ARCH COAL INC - 10-Q Quarterly Report

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

(Mark One)


[ X ]		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
		EXCHANGE ACT OF 1934
		For the Quarterly Period Ended September 30, 2003


[ ]		TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
		EXCHANGE ACT OF 1934
		For the transition period from to

		Commission file number 1-13105

ARCH COAL, INC.

(Exact name of registrant as specified in its charter)


Delaware		43-0921172
(State or other jurisdiction of		(I.R.S. Employer Identification No.)
incorporation or organization)

One CityPlace Drive, Suite 300, St. Louis, Missouri 63141
(Address of principal executive offices)(Zip Code)

Registrant’s telephone number, including area code: (314) 994-2700

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes [X] No [ ]

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Exchange Act). Yes [X] No [ ]

At November 1, 2003, there were 52,652,385 shares of registrant’s common stock outstanding.

TABLE OF CONTENTS


PART I - FINANCIAL INFORMATION
	ITEM 1. FINANCIAL STATEMENTS
		CONDENSED CONSOLIDATED BALANCE SHEETS
		CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
		CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
		NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
	ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
	ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
	ITEM 4. CONTROLS AND PROCEDURES
PART II — OTHER INFORMATION
	ITEM 1. LEGAL PROCEEDINGS
	ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
SIGNATURES
EX-4.1 Amendment to Credit Facility
EX-31.1 Certification-Principal Executive Officer
EX-31.2 Certification-Principal Financial Officer
EX-32.1 Statement-Principal Executive Officer
EX-32.2 Statement-Principal Financial Officer

INDEX


			PAGE
PART I. FINANCIAL INFORMATION
	Item 1. Financial Statements
		Condensed Consolidated Balance Sheets as of September 30, 2003 and December 31, 2002		1
		Condensed Consolidated Statements of Operations for the Three Months Ended September 30, 2003 and 2002 and the Nine Months Ended September 30, 2003 and 2002		2
		Condensed Consolidated Statements of Cash Flows for the Nine Months Ended September 30, 2003 and 2002		3
		Notes to Condensed Consolidated Financial Statements		4
	Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations			13
	Item 3. Quantitative and Qualitative Disclosures About Market Risk			36
	Item 4. Controls and Procedures			36
PART II. OTHER INFORMATION
	Item 1. Legal Proceedings			36
	Item 6. Exhibits and Reports on Form 8-K			36

PART I - FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS

ARCH COAL, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS

(IN THOUSANDS)


				September 30,			December 31,
				2003			2002

				(Unaudited)
Assets
	Current assets
		Cash and cash equivalents		$	125,551		$	9,557
		Trade accounts receivable			122,281			135,903
		Other receivables			23,292			30,927
		Inventories			76,496			66,799
		Prepaid royalties			3,934			4,971
		Deferred income taxes			27,775			27,775
		Other			10,642			15,781

			Total current assets		389,971			291,713

	Property, plant and equipment, net				1,308,865			1,284,968

	Other assets
		Prepaid royalties			67,678			51,078
		Coal supply agreements			9,810			59,240
		Deferred income taxes			245,325			221,116
		Equity investments			227,274			231,551
		Other			62,419			43,142

			Total other assets		612,506			606,127

			Total assets	$	2,311,342		$	2,182,808

Liabilities and stockholders’ equity
	Current liabilities
		Accounts payable		$	97,499		$	113,527
		Accrued expenses			158,074			133,287
		Current portion of debt			69			7,100

			Total current liabilities		255,642			253,914
	Long-term debt				700,071			740,242
	Accrued postretirement benefits other than pension				344,921			324,539
	Asset retirement obligations				144,112			117,804
	Accrued workers’ compensation				80,027			80,985
	Other noncurrent liabilities				134,632			130,461

			Total liabilities		1,659,405			1,647,945

Stockholders’ equity
	Preferred stock				29			—
	Common stock				529			527
	Paid-in-capital				977,113			835,763
	Retained deficit				(275,038	)		(253,943	)
	Treasury stock, at cost				(5,047	)		(5,047	)
	Accumulated other comprehensive loss				(45,649	)		(42,437	)

			Total stockholders’ equity		651,937			534,863

			Total liabilities and stockholders’ equity	$	2,311,342		$	2,182,808

See notes to condensed consolidated financial statements.

ARCH COAL, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(IN THOUSANDS, EXCEPT PER SHARE DATA)
(UNAUDITED)


				Three Months Ended						Nine Months Ended
				September 30,						September 30,

				2003			2002			2003			2002

Revenues and operating income
	Coal sales revenues			$	354,276		$	386,298		$	1,060,558		$	1,103,882
	Income from equity investments				5,657			1,222			28,958			2,291
	Other operating income				10,343			13,235			33,428			37,523

					370,276			400,755			1,122,944			1,143,696

Costs and expenses
	Cost of coal sales				346,142			368,054			1,052,105			1,056,194
	Selling, general and administrative expenses				11,082			9,734			34,845			29,675
	Amortization of coal supply agreements				2,890			5,385			13,209			15,872
	Other expenses				3,636			7,484			13,157			20,856

					363,750			390,657			1,113,316			1,122,597

		Income from operations			6,526			10,098			9,628			21,099
	Interest expense, net:
		Interest expense			(13,187	)		(13,425	)		(36,407	)		(39,783	)
		Interest income			425			217			1,251			799

					(12,762	)		(13,208	)		(35,156	)		(38,984	)
	Other non-operating income (expense):
		Expenses resulting from early debt extinguishment and termination of hedge accounting for interest rate swaps			(2,066	)		—			(6,889	)		—
		Other non-operating income			10,441			—			11,314			—

					8,375			—			4,425			—

			Income (loss) before income taxes and cumulative effect of accounting change		2,139			(3,110	)		(21,103	)		(17,885	)
	Benefit from income taxes				(8,910	)		(4,750	)		(17,510	)		(14,250	)

		Income (loss) before cumulative effect of accounting change			11,049			1,640			(3,593	)		(3,635	)
	Cumulative effect of accounting change				—			—			(3,654	)		—

		Net income (loss)			11,049			1,640			(7,247	)		(3,635	)
	Preferred stock dividends				(1,797	)		—			(4,792	)		—

		Net income (loss) available to common shareholders		$	9,252		$	1,640		$	(12,039	)	$	(3,635	)

	Earnings (loss) per common share
		Earnings (loss) before cumulative effect of accounting change		$	0.18		$	0.03		$	(0.16	)	$	(0.07	)
		Cumulative effect of accounting change			—			—			(0.07	)		—

		Basic and diluted earnings (loss) per common share		$	0.18		$	0.03		$	(0.23	)	$	(0.07	)

	Dividends declared per share			$	0.0575		$	0.0575		$	0.1725		$	0.1725

See notes to condensed consolidated financial statements.

ARCH COAL, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(IN THOUSANDS)
(UNAUDITED)


			Nine Months Ended
			September 30,

			2003			2002

Operating activities
Net loss			$	(7,247	)	$	(3,635	)
Adjustments to reconcile to cash provided by operating activities:
	Depreciation, depletion and amortization			118,142			130,835
	Prepaid royalties expensed			10,206			5,738
	Accretion on asset retirement obligations			10,148			—
	Net gain on disposition of assets			(3,174	)		(501	)
	Income from equity investments			(28,958	)		(2,291	)
	Net distributions from equity investments			32,291			15,177
	Cumulative effect of accounting change			3,654			—
	Other nonoperating (income) expense			(4,425	)		—
	Changes in:
		Receivables		22,004			7,119
		Inventories		(9,446	)		(13,577	)
		Accounts payable and accrued expenses		(8,146	)		403
		Income taxes		(18,868	)		(14,406	)
		Accrued postretirement benefits other than pension		20,381			(1,597	)
		Asset retirement obligations		(12,771	)		6,650
		Accrued workers’ compensation benefits		(958	)		3,947
		Other		(8,577	)		(4,113	)

	Cash provided by operating activities			114,256			129,749

Investing activities
Additions to property, plant and equipment				(91,652	)		(117,363	)
Proceeds from dispositions of property, plant and equipment				3,325			2,231
Proceeds from coal supply agreement				52,548			—
Additions to prepaid royalties				(25,768	)		(21,717	)

	Cash used in investing activities			(61,547	)		(136,849	)

Financing activities
Net proceeds from (payments on) revolver and lines of credit				(72,202	)		24,936
Payments on term loans				(675,000	)		—
Proceeds from issuance of senior notes				700,000			—
Debt financing costs				(18,246	)		(8,228	)
Proceeds from sale and leaseback of equipment				—			9,213
Reduction of obligations under capital leases				—			(7,778	)
Dividends paid				(12,647	)		(9,033	)
Proceeds from issuance of preferred stock				139,024			—
Proceeds from sale of common stock				2,356			313

	Cash provided by financing activities			63,285			9,423

Increase in cash and cash equivalents				115,994			2,323
Cash and cash equivalents, beginning of period				9,557			6,890

Cash and cash equivalents, end of period			$	125,551		$	9,213

See notes to condensed consolidated financial statements.

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
SEPTEMBER 30, 2003
(UNAUDITED)

Note A – General

The accompanying unaudited Condensed Consolidated Financial Statements have been prepared in accordance with generally accepted accounting principles for interim financial reporting and Securities and Exchange Commission regulations, but are subject to any year-end adjustments that may be necessary. In the opinion of management, all adjustments (consisting of normal recurring accruals) considered necessary for a fair presentation have been included. Results of operations for the period ended September 30, 2003 are not necessarily indicative of results to be expected for the year ending December 31, 2003.

Arch Coal, Inc. (the “Company”) operates one reportable segment: the production of steam and metallurgical coal from surface and deep mines throughout the United States, for sale to utility, industrial and export markets. The Company’s mines are primarily located in the central Appalachian and western regions of the United States. All subsidiaries (except as noted below) are wholly owned. Significant intercompany transactions and accounts have been eliminated in consolidation.

The Company’s Wyoming, Colorado and Utah coal operations are included in a joint venture named Arch Western Resources, LLC (“Arch Western”). Arch Western is 99% owned by the Company and 1% owned by BP p.l.c. The Company also acts as the managing member of Arch Western.

The membership interests in the Utah coal operations, Canyon Fuel Company, LLC (“Canyon Fuel”), are owned 65% by Arch Western and 35% by a subsidiary of ITOCHU Corporation. The Company’s 65% ownership of Canyon Fuel is accounted for on the equity method in the Condensed Consolidated Financial Statements as a result of certain super-majority voting rights in the joint venture agreement. Income from Canyon Fuel is reflected in the Condensed Consolidated Statements of Operations as income from equity investment. (See additional discussion in Note F – “Equity Investments”).

The Company owns 34% of the limited partnership units of Natural Resource Partners, LP (“NRP”) and 42.25% of the general partner interest. The Company’s investment in NRP is accounted for on the equity method in the Condensed Consolidated Financial Statements. (See additional discussion in Note F – “Equity Investments”).

Note B – Acquisition of Triton Coal Company

On May 29, 2003, the Company entered into a definitive agreement to acquire (1) Vulcan Coal Holdings, L.L.C. (“Vulcan”), which owns all of the common equity of Triton Coal Company, LLC (“Triton”), and (2) all of the preferred units of Triton, for an aggregate purchase price of $364.0 million, subject to working capital adjustments. Consummation of the transaction is subject to various conditions, including the receipt by the Company and Vulcan of all necessary governmental and regulatory consents and other customary conditions. Upon consummation, the acquisition will be accounted for under the purchase method of accounting in accordance with FASB Statement No. 141, Business Combinations. The Company intends to finance the acquisition with cash, borrowings under its existing revolving credit facility and a $100.0 million term loan facility at its Arch Western subsidiary.

Note C – Preferred Stock Offering

On January 31, 2003, the Company utilized its Universal Shelf Registration Statement and completed a public offering of 2,875,000 shares of 5% Perpetual Cumulative Convertible Preferred Stock. The Company realized net proceeds of $139.0 million from the offering. Dividends on the preferred stock are cumulative and are payable quarterly at the annual rate of 5% of the liquidation preference. Each share of the preferred stock is initially convertible, under certain conditions, into 2.3985 shares of the Company’s common stock. The preferred stock is redeemable, at the Company’s option, on or after January 31, 2008 if certain conditions are met. The holders of the

preferred stock are not entitled to voting rights on matters submitted to the Company’s common shareholders. However, if the Company fails to pay the equivalent of six quarterly dividends, the holders of the preferred stock will be entitled to elect two directors to the Company’s board of directors.

Note D – Adoption of FAS 143

On January 1, 2003, the Company adopted Statement of Financial Accounting Standards No. 143, Accounting for Asset Retirement Obligations (“FAS 143”). FAS 143 requires legal obligations associated with the retirement of long-lived assets to be recognized at fair value at the time the obligations are incurred. Upon initial recognition of a liability, that cost should be capitalized as part of the carrying amount of the related long-lived asset and allocated to expense over the useful life of the asset. Previously, the Company accrued for the expected costs of these obligations over the estimated useful mining life of the property.

The cumulative effect of the change on periods prior to January 1, 2003 resulted in a charge to income of $3.7 million (net of income taxes of $2.3 million), or $0.07 per share, which is included in the Company’s results of operations for the nine months ended September 30, 2003. In addition, the net loss of the Company, excluding the cumulative effect of accounting change, for the nine months ended September 30, 2003 is $1.0 million more ($0.02 per share), than it would have been if the Company had continued to account for these obligations under its old method (there is not a significant difference in the quarter ended September 30, 2003). The unaudited pro forma amounts below reflect the retroactive application of FAS 143 as if the Company had adopted the standard on January 1, 2002 and the corresponding elimination of the cumulative effect of accounting change:


		Three Months Ended				Nine Months Ended
		September 30,				September 30,

		2003		2002		2003			2002

		(in thousands, except per share data)
As reported
	Net income (loss) available to common shareholders	$	9,252	$	1,640	$	(12,039	)	$	(3,635	)
	Basic and diluted income (loss) per share		0.18		0.03		(0.23	)		(0.07	)
Pro forma
	Net income (loss) available to common shareholders	$	9,252	$	1,214	$	(8,385	)	$	(5,379	)
	Basic and diluted income (loss) per share		0.18		0.02		(0.16	)		(0.10	)

If the Company had accounted for its asset retirement obligations in accordance with FAS 143 for all periods presented, the asset retirement obligation liability (including amounts classified as current) would have been $162.0 million and $166.6 million at September 30, 2002 and December 31, 2002, respectively.

The following table describes the changes to the Company’s asset retirement obligation for the nine months ended September 30, 2003:


Balance at December 31, 2002 (including current portion)	$	125,440
Impact of adoption		41,198
Accretion expense		10,148
Additions resulting from property additions		1,301
Payments		(13,567	)

Balance at September 30, 2003		164,520
Current portion included in accrued expenses		(20,408	)

Long-term liability	$	144,112

Note E – Stock-Based Compensation

These interim financial statements include the disclosure requirements of Statement of Financial Accounting Standards No. 123, Accounting for Stock-Based Compensation (“FAS 123”), as amended by Statement of Financial Accounting Standards No. 148, Accounting for Stock-Based Compensation — Transition and Disclosure (“FAS 148”). With respect to accounting for its stock options, as permitted under FAS 123, the Company has retained the intrinsic value method prescribed by Accounting Principles Board Opinion No. 25, Accounting for Stock Issued to Employees (“APB 25”), and related Interpretations. Had compensation expense for stock option grants been determined based on the fair value at the grant dates consistent with the method required by FAS 123, the Company’s net loss available to common shareholders and loss per common share would have been changed to the pro forma amounts as indicated in the following table:


		Three Months Ended					Nine Months Ended
		September 30,					September 30,

		2003		2002			2003			2002

		(in thousands, except per share data)
As reported
	Net income (loss) available to common shareholders	$	9,252	$	1,640		$	(12,039	)	$	(3,635	)
	Basic and diluted income (loss) per share		0.18		0.03			(0.23	)		(0.07	)
Pro forma
	Net income (loss) available to common shareholders	$	6,953	$	(742	)	$	(18,988	)	$	(9,852	)
Basic and diluted income (loss) per share			0.13		(0.01	)		(0.36	)		(0.19	)

Note F – Equity Investments

The Company’s equity investments are comprised of its ownership interests in Canyon Fuel and NRP. Amounts recorded in the Condensed Consolidated Financial Statements are as follows:


		September 30, 2003		December 31, 2002

		(in thousands)
Equity investments:
	Investment in Canyon Fuel	$	156,722	$	160,787
	Investment in NRP		70,552		70,764

Equity investments as reported in the Condensed Consolidated Balance Sheets		$	227,274	$	231,551


		Three Months Ended				Nine Months Ended
		September 30,				September 30,

		2003		2002		2003		2002

		(in thousands)
Income from equity investments:
	Income from investment in Canyon Fuel	$	1,392	$	1,222	$	17,596	$	2,291
	Income from investment in NRP		4,265		—		11,362		—

Income from equity investments in the Condensed Consolidated Statements of Operations		$	5,657	$	1,222	$	28,958	$	2,291

Investment in Canyon Fuel

The following table presents unaudited summarized financial information for Canyon Fuel:


	Three Months Ended						Nine Months Ended
	September 30,						September 30,

Condensed Income Statement Information	2003			2002			2003		2002

	(in thousands)
Revenues	$	57,751		$	52,337		$	179,234	$	189,637
Total costs and expenses		57,879			54,610			161,015		194,209

Net income (loss) before cumulative effect of accounting change	$	(128	)	$	(2,273	)	$	18,219	$	(4,572	)

65% of Canyon Fuel net income (loss) before cumulative effect of accounting change	$	(83	)	$	(1,477	)	$	11,842	$	(2,972	)
Effect of purchase adjustments		1,475			2,699			5,754		5,263

Company’s income from its equity investment in Canyon Fuel	$	1,392		$	1,222		$	17,596	$	2,291

The Company’s income from its equity investment in Canyon Fuel represents 65% of Canyon Fuel’s net income after adjusting for the effect of purchase adjustments related to its investment in Canyon Fuel. The Company’s investment in Canyon Fuel reflects purchase adjustments primarily related to the reduction in amounts assigned to sales contracts, mineral reserves and other property, plant and equipment. The purchase adjustments are amortized consistent with the underlying assets of the joint venture.

Effective January 1, 2003, Canyon Fuel adopted FAS 143 and recorded a cumulative effect loss of $2.4 million. The Company’s 65% share of this amount was offset by purchase adjustments of $0.5 million. These amounts are included in the cumulative effect of accounting change reported in the Company’s Condensed Consolidated Statements of Operations.

Investment in NRP

Summarized financial information for NRP as of September 30, 2003 and for the three and nine months ended September 30, 2003 follows (in thousands):


		Three Months Ended		Nine Months Ended
		September 30, 2003		September 30, 2003

Results of Operations
	Revenues	$	23,539	$	63,448
	Income from operations		12,555		32,704
	Net Income		10,112		28,268
Arch Coal’s income from equity investment in NRP		$	4,265	$	11,362


		September 30,
		2003

Financial Position
	Total assets	$	514,664
	Total liabilities		202,703
	Partners’ equity		311,961
Arch Coal’s equity investment in NRP		$	70,552

Income from the Company’s equity investment in NRP for the three and nine months ended September 30, 2003 represents the Company’s share of NRP’s earnings for the period from June 1, 2003 through August 31, 2003 and the

period from December 1, 2002 through August 31, 2003, respectively. As disclosed in the Company’s annual report, the Company accounts for income from its investment in NRP on a one-month lag.

Note G – Reduction in Force

During the three and nine months ending September 30, 2003, the Company instituted ongoing cost reduction efforts throughout its operations. These cost reduction efforts included the termination of approximately 100 employees at the Company’s corporate headquarters and its eastern mining operations and the recognition of expenses related to severance of $2.6 million in the nine months ended September 30, 2003. Of this amount, $1.6 million was reported as a component of cost of coal sales, with the remainder reported in selling, general and administrative expenses. At September 30, 2003, $0.2 million of the amounts recognized remained accrued as a liability on the Company’s Condensed Consolidated Balance Sheet.

Note H – Other Comprehensive Income

Other comprehensive income items under FAS 130, Reporting Comprehensive Income, are transactions recorded in stockholders’ equity during the year, excluding net income and transactions with stockholders. The following table presents comprehensive income:


	Three Months Ended					Nine Months Ended
	September 30,					September 30,

	2003		2002			2003			2002

			(in thousands)
Net income (loss)	$	11,049	$	1,640		$	(7,247	)	$	(3,635	)
Other comprehensive income (loss) net of tax (net of amounts reclassified to earnings)		2,601		(8,078	)		(3,212	)		(3,583	)

Total comprehensive income (loss)	$	13,650	$	(6,438	)	$	(10,459	)	$	(7,218	)

Other comprehensive income for all periods presented is comprised entirely of mark-to-market adjustments related to the Company’s financial derivatives positions for the periods when those positions were deemed to be effective hedges.

Note I – Inventories

Inventories consist of the following:


	September 30,		December 31,
	2003		2002

	(in thousands)
Coal	$	46,287	$	35,039
Repair parts and supplies		30,209		31,760

	$	76,496	$	66,799

Note J – Debt

Debt consists of the following:


	September 30,		December
	2003		31, 2002

	(in thousands)
Indebtedness to banks under lines of credit	$	—	$	—
Indebtedness to banks under revolving credit agreement, expiring April 18, 2007		—		65,000
Indebtedness to banks under variable rate, non-amortizing term loan due April 18, 2007		—		150,000
Indebtedness to banks under variable rate, non-amortizing term loan due April 18, 2008		—		525,000
6.75% senior notes due July 1, 2013		700,000		—
Other		140		7,342

		700,140		747,342
Less current portion		69		7,100

Long-term debt	$	700,071	$	740,242

On June 25, 2003, Arch Western Finance, LLC, a subsidiary of Arch Western, completed the offering of $700 million of senior notes and utilized the proceeds of the offering to repay Arch Western’s existing term loans. The senior notes bear a fixed rate of interest of 6.75% and are due in full on July 1, 2013. Interest on the senior notes is payable on January 1 and July 1 each year commencing January 1, 2004. The senior notes are guaranteed by Arch Western and certain of Arch Western’s subsidiaries and are secured by a security interest in loans made to Arch Coal by Arch Western. The terms of the senior notes contain restrictive covenants that limit Arch Western’s ability to, among other things, incur additional debt, sell or transfer assets, and make investments.

In connection with the repayment of the term loans, the Company recognized expenses related to the write-off of loan fees and other debt extinguishment costs. Additionally, the Company had designated certain interest rate swaps as hedges of the variable rate interest payments due under the Arch Western term loans. Pursuant to the requirements of Statement of Financial Accounting Standards No. 133, Accounting for Derivative Instruments and Hedging Activities (“FAS 133”), historical mark-to-market adjustments related to these swaps through June 25, 2003 of $27.0 million (net of tax) were deferred as a component of Accumulated Other Comprehensive Loss. Subsequent to the repayment of the term loans, these deferred amounts will be amortized as additional expense over the contractual terms of the swap agreements. The swap agreements’ contractual termination dates range from September 2005 through October 2007. For the quarter and nine months ending September 30, 2003, the Company recognized expense resulting from early debt extinguishment and termination of hedge accounting for interest rate swaps of $2.1 million and $6.9 million, respectively. Of these amounts, $2.1 million and $2.2 million, respectively, related to the amortization of previously deferred mark-to-market adjustments. The remaining $4.7 million of the expense recognized in the nine months ending September 30, 2003 represents early debt extinguishment costs.

Changes in the market value of the swaps subsequent to the repayment of the loans on June 25, 2003 are recognized as income or expense. During the quarter and nine months ended September 30, 2003, the Company recognized income of $10.6 million and $11.6 million, respectively, from changes in the market value of the swaps. This amount is included in the line item “Other non-operating income” in the accompanying Condensed Consolidated Statements of Operations.

On September 19, 2003, Arch Western established a new term loan facility that provides for a $100 million term loan. The facility is subject to certain conditions of borrowing, including the consummation of the Company’s anticipated acquisition of Vulcan. Currently, no amount is available to the Company under the facility. If Arch Western borrows pursuant to the terms of the facility, the term loan will be due in quarterly installments from October 2004 through April 2007.

Note K – Buyout of Coal Supply Agreement

In April 2003, the Company agreed to terms with a large customer seeking to buy out of the remaining term of an above-market coal supply contract. The buyout resulted in the receipt of $52.5 million in cash during the quarter. The Company recorded a deferred gain of approximately $15 million related to this transaction, which will be recognized ratably through 2012.

Note L – Contingencies

The Company is a party to numerous claims and lawsuits with respect to various matters. The Company provides for costs related to contingencies when a loss is probable and the amount is reasonably determinable. After conferring with counsel, it is the opinion of management that the ultimate resolution of these claims, to the extent not previously provided for, will not have a material adverse effect on the consolidated financial position, results of operations or liquidity of the Company.

Note M – Transactions or Events Affecting Comparability of Reported Results

During the three and nine months ended September 30, 2003, the Company recognized gains of $1.4 million and $2.9 million, respectively from sales of land at one of its idle properties. These amounts have been recorded as other operating income in the accompanying Condensed Consolidated Statements of Operations.

During the three and nine months ended September 30, 2003, the Company recognized income of $1.6 million resulting from the collection of receivables which had previously been estimated to be uncollectible and had been fully reserved in prior periods.

During the nine months ended September 30, 2003, the Company was notified by the State of Wyoming of a favorable ruling as it relates to the Company’s calculation of coal severance taxes. The ruling resulted in a refund of previously paid taxes and the reversal of previously accrued taxes payable. The impact on the three and nine months ended September 30, 2003 was a loss of $0.8 million and gain of $2.5 million, respectively. During the three months ended September 30, 2003, the Company revised its estimate of amounts it expects to ultimately collect based on additional information obtained during such period.

During the nine months ended September 30, 2003, the Company received $1.4 million from a customer that did not meet its contractual purchase requirements. This amount has been recorded as other operating income in the accompanying Condensed Consolidated Statements of Operations.

During the nine months ended September 30, 2002, the Company settled certain coal contracts with a customer that was partially unwinding its coal supply position and desired to buy out of the remaining terms of those contracts. The settlements resulted in a pre-tax gain of $5.6 million which was recognized in other operating income in the Condensed Consolidated Statements of Operations.

During the nine months ended September 30, 2002, the Company recognized a pre-tax gain of $4.6 million during the quarter as a result of a workers’ compensation premium adjustment refund from the State of West Virginia. During 1998, the Company entered into the West Virginia workers’ compensation plan at one of its subsidiary operations. The subsidiary paid standard base rates until the West Virginia Division of Workers’ Compensation could determine the actual rates based on claims experience. Upon review, the Division of Workers’ Compensation refunded $4.6 million in premiums which the Company received during the quarter ended June 30, 2002. Partially offsetting this gain was an increase to the workers’ compensation accrual resulting in a pre-tax loss of $3.3 million caused by adverse experience at several of the Company’s self-insured locations. These workers’ compensation items were recognized as adjustments to costs of coal sales in the Condensed Consolidated Statements of Operations.

Note N - Earnings (Loss) per Share

The following table sets forth the computation of basic and diluted earnings (loss) per common share from continuing operations.


		Three Months Ended					Nine Months Ended
		September 30,					September 30,

		2003			2002		2003			2002

		(in thousands, except per share data)
Numerator:
	Net income (loss)	$	11,049		$	1,640	$	(7,247	)	$	(3,635	)
	Preferred stock dividends		(1,797	)		—		(4,792	)		—

Net income (loss) available to common shareholders		$	9,252		$	1,640	$	(12,039	)	$	(3,635	)

Denominator:
	Weighted average shares – denominator for basic		52,520			52,380		52,441			52,371
	Dilutive effect of employee stock options		304			121		—			—

	Adjusted weighted average shares – denominator for diluted		52,824			52,501		52,441			52,371

Earnings (loss) per common share
	Basic	$	0.18		$	.03	$	(0.23	)	$	(.07	)
	Diluted	$	0.18		$	.03	$	(0.23	)	$	(.07	)

For the nine month periods ending September 30, 2003 and 2002, employee stock options did not have a dilutive impact because the Company incurred losses in those periods. The Company’s Perpetual Cumulative Convertible Preferred Stock has not been considered in the calculation of the number of diluted shares outstanding because the conditions necessary for the shares to become convertible have not been met as of September 30, 2003.

Note O – Guarantees

The Company holds a 17.5% general partnership interest in Dominion Terminal Associates (“DTA”), which operates a ground storage-to-vessel coal transloading facility in Newport News, Virginia. DTA leases the facility from Peninsula Ports Authority of Virginia (“PPAV”) for amounts sufficient to meet debt-service requirements. Financing is provided through $132.8 million of tax-exempt bonds issued by PPAV (of which the Company is responsible for 17.5%, or $23.2 million), which mature July 1, 2016. Under the terms of a throughput and handling agreement with DTA, each partner is charged its share of cash operating and debt-service costs in exchange for the right to use its share of the facility’s loading capacity and is required to make periodic cash advances to DTA to fund such costs. On a cumulative basis, costs exceeded cash advances by $13.0 million at September 30, 2003 (such amount is included in other noncurrent liabilities). Future payments for fixed operating costs and debt service are estimated to approximate $2.3 million annually through 2015 and $26.0 million in 2016.

In connection with the Company’s acquisition of the coal operations of Atlantic Richfield Company (“ARCO”) and the simultaneous combination of the acquired ARCO operations and the Company’s Wyoming operations into the Arch Western joint venture, the Company agreed to indemnify another member of Arch Western against certain tax liabilities in the event that such liabilities arise as a result of certain actions taken prior to June 1, 2013, including the sale or other disposition of certain properties of Arch Western, the repurchase of certain equity interests in Arch Western by Arch Western or the reduction under certain circumstances of indebtedness incurred by Arch Western in connection with the acquisition. Depending on the time at which any such indemnification obligation was to arise, it could have a material adverse effect on the business, results of operations and financial condition of the Company.

Note P - Reclassifications

Certain amounts in the 2002 financial statements have been reclassified to conform with the classifications in the 2003 financial statements with no effect on previously reported net income or stockholders’ equity.

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

FORWARD-LOOKING STATEMENTS

Statements in this quarterly report which are not statements of historical fact are forward-looking statements within the “safe harbor” provision of the Private Securities Litigation Reform Act of 1995. These forward-looking statements are based on the information available to, and the expectations and assumptions deemed reasonable by, the Company at the time the statements were made. Because these forward-looking statements are subject to various risks and uncertainties, actual results may differ materially from those projected in the statements. These expectations, assumptions and uncertainties include the Company’s expectation of growth in the demand for electricity; belief that legislation and regulations relating to the Clean Air Act and the relatively higher costs of competing fuels will increase demand for its compliance and low-sulfur coal; expectation that the Company will continue to have adequate liquidity from its cash flow from operations, together with available borrowings under its credit facilities, to finance the Company’s working capital needs and meet its debt reduction goals; a variety of market, operational, geologic, permitting, labor and weather related factors and the other risks and uncertainties which are described below under “Contingencies” and “Certain Trends and Uncertainties.”

RESULTS OF OPERATIONS

Items Affecting Comparability of Reported Results

The comparison of our operating results for the quarter to date and year to date periods ending September 30, 2003 and 2002 are affected by the following significant items:


		Three months ended					Nine months ended
		September 30,					September 30,

		2003			2002		2003			2002
(Dollar amounts in millions)
Operating Income
	Severance tax recoveries	$	(0.8	)	$	—	$	2.5		$	—
	Reversal of accounts receivable allowance		1.6					1.6
	Reduction in workforce		—			—		(2.6	)		—
	Gain from land sale		1.4			—		2.9			—
	Gain from coal sales contract shortfall		—			—		1.4			—
	Gain on contract buyout		—			—		—			5.6
	Workers’ compensation premium adjustment		—			—		—			4.6

Net impact on operating income			2.2			—		5.8			10.2
Other
	Expenses resulting from early debt extinguishment and termination of hedge accounting for interest rate swaps		(2.1	)		—		(6.9	)		—
	Mark-to-market adjustments on interest rate swaps that no longer qualify as hedges		10.6			—		11.6			—

Net impact on pre-tax income		$	10.7		$	—	$	10.5		$	10.2

Severance Tax Recoveries

During the nine months ended September 30, 2003, the Company was notified by the State of Wyoming of a favorable ruling as it relates to the Company’s calculation of coal severance taxes. The ruling resulted in a refund of previously paid taxes and the reversal of previously accrued taxes payable. During the three months ended September 30, 2003, the Company revised its estimate of amounts it expects to ultimately collect based on additional information obtained during such period.

Reversal of Accounts Receivable Allowance

During the three and nine months ended September 30, 2003, the Company recognized income resulting from the collection of receivables which had previously been estimated to be uncollectible and had been fully reserved in prior periods.

Reduction in Workforce

During the nine months ending September 30, 2003, the Company instituted cost reduction efforts throughout its operations. These cost reduction efforts included the termination of approximately 100 employees at the Company’s corporate office and eastern mining operations. Of the expense recognized, $1.6 million was recognized as a component of cost of coal sales during the nine months ended September 30, 2003, with the remainder recognized as a component of selling, general and administrative expenses.

Gain from Land Sale

During the three and nine months ended September 30, 2003, the Company recognized gains from land sales at one of its idle properties. These gains are reported as other operating income.

Gain from Coal Sales Contract Shortfall

During the first nine months of 2003, the Company received $1.4 million from a customer that did not meet its contractual purchase requirements.

Expenses resulting from early debt extinguishment and termination of hedge accounting for interest rate swaps

On June 25, 2003, the Company repaid the term loans of its subsidiary, Arch Western, with the proceeds from the offering of senior notes. In connection with the repayment of the term loans, the Company recognized expenses related to the write-off of loan fees and other debt extinguishment costs. Additionally, the Company had designated certain interest rate swaps as hedges of the variable rate interest payments due under the Arch Western term loans. Pursuant to the requirements of Statement of Financial Accounting Standards No. 133, Accounting for Derivative Instruments and Hedging Activities (“FAS 133”), historical mark-to-market adjustments related to these swaps through June 25, 2003 were deferred as a component of Accumulated Other Comprehensive Loss. Subsequent to the repayment of the term loans, these deferred amounts will be amortized as additional expense over the contractual terms of the swap agreements. For the quarter and nine months ending September 30, 2003, the Company recognized expense of $2.1 million and $2.2 million, respectively, related to the amortization of previously deferred mark-to-market adjustments. The remainder of the expense recognized in the nine months ending September 30, 2003 represents early debt extinguishment costs.

Mark-To-Market Adjustments

The Company is a party to several interest rate swap agreements that were entered into in order to hedge the variable rate interest payments due under Arch Western’s term loans. Subsequent to the repayment of those term loans, the swaps no longer qualify for hedge accounting under FASB Statement No. 133. As such, changes in the market value of the swap agreements are recorded as a component of income.

Gain on Contract Buyout

During the first nine months of 2002, the Company settled certain coal contracts with a customer that was partially unwinding its coal supply position and desired to buy out of the remaining terms of those contracts. The settlements resulted in a pre-tax gain which was recognized in other operating income in the Condensed Consolidated Statements of Operations.

Workers’ Compensation Premium Adjustment

During the nine months ended September 30, 2002, the Company received a workers’ compensation premium adjustment refund from the State of West Virginia. During 1998, the Company entered into the West Virginia workers’ compensation plan at one of its subsidiary operations. The subsidiary paid standard base rates until the West Virginia Division of Workers’ Compensation could determine the actual rates based on claims experience. Upon review, the Division of Workers’ Compensation refunded $4.6 million in premiums.

Quarter Ended September 30, 2003, Compared
to Quarter Ended September 30, 2002

Revenues and Operating Income


	Three Months Ended
	September 30,				Increase (Decrease)
(Dollar amounts in thousands)	2003		2002		$			%

Coal sales revenues	$	354,276	$	386,298	$	(32,022	)		(8.3	%)
Income from equity investments		5,657		1,222		4,435			N/A
Other operating income		10,343		13,235		(2,892	)		(21.9	%)

	$	370,276	$	400,755	$	(30,479	)		(7.6	%)

Tons sold (in thousands)		25,252		28,720		(3,468	)		(12.1	%)
Coal sales realization per ton	$	14.03	$	13.45	$	0.58			4.3	%

Coal sales revenues. The decline in coal sales revenues was attributable to the 12.1% reduction in tons sold, which was partially offset by an increase in the average per ton realization. The increase in per ton realization was due to higher contract prices on shipments made during the quarter ending September 30, 2003 as compared to the same period in 2002. The mix of sales between the Company’s eastern and western operations was not significantly different in the two quarters.

Income from equity investments. Income from equity investments for the quarter ended September 30, 2003 is comprised of $1.4 million from the Company’s investment in Canyon Fuel and $4.3 million from the Company’s investment in Natural Resource Partners (“NRP”). The Company’s income from equity investments for the quarter ended September 30, 2002 was solely from the Company’s investment in Canyon Fuel.

Other operating income. The decline in other operating income results primarily from lower outlease royalty income in 2003 due to the contribution of reserves and related outleases to NRP. This decline was partially offset by the gain on the sale of land described above.

Costs and Expenses


	Three Months Ended
	September 30,				Increase (Decrease)
(Dollar amounts in thousands)	2003		2002		$			%

Cost of coal sales	$	346,142	$	368,054	$	(21,912	)		(6.0	%)
Selling, general and administrative expenses		11,082		9,734		1,348			13.8	%
Amortization of coal supply agreements		2,890		5,385		(2,495	)		(46.3	%)
Other expenses		3,636		7,484		(3,848	)		(51.4	%)

	$	363,750	$	390,657	$	(26,907	)		(6.9	%)

Cost of coal sales per ton sold	$	13.71	$	12.82	$	0.89			6.9	%

Cost of coal sales. The decrease in cost of coal sales is primarily attributable to lower sales volumes as described above. Cost of coal sales per ton sold increased primarily due to increased costs of the Company’s pension and postretirement benefit plans of $7.6 million and to the impact of the Company’s fixed costs being spread over fewer tons. Additionally, costs for workers’ compensation were $1.5 million higher in the quarter ended September 30, 2003 as compared to the same period in 2002, primarily related to the Company’s eastern operations.

Selling, general and administrative expenses. The increase in selling, general and administrative expenses is primarily due to increased salary and benefit costs of $2.2 million. This increase is primarily attributable to increased costs related to the Company’s postretirement and pension plans of $0.6 million and to the Company’s deferred compensation plans of $0.6 million.

Amortization of coal supply agreements. The decrease in amortization of coal supply agreements is due primarily to a decrease in the coal supply agreements asset balance. The decrease in the asset balance is primarily the result of a buyout of a significant supply contract in the second quarter of 2003.

Other expenses. The decrease in other expenses is primarily a result of lower costs to terminate certain contractual obligations for the purchase or sale of coal as compared to the prior year’s period.

Interest Expense, Net


	Three Months Ended
	September 30,						Increase (Decrease)
(Dollar amounts in thousands)	2003			2002			$			%

Interest expense	$	13,187		$	13,425		$	(238	)		(1.8	%)
Interest income		(425	)		(217	)		(208	)		(95.9	%)

	$	12,762		$	13,208		$	(446	)		(3.4	%)

Interest expense. Interest expense declined slightly due to the fact that average debt levels were approximately 14% lower in the quarter ended September 30, 2003 as compared to the same period in 2002. The impact of the lower debt levels was reduced by higher effective interest rates in the quarter ended September 30, 2003. During the quarter ended September 30, 2003, substantially all of the Company’s outstanding debt bore interest at a fixed rate of 6.75%. During the quarter ended September 30, 2002, substantially all of the Company’s outstanding debt bore interest at a variable based on LIBOR. The LIBOR-based rates in that period were lower than the fixed rate that the Company’s debt currently bears.

Other Non-operating Income and Expense

Amounts reported as non-operating consist of income or expense resulting from the Company’s financing activities other than interest. As described above, the Company’s results of operations for the quarter ended September 30, 2003 include expenses of $2.1 million related to the termination of hedge accounting and resulting amortization of amounts that had previously been deferred.

Additionally, during the quarter ended September 30, 2003, the Company recognized income of $10.6 million from mark-to-market adjustments for interest rate swap agreements which no longer qualify for hedge accounting.

Income Taxes


	Three Months Ended
	September 30,				Increase (Decrease)
(Dollar amounts in thousands)	2003		2002		$		%

Benefit from income taxes	$	8,910	$	4,750	$	4,160		87.6	%

The Company’s effective tax rate is sensitive to changes in estimates of annual profitability and percentage depletion. The increase in the income tax benefit recorded in the third quarter of 2003 as compared to the same period in 2002 is primarily the result of tax elections made regarding reclamation costs at certain mines.

Net Income


	Three Months Ended
	September 30,				Increase (Decrease)
(Dollar amounts in thousands)	2003		2002		$		%

Net income (loss)	$	11,049	$	1,640	$	9,409		573.7	%

The increase in net income is primarily attributable to the mark-to-market adjustments and increased income tax benefit, both of which are described above.

Preferred Stock Dividends

On January 31, 2003, the Company utilized its Universal Shelf Registration Statement and completed a public offering of 2,875,000 shares of 5% Perpetual Cumulative Convertible Preferred Stock. Dividends on the preferred stock are cumulative and are payable quarterly at the annual rate of 5% of the liquidation preference. The Company’s net income available to common shareholders for the three months ending September 30, 2003 includes $1.8 million of preferred dividends.

Nine Months Ended September 30, 2003, Compared
to Nine Months Ended September 30, 2002

Revenues and Operating Income


	Nine Months Ended
	September 30,				Increase (Decrease)
(Dollar amounts in thousands)	2003		2002		$			%

Coal sales revenues	$	1,060,558	$	1,103,882	$	(43,324	)		(3.9	%)
Income from equity investments		28,958		2,291		26,667			N/A
Other operating income		33,428		37,523		(4,095	)		(10.9	%)

	$	1,122,944	$	1,143,696	$	(20,752	)		(1.8	%)

Tons sold (in thousands)		73,594		78,337		(4,743	)		(6.1	%)
Coal sales realization per ton	$	14.41	$	14.09	$	0.32			2.3	%

Coal sales revenues. The decline in coal sales revenue is the result of a decline in sales volumes. This decline was partially mitigated by higher average sales prices. The increase in per ton coal sales realization is due to higher contract pricing. The higher prices offset the impact of a change in the sales mix between the Company’s eastern and western operations. During the nine months ended September 30, 2003, a greater percentage of the Company’s sales volumes were from its western operations, which have lower pricing than the eastern operations.

Income from equity investments. Income from equity investments for the nine months ended September 30, 2003 is comprised of $17.6 million of income from the Company’s investment in Canyon Fuel, and $11.3 million from the Company’s investment in NRP. Income from equity investments for the first nine months of 2002 is comprised solely of income from the Company’s investment in Canyon Fuel. The improved results from Canyon Fuel are due primarily to improved operating margins, as reduced operating costs more than offset slightly lower realizations.

Other operating income. The decrease in other operating income is due primarily to lower outlease royalty income resulting from the contribution of reserves and the related leases to NRP. The royalty income recorded by the Company in the nine months ended September 30, 2003 was approximately $6.4 million lower than that reported in the same period in 2002. This decline was partially offset by the gains on the sale of land described above.

Costs and Expenses


	Nine Months Ended
	September 30,				Increase (Decrease)
(Dollar amounts in thousands)	2003		2002		$			%

Cost of coal sales	$	1,052,105	$	1,056,194	$	(4,089	)		(0.4	%)
Selling, general and administrative expenses		34,845		29,675		5,170			17.4	%
Amortization of coal supply agreements		13,209		15,872		(2,663	)		(16.8	%)
Other expenses		13,157		20,856		(7,699	)		(36.9	%)

	$	1,113,316	$	1,122,597	$	(9,281	)		(0.8	%)

Cost of coal sales per ton sold	$	14.30	$	13.48	$	0.82			6.1	%

Cost of coal sales. Cost of coal sales was relatively unchanged despite a decrease in coal sales due primarily to increased costs related to the Company’s pension and postretirement medical plans of $25.8 million. Additionally, the Company experienced higher costs due to disruptions in production resulting from severe weather in February and March 2003 at certain of its operations and to higher prices for operating supplies, including diesel fuel and explosives.

Selling, general and administrative expenses. The increase in selling, general and administrative expenses is due primarily to higher salary and benefit costs of approximately $5.5 million, including the costs of the reduction in workforce described above.

Interest Expense, Net


	Nine Months Ended
	September 30,						Increase (Decrease)
(Dollar amounts in thousands)	2003			2002			$			%

Interest expense	$	36,407		$	39,783		$	(3,376	)		(8.5	%)
Interest income		(1,251	)		(799	)		(452	)		(56.6	%)

	$	35,156		$	38,984		$	(3,828	)		(9.8	%)

Interest expense. The decrease in interest expense is primarily attributable to a decrease in outstanding borrowings during the nine months ended September 30, 2003 as compared to the same period in 2002.

Other Non-operating Income and Expense

Amounts reported as non-operating consist of income or expense resulting from the Company’s financing activities other than interest. As described above, the Company’s results of operations for the nine months ended September 30, 2003 include expenses of $4.7 million related to debt extinguishment costs and $2.2 million related to the termination of hedge accounting and resulting amortization of amounts that had previously been deferred.

Additionally, during the nine months ended September 30, 2003, the Company recognized income of $11.6 million from mark-to-market adjustments for interest rate swap agreements which no longer qualify for hedge accounting.

Income Taxes


	Nine Months Ended
	September 30,				Increase (Decrease)
(Dollar amounts in thousands)	2003		2002		$		%

Benefit from income taxes	$	17,510	$	14,250	$	3,260		22.9	%

The Company’s effective tax rate is sensitive to changes in estimates of annual profitability and percentage depletion. The increase in the income tax benefit for the first nine months of 2003 as compared to the same period in 2002 is primarily the result of tax elections made regarding reclamation costs at certain mines.

Net Loss Before Cumulative Effect of Accounting Change


	Nine Months Ended
	September 30,						Increase (Decrease)
(Dollar amounts in thousands)	2003			2002			$		%

Net loss before cumulative effect of accounting change	$	(3,593	)	$	(3,635	)	$	42		1.2	%

The net loss for the nine months ended September 30, 2003 is comparable to that for the period ended September 30, 2002 as a decline in operating income was offset by the mark-to-market gains and increased tax benefit described above.

Cumulative Effect of Accounting Change

Effective January 1, 2003, the Company adopted Statement of Financial Accounting Standards No. 143, Accounting for Asset Retirement Obligations (“FAS 143”). FAS 143 requires legal obligations associated with the retirement of long-lived assets to be recognized at fair value at the time obligations are incurred. Upon initial recognition of a liability, that cost should be capitalized as part of the related long-lived asset and allocated to expense over the useful life of the asset. Application of FAS 143 resulted in a cumulative effect loss as of January 1, 2003 of $3.7 million, net of tax.

Preferred Stock Dividends

On January 31, 2003, the Company utilized its Universal Shelf Registration Statement and completed a public offering of 2,875,000 shares of 5% Perpetual Cumulative Convertible Preferred Stock. Dividends on the preferred stock are cumulative and are payable quarterly at the annual rate of 5% of the liquidation preference. The Company’s net loss available to common shareholders for the nine months ending September 30, 2003 includes $4.8 million of preferred dividends.

DISCLOSURE CONTROLS

An evaluation was performed under the supervision and with the participation of the Company’s management, including the CEO and CFO, of the effectiveness of the design and operation of the Company’s disclosure controls and procedures as of September 30, 2003. Based on that evaluation, the Company’s management, including the CEO and CFO, concluded that the Company’s disclosure controls and procedures were effective as of such date. There have been no significant changes in the Company’s internal controls or in other factors that could significantly affect internal controls subsequent to September 30, 2003.

OUTLOOK

Vulcan Acquisition. On May 29, 2003, the Company entered into a definitive agreement to acquire (1) Vulcan Coal Holdings, L.L.C. (“Vulcan”), which owns all of the common equity of Triton Coal Company, LLC (“Triton”), and (2) all of the preferred units of Triton, for an aggregate purchase price of $364.0 million, subject to working capital adjustments. Consummation of the transaction is subject to various conditions, including the receipt by the Company and Vulcan of all necessary governmental and regulatory consents and other customary conditions. The Company intends to finance the acquisition with cash, borrowings under its existing revolving credit facility and a $100 million term loan at its Arch Western subsidiary.

Triton is the nation’s seventh largest coal producer and the operator of two mines in the Powder River Basin. These mines, North Rochelle and Buckskin, produced a combined total of 42.2 million tons of coal in 2002 and are supported by approximately 744 million tons of proven and probable reserves. The North Rochelle mine produces 8,800 Btu super-compliance quality coal on a reserve base of approximately 250 million tons. In 2002, North Rochelle produced 23.9 million tons of coal. The Buckskin mine produces 8,400 Btu compliance quality coal on a reserve base of approximately 494 million tons. In 2002, Buckskin produced 18.3 million tons of coal.

The acquisition of Triton will increase the Company’s total reserves in the Powder River Basin by approximately 50%, from 1.6 billion tons to 2.3 billion tons. North Rochelle and Black Thunder are contiguously located, sharing a 5.5-mile property line. The Company has identified expected synergies, based on Triton’s 2002 earnings, of approximately $18 million to $22 million annually that may be realized through the operational integration of Triton’s North Rochelle mine and the Black Thunder mine.

Production Levels. The Company reduced its overall rate of coal production by approximately 6% during the first nine months of 2003 as compared to the same period in 2002. This was in addition to a reduction in overall production of approximately 5% during 2002. These actions were taken in response to unfavorable spot coal markets following an extremely mild winter in 2001-2002, a period of industrial economic weakness that dampened electricity demand and an effort by electric utilities to reduce coal stockpile levels. Although the timing of any recovery in coal markets remains uncertain, there have been indications that prices may return to more favorable levels in the future. These indications include more normal weather patterns over much of the country, some indication of economic recovery and an overall decrease in coal production and utility stockpiles.

The Company’s 65% owned Canyon Fuel subsidiary previously announced that its Skyline mine is scheduled to be idled by June 20, 2004. The Skyline mine produced 2.2 million tons of coal in the first nine months of 2003 and contributed $5.6 million to the Company’s operating income in the first nine months of 2003. Canyon Fuel anticipates increasing production from its other two mines to make up a portion of the scheduled production decrease associated with the idling.

Postretirement Obligations. The Company expects to incur significantly higher expenses related to its postretirement health care obligations in 2003. These obligations, coupled with a much smaller increase in pension-related expenses, increased costs by $8.2 million and $26.0 million during the third quarter and first nine months of 2003, respectively, and are expected to increase non-cash costs by approximately $8.0 million in the fourth quarter as compared to prior year levels.

Expenses Related to Interest Rate Swaps. The Company had designated certain interest rate swaps as hedges of the variable rate interest payments due under Arch Western’s term loans. Pursuant to the requirements of FASB Statement No. 133, historical mark-to-market adjustments related to these swaps through June 25, 2003 of $27.0 million (net of tax) were deferred as a component of Accumulated Other Comprehensive Loss. Subsequent to the repayment of the term loans, these deferred amounts will be amortized as additional expense over the original contractual terms of the swap agreements. As of September 30, 2003, the remaining deferred amounts will be recognized as expense in the following periods: $2.1 million in the fourth quarter of 2003; $8.3 million in 2004; $7.7 million in 2005; $4.8 million in 2006; and $1.9 million in 2007. Future mark-to-market adjustments for these interest rate swaps will be recognized as income or expense as appropriate.

Permitting Issues. The Company idled its Dal-Tex operation on July 23, 1999 as a result of an adverse ruling in litigation on the issue of valley fills. This ruling was later reversed on appeal; however, the Company has not yet completed the process necessary to obtain the required permits for the mine’s surface operations. Once the Company obtains the necessary permits, it intends to open a surface operation at the mine, subject to then-existing market conditions.

Chief Objectives. The Company continues to focus on taking steps to increase shareholder returns by improving earnings, strengthening cash generation, and improving productivity at its large-scale mines, while building on its leading position in its target coal-producing basins, the Powder River Basin and the Central Appalachian Basin. In addition, the Company is aggressively pursuing savings in both overhead and operating costs. The Company instituted personnel cutbacks at its corporate headquarters and Eastern operations in the first half of 2003 and recently initiated a cost reduction effort targeting key cost drivers at each of its captive mines.

LIQUIDITY AND CAPITAL RESOURCES

The following is a summary of cash provided by or used in each of the indicated types of activities during the nine months ended September 30, 2003 and 2002:


		2003			2002

		(in thousands)
Cash provided by (used in):
	Operating activities	$	114,256		$	129,749
	Investing activities		(61,547	)		(136,849	)
	Financing activities		63,285			9,423

Cash provided by operating activities declined due primarily to lower operating income in the nine months ended September 30, 2003 as compared to the nine months ended September 30, 2002.

Cash used in investing activities during the nine months ended September 30, 2003 was lower than the same period in 2002 due to the receipt of $52.5 million from the buyout of a coal supply contract with above-market pricing. Additionally, capital expenditures were reduced in the first nine months of 2003 as compared to the same period in 2002 due to the Company’s decision to better match its capital expenditures to the weak coal markets during this time. During the first nine months of 2002 and 2003, the Company made the fourth and fifth, respectively, of five annual payments under the Thundercloud federal lease, which is mined by the Black Thunder mine in Wyoming.

Cash provided by financing activities during the first three quarters of 2003 reflects the proceeds from the issuance of the Arch Western senior notes (which were used to retire existing debt) and the proceeds from the sale of preferred stock. On January 31, 2003, the Company utilized its Universal Shelf and completed the sale of 2,875,000 shares of its 5% Perpetual Cumulative Convertible Preferred Stock. The net proceeds from the offering of approximately $139.0 million were used to reduce indebtedness under the Company’s revolving credit facility and for working capital and general corporate purposes, including potential acquisitions. On June 25, 2003, Arch Western Finance, LLC, a subsidiary of Arch Western, completed the offering of $700 million of 6.75% senior notes. The proceeds of the offering were primarily used to repay Arch Western’s existing term loans. The cash provided by financing activities during the nine months ended September 30, 2002 reflects borrowings under the Company’s revolver and line of credit to fund capital expenditures.

The Company generally satisfies its working capital requirements and funds its capital expenditures and debt-service obligations with cash generated from operations. The Company believes that cash generated from operations and its borrowing capacity will be sufficient to meet its working capital requirements, anticipated capital expenditures and scheduled debt payments for at least the next several years. The Company’s ability to satisfy debt service obligations, to fund planned capital expenditures, to make acquisitions and to pay dividends will depend upon its future operating performance, which will be affected by prevailing economic conditions in the coal industry and financial, business and other factors, some of which are beyond the Company’s control.

Expenditures for property, plant and equipment were $91.7 million for the nine months ended September 30, 2003, compared to $117.4 million for the nine months ended September 30, 2002. Capital expenditures are made to improve and replace existing mining equipment, expand existing mines, develop new mines and improve the overall efficiency of mining operations. It is anticipated that future capital expenditures will be funded by available cash and existing credit facilities.

At September 30, 2003, the Company had $44.5 million in letters of credit outstanding, which resulted in $305.5 million of unused capacity under the Company’s revolving credit facility. Sufficient unused capacity is currently available to fund all operating needs. Financial covenant requirements may restrict the amount of unused capacity available to the Company for borrowing and letters of credit.

Financial covenants contained in the Company’s revolving credit facility consist of a maximum leverage ratio, a minimum fixed charge coverage ratio and a minimum net worth test. The leverage ratio requires that the Company

not permit the ratio of total indebtedness at the end of any calendar quarter to adjusted EBITDA (as defined in the agreement) for the four quarters then ended to exceed a specified amount. The fixed charge coverage ratio requires that the Company not permit the ratio of the Company’s adjusted EBITDA plus lease expense to interest expense plus lease expense for the four quarters then ended to be less than a specified amount. The net worth test requires that the Company not permit its net worth to be less than a specified amount plus 50% of cumulative net income.

On June 25, 2003, Arch Western Finance LLC, a subsidiary of Arch Western, completed the offering of $700 million of senior notes and utilized the proceeds of the offering to repay Arch Western’s existing term loans. The senior notes bear a fixed rate of interest of 6.75% and are due in full on July 1, 2013. Interest on the senior notes is payable on January 1 and July 1 each year commencing January 1, 2004. The senior notes are guaranteed by Arch Western and certain of Arch Western’s subsidiaries and are secured by a security interest in loans made to Arch Coal by Arch Western. The terms of the senior notes contain restrictive covenants that limit Arch Western’s ability to, among other things, incur additional debt, sell or transfer assets, and make investments.

On September 19, 2003, Arch Western established a new term loan facility that provides for a $100 million term loan. The facility is subject to certain conditions of borrowing, including the consummation of the Company’s acquisition of Vulcan. Currently, no amount is available to the Company under the facility. If Arch Western borrows pursuant to the terms of the facility, the term loan will be due in quarterly installments from October 2004 through April 2007.

The Company periodically establishes uncommitted lines of credit with banks. These agreements generally provide for short-term borrowings at market rates. At September 30, 2003, there were $20.0 million of such agreements in effect, of which none were outstanding. The Company can also issue an additional $311.8 million in public debt and equity securities under a shelf registration statement.

The Company is exposed to market risk associated with interest rates due to its existing level of indebtedness. At September 30, 2003, substantially all of the Company’s outstanding debt bore interest at fixed rates.

Additionally, the Company is exposed to market risk associated with interest rates resulting from its interest rate swap positions. Prior to the June 25, 2003 Arch Western senior notes offering and subsequent repayment of Arch Western’s term loans, the Company utilized interest rate swap agreements to convert the variable-rate interest payments due under the term loans and the Company’s revolving credit facility to fixed-rate payments. As of June 25, 2003, the Company was a party to interest rate swap agreements having a total notional value of $525.0 million. During the quarter ended September 30, 2003, the Company entered into the following transactions impacting its interest rate swap position:

• Terminated swaps with a notional value of $150.0 million by paying $2.9 million to the swap counterparties.

• Entered into offsetting swap positions with a total notional value of $150.0 million. Under these offsetting positions, the Company pays a variable rate based on LIBOR and receives a fixed rate. The variable rate, reset dates and maturities of the offsetting swaps match those of certain of the Company’s original swap positions. As such, variable amounts paid pursuant to these offsetting positions will equal the variable amounts received under the original swap positions.

After taking into consideration these transactions, as of September 30, 2003, the Company’s net interest rate swap position is as follows:

• Swaps with a notional value of $25.0 million which are designated as hedges of future interest payments to be made under the Company’s revolving credit facility. Under these swaps, the Company pays a fixed rate of 5.96% (before the credit spread over LIBOR) and receives a variable rate based upon 30-day LIBOR. The remaining term of the swap agreements at September 30, 2003 was 44 months.

• Swaps with a notional value of $200.0 million which are not designated as hedges and for which the Company has not entered offsetting positions. Under these swaps, the Company pays a weighted average fixed rate of 4.78% (before the credit spread over LIBOR) and receives a weighted average variable rate based upon 30-day and 90-day LIBOR. The remaining terms of the swap agreements at September 30, 2003 ranged from 23 to 46 months.

• Swaps with a total notional value of $300.0 million consisting of offsetting positions of $150.0 million each. Because of the offsetting nature of these positions, the Company is not exposed to market interest rate risk related to these swaps. Under these swaps, the Company pays a weighted average fixed rate of 5.61% on $150.0 million of notional value and receives a weighted average fixed rate of 2.68% on $150.0 million of notional value. The remaining terms of these swap agreements at September 30, 2003 ranged from 23 to 46 months.

As of September 30, 2003, the fair value of the Company’s net interest rate swap position was a liability of $30.2 million.

The Company is also exposed to commodity price risk related to its purchase of diesel fuel. The Company enters into heating oil swaps and forward purchase contracts to substantially reduce volatility in the price of diesel fuel purchased for its operations. The swap agreements essentially fix the price paid for diesel fuel by requiring the Company to pay a fixed heating oil price and receive a floating heating oil price.

The discussion below presents the sensitivity of the market value of the Company’s financial instruments to selected changes in market rates and prices. The range of changes reflects the Company’s view of changes that are reasonably possible over a one-year period. Market values are the present value of projected future cash flows based on the market rates and prices chosen. The major accounting policies for these instruments are described in Note 1 to the consolidated financial statements of the Company as of and for the year ended December 31, 2002 as filed on its Annual Report on Form 10-K with the Securities and Exchange Commission.

At September 30, 2003, the Company’s debt portfolio consists substantially of fixed rate debt. A change in interest rates on the fixed rate debt impacts the net financial instrument position but has no impact on interest incurred or cash flows. The sensitivity analysis related to the Company’s fixed rate debt assumes an instantaneous 100-basis-point move in interest rates from their levels at September 30, 2003, with all other variables held constant. A 100-basis-point increase in market interest rates would result in a $47.4 million decrease in the fair value of the Company’s fixed rate debt at September 30, 2003.

As it relates to the Company’s interest rate swap positions, a change in interest rates impacts the net financial instrument position. Additionally, because most of the swaps no longer qualify for hedge accounting, changes in the net financial instrument position of these swaps will directly impact the Company’s earnings. A 100-basis point increase in market interest rates would result in a $6.4 million decrease in the fair value of the Company’s liability under the interest rate swap positions at September 30, 2003, of which $5.5 million would be recognized as income.

Similarly, relative to the Company’s diesel hedge position, at September 30, 2003, a $.05 per gallon decrease in the price of heating oil would not have a material impact on the fair value of the financial position of the heating oil swap.

CONTINGENCIES

Reclamation

The federal Surface Mining Control and Reclamation Act of 1977 (“SMCRA”) and similar state statutes require that mine property be restored in accordance with specified standards and an approved reclamation plan. The Company accrues for the costs of final mine closure reclamation in accordance with the provisions of FAS 143, which was adopted as of January 1, 2003. These costs relate to reclaiming the pit and support acreage at surface mines and sealing portals at deep mines. Other costs of final mine closure common to surface and underground mining are related to reclaiming refuse and slurry ponds, eliminating sedimentation and drainage control structures, and dismantling or demolishing equipment or buildings used in mining operations. The establishment of the final mine closure reclamation liability is based upon permit requirements and requires various estimates and assumptions, principally associated with costs and productivities.

The Company reviews its entire environmental liability periodically and makes necessary adjustments, including permit changes and revisions to costs and productivities to reflect current experience. The Company’s management believes it is making adequate provisions for all expected reclamation and other associated costs.

Legal Contingencies

Permit Litigation Matters. A group of local and national environmental organizations filed suit against the U.S. Army Corps of Engineers in the U.S. District Court in Huntington, West Virginia on October 23, 2003. In its complaint, Ohio Valley Environmental Coalition, et al v. Bullen, et al, the plaintiffs allege that the Corps has violated its statutory duties arising under the Clean Water Act, the Administrative Procedure Act and the National Environmental Policy Act in issuing the Nationwide 21 (NWP 21) general permit. The plaintiffs allege that the procedural requirements of the three federal statutes identified in their complaint have been violated, and that the Corps may not utilize the mechanism of a nationwide permit to authorize valley fills. Among specific fills identified in the complaint as not meeting the requirements of the NWP 21 are valley fills associated with several of the Company’s operating subsidiaries. If the plaintiffs prevail in this litigation, it may delay the Company’s receipt of these permits.

A separate matter involves a surface mining permit issued by the West Virginia Department of Environmental Protection (DEP) to the Company’s Coal-Mac subsidiary on September 29, 2003. This permit has been challenged in an administrative proceeding brought by the West Virginia Highlands Conservancy. The appeal alleges that the permit is incomplete and inaccurate, and thereby not in compliance with the DEP’s regulations. Specifically, the petition alleges that the proposal to construct a valley fill is inconsistent with a provision of the state regulations known as the “buffer zone rule”, that the operation has failed to provide for suitable topsoil material for use in its reclamation, and that the state agency failed to evaluate the consequences to the water quality from the alleged discharge of one substance from the mine site. The DEP is required by state law to defend the issuance of the permit. The company has filed a notice to intervene in the proceeding. While the outcome of this litigation is subject to various uncertainties, the Company believes that the permit was validly issued.

West Virginia Flooding Litigation. The Company and three of its subsidiaries have been named, among others, in 17 separate complaints filed in the West Virginia Counties of: Wyoming, McDowell, Fayette, Upshur, Kanawha, Raleigh, Boone and Mercer. These cases collectively include approximately 1,780 plaintiffs who are seeking damages for property damage and personal injuries arising out of flooding that occurred in southern West Virginia in July 2001. The plaintiffs have sued coal, timber, railroad and land companies under the theory that mining, construction of haul roads and removal of timber caused natural surface waters to be diverted in an unnatural way, thereby causing damage to the plaintiffs. The West Virginia Supreme Court has ruled that these cases, along with several additional flood damage cases not involving the Company’s subsidiaries, be handled pursuant to the Court’s Mass Litigation rules. As a result of this ruling, the cases have been transferred to the Circuit Court of Raleigh County in West Virginia to be handled by a panel consisting of three circuit court judges, which has certified certain legal issues back to the West Virginia Supreme Court. Upon resolution of the legal issues by the West Virginia Supreme Court, the panel will, among other things, determine whether the individual cases should be consolidated or returned to their original circuit courts.

While the outcome of this litigation is subject to uncertainties, based on the Company’s preliminary evaluation of the issues and the potential impact on it, the Company believes this matter will be resolved without a material adverse effect on its financial condition or results of operations.

The Company is a party to numerous other claims and lawsuits with respect to various matters. The Company provides for costs related to contingencies, including environmental matters, when a loss is probable and the amount is reasonably determinable. After conferring with counsel, it is the opinion of management that the ultimate resolution of these claims, to the extent not previously provided for, will not have a material adverse effect on the consolidated financial condition, results of operations or liquidity of the Company.

CERTAIN TRENDS AND UNCERTAINTIES

Substantial Leverage — Covenants

As of September 30, 2003, the Company had outstanding consolidated indebtedness of $700.1 million, representing approximately 52% of the Company’s capital employed. Despite making substantial progress in reducing debt, the Company continues to have significant debt service obligations, and the terms of its credit agreements limit its flexibility and result in a number of limitations on the Company. The Company also has significant lease and royalty obligations. The Company’s ability to satisfy debt service, lease and royalty obligations and to effect any refinancing of its indebtedness will depend upon future operating performance, which will be affected by prevailing economic conditions in the markets that the Company serves as well as financial, business and other factors, many of which are beyond the Company’s control. The Company may be unable to generate sufficient cash flow from operations and future borrowings, or other financings may be unavailable in an amount sufficient to enable it to fund its debt service, lease and royalty payment obligations or its other liquidity needs.

The Company’s relative amount of debt and the terms of its credit agreements could have material consequences to its business, including, but not limited to: (i) making it more difficult to satisfy debt covenants and debt service, lease payment and other obligations; (ii) making it more difficult to pay quarterly dividends as the Company has in the past; (iii) increasing the Company’s vulnerability to general adverse economic and industry conditions; (iv) limiting the Company’s ability to obtain additional financing to fund future acquisitions, working capital, capital expenditures or other general corporate requirements; (v) reducing the availability of cash flows from operations to fund acquisitions, working capital, capital expenditures or other general corporate purposes; (vi) limiting the Company’s flexibility in planning for, or reacting to, changes in the Company’s business and the industry in which the Company competes; or (vii) placing the Company at a competitive disadvantage when compared to competitors with less relative amounts of debt.

Terms of the Company’s credit facilities and leases contain financial and other covenants that create limitations on the Company’s ability to, among other things, effect acquisitions or dispositions and borrow additional funds, and require the Company to, among other things, maintain various financial ratios and comply with various other financial covenants. Failure by the Company to comply with such covenants could result in an event of default under these agreements which, if not cured or waived, would enable the Company’s lenders to declare amounts borrowed due and payable, or otherwise result in unanticipated costs.

Losses

The Company reported a net loss available to common shareholders of $2.6 million for the year ended December 31, 2002 and $12.0 million in the first nine months of 2003. These losses are primarily attributable to the Company’s decision to scale back production during the period in response to a weak market environment and increased costs at certain Company operations. The decision to scale back production came after the Company had prepared most of the operations to maximize production in order to capitalize on higher market prices for coal the Company had previously projected. Therefore, certain costs incurred to maximize production did not result in higher revenues but did increase the cost of coal sales.

Because the coal mining industry is subject to significant regulatory oversight and affected by the possibility of adverse pricing trends or other industry trends beyond the Company’s control, the Company may suffer losses in the

future if legal and regulatory rulings, mine idlings and closures, adverse pricing trends or other factors affect the Company’s ability to mine and sell coal profitably.

Environmental and Regulatory Factors

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

• the discharge of materials into the environment;

• employee health and safety;

• mine permits and other licensing requirements;

• reclamation and restoration of mining properties after mining is completed;

• management of materials generated by mining operations;

• surface subsidence from underground mining;

• water pollution;

• legislatively mandated benefits for current and retired coal miners;

• air quality standards;

• protection of wetlands;

• endangered plant and wildlife protection;

• limitations on land use;

• storage of petroleum products and substances that are regarded as hazardous under applicable laws; and

• management of electrical equipment containing polychlorinated biphenyls, or PCBs.

In addition, the electric generating 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 the Company’s coal. The possibility exists that new legislation or regulations may be adopted or that the enforcement of existing laws could become more stringent, either of which may have a significant impact on the Company’s mining operations or its customers’ ability to use coal and may require the Company or its customers to change operations significantly or incur substantial costs.

While it is not possible to quantify the expenditures incurred by the Company to maintain compliance with all applicable federal and state laws, those costs have been and are expected to continue to be significant. The Company posts performance bonds pursuant to federal and state mining laws and regulations for the estimated costs of reclamation and mine closing, including the cost of treating mine water discharge when necessary. Compliance with these laws has substantially increased the cost of coal mining for all domestic coal producers.

Clean Air Act. The federal Clean Air Act and similar state and local laws, which regulate emissions into the air, affect coal mining and processing operations primarily through permitting and emissions control requirements. The Clean Air Act also indirectly affects coal mining operations by extensively regulating the emissions from coal- fired industrial boilers and power plants, which are the largest end-users of the Company’s coal. These regulations can take a variety of forms, as explained below.

The Clean Air Act imposes obligations on the Environmental Protection Agency, or EPA, and the states to implement regulatory programs that will lead to the attainment and maintenance of EPA-promulgated ambient air quality standards, including standards for sulfur dioxide, particulate matter, nitrogen oxides and ozone. Owners of coal-fired power plants and industrial boilers have been required to expend considerable resources in an effort to comply with these ambient air standards. Significant additional emissions control expenditures will be needed in order to meet the current national ambient air standard for ozone. In particular, coal-fired power plants will be affected by state regulations designed to achieve attainment of the ambient air quality standard for ozone. Ozone is produced by the combination of two precursor pollutants: volatile organic compounds and nitrogen oxides. Nitrogen oxides are a by-product of coal combustion. Accordingly, emissions control requirements for new and expanded coal-fired power plants and industrial boilers will continue to become more demanding in the years ahead.

In July 1997, the EPA adopted more stringent ambient air quality standards for particulate matter and ozone. In a February 2001 decision, the U.S. Supreme Court largely upheld the EPA’s position, although it remanded the EPA’s ozone implementation policy for further consideration. On remand, the Court of Appeals for the D.C. Circuit affirmed the EPA’s adoption of these more stringent ambient air quality standards. As a result of the finalization of these standards, states that are not in attainment for these standards will have to revise their State Implementation Plans to include provisions for the control of ozone precursors and/or particulate matter. Revised State Implementation Plans could require electric power generators to further reduce nitrogen oxide and particulate matter emissions. The potential need to achieve such emissions reductions could result in reduced coal consumption by electric power generators. Thus, future regulations regarding ozone, particulate matter and other pollutants could restrict the market for coal and the development of new mines by the Company. This in turn may result in decreased production by the Company and a corresponding decrease in the Company’s revenues. Although the future scope of these ozone and particulate matter regulations cannot be predicted, future regulations regarding these and other ambient air standards could restrict the market for coal and the development of new mines.

Furthermore, in October 1998, the EPA finalized a rule that will require 19 states in the Eastern United States that have ambient air quality problems to make substantial reductions in nitrogen oxide emissions by the year 2004. To achieve these reductions, many power plants would be required to install additional control measures. The installation of these measures would make it more costly to operate coal-fired power plants and, depending on the requirements of individual state implementation plans, could make coal a less attractive fuel.

Along with these regulations addressing ambient air quality, the EPA has initiated a regional haze program designed to protect and to improve visibility at and around National Parks, National Wilderness Areas and International Parks. This program restricts the construction of new coal-fired power plants whose operation may impair visibility at and around federally protected areas. Moreover, this program may require certain existing coal-fired power plants to install additional control measures designed to limit haze-causing emissions, such as sulfur dioxide, nitrogen oxides and particulate matter. By imposing limitations upon the placement and construction of new coal-fired power plants, the EPA’s regional haze program could affect the future market for coal.

Additionally, the U.S. Department of Justice, on behalf of the EPA, has filed lawsuits against eight investor-owned electric utilities and brought an administrative action against one government-owned electric utility for alleged violations of the Clean Air Act. The EPA claims that these utilities have failed to obtain New Source Review permits required under the Clean Air Act for alleged major modifications to their power plants. The suit against the government-owned utility was dismissed by a federal court of appeal in June. The enforcement cases against six of the investor-owned utilities continue, The Company supplies coal to some of the currently affected utilities. These lawsuits could require the utilities to pay penalties and install pollution control equipment or undertake other emission reduction measures, which could adversely impact their demand for coal.

New regulations governing New Source Review were announced by EPA in October. In addition, EPA has indicated that it would discontinue investigations of additional power plants owned by other utilities commenced under the old regulations. The attorneys general of several Northeastern and Mid Atlantic states, however, may commence legal actions against those same utilities.

Other Clean Air Act programs are also applicable to power plants that use the Company’s coal. For example, the acid rain control provisions of Title IV of the Clean Air Act require a reduction of sulfur dioxide emissions from power

plants. Because sulfur is a natural component of coal, required sulfur dioxide reductions can affect coal mining operations. Title IV imposes a two phase approach to the implementation of required sulfur dioxide emissions reductions. Phase I, which became effective in 1995, regulated the sulfur dioxide emissions levels from 261 generating units at 110 power plants and targeted the highest sulfur dioxide emitters. Phase II, implemented January 1, 2000, made the regulations more stringent and extended them to additional power plants, including all power plants of greater than 25 megawatt capacity. Affected electric utilities 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, which reduce the emissions from high sulfur coal;

• reducing electricity generating levels; or

• purchasing or trading emissions credits.

Specific emissions sources receive these credits, which electric utilities and industrial concerns can trade or sell to allow other units to emit higher levels of sulfur dioxide. Each credit allows its holder to emit one ton of sulfur dioxide.

In addition to emissions control requirements designed to control acid rain and to attain the national ambient air quality standards, the Clean Air Act also imposes standards on sources of hazardous air pollutants. Although these standards have not yet been extended to coal mining operations, the EPA recently announced that it will 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. These controls are likely to require significant new improvements in controls by power plant owners. The most prominently targeted pollutant is mercury, although other by-products of coal combustion may be covered by future hazardous air pollutant standards for coal combustion sources.

Other proposed initiatives may have an effect upon coal operations. One such proposal is the Bush Administration’s recently announced Clear Skies Initiative. As proposed, this initiative is designed to reduce emissions of sulfur dioxide, nitrogen oxides, and mercury from power plants. Other so-called multi-pollutant bills, which could regulate additional air pollutants, have been proposed by various members of Congress. While the details of all of these proposed initiatives vary, there appears to be a movement towards increased regulation of a number of air pollutants. Were such initiatives enacted into law, power plants could choose to shift away from coal as a fuel source to meet these requirements.

Mine Health and Safety Laws. Stringent safety and health standards have been imposed by federal legislation since the adoption of the Mine Safety and Health Act of 1969. The Mine Safety and Health Act of 1977, which significantly expanded the enforcement of health and safety standards of the Mine Safety and Health Act of 1969, imposes comprehensive safety and health standards on all mining operations. In addition, as part of the Mine Safety and Health Acts of 1969 and 1977, the Black Lung Act requires payments of benefits by all businesses conducting current mining operations to coal miners with black lung and to some survivors of a miner who dies from this disease.

Surface Mining Control and Reclamation Act. SMCRA establishes operational, reclamation and closure standards for all aspects of surface mining as well as many aspects of deep mining. SMCRA requires that comprehensive environmental protection and reclamation standards be met during the course of and upon completion of mining activities. In conjunction with mining the property, the Company is contractually obligated under the terms of its leases to comply with all laws, including SMCRA and equivalent state and local laws. These obligations include reclaiming and restoring the mined areas by grading, shaping, preparing the soil for seeding and by seeding with grasses or planting trees for use as pasture or timberland, as specified in the approved reclamation plan.

SMCRA also requires the Company to submit a bond or otherwise financially secure the performance of its reclamation obligations. The earliest a reclamation bond can be completely released is five years after reclamation has been achieved. Federal law and some states impose on mine operators the responsibility for repairing the

property or compensating the property owners for damage occurring on the surface of the property as a result of mine subsidence, a consequence of longwall mining and possibly other mining operations. In addition, the Abandoned Mine Lands Act, which is part of SMCRA, imposes a tax on all current mining operations, the proceeds of which are used to restore mines closed before 1977. The maximum tax is $0.35 per ton of coal produced from surface mines and $0.15 per ton of coal produced from underground mines.

The Company also leases some of its coal reserves to third party operators. Under SMCRA, responsibility for unabated violations, unpaid civil penalties and unpaid reclamation fees of independent mine lessees and other third parties could potentially be imputed to other companies that are deemed, according to the regulations, to have “owned” or “controlled” the mine operator. Sanctions against the “owner” or “controller” are quite severe and can include civil penalties, reclamation fees and reclamation costs. The Company is not aware of any currently pending or asserted claims against it asserting that it “owns” or “controls” any of its lessees’ operations.

Framework Convention on Global Climate Change. 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, that is intended to limit or capture emissions of greenhouse gases such as carbon dioxide and methane. The U.S. Senate has neither ratified the treaty commitments, which would mandate a reduction in U.S. greenhouse gas emissions, nor enacted any law specifically controlling greenhouse gas emissions and the Bush Administration has withdrawn support for this treaty. Nonetheless, future regulation of greenhouse gases could occur either pursuant to future U.S. treaty obligations or pursuant to statutory or regulatory changes under the Clean Air Act. Efforts to control greenhouse gas emissions could result in reduced demand for coal if electric power generators switch to lower carbon sources of fuel.

West Virginia Antidegradation Policy. In January 2002, the Ohio Valley Environmental Coalition and other groups and individuals filed suit in the U.S. District Court for the Southern District of West Virginia against the U.S. EPA to challenge the agency’s approval of West Virginia’s antidegradation implementation policy. Under the federal Clean Water Act, state regulatory authorities must conduct an antidegradation review before approving permits for the discharge of pollutants to waters that have been designated as high quality by the state. Antidegradation review involves public and intergovernmental scrutiny of permits and requires permittees to demonstrate that the proposed activities are justified in order to accommodate significant economic or social development in the area where the waters are located. On August 29, 2003 the district court ruled in this lawsuit, Ohio Valley Environmental Coalition v. Horinko, and remanded seven provisions in West Virginia’s antidegradation implementation policy that exempt current holders of National Pollutant Discharge Elimination System (NPDES) permits and Section 404 permits, among other parties, from the antidegradation review process. Six other provisions of the policy were upheld. The Company was exempt from antidegradation review under the overturned provisions. The EPA and the West Virginia DEP have indicated that they will attempt to revise the policy in accordance with the court’s opinion. Subjecting the Company to the antidegradation review process could delay the issuance or reissuance of Clean Water Act permits to the Company or cause these permits to be denied. If the plaintiffs are successful and if the Company discharges into waters that have been designated as high-quality by the state, the costs, time and difficulty associated with obtaining and complying with Clean Water Act permits for surface mining of its operations could increase.

Comprehensive Environmental Response, Compensation and Liability Act. CERCLA and similar state laws affect coal mining operations by, among other things, imposing cleanup requirements for threatened or actual releases of hazardous substances that may endanger public health or welfare or the environment. Under CERCLA and similar state laws, joint and several liability may be imposed on waste generators, site owners and lessees and others regardless of fault or the legality of the original disposal activity. Although the EPA excludes most wastes generated by coal mining and processing operations from the hazardous waste laws, such wastes can, in certain circumstances, constitute hazardous substances for the purposes of CERCLA. In addition, the disposal, release or spilling of some products used by coal companies in operations, such as chemicals, could implicate the liability provisions of the statute. Thus, coal mines that the Company currently owns or has previously owned or operated, and sites to which the Company sent waste materials, may be subject to liability under CERCLA and similar state laws. In particular, the Company may be liable under CERCLA or similar state laws for the cleanup of hazardous substance contamination at sites where it owns surface rights.

Mining Permits and Approvals. Numerous governmental permits or approvals are required for mining operations. In connection with obtaining these permits and approvals, the Company may be required to prepare and present to federal, state or local authorities data pertaining to the effect or impact that any proposed production of coal may have upon the environment. The requirements imposed by any of these authorities may be costly and time consuming and may delay commencement or continuation of mining operations. Regulations also provide that a mining permit can be refused or revoked if an officer, director or a shareholder with a 10% or greater interest in the entity is affiliated with another entity that has outstanding permit violations. Thus, past or ongoing violations of federal and state mining laws could provide a basis to revoke existing permits and to deny the issuance of additional permits.

In order to obtain mining permits and approvals from state regulatory authorities, mine operators, including the Company, must submit a reclamation plan for restoring, upon the completion of mining operations, the mined property to its prior condition, productive use or other permitted condition. Typically the Company submits the necessary permit applications several months before it plans to begin mining a new area. In the Company’s recent experience, permits generally are approved several months after a completed application is submitted. In the past, the Company has generally obtained its mining permits without significant delay. However, the Company cannot be sure that it will not experience difficulty in obtaining mining permits in the future.

Future legislation and administrative regulations may emphasize the protection of the environment and, as a consequence, the activities of mine operators, including the Company, may be more closely regulated. Legislation and regulations, as well as future interpretations of existing laws, may also require substantial increases in equipment expenditures and operating costs, as well as delays, interruptions or the termination of operations. The Company cannot predict the possible effect of such regulatory changes.

Under some circumstances, substantial fines and penalties, including revocation or suspension of mining permits, may be imposed under the laws described above. Monetary sanctions and, in severe circumstances, criminal sanctions may be imposed for failure to comply with these laws.

Surety Bonds. Federal and state laws require the Company to obtain surety bonds to secure payment of certain long-term obligations including mine closure or reclamation costs, federal and state workers’ compensation costs, coal leases and other miscellaneous obligations. Many of these bonds are renewable on a yearly basis upon an expansion of an existing permit. It has become increasingly difficult for the Company to secure new surety bonds or renew certain bonds without the posting of collateral. In addition, surety bond costs have increased while the terms of such bonds have generally become more unfavorable.

Endangered Species. The federal Endangered Species Act and counterpart state legislation protects species threatened with possible extinction. Protection of endangered species may have the effect of prohibiting or delaying the Company from obtaining mining permits and may include restrictions on timber harvesting, road building and other mining or agricultural activities in areas containing the affected species. Certain endangered species are indigenous to the regions in which the Company operates, but surveys conducted as part of the permitting process have not verified the existence of these species on Company property such that mining would be prohibited.

Other Environmental Laws Affecting the Company. The Company is required to comply with numerous other federal, state and local environmental laws in addition to those previously discussed. These additional laws include, for example, the Resource Conservation and Recovery Act, the Safe Drinking Water Act, the Toxic Substance Control Act and the Emergency Planning and Community Right-to-Know Act. The Company believes that it is in substantial compliance with all applicable environmental laws.

Competition — Excess Industry Capacity

The coal industry is intensely competitive, primarily as a result of the existence of numerous producers in the coal-producing regions in which the Company operates, and some of the Company’s competitors may have greater financial resources. The Company competes with several major coal producers in the Central Appalachian and Powder River Basin areas. The Company also competes with a number of smaller producers in those and other market regions. The Company is also subject to the risk of reduced profitability as a result of excess industry capacity, which results in reduced coal prices.

Electric Industry Factors; Customer Creditworthiness

Demand for coal and the prices that the Company will be able to obtain for its coal are closely linked to coal consumption patterns of the domestic electric generation industry, which has accounted for approximately 90% of domestic coal consumption in recent years. These coal consumption patterns are influenced by factors beyond the Company’s control, including the demand for electricity (which is dependent to a significant extent on summer and winter temperatures); government regulation; technological developments and the location, availability, quality and price of competing sources of coal; other fuels such as natural gas, oil and nuclear; and alternative energy sources such as hydroelectric power. Demand for the Company’s low-sulfur coal and the prices that the Company will be able to obtain for it will also be affected by the price and availability of high-sulfur coal, which can be marketed in tandem with emissions allowances in order to meet federal Clean Air Act requirements. Any reduction in the demand for the Company’s coal by the domestic electric generation industry may cause a decline in profitability.

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. Deregulation may have a negative effect on the Company’s profitability to the extent it causes the Company’s customers to be more cost-sensitive.

In addition, the Company’s ability to receive payment for coal sold and delivered depends on the creditworthiness of its customers. In general, the creditworthiness of the Company’s customers has deteriorated. If such trends continue, the Company’s acceptable customer base may be limited.

Reliance on and Terms of Long-Term Coal Supply Contracts

During 2002, sales of coal under long-term contracts, which are contracts with a term greater than 12 months, accounted for 84% of the Company’s total revenues. The prices for coal shipped under these contracts may be below the current market price for similar type coal at any given time. As a consequence of the substantial volume of its sales which are subject to these long-term agreements, the Company has less coal available with which to capitalize on stronger coal prices if and when they arise. In addition, because long-term contracts typically allow the customer to elect volume flexibility, the Company’s ability to realize the higher prices that may be available in the spot market may be restricted when customers elect to purchase higher volumes under such contracts, or the Company’s exposure to market-based pricing may be increased should customers elect to purchase fewer tons. The increasingly short terms of sales contracts and the consequent absence of price adjustment provisions in such contracts also make it more likely that inflation related increases in mining costs during the contract term will not be recovered by the Company.

Reserve Degradation and Depletion

The Company’s profitability depends substantially on its ability to mine coal reserves that have the geological characteristics that enable them to be mined at competitive costs. 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. The Company has in the past acquired and will in the future acquire, coal reserves for its mine portfolio from third parties. The Company may not be able to accurately assess the geological characteristics of any reserves that it acquires, which may adversely affect the profitability and financial condition of the Company. Exhaustion of reserves at particular mines can also have an adverse effect on operating results that is disproportionate to the percentage of overall production represented by such mines. Mingo Logan’s Mountaineer Mine is estimated to exhaust its longwall mineable reserves in 2006. The Mountaineer Mine generated $33.7 million and $36.7 million of the Company’s total operating income in the year ended 2002 and 2001, respectively.

Potential Fluctuations in Operating Results — Factors Routinely Affecting Results of Operations

The Company’s mining operations are inherently subject to changing conditions that can affect levels of production and production costs at particular mines for varying lengths of time and can result in decreases in profitability. Weather conditions, equipment replacement or repair, fuel and supply prices, insurance costs, fires, variations in coal

seam thickness, amounts of overburden rock and other natural materials, and other geological conditions have had, and can be expected in the future to have, a significant impact on operating results. A prolonged disruption of production at any of the Company’s principal mines, particularly its Mingo Logan operation in West Virginia or Black Thunder mine in Wyoming, would result in a decrease, which could be material, in the Company’s revenues and profitability. Other factors affecting the production and sale of the Company’s coal that could result in decreases in its profitability include: (i) expiration or termination of, or sales price redeterminations or suspension of deliveries under, coal supply agreements; (ii) disruption or increases in the cost of transportation services; (iii) changes in laws or regulations, including permitting requirements; (iv) litigation; (v) work stoppages or other labor difficulties; (vi) mine worker vacation schedules and related maintenance activities; and (vii) changes in coal market and general economic conditions.

Transportation

The coal industry depends on rail, trucking and barge transportation to deliver shipments of coal to customers, and transportation costs are a significant component of the total cost of supplying coal. Disruption of these transportation services could temporarily impair the Company’s ability to supply coal to its customers. Increases in transportation costs, or changes in such costs relative to transportation costs for coal produced by its competitors or for other fuels, could have an adverse effect on the Company’s business and results of operations.

Reserves — Title

The Company bases its reserve information on geological data assembled and analyzed by its staff which includes various engineers and geologists, and outside firms. The reserve estimates are annually updated to reflect production of coal from the reserves and new drilling or other data received. There are numerous uncertainties inherent in estimating quantities of recoverable reserves, including many factors beyond the control of the Company. Estimates of economically recoverable coal reserves and net cash flows necessarily depend upon a number of variable factors and assumptions, such as geological and mining conditions which may not be fully identified by available exploration data or may differ from experience in current operations, historical production from the area compared with production from other producing areas, the assumed effects of regulation by governmental agencies, and assumptions concerning coal prices, operating costs, severance and excise taxes, development costs, and reclamation costs, all of which may cause estimates to vary considerably from actual results.

For these reasons, estimates of the economically recoverable quantities attributable to any particular group of properties, classifications of such reserves based on risk of recovery and estimates of net cash flows expected therefrom, prepared by different engineers or by the same engineers at different times, may vary substantially. Actual coal tonnage recovered from identified reserve areas or properties, and revenues and expenditures with respect to the Company’s reserves, may vary from estimates, and such variances may be material. These estimates thus may not accurately reflect the Company’s actual reserves.

The Company continually seeks to expand its operations and coal reserves in the regions in which it operates through acquisitions of businesses and assets. Acquisition transactions involve various inherent risks, such as assessing the value, strengths, weaknesses, contingent and other liabilities, and potential profitability of acquisition or other transaction candidates; timely approval of government agencies, the potential loss of key personnel of an acquired business; the ability to achieve identified operating and financial synergies anticipated to result from an acquisition or other transaction; and unanticipated changes in business, industry or general economic conditions that affect the assumptions underlying the acquisition or other transaction. Any one or more of these factors could impair the Company’s ability to realize the benefits anticipated to result from the acquisition of businesses or assets.

A significant part of the Company’s mining operations are conducted on properties leased by the Company. The loss of any lease could adversely affect the Company’s ability to develop the associated reserves. Because title to most of the Company’s leased properties and mineral rights is not usually verified until a commitment is made by the Company to develop a property, which may not occur until after the Company has obtained necessary permits and completed exploration of the property, the Company’s right to mine certain of its reserves may be adversely affected if defects in title or boundaries exist. In order to obtain leases or mining contracts to conduct mining operations on property where these defects exist, the Company has had to, and may in the future have to, incur unanticipated costs.

In addition, the Company may not be able to successfully negotiate new leases or mining contracts for properties containing additional reserves or maintain its leasehold interests in properties on which mining operations are not commenced during the term of the lease.

Certain Contractual Arrangements

The Company’s affiliate, Arch Western Resources, LLC, is the owner of Company reserves and mining facilities in the western United States. The agreement under which Arch Western was formed provides that a subsidiary of the Company, as the managing member of Arch Western, generally has exclusive power and authority to conduct, manage and control the business of Arch Western. However, consent of BP Amoco, the other member of Arch Western, would generally be required in the event that Arch Western proposes to make a distribution, incur indebtedness, sell properties or merge or consolidate with any other entity if, at such time, Arch Western has a debt rating less favorable than specified ratings with Moody’s Investors Service or Standard & Poor’s or fails to meet specified indebtedness and interest ratios.

In connection with the Company’s June 1, 1998 acquisition of Atlantic Richfield Company’s (“ARCO”) coal operations, the Company entered into an agreement under which it agreed to indemnify ARCO against specified tax liabilities in the event that these liabilities arise as a result of certain actions taken prior to June 1, 2013, including the sale or other disposition of certain properties of Arch Western, the repurchase of certain equity interests in Arch Western by Arch Western, or the reduction under certain circumstances of indebtedness incurred by Arch Western in connection with the acquisition. ARCO was acquired by BP Amoco in 2000. Depending on the time at which any such indemnification obligation were to arise, it could impact the Company’s profitability for the period in which it arises.

The membership interests in Canyon Fuel, which operates three coal mines in Utah, are owned 65% by Arch Western and 35% by a subsidiary of ITOCHU Corporation of Japan. The agreement that governs the management and operations of Canyon Fuel provides for a management board to manage its business and affairs. Some major business decisions concerning Canyon Fuel require the vote of 70% of the membership interests and therefore limit the Company’s ability to make these decisions. These decisions include admission of additional members; approval of annual business plans; the making of significant capital expenditures; sales of coal below specified prices; agreements between Canyon Fuel and any member; the institution or settlement of litigation; a material change in the nature of Canyon Fuel’s business or a material acquisition; the sale or other disposition, including by merger, of assets other than in the ordinary course of business; incurrence of indebtedness; the entering into of leases; and the selection and removal of officers. The Canyon Fuel agreement also contains various restrictions on the transfer of membership interests in Canyon Fuel.

The Company’s Amended and Restated Certificate of Incorporation requires the affirmative vote of the holders of at least two-thirds of outstanding common stock voting thereon to approve a merger or consolidation and certain other fundamental actions involving or affecting control of the Company. The Company’s Bylaws require the affirmative vote of at least two-thirds of the members of the Board of Directors of the Company in order to declare dividends and to authorize certain other actions.

CRITICAL ACCOUNTING POLICIES

The Company’s Annual Report on Form 10-K for the year ended December 31, 2002 contains a description of the critical accounting policies impacting the Company’s financial statements. Since that report, the Company has changed its method of accounting for its final mine closure reclamation liabilities to comply with FAS 143. Asset retirement obligations recorded in accordance with FAS 143 depend on the estimates and assumptions described in the Company’s Annual Report on Form 10-K, as well as the following:

• Discount rate – FAS 143 requires the asset retirement obligation to be recorded at its fair value. In accordance with the provisions of FAS 143, the Company utilized discounted cash flow techniques to estimate the fair value of its obligations. The rates used by the Company are based on rates for treasury bonds with maturities similar to expected mine lives, adjusted for the Company’s credit standing.

• Third-party margin – FAS 143 requires the measurement of an obligation to be based upon the amount a third party would demand to assume the obligation. Because the Company plans to perform a significant amount of its final mine closure reclamation activities with internal resources, a third-party margin was added to the estimated costs of these activities. This margin was estimated based on the Company’s historical experience with contractors performing certain types of reclamation activities. The inclusion of this margin will result in a recorded obligation that is greater than the Company’s estimates of its cost to perform the reclamation activities. If the Company’s cost estimates are accurate, the excess of the recorded obligation over the cost incurred to perform the work will be recorded as a gain at the time that reclamation work is completed.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The information required by this Item is contained under the caption “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this report and is incorporated herein by reference.

ITEM 4. CONTROLS AND PROCEDURES

PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

The information required by this Item is contained in the “Contingencies – Legal Contingencies” section of “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in this report and is incorporated herein by reference.

ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K

(a)


3.1		Amended and Restated Certificate of Incorporation of Arch Coal, Inc. (incorporated herein by reference to Exhibit 3.1 to the Company’s Quarterly Report on Form 10-Q for the Quarter Ended March 31, 2000)

3.2		Amended and Restated Bylaws of Arch Coal, Inc. (incorporated herein by reference to Exhibit 3.2 to the Company’s Annual Report on Form 10-K for the Year Ended December 31, 2000)

3.3		Certificate of Designations Establishing the Designations, Powers, Preferences, Rights, Qualifications, Limitations and Restrictions of the Company’s 5% Perpetual Cumulative Convertible Preferred Stock (incorporated herein by reference to Exhibit 3 to current report on Form 8-A filed on March 5, 2003)

4.1		Third Amendment to Credit Agreement effective August 19, 2003 by and among Arch Coal, Inc., the Lenders party thereto, PNC Bank, National Association, as administrative agent, and Citibank, N.A., Credit Lyonnais New York Branch and U.S. Bank National Association, as co-documentation agents.

4.2		Credit Agreement dated September 19, 2003 by and among Arch Western Resources, LLC and the Lenders party thereto and PNC Bank, National Association, as agent, and PNC Capital Markets, Inc., as lead arranger and bookrunner (incorporated herein by reference to Exhibit 4.5 to Amendment No. 1 to Form S-4 of Arch Western Finance, LLC (Reg. No. 333-107569)).

31.1		Certification of Principal Executive Officer Pursuant to § 302 of the Sarbanes-Oxley Act of 2002.

31.2		Certification of Principal Financial Officer Pursuant to § 302 of the Sarbanes-Oxley Act of 2002.

32.1		Statement Under Oath of Principal Executive Officer Regarding Facts and Circumstances Relating to Exchange Act Filings executed by Steven F. Leer

32.2		Statement Under Oath of Principal Financial Officer Regarding Facts and Circumstances Relating to Exchange Act Filings executed by Robert J. Messey

(b)		Reports on Form 8-K: The following reports on Form 8-K were filed by the Company in the quarter ended September 30, 2003:

(1) A report dated July 18, 2003 announcing the Company’s second quarter 2003 earnings and operating results; and

(2) A report dated August 6, 2003 announcing the Company’s receipt of a request for additional information from the Federal Trade Commission with respect to the Vulcan acquisition.

SIGNATURES

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


		ARCH COAL, INC.

		(Registrant)

Date: November 12, 2003		/s/ John W. Lorson

		John W. Lorson Controller (Chief Accounting Officer)

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	•		Terminated swaps with a notional value of $150.0 million by paying $2.9 million to the swap counterparties.

	•		Entered into offsetting swap positions with a total notional value of $150.0 million. Under these offsetting positions, the Company pays a variable rate based on LIBOR and receives a fixed rate. The variable rate, reset dates and maturities of the offsetting swaps match those of certain of the Company’s original swap positions. As such, variable amounts paid pursuant to these offsetting positions will equal the variable amounts received under the original swap positions.

	•		Swaps with a notional value of $200.0 million which are not designated as hedges and for which the Company has not entered offsetting positions. Under these swaps, the Company pays a weighted average fixed rate of 4.78% (before the credit spread over LIBOR) and receives a weighted average variable rate based upon 30-day and 90-day LIBOR. The remaining terms of the swap agreements at September 30, 2003 ranged from 23 to 46 months.

	•		Swaps with a total notional value of $300.0 million consisting of offsetting positions of $150.0 million each. Because of the offsetting nature of these positions, the Company is not exposed to market interest rate risk related to these swaps. Under these swaps, the Company pays a weighted average fixed rate of 5.61% on $150.0 million of notional value and receives a weighted average fixed rate of 2.68% on $150.0 million of notional value. The remaining terms of these swap agreements at September 30, 2003 ranged from 23 to 46 months.

	•		the discharge of materials into the environment;

	•		employee health and safety;

	•		mine permits and other licensing requirements;

	•		reclamation and restoration of mining properties after mining is completed;

	•		management of materials generated by mining operations;

	•		surface subsidence from underground mining;

	•		water pollution;

	•		legislatively mandated benefits for current and retired coal miners;

	•		air quality standards;

	•		protection of wetlands;

	•		endangered plant and wildlife protection;

	•		limitations on land use;

	•		storage of petroleum products and substances that are regarded as hazardous under applicable laws; and

	•		management of electrical equipment containing polychlorinated biphenyls, or PCBs.

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

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

	•		reducing electricity generating levels; or

	•		purchasing or trading emissions credits.