Each of Master Fund and Alpha is or may be deemed to be an affiliate of a registered broker-dealer. Master Fund is an entity organized in the Cayman Islands. Offshore Manager is the sole investment manager of the Master Fund. HMC Investors is the managing member of the Offshore Manager. Philip A. Falcone is a member of Offshore Manager and acts as portfolio manager for the Master Fund. Alpha is a separate managed account also managed by Philip A. Falcone. Raymond J. Harbert and Michael D. Luce are members of HMC Investors. The business address of the Master Fund is c/o International Fund Services (Ireland) Limited, 3^rd Floor, Bishop’s Square, Redmond’s Hill, Dublin 2, Ireland. The business address of Alpha is c/o 555 Madison Avenue, 16^th Floor, New York, New York 10022.

(7) As of January 21, 2005, based on information in the Form 4/A filed on January 25, 2005. The business address of Glencore Finance AG is Baarermattstrasse 3, CH-6341 Baar, Switzerland.

(8) As of December 31, 2004, based on information in the Schedule 13G filed on February 14, 2005. The business address of Merrill Lynch PCG, Inc. is 4 World Financial Center, New York, New York 10080.

(9) As of December 31, 2004, based on information in the Schedule 13G filed on February 15, 2005. The Triage Group consists of Triage Capital LF Group LLC, a Delaware limited liability company (“Triage Capital”) that acts as a general partner to (i) a general partner of different funds and an investment manager of a managed account and (ii) an investment manager of a Cayman Islands company, and Leonid Frenkel, who is (i) the managing member of Triage Capital and controls its business activities and (ii) the manager of another limited liability company. The business address of the Triage Group is 401 City Avenue, Suite 800, Bala Cynwyd, Pennsylvania 19004.

(10) Includes 41,250 shares of restricted stock that will vest within 60 days of the date of this prospectus and 30,000 shares subject to presently exercisable stock options and options that will vest within 60 days of the date of this prospectus. Mr. Socha’s business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

(11) Includes 333 shares of restricted stock that will vest within 60 days of the date of this prospectus and 3,333 shares subject to presently exercisable stock options and options that will vest within 60 days of the date of this prospectus. Mr. Crown’s business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

(12) Includes 333 shares of restricted stock that will vest within 60 days of the date of this prospectus and 3,333 shares subject to presently exercisable stock options and options that will vest within 60 days of the date of this prospectus. Mr. Kujawa’s business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

(13) Includes 333 shares of restricted stock that will vest within 60 days of the date of this prospectus and 3,333 shares subject to presently exercisable stock options and options that will vest within 60 days of the date of this prospectus. Mr. Vining’s business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

(14) Includes 333 shares of restricted stock that will vest within 60 days of the date of this prospectus and 3,333 shares subject to presently exercisable stock options and options that will vest within 60 days of the date of this prospectus. Mr. Wilson’s business address is 900 Third Avenue, 33^rd Floor, New York, New York 10022. Mr. Wilson is one of three individual general partners of Carl Marks Management Company, L.P., a Delaware limited partnership and registered investment advisor, which is the sole general partner of (i) Carl Marks Strategic Investments, L.P., a Delaware limited partnership and private investment partnership, and (ii) Carl Marks Strategic Investments III, L.P., a Delaware limited partnership and private investment partnership. The shares of common stock which are owned by Carl Marks Strategic Investments, L.P. and Carl Marks Strategic Investments III, L.P. may be deemed to be beneficially owned indirectly, on a shared basis, by Mr. Wilson and the other individual general partners of Carl Marks Management Company, L.P., who share the power to direct the vote or dispose of such securities.

(15) Includes 13,750 shares of restricted stock that will vest within 60 days of the date of this prospectus. Mr. Hopkins’ business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

(16) Mr. Lane’s business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

(17) Mr. Crawford’s business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

(18) Mr. Sullivan’s business address is c/o James River Coal Company, 901 E. Byrd Street, Suite 1600, Richmond, Virginia 23219.

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RELATED PARTY TRANSACTIONS

Settlement Agreement with Mr. Crawford.  On March 17, 2003, James B. Crawford resigned all positions with the Company. In connection with Mr. Crawford’s resignation, the Company, Mr. Crawford and J.R. Coal Associates (a Virginia partnership in which Mr. Crawford was a partner) entered into a Settlement Agreement, pursuant to which Mr. Crawford received, among other things:

(i) rights under two life insurance contracts, one of which represented the vested amount in Mr. Crawford’s account in our Supplemental Savings and Profit Sharing Plan of $535,021, and the other of which was a life insurance policy with a cash value of $143,668;

(ii) the right to receive $1,383,002 in cash from us upon our consummation of a Chapter 11 plan of reorganization or the sale of all or substantially all of our assets (which amount was paid on May 6, 2004); and

(iii) welfare benefit continuation until the payment under (ii) above was made.

In the event Mr. Crawford is engaged by us or any purchaser of us, or any successor to either, as Chairman, Chief Executive Officer, Chief Operations Officer or any similar position within the 12 months from the payment under (ii) above, Mr. Crawford is obligated to repay the amount received under (ii) above. Additionally, pursuant to the settlement agreement:

(iv) Mr. Crawford sold all of his equity interests in the Company to J.R. Coal Associates in exchange for the transfer by J.R. Coal Associates to the Company of certain life insurance policies;

(v) each of the Company and Mr. Crawford released the other from certain claims; and

(vi) Mr. Crawford agreed not to compete with us for a period that ended October 31, 2003.

Coal Transaction with Mr. Vining.  In February 2004, we sold 10,000 tons of coal to Ellett Valley CC, Inc., the coal industry consulting company that is 100% owned and controlled by Mr. Vining, a Company director. The total price of the coal was $500,000, which was consistent with then-prevailing market rates for comparable coal. Ellett Valley CC, Inc., acting as a broker, then resold the coal. This transaction took place before Mr. Vining was considered for service as a director of the Company.

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DESCRIPTION OF CAPITAL STOCK

Authorized Capital Stock

Our charter authorizes the issuance of up to 100,000,000 shares of common stock, $0.01 par value, and 10,000,000 shares of preferred stock, $1.00 par value, the rights and preferences of which may be established from time to time by our Board of Directors. As of the date of this prospectus, 14,740,694 shares of common stock and no shares of preferred stock were issued and outstanding. As of February 24, 2005, we had approximately 104 record shareholders.

The following is a materially complete summary of our capital stock, but is subject to the provisions of our charter and our bylaws, as well as to applicable provisions of the Virginia Stock Corporation Act. A copy of our charter and our bylaws are filed as exhibits to the registration statement of which this prospectus is a part.

Common Stock

The holders of our common stock are entitled to one vote for each share on all matters voted on by shareholders, including elections of directors, and, except as otherwise required by law or provided in any resolution adopted by our Board of Directors with respect to any series of preferred stock (a “preferred stock designation”), the holders of our common stock possess all of the voting power. Our articles of incorporation do not provide for cumulative voting in the election of directors. Subject to any preferential rights of any outstanding series of our preferred stock created by our Board of Directors from time to time, the holders of our common stock are entitled to such dividends as may be declared from time to time by our Board of Directors from funds legally available for the payment of dividends, and, upon liquidation, dissolution or winding up, will be entitled to receive pro rata all assets available for distribution to the holders of our common stock after payment of a proper amount to the holders of any series of preferred stock that may be issued in the future.

Preferred Stock

Our articles of incorporation authorize our Board of Directors to establish one or more series of preferred stock and to determine, with respect to any series of preferred stock, the terms and rights of such series, including, but not limited to:

• the designation of the series;

• the number of shares of the series, which number our Board of Directors may later, except where otherwise provided in the preferred stock designation, increase or decrease, but not below the number of shares of that series then outstanding;

• whether dividends, if any, will be cumulative or noncumulative, and, in the case of shares of any series having cumulative dividend rights, the date or dates or method of determining the date or dates from which dividends on the shares of the series having cumulative dividend rights shall be cumulative;

• the rate of any dividends, or method of determining the dividends, payable to the holders of the shares of the series, any conditions upon which the dividends will be paid and the date or dates or the method for determining the date or dates upon which the dividends will be payable;

• the redemption rights and price or prices, if any, for shares of the series;

• the terms and amounts of any sinking fund provided for the purchase or redemption of shares of the series;

• the amounts payable on and the preferences, if any, of shares of the series in the event of any voluntary or involuntary liquidation, dissolution or winding up of our affairs;

• whether the shares of the series will be convertible or exchangeable into shares of any other class or series, or any other security, of us or any other corporation, and, if so, the specification of the other class or series or the other security, the conversion or exchange price or prices or rate or rates, any adjustments thereof,

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the date or dates as of which the shares will be convertible or exchangeable and all other terms and conditions upon which the conversion or exchange may be made;

• restrictions on the issuance of shares of the same series or of any other class or series; and

• the voting rights, if any, of the holders of the shares of the series.

We believe that the ability of our Board of Directors to issue one or more series of preferred stock will provide us with flexibility in structuring possible future financings and acquisitions, and in meeting other corporate needs that might arise. The authorized shares of our preferred stock, as well as shares of our common stock, will be available for issuance without further action by our shareholders unless required by applicable law or the rules of any stock exchange or automated quotation system on which our securities may be listed or traded. If the approval of our shareholders is not required for the issuance of shares of our preferred stock or common stock, our Board of Directors may determine not to seek shareholder approval.

As of the date hereof, 500,000 shares of our Series A Preferred Stock are reserved for issuance upon exercise of the rights issued under our shareholders rights agreement. For a more complete discussion of our rights agreement, see “Description of Capital Stock—Shareholders Rights Agreement” below.

Preemptive Rights

Neither the holders of our common stock nor of any series of our preferred stock will be entitled to any preemptive or other subscription rights.

Shareholder Rights Agreement

Our Board of Directors voted to adopt the proposed Rights Agreement between the Company and SunTrust Bank, as rights agent (the “Rights Agreement”), on May 7, 2004, and our shareholders approved the Rights Agreement on May 25, 2004. On the effective date of the Rights Agreement, May 25, 2004, our Board of Directors declared a dividend of one preferred share purchase right for each two shares of common stock outstanding. The following is a summary of the Rights Agreement. The Rights Agreement has been incorporated by reference as an exhibit to the registration statement of which this prospectus is a part.

Each share purchase right entitles the registered holder to purchase from us one one-hundredth (1/100) of a share of our Series A Participating Cumulative Preferred Stock, par value $1.00 per share, at a price of $200 per one one-hundredth of a Series A preferred share. The exercise price and the number of Series A preferred shares issuable upon exercise is subject to adjustment from time to time to prevent dilution. The share purchase rights are not exercisable until the earlier to occur of (1) ten days following a public announcement that a person or group of affiliated or associated persons (an “Acquiring Person”) have acquired beneficial ownership of 15% or more of our outstanding common stock or (2) ten business days following the commencement of, or announcement of an intention to make, a tender offer or exchange offer the consummation of which would result in the beneficial ownership by a person or group of 15% or more of the outstanding shares of our common stock.

In the event that we are acquired in a merger or other business combination transaction or 50% or more of our consolidated assets or earning power is sold after a person or group has become an Acquiring Person, proper provision will be made so that each holder of a share purchase right, other than share purchase rights beneficially owned by the Acquiring Person (which will thereafter be void), will thereafter have the right to receive, upon the exercise thereof at the then current exercise price of the share purchase right, that number of shares of common stock of the acquiring company which at the time of such transaction will have a market value of two times the exercise price of the share purchase right. In the event that any person or group of affiliated or associated persons becomes an Acquiring Person, proper provision shall be made so that each holder of a share purchase right, other than share purchase rights beneficially owned by the Acquiring Person (which will thereafter be void), will thereafter have the right to receive upon exercise, without payment of the exercise price, that number of shares of common stock having a market value of two times the exercise price of the share purchase right.

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Series A preferred shares purchasable upon exercise of the share purchase rights will not be redeemable. Each Series A preferred share will be entitled to a minimum preferential quarterly dividend payment of $1.00 per share but will be entitled to an aggregate dividend of 100 times the dividend declared per share of common stock. In the event we liquidate, the holders of the Series A preferred shares will be entitled to a minimum preferential liquidation payment of $1.00 per share but will be entitled to an aggregate payment of 100 times the payment made per share of common stock. Each Series A preferred share will have 100 votes, voting together with the shares of common stock. Finally, in the event of any merger, consolidation or other transaction in which shares of common stock are exchanged, each Series A preferred share will be entitled to receive 100 times the amount received per share of common stock. These rights are protected by customary antidilution provisions.

Prior to the date the share purchase rights are exercisable, the share purchase rights may not be detached or transferred separately from the common stock. The share purchase rights will expire ten years after the date of effectiveness, unless that expiration date is extended or unless the share purchase rights are earlier redeemed or exchanged by us, in each case, as described below. At any time prior to the acquisition by a person or group of affiliated or associated persons of beneficial ownership of 15% or more of the outstanding common stock, the Board of Directors may redeem the share purchase rights in whole, but not in part, at a price of $0.001 per share purchase right. Immediately upon any redemption of the share purchase rights, the right to exercise the share purchase rights will terminate and the only right of the holders of share purchase rights will be to receive the redemption price.

The Rights Agreement could have the effect of discouraging tender offers or other transactions that might otherwise result in our shareholders receiving a premium over the market price for their common stock.

The Board of Directors believes that the Rights Agreement enhances our flexibility to respond to any unsolicited offer, will generally increase the amount to be received by our shareholders in the event of any such offer, and will allow us to protect our shareholders from coercive offers or offers that the Board of Directors deems, for various reasons, not to be in the best interests of our shareholders and the Company. The Rights Agreement provides us with a defensive mechanism that decreases the risk that a hostile acquirer will attempt to take control of us without negotiating directly with the Board of Directors.

Certain Anti-Takeover Provisions of Virginia Law and Our Charter and Bylaws

The following discussion concerns material provisions of Virginia law and our articles of incorporation and bylaws that could be viewed as having the effect of discouraging an attempt to obtain control of us. The anti-takeover aspects of our shareholders rights agreement have been described above.

Anti-Takeover Statutes

We are subject to the Virginia anti-takeover law regulating “control share acquisitions.” A control share acquisition is an acquisition of voting shares by a person that, when added to all the other voting shares beneficially owned by that person, would cause that person’s voting strength with respect to an election of directors to meet or exceed any of the following thresholds:

• one-fifth;

• one-third; or

• a majority.

Under Virginia law, shares acquired in a control share acquisition have no voting rights unless granted by a majority vote of all outstanding shares other than those held by the acquiring person or any officer or employee director of the corporation, or the articles of incorporation or bylaws of the corporation provide that this regulation does not apply to acquisitions of its shares. An acquiring person that owns 5% or more of the corporation’s voting stock may require that a special meeting of the shareholders be held, within 50 days of the acquiring person’s request, to consider the grant of voting rights to the shares acquired or to be acquired in the control share acquisition. If voting rights are not granted and the corporation’s articles of incorporation or bylaws permit, the acquiring person’s shares acquired in a control share acquisition may be repurchased by the corporation, at its option, at a price per

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share equal to the acquiring person’s cost. Virginia law grants dissenters’ rights to any shareholder who objects to a control share acquisition that is approved by a vote of disinterested shareholders and that gives the acquiring person control of a majority of the corporation’s voting shares.

We are also subject to the Virginia law regulating “affiliated transactions.” Material acquisition transactions between a Virginia corporation and any holder of more than 10% of any class of its outstanding voting shares are required to be approved by:

• the holders of at least two-thirds of the remaining voting shares; and

• a majority of the disinterested directors if the acquisition transaction occurs within three years after the acquiring person became a 10% holder.

Affiliated transactions subject to this approval requirement include mergers, share exchanges, material dispositions of corporate assets not in the ordinary course of business, any dissolution of the corporation proposed by or on behalf of a 10% holder or any reclassification, including reverse stock splits, recapitalization or merger of the corporation with its subsidiaries, that increases the percentage of voting shares owned beneficially by a 10% holder by more than 5%. There are certain exceptions to these approval requirements, including an exception for acquisition transactions with a 10% holder whose acquisition of its 10% interest was pre-approved by a majority of the disinterested directors.

Board of Directors; Duties; Classification; Removal; Vacancies

Under Virginia law, directors must discharge their duties in accordance with their good faith business judgment of the best interests of the corporation. Directors may rely on the advice or acts of others, including officers, employees, attorneys, accountants and Board of Directors committees if they have a good faith belief in their competence. Directors’ actions are not subject to a reasonableness or prudent person standard. Virginia’s federal and state courts have focused on the process involved with directors’ decision-making and are generally supportive of directors if they have based their decision on an informed process. These elements of Virginia law could make it more difficult to take over a Virginia corporation than corporations organized under the laws of other states.

Our Board of Directors is divided into three classes of directors serving staggered three-year terms. Each class consists of, as nearly as possible, one-third of the total number of directors. The classification of directors makes it more difficult for shareholders to change the composition of our Board of Directors. At least two annual meetings of shareholders, instead of one, generally will be required to change the majority of our Board of Directors. The classification provisions of our articles of incorporation could discourage a third party from initiating a proxy contest, making a tender offer or otherwise attempting to obtain control of us.

Our bylaws provide that the number of members of our Board of Directors shall be five. Under Virginia law, our Board of Directors may amend the bylaws from time to time to increase or decrease the number of directors by up to 30% of the number of directors in office immediately following the most recent election of directors by its shareholders; provided, that any decrease in the number of directors may not shorten an incumbent director’s term or reduce any quorum or voting requirements until the person ceases to be a director. However, under our articles of incorporation, our total number of directors may not exceed 15 nor be less than three.

Under Virginia law, a member of our Board of Directors may be removed with or without cause by a majority of the votes entitled to be cast at a meeting of shareholders called expressly for that purpose at which a quorum is present. If a director is elected by a voting group of shareholders, only the shareholders of that voting group may participate in the vote to remove the director.

Our bylaws provide that any vacancy occurring on our Board of Directors, including a vacancy resulting from the removal of a director or an increase in the number of directors, may be filled:

• by our shareholders;

• by the remaining directors; or

• by the affirmative vote of a majority of the remaining directors, though less than a quorum.

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Special Meetings of Shareholders

Our bylaws provide that special meetings of shareholders may be called only by the Chairman of our Board of Directors, our President or our Board of Directors.

Shareholder Nominations and Proposals

Our bylaws provide that a shareholder may nominate one or more persons for election as director at a meeting only if advance notice of such nomination has been delivered to our secretary, by personal delivery or United States mail, not later than:

• with respect to an election to be held at an annual meeting of shareholders, 120 days in advance of such meeting; or

• with respect to a special meeting of shareholders for the election of directors, the close of business on the seventh day following the date on which notice of such meeting is given to shareholders.

That notice must include:

• the name and address of the shareholder making the nomination and of the person or persons being nominated;

• a representation that the shareholder is a holder of record of our stock entitled to vote at such meeting and intends to appear in person or by proxy at the meeting;

• a description of all the arrangements or understandings between the shareholder and each nominee and any other person pursuant to which the nomination is being made by the shareholder;

• any other information regarding each nominee that would be required by the Securities and Exchange Commission to be included in a proxy statement had the nominee been nominated or intended to be nominated by the Board of Directors; and

• the consent of each nominee to serve as a director if so elected.

Our bylaws provide that a shareholder may present business before an annual meeting of shareholders if advance notice of such proposal has been delivered to our secretary, by personal delivery or United States mail:

• on or after February 1st and before March 1st of the year in which the meeting will be held; or

• not less than 90 days before the date of the meeting if the date of such meeting has been changed by more than 30 days.

That notice must include:

• the name and address of the shareholder proposing business;

• the class and number of shares of our stock beneficially owned by such shareholder;

• a brief description of the business desired to be brought before the meeting, including the complete text of any resolution and the reasons for conducting such business at the meeting; and

• any interest that the shareholder may have in such business.

These procedural requirements could have the effect of delaying or preventing the submission of matters proposed by any shareholder to a vote of the shareholders.

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Indemnification and Limitations on Liability of Directors and Officers

The laws of the Commonwealth of Virginia pursuant to which we are incorporated permit us to indemnify our officers and directors against certain liabilities with the approval of our shareholders. Our Amended and Restated Articles of Incorporation provide for the indemnification of each director and officer (including former directors and officers and each person who may have served at our request as a director or officer of any other legal entity and, in all such cases, his or her heirs, executors and administrators) against liabilities (including expenses) reasonably incurred by him or her in connection with any actual or threatened action, suit or proceeding to which he or she may be made a party by reason of his or her being or having been a director or officer of the Company, except in relation to any action, suit or proceeding in which he or she has been adjudged liable because of willful misconduct or a knowing violation of criminal law.

We have purchased directors’ and officers’ liability insurance policies. Within the limits of their coverage, the policies insure (1) the directors and officers of the Company and our subsidiaries against certain losses resulting from claims against them in their capacities as directors and officers to the extent that such losses are not indemnified by us and (2) us to the extent that we indemnify such directors and officers for losses as permitted under the laws of Virginia.

Transfer Agent and Registrar

The Transfer Agent and Registrar for our common stock is SunTrust Bank, Atlanta, Georgia.

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DESCRIPTION OF INDEBTEDNESS

Description of Proposed New Senior Secured Credit Facility

Concurrently with this offering, we expect to enter into a credit agreement with PNC Bank, National Association, as administrative agent, Morgan Stanley Senior Funding, Inc., as syndication agent, and the lenders referred to therein that will provide senior secured credit facilities consisting of a $75.0 million synthetic letter of credit facility and a $25.0 million revolving credit facility (a portion of which will be available in the form of letters of credit). The commitments of the lenders to provide the senior facilities are subject to numerous conditions, including the consummation of the Triad Acquisition. The senior secured credit facilities also provide that we may increase the size of the revolving credit facility, on substantially the same terms, by an aggregate amount not to exceed $25.0 million, subject to obtaining additional commitments from the same or other lenders. The following is a summary description of the principal terms of the senior facilities and is subject to and qualified in its entirety by reference to the credit agreement.

The synthetic letter of credit facility will mature on the six and a half year anniversary of the facility and the revolving credit facility will mature on the fifth anniversary of the facility. Each of the senior facilities will require mandatory repayments and prepayments, as applicable, in the following amounts: 50% of the net proceeds of any sale or issuance of equity securities and 100% of the net proceeds of any incurrence of certain indebtedness, in each case by us or by any of our subsidiaries, and 100% of the net proceeds of any sale or other disposition (including as a result of casualty or condemnation) by us or any of our subsidiaries or any assets, subject to reinvestment rights and other limited exceptions. Voluntary prepayments of either senior facility will be permitted at any time, subject to certain notice requirements and to the cancellation, repayment or reimbursement, as the case may be, of any outstanding letters of credit under the senior facilities.

The proceeds of the revolving credit facility will be available solely for working capital needs and other general corporate purposes. The proceeds of the synthetic letter of credit facility will be deposited into a credit-linked certificate of deposit account maintained by PNC Bank, National Association. Such deposits will be used solely to support the issuance of letters of credit by PNC Bank, National Association (or a successor issuing bank), and will not constitute loans to us. Letters of credit will be available under the synthetic letter of credit facility and the revolving credit facility solely to satisfy performance and payment obligations incurred in the ordinary course of business by us and our subsidiaries.

The revolving credit facility will bear an interest rate per annum equal, at our option, to (i) an adjusted LIBOR plus or (ii) a rate equal to the greater of the administrative agent’s prime rate and the federal funds effective rate from time to time, or ABR, plus 0.50%, plus a specified percentage. Overdue principal, interest, fees and other amounts will bear interest, in the case of principal, at the otherwise applicable interest rate plus 2.00% per annum, and in the case of any other amount, at the interest rate applicable to ABR loans plus 2.00% per annum.

Under the synthetic letter of credit facility, a participation fee will accrue on the aggregate daily amount of the credit-linked deposits in the certificate of deposit account at a specified per annum rate and will be payable by us in arrears at the end of each quarter and upon termination of the synthetic letter of credit facility. In addition, on each date on which such participation fees are payable in respect of any period, we will pay to the administrative agent, for the account of the lenders under the synthetic letter of credit facility, a supplemental fee equal to the amount by which the amount of interest that would have accrued on the aggregate daily amount of the credit-linked deposits in the certificate of deposit account during such period at the one-month LIBOR calculated on the basis of a 360-day year exceeds the amount of interest payable on credit-linked deposits in the certificate of deposit account in respect of such period. Under the revolving credit facility, a participation fee will accrue on the aggregate face amount of letters of credit outstanding under the revolving credit facility at a per annum rate equal to the applicable spread over an adjusted LIBOR and will be payable in arrears at the end of each quarter and upon termination of the revolving credit facility.

The credit agreement will contain certain customary covenants restricting or limiting our ability and the ability of our subsidiaries to, among other things:

• declare dividends or make other distributions on capital stock;

• redeem and repurchase capital stock;

• prepay, redeem and repurchase debt (other than loans under the senior secured credit facilities);

• incur liens and sale-leaseback transactions;

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• make loans and investments;

• incur debt and enter into hedging arrangements;

• engage in mergers and other business combinations, recapitalizations, acquisitions and asset sales;

• engage in transactions with affiliates;

• alter the business that we conduct; and

• amend debt and other material agreements.

The credit agreement will also contain customary affirmative covenants, including, without limitation, the maintenance of corporate existence and rights, performance of obligations, delivery of our audited annual consolidated financial statements and our unaudited quarterly consolidated financial statements and other financial information, delivery of periodic certifications and updates regarding the collateral and guarantees, delivery of notices of default, litigation, material adverse change and other matters, maintenance of properties in good working order, maintenance of satisfactory insurance, compliance with laws, inspection of books and properties, further assurances, payment of taxes and other obligations, and use of proceeds.

The credit agreement will contain customary events of default, including, without limitation, payment defaults, breaches of representations and warranties, covenant defaults, cross-default and cross-acceleration to certain other debt, bankruptcy and insolvency, material judgments, certain ERISA events, actual or asserted invalidity of any loan document, security interest guarantee or subordination provision, certain environmental claims and a change of control.

All of our obligations under each of the senior facilities will be unconditionally and irrevocably guaranteed by us and by each of our existing, and subsequently acquired or organized, direct and indirect domestic and, to the extent no adverse tax consequences to us would result, foreign subsidiaries. Each of the senior facilities will be secured by substantially all of our assets and the assets of our subsidiaries, including, without limitation, a perfected first-priority pledge of all the capital stock held by us or any of our subsidiaries, except that the pledge of the voting capital stock of a foreign subsidiary will be limited to 65% to the extent that the pledge of a greater amount would result in adverse tax consequences to us, of each existing and subsequently acquired or organized direct or indirect subsidiary of ours and perfected first-priority security interests in, and mortgages on, substantially all tangible and intangible assets of ours and of each subsidiary guarantor. A security interest in our leased coal reserves will be obtained through a lease-hold mortgage interest, to the extent consent of assignment is not required to perfect.

Once executed and effective, the senior facilities, including the terms and conditions described above, will be subject to modification, amendment and waiver by the parties thereto.

Description of Proposed Senior Notes due 2012

Concurrently with this offering, we will issue $150.0 million in senior notes maturing on June 1, 2012. The notes will rank equally with all of our other existing and future unsecured and unsubordinated debt and will bear interest at a rate per annum of 9.375%, payable semiannually. The notes will be guaranteed, jointly and severally, on an unsecured unsubordinated basis by our existing subsidiaries and, subject to certain exceptions, future subsidiaries.

The indenture governing these notes will contain customary events of default and restricts our ability and the ability of our subsidiaries and future subsidiaries to, among other things, incur additional debt and issue preferred stock, pay dividends, acquire shares of capital stock, make payments on subordinated debt or make investments, place limitations on distributions from our subsidiaries, issue or sell capital stock of our subsidiaries, issue guarantees, sell or exchange assets, enter into transactions with shareholders and affiliates, create liens, engage in unrelated businesses and effect mergers.

We may redeem our notes, in whole or in part, at any time on or after June 1, 2009. In addition, at any time prior to June 1, 2008, we may redeem up to 35% of the principal amount of such notes at a specified redemption price with the net proceeds of a public equity offering, provided that at least 65% of the original aggregate principal amount of such notes remains outstanding after each such redemption. If we experience a change of control, we will be required to offer to repurchase such notes at 101% of the principal amount thereof, plus accrued interest, if any.

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SHARES ELIGIBLE FOR FUTURE SALE

Upon completion of this offering, we will have 16,240,694 shares of our common stock outstanding. If the underwriters exercise their over-allotment option in full, we will have a total of 16,765,694 shares of our common stock outstanding. If the Triad acquisition is completed, there will be additional shares of our common stock outstanding with an aggregate value of $11,000,000. Additionally, pursuant to the terms of the Triad acquisition, we may be obligated to issue additional shares of our common stock, in an amount with an aggregate value of up to $5,000,000, upon the achievement of certain performance measures relating to the acquisition of additional coal reserves after the closing of the Triad acquisition. All of the shares sold in this offering, as well as all of the shares outstanding prior to this offering, will be freely tradable without restriction or further registration under the Securities Act, unless such shares are held or purchased by “affiliates” as that term is defined in Rule 144 under the Securities Act. The shares of our common stock issued in connection with the Triad acquisition, if completed, will be “restricted securities” as that term is defined in Rule 144 under the Securities Act, described below, but will have certain registration rights described below.

We cannot make any predictions as to the number of shares that may be sold in the future or the effect, if any, that sales of these shares, or the availability of these shares for future sale, will have on the prevailing market prices of our common stock. Sales of a significant number of shares of our common stock in the public market, or the perception that these sales could occur, could adversely affect prevailing market prices of our common stock and could impair our ability to raise equity capital in the future.

Lock-up Agreements

We, the selling shareholder and our directors and executive officers have agreed with the underwriters not to sell, dispose of or hedge any of their common stock or securities convertible into or exchangeable for shares of common stock, and we have agreed not to file any registration statement for ourselves or for the benefit of any shareholders relating to our common stock or securities convertible into or exchangeable for shares of common stock, during the period, subject to certain exceptions, from the date of this prospectus continuing through the date 180 days after the date of this prospectus, except with the prior written consent of Morgan Stanley & Co. Incorporated. Morgan Stanley & Co. Incorporated has advised us that it does not have any intention of shortening or releasing us or any individual subject to a lock-up agreement from this 180-day restriction. Morgan Stanley & Co. Incorporated has further advised us that it does not have any pre-established conditions to waiving the terms of the lock-up agreements and grants waivers after evaluating the unique facts and circumstances of each request for such a waiver.

The restrictions described in the previous paragraph do not apply to certain transactions, including the following:

• the sale of shares of common stock to the underwriters pursuant to this offering;

• the issuance by us of shares of common stock pursuant to the exercise of an option or similar security;

• transactions by any person other than us relating to shares of our common stock acquired in open market transactions after completion of this offering;

• transfers of shares of common stock as a bona fide gift or as a result of testate, intestate succession or bona fide estate planning; transfers of shares to a trust, partnership, limited liability company or other entity, all of the beneficial ownership interests of which are held by the transferor; or distributions of shares to limited partners or shareholders of the transferor, in each case provided that the transferee or distributee agrees to be bound by the restrictions described in the previous paragraph;

• the issuance of any shares in connection with the Triad acquisition; or

• the transfer of shares to us solely to satisfy tax withholding obligations incurred as a result of the vesting of restricted stock.

The 180-day restricted period described above is subject to extension such that, in the event that either (1) during the last 17 days of the 180-day restricted period we issue an earnings release or material news or a material event relating to us occurs, or (2) prior to the expiration of the 180-day restricted period, we announce that we will

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release earnings results during the 16-day period beginning on the last day of the 180-day period, the “lock-up” restrictions described above will continue to apply until the expiration of the 18-day period beginning on the earnings release or the occurrence of the material news or material event.

Rule 144

In general, under Rule 144, as currently in effect, beginning 90 days after the date of this prospectus, a person who has beneficially owned shares of our common stock for at least one year would be entitled to sell within any three-month period a number of shares that does not exceed the greater of:

• 1% of the number of shares of our common stock then outstanding, which will equal approximately 165,000 shares immediately after this offering (assuming completion of the Triad acquisition); or

• the average weekly trading volume of the common stock on the Nasdaq National Market System during the four calendar weeks preceding the filing of a notice on Form 144 with respect to the sale.

Sales under Rule 144 are also subject to manner of sale provisions and notice requirements and to the availability of current public information about us.

Rule 144(k)

Under Rule 144(k), a person who is not deemed to have been one of our affiliates at any time during the 90 days preceding a sale, and who has beneficially owned the shares proposed to be sold for at least two years, including the holding period of any prior owner other than an affiliate, is entitled to sell the shares without complying with the manner of sale, public information, volume limitation or notice provisions of Rule 144.

Rule 701

Rule 701, as currently in effect, permits resales of shares in reliance upon Rule 144 but without compliance with certain restrictions, including the holding period requirement, of Rule 144. Any of our employees, officers, directors or consultants who purchased shares under a written compensatory plan or contract may be entitled to rely on the resale provisions of Rule 701. Rule 701 permits affiliates to sell their Rule 701 shares under Rule 144 without complying with the holding period requirements of Rule 144. Rule 701 further provides that non-affiliates may sell their shares in reliance on Rule 144 without having to comply with the holding period, public information, volume limitation or notice provisions of Rule 144.

Registration Rights

2004 Registration Rights Agreement. On May 6, 2004, we entered into a registration rights agreement (the “2004 Registration Rights Agreement”) with holders of 4,544,708 shares, or, at the time, approximately 33%, of our issued and outstanding common stock who by virtue of each such holder’s relationship with us could reasonably have been deemed to be an “affiliate” (as such term is used within the meaning of applicable securities laws) of ours.

Pursuant to the terms of the 2004 Registration Rights Agreement, which is described in more detail below, we were obligated to register the subject shares under the Securities Act on the terms described below. Pursuant to Registration Statement No. 333-118190, which was declared effective as of November 12, 2004, we registered all 4,544,708 shares of our common stock for the shareholders party to the 2004 Registration Rights Agreement.

If we propose to file or file a registration statement under the Securities Act with respect to an offering by us for our own account of any common stock (other than a registration statement relating to shares to be issued in connection with a merger or other acquisition or with stock-based compensation arrangements), then we will give shareholders party to the 2004 Registration Rights Agreement the opportunity to register the number of shares subject to registration rights as each such holder may request. This right is known as a piggyback registration right. If the proposed offering that triggers the piggyback registration right is an underwritten offering, we may be required by the managing underwriter of such offering to limit the number of shares to be registered in the offering (the

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“Cutback Right”), and such Cutback Right may decrease the number of shares subject to the piggyback registration right.

Triad Registration Rights Agreement. Our purchase agreement with Triad contemplates that we will enter into a separate registration rights agreement with holders of Triad’s common stock (the “Triad Registration Rights Agreement”) upon the closing of the Triad acquisition. The holders will generally have the right to make one demand, but to the extent that the two Triad principals receive additional shares pursuant to their consulting agreements (as summarized above), those two individuals will have the right to make one additional demand. Except as specified below, our obligation would be on materially the same terms as described under the 2004 Registration Rights Agreement.

We will not be required to file a registration statement with the SEC covering the shares of our Common Stock to be issued to the holders of Triad stock until 180 days after the closing of the Triad acquisition. Such holders collectively would be prohibited from selling, within any 90-day period commencing on such 180^th day, more than 33.3% of the total number of shares issued to them. To the extent that the holders sell less than 33.3% in a given 90-day period, they would have the right to carry over and sell such additional amount in a subsequent period. To the extent we are required to exercise a Cutback Right, the holders will be treated within the same group as the holders of Common Stock subject to the 2004 Registration Rights Agreement.

Registration of our shares pursuant to the exercise of demand registration rights or piggyback registration rights under the Securities Act will result in such shares becoming freely tradeable without restriction under the Securities Act immediately upon the effectiveness of the registration. We have agreed to pay all registration expenses, other than underwriting discounts and commissions and other selling expenses, in connection with any such registration.

The foregoing is a summary of all material provisions of each registration rights agreement, but as a summary, is not a complete discussion of all provisions of that agreement. A copy of each registration rights agreement has been filed or incorporated by reference as an exhibit to the registration statement of which this prospectus is a part.

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UNDERWRITING

Under the terms and subject to the conditions contained in an underwriting agreement dated the date of this prospectus, the underwriters named below, for whom Morgan Stanley & Co. Incorporated is acting as representative, have severally agreed to purchase, and we and the selling shareholder have agreed to sell to them, severally, the number of shares indicated below.

Name	Number of Shares
Morgan Stanley & Co. Incorporated		2,240,000
Bear, Stearns & Co. Inc.		630,000
Raymond James & Associates, Inc.		315,000
Wachovia Capital Markets, LLC		315,000
Total		3,500,000

 

The underwriters and the representative are referred to as the “underwriters” and the “representative”, respectively. The underwriters are offering the shares of common stock subject to their acceptance of the shares from each of us and the selling shareholder and subject to prior sale. The underwriting agreement provides that the obligations of the several underwriters to pay for and accept delivery of the shares of common stock offered by this prospectus are subject to the approval of certain legal matters by their counsel and to certain other conditions. The underwriters are obligated to take and pay for all of the shares of common stock offered by this prospectus if any such shares are taken. However, the underwriters are not required to take or pay for the shares covered by the underwriters’ over-allotment option described below.

The underwriters initially propose to offer part of the shares of common stock directly to the public at the public offering price listed on the cover page of this prospectus and part to certain dealers at a price that represents a concession not in excess of $1.2675 a share under the public offering price. After the initial common stock offering, the offering price and other selling terms may from time to time be varied by the representative.

We have granted to the underwriters an option, exercisable for 30 days from the date of this prospectus, to purchase up to an aggregate of 525,000 additional shares of common stock at the public offering price listed on the cover page of this prospectus, less underwriting discounts and commissions. The underwriters may exercise this option solely for the purpose of covering over-allotments, if any, made in connection with the offering of the shares of common stock offered by this prospectus. To the extent the option is exercised, each underwriter will become obligated, subject to certain conditions, to purchase about the same percentage of the additional shares of common stock as the number listed next to the underwriter’s name in the preceding table bears to the total number of shares of common stock listed next to the names of all underwriters in the preceding table. If the underwriters’ option is exercised in full, the total price to the public would be $130,812,500, the total underwriters’ discounts and commissions would be $8,502,812.50 and total proceeds to us and the selling shareholder would be $61,534,687.50 and $60,775,000, respectively.

The following table shows the total underwriting discounts and commissions to be paid to the underwriters by us and the selling shareholder for the common stock. These amounts are shown assuming both no exercise and full exercise of the option of the underwriters to purchase up to an additional 525,000 shares of common stock.

	Per Share				Total
	No Exercise		Full Exercise		No Exercise		Full Exercise
Underwriting discounts and commissions paid by us	$	2.1125	$	2.1125	$	3,168,750	$	4,277,812.50
Underwriting discounts and commissions paid by the selling shareholder	$	2.1125	$	2.1125	$	4,225,000	$	4,225,000

 

Each of us and our directors, executive officers and certain of our other shareholders, and the selling shareholder has agreed that, without the prior written consent of Morgan Stanley & Co. Incorporated on behalf of the

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underwriters, subject to the exceptions described below, it and they will not, during the period ending 180 days after the date of this prospectus:

• offer, pledge, sell, contract to sell, sell any option or contract to purchase, purchase any option or contract to sell, grant any option, right or warrant to purchase, lend or otherwise transfer or dispose of directly or indirectly, any shares of common stock or any securities convertible into or exercisable or exchangeable for common stock, referred to as common stock rights; or

• enter into any swap or other arrangement that transfers to another, in whole or in part, any of the economic consequences of ownership of the common stock,

whether any transaction described above is to be settled by delivery of common stock or such other securities, in cash or otherwise.

The restrictions described in the above paragraph do not apply to:

• the sale of shares of common stock to the underwriters pursuant to this offering;

• the issuance by us of shares of common stock pursuant to the exercise of an option or similar security;

• transactions by any person other than us relating to shares of our common stock acquired in open market transactions after completion of this offering;

• transfers of shares of common stock as a bona fide gift or as a result of testate, intestate succession or bona fide estate planning; transfers of shares to a trust, partnership, limited liability company or other entity, all of the beneficial ownership interests of which are held by the transferor; or distributions of shares to limited partners or shareholders of the transferor, in each case provided that the transferee or distributee agrees to be bound by the restrictions described in the previous paragraph;

• the issuance of any shares in connection with the Triad acquisition; or

• the transfer of shares to us solely to satisfy tax withholding obligations incurred as a result of the vesting of restricted stock.

The 180-day restricted period described above is subject to extension such that, in the event that either (1) during the last 17 days of the 180-day restricted period we issue an earnings release or material news or a material event relating to us occurs, or (2) prior to the expiration of the 180-day restricted period, we announce that we will release earnings results during the 16-day period beginning on the last day of the 180-day period, the “lock-up” restrictions described above will continue to apply until the expiration of the 18-day period beginning on the earnings release or the occurrence of the material news or material event.

In order to facilitate the offering of the common stock, the underwriters may engage in transactions that stabilize, maintain or otherwise affect the price of the common stock. Specifically, the underwriters may over-allot in connection with the offering, creating a short position in the common stock for their own account. A short sale is covered if the short position is no greater than the number of shares available for purchase by the underwriters under their over-allotment option to purchase additional shares. The underwriters can close out a covered short sale by exercising their option to purchase additional shares or purchasing the shares in the open market. In determining the source of shares to close out a covered short sale, the underwriters will consider, among other things, the open market price of shares compared to the price available under the over-allotment option. The underwriters may also sell common stock in excess of the over-allotment option, creating a naked short position. The underwriters must close out any naked short position by purchasing common stock in the open market. A naked short position is more likely to be created if an underwriter is concerned that there may be downward pressure on the price of the common stock in the open market after pricing that could adversely affect investors who purchase in the offering. In addition, to cover over-allotments or to stabilize the price of the common stock, the underwriters may bid for, and purchase, shares of common stock in the open market. Finally, the underwriting syndicate may reclaim selling concessions allowed to an underwriter or a dealer for distributing the common stock in the offering, if the syndicate repurchases previously distributed common stock in transactions to cover syndicate short positions, in stabilization transactions or otherwise. Any of these activities may stabilize or maintain the market price of the common stock above

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independent market levels. The underwriters are not required to engage in these activities, and may end any of these activities at any time.

We estimate that the total expenses of the offering, excluding underwriting discounts and commissions, will be approximately $800,000.

From time to time, certain of the underwriters have provided, and may continue to provide, various financial advisory or investment banking services to us. The underwriters are also acting as underwriters with respect to the offering of our senior notes due 2012 being conducted concurrently with this offering. PNC Bank, National Association and Morgan Stanley Senior Funding, Inc. are joint lead arrangers, under our proposed new senior secured credit facility, PNC Bank, National Association is acting as administrative agent and Morgan Stanley Senior Funding, Inc. is acting as syndication agent.

We and the selling shareholder have agreed to indemnify the underwriters against certain liabilities, including liabilities under the Securities Act.

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LEGAL MATTERS

The validity of the issuance of the shares of common stock offered hereby has been passed upon for us by Kilpatrick Stockton LLP, Atlanta, Georgia. As of the date hereof, no attorneys with Kilpatrick Stockton LLP who worked on the preparation of this prospectus beneficially own any shares of the common stock.

The underwriters have been represented in connection with this offering by Cravath, Swaine & Moore, LLP, New York, New York.

EXPERTS

The consolidated balance sheets of James River Coal Company and subsidiaries as of December 31, 2004 (Successor Company) and 2003 (Predecessor Company), and the related consolidated statements of operations, changes in shareholders’ equity (deficit) and comprehensive income (loss), and cash flows for the eight months ended December 31, 2004 (Successor Company), the four months ended April 30, 2004 (Predecessor Company), and the years ended December 31, 2003 and 2002 (Predecessor Company), have been included herein and in the registration statement in reliance upon the report of KPMG LLP, independent registered public accounting firm, appearing elsewhere herein, and upon the authority of said firm as experts in accounting and auditing. The report dated March 25, 2005 includes explanatory paragraphs that state that (1) in connection with the Company’s emergence from Chapter 11, all assets and liabilities were restated to their respective fair values as of May 6, 2004 in order to reflect the effects of fresh start accounting and, as a result, the consolidated financial statements of the Successor Company are presented on a different basis than those of the Predecessor Company and, therefore, are not comparable and (2) the Company changed its method of accounting for reclamation liabilities and its method of accounting for redeemable preferred stock in 2003.

The consolidated financial statements of Triad Mining, Inc. and subsidiary as of December 31, 2004, and for the year then ended, have been included herein and in the registration statement in reliance upon the report of KPMG LLP, independent registered public accounting firm, appearing elsewhere herein, and upon the authority of said firm as experts in accounting and auditing.

The information appearing in this prospectus concerning estimates of the proven and probable coal reserves for us, as of March 31, 2004, and for Triad, as of February 1, 2005, was prepared by Marshall Miller & Associates, Inc. and has been included herein upon the authority of this firm as an expert.

WHERE YOU CAN FIND MORE INFORMATION

This prospectus is part of a registration statement on Form S-1 that we have filed with the SEC covering the shares of common stock being offered. This prospectus does not contain all of the information presented in the registration statement, and you should refer to that registration statement with its exhibits for further information. You may read and copy any document we file at the SEC’s public reference room at 450 Fifth Street, N.W., Washington, D.C. 20549 or 175 Jackson Boulevard, Suite 900, Chicago, Illinois 60604. Please call the SEC at 1-800-SEC-0330 (1-800-732-0330) for further information on the public reference room. You can also obtain copies of these materials from the public reference section of the SEC at 450 Fifth Street, N.W., Washington, D.C. 20549, at prescribed rates. You can also inspect our registration statement on the Internet at the SEC’s web site, http://www.sec.gov.

We are required to file annual, quarterly, and current reports, proxy and information statements and other information with the SEC. You can review this information at the SEC’s Public Reference Room or on the SEC’s web site, as described above.

118

INDEX TO OUR CONSOLIDATED FINANCIAL STATEMENTS

	Page
Audited Financial Statements
Report of Independent Registered Public Accounting Firm		F-2
Consolidated Balance Sheets as of December 31, 2004 (Successor) and December 31, 2003 (Predecessor)		F-3
Consolidated Statements of Operations for the eight months ended December 31, 2004 (Successor), the four months ended April 30, 2004 (Predecessor) and the years ended December 31, 2003 (Predecessor) and 2002 (Predecessor)		F-5
Consolidated Statements of Changes in Shareholders’ Equity (Deficit) and Comprehensive Income (Loss) for the eight months ended December 31, 2004 (Successor), the four months ended April 30, 2004 (Predecessor) and the years ended December 31, 2003 (Predecessor) and 2002 (Predecessor)		F-6
Consolidated Statements of Cash Flows for the eight months ended December 31, 2004 (Successor), the four months ended April 30, 2004 (Predecessor) and the years ended December 31, 2003 (Predecessor) and 2002 (Predecessor)		F-7
Notes to Consolidated Financial Statements		F-8
Unaudited Financial Statements
Condensed Consolidated Balance Sheets as of March 31, 2005 and December 31, 2004 (Successor)		F-35
Condensed Consolidated Statements of Operations for the three months ended March 31, 2005 (Successor) and March 31, 2004 (Predecessor)		F-37
Condensed Consolidated Statements of Changes in Shareholders’ Equity (Deficit) and Comprehensive Income (Loss) for the three months ended March 31, 2005 (Successor), eight months ended December 31, 2004 (Successor) and four months ended April 30, 2004 (Predecessor)		F-38
Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2005 (Successor) and March 31, 2004 (Predecessor)		F-39
Notes to Condensed Consolidated Financial Statements		F-40

 

F-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors
James River Coal Company:

We have audited the accompanying consolidated balance sheets of James River Coal Company and subsidiaries as of December 31, 2004 (Successor Company) and 2003 (Predecessor Company), and the related consolidated statements of operations, changes in shareholders’ equity (deficit) and comprehensive income (loss), and cash flows for the eight months ended December 31, 2004 (Successor Company), the four months ended April 30, 2004, and the years ended December 31, 2003 and 2002 (Predecessor Company). These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audits.

We conducted our audits in accordance with the standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of James River Coal Company and subsidiaries as of December 31, 2004 (Successor Company) and 2003 (Predecessor Company), and the results of their operations and their cash flows for the eight months ended December 31, 2004 (Successor Company), the four months ended April 30, 2004, and the years ended December 31, 2003 and 2002 (Predecessor Company) in conformity with U.S. generally accepted accounting principles.

As described more fully in Notes 1 and 3 to the consolidated financial statements, the Company was reorganized under a plan of reorganization confirmed by the United States Bankruptcy Court for the Middle District of Tennessee, effective May 6, 2004. In connection with the Company’s emergence from Chapter 11, all assets and liabilities were restated to their respective fair values in order to reflect the effects of fresh start accounting. As a result of the application of fresh start accounting, the consolidated financial statements of the Successor Company are presented on a different basis than those of the Predecessor Company and, therefore, are not comparable in all respects.

As discussed in Notes 1(f) and 9(d) to the consolidated financial statements, the Company changed its method of accounting for reclamation liabilities and its method of accounting for redeemable preferred stock in 2003.

/s/ KPMG LLP

Richmond, Virginia
March 25, 2005

F-2

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS

(in thousands, except share data)	Successor		Predecessor
December 31,	2004		2003
Assets
Current assets:
Cash	$	3,879	$	4,890
Receivables:
Trade		23,871		17,631
Other		7,362		4,324
Total receivables		31,233		21,955
Inventories:
Coal		2,305		3,278
Materials and supplies		4,084		4,624
Total inventories		6,389		7,902
Prepaid royalties		4,358		8,417
Other current assets		6,337		4,742
Total current assets		52,196		47,906
Property, plant, and equipment, at cost:
Land		2,698		6,666
Mineral rights		162,577		216,336
Buildings, machinery and equipment		106,105		230,346
Mine development costs		5,729		11,208
Construction-in-progress		231		997
Total property, plant, and equipment		277,340		465,553
Less accumulated depreciation, depletion, and amortization		21,765		208,397
Property, plant and equipment, net		255,575		257,156
Restricted cash (note 1(c))		8,404		8,321
Other assets		11,651		4,906
Total assets	$	327,826	$	318,289

 

See accompanying notes to consolidated financial statements.

F-3

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS

(in thousands, except share data)	Successor			Predecessor
December 31,	2004			2003
Liabilities and Shareholders’ Equity (Deficit)
Current liabilities:
Current maturities of long-term debt (note 5)	$	2,700		$	—
Current installments of obligations under capital leases		388			613
Accounts payable		15,116			18,566
Accrued salaries, wages, and employee benefits		2,093			2,275
Workers’ compensation benefits		12,090			9,000
Black lung benefits		2,600			2,200
Accrued taxes		3,530			3,449
Other current liabilities		3,633			2,794
Total current liabilities		42,150			38,897
Long-term debt, less current maturities (note 5)		92,300			—
Other liabilities:
Noncurrent portion of workers’ compensation benefits		38,223			41,782
Noncurrent portion of black lung benefits		23,341			11,508
Pension obligations		15,744			14,315
Asset retirement obligations		14,939			13,674
Obligations under capital leases, excluding current installments		637			1,457
Deferred income taxes		34,615			—
Other		292			662
Total other liabilities		127,791			83,398
Liabilities subject to compromise		—			319,595
Total liabilities		262,241			441,890
Shareholders’ equity (deficit):
Preferred Stock, $1.00 par value. Authorized 10,000,000 shares		—			—
Common stock, $.01 par value. Authorized 100,000,000 shares; (40,000shares as of December 31, 2003); issued and outstanding 14,715,694shares (16,890 shares as of December 31, 2003)		147			—
Paid-in-capital		71,784			226
Deferred stock-based compensation		(7,540	)		—
Retained earnings (accumulated deficit)		1,151			(107,989	)
Subscribed shares		—			(821	)
Accumulated other comprehensive income (loss)		43			(15,017	)
Total shareholders’ equity (deficit)		65,585			(123,601	)
Commitments and contingencies (note 14)
Total liabilities and shareholders’ equity (deficit)	$	327,826		$	318,289

 

See accompanying notes to consolidated financial statements.

F-4

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS

	Successor			Predecessor
(in thousands, except per share data)	Eight Months Ended 12/31/04			Four Months Ended 04/30/04			Year Ended 12/31/2003			Year Ended 12/31/2002
Revenues	$	231,698		$	113,949		$	304,052		$	397,599
Cost of sales:
Cost of coal sold		190,926			89,294			278,939			344,222
Depreciation, depletion, and amortization		21,765			12,314			40,427			46,393
Total cost of sales		212,691			101,608			319,366			390,615
Gross profit (loss)		19,007			12,341			(15,314	)		6,984
Selling, general, and administrative expenses		11,412			5,023			19,835			19,994
Other operating expenses (note 15)		—			—			—			26,554
Total operating income (loss)		7,595			7,318			(35,149	)		(39,564	)
Interest expense		5,733			567			18,536			29,883
Interest income		(72	)		—			(144	)		(1,003	)
Miscellaneous income, net		(833	)		(331	)		(1,519	)		(1,222	)
Total other expense, net		4,828			236			16,873			27,658
Income (loss) before reorganization items and income tax expense		2,767			7,082			(52,022	)		(67,222	)
Reorganization items, net (note 16)		—			(100,907	)		7,630			—
Income (loss) before income taxes		2,767			107,989			(59,652	)		(67,222	)
Income tax expense (benefit)		791			—			(2,891	)		(8,125	)
Net income (loss) before cumulative effect of accounting change		1,976			107,989			(56,761	)		(59,097	)
Cumulative effect of accounting change (note 17)		—			—			(3,045	)		—
Net income (loss)		1,976			107,989			(59,806	)		(59,097	)
Preferred dividends (note 9(d))		—			—			(340	)		(680	)
Decrease in redemption amount of redeemable common stock (note 9(e))		—			—			—			8,798
Net income (loss) attributable to common shareholders	$	1,976		$	107,989		$	(60,146	)	$	(50,979	)
Earnings (loss) per common share (note 18)
Basic earnings (loss) per common share
Income (loss) before cumulative effect of accounting change	$	0.14		$	6,393.67		$	(3,380.78	)	$	(3,018.31	)
Cumulative effect of accounting change		—			—			(180.28	)		—
Net income (loss)	$	0.14		$	6,393.67		$	(3,561.06	)	$	(3,018.31	)
Shares used to calculate basic earnings (loss) per share		13,800			17			17			17
Diluted earnings (loss) per common share
Income (loss) before cumulative effect of accounting change	$	0.14		$	6,393.67		$	(3,380.78	)	$	(3,018.31	)
Cumulative effect of accounting change		—			—			(180.28	)		—
Net income (loss)	$	0.14		$	6,393.67		$	(3,561.06	)	$	(3,018.31	)
Shares used to calculate dilutive earnings (loss) per share		14,623			17			17			17

 

See accompanying notes to consolidated financial statements.

F-5

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY

(in thousands)	Common stock		Paid-in- capital			Deferred stock-based Compensation			Retained earnings (accumulated deficit)			Subscribed shares			Accumulated other comprehensive income (loss)			Total
Predecessor Company
Balances, December 31, 2001	$	—		226			—			3,137			(1,403	)		(10,995	)		(9,035	)
Net loss		—		—			—			(59,097	)		—			—			(59,097	)
Minimum pension liability adjustment		—		—			—			—			—			(7,546	)		(7,546	)
Change in fair value of cash flow hedges		—		—			—			—			—			(1,663	)		(1,663	)
Comprehensive loss		—		—			—			—			—			—			(68,306	)
Payments on subscribed shares		—		—			—			—			497			—			497
Preferred dividends		—		—			—			(680	)		—			—			(680	)
Change in redemption amount of redeemable common stock		—		—			—			8,797			—			—			8,797
Balances, December 31, 2002		—		226			—			(47,843	)		(906	)		(20,204	)		(68,727	)
Net loss		—		—			—			(59,806	)		—			—			(59,806	)
Minimum pension liability adjustment																(1,194	)		(1,194	)
Reclassification to interest expense, net of taxes of $2,890		—		—			—			—			—			6,381			6,381
Comprehensive loss																			(54,619	)
Forgiveness of receivable for subscribed shares		—		—			—			—			85			—			85
Preferred dividends		—		—			—			(340	)		—			—			(340	)
Balances, December 31, 2003		—		226			—			(107,989	)		(821	)		(15,017	)		(123,601	)
Net income		—		—			—			107,989			—			—			107,989
Minimum pension liability adjustment		—		—			—			—			—			(692	)		(692	)
Comprehensive income																			107,297
Application of fresh start accounting (note 3)
Cancellation of Predecessor common stock		—		(226	)		—			—			—			—			(226	)
Elimination of Predecessor accumulated other comprehensive loss and subscribed shares		—		—			—			—			821			15,709			16,530
Balances, April 30, 2004		—		—			—			—			—			—			—
Successor Company
Issuance of Successor common stock		138		63,153			—			—			—			—			63,291
Net income		—		—			—			1,976			—			—			1,976
Unrealized gain on marketable securities, net		—		—			—			—			—			43			43
Comprehensive Income																			2,019
Deferred compensation related to restricted stock awards		9		8,631			(8,640	)					—			—			—
Cost to register common stock		—		—			—			(825	)		—			—			(825	)
Amortization of deferred stock-based compensation		—		—			1,100			—			—			—			1,100
Balances, December 31, 2004	$	147		71,784			(7,540	)		1,151			—			43			65,585

 

See accompanying notes to consolidated financial statements.

F-6

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS

	Successor			Predecessor
(in thousands, except share data)	Eight Months Ended 12/31/04			Four Months Ended 04/30/04			Year Ended 12/31/2003			Year Ended 12/31/2002
Cash flows from operating activities:
Net income (loss)	$	1,976			107,989			(59,806	)		(59,097	)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation, depletion, and amortization of property, plant, and equipment		21,765			12,314			40,692			46,664
Accretion of asset retirement obligations		807			397			1,128			—
Amortization of debt issue costs		275			—			—			5,750
Amortization of deferred stock-based compensation		1,100			—			—			—
Deferred income tax expense (benefit)		766			—			(2,891	)		(3,146	)
Gain (loss) on sale or disposal of property, plant, and equipment		(36	)		19			(23	)		18,881
Gain on sale of investment		—			—			(999	)		—
Provision for severance costs		—			—			—			2,879
Fresh start accounting adjustment		—			(111,533	)		—			—
Non-cash reorganization items		—			10,010			796			—
Cumulative effect of change in accounting principle		—			—			3,045			—
Realized loss on termination of interest rate swap agreement		—			—			9,272			—
Unrealized gain on interest rate swap		—			—			(949	)		111
Changes in operating assets and liabilities:
Receivables		4,604			(12,882	)		4,193			7,019
Inventories		6,619			(4,028	)		(233	)		2,226
Prepaid royalties and other current assets		3,093			(1,236	)		991			1,691
Other assets		(7,001	)		132			661			(656	)
Accounts payable		(11,177	)		(2,921	)		15,016			2,684
Accrued salaries, wages, and employee benefits		(2,408	)		1,429			(818	)		(1,169	)
Accrued taxes		(58	)		139			(651	)		(1,196	)
Other current liabilities		(404	)		1,535			6,574			3,880
Workers’ compensation benefits		(1,886	)		1,417			5,770			2,574
Black lung benefits		(830	)		(547	)		(630	)		(347	)
Pension obligations		(1,887	)		(609	)		2,906			451
Asset retirement obligation		(477	)		(108	)		(978	)		(164	)
Other liabilities		(743	)		(4	)		(33	)		(136	)
Net cash provided by operating activities		14,098			1,513			23,033			28,899
Cash flows from investing activities:
Additions to property, plant, and equipment		(25,811	)		(9,521	)		(20,116	)		(22,925	)
Proceeds from sale of property and equipment		4,123			86			179			—
Proceeds from sale of investment		—			—			2,000			—
(Increase) decrease in restricted cash		(56	)		(28	)		2,277			(10,597	)
Net cash used in investing activities		(21,744	)		(9,463	)		(15,660	)		(33,522	)
Cash flows from financing activities:
Proceeds from issuance of long-term debt		20,000			—			—			3,373
Proceeds from (repayments of) short-term borrowings		(6,400	)		6,400			(1,940	)		(74	)
Common stock registration costs		(825	)		—						—
Principal payments under capital lease obligations		(370	)		(165	)		(549	)		(449	)
Debt issuance costs		(2,181	)		(1,874	)		—			—
Proceeds from issuance of common stock and payments on subscribed shares		—			—			—			497
Net cash provided by (used in) financing activities		10,224			4,361			(2,489	)		3,347
Increase in cash		2,578			(3,589	)		4,884			(1,276	)
Cash at beginning of period		1,301			4,890			6			1,282
Cash at end of period	$	3,879			1,301			4,890			6

 

See accompanying notes to consolidated financial statements.

F-7

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(1)   SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND OTHER INFORMATION

(a)   Description of Business and Principles of Consolidation

The Company mines, processes and sells bituminous, low sulfur, steam- and industrial-grade coal through five operating subsidiaries located throughout Eastern Kentucky. Substantially all coal sales and accounts receivable relate to the electric utility and industrial markets.

The consolidated financial statements include the accounts of James River Coal Company and its wholly owned subsidiaries. All significant intercompany accounts and transactions have been eliminated in consolidation.

(b)   Bankruptcy and Restructuring

On March 25, 2003, James River Coal Company and subsidiaries (the Company) filed a voluntary petition for relief under Chapter 11 with the United States Bankruptcy Court for the Middle District of Tennessee. Under Chapter 11, certain claims against the Company in existence prior to the filing of the petition for relief were stayed while the Company continued business operations as Debtor-in-possession. These claims are reflected in the December 31, 2003 balance sheet as Liabilities Subject to Compromise.

On April 21, 2004 the United States Bankruptcy Court for the Middle District of Tennessee confirmed the Company’s Plan of Reorganization (the Plan). The Plan of Reorganization became effective May 6, 2004 (the Effective Date) which is the date on which the Company formally emerged from Chapter 11. As part of the Plan, the Company canceled the existing equity securities, extinguished approximately $266,000 in debt, accrued interest, and the terminated interest rate swap liability under existing credit facilities in exchange for a restructured term loan of $75,000, which is secured by a second lien on substantially all the Company’s assets, and 13,799,994 shares of new common stock, par value $0.01 per share, which were distributed on a pro-rata basis to the holders of the pre-petition credit facilities. Pursuant to the Plan, the Company’s unsecured creditors claims were discharged and terminated.

On the Effective Date, the Company entered into a new $50,000 loan and security agreement which is comprised of a $20,000 term loan and a $30,000 revolving credit facility (see Note 5). The Company borrowed $20,000 under the term loan component to make cash payments to satisfy certain claims, administrative expenses, and retire obligations under the debtor-in-possession credit facility required to be paid under the Plan. The remaining $30,000 revolving credit facility is available for the Company’s working capital requirements, general, and letter of credit needs, and is subject to customary borrowing conditions.

The Company’s accompanying consolidated financial statements for the four months ended April 20, 2004 and for the year ended December 31, 2003 have been prepared in accordance with the American Institute of Certified Public Accountants’ Statement of Position 90-7, Financial Reporting by Entities in Reorganization under the Bankruptcy Code (SOP 90-7), which provides guidance for financial reporting by entities that have filed petitions under Bankruptcy. As a result, all assets and liabilities were restated to reflect their respective fair values. Although the Effective Date of the Plan of Reorganization was May 6, 2004, the consummation of the Plan of Reorganization has been reflected as of April 30, 2004, the end of the Company’s most recent fiscal month prior to the Effective Date. The consolidated financial statements after emergence are those of a new reporting entity (the Successor) and are not comparable to the consolidated financial statements of the pre-emergence Company (the Predecessor). A black line has been drawn in the financial statements to distinguish Predecessor and Successor financial information. See notes 3, 6 and 16 for further discussion.

The historical consolidated financial statements for 2002 do not reflect the effects resulting from the Company filing Chapter 11. As such, the statements for 2002 do not reflect the results of implementing SOP 90-7.

F-8

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(c)   Restricted Cash

As of December 31, 2004 and 2003, $8,404 and $8,321, respectively, of the Company’s cash was restricted as to its use. Restrictions are imposed by the Company’s bank relating to a letter of credit issued to one of the Company’s insurers (see note 14).

(d)   Trade Receivables

Trade receivables are recorded at the invoiced amount and do not bear interest. The Company evaluates the need for an allowance for doubtful accounts based on review of historical write off experience and industry data. The Company has determined that no allowance is necessary for trade receivables as of December 31, 2004 and 2003. The Company does not have any off-balance sheet credit exposure related to its customers.

(e)   Inventories

Inventories of coal and materials and supplies are stated at the lower of cost or market. Cost is determined using the average cost for coal inventories and the first-in, first-out method for materials and supplies. Coal inventory costs include labor, supplies, equipment cost, depletion, royalties, black lung tax, reclamation tax and preparation plant cost. Coal is classified as inventory at the point and time that the coal is extracted and removed from the mine.

(f)   Reclamation Costs

Effective January 1, 2003, the Company adopted Financial Accounting Standards Board (FASB) Statement No. 143, Accounting for Asset Retirement Obligations. Statement No. 143 requires that asset retirement obligations be recorded as a liability based on fair value, which is calculated as the present value of the estimated future cash flows, in the period in which it is incurred. The estimate of ultimate reclamation liability and the expected period in which reclamation work will be performed is reviewed periodically by the Company’s management and engineers. In estimating future cash flows, the Company considers the estimated current cost of reclamation and applies inflation rates and a third party profit, as necessary. The third party profit is an estimate of the approximate markup that would be charged by contractors for work performed on behalf of the Company. When the liability is initially recorded, the offset is capitalized by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Accretion expense is included in cost of produced coal. To settle the liability, the obligation is paid, and to the extent there is a difference between the liability and the amount of cash paid, a gain or loss upon settlement is incurred. At December 31, 2004 and December 31, 2003, the Company had accrued $15,989 and $14,724, respectively, related to estimated mine reclamation costs.

F-9

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

The change in the reclamation obligation for the years ended December 31, 2004 and 2003 are as follows:

	12/31/2004			12/31/2003
Amount included in other current liabilities	$	1,050		$	1,405
Long term asset retirement obligations		13,674			6,319
Reclamation liability at beginning of year		14,724			7,724
Cumulative effect adjustment		—			6,849
Liabilities incurred in current period (Predecessor Company)		636			—
Accretion expense
Predecessor Company		398			1,128
Successor Company		806			—
Liabilities settled in current period
Predecessor Company		(131	)		(977	)
Successor Company		(454	)		—
Reclamation liability at end of year		15,979			14,724
Less amount included in other current liabilities		(1,040	)		(1,050	)
Total noncurrent liability	$	14,939		$	13,674

 

(g)   Property, Plant, and Equipment

Expenditures for maintenance and repairs are charged to expense, and the costs of mining equipment rebuilds and betterments that extend the useful life are capitalized. Depreciation is provided principally using the straight-line method based upon estimated useful lives, generally ten to 20 years for buildings and one to seven years for machinery and equipment. Equipment held under capital leases is amortized using the straight line method over the lesser of the lease term or the estimated useful life of the asset. Amortization of mineral rights is provided by the units of production method over estimated total recoverable proven and probable reserves.

(h)   Impairment of Long-Lived Assets

In accordance with Financial Accounting Standards Board (FASB) Statement No. 144, Accounting for the Impairment or Disposal of Long-Lived Assets, long-lived assets, such as property, plant, and equipment, and purchased intangibles subject to amortization, are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Recoverability of assets to be held and used is measured by a comparison of the carrying amount of an asset to estimated undiscounted future cash flows expected to be generated by the asset. If the carrying amount of an asset exceeds its estimated future cash flows, an impairment charge is recognized for the amount by which the carrying amount of the asset exceeds the fair value of the asset. The Company did not recognize any impairment charges during the eight months ended December 31, 2004, the four months ended April 30, 2004 or the years ended December 31, 2003 and 2002.

(i)   Mine Development Costs

Mine development costs are capitalized and amortized by the units of production method over estimated total recoverable proved and probable reserves.

F-10

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(j)   Prepaid Royalties

Mineral rights are often acquired in exchange for advance royalty payments. Royalty payments representing prepayments recoupable against future production are capitalized, and amounts expected to be recouped within one year are classified as a current asset. As mining occurs on these leases, the prepayment is offset against earned royalties and is included in the cost of coal sold. Amounts determined to be nonrecoupable are charged to expense.

(k)   Revenue Recognition

Revenues include sales to customers of Company-produced coal and coal purchased from third parties. The Company recognizes revenue from the sale of Company-produced coal and coal purchased from third parties at the time delivery occurs and title passes to the customer, which is either upon shipment or upon customer receipt of coal based on contractual terms. Also, the sales price must be determinable and collection reasonably assured.

(l)   Income Taxes

Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

(m)   Accumulated Comprehensive Gain (Loss)

The accumulated other comprehensive loss at December 31, 2003 represents the aggregate minimum pension liability adjustment. The accumulated other comprehensive gain at December 31, 2004 represents the aggregate unrealized gain on marketable securities.

(n)   Derivative Financial Instruments

The Company currently does not utilize any interest rate swaps, however, the Company has in the past utilized interest rate swaps to hedge the impact of changes in interest rates on its floating rate debt. Prior to January 1, 2003, the Company accounted for its interest rate swaps as cash flow hedges. Interest to be received or paid on the interest rate swaps was accrued monthly through March 2003 until the swap agreements were terminated (see note 5(e)).

Under the terms of these interest rate swaps, the Company was the fixed rate payor and the floating rate receiver. The fair value of the interest rate swaps was recorded on the consolidated balance sheets with changes in the fair value included in other comprehensive loss. Prior to January 1, 2003, to the extent the hedge was not completely effective, the ineffective portion was charged or credited to interest expense in the consolidated statements of operations. The ineffective portion charged to interest expense during the year ended December 31, 2002 was approximately $111. The amounts recorded in other comprehensive loss were subsequently reclassified into interest expense as a yield adjustment in the same period in which the related interest expense on the underlying debt affected results of operations.

F-11

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

Subsequent to December 31, 2002, the Company did not make the required monthly interest payments on the floating rate debt and the future forecasted interest payments were no longer probable. Accordingly, the hedge designation for the related interest rate swaps was discontinued effective January 1, 2003. As a result, the balance in accumulated other comprehensive loss related to the swaps as of that date was recorded as interest expense in 2003. An unrealized gain of approximately $949 representing subsequent changes in the fair value of the swaps was credited to interest expense in 2003.

(o)   Workers’ Compensation

The Company is liable for workers’ compensation benefits for traumatic injuries under state workers’ compensation laws in which it has operations. Subsequent to 2001, a portion of its workers’ compensation benefits are payable under a high-deductible, fully-insured workers’ compensation insurance policy. For claims incurred prior to 2002, the Company is self- insured, except for those claims incurred between 1979 and 1982, which are covered by a third party insurance company. Specific excess insurance with independent insurance carriers is in force to cover traumatic claims in excess of the self-insured limits.

The Company accrues for workers’ compensation benefits by recognizing a liability when it is probable that the liability has been incurred and the cost can be reasonably estimated. To assist in the determination of this estimated liability, the Company utilizes the services of third party administrators who develop claim reserves from historical experience. These third parties provide information to independent actuaries, who after review and consultation with the Company with regards to actuarial assumptions, including the appropriate discount rate, prepare an evaluation of the estimated liabilities for workers’ compensation benefits.

(p)   Black Lung Benefits

The Company is responsible under the Federal Coal Mine Health and Safety Act of 1969, as amended, and various states’ statutes for the payment of medical and disability benefits to employees and their dependents resulting from occurrences of coal worker’s pneumoconiosis disease (black lung). The Company provides for federal and state black lung claims through a self-insurance program. The Company uses the service cost method to account for its self-insured black lung obligation. The liability measured under the service cost method represents the discounted future estimated cost for former employees either receiving or projected to receive benefits, and the portion of the projected liability relating to prior service for active employees projected to receive benefits.

The periodic expense for black lung claims under the service cost method represents the service cost, which is the portion of the present value of benefits allocated to the current year, interest on the accumulated benefit obligation, and amortization of unrecognized actuarial gains and losses. The Company amortizes unrecognized actuarial gains and losses over the average remaining work life of the workforce.

Annual actuarial studies are prepared by independent actuaries using certain assumptions to determine the liability. The calculation is based on assumptions regarding disability incidence, medical costs, mortality, death benefits, dependents, and interest rates. These assumptions are derived from actual Company experience and industry sources.

(q)   Health Claims

The Company is self-insured for certain health care coverage. The cost of this self-insurance program is accrued based upon estimates of the costs for known and anticipated claims. The Company recorded an estimated amount to cover known claims and claims incurred but not reported of $1,144 and $1,013 as of December 31, 2004 and 2003, respectively, which is included in accrued salaries, wages, and employee benefits.

F-12

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(r)   Stock Plans

The Company accounts for stock-based compensation using the intrinsic value method prescribed by Accounting Principles Board (“APB”) Opinion No. 25, “Accounting for Stock Issued to Employees,” and related Interpretations. Accordingly, compensation cost for stock options granted to employees is measured as the excess, if any, of the quoted market price of the stock at the date of grant over the amount an employee must pay to acquire the stock. Compensation cost for stock appreciation rights and performance equity units is recorded based on the quoted market price of the Company’s stock at the end of the period. Stock-based compensation other than stock options is recorded to expense on a straight-line basis. The Company has implemented the disclosure-only provisions of FASB Statement No. 123 “Accounting for Stock-Based Compensation”. The Company has not recognized stock-based compensation expense related to stock options in any period as all options granted had an exercise price at least equal to the fair value of the underlying common stock on the date of the grant. The estimated fair value at grant dates for options granted during the eight months ended December 31, 2004 was less than $.01 per share. In performing the Statement No. 123 analysis for stock options, a risk free rate of 5% was assumed, expected volatility was zero, and no dividends were anticipated.

If the Company had followed the fair value method under FASB Statement No. 123 to account for stock based compensation cost for stock options, the amount of stock based compensation cost for stock options, net of related tax, which would have been recognized for each period and pro-forma net income for each period would have been as follows:

	Eight Months December 31, 2004
Net Income, as reported	$	1,976
Add: Net stock-based employee compensation expense recorded for restricted and performance based stock grants		785
Deduct: Net stock-based employee compensation expense for restricted and performance based stock determined under Black-Scholes option pricing model		(479	)
Pro forma net income	$	2,282
Income per share:
Basic—as reported	$	0.14
Basic—pro forma	$	0.17
Diluted—as reported	$	0.14
Diluted—pro forma	$	0.16

 

On December 16, 2004, the Financial Accounting Standards Board (“FASB”) issued Statement of Financial Accounting Standards No. 123 (revised 2004), “Share-Based Payment” (FAS 123R), which requires all public companies to measure compensation cost in the income statement for all share-based payments (including employee stock options) at fair value for interim or annual periods beginning after June 15, 2005. The Company intends to adopt FAS 123R on July 1, 2005 using the modified-prospective method. The Company has not completed its assessment of the impact of the adoption of this statement on its financial statements.

(s)   Use of Estimates

Management of the Company has made a number of estimates and assumptions relating to the reporting of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in order to prepare these consolidated financial statements in conformity with accounting principles generally accepted in the United States of America. Significant estimates made by management include the valuation allowance for deferred tax assets, accrued reclamation and mine closure costs and amounts accrued related to the Company’s workers’ compensation, black lung, and health claim obligations. Actual results could differ from these estimates.

F-13

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(3)   FRESH START ACCOUNTING

The Company implemented fresh start accounting and reporting in accordance with SOP 90-7 on April 30, 2004, the end of the Company’s most recent fiscal month prior to the Effective Date. Fresh start accounting requires that the reorganization value of the reorganized debtors be allocated to their assets in conformity with FASB Statement No. 141, Business Combinations, for transactions reported on the basis of the purchase method. The enterprise value (value of the net assets and liabilities excluding cash, debt, and capital leases) of the reorganized company was estimated to range from $145,000 to $165,000 based on a third-party valuation prepared in connection with the bankruptcy proceedings. For purposes of applying fresh start accounting, an enterprise value for the reorganized company of $155,000 was utilized.

The effects of the Plan and the application of fresh-start accounting on the Company’s pre-confirmation consolidated balance sheet include adjustments to record the gain on the debt extinguished under the plan and adjustments to record the assets of the Company at their estimated fair value and the liabilities of the Company at their estimated present values. The reorganization value was derived from the enterprise value for the reorganized company as follows:

Estimated enterprise value of the reorganized company	$	155,000
Borrowings under credit facility		(6,400	)
Capital leases assumed		(1,396	)
Cash balance excluded from enterprise value		1,301
Administrative claims payable excluded from enterprise value		(10,214	)
		138,291
Less: new secured debt issued to extinguish prepetition debt		75,000
Fair value of common shares issued to extinguish prepetition debt	$	63,291

 

	Fresh Start Adjustments
Assets	Predecessor Company 4/30/04		Debt Extinguishment			Reorganization Adjustments			Successor Company 4/30/04
Cash	$	1,301		—			—			1,301
Receivables		35,838		—			—			35,838
Inventories		11,930		—			1,079	(2)		13,009
Prepaid royalties		9,932		—			(362	)(2)		9,570
Other current assets		4,463		—			(347	)(2)		4,116
Total current assets		63,464		—			370			63,834
Land and mineral rights		223,004		—			(57,567	)(2)		165,437
Buildings, machinery, and equipment		236,901		—			(155,050	)(2)		81,851
Mine development costs		12,984		—			(12,984	)(2)		—
Construction-in-progress		974		—			—			974
		473,863		—			(225,601	)		248,262
Less accumulated depreciation, depletion, and amortization		219,604		—			(219,604	)(2)		—
Net property, plant, and equipment		254,259		—			(5,997	)		248,262
Restricted cash		8,348		—			—			8,348
Other long-term assets		6,518		(3,110	)(1)		(734	)(2)		2,674
Total assets	$	332,589		(3,110	)		(6,361	)		323,118

 

F-14

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

	Fresh Start Adjustments
Liabilities and Shareholders’ Equity (Deficit)	Predecessor Company 4/30/04			Debt Extinguishment			Reorganization Adjustments			Successor Company 4/30/04
Borrowings under DIP credit agreement	$	6,400			—			—			6,400
Current installments of obligations under capital leases		749			—			(272	)(3)		477
Accounts payable		26,293			—			—			26,293
Accrued salaries, wages and employee benefits		4,501			—			—			4,501
Workers’ compensation benefits		9,500			—			—			9,500
Black lung benefits		2,500			—			—			2,500
Accrued taxes		3,588			—			—			3,588
Other current liabilities		4,037			—			—			4,037
Total current liabilities		57,568			—			(272	)		57,296
Long term debt		—			75,000	(1)		—			75,000
Noncurrent portion of workers’ compensation benefits		42,699			—			—			42,699
Noncurrent portion of black lung benefits		10,661			—			13,610	(4)		24,271
Pension obligations		14,267			—			3,363	(5)		17,630
Asset retirement obligations		13,963			—			—			13,963
Obligations under capital leases, excluding current installments		1,159			—			(240	)(3)		919
Deferred income taxes		—			—			27,391	(6)		27,391
Other long term liabilities		658			—			—			658
Total other liabilities		83,407			—			44,124			127,531
Liabilities subject to compromise		319,451			(319,451	)(1)		—			—
Total liabilities		460,426			(244,451	)		43,852			259,827
Common stock		—			138	(1)		—			138
Paid-in-capital		226			63,153	(1)		(226	)(7)		63,153
Retained earnings (accumulated deficit)		(111,533	)		178,050	(1)		(66,517	)(7)		—
Subscribed shares		(821	)		—			821	(7)		—
Accumulated other comprehensive income (loss)		(15,709	)		—			15,709	(7)		—
Total shareholders’ equity (deficit)		(127,837	)		241,341			(50,213	)		63,291
Total liabilities and shareholders’ equity	$	332,589			(3,110	)		(6,361	)		323,118

 

F-15

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

The following is a description of the fresh start adjustments for debt extinguishment and reorganization adjustments:

Extinguishment of Debt

(1) Liabilities subject to compromise that were extinguished in bankruptcy consist of:

Pre-petition bank loan agreement	$	207,807
Pre-petition senior note		37,953
Accrued and unpaid interest		12,234
Terminated interest rate swap		8,434
Total secured		266,428
Promissory notes		5,176
Redeemable preferred stock		8,500
Accounts payable and other		39,347
Total unsecured		53,023
Total liabilities subject to compromise	$	319,451

 

The Company issued new common shares, new secured debt, and transferred its interest in specified life insurance policies held in a rabbi trust to the creditors in full satisfaction of pre-petition claims. The gain on extinguishment of pre-petition claims is calculated as follows:

Liabilities subject to compromise	$	319,451
Less: Assets of rabbi trust transferred to creditors		(3,110	)
Less: New secured debt issued in exchange for pre-petition debt		(75,000	)
Less: Fair value of common shares issued		(63,291	)
Gain on extinguishment of pre-petition claims	$	178,050

 

Reorganization Adjustments

(2) In connection with the application of fresh start accounting, the Company made adjustments aggregating approximately $6,361 to record its identifiable assets at fair value as follows:

	Increase/(Decrease)
Coal inventories	$	1,079
Prepaid royalties		(362	)
Other current assets		(347	)
Land and mineral rights		(57,567	)
Buildings, machinery and equipment		(155,050	)
Mine development costs		(12,984	)
Less accumulated depreciation, depletion, and amortization		219,604
Other long-term assets		(734	)
Total fair value adjustments to identifiable assets	$	(6,361	)

 

(3) Contractual terms of certain capital lease agreements were renegotiated during bankruptcy. Obligations under capital leases have been adjusted to reflect the revised terms.

(4) The liability for black lung benefits has been adjusted to reflect the total discounted benefit obligation.

(5) The pension liability has been adjusted to reflect the total discounted projected benefit obligation of the plan.

F-16

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(6) Deferred income taxes have been adjusted to reflect differences in the book and tax basis of the revalued assets and liabilities of the Company after application of fresh start accounting.

(7) The equity of the predecessor company, including subscribed shares and accumulated other comprehensive loss, has been eliminated in fresh start accounting.

(4)   OTHER CURRENT ASSETS

Other current assets at December 31, 2004 and 2003 are as follows:

	2004		2003
Prepaid insurance	$	3,535	$	3,107
Income tax receivable		2,575		—
Other		227		1,635
	$	6,337	$	4,742

 

(5)   LONG TERM DEBT, DIP FINANCING, AND INTEREST EXPENSE

Long-term debt at December 31, 2004 is as follows:

	December 31, 2004
Senior secured credit facility:
Term loan component	$	20,000
Revolver component		—
Term credit facility		75,000
Total long-term debt		95,000
Less amounts classified as current		2,700
Total long-term debt, less current maturities	$	92,300

 

Scheduled maturities of long-term debt are as follows:

Year ended December 31:
2005	$	2,700
2006		8,100
2007		9,600
2008		12,600
2009		16,500
Thereafter		45,500
Total Debt	$	95,000

 

(a)   Senior Secured Credit Facility

Effective May 6, 2004, the Company closed a $50,000 senior secured credit facility with Wells Fargo Foothill, Inc. (the Senior Secured Credit Facility). This facility was used to repay outstanding amounts and replace letters of credit previously issued under the $20,000 debtor-in-possession facility as discussed in note 5(c), to pay expenses associated with the exit from bankruptcy and to provide liquidity for general corporate purposes. The Senior Secured Credit Facility is comprised of a $30,000 revolver component (the Revolver) and a $20,000 term component. The

F-17

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

term loan was fully funded at closing. Borrowings under the Revolver bear interest at LIBOR +2.5% or the Base Rate (as defined in the credit agreement) +1.0%. Borrowings under the term component bear interest at LIBOR +5.25% or the Base Rate +3.85%. The Company’s interest rate was 7.53% at December 31, 2004. The term of the Senior Secured Credit Facility is five years. Principal payments on the term component of $900 per quarter commence on April 1, 2005 and continue through April 1, 2009, with the remaining principal balance due on May 6, 2009. Interest is payable in arrears, on the first day of each month on Base Rate borrowings while interest on LIBOR Rate borrowings is due on the last day of the LIBOR interest period. Advances under the Senior Secured Credit Facility are secured by a first priority lien on substantially all of the Company’s assets, and, except for the Term Credit Facility, the Company may not incur additional debt on the assets securing the Revolver. Advances under the Revolver may not exceed a borrowing base calculation derived as a percentage of eligible assets less outstanding letters of credit. Based on the Company’s eligible assets and letters of credit outstanding, the Company had no availability under the Revolver at December 31, 2004. The Senior Secured Credit Facility can be terminated with 90 days written notice by paying all outstanding principal and interest and making any prepayment premium payments due. The $30,000 Revolver has a prepayment premium of 2.5% of the total revolver commitment for the first year, declining to 2.0% for the second year, 1.5% for the third year and 0.5% for the fourth year. There is not a prepayment premium for the fifth year of the revolver component of the Senior Secured Credit Facility. The $20,000 term loan component has a prepayment premium of $200 (1.0%) if paid prior to April 30, 2007. There is no prepayment premium after April 30, 2007 for the term loan component. The Revolver has a commitment fee of .375% per annum on the unused portion reduced by outstanding letters of credit (note 14).

(b)   Term Credit Facility

The Company also entered into a $75,000 term credit facility with the Company’s pre-petition secured lenders (the Term Credit Facility) in partial satisfaction of its prepetition obligations, pursuant to the Plan of Reorganization. The Term Credit Facility has a term of seven years, accrues interest at 9%, and is secured by a second priority lien on substantially all of the Company’s assets. Except for the Senior Secured Credit Facility, the Company may not incur additional debt on the assets securing the Term Credit Facility. In addition, the Company may not incur any unsecured debt (other than normal trade payables) and may not incur more than $5,000 of recourse debt (including the Senior Secured Credit Facility and the Term Credit Facility). There is no scheduled amortization of this facility for the first two years. The notes require repayments of $1,500 per quarter beginning June 30, 2006 and increasing to $2,500 per quarter beginning June 30, 2008. All remaining principal and interest is due May 6, 2011. Borrowings under the Term Credit Facility may be prepaid without penalty.

(c)   Debtor-In-Possession Financing

On March 27, 2003, the Company entered into a Secured Super-Priority Debtor-In-Possession Revolving Credit Agreement (DIP Credit Agreement) with the lenders who are the parties to the Prepetition Credit Agreement. The DIP Credit Agreement provided, among other things, for a secured $20,000 revolving credit facility, a $5,000 swing loan facility and a $17,000 letter of credit facility. The combination of amounts drawn under the revolving credit, swing loan, and letter of credit facility could not exceed $20,000.

Amounts borrowed under the DIP Credit Agreement bore interest at a floating rate (based on the prime rate or the Federal Funds Rate), plus a margin of 2.5%. As security for the DIP Credit Agreement obligation the Company granted the lenders’ liens on all presently owned or hereafter acquired property and assets.

As of May 6, 2004, the Company had drawn $6,400 under the DIP Credit Agreement. There were no amounts outstanding under the DIP Credit Agreement as of December 31, 2003. There were $13,508 and $11,008 of letters of credit outstanding as of May 6, 2004 and December 31, 2003, respectively. The Company was charged a fee of 3% annually on letters of credits outstanding.

F-18

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

All outstanding amounts on the DIP Credit Agreement were repaid upon emergence from bankruptcy on May 6, 2004.

(d)   Interest Expense and Other

During the eight months ended December 31, 2004, the Company paid $5,536 in interest.

The Senior Secured Credit Facility and the Term Credit Facility contain financial covenants including a fixed charge coverage, a minimum leverage, minimum consolidated tangible net worth, minimum consolidated total annualized EBITDDA (as defined in each of the credit facilities), and maximum annual limits on capital expenditures. The Company was in compliance with all of the financial covenants for the Senior Secured Credit Facility and the Term Credit Facility as of December 31, 2004. The Company’s debt covenants also prohibit payment of cash dividends.

(e)   Prepetition Debt

Notes payable and debt at December 31, 2003 is as follows:

	2003
Bank Loan Agreement, revolving component	$	170,596
Bank Loan Agreement, term component		37,211
Senior Note, interest at 12.61%		37,953
Promissory note, interest at 5.32%		4,664
Promissory note, interest at 5.82%		512
Total notes payable and debt		250,936
Less amounts classified as liabilities subject to compromise (note 6)		250,936
Total long-term debt, less current maturities and debt in default	$	—

 

Until the date of filing of bankruptcy, the Company accrued interest. The Company determined that there was insufficient collateral to cover the interest portion of the scheduled payments on its prepetition debt obligation. As of the bankruptcy date the Company ceased accruing interest on the prepetition debt obligations. If such interest had continued to be accrued, interest expense for the four months ended April 30, 2004 and the year ended December 31, 2003 would have been approximately $7,639 and $16,270 higher than reported. During the four months ended April 30, 2004 and the years ended December 31, 2003 and 2002, the Company paid $273, $2,934 and $26,261, respectively, in interest.

At December 31, 2002, the Company was a party to interest rate swap agreements with a notional amount of $100,000, which required the Company to make fixed-rate interest payments in exchange for floating rate interest payments related to the Company’s Bank Loan Agreement. In 2003, the derivative instrument was terminated due to an event of default, and the balance due at the date of termination of approximately $8,434 is included in Liabilities Subject to Compromise as of December 31, 2003.

F-19

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(6)   LIABILITIES SUBJECT TO COMPROMISE

At December 31, 2003 Liabilities Subject to Compromise due to the Chapter 11 filing consist of the following:

Prepetition Bank Loan Agreement	$	207,807
Prepetition Senior Note		37,953
Accrued and unpaid interest		12,234
Terminated interest rate swap		8,434
Total secured		266,428
Promissory notes		5,176
Redeemable preferred stock		8,500
Accounts payable and other		39,491
Total unsecured		53,167
Total liabilities subject to compromise	$	319,595

 

(7)   WORKERS’ COMPENSATION BENEFITS

As of December 31, 2004 and 2003, workers’ compensation benefit obligation consisted of the following:

	2004		2003
Workers’ compensation benefits	$	50,313	$	50,782
Less current portion		12,090		9,000
Noncurrent portion of workers’ compensation	$	38,223	$	41,782

 

Actuarial assumptions used in the determination of the liability for the self-insured portion of workers’ compensation benefits included a discount rate of 5.25%, 5.5% and 6.75% at December 31, 2004, 2003 and 2002, respectively.

F-20

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(8)   PNEUMOCONIOSIS (BLACK LUNG) BENEFITS

As of December 31, 2004 and 2003, black lung benefits obligation consisted of the following:

	2004		2003
Black lung benefits	$	25,941	$	13,708
Less current portion		2,600		2,200
Noncurrent portion of black lung benefits	$	23,341	$	11,508

 

A reconciliation of the changes in the black lung obligation is as follows:

	2004			2003
Beginning of the year black lung obligation	$	13,708		$	22,528
Fresh Start adjustment (note 3)		13,610
Service cost:
Predecessor Company		99			350
Successor Company		221			—
Interest cost:
Predecessor Company		254			1,210
Successor Company		566			—
Actuarial loss:
Predecessor Company		261			6,269
Successor Company		2,789			—
Benefit payments:
Predecessor Company		(1,613	)		(3,039	)
Successor Company		(1,165	)		—
End of year accumulated black lung obligation		28,730			27,318
Unamortized actuarial loss		(2,789	)		(13,610	)
Accrued black lung obligation	$	25,941		$	13,708

 

The actuarial assumptions used in the determination of black lung benefits included a discount rate of 5.25%, 5.5% and 6.75% at December 31, 2004, 2003 and 2002, respectively.

F-21

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(9)   EQUITY

(a)   Preferred Stock and Shareholder Rights Agreement

The Company has authorized 10,000,000 shares of preferred stock, $1.00 par value, the rights and preferences of which are established by the Board of the Directors. The Company has reserved 500,000 of these shares as Series A Preferred Stock for issuance under a shareholder rights agreement (the “Rights Agreement”).

On May 25, 2004, the Company’s shareholders approved the Rights Agreement and declared a dividend of one preferred share purchase right (“Right”) for each two shares of common stock outstanding. Each Right entitles the registered holder to purchase from the Company one one-hundredth (1/100) of a share of our Series A Participating Cumulative Preferred Stock, par value $1.00 per share, at a price of $200 per one one-hundredth of a Series A preferred share. The Rights are not exercisable until a person or group of affiliated or associated persons (an “Acquiring Person”) have acquired or announced the intention to acquire 15% or more of the Company’s outstanding common stock.

In the event that the Company is acquired in a merger or other business combination transaction or 50% or more of the Company’s consolidated assets or earning power is sold after a person or group has become an Acquiring Person, each holder of a Right, other than the Rights beneficially owned by the Acquiring Person (which will thereafter be void), will receive, upon the exercise of the Right, that number of shares of common stock of the acquiring company which at the time of such transaction will have a market value of two times the exercise price of the Right. In the event that any person becomes an Acquiring Person, each Right holder, other than the Acquiring Person (whose Rights will become void), will have the right to receive upon exercise that number of shares of common stock having a market value of two times the exercise price of the Right.

The rights will expire May 25, 2014, unless that expiration date is extended. The Board of Directors may redeem the Rights at a price of $0.001 per Right at any time prior to the time that a person or group becomes an Acquiring Person.

(b)   Equity Based Compensation

Under the 2004 Equity Incentive Plan (the Plan), participants may be granted stock options (qualified and nonqualified), stock appreciation rights (“SARs”), restricted stock, restricted stock units, and performance shares. The total number of shares that may be awarded under the Plan is 1,650,000, and no more than 1,000,000 of the shares reserved under the Plan may be granted in the form of incentive stock options.

Shares awarded or subject to purchase under the Plan that are not delivered or purchased, or revert to the Company as a result of forfeiture or termination, expiration or cancellation of an award or that are used to exercise an award or for tax withholding, will be again available for issuance under the Plan. At December 31, 2004, 464,300 shares were available under the Plan for future awards.

Restricted Stock Awards

Pursuant to the Plan certain employees and directors have been awarded restricted common stock with such shares vesting over three or five years, respectively, or earlier under certain conditions. The related expense is amortized over the vesting period. Restricted shares subject to continuing vesting requirements are included in diluted shares outstanding. For the eight months ended December 31, 2004, the Company recognized $538 in compensation expense related to these shares.

F-22

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

Performance Stock Awards

Performance stock awards have been made to certain employees pursuant to the Plan. The number of shares of common stock to be received under these awards by such employees at the end of the performance period will depend on the attainment of performance objectives based on achieving certain financial results and the successful development of a new mine. The expected cost of these shares is reflected in income over the performance period. For the eight months ended December 31, 2004, the Company recorded $562 in compensation expense related to these shares. Since performance-based unvested stock is contingent upon satisfying conditions, those unvested shares are considered to be contingently issuable shares and are not included in the computation of diluted earnings per share.

Stock Options Awards

There were 270,000 stock options granted during the eight months ended December 31, 2004. The following table summarizes information about the stock options outstanding at December 31, 2004.

Range of Exercise Price	Outstanding Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Life (Years)
$10.80		150,000	$	10.80		4.3
$15.00–$17.50		120,000	$	16.70		3.8
$10.80–$17.50		270,000	$	13.41		4.1

 

The following is a summary of performance stock, restricted stock and stock option awards:

	Performance Stock				Restricted Stock					Stock Options
	Number of Shares		Estimated Fair Value at Issue		Number of Shares			Estimated Fair Value at Issue		Number of Shares		Weighted Average Exercise Price
Outstanding at April 30, 2004		—	$	—		—		$	—		—	$	—
Granted		100,000		4.59		839,000			4.59		270,000		13.41
Vested/Exercised		—		—		—			—		—		—
Canceled		—		—		(23,300	)		4.59		—		—
December 31, 2004		100,000	$	4.59		815,700		$	4.59		270,000	$	13.41

 

(c)   Stock Split

On September 30, 2004, the Board of Directors approved a two-for-one stock split of the Company’s common stock. The capital stock accounts and all share and earnings per share data, in this report give effect to the stock split, applied retroactively, to all periods presented for the Successor Company.

(d)   Redeemable Preferred Stock (Predecessor Company)

As of December 31, 2003, the Company had 8,500 shares of Class C, nonvoting, mandatorily redeemable preferred stock outstanding. The preferred shares had a par value of $1,000 per share and a dividend rate of 8%. The preferred stock outstanding was included in Liabilities Subject to Compromise at December 31, 2003.

F-23

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

On July 1, 2003, the Company adopted Statement No. 150, Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity, which required that dividends on redeemable preferred stock be reported as a financing cost in our consolidated statements of operations. Accordingly, preferred dividends of $227 for the four months ended April 30, 2004 and $340 for the year ended December 31, 2003, are included in interest expense in the consolidated statements of operations. Prior to the adoption of Statement No. 150, preferred dividends are shown separately as preferred dividends in the consolidated statements of operations.

The preferred stock was cancelled on May 6, 2004 in accordance with the terms of the Plan of Reorganization.

(e)   Redeemable Common Stock (Predecessor Company)

The Company had a put/call arrangement with a group of shareholders that owned 6,344 shares of the Company’s common stock at December 31, 2001. This arrangement gave these shareholders the right to require the Company to repurchase the shares for an amount per share as set forth in the underlying agreements. This put/call agreement was terminated in 2002. Changes in the redemption amount were included in net loss attributable to common shareholders.

(10)   INCOME TAXES

Income tax expense (benefit) consists of:

					Year Ended
	Eight Months Ended 12/31/2004		Four Months Ended 4/30/2004		2003			2002
Current:
Federal	$	25		—		—			(4,980	)
State		—		—		—			—
		25		—		—			(4,980	)
Deferred:
Federal		692		—		(2,528	)		(3,017	)
State		74		—		(363	)		(128	)
		766		—		(2,891	)		(3,145	)
	$	791		—		(2,891	)		(8,125	)

 

F-24

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

A reconciliation of income taxes computed at the statutory federal income tax rate to the expense (benefit) for income taxes included in the consolidated statements of operations is presented below:

							Year Ended
	Eight Months Ended 12/31/2004			Four Months Ended 4/30/2004			2003			2002
Federal income taxes at statutory rates		34.0	%		34.0	%		(34.0	)%		(34.0	)%
Percentage depletion		(42.0	)		(2.2	)		(0.5	)		(1.6	)
Other permanent items		12.3			—			—			—
Amortization of coal properties not deductible		—			—			0.8			0.9
Non-Taxable gain on debt discharge		—			(35.1	)		—			—
Non-deductible reorganization costs		—			3.3			—			—
Change in valuation allowance		23.8			—			28.5			21.2
State income taxes, net of federal		1.8			—			(0.4	)		(0.1	)
Other, net		(1.3	)		—			1.0			1.5
		28.6	%		—	%		(4.6	)%		(12.1	)%

 

As discussed in note 1(b), the Company emerged from Chapter 11 bankruptcy on May 6, 2004. Under provisions of certain federal and state income tax laws, emergence from bankruptcy will have the effect of substantially reducing the Company’s ability to utilize the net operating loss carryforwards during 2004 and eliminates most, if not all, future benefit associated with the net operating loss carryforwards and the alternative minimum tax credit carryforwards for 2005 and subsequent years. The income tax attributes of other assets may also be reduced. To the extent asset basis is reduced for tax purposes, depreciation, and amortization of assets will also be reduced and, as a result, a gain may be recognized (and, therefore more tax imposed) in conjunction with the disposition of such assets. The Company must generally reduce its tax attributes, such as NOLs, tax credits, capital loss carryforwards, and tax basis in its assets, by any cancellation of indebtedness (COI) income realized. This reduction is effective January 1, 2005.

The tax effects of temporary differences that give rise to significant portions of the deferred tax assets and deferred tax liabilities at December 31, 2004 and 2003 are presented below:

	2004			2003
Deferred tax assets:
Accruals for financial reporting purposes, principally workers’ compensation and black lung obligations	$	46,279		$	34,340
Alternative minimum tax credit carryforwards		5,450			5,425
Net operating loss carryforwards		55,631			56,213
Accumulated comprehensive income		26			7,162
Total gross deferred tax assets		107,386			103,140
Less valuation allowance		61,081			45,859
Net deferred tax asset		46,305			57,281
Deferred tax liabilities—property, plant and equipment, principally due to differences in depreciation, depletion and amortization		80,920			57,281
Net deferred tax asset (liability)	$	(34,615	)	$	—

 

F-25

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

At December 31, 2004, the Company has consolidated net operating loss carryforwards (NOLs) for federal income tax purposes of approximately $136,000, consolidated Kentucky net operating loss carryforwards of approximately $97,000 and a separate company limited federal net operating loss of approximately $13,000 which was obtained via a 1998 acquisition. These net operating loss carryforwards generate a combined federal and state tax benefit of approximately $55,600. In addition, the Company has alternative minimum tax credit carryforwards of approximately $5,450. The Company has fully reserved its NOLs and alternative minimum tax credits.

At December 31, 2004, the Company had a $61,081 valuation allowance recorded for the portion of the deferred tax assets that are not anticipated to be realizable in the future. The tax valuation allowance includes $14,600 recorded due to the impact of the Fresh Start Accounting Entries. In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon availability of the deferred tax assets and the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax planning strategies in making this assessment.

In addition to the $27,391 increase in the deferred tax liability that was originally recorded in connection with the fresh start accounting adjustment (see note 3), the Company recorded an additional increase in the deferred tax liability of $6,458 to adjust the fair values assigned to certain assets and liabilities for purposes of applying fresh start accounting.

During the years ended December 31, 2003 and 2002, the Company received income tax refunds of $4,980 and $5,677 and made no income tax payments. The Company made income tax payments of $2,600 and $0 for the eight months ended December 31, 2004 and the four months ended April 30, 2004, respectively.

(11)   EMPLOYEE BENEFIT PLANS

(a)   Defined Benefit Pension Plan

Substantially all employees of the Company who meet certain length of service requirements are covered by a qualified noncontributory defined benefit pension plan. The Company’s funding policy is to contribute annually an amount at least equal to the minimum funding requirements actuarially determined in accordance with the Employee Retirement Income Security Act of 1974.

The plan assets for the qualified defined benefit pension plan are held by an independent trustee. The plan’s assets include cash and cash equivalents, corporate and government bonds, preferred and common stocks. The Company has an internal investment committee that sets investment policy, selects and monitors investment managers and monitors asset allocation.

The investment policy for the pension plan assets includes the objectives of providing growth of capital and income while achieving a target annual rate of return of 8.0% over a full market cycle, approximately 5 to 7 years. Diversification of assets is employed to reduce risk. The target asset allocation is 70% for equity securities (including 45% Large Cap, 15% Small Cap, 10% International) and 30% for cash and interest bearing securities. The investment policy is based on the assumption that the overall portfolio volatility will be similar to that of the target allocation. Given the volatility of the capital markets, strategic adjustments in various asset classes may be required to rebalance asset allocation back to its target policy. Investment fund managers are not permitted to invest in certain securities and transactions as outlined by the investment policy statements specific to each investment category without prior investment committee approval.

To develop the expected long-term rate of return on assets assumption, the Company considered the historical returns and the future expectations for returns for each asset class, as well as the target asset allocation of the pension

F-26

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

portfolio. This evaluation resulted in the selection of the 8.0% long-term rate of return on assets assumption for the year ended December 31, 2004.

The fair value of the major categories of qualified defined benefit pension plan assets includes the following:

	2004					2003
	Amount		Percentage			Amount		Percentage
Equity securities	$	24,859		67.7	%	$	19,732		66.4	%
Debt securities		10,689		29.1	%		9,836		33.1	%
Other (includes cash and cash equivalents)		1,195		3.2	%		149		0.5	%
		36,743		100.0	%		29,717		100.0	%

 

The following table sets forth changes in the plan’s benefit obligations, changes in the fair value of plan assets, and funded status at December 31, 2004 and 2003:

	2004			2003
Change in benefit obligation:
Benefit obligation at beginning of year	$	48,522		$	41,013
Service cost		1,834			1,764
Interest cost		2,924			2,707
Actuarial loss		7,207			4,985
Benefits paid		(1,851	)		(1,947	)
Benefit obligation at end of year		58,636			48,522
Change in plan assets:
Fair value of plan assets at beginning of year		29,717			23,718
Actual return on plan assets		3,590			4,333
Employer contributions		5,287			3,613
Benefits paid		(1,851	)		(1,947	)
Fair value of plan assets at end of year		36,743			29,717
Reconciliation of funded status:
Funded status		(21,893	)		(18,805	)
Unrecognized actuarial loss		6,149			23,348
Unrecognized prior service cost		—			390
Net amount recognized		(15,744	)		4,933
Amounts recognized in the consolidated balance sheets consist of:
Accrued benefit liability		(15,744	)		(14,315	)
Intangible asset		—			390
Accumulated other comprehensive loss		—			18,858
Net amount recognized		(15,744	)		4,933

 

The accumulated benefit obligation of the plan was $52,446 and $44,032 as of December 31, 2004 and 2003, respectively. Company contributions in 2005 are expected to be approximately $5,046.

During Fresh Start Accounting (note 3), the Company adjusted the previously unrecognized actuarial loss and the previously unrecognized prior service costs to $0.

F-27

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

The components of net periodic benefit cost and the benefits paid by period are as follows:

	Successor			Predecessor
	Eight Months Ended 12/31/04			Four Months Ended 4/30/04			Year Ended 2003			Year Ended 2002
Service cost	$	1,223			611			1,764			1,583
Interest cost		1,959			965			2,707			2,444
Expected return on plan assets		(1,721	)		(811	)		(2,092	)		(2,122	)
Amortization of prior service cost		—			130			843			843
Recognized actuarial loss		—			340			1,178			670
Net periodic benefit cost	$	1,461			1,235			4,400			3,418
Benefits Paid	$	1,288			563			1,947

 

The weighted-average assumptions used in determining pension benefit obligations and pension expense are as follows:

	2004	2003	2002
Discount rate	5.50%	6.00%	6.75%
Expected return on plan assets	8.00%	8.00%	8.50%
Rate of compensation increase	4.00%	4.00%	4.00%
Measurement date	October 1, 2004	October 1, 2003	October 1, 2002

 

The following benefit payments are expected to be paid (based on the assumptions described above).

Year ended December 31:
2005	$	1,989
2006		2,122
2007		1,782
2008		1,982
2009		2,170
Thereafter		14,485

 

(b)   Savings and Profit Sharing Plan

All eligible employees of the Company may participate in the Company’s Savings and Profit Sharing Plan. Employees may contribute up to 15% of their salary to the Plan. The Company is required to match up to 3% of the employee’s salary and may also make an additional discretionary contribution. The Company recognized approximately $588, $253, $832 and $965 of expense relating to the Savings and Profit Sharing Plan for the eight months ended December 31, 2004, the four months ended April 30, 2004 and the years ended December 31, 2003 and 2002, respectively.

(c)   Nonqualified Retirement Plan

The Company sponsored a nonqualified plan that provided retirement benefits to certain officers to supplement benefits not provided under the qualified plan. The Company owned insurance policies designed to fund benefits under the nonqualified plan, which were placed in a Rabbi Trust. The cash surrender value of the life insurance policies totaled $3,132 at December 31, 2003. The Plan was terminated March 25, 2003.

F-28

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

The following table sets forth the benefit obligation of the nonqualified retirement plan at December 31, 2003:

	2003
Benefit obligation at beginning of year	$	4,244
Service cost		14
Interest cost		95
Actuarial (gain) loss		2,423
Benefits paid		(28	)
Benefits forfeited		(2,370	)
Benefit obligation at end of year	$	4,378

 

The components of net periodic benefit cost for the years ended December 31, 2003 and 2002 are as follows:

	2003			2002
Service cost	$	14		$	158
Interest cost		95			312
Amortization of prior service cost		28			111
Recognized actuarial loss		6			55
Recognized benefits forfeited		(2,371	)		—
Effect of plan termination		4,388			—
Net periodic benefit cost		2,160			636

 

The weighted-average assumptions used in determining pension benefit obligations and pension expense are as follows:

	2003			2002
Discount rate		6.00	%		6.75	%
Rate of compensation increase		4.00	%		4.00	%
Measurement date	March 25, 2003			October 1, 2002

 

As part of the Company’s Plan of Reorganization the assets of the Rabbi Trust were transferred to the unsecured creditors Liquidating Trust to pay unsecured creditors’ claims. Prior to the termination of the Plan, the Company recognized a gain on benefits forfeited by a Company employee as part of a settlement agreement. The Company also recorded an expense of $4,388 on March 25, 2003 when the Plan was terminated. The benefit obligation for the nonqualified plan is included in Liabilities Subject to Compromise at December 31, 2003.

(12)   MAJOR CUSTOMERS

In the eight months ended December 31, 2004, approximately 50% of revenues were from two customers, the largest of which represented 30% of revenues. In the four months ended April 30, 2004, approximately 54% of revenues were from two customers, the largest of which represented 31% of revenues. In 2003, approximately 73% of total revenues was from three customers, the largest of which represented 43% of revenues. In 2002, approximately 60% of revenues were from two customers, the largest of which represented 39% of coal revenues.

F-29

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(13)   LEASES

The Company is obligated under capital leases covering certain machinery and equipment that expire at various dates during the next three years. At December 31, 2004 and 2003, the gross amount of machinery and equipment and related accumulated amortization recorded under capital leases were as follows:

	2004		2003
Machinery and equipment	$	1,367		3,189
Less accumulated amortization		539		1,111
	$	828		2,078

 

Amortization of assets held under capital leases is included with depreciation expense. Future minimum lease payments under noncancelable operating leases (with initial or remaining lease terms in excess of one year) and future minimum capital lease payments as of December 31, 2004 are:

	Capital leases		Operating leases
Year ended December 31:
2005	$	459	$	605
2006		444		312
2007		239		240
2008		—		82
		1,142	$	1,239
Less amount representing interest (at 8.5%)		117
Present value of net minimum capital lease payments		1,025
Less current portion of obligations under capital leases		388
Obligations under capital leases, excluding current portion	$	637

 

The Company incurred rent expense on equipment and offices space of approximately $462, $278, $1,090, and $1,299 for the eight months ended December 31, 2004, the four months ended April 30, 2004 and the years ended December 31, 2003, and 2002, respectively.

(14)   COMMITMENTS AND CONTINGENCIES

Future minimum royalty commitments under coal lease agreements at December 31, 2004 were as follows:

	Royalty commitments
Year ended December 31:
2005	$	14,705
2006		15,919
2007		15,314
2008		14,512
2009 and thereafter		81,282
	$	141,732

 

F-30

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

Certain coal leases do not have set expiration dates but extend until completion of mining of all merchantable and mineable coal reserves. For purposes of this table, the Company generally assumed that minimum royalties on such leases will be paid for a period of ten years.

The Company has established irrevocable letters of credit totaling $29,960 as of December 31, 2004 to guarantee performance under certain contractual arrangements. The Company has letters of credit totaling $7,822 that are collateralized by restricted cash (see note 1(c)). The remaining letters of credit totaling $22,138 were issued under the Senior Secured Credit Facility and reduce the Company’s availability under the $30,000 revolver component. The Company is charged a fee of 2.5% annually on letters of credit outstanding.

The Company is involved in various claims and legal actions arising in the ordinary course of business. In the opinion of management, the ultimate disposition of these matters will not have a material adverse effect on the Company’s consolidated financial position, results of operations or liquidity.

(15)   OTHER OPERATING EXPENSES

For the year ended December 31, 2002, other operating expenses consist of the following:

Fixed asset disposals	$	9,111
Write off of mine development costs		7,664
Write off of prepaid royalties on abandoned properties		4,167
Write off of capitalized debt issuance costs for terminated transactions		4,062
Accrual for legal obligations		1,512
Other		38
	$	26,554

 

(16)   REORGANIZATION ITEMS, NET

Reorganization items consist of the following:

	Predecessor
	Four Months Ended 4/30/04			Year Ended 12/31/03
Professional fees and administrative expenses	$	10,685			8,399
Forgiveness of receivable for subscribed shares, including accrued interest		—			94
Gain on settlements of obligations, net		(111,533	)		(798	)
Interest income		(59	)		(65	)
	$	(100,907	)		7,630

 

Cash paid for reorganization items totaled $8,083, $1,208 and $9,882 for the eight months ended December 31, 2004, the four months ended April 30, 2004 and for the year ended December 31, 2003, respectively. The Company also received $900 during 2003 in a settlement of potential litigation related to collecting the remaining proceeds from the sale of mining property and retained royalty obligations in 1998.

F-31

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(17)   CUMULATIVE EFFECT OF ACCOUNTING CHANGE FOR RECLAMATION LIABILITIES

Effective January 1, 2003 the Company changed its method of accounting for reclamation liabilities in accordance with the provisions of Statement No. 143. As a result of adoption of Statement No. 143, the Company recognized an increase in total reclamation liability of $6,849. The Company recorded the related capitalized asset retirement costs by increasing property, plant and equipment, net of accumulated depreciation, by $3,804. The cumulative effect of the change on prior years resulted in a charge to operations of $3,045.

The pro forma effect of the application of Statement No. 143, as if Statement No. 143 had been applied retroactively, is presented below:

	2002
Net loss, as reported	$	(59,097	)
Pro forma net loss		(59,778	)

 

(18)   EARNINGS (LOSS) PER SHARE

Basic earnings (loss) per share is computed by dividing net income (loss) 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 and restricted common stock subject to continuing vesting requirements, pursuant to the treasury stock method.

The following table provides a reconciliation of the number of shares used to calculate basic and diluted earnings (loss) per share:

	Successor Company Eight Months Ended 12/31/04		Predecessor Company Four Months Ended 4/30/04		Predecessor Company Twelve Months Ended 12/31/03		Predecessor Company Twelve Months Ended 12/31/02
Weighted average number of common shares outstanding:
Basic		13,799,994		16,890		16,890		16,890
Effect of dilutive instruments		822,626		—		—		—
Diluted		14,622,620		16,890		16,890		16,890

 

On May 6, 2004 the Company emerged from bankruptcy under a joint plan of reorganization. On that date the Company cancelled all existing equity securities and issued 13,799,994 shares of new common stock, which were distributed pro-rata to the pre-petition secured creditors.

(19)   FAIR VALUE OF FINANCIAL INSTRUMENTS

The estimated fair value of financial instruments has been determined by the Company using available market information. As of December 31, 2004, except for long-term debt obligations, the carrying amounts of all financial instruments approximate their fair values due to their short maturities. The Company believes that the fair value of its outstanding debt approximates fair value at December 31, 2004 based on the timing of the issuance of these securities.

As a result of the Company’s financial difficulties and default on its debt obligations the Company was unable to estimate the fair value of its debt obligations at December 31, 2003.

F-32

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(20)   SUBSEQUENT EVENT

In March 2005, the Company signed a definitive agreement to acquire Triad Mining Inc. (“Triad”) for approximately $75 million, consisting of $64 million in cash and $11 million of Company common stock. Triad operates six surface mines and one underground mine in Southern Indiana.

(21)   QUARTERLY INFORMATION (UNAUDITED)

Set forth below is the Company’s quarterly financial information for the previous two fiscal years:

	Three Months Ended (1)
	March 31, 2004			June 30, 2004			September 30, 2004		December 31, 2004
Total revenue	$	80,858			97,576			89,881		77,332
Gross profit (loss)		5,879			18,099			8,276		(906	)
Income (loss) from operations		2,318			14,071			3,434		(4,910	)
Reorganization items gain (loss), net		(1,557	)		102,465			—		—
Income (loss) before taxes		411			115,650			1,780		(7,085	)
Net income (loss)		411			113,923			1,399		(5,768	)
Income per share (Basic and Diluted)	$	24.33			N/A	(2)		0.10		(0.42	)

 

	Three Months Ended (1)
	March 31, 2003			June 30, 2003			September 30, 2003			December 31, 2003
Total revenue	$	77,372			78,704			79,885			68,092
Gross loss		(6,375	)		(1,015	)		(950	)		(6,974	)
Loss from operations		(14,495	)		(5,003	)		(4,650	)		(11,000	)
Reorganization items gain (loss), net		—			(2,541	)		(2,471	)		(2,618	)
Loss before taxes		(31,022	)		(7,681	)		(7,414	)		(13,534	)
Loss before cumulative effect of accounting change		(28,131	)		(7,681	)		(7,414	)		(13,534	)
Net loss		(31,176	)		(7,681	)		(7,414	)		(13,534	)
Loss per share (Basis and Diluted):
Loss before cumulative effect of accounting change	$	(1,665.56	)		(464.85	)		(438.97	)		(801.33	)
Net loss	$	(1,845.84	)		(464.85	)		(438.97	)		(801.33	)

 

(1) The quarters ended in 2003 and the quarter ended March 31, 2004, represent the results of the Predecessor Company. The quarter ended June 30, 2004 includes the Predecessor Company for one month (April 2004) and the Successor Company for two months. The quarters ended September 30, 2004 and December 31, 2004 represent the results of the Successor Company. As discussed in Note 1, the consolidated financial statements of the Company after emergence from bankruptcy are those of a new reporting entity (the Successor) and are not comparable to the financial statements of the pre-emergence Company (the Predecessor).

F-33

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(In Thousands, Except Share Data)

(2) Information for the net income per share for the two months ended June 30, 2004 (Successor) and the one month ended April 30, 2004 (Predecessor) follows:

	Two Months Ended June 30, 2004		One Month Ended April 30, 2004
Total revenue	$	64,485		33,091
Gross profit (loss)		11,637		6,462
Income from operations		9,071		5,000
Reorganization items gain (loss), net		—		102,465
Income before taxes		8,072		107,578
Net income		6,345		107,578
Basic Earnings Per Share		0.46		6,369.32
Diluted Earning Per Share		0.43		6,369.32

 

F-34

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS

	March 31, 2005		December 31, 2004
	(Unaudited)
Assets
Current assets:
Cash	$	1,724		3,879
Receivables:
Trade		37,496		23,871
Other		2,928		7,362
Total receivables		40,424		31,233
Inventories:
Coal		5,500		2,305
Materials and supplies		4,446		4,084
Total inventories		9,946		6,389
Prepaid royalties		3,731		4,358
Other current assets		4,310		6,337
Total current assets		60,135		52,196
Property, plant, and equipment, at cost:
Land		2,745		2,698
Mineral rights		162,577		162,577
Buildings, machinery and equipment		114,597		106,105
Mine development costs		11,428		5,729
Construction-in-progress		706		231
Total property, plant, and equipment		292,053		277,340
Less accumulated depreciation, depletion, and amortization		31,272		21,765
Property, plant and equipment, net		260,781		255,575
Restricted cash (note 1(c))		8,425		8,404
Other assets		11,792		11,651
Total assets	$	341,133		327,826

 

See accompanying notes to condensed consolidated financial statements.

F-35

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS

	March 31, 2005			December 31, 2004
	(Unaudited)
Liabilities and Shareholders’ Equity
Current liabilities:
Current maturities of long-term debt (note 3)	$	3,600			2,700
Current installments of obligations under capital leases		374			388
Accounts payable		25,043			15,116
Accrued salaries, wages, and employee benefits		3,235			2,093
Workers’ compensation benefits		12,090			12,090
Black lung benefits		2,600			2,600
Accrued taxes		4,326			3,530
Other current liabilities		4,654			3,633
Total current liabilities		55,922			42,150
Long-term debt, less current maturities (note 3)		91,400			92,300
Other liabilities:
Noncurrent portion of workers’ compensation benefits		38,381			38,223
Noncurrent portion of black lung benefits		23,421			23,341
Pension obligations		15,206			15,744
Asset retirement obligations		15,129			14,939
Obligations under capital leases, excluding current installments		518			637
Deferred income taxes		34,569			34,615
Other		245			292
Total liabilities		274,791			262,241
Shareholders’ equity
Preferred Stock, $1.00 par value. Authorized 10,000,000 shares; none issued		—			—
Common stock, $.01 par value. Authorized 100,000,000 shares; issued and outstanding 14,740,694 and 14,715,694, respectively		147			147
Paid-in-capital		73,592			71,784
Deferred stock-based compensation		(8,900	)		(7,540	)
Retained earnings		1,460			1,151
Accumulated other comprehensive income		43			43
Total shareholders’ equity		66,342			65,585
Commitments and contingencies (note 5)
Total liabilities and shareholders’ equity	$	341,133			327,826

 

See accompanying notes to condensed consolidated financial statements.

F-36

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(in thousands, except per share data)
(unaudited)

	Successor			Predecessor
	Three Months Ended 03/31/05			Three Months Ended 03/31/04
Revenues	$	97,875			80,858
Cost of sales:
Cost of coal sold		80,942			65,707
Depreciation, depletion, and amortization		9,478			9,272
Total cost of sales		90,420			74,979
Gross profit		7,455			5,879
Selling, general, and administrative expenses		5,035			3,561
Total operating income		2,420			2,318
Interest expense (note 3)		2,186			403
Interest income		(21	)		—
Miscellaneous income, net		(123	)		(53	)
Total other expense, net		2,042			350
Income before reorganization items and income tax expense		378			1,968
Reorganization items, net (note 6)		—			1,557
Income before income taxes		378			411
Income tax expense		69			—
Net income attributable to common shareholders	$	309			411
Earnings per common share (note 7)
Basic earnings per common share	$	0.02			24.33
Shares used to calculate basic earnings per share		13,800			17
Diluted earnings per common share	$	0.02			24.33
Shares used to calculate diluted earnings per share		14,752			17

 

See accompanying notes to condensed consolidated financial statements.

F-37

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’
EQUITY (DEFICIT) AND COMPREHENSIVE INCOME (LOSS)
Three Months ended March 31, 2005 (Successor), eight months ended December 31, 2004 (Successor) and four months ended April 30, 2004 (Predecessor)

(in thousands)	Common stock		Paid-in- capital			Deferred stock-based Compensation			Retained earnings (accumulated deficit)			Subscribed shares			Accumulated other comprehensive income (loss)			Total
Predecessor Company
Balances, December 31, 2003	$	—		226			—			(107,989	)		(821	)		(15,017	)		(123,601	)
Net income		—		—			—			107,989			—			—			107,989
Minimum pension liability adjustment		—		—			—			—			—			(692	)		(692	)
Comprehensive income																			107,297
Application of fresh start accounting (note 2)
Cancellation of Predecessor common stock		—		(226	)		—			—			—			—			(226	)
Elimination of Predecessor accumulated other comprehensive loss and subscribed shares		—		—			—			—			821			15,709			16,530
Balances, April 30, 2004	$	—		—			—			—			—			—			—
Successor Company
Issuance of Successor common stock	$	138		63,153			—			—			—			—			63,291
Net income		—		—			—			1,976			—			—			1,976
Unrealized gain on marketable securities, net		—		—			—			—			—			43			43
Comprehensive Income																			2,019
Deferred compensation related to restricted stock awards		9		8,631			(8,640	)		—			—			—			—
Cost to register common stock		—		—			—			(825	)		—			—			(825	)
Amortization of deferred stock-based compensation		—		—			1,100			—			—			—			1,100
Balances, December 31, 2004		147		71,784			(7,540	)		1,151			—			43			65,585
Net income		—		—			—			309			—			—			309
Deferred compensation related to restricted stock awards		—		1,808			(1,808	)		—			—			—			—
Amortization of deferred stock-based compensation		—		—			448			—			—			—			448
Balances, March 31, 2005	$	147		73,592			(8,900	)		1,460			—			43			66,342

 

See accompanying notes to consolidated financial statements.

F-38

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
(unaudited)

	Successor			Predecessor
	Three Months Ended 03/31/05			Three Months Ended 03/31/04
Cash flows from operating activities:
Net income	$	309			411
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion, and amortization		9,478			9,271
Accretion of asset retirement obligations		325			299
Amortization of debt issue costs		103			—
Amortization of deferred stock-based compensation		448			—
Deferred income tax expense		(46	)		—
Gain on sale or disposal of property, plant, and equipment		6			14
Changes in operating assets and liabilities:
Receivables		(9,191	)		(10,776	)
Inventories		(3,557	)		(3,068	)
Prepaid royalties and other current assets		627			(1,193	)
Other assets		1,783			27
Accounts payable		9,927			(3,241	)
Accrued salaries, wages, and employee benefits		1,142			1,211
Accrued taxes		796			2,127
Other current liabilities		1,021			1,172
Workers’ compensation benefits		158			1,165
Black lung benefits		80			(391	)
Pension obligations		(538	)		28
Asset retirement obligation		(135	)		(131	)
Other liabilities		(47	)		4
Net cash provided by (used in) operating activities		12,689			(3,071	)
Cash flows from investing activities:
Additions to property, plant, and equipment		(14,690	)		(6,815	)
Proceeds from sale of equipment and property		—			40
Increase in restricted cash		(21	)		(21	)
Net cash used in investing activities		(14,711	)		(6,796	)
Cash flows from financing activities:
Proceeds from borrowings		—			6,400
Principal payments under capital lease obligations		(133	)		(101	)
Net cash provided by (used in) financing activities		(133	)		6,299
Decrease in cash		(2,155	)		(3,568	)
Cash at beginning of period		3,879			4,890
Cash at end of period	$	1,724			1,322

 

See accompanying notes to condensed consolidated financial statements.

F-39

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

(1)   SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES AND OTHER INFORMATION

(a)   Description of Business and Principles of Consolidation

The Company mines, processes and sells bituminous, low sulfur, steam- and industrial-grade coal through five operating subsidiaries located throughout Eastern Kentucky. Substantially all coal sales and accounts receivable relate to the electric utility and industrial markets.

The interim condensed consolidated financial statements include the accounts of James River Coal Company and its wholly owned subsidiaries. The interim condensed consolidated financial statements of James River Coal Company and subsidiaries (Company) as of and for the three months ended March 31, 2005, and the three months ended March 31, 2004 presented in this report are unaudited. All significant intercompany balances and transactions have been eliminated in consolidation. The results of operations for any interim period are not necessarily indicative of the results to be expected for the full year. These financial statements should be read in conjunction with the consolidated financial statements and the notes thereto for the year ended December 31, 2004. The balances presented as of December 31, 2004 are derived from the Company’s audited consolidated financial statements.

Management of the Company has made a number of estimates and assumptions relating to the reporting of assets, liabilities, revenues and expenses and the disclosure of contingent assets and liabilities in order to prepare these condensed consolidated financial statements in conformity with accounting principles generally accepted in the United States of America. Significant estimates made by management include the valuation allowance for deferred tax assets, accrued reclamation costs and amounts accrued related to the Company’s workers’ compensation, black lung, health claim, and pension obligations. Actual results could differ from these estimates. In the opinion of management, the accompanying unaudited condensed consolidated financial statements contain all adjustments, consisting of only normal recurring accruals, which are necessary to present fairly the consolidated financial position of the Company and the consolidated results of its operations and cash flows for all periods presented.

(b)  Bankruptcy and Restructuring

On March 25, 2003, James River Coal Company and subsidiaries (the Company) filed a voluntary petition for relief under Chapter 11 with the United States Bankruptcy Court for the Middle District of Tennessee. On April 21, 2004 the United States Bankruptcy Court for the Middle District of Tennessee confirmed the Company’s Plan of Reorganization (the Plan). The Plan of Reorganization became effective May 6, 2004 (the Effective Date) which is the date on which the Company formally emerged from Chapter 11. Pursuant to the Plan, the Company’s unsecured creditors claims were discharged and terminated.

The Company’s accompanying consolidated financial statements for the three months ended March 31, 2004, have been prepared in accordance with the American Institute of Certified Public Accountants’ Statement of Position 90-7, Financial Reporting by Entities in Reorganization under the Bankruptcy Code (SOP 90-7), which provides guidance for financial reporting by entities that have filed petitions under Bankruptcy. The consolidated financial statements after emergence are those of a new reporting entity (the Successor) and are not comparable to the consolidated financial statements of the pre-emergence Company (the Predecessor). A black line has been drawn in the financial statements to distinguish Predecessor and Successor financial information. See note 2 for additional information.

F-40

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

(c)  Restricted Cash

As of March 31, 2005 and December 31, 2004, $8,425 and $8,404 respectively, of the Company’s cash was restricted as to its use. Restrictions were imposed by the Company’s bank relating to a letter of credit issued to one of the Company’s insurers (see note 5).

(d)  Inventories

Inventories of coal and materials and supplies are stated at the lower of cost or market. Cost is determined using the average cost for coal inventories and the first-in, first-out method for materials and supplies. Coal inventory costs include labor, supplies, equipment cost, depletion, royalties, black lung tax, reclamation tax and preparation plant cost. Coal is classified as inventory at the point in time that the coal is extracted and removed from the mine.

(e)  Reclamation Costs

Effective January 1, 2003, the Company adopted Financial Accounting Standards Board (FASB) Statement No. 143, Accounting for Asset Retirement Obligations. Statement No. 143 requires that asset retirement obligations be recorded as a liability based on fair value, which is calculated as the present value of the estimated future cash flows, in the period in which it is incurred. The estimate of ultimate reclamation liability and the expected period in which reclamation work will be performed is reviewed periodically by the Company’s management and engineers. In estimating future cash flows, the Company considers the estimated current cost of reclamation and applies inflation rates and a third party profit, as necessary. The third party profit is an estimate of the approximate markup that would be charged by contractors for work performed on behalf of the Company. When the liability is initially recorded, the offset is capitalized by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. Accretion expense is included in cost of produced coal. To settle the liability, the obligation is paid, and to the extent there is a difference between the liability and the amount of cash paid, a gain or loss upon settlement is incurred. At March 31, 2005 and December 31, 2004, the Company had accrued $16,179 and $15,989, respectively, related to estimated mine reclamation costs.

(f)  Workers’ Compensation

The Company is liable for workers’ compensation benefits for traumatic injuries under state workers’ compensation laws in which it has operations. Subsequent to 2001, a portion of its workers’ compensation benefits are payable under a high-deductible, fully-insured workers’ compensation insurance policy. For claims incurred prior to 2002, the Company is self-insured, except for those claims incurred between 1979 and 1982, which are covered by a third party insurance company. Specific excess insurance with independent insurance carriers is in force to cover traumatic claims in excess of the self-insured limits.

The Company accrues for workers’ compensation benefits by recognizing a liability when it is probable that the liability has been incurred and the cost can be reasonably estimated. To assist in the determination of this estimated liability, the Company utilizes the services of third party administrators who develop claim reserves from historical experience. These third parties provide information to independent actuaries, who after review and consultation with the Company with regards to actuarial assumptions, including discount rate, prepare an evaluation of the liabilities for workers’ compensation benefits.

F-41

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

(g)  Black Lung Benefits

The Company is responsible under the Federal Coal Mine Health and Safety Act of 1969, as amended, and various states’ statutes for the payment of medical and disability benefits to employees and their dependents resulting from occurrences of coal worker’s pneumoconiosis disease (black lung). The Company provides for federal and state black lung claims through a self-insurance program. The Company uses the service cost method to account for its self-insured black lung obligation. The liability measured under the service cost method represents the discounted future estimated cost for former employees either receiving or projected to receive benefits, and the portion of the projected liability relative to prior service for active employees projected to receive benefits.

The periodic expense for black lung claims under the service cost method represents the service cost, which is the portion of the present value of benefits allocated to the current year, interest on the accumulated benefit obligation, and amortization of unrecognized actuarial gains and losses. The Company amortizes unrecognized actuarial gains and losses over the average remaining work life of the workforce.

Annual actuarial studies are prepared by independent actuaries using certain assumptions to determine the liability. The calculation is based on assumptions regarding disability incidence, medical costs, mortality, death benefits, dependents, and interest rates. These assumptions are derived from actual Company experience and industry sources.

(h)  Revenue Recognition

Revenues include sales to customers of Company-produced coal and coal purchased from third parties. The Company recognizes revenue from the sale of Company-produced coal and coal purchased from third parties at the time delivery occurs and title passes to the customer, which is either upon shipment or upon customer receipt of coal based on contractual terms. Also, the sales price must be determinable and collection reasonably assured.

(i)  Income Taxes

Income taxes are accounted for under the asset and liability method. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases and operating loss and tax credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in income in the period that includes the enactment date.

(j)  Equity-Based Compensation Plan

The Company accounts for stock-based compensation using the intrinsic value method prescribed by Accounting Principles Board (“APB”) Opinion No. 25, “Accounting for Stock Issued to Employees,” and related Interpretations. Accordingly, compensation cost for stock options granted to employees is measured as the excess, if any, of the quoted market price of the stock at the date of grant over the amount an employee must pay to acquire the stock. Compensation cost for stock appreciation rights and performance equity units is recorded based on the quoted market price of the Company’s stock at the end of the period. Stock-based compensation other than stock options is recorded to expense on a straight-line basis. The Company has implemented the disclosure-only provisions of FASB Statement No. 123 “Accounting for Stock-Based Compensation”. The Company has not recognized stock-based compensation expense related to stock options in any period as all options granted had an exercise price at least equal to the fair value of the underlying common stock on the date of the grant. If the Company

F-42

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

had followed the fair value method under FASB Statement No. 123 for options outstanding the impact on the three months ended March 31, 2005 would have been less than $.01 per share. In performing the Statement No. 123 analysis for stock options, a risk free rate of 5% was assumed, expected volatility was zero, and no dividends were anticipated. The Company had no stock options outstanding as of March 31, 2004.

If the Company had followed the fair value method under FASB Statement No. 123 to account for stock based compensation cost for restricted stock grants the amount of stock based compensation, net of related tax, which would have been recognized for each period and pro-forma net income for each period would have been as follows (in 000’s except per share amounts):

	Three Months March 31, 2005
Net Income, as reported	$	309
Add: Net stock-based employee compensation expense recorded for restricted and performance based stock grants		358
Deduct: Net stock-based employee compensation expense for restricted and performance based stock grants determined under Black-Scholes option pricing model		(289	)
Pro forma net income	$	378
Income per share:
Basic—as reported	$	0.02
Basic—pro forma	$	0.03
Diluted—as reported	$	0.02
Diluted—pro forma	$	0.03

 

The Financial Accounting Standards Board (“FASB”) has issued Statement of Financial Accounting Standards No. 123 (revised 2004), “Share-Based Payment” (FAS 123R), which requires all public companies to measure compensation cost in the income statement for all share-based payments (including employee stock options) at fair value. The Company intends to adopt FAS 123R on January 1, 2006 using the modified-prospective method. The Company has not completed its assessment of the impact of the adoption of this statement on its financial statements.

(2)  FRESH START ACCOUNTING

The Company implemented fresh start accounting and reporting in accordance with SOP 90-7 on April 30, 2004, the end of the Company’s most recent fiscal month prior to the Effective Date. Fresh start accounting requires that the reorganization value of the reorganized debtors be allocated to their assets in conformity with FASB Statement No. 141, Business Combinations, for transactions reported under the purchase method. The enterprise value (value of the net assets and liabilities excluding cash, debt, and capital leases) of the reorganized company was estimated to range from $145 million to $165 million based on a third-party valuation prepared in connection with the bankruptcy proceedings. For purposes of applying fresh start accounting, an enterprise value for the reorganized company of $155 million was utilized.

F-43

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

The effects of the Plan and the application of fresh-start accounting on the Company’s pre-confirmation consolidated balance sheet include adjustments to record the gain on the debt extinguished under the plan and adjustments to record the assets of the Company at their estimated fair value and the liabilities of the Company at their estimated present values. The reorganization value was derived from the enterprise value for the reorganized company as follows: (amounts in 000’s)

Estimated enterprise value of the reorganized company	$	155,000
Borrowings under credit facility		(6,400	)
Capital leases assumed		(1,396	)
Cash balance excluded from enterprise value		1,301
Administrative claims payable excluded from enterprise value		(10,214	)
		138,291
Less: new secured debt issued to extinguish prepetition debt		75,000
Fair value of common shares issued to extinguish prepetition debt	$	63,291

 

James River Coal Company
Reorganized Condensed Consolidated Balance Sheet
As of April 30, 2004
(amounts in 000’s)
(Unaudited)

			Fresh Start Adjustments
Assets	Predecessor Company 4/30/04		Debt Extinguishment			Reorganization Adjustments			Successor Company 4/30/04
Cash	$	1,301		—			—			1,301
Receivables		35,838		—			—			35,838
Inventories		11,930		—			1,079	(2)		13,009
Prepaid royalties		9,932		—			(362	)(2)		9,570
Other current assets		4,463		—			(347	)(2)		4,116
Total current assets		63,464		—			370			63,834
Land and mineral rights		223,004		—			(57,567	)(2)		165,437
Buildings, machinery, and equipment		236,901		—			(155,050	)(2)		81,851
Mine development costs		12,984		—			(12,984	)(2)		—
Construction-in-progress		974		—			—			974
		473,863		—			(225,601	)		248,262
Less accumulated depreciation, depletion, and amortization		219,604		—			(219,604	)(2)		—
Net property, plant, and equipment		254,259		—			(5,997	)		248,262
Restricted cash		8,348		—			—			8,348
Other long-term assets		6,518		(3,110	)(1)		(734	)(2)		2,674
Total assets	$	332,589		(3,110	)		(6,361	)		323,118

 

F-44

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

James River Coal Company
Reorganized Condensed Consolidated Balance Sheet
As of April 30, 2004
(amounts in 000’s)
(Unaudited)

	Fresh Start Adjustments
Liabilities and Shareholders’ Equity (Deficit)	Predecessor Company 4/30/04			Debt Extinguishment			Reorganization Adjustments			Successor Company 4/30/04
Borrowings under DIP credit agreement	$	6,400			—			—			6,400
Current installments of obligations under capital leases		749			—			(272	)(3)		477
Accounts payable		26,293			—			—			26,293
Accrued salaries, wages and employee benefits		4,501			—			—			4,501
Workers’ compensation benefits		9,500			—			—			9,500
Black lung benefits		2,500			—			—			2,500
Accrued taxes		3,588			—			—			3,588
Other current liabilities		4,037			—			—			4,037
Total current liabilities		57,568			—			(272	)		57,296
Long term debt		—			75,000	(1)		—			75,000
Noncurrent portion of workers’ compensation benefits		42,699			—			—			42,699
Noncurrent portion of black lung benefits		10,661			—			13,610	(4)		24,271
Pension obligations		14,267			—			3,363	(5)		17,630
Asset retirement obligations		13,963			—			—			13,963
Obligations under capital leases, excluding current installments		1,159			—			(240	)(3)		919
Deferred income taxes		—			—			27,391	(6)		27,391
Other long term liabilities		658			—			—			658
Total other liabilities		83,407			—			44,124			127,531
Liabilities subject to compromise		319,451			(319,451	)(1)		—			—
Total liabilities		460,426			(244,451	)		43,852			259,827
Common stock		—			138	(1)		—			138
Paid-in-capital		226			63,153	(1)		(226	)(7)		63,153
Retained earnings (accumulated deficit)		(111,533	)		178,050	(1)		(66,517	)(7)		—
Subscribed shares		(821	)		—			821	(7)		—
Accumulated other comprehensive income (loss)		(15,709	)		—			15,709	(7)		—
Total shareholders’ equity (deficit)		(127,837	)		241,341			(50,213	)		63,291
Total liabilities and shareholders’ equity	$	332,589			(3,110	)		(6,361	)		323,118

 

F-45

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

The following is a description of the fresh start adjustments for debt extinguishment and reorganization adjustments:

Extinguishment of Debt

(1) Liabilities subject to compromise that were extinguished in bankruptcy consist of the following (amounts in 000’s):

Pre-petition bank loan agreement	$	207,807
Pre-petition senior note		37,953
Accrued and unpaid interest		12,234
Terminated interest rate swap		8,434
Total secured		266,428
Promissory notes		5,176
Redeemable preferred stock		8,500
Accounts payable and other		39,347
Total unsecured		53,023
Total liabilities subject to compromise	$	319,451

 

The Company issued new common shares, new secured debt, and transferred its interest in specified life insurance policies held in a rabbi trust to the creditors in full satisfaction of pre-petition claims. The gain on extinguishment of pre-petition claims is calculated as follows (amounts in 000’s):

Liabilities subject to compromise	$	319,451
Less: Assets of rabbi trust transferred to creditors		(3,110	)
Less: New secured debt issued in exchange for pre-petition debt		(75,000	)
Less: Fair value of common shares issued		(63,291	)
Gain on extinguishment of pre-petition claims	$	178,050

 

Reorganization Adjustments

(2) In connection with the application of fresh start accounting, the Company made adjustments aggregating approximately $6.3 million to record its identifiable assets at fair value as follows (amounts in 000’s):

	Increase/(Decrease)
Coal inventories	$	1,079
Prepaid royalties		(362	)
Other current assets		(347	)
Land and mineral rights		(57,567	)
Buildings, machinery and equipment		(155,050	)
Mine development costs		(12,984	)
Less accumulated depreciation, depletion, and amortization		219,604
Other long-term assets		(734	)
Total fair value adjustments to identifiable assets	$	(6,361	)

 

(3) Contractual terms of certain capital lease agreements were renegotiated during bankruptcy. Obligations under capital leases have been adjusted to reflect the revised terms.

F-46

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

(4) The liability for black lung benefits has been adjusted to reflect the total discounted benefit obligation.

(5) The pension liability has been adjusted to reflect the total discounted projected benefit obligation of the plan.

(6) Deferred income taxes have been adjusted to reflect differences in the book and tax basis of the revalued assets and liabilities of the Company after application of fresh start accounting.

(7) The equity of the predecessor company, including subscribed shares and accumulated other comprehensive loss, has been eliminated in fresh start accounting.

(3)   LONG TERM DEBT AND INTEREST EXPENSE

Long-term debt at March 31, 2005 is as follows (amounts in 000’s):

	March 31, 2005
Senior secured credit facility:
Term loan component	$	20,000
Revolver component		—
Term credit facility		75,000
Total long-term debt		95,000
Less amounts classified as current		3,600
Total long-term debt, less current maturities	$	91,400

 

(a)  Senior Secured Credit Facility

Effective May 6, 2004, the Company closed a $50 million senior secured credit facility with Wells Fargo Foothill, Inc. (the Senior Secured Credit Facility). This facility was used to repay outstanding amounts and replace letters of credit previously issued under the $20 million debtor-in-possession facility to pay expenses associated with the exit from bankruptcy and to provide liquidity for general corporate purposes. The Senior Secured Credit Facility is comprised of a $30 million revolver component and a $20 million term component. The term loan was fully funded at closing. Borrowings under the revolver component bear interest at LIBOR + 2.5% or the Base Rate (as defined in the credit agreement) + 1.0%. Borrowings under the term component bear interest at LIBOR + 5.25% or the Base Rate + 3.85%. The term of the Senior Secured Credit Facility is five years. Principal payments on the term component of $900,000 per quarter commence on April 1, 2005 and continue through April 1, 2009, with the remaining principal balance due on May 6, 2009. Interest is payable in arrears, on the first day of each month on Base Rate borrowings while interest on LIBOR Rate borrowings is due on the last day of the LIBOR interest period. Advances under the Senior Secured Credit Facility are secured by a first priority lien on substantially all of the Company’s assets, and, except for the Term Credit Facility, the Company may not incur additional debt on the assets securing the Revolving Credit Facility. Advances under the revolver component may not exceed a borrowing base calculation derived as a percentage of eligible assets. The Senior Secured Credit Facility can be terminated with 90 days written notice by paying all outstanding principal, interest and making any prepayment premium payments due. The $30 million revolver component has a prepayment premium of 2.5% of the total revolver commitment for the first year, declining to 2.0% for the second year, 1.5% for the third year and 0.5% for the fourth year. There is not a prepayment premium for the fifth year of the revolver component of the Senior Secured Credit Facility. The $20 million term loan component has a prepayment premium of $200,000 (1.0%) if paid prior to April 30, 2007. There is no prepayment premium after April 30, 2007 for the term loan component.

F-47

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

(b)  Term Credit Facility

The Company also entered into a $75 million term credit facility with the Company’s pre-petition secured lenders (the Term Credit Facility) in partial satisfaction of its prepetition obligations, pursuant to the Plan of Reorganization. The term of the Term Credit Facility is seven years, and the repayment of the Term Credit Facility is secured by a second priority lien on substantially all of the Company’s assets. Except for the Senior Secured Credit Facility, the Company may not incur additional debt on the assets securing the Term Credit Facility. In addition, the Company may not incur any unsecured debt (other than normal trade payables) and may not incur more than $5 million of recourse debt (including the Senior Secured Credit Facility and the Term Credit Facility). There is no scheduled amortization of this facility for the first two years. The notes are payable over seven years with principal repayments of $1.5 million per quarter beginning June 30, 2006 and increasing to $2.5 million per quarter beginning June 30, 2008. All remaining principal and interest is due May 6, 2011. Borrowings under the Term Credit Facility may be prepaid without penalty.

(c)  Interest Expense and Other

Until the date of filing of bankruptcy, the Company accrued interest. The Company determined that there was insufficient collateral to cover the interest portion of the scheduled payments on its prepetition debt obligations. As of the bankruptcy date the Company ceased accruing interest on all the prepetition secured debt obligations. If such interest had continued to be accrued, interest expense would have been approximately $5.7 million for the three months ended March 31, 2004. During the three months ended March 31, 2005 and 2004, the Company paid $2,087,000 and $147,000 in interest, respectively.

The Senior Secured Credit Facility and the Term Credit Facility contain financial covenants including a fixed charge coverage, a minimum leverage, minimum consolidated tangible net worth, minimum consolidated total annualized EBITDDA (as defined in each of the credit facilities), and maximum annual limits on capital expenditures. The Company was in compliance with all of the financial covenants for the Senior Secured Credit Facility and the Term Credit Facility as of March 31, 2005. The Company’s debt covenants also prohibit payment of cash dividends.

(4)  EQUITY

(a)  Preferred Stock and Shareholder Rights Agreement

The Company has authorized 10,000,000 shares of preferred stock, $1.00 par value, the rights and preferences of which are established by the Board of the Directors. The Company has reserved 500,000 of these shares as Series A Preferred Stock for issuance under a shareholder rights agreement (the “Rights Agreement”)

On May 25, 2004, the Company’s shareholders approved the Rights Agreement and declared a dividend of one preferred share purchase right (“Right”) for each two shares of common stock outstanding. Each Right entitles the registered holder to purchase from the Company one one-hundredth (1/100) of a share of our Series A Participating Cumulative Preferred Stock, par value $1.00 per share, at a price of $200 per one one-hundredth of a Series A preferred share. The Rights are not exercisable until a person or group of affiliated or associated persons (an “Acquiring Person”) have acquired or announced the intention to acquire 15% or more of the Company’s outstanding common stock.

In the event that the Company is acquired in a merger or other business combination transaction or 50% or more of the Company’s consolidated assets or earning power is sold after a person or group has become an Acquiring

F-48

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

Person, each holder of a Right, other than the Rights beneficially owned by the Acquiring Person (which will thereafter be void), will receive, upon the exercise of the Right, that number of shares of common stock of the acquiring company which at the time of such transaction will have a market value of two times the exercise price of the Right. In the event that any person becomes an Acquiring Person, each Right holder, other than the Acquiring Person (whose Rights will become void), will have the right to receive upon exercise that number of shares of common stock having a market value of two times the exercise price of the Right.

The rights will expire May 25, 2014, unless that expiration date is extended. The Board of Directors may redeem the Rights at a price of $0.001 per Right at any time prior to the time that a person or group becomes an Acquiring Person.

(b)  Redeemable Preferred Stock (Predecessor Company)

The Company had 8,500 shares of Class C, nonvoting, mandatorily redeemable preferred stock outstanding. The preferred shares had a par value of $1,000 per share and a dividend rate of 8%.

On July 1, 2003, the Company adopted Statement No. 150, Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity, which required that dividends on redeemable preferred stock be reported as a financing cost in our statement of operations. Accordingly, preferred dividends of $170,000 for the three months ended March 31, 2004, are included in interest expense in the condensed consolidated statements of operations.

The preferred stock was cancelled on May 6, 2004 in accordance with the terms of the Plan of Reorganization.

(5)  COMMITMENTS AND CONTINGENCIES

The Company has established irrevocable letters of credit totaling $32.7 million as of March 31, 2005 to guarantee performance under certain contractual arrangements. The Company has letters of credit totaling $7.8 million that are collateralized by restricted cash (see note 1(c)). The remaining letters of credit totaling $24.9 million were issued under the Senior Secured Credit Facility and reduce the Company’s availability under the $30 million revolver component. The Company is charged a fee of 2.5% annually on letters of credit outstanding.

The Company is involved in various claims and legal actions arising in the ordinary course of business. In the opinion of management, the ultimate disposition of these matters will not have a material adverse effect on the Company’s consolidated financial position, results of operations or liquidity.

(6)  REORGANIZATION ITEMS, NET

Reorganization items, net, consists of the following (amounts in 000’s):

	Predecessor Company Three Months Ended 03/31/04
Professional fees and administrative expenses	$	1,607
Interest income		(50	)
	$	1,557

 

F-49

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

(7)  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 and restricted common stock subject to continuing vesting requirements, pursuant to the treasury stock method.

The following table provides a reconciliation of the number of shares used to calculate basic and diluted earnings per share:

	Successor Company Three Months Ended 3/31/05		Predecessor Company Three Months Ended 3/31/04
Weighted average number of common shares outstanding:
Basic		13,799,994		16,890
Effect of dilutive instruments		951,678		—
Diluted		14,751,672		16,890

 

On May 6, 2004 the Company emerged from bankruptcy under a joint plan of reorganization. On that date the Company cancelled all existing equity securities and issued 13,799,994 shares of new common stock, which were distributed pro-rata to the pre-petition secured creditors.

(8)  PENSION EXPENSE

The components of net periodic benefit cost are as follows (amounts in 000’s):

	Successor Company Three Months Ended 3/31/05			Predecessor Company Three Months Ended 3/31/04
Service cost	$	527			459
Interest cost		793			723
Expected return on plan assets		(761	)		(608	)
Amortization of prior service cost		—			97
Recognized actuarial loss		—			255
Net periodic benefit cost	$	559			926

 

F-50

JAMES RIVER COAL COMPANY AND SUBSIDIARIES
Notes to Condensed Consolidated Financial Statements
(Unaudited)

(9)  PNEUMOCONIOSIS (BLACK LUNG) BENEFITS

The expense for black lung benefits consists of the following (amounts in 000’s):

	Successor Company Three Months Ended 3/31/05		Predecessor Company Three Months Ended 3/31/04
Service cost	$	74		74
Interest cost		340		188
Amortization of actuarial loss		54		262
Total expense	$	468		524

 

(10)  DEFINITIVE AGREEMENT TO ACQUIRE TRIAD MINING, INC.

In March 2005, the Company signed a definitive agreement to acquire Triad Mining Inc. (“Triad”) for approximately $75 million, consisting of $64 million in cash and $11 million of Company common stock. Triad operates six surface mines and one underground mine in Southern Indiana.

(11)  SUBSEQUENT EVENT

On April 19, 2005, the Company filed a Registration Statement on Form S-1 for the registration of up to 4,025,000 shares of its common stock, and $150 million of Senior Notes due 2012 (the “Notes”). Payment of the principal and interest on the Notes will be guaranteed by each of the Company’s subsidiaries. The Company has no independent assets or operations (as defined in Rule 3-10(h)(5) of Regulation S-X) aside from those of its subsidiaries. The guarantees will be full and unconditional and joint and several obligations (as such terms are defined in Rule 3-10(h)(5) of Regulation S-X) issued by all of the Company’s subsidiaries. Accordingly, pursuant to Rule 3-10(f) of Regulation S-X, the Company has not provided separate financial information with respect to the Company’s subsidiaries.

F-51

INDEX TO TRIAD MINING, INC. CONSOLIDATED FINANCIAL STATEMENTS

	Page
Audited Financial Statements
Report of Independent Registered Public Accounting Firm		T-2
Consolidated Balance Sheet December 31, 2004		T-3
Consolidated Statement of Income Year ended December 31, 2004		T-4
Consolidated Statement of Changes in Stockholders’ Equity and Other Comprehensive Income Year ended December 31, 2004		T-5
Consolidated Statement of Cash Flows Year ended December 31, 2004		T-6
Notes to Financial Statements December 31, 2004		T-7
Unaudited Financial Statements
Condensed Consolidated Balance Sheets March 31, 2005 and December 31, 2004		T-14
Condensed Consolidated Statements of Income Three months ended March 31, 2005 and March 31, 2004		T-15
Condensed Consolidated Statements of Changes in Stockholders’ Equity and Comprehensive Income Three months ended March 31, 2005 and year ended December 31, 2004		T-16
Condensed Consolidated Statements of Cash Flows Three months ended March 31, 2005 and March 31, 2004		T-17
Notes to Condensed Consolidated Financial Statements March 31, 2005		T-18

 

T-1

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

The Board of Directors
Triad Mining, Inc.:

We have audited the accompanying consolidated balance sheet of Triad Mining, Inc. and subsidiary (the Company) as of December 31, 2004 and the related consolidated statements of income, changes in stockholders’ equity and other comprehensive income, and cash flows for the year then ended. These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated financial statements based on our audit.

We conducted our audit in accordance with standards of the Public Company Accounting Oversight Board (United States). Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes consideration of internal control over financial reporting as a basis for designing audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the Company’s internal control over financial reporting. Accordingly, we express no such opinion. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe our audit provides a reasonable basis for our opinion.

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Triad Mining, Inc. and subsidiary as of December 31, 2004, and the results of their operations and their cash flows for the year then ended in conformity with U.S. generally accepted accounting principles.

/s/ KPMG LLP

Richmond, Virginia
April 12, 2005

T-2

TRIAD MINING, INC. AND SUBSIDIARY
Consolidated Balance Sheet
December 31, 2004

Assets
Current assets:
Cash and cash equivalents	$	8,135,128
Available for sale securities		16,729,848
Accounts receivable		7,371,053
Coal inventory		981,646
Stores inventory		948,775
Advance royalties — current portion		430,449
Prepaid expenses		545,660
Accrued interest receivable		120,881
Other		28,664
Total current assets		35,292,104
Property and equipment, net		21,245,321
Mineral rights, net		4,052,590
Mine development costs, net		1,070,043
Long-term portion of advance royalties		530,525
	$	62,190,583
Liabilities and Stockholders’ Equity
Current liabilities:
Current maturities of long-term debt	$	1,712,361
Accounts payable		4,756,779
Accrued expenses		1,271,780
Total current liabilities		7,740,920
Reclamation and mine closing liabilities		7,395,580
Total liabilities		15,136,500
Stockholders’ equity:
Common stock, no par value. Authorized 1,000 shares; issued and outstanding 411 shares		48,446
Accumulated other comprehensive loss		(135,967	)
Notes receivable from and advances to stockholders		(388,928	)
Retained earnings		47,530,532
Total stockholders’ equity		47,054,083
	$	62,190,583

 

See accompanying notes to consolidated financial statements.

T-3

TRIAD MINING, INC. AND SUBSIDIARY
Consolidated Statement of Income
Year ended December 31, 2004

Coal sales	$	81,602,894
Operating costs and expenses:
Cost of coal sold		59,290,543
Selling, administrative, and other		3,736,452
Depreciation		4,621,489
Amortization		878,321
Total operating costs and expenses		68,526,805
Income from operations		13,076,089
Other income (expense):
Interest income		567,227
Interest expense		(174,328	)
Loss on sale and impairment of investments		(72,696	)
Gain on sale of assets		16,615
Miscellaneous income		112,634
Total other income		449,452
Net income	$	13,525,541

 

See accompanying notes to consolidated financial statements.

T-4

TRIAD MINING, INC. AND SUBSIDIARY
Consolidated Statement of Changes in Stockholders’ Equity
and Other Comprehensive Income
Year ended December 31, 2004

	Common Stock		Accumulated other comprehensive loss			Notes receivable from and advances to stockholders			Retained earnings			Total stockholders’ equity
Balances at January 1, 2004	$	48,446	$	(45,635	)	$	(137,351	)	$	45,970,492		$	45,835,952
Comprehensive income:
Net income		—		—			—			13,525,541			13,525,541
Other comprehensive loss:
Unrealized losses on securities, net of reclassification adjustment		—		(90,332	)		—			—			(90,332	)
Comprehensive income													13,435,209
Increase in receivables from and advances to stockholders, net		—		—			(251,577	)		—			(251,577	)
Distributions to stockholders		—		—			—			(11,965,501	)		(11,965,501	)
Balances at December 31, 2004	$	48,446	$	(135,967	)	$	(388,928	)	$	47,530,532		$	47,054,083

 

See accompanying notes to consolidated financial statements.

T-5

TRIAD MINING, INC. AND SUBSIDIARY
Consolidated Statement of Cash Flows
Year ended December 31, 2004

Operating activities:
Net income	$	13,525,541
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		5,499,810
Accretion of reclamation and mine closing liabilities		323,443
Gain on sale of assets		(16,615	)
Loss on sale and impairment of investments		72,696
(Increase) decrease in:
Accounts receivable		(329,611	)
Inventories		74,935
Advance royalties		171,674
Prepaid expenses		67,133
Accrued interest		2,712
Other assets		158,289
Increase in:
Accounts payable		707,148
Accrued expenses		156,190
Net cash provided by operating activities		20,413,345
Investing activities:
Expenditures for property and equipment		(4,705,437	)
Proceeds from sale of property and equipment		19,615
Purchases of securities		(7,721,433	)
Proceeds from maturities of securities		1,990,000
Proceeds from sale of securities		4,314,000
Purchase of mineral rights		(400,887	)
Expenditures for mine development costs		(208,821	)
Receivables from and advances to stockholders		(571,275	)
Repayment of receivables from and advances to stockholders		319,698
Net cash used in investing activities		(6,964,540	)
Financing activities:
Distributions to stockholders		(11,965,501	)
Repayment of long-term debt		(2,421,859	)
Net cash used in financing activities		(14,387,360	)
Net decrease in cash and cash equivalents		(938,555	)
Cash and cash equivalents at beginning of year		9,073,683
Cash and cash equivalents at end of year	$	8,135,128
Supplemental disclosure of cash flow information:
Cash paid during the year for:
Interest	$	174,328

 

See accompanying notes to consolidated financial statements.

T-6

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2004

(1)  OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a)  Operations

Triad Mining, Inc. (the Company) is engaged in the business of mining and selling coal, primarily to electric utility companies located in Indiana. Sales are made under long-term contracts and in the spot market.

(b)  Principles of Consolidation

The consolidated financial statements include the accounts of Triad Mining, Inc. and its wholly owned subsidiary, Triad Underground Mining, LLC. All intercompany transactions have been eliminated.

(c)  Use of Estimates

Financial statements prepared in conformity with U.S. generally accepted accounting principles require management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates made by management include the accrual for reclamation and mine closure costs, the level of proven and probable reserves used to calculate depletion, and the useful life of depreciable assets. Actual results could differ from these estimates.

(d)  Cash and Cash Equivalents

Cash equivalents include highly liquid investments with original maturities of three months or less.

(e)  Available for Sale Securities

The Company classifies its debt and equity securities as available for sale. Available for sale securities are carried at fair value with unrealized gains and losses reported in other comprehensive income (loss). Realized gains and losses on securities available for sale are included in other income (expense) and, when applicable, are reported as a reclassification adjustment in other comprehensive income. Gains and losses on the sale of available for sale securities are determined using the specific identification method.

(f)  Inventories

Coal and stores inventories are valued at the lower of cost or market. The cost of coal inventories is determined based on the average cost of production, which includes all costs incurred to extract, transport, and process the coal. The cost of store inventories is determined on the first-in, first-out method.

(g)  Property and Equipment

Property and equipment are recorded at cost. Depreciation is determined using the straight-line method over the estimated useful lives of the related assets (ranging from three to ten years). Maintenance expense is recognized when repairs that do not extend an asset’s useful life or increase its utility are performed.

(h)  Mine Development Costs

Mine development costs are capitalized and amortized using the units of production method over estimated total recoverable proved and probable reserves.

T-7

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2004

(i)  Mineral Rights

Depletion of mineral rights is based on estimated recoverable proven and probable reserves. The components of mineral rights as of December 31, 2004 is as follows:

Original cost	$	8,885,588
Less accumulated depletion		(4,832,998	)
Balance at December 31, 2004	$	4,052,590

 

(j)  Income Taxes

In 1995, the Company elected to include its taxable income or loss with that of its stockholders (an S-Corporation election) for federal and state income tax purposes. Accordingly, federal and state income tax liabilities or benefits accrue to the stockholders instead of the Company.

(k)  Allowance for Uncollectible Receivables

The Company evaluates the need for an allowance for doubtful accounts based on a review of historical write off experience and industry data. It is management’s opinion that no allowance is necessary for trade receivables as of December 31, 2004.

(l)  Asset Impairment

If facts and circumstances suggest that a long-lived asset may be impaired, the carrying value is reviewed. If this review indicates that the value of the asset will not be recoverable, as determined based on projected undiscounted cash flows related to the asset over its remaining life, then the carrying value of the asset is reduced to its estimated fair value. The Company did not recognize an asset impairment charge in 2004.

(m)  Revenue Recognition

Coal sales revenues include sales to customers of coal produced at Company operations. The Company recognizes revenues from coal sales at the time title passes to the customer. Revenues from sources other than coal sales, are included in other revenues and are recognized as services are performed or otherwise earned.

(n)  Advance Coal Royalty

Advance coal royalties are capitalized when paid and charged to expense using the unit-of-production method at the time coal production commences on the respective property.

(o)  Reclamation and Mine Closing Liabilities

Minimum standards for mine reclamation have been established by various regulatory agencies and dictate the reclamation requirements at the Company’s operations. The Company records these reclamation obligations under the provisions of FASB Statement No. 143, Accounting for Asset Retirement Obligations. Statement 143 requires the fair value of a liability for an asset retirement obligation to be recognized in the period in which the legal obligation associated with the retirement of the long-lived asset is incurred. When the liability is initially recorded, the offsetting amount is recorded as an increase in the carrying amount of the long-lived asset. Over time, the liability is accreted as a component of cost of coal sales to its present value each period, and the capitalized

T-8

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2004

cost is depreciated over the useful life of the related asset. A gain or loss upon settlement is recorded upon the settlement of the liability to the extent there is a difference between the liability recognized and the amount of cash paid to settle the obligation. The Company annually reviews its estimated future cash flows for its asset retirement obligations.

(p)  Derivatives

The Company currently utilizes interest rate swaps to economically hedge the impact of changes in interest rates on its floating rate debt. Under the terms of these interest rate swaps, the Company is the fixed rate payor and the floating rate receiver. The fair value of the interest rate swaps was recorded on the consolidated balance sheets as a component of accounts payable with changes in the fair value included in net income as a component of miscellaneous income. The notional amount and the fair value liability of these interest rate swaps were $2,066,997 and $16,867, respectively, as of December 31, 2004.

(2)  PROPERTY AND EQUIPMENT

As of December 31, 2004, the components of property and equipment were as follows:

Land	$	2,869,992
Mine equipment and vehicles		64,368,454
Less accumulated depreciation		(45,993,125	)
Property and equipment, net	$	21,245,321

 

(3)  MINE DEVELOPMENT COSTS

Mine development costs net of coal sales during the mine development stage were capitalized and are being amortized over the estimated life of the mines based on recoverable coal reserves. The components of mine development costs as of December 31, 2004 is as follows:

Mine development costs	$	2,943,538
Less accumulated amortization		(1,873,495	)
Mine development costs, net	$	1,070,043

 

(4)  AVAILABLE FOR SALE SECURITIES

The Company has investments in certain debt and equity securities. As of December 31, 2004, these securities were classified as available for sale securities and are reported at fair value, with the unrealized gains and losses included in other comprehensive income (loss).

Available for sale securities are stated at fair value and consist of the following at December 31, 2004:

	Cost Basis		Gross unrealized gains		Gross unrealized losses			Fair value
Equity securities	$	381,359	$	26,620	$	(19,253	)	$	388,726
U.S. Government agency obligations		2,099,156		397		(8,990	)		2,090,563
Municipal bonds and notes		14,385,300		9,693		(144,434	)		14,250,559
	$	16,865,815	$	36,710	$	(172,677	)	$	16,729,848

 

T-9

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2004

The following table shows the gross unrealized losses and fair value of the Company’s available for sale securities (by category) with unrealized losses and the length of time that individual securities have been in a continuous unrealized loss position as of December 31, 2004:

	Greater than 12 months				Less than 12 months
	Fair Value		Gross unrealized losses		Fair value		Gross unrealized losses
Equity securities	$	63,017		—		117,474		19,253
U.S. Government agency obligations		199,000		1,009		1,691,157		7,981
Municipal bonds and notes		9,996,848		128,924		1,333,782		15,510
	$	10,258,865		129,933		3,142,413		42,744

 

The maturities of debt securities available for sale at December 31, 2004 is as follows:

	Cost Basis		Fair value
Year ended December 31,
2005	$	6,194,316		6,145,416
2006		5,965,468		5,895,078
2007		3,896,243		3,871,538
2008		428,429		429,090
	$	16,484,456		16,341,122

 

Proceeds from the sale of available-for-sale securities aggregated $4,314,000 in 2004. Gross realized gains and gross realized losses associated with such sales in 2004 were $19,275 and $62,063, respectively. Unrealized losses of $29,908 were also recognized as a result of other than temporary impairments of certain equity securities.

The change in the net unrealized losses on available for sale securities reported in accumulated other income is as follows:

	2004
Unrealized holding losses arising during the year	$	(163,028	)
Less: reclassification adjustment for losses included in net income		72,696
Net unrealized losses on available for sale securities	$	(90,332	)

 

(5)  NOTES RECEIVABLE FROM AND ADVANCES TO STOCKHOLDERS

Notes receivable from and advances to stockholders consist of the following:

• A $371,275 unsecured promissory note (interest rate 3.00%) from a stockholder, maturing in 2006. Principal and interest are due at maturity.

• A $15,553 unsecured promissory note from a stockholder, maturing in 2007. Principal and interest (6.00%) are payable monthly.

• Other non-interest bearing advances to stockholders aggregating $2,100.

These amounts are classified in the consolidated balance sheet as a reduction of stockholders’ equity.

T-10

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2004

(6)  LONG-TERM DEBT

As of December 31, 2004, the Company had the following debt outstanding:

Note payable to a bank, principal and interest payable monthly; interest rate based on LIBOR + 1.00% (3.31% as of December 31, 2004), secured by equipment and accounts receivable; maturing October 2005	$	1,064,623
Note payable to a bank, principal and interest payable monthly; interest rate based on LIBOR + 1.00% (3.31% as of December 31, 2004), secured by equipment and accounts receivable; maturing October 2005		647,738
Total		1,712,361
Less current maturities		1,712,361
Long-term debt	$	—

 

(7)  RECLAMATION LIABILITY

Activity related to the Company’s reclamation and mine closing liabilities for the year ended December 31, 2004 was as follows:

Reclamation and mine closing liabilities, beginning of year	$	7,486,744
Accretion expense		323,443
Settlements		(117,323	)
Reclamation and mine closing liabilities, end of year		7,692,864
Less: amount included in accrued expenses		297,284
Non-current reclamation and mine closing liabilities, end of year	$	7,395,580

 

These reclamation liabilities are secured by irrevocable letters of credit aggregating $5,875,865 as of December 31, 2004 in accordance with the required procedures for obtaining mining permits and bonding the permitted areas for reclamation purposes.

(8)  PNEUMOCONIOSIS (BLACK LUNG) BENEFIT OBLIGATION

The Federal Coal Mine Health and Safety Act of 1969, as amended in 1972 by the Black Lung Benefit Act, imposes a liability on coal mine operators for payment of benefits to eligible employees, former employees, and certain of their survivors and dependents on all black lung claims filed after June 30, 1973. The Company is fully insured for these benefits through a commercial insurance carrier and is making premium payments for such coverage.

(9)  LEASES

The Company leases certain mining properties under operating leases, with terms in excess of one year or for so long as the Company is commercially mining coal from the leased property. The leases are cancelable and all obligations of the Company end upon written notice of termination by the Company. Payments of advance royalties are recoupable from future earned royalties. Payments of earned royalties are due at a specific rate per ton for all coal extracted from the leased property. The total royalty expense recorded in operating costs and expenses was $4,071,644 for 2004.

T-11

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2004

The Company does not have any future minimum royalty commitments under coal lease agreements as of December 31, 2004.

(10)  SALES COMMITMENTS AND MAJOR CUSTOMERS

As of December 31, 2004, the Company has long-term sales agreements (terms ranging from $21 to $26 per ton) to supply coal within minimum and maximum tonnages which are as follows:

	Tons
	Minimum		Maximum
Year ended December 31:
2005		2,601,555		3,410,000
2006		2,116,500		2,853,500
2007		950,000		2,350,000
2008		950,000		2,350,000
2009		950,000		1,250,000
		7,568,055		12,213,500

 

The Company operates one business segment, the mining of coal. Shipments to four customers accounted for 48.8%, 20.4%, 19.7%, and 10.6%, respectively, of coal sales during the year ended December 31, 2004.

Accounts receivable at year end from these four customers represented 38.2%, 16.1%, 23.5%, and 20.9%, respectively, of total accounts receivable.

(11)  SELF-INSURANCE HEALTH CARE PLAN

The Company employees are covered under a self-insurance program that covers that portion of employee’s health care costs not covered by stop loss insurance, which sets the maximum cash outlay at $35,000 for each employee or employee’s dependents, and provides a cap for aggregate claims at approximately $1,866,000. Health care costs were approximately $1,740,000 for 2004. As of December 31, 2004, the Company had accrued $184,211 related to unprocessed claims.

(12)  EMPLOYEE BENEFIT PLAN

The Company has a defined contribution plan that provides retirement benefits to substantially all employees with 100% vesting after five years of service. The plan is a noncontributory plan with the Company’s contribution being allocated to each participant on the basis of the participant’s compensation to total compensation of all participants. The Company is not obligated to make an annual contribution and the contribution may vary from year to year. For 2004, approximately $1,797,000 was contributed to the plan.

The Company also sponsors a 401(k) plan that allows all employees to participate in the plan to the extent allowed under the Internal Revenue Service Regulations. The Company does not make contributions to this plan.

The Company also has a profit sharing plan in which the contributions are discretionary, based on an amount determined by the Board of Directors. Total profit sharing expense during 2004 was $18,209.

T-12

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
DECEMBER 31, 2004

(13)  CONCENTRATION OF CREDIT RISK

The Company, in the normal course of business, extends credit to its customers without requiring collateral. Credit risk with respect to trade accounts receivable is minimized by reviewing customer credit history before extending credit and by monitoring customer’s credit exposure on a continuing basis.

The Company does not believe that it is exposed to any significant credit risk in connection with the extension of credit to its customers.

(14)  CONTINGENCY

At December 31, 2004, the Company had outstanding letters of credit for $5,875,865. These were issued to obtain mining permits and to support bonds issued to secure reclamation obligations (note 7).

The Company is from time to time, involved in lawsuits arising in the ordinary course of its business that, in the opinion of management, would not have a material effect on the Company’s financial position or results of operations.

(15)  SUBSEQUENT EVENT

In March 2005, the Company’s stockholders entered into a definitive agreement to sell all of the outstanding common stock of the Company to James River Coal Company (“James River Coal”) for approximately $75,000,000, consisting of $64,000,000 in cash and $11,000,000 of James River Coal common stock. James River Coal is a public company that primarily operates underground mines in Eastern Kentucky.

T-13

TRIAD MINING, INC. AND SUBSIDIARY
Condensed Consolidated Balance Sheets

	March 31, 2005			December 31, 2004
	(unaudited)
Assets
Current assets:
Cash and cash equivalents	$	6,677,899			8,135,128
Available for sale securities		16,868,567			16,729,848
Accounts receivable		10,316,934			7,371,053
Coal inventory		1,178,785			981,646
Stores inventory		1,052,226			948,775
Advance royalties — current portion		595,245			430,449
Prepaid expenses		367,735			545,660
Accrued interest receivable		119,055			120,881
Other		—			28,664
Total current assets		37,176,446			35,292,104
Property and equipment, net		20,620,950			21,245,321
Mineral rights, net		3,597,714			4,052,590
Mine development costs, net		988,338			1,070,043
Long-term portion of advance royalties		530,525			530,525
	$	62,913,973			62,190,583
Liabilities and Stockholders’ Equity
Current liabilities:
Current maturities of long-term debt	$	884,899			1,712,361
Accounts payable		3,561,019			4,756,779
Accrued expenses		1,962,285			1,271,780
Total current liabilities		6,408,203			7,740,920
Reclamation and mine closing liabilities		7,488,228			7,395,580
Total liabilities		13,896,431			15,136,500
Stockholders’ equity:
Common stock, no par value. Authorized 1,000 shares; issued and outstanding 411 shares		48,446			48,446
Accumulated other comprehensive loss		(249,227	)		(135,967	)
Notes receivable from and advances to stockholders		(396,201	)		(388,928	)
Retained earnings		49,614,524			47,530,532
Total stockholders’ equity		49,017,542			47,054,083
	$	62,913,973			62,190,583

 

See accompanying notes to condensed consolidated financial statements.

T-14

TRIAD MINING, INC. AND SUBSIDIARY
Condensed Consolidated Statements of Income
(unaudited)

	Three Months Ended
	March 31, 2005			March 31, 2004
Coal sales	$	23,396,026			19,645,000
Operating costs and expenses:
Cost of coal sold		17,202,910			14,111,235
Selling, administrative, and other		886,214			841,625
Depreciation		1,204,724			1,125,300
Amortization		425,733			189,623
Total operating costs and expenses		19,719,581			16,267,783
Income from operations		3,676,445			3,377,217
Other income (expense):
Interest income		149,543			122,055
Interest expense		(21,031	)		(53,313	)
Loss on sale of investments		(19,211	)		(13,488	)
Loss on sale of assets		(80,500	)		—
Miscellaneous income		28,875			18,061
Total other income		57,676			73,315
Net income	$	3,734,121			3,450,532

 

See accompanying notes to condensed consolidated financial statements.

T-15

TRIAD MINING, INC. AND SUBSIDIARY
Condensed Consolidated Statements of Changes in Stockholders’ Equity
and Other Comprehensive Income
Three Months Ended March 31, 2005 and the Year Ended December 31, 2004
(unaudited)

	Common Stock		Accumulated other comprehensive loss			Notes receivable from and advances to stockholders			Retained earnings			Total stockholders’ equity
Balances at January 1, 2004	$	48,446		(45,635	)		(137,351	)		45,970,492			45,835,952
Comprehensive income:
Net income		—		—			—			13,525,541			13,525,541
Other comprehensive loss:
Unrealized losses on securities, net of reclassification adjustment		—		(90,332	)		—			—			(90,332	)
Comprehensive income													13,435,209
Increase in receivables from and advances to stockholders, net		—		—			(251,577	)		—			(251,577	)
Distributions to stockholders		—		—			—			(11,965,501	)		(11,965,501	)
Balances at December 31, 2004		48,446		(135,967	)		(388,928	)		47,530,532			47,054,083
Comprehensive income:
Net income		—		—			—			3,734,121			3,734,121
Other comprehensive loss:
Unrealized losses on securities, net of reclassification adjustment		—		(113,260	)		—			—			(113,260	)
Comprehensive income													3,620,861
Increase in receivables from and advances to stockholders, net		—		—			(7,273	)		—			(7,273	)
Distributions to stockholders		—		—			—			(1,650,129	)		(1,650,129	)
Balances at March 31, 2005	$	48,446		(249,227	)		(396,201	)		49,614,524			49,017,542

 

See accompanying notes to condensed consolidated financial statements.

T-16

TRIAD MINING, INC. AND SUBSIDIARY
Condensed Consolidated Statements of Cash Flows
(unaudited)

	Three Months Ended
	March 31, 2005			March 31, 2004
Operating activities:
Net income	$	3,734,121			3,450,532
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization		1,630,457			1,314,923
Accretion of reclamation and mine closing liabilities		92,648			80,800
Loss on sale of assets		80,500			—
Loss on sale of securities		19,211			13,488
Change in operating assets and liabilities
Accounts receivable		(2,945,881	)		(317,797	)
Inventories		(300,590	)		(552,232	)
Advance royalties		(164,796	)		(7,391	)
Prepaid expenses		177,925			90,406
Accrued interest		1,826			(54,410	)
Other assets		28,664			160,807
Accounts payable		10,241			86,778
Other liabilities		690,505			213,199
Net cash provided by operating activities		3,054,831			4,479,103
Investing activities:
Capital expenditures		(1,756,006	)		(46,008	)
Purchases of securities		(2,224,401	)		(872,365	)
Proceeds from maturities of securities		1,953,211			287,300
Repayment and advances to stockholders, net		(7,273	)		102,710
Net cash used in investing activities		(2,034,469	)		(528,363	)
Financing activities:
Distributions to stockholders		(1,650,129	)		(1,100,180	)
Repayment of long-term debt		(827,462	)		(613,067	)
Net cash used in financing activities		(2,477,591	)		(1,713,247	)
Net increase (decrease) in cash and cash equivalents		(1,457,229	)		2,237,493
Cash and cash equivalents at beginning of year		8,135,128			9,073,683
Cash and cash equivalents at end of year	$	6,677,899			11,311,176

 

See accompanying notes to condensed consolidated financial statements.

T-17

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
(unaudited)

(1)  OPERATIONS AND SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(a)  Operations and Definitive Agreement to Sell the Outstanding Common Stock

Triad Mining, Inc. (the Company) is engaged in the business of mining and selling coal, primarily to electric utility companies located in Indiana. Sales are made under long-term contracts and in the spot market.

In March 2005, the Company’s stockholders entered into a definitive agreement to sell all of the outstanding common stock of the Company to James River Coal Company (“James River Coal”) for approximately $75,000,000, consisting of $64,000,000 in cash and $11,000,000 of James River Coal common stock. James River Coal is a public company that primarily operates underground mines in Eastern Kentucky.

(b)  Principles of Consolidation

The interim condensed consolidated financial statements include the accounts of Triad Mining, Inc. and its wholly owned subsidiary, Triad Underground Mining, LLC. The interim condensed consolidated financial statements of Triad Mining, Inc. and subsidiary (the Company) as of and for the three months ended March 31, 2005, and for the three months ended March 31, 2004 presented in this report are unaudited. All intercompany transactions have been eliminated. The results of operations for any interim period are not necessarily indicative of the results to be expected for the full year. These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto for the year ended December 31, 2004. The balances presented as of December 31, 2004 are derived from the Company’s audited consolidated financial statements.

(c)  Use of Estimates

Financial statements prepared in conformity with U.S. generally accepted accounting principles require management to make estimates and assumptions that affect the reported amount of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Significant estimates made by management include the accrual for reclamation and mine closure costs, the level of proven and probable reserves used to calculate depletion, and the useful life of depreciable assets. Actual results could differ from these estimates. In the opinion of management, the accompanying unaudited condensed consolidated financial statements contain all adjustments, consisting of only normal recurring accruals, which are necessary to present fairly the consolidated financial position of the Company and the consolidated results of its operations and cash flows for all periods presented.

(d)  Cash and Cash Equivalents

Cash equivalents include highly liquid investments with original maturities of three months or less.

(e)  Available for Sale Securities

The Company classifies its debt and equity securities as available for sale. Available for sale securities are carried at fair value with unrealized gains and losses reported in other comprehensive income (loss). Realized gains and losses on securities available for sale are included in other income (expense) and, when applicable, are reported as a reclassification adjustment in other comprehensive income. Gains and losses on the sale of available for sale securities are determined using the specific identification method.

T-18

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
(unaudited)

(f)  Inventories

Coal and stores inventories are valued at the lower of cost or market. The cost of coal inventories is determined based on the average cost of production, which includes all costs incurred to extract, transport, and process the coal. The cost of store inventories is determined on the first-in, first-out method.

(g)  Property and Equipment

Property and equipment are recorded at cost. Depreciation is determined using the straight-line method over the estimated useful lives of the related assets (ranging from three to ten years). Maintenance expense is recognized when repairs that do not extend an asset’s useful life or increase its utility are performed.

(h)  Mine Development Costs

Mine development costs are capitalized and amortized using the units of production method over estimated total recoverable proved and probable reserves.

(i)  Mineral Rights

Depletion of mineral rights is based on estimated recoverable proven and probable reserves.

(j)  Income Taxes

In 1995, the Company elected to include its taxable income or loss with that of its stockholders (an S-Corporation election) for federal and state income tax purposes. Accordingly, federal and state income tax liabilities or benefits accrue to the stockholders instead of the Company.

(k)  Allowance for Uncollectible Receivables

The Company evaluates the need for an allowance for doubtful accounts based on a review of historical write off experience and industry data. It is management’s opinion that no allowance is necessary for trade receivables as of March 31, 2005 or December 31, 2004.

(l)  Asset Impairment

If facts and circumstances suggest that a long-lived asset may be impaired, the carrying value is reviewed. If this review indicates that the value of the asset will not be recoverable, as determined based on projected undiscounted cash flows related to the asset over its remaining life, then the carrying value of the asset is reduced to its estimated fair value. The Company did not recognize an asset impairment charge in 2004 or in the three months ended 2005.

(m)  Revenue Recognition

Coal sales revenues include sales to customers of coal produced at Company operations. The Company recognizes revenues from coal sales at the time title passes to the customer. Revenues from sources other than coal sales, are included in other revenues and are recognized as services are performed or otherwise earned.

(n)  Advance Coal Royalty

Advance coal royalties are capitalized when paid and charged to expense using the unit-of-production method at the time coal production commences on the respective property.

T-19

TRIAD MINING, INC. AND SUBSIDIARY
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
MARCH 31, 2005
(unaudited)

(o)  Reclamation and Mine Closing Liabilities

Minimum standards for mine reclamation have been established by various regulatory agencies and dictate the reclamation requirements at the Company’s operations. The Company records these reclamation obligations under the provisions of FASB Statement No. 143, Accounting for Asset Retirement Obligations. Statement 143 requires the fair value of a liability for an asset retirement obligation to be recognized in the period in which the legal obligation associated with the retirement of the long-lived asset is incurred. When the liability is initially recorded, the offsetting amount is recorded as an increase in the carrying amount of the long-lived asset. Over time, the liability is accreted as a component of cost of coal sales to its present value each period, and the capitalized cost is depreciated over the useful life of the related asset. A gain or loss upon settlement is recorded upon the settlement of the liability to the extent there is a difference between the liability recognized and the amount of cash paid to settle the obligation. The Company annually reviews its estimated future cash flows for its asset retirement obligations.

(p) Derivatives

The Company currently utilizes interest rate swaps to economically hedge the impact of changes in interest rates on its floating rate debt. Under the terms of these interest rate swaps, the Company is the fixed rate payor and the floating rate receiver. The fair value of the interest rate swaps was recorded on the consolidated balance sheets as a component of accounts payable with changes in the fair value included in net income as a component of miscellaneous income. The notional amount and the fair value liability of these interest rate swaps were $2,066,997 and $16,867, respectively, as of December 31, 2004 and $1,454,835 and $6,697, respectively, as of March 31, 2005.

T-20