Edgar Filing: ARCH COAL INC

e10vq

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-Q

(Mark One)


þ		Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended June 30, 2010


o		Transition Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from to .

Commission file number: 1-13105

(Exact name of registrant as specified in its charter)


Delaware		43-0921172
(State or other jurisdiction		(I.R.S. Employer
of incorporation or organization)		Identification Number)

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

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

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes þ No o

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):


Large accelerated filer þ		Accelerated filer o		Non-accelerated filer o (Do not check if a smaller reporting company)		Smaller reporting company o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes o No þ

At August 2, 2010 there were 162,479,414 shares of the registrant’s common stock outstanding.

Table of Contents


	Page
Item 1. Financial Statements		1
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations		24
Item 3. Quantitative and Qualitative Disclosures About Market Risk		32
Item 4. Controls and Procedures		33

Part II OTHER INFORMATION		34
Item 1A. Risk Factors		35
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		36
Item 3. Defaults Upon Senior Securities		36
Item 4. Reserved		36
Item 5. Other Information		36
Item 6. Exhibits		38
EX-12.1
EX-31.1
EX-31.2
EX-32.1
EX-32.2
EX-101 INSTANCE DOCUMENT
EX-101 SCHEMA DOCUMENT
EX-101 CALCULATION LINKBASE DOCUMENT
EX-101 LABELS LINKBASE DOCUMENT
EX-101 PRESENTATION LINKBASE DOCUMENT

Part I
FINANCIAL INFORMATION


Item 1.		Financial Statements.

Arch Coal, Inc. and Subsidiaries
Condensed Consolidated Statements of Income
(in thousands, except per share data)


	Three Months Ended June 30						Six Months Ended June 30
	2010			2009			2010			2009
				(unaudited)
REVENUES
Coal sales	$	764,295		$	554,612		$	1,476,169		$	1,235,652

COSTS, EXPENSES AND OTHER
Cost of coal sales		570,861			467,521			1,121,611			1,014,647
Depreciation, depletion and amortization		87,759			68,419			176,278			141,688
Amortization of acquired sales contracts, net		5,214			58			15,967			(170	)
Selling, general and administrative expenses		35,344			21,627			62,510			46,741
Change in fair value of coal derivatives and coal trading activities, net		4,587			(6,458	)		10,464			(6,986	)
Gain on Knight Hawk transaction		(41,577	)		—			(41,577	)		—
Costs related to acquisition of Jacobs Ranch		—			3,025			—			6,375
Other operating income, net		(4,392	)		(6,889	)		(7,783	)		(12,524	)

		657,796			547,303			1,337,470			1,189,771


Income from operations		106,499			7,309			138,699			45,881

Interest expense, net:
Interest expense		(35,125	)		(20,657	)		(70,208	)		(40,675	)
Interest income		623			417			961			6,885

		(34,502	)		(20,240	)		(69,247	)		(33,790	)

Income (loss) before income taxes		71,997			(12,931	)		69,452			12,091
Provision for (benefit from) income taxes		5,723			2,230			4,948			(3,320	)


Net income (loss)		66,274			(15,161	)		64,504			15,411
Less: Net (income) loss attributable to noncontrolling interest		(118	)		35			(144	)		42

Net income (loss) attributable to Arch Coal, Inc	$	66,156		$	(15,126	)	$	64,360		$	15,453


EARNINGS (LOSS) PER COMMON SHARE
Basic earnings (loss) per common share	$	0.41		$	(0.11	)	$	0.40		$	0.11
Diluted earnings (loss) per common share	$	0.41		$	(0.11	)	$	0.40		$	0.11

Basic weighted average shares outstanding		162,388			142,815			162,380			142,802
Diluted weighted average shares outstanding		163,130			142,815			163,105			142,924

Dividends declared per common share	$	0.10		$	0.09		$	0.19		$	0.18

The accompanying notes are an integral part of the condensed consolidated financial statements.

Arch Coal, Inc. and Subsidiaries
Condensed Consolidated Balance Sheets
(in thousands, except per share data)


	June 30,			December 31,
	2010			2009
	(unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	56,966		$	61,138
Trade accounts receivable		243,567			190,738
Other receivables		33,221			40,632
Inventories		238,317			240,776
Prepaid royalties		49,441			21,085
Deferred income taxes		20,937			—
Coal derivative assets		14,598			18,807
Other		88,094			113,606

Total current assets		745,141			686,782

Property, plant and equipment, net		3,346,294			3,366,186

Other assets:
Prepaid royalties		65,683			86,622
Goodwill		113,701			113,701
Deferred income taxes		335,412			354,869
Equity investments		150,136			87,268
Other		134,173			145,168

Total other assets		799,105			787,628


Total assets	$	4,890,540		$	4,840,596


LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	157,965		$	128,402
Coal derivative liabilities		7,570			2,244
Deferred income taxes		—			5,901
Accrued expenses and other current liabilities		226,365			227,716
Current maturities of debt and short-term borrowings		243,660			267,464

Total current liabilities		635,560			631,727

Long-term debt		1,540,363			1,540,223
Asset retirement obligations		317,257			305,094
Accrued pension benefits		67,252			68,266
Accrued postretirement benefits other than pension		45,441			43,865
Accrued workers’ compensation		27,676			29,110
Other noncurrent liabilities		95,559			98,243

Total liabilities		2,729,108			2,716,528

Redeemable noncontrolling interest		9,993			8,962

Stockholders’ equity:
Common stock, $0.01 par value, authorized 260,000 shares, issued 163,963 shares and 163,953 shares, respectively		1,643			1,643
Paid-in capital		1,728,806			1,721,230
Treasury stock, 1,512 shares at June 30, 2010 and December 31, 2009, at cost		(53,848	)		(53,848	)
Retained earnings		499,423			465,934
Accumulated other comprehensive loss		(24,585	)		(19,853	)

Total stockholders’ equity		2,151,439			2,115,106


Total liabilities and stockholders’ equity	$	4,890,540		$	4,840,596

The accompanying notes are an integral part of the condensed consolidated financial statements.

Arch Coal, Inc. and Subsidiaries
Condensed Consolidated Statements of Cash Flows
(in thousands)


	Six Months Ended June 30
	2010			2009
	(unaudited)
OPERATING ACTIVITIES
Net income	$	64,504		$	15,411
Adjustments to reconcile net income to cash provided by operating activities:
Depreciation, depletion and amortization		176,278			141,688
Amortization of acquired sales contracts, net		15,967			(170	)
Prepaid royalties expensed		16,048			17,173
Gain on Knight Hawk transaction		(41,577	)		—
Gain on dispositions of property, plant and equipment		(111	)		(286	)
Employee stock-based compensation		7,439			6,901
Changes in:
Receivables		(44,057	)		60,982
Inventories		2,458			(49,260	)
Coal derivative assets and liabilities		11,631			16,830
Accounts payable, accrued expenses and other current liabilities		32,060			(51,760	)
Deferred income taxes		(4,719	)		(5,751	)
Other		23,434			8,433


Cash provided by operating activities		259,355			160,191


INVESTING ACTIVITIES
Capital expenditures		(171,958	)		(246,562	)
Proceeds from dispositions of property, plant and equipment		229			715
Purchases of investments and advances to affiliates		(14,249	)		(9,463	)
Additions to prepaid royalties		(23,466	)		(22,524	)
Reimbursement of deposits on equipment		—			3,209


Cash used in investing activities		(209,444	)		(274,625	)


FINANCING ACTIVITIES
Net increase (decrease) in borrowings under lines of credit and commercial paper program		(15,555	)		134,349
Net payments on other debt		(8,249	)		(9,763	)
Debt financing costs		(437	)		(4,574	)
Dividends paid		(30,870	)		(25,725	)
Issuance of common stock under incentive plans		137			58
Contribution from noncontrolling interest		891			—


Cash provided by (used in) financing activities		(54,083	)		94,345


Decrease in cash and cash equivalents		(4,172	)		(20,089	)
Cash and cash equivalents, beginning of period		61,138			70,649


Cash and cash equivalents, end of period	$	56,966		$	50,560

The accompanying notes are an integral part of the condensed consolidated financial statements.

Arch Coal, Inc. and Subsidiaries
Notes to Condensed Consolidated Financial Statements
(unaudited)

1. Basis of Presentation

The accompanying unaudited condensed consolidated financial statements include the accounts of Arch Coal, Inc. and its subsidiaries and controlled entities (the “Company”). The Company’s primary business is the production of steam and metallurgical coal from surface and underground mines located throughout the United States, for sale to utility, industrial and export markets. The Company’s mines are located in southern West Virginia, eastern Kentucky, Virginia, Wyoming, Colorado and Utah. All subsidiaries (except as noted below) are wholly-owned. Intercompany transactions and accounts have been eliminated in consolidation.

The accompanying unaudited condensed consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States for interim financial reporting and U.S. Securities and Exchange Commission regulations. In the opinion of management, all adjustments, consisting of normal, recurring accruals considered necessary for a fair presentation, have been included. Results of operations for the three and six month periods ended June 30, 2010 are not necessarily indicative of results to be expected for the year ending December 31, 2010. These financial statements should be read in conjunction with the audited financial statements and related notes as of and for the year ended December 31, 2009 included in the Company’s Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission.

The Company owns a 99% membership interest in a joint venture named Arch Western Resources, LLC (“Arch Western”) which operates coal mines in Wyoming, Colorado and Utah. The Company also acts as the managing member of Arch Western.

2. Accounting Policies

There are no new accounting pronouncements whose adoption is expected to have a material impact on the Company’s consolidated financial statements.

3. Knight Hawk Transaction

In the second quarter of 2010, the Company exchanged 68.4 million tons of coal reserves in the Illinois Basin for an additional 9% ownership interest in Knight Hawk Holdings, LLC (“Knight Hawk”), increasing the Company’s ownership to 42%. The Company recognized a gain of $41.6 million on the transaction, representing the difference between the fair value and the $12.1 million net book value of the coal reserves, adjusted for the Company’s retained ownership interest in the reserves through its investment in Knight Hawk.

4. Property Transactions

On March 18, 2010, the Company was awarded a Montana state coal lease for the Otter Creek tracts for a price of $85.8 million. Arch now controls approximately 1.5 billion tons of coal reserves in Montana’s Otter Creek area, including a coal lease secured in November 2009. The Company believes these Northern Powder River Basin reserves will help the Company competitively serve U.S. power producers and supply additional coal for export to Asian markets or that they could serve as the location of future coal-conversion facility.

Payments under this, and other non-cancelable royalty lease agreements and federal lease bonus payments under which future minimum payments are due, are capitalized as a cost of the underlying mineral reserves. As of June 30, 2010, the Company had paid $93.1 million of its 2010 payments due under these agreements, including the Otter Creek lease, and will make a payment of $16.1 million in the fourth quarter. Future annual payments under these arrangements will be $23.4 million in 2011, 2012 and 2013 and $7.3 million in 2014.

5. Fair Value Measurements

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

•

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

	•		Level 2 is defined as observable inputs other than Level 1 prices. These include quoted prices for similar assets or liabilities in an active market, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. The Company’s level 2 assets and liabilities include commodity contracts (coal and heating oil) with fair values derived from quoted prices in over-the-counter markets or from prices received from direct broker quotes.

	•		Level 3 is defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. These include the Company’s commodity option contracts (primarily coal and heating oil) valued using modeling techniques, such as Black-Scholes, that require the use of inputs, particularly volatility, that are not observable.

The table below sets forth, by level, the Company’s financial assets and liabilities that are accounted for at fair value:


	Fair Value at June 30, 2010
	Total		Level 1		Level 2		Level 3
			(In thousands)
Assets:
Investments in equity securities	$	2,864	$	2,837	$	—	$	27
Derivatives		24,022		—		17,293		6,729

Total assets	$	26,886	$	2,837	$	17,293	$	6,756


Liabilities:
Derivatives	$	7,570	$	4,285	$	3,932	$	(647	)

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

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


	Three Months Ended			Six Months Ended
	June 30, 2010			June 30, 2010
	(In thousands)
Balance, beginning of period	$	9,694		$	8,217
Realized and unrealized losses recognized in earnings		(3,164	)		(5,376	)
Realized and unrealized losses recognized in other comprehensive income		(5,097	)		(6,119	)
Settlements, purchases and issuances		5,970			10,681

Balance, end of period	$	7,403		$	7,403

Net unrealized losses during the three and six month periods ended June 30, 2010 related to level 3 financial instruments held on June 30, 2010 were $6.3 million and $7.2 million, respectively.

Fair Value of Long-Term Debt

At June 30, 2010 and December 31, 2009, the fair value of the Company’s senior notes and other long-term debt, including amounts classified as current, was $1,821.5 million and $1,844.1 million, respectively. Fair values are based upon observed prices in an active market when available or from valuation models using market information.

6. Derivatives

The Company generally utilizes derivative financial instruments to manage exposures to commodity prices. Additionally, the Company may hold certain coal derivative financial instruments for trading purposes.

All derivative financial instruments are recognized in the balance sheet at fair value. In a fair value hedge, the Company hedges the risk of changes in the fair value of a firm commitment, typically a fixed-price coal sales contract. Changes in both the hedged firm commitment and the fair value of a derivative used as a hedge instrument in a fair value hedge are

recorded in earnings. In a cash flow hedge, the Company hedges the risk of changes in future cash flows related to a forecasted purchase or sale. Changes in the fair value of the derivative instrument used as a hedge instrument in a cash flow hedge are recorded in other comprehensive income. Amounts in other comprehensive income are reclassified to earnings when the hedged transaction affects earnings and are classified in a manner consistent with the transaction being hedged. The Company formally documents the relationships between hedging instruments and the respective hedged items, as well as its risk management objectives for hedge transactions.

The Company evaluates the effectiveness of its hedging relationships both at the hedge’s inception and on an ongoing basis. Any ineffective portion of the change in fair value of a derivative instrument used as a hedge instrument in a fair value or cash flow hedge is recognized immediately in earnings. The ineffective portion is based on the extent to which exact offset is not achieved between the change in fair value of the hedge instrument and the cumulative change in expected future cash flows on the hedged transaction from inception of the hedge in a cash flow hedge or the change in the fair value of the firm commitment in a fair value hedge.

Diesel fuel price risk management

The Company is exposed to price risk with respect to diesel fuel purchased for use in its operations. The Company purchases approximately 50 million to 60 million gallons of diesel fuel annually in its operations. To reduce the volatility in the price of diesel fuel for its operations, the Company uses forward physical diesel purchase contracts, as well as heating oil swaps and purchased call options. At June 30, 2010, the Company had protected the price of approximately 65% of its remaining expected purchases for fiscal year 2010 and 54% for fiscal year 2011.

At June 30, 2010, the Company held heating oil swaps and purchased call options for approximately 56.5 million gallons for the purpose of managing the price risk associated with future diesel purchases. Since the changes in the price of heating oil highly correlate to changes in the price of the hedged diesel fuel purchases, the heating oil swaps and purchased call options qualify for cash flow hedge accounting.

Coal risk management positions

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

At June 30, 2010, the Company held derivatives for risk management purposes totaling 1.6 million tons of coal sales and 1.4 million tons of coal purchases that are expected to settle during the remainder of 2010 and 1.0 million tons of coal sales and 0.1 million tons of coal purchases that are expected to settle in 2011.

Coal trading positions

The Company may sell or purchase forward contracts, swaps and options in the over-the-counter coal market for trading purposes. The Company may also include non-derivative contracts in its trading portfolio. The Company is exposed to the risk of changes in coal prices on its coal trading portfolio. The timing of the estimated future realization of the value of the trading portfolio is 46% in the remainder of 2010 and 54% in 2011.

Tabular derivatives disclosures

The Company’s contracts with certain of its counterparties allow for the settlement of contracts in an asset position with contracts in a liability position in the event of default or termination. Such netting arrangements reduce the Company’s credit exposure related to these counterparties. For classification purposes, the Company records the net fair value of all the positions with these counterparties as a net asset or liability. The amounts shown in the table below represent the fair value position of individual contracts, regardless of the net position presented in the accompanying condensed consolidated balance sheets. The fair value and location of derivatives reflected in the accompanying condensed consolidated balance sheets are as follows:

Fair Value of Derivatives
(in thousands)


	June 30, 2010								December 31, 2009
	Asset			Liability					Asset			Liability
	Derivatives			Derivatives					Derivatives			Derivatives
Derivatives Designated as Hedging Instruments
Heating oil	$	9,552		$	(128	)			$	13,954		$	(2,432	)
Coal		5,666			(6,756	)				3,075			(6,355	)

Total		15,218			(6,884	)				17,029			(8,787	)
Derivatives Not Designated as Hedging Instruments
Coal — held for trading purposes		31,916			(25,670	)				41,544			(31,262	)
Coal		5,023			(3,151	)				11,459			(1,898	)

Total		36,939			(28,821	)				53,003			(33,160	)

Total derivatives		52,157			(35,705	)				70,032			(41,947	)
Effect of counterparty netting		(28,135	)		28,135					(39,227	)		39,227

Net derivatives as classified in the balance sheet	$	24,022		$	(7,570	)	$	16,452	$	30,805		$	(2,720	)	$	28,085

Net derivatives as reflected on the balance sheets


		June 30,			December 31,
		2010			2009
Heating oil
	Other current assets	$	9,424		$	11,998
	Accrued expenses and other current liabilities		—			(476	)

Coal
	Coal derivative assets		14,598			18,807
	Coal derivative liabilities		(7,570	)		(2,244	)

		$	16,452		$	28,085

The Company had a current asset for the right to reclaim cash collateral of $10.1 million and $12.5 million at June 30, 2010 and December 31, 2009, respectively. These amounts are not included with the derivatives presented in the table above and are included in “other current assets” in the accompanying condensed consolidated balance sheets.

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

Three Months Ended June 30
(in thousands)

Gain on Derivatives

Hedged Items in

Loss on Hedged

Derivatives used in

Used in Fair Value

Fair Value Hedge

Items In Fair Value

Fair Value Hedging Relationships

Hedge Relationships

2010

2009

2010

2009

Coal

—

1,604

Firm commitments

—

(1,604)


													Gain (Loss)
													Recognized in
							Gains (Losses)						Income (Ineffective
	Gain (Loss)						Reclassified from						Portion and Amount
	Recognized in OCI						OCI into Income						Excluded from
Derivatives used in	(Effective Portion)						(Effective Portion)						Effectiveness Testing)
Cash Flow Hedging Relationships	2010			2009			2010			2009			2010		2009
Heating oil	$	(8,572	)	$	11,604		$	1,925		$	(14,367	) ²	$	—	$	—
Coal sales		(7,237	)		374			(1,201	)		—	¹		—		—
Coal purchases		7,167			(570	)		—			(5,440	) ²		—		—

Totals	$	(8,642	)	$	11,408		$	724		$	(19,807	)	$	—	$	—


Derivatives Not Designated as
Hedging Instruments	Gain (Loss)
	2010			2009
Coal – unrealized	$	(3,466	)	$	507	³

Coal – realized	$	1,252		$	—	⁴


Location in Statement of Income:

1-	Coal sales

2-	Cost of coal sales

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

4-	Other operating income, net

During the three months ended June 30, 2010 and 2009, the Company recognized net unrealized and realized losses of $1.1 million and net unrealized and realized gains of $6.0 million, respectively, related to its trading portfolio (including derivative and non-derivative contracts). These balances are included in the caption “Change in fair value of coal derivatives and coal trading activities, net” in the accompanying condensed consolidated statements of income and are not included in the previous table.

Six Months Ended June 30
(in thousands)

Loss on Derivatives

Hedged Items in

Gain on Hedged

Derivatives used in

Used in Fair Value

Fair Value Hedge

Items In Fair Value

Fair Value Hedging Relationships

Hedge Relationships

2010

2009

2010

2009

Coal

—

(1,584

) ¹

Firm commitments

—

1,584


													Gain (Loss)
													Recognized in
							Losses						Income (Ineffective
	Gain (Loss)						Reclassified from						Portion and Amount
	Recognized in OCI						OCI into Income						Excluded from
Derivatives used in	(Effective Portion)						(Effective Portion)						Effectiveness Testing)
Cash Flow Hedging Relationships	2010			2009			2010			2009			2010		2009
Heating oil	$	(8,560	)	$	8,739		$	(304	)	$	(26,584	) ²	$	—	$	—
Coal sales		(7,638	)		(1,316	)		(1,330	)		(2,984	) ¹		—		—
Coal purchases		8,069			(4,502	)		(336	)		(5,440	) ²		—		—

Totals	$	(8,129	)	$	2,921		$	(1,970	)	$	(35,008	)	$	—	$	—


Derivatives Not Designated as	Gain (Loss)
Hedging Instruments	2010			2009
Coal – unrealized	$	(8,388	)	$	688	³

Coal -realized	$	2,852		$	—	⁴


Location in Statement of Income:

1-	Coal sales

2-	Cost of coal sales

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

4-	Other operating income, net

During the six months ended June 30, 2010 and 2009, the Company recognized net unrealized and realized losses of $2.1 million and net unrealized and realized gains of $6.3 million, respectively, related to its trading portfolio (including derivative and non-derivative contracts). These balances are included in the caption “Change in fair value of coal derivatives and coal trading activities, net” in the accompanying condensed consolidated statements of income and are not included in the previous table.

During the next twelve months, based on fair values at June 30, 2010, gains on derivative contracts designated as hedge instruments in cash flow hedges of approximately $5.4 million are expected to be reclassified from other comprehensive income into earnings.

7. Inventories

Inventories consist of the following:


	June 30,		December 31,
	2010		2009
	(In thousands)
Coal	$	110,182	$	99,161
Repair parts and supplies, net of allowance		128,135		141,615

	$	238,317	$	240,776

The repair parts and supplies are stated net of an allowance for slow-moving and obsolete inventories of $14.2 million at June 30, 2010, and $13.4 million at December 31, 2009.

8. Debt


	June 30,		December 31,
	2010		2009
	(In thousands)
Commercial paper	$	61,998	$	49,453
Indebtedness to banks under credit facilities		175,900		204,000
6.75% senior notes ($950.0 million face value) due July 1, 2013		954,098		954,782
8.75% senior notes ($600.0 million face value) due August 1, 2016		586,265		585,441
Other		5,762		14,011

		1,784,023		1,807,687
Less current maturities of debt and short-term borrowings		243,660		267,464

Long-term debt	$	1,540,363	$	1,540,223

The current maturities of debt and short-term borrowings includes amounts borrowed that are supported by credit facilities that have a term of less than one year and amounts borrowed under credit facilities with terms longer than one year that the Company does not intend to refinance on a long-term basis, based on cash projections and management’s plans.

Amendments to agreements

On February 24, 2010, the Company entered into an amendment to its accounts receivable securitization program revising certain terms to expand the pool of receivables included in the program. The credit facility supporting the borrowings under the program was also renewed and now expires on February 23, 2011. The size of the program continues to allow for aggregate borrowings and letters of credit of up to $175.0 million, as limited by eligible accounts receivable.

On March 19, 2010 the Company entered into an amendment to its $860.0 million secured revolving credit facility. The amendment enables Arch Coal to make certain intercompany loans to its subsidiary, Arch Western Resources LLC (“AWR”), without repaying the existing loan from AWR to Arch Coal.

On March 25, 2010, the Company entered into an amendment to its commercial paper program which decreased the maximum aggregate principal amount of the program to $75 million from $100 million. The commercial paper program is supported by a line of credit that has been renewed and expires on April 30, 2011.

Availability

As of June 30, 2010 and December 31, 2009, the Company had $65.0 million and $120.0 million, respectively, of borrowings outstanding under the revolving credit facility. At June 30, 2010, the Company had availability of approximately $795.0 million under the revolving credit facility. The Company had borrowings under the accounts receivable securitization program of $110.9 million and $84.0 million at June 30, 2010 and December 31, 2009, respectively. The Company also had letters of credit outstanding under the accounts receivable securitization program of $64.0 million as of June 30, 2010. At June 30, 2010, the Company had no availability under the accounts receivable securitization program.

9. Stock-Based Compensation

During the six months ended June 30, 2010, the Company granted options to purchase approximately 0.8 million shares of common stock with a weighted average exercise price of $22.66 per share and a weighted average grant-date fair value of $9.44 per share. The options’ fair value was determined using the Black-Scholes option pricing model, using a weighted average risk-free rate of 2.18%, a weighted average dividend yield of 2.00% and a weighted average volatility of 57.09%. The options’ expected life is 4.5 years and the options vest ratably over four years. The options provide for the continuation of vesting for retirement-eligible recipients that meet certain criteria. The expense for these options will be recognized through the date that the employee first becomes eligible to retire and is no longer required to provide service to earn part or all of the award.

The Company recognized stock-based compensation expense from all plans of $3.7 million and $3.4 million for the three months ended June 30, 2010 and 2009, respectively, and $7.4 million and $6.9 million for the six months ended June 30, 2010 and 2009, respectively. This expense is primarily included in selling, general and administrative expenses in the accompanying condensed consolidated statements of income.

10. Workers’ Compensation Expense

The following table details the components of workers’ compensation expense:


	Three Months Ended						Six Months Ended
	June 30						June 30
	2010			2009			2010			2009
	(In thousands)
Self-insured occupational disease benefits:
Service cost	$	208		$	145		$	363		$	265
Interest cost		194			167			338			279
Net amortization		(382	)		(469	)		(930	)		(1,440	)

Total occupational disease		20			(157	)		(229	)		(896	)
Traumatic injury claims and assessments		2,244			2,047			3,920			3,552

Total workers’ compensation expense	$	2,264		$	1,890		$	3,691		$	2,656

11. Employee Benefit Plans

The following table details the components of pension benefit costs:


	Three Months Ended						Six Months Ended
	June 30						June 30
	2010			2009			2010			2009
	(In thousands)
Service cost	$	4,062		$	3,493		$	7,935		$	6,722
Interest cost		3,790			4,303			7,911			7,962
Expected return on plan assets		(5,530	)		(4,377	)		(9,696	)		(8,860	)
Amortization of prior service cost		43			150			86			97
Amortization of other actuarial gains and losses		1,161			1,180			3,566			1,983
Curtailments		—			586			—			586

	$	3,526		$	5,335		$	9,802		$	8,490

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


	Three Months Ended						Six Months Ended
	June 30						June 30
	2010			2009			2010			2009
	(In thousands)
Service cost	$	308		$	897		$	754		$	1,631
Interest cost		394			1,088			1,042			2,017
Amortization of prior service cost (credit)		(679	)		1,026			(1,182	)		1,890
Amortization of other actuarial gains and losses		(989	)		(795	)		(1,459	)		(1,706	)

	$	(966	)	$	2,216		$	(845	)	$	3,832

12. Comprehensive Income

Comprehensive income consists of net income and other comprehensive income. Other comprehensive income items are transactions recorded in stockholders’ equity during the year, excluding net income and transactions with stockholders.

The following table presents the components of comprehensive income:


	Three Months Ended						Six Months Ended
	June 30						June 30
	2010			2009			2010			2009
	(In thousands)
Net income (loss) attributable to Arch Coal, Inc.	$	66,156		$	(15,126	)	$	64,360		$	15,453
Other comprehensive income, net of income taxes:
Pension, postretirement and other post-employment benefits, reclassifications into net income		(536	)		962			56			791
Unrealized losses on available-for-sale securities		(925	)		(56	)		(916	)		(94	)
Unrealized gains and losses on derivatives, net of reclassifications into net income:
Unrealized gains (losses) on derivatives		(5,451	)		7,302			(5,089	)		1,870
Reclassifications of (gains) losses into net income		(506	)		12,677			1,217			22,405

Total comprehensive income	$	58,738		$	5,759		$	59,628		$	40,425

13. Earnings per Share

The following table provides the basis for earnings per share calculations by presenting the income available to common stockholders of the Company and by reconciling basic and diluted weighted average shares outstanding:


	Three Months Ended					Six Months Ended
	June 30					June 30
	2010		2009			2010		2009
	(In thousands)
Income (loss) for basic earnings per share calculation:
Net income (loss) allocated to common stockholders	$	66,109	$	(15,109	)	$	64,313	$	15,436


Weighted average shares outstanding:
Basic weighted average shares outstanding		162,388		142,815			162,380		142,802
Effect of common stock equivalents under incentive plans		742		—			725		122


Diluted weighted average shares outstanding		163,130		142,815			163,105		142,924

The effect of options to purchase 2.4 million and 1.7 million shares of common stock were excluded from the calculation of diluted weighted average shares outstanding for the three and six month periods ended June 30, 2010 and 2009, respectively, because the exercise price of these options exceeded the average market price of the Company’s common stock for these periods. The additional dilutive effect of options, restricted stock and restricted stock units totaling 2.5 million shares of common stock were excluded from the calculation of diluted weighted average shares outstanding for the three months ended June 30, 2009 because of the net loss for the quarter.

14. Guarantees

The Company has agreed to continue to provide surety bonds and letters of credit for the reclamation and retiree healthcare obligations of Magnum Coal Company (“Magnum”) related to the properties the Company sold to Magnum on December 31, 2005. The purchase agreement requires Magnum to reimburse the Company for costs related to the surety bonds and letters of credit and to use commercially reasonable efforts to replace the obligations. If the surety bonds and letters of credit related to the reclamation obligations are not replaced by Magnum within a specified period of time, Magnum must post a letter of credit in favor of the Company in the amounts of the reclamation obligations. At June 30, 2010, the Company had approximately $91.6 million of surety bonds related to properties sold to Magnum. As a result of Magnum’s purchase by Patriot Coal Corporation, Magnum will be required to post letters of credit in the Company’s favor for the full amount of the reclamation obligation on or before February 2011.

Magnum also acquired certain coal supply contracts with customers who have not consented to the contracts’ assignment from the Company to Magnum. The Company has committed to purchase coal from Magnum to sell to those customers at the same price it is charging the customers for the sale. In addition, certain contracts were assigned to Magnum, but the Company has guaranteed Magnum’s performance under the contracts. The longest of the coal supply contracts extends to the year 2017. If Magnum is unable to supply the coal for these coal sales contracts then the Company would be required to purchase coal on the open market or supply contracts from its existing operations. At market prices effective at June 30, 2010, the cost of purchasing 12.4 million tons of coal to supply the contracts that have not been assigned over their duration would exceed the sales price under the contracts by approximately $336.7 million, and the cost of purchasing 2.1 million tons of coal to supply the assigned and guaranteed contracts over their duration would exceed the sales price under the contracts by approximately $43.5 million. The Company has also guaranteed Magnum’s performance under certain operating leases, the longest of which extends through 2011. If the Company were required to perform under its guarantees of the operating lease agreements, it would be required to make $1.6 million of lease payments. As the Company does not believe that it is probable that it would have to purchase replacement coal or fulfill its obligations under the lease guarantees, no losses have been recorded in the condensed consolidated financial statements as of June 30, 2010. However, if the Company would have to perform under these guarantees, it could potentially have a material adverse effect on the business, results of operations and financial condition of the Company.

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 the other member of Arch Western against certain tax liabilities in the event that such liabilities arise prior to June 1, 2013 as a result of certain actions taken, 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. If the Company were to become liable, the maximum amount of potential future tax payments is $36.5 million at June 30, 2010, which is not recorded as a liability in the Company’s condensed consolidated financial statements. Since the indemnification is dependent upon the initiation of activities within the Company’s control and the Company does not intend to initiate such activities, it is remote that the Company will become liable for any obligation related to this indemnification. However, if such indemnification obligation were to arise, it could potentially have a material adverse effect on the business, results of operations and financial condition of the Company.

15. 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 estimable. After conferring with counsel, it is the opinion of management that the ultimate resolution of pending claims will not have a material adverse effect on the consolidated financial condition, results of operations or liquidity of the Company.

16. Segment Information

The Company has three reportable business segments, which are based on the major low-sulfur coal basins in which the Company operates. Each of these reportable business segments includes a number of mine complexes. The Company manages its coal sales by coal basin, not by individual mine complex. Geology, coal transportation routes to customers, regulatory environments and coal quality are generally consistent within a basin. Accordingly, market and contract pricing have developed by coal basin. Mine operations are evaluated based on their per-ton operating costs (defined as including all mining costs but excluding pass-through transportation expenses), as well as on other non-financial measures, such as safety and environmental performance. The Company’s reportable segments are the Powder River Basin (PRB) segment, with operations in Wyoming; the Western Bituminous (WBIT) segment, with operations in Utah, Colorado and southern Wyoming; and the Central Appalachia (CAPP) segment, with operations in southern West Virginia, eastern Kentucky and Virginia.

Operating segment results for the three and six month periods ended June 30, 2010 and 2009 are presented below. Results for the operating segments include all direct costs of mining, including all depreciation, depletion and amortization related to the mining operations. Corporate, Other and Eliminations includes the change in fair value of coal derivatives and coal trading activities, net; corporate overhead; land management; other support functions; and the elimination of intercompany transactions.

The asset amounts below represent an allocation of assets used in the segments’ cash-generating activities. The amounts in Corporate, Other and Eliminations represent primarily corporate assets (cash, receivables, investments, plant, property and equipment) as well as goodwill, unassigned coal reserves, above-market acquired sales contracts and other unassigned assets.


								Corporate,
								Other and
	PRB		WBIT			CAPP		Eliminations			Consolidated
	(In thousands)
Three months ended June 30, 2010
Coal sales	$	370,499	$	132,150		$	261,646	$	—		$	764,295
Income from operations		33,177		13,876			54,079		5,367			106,499
Depreciation, depletion and amortization		44,433		18,390			24,581		355			87,759
Amortization of acquired sales contracts, net		5,214		—			—		—			5,214
Capital expenditures		3,725		20,703			12,972		102,583			139,983

Three months ended June 30, 2009
Coal sales	$	268,558	$	112,081		$	173,973	$	—		$	554,612
Income (loss) from operations		18,093		(4,457	)		12,282		(18,609	)		7,309
Depreciation, depletion and amortization		27,637		18,879			21,416		487			68,419
Amortization of acquired sales contracts, net		58		—			—		—			58
Capital expenditures		8,092		27,412			17,548		1,624			54,676

Six months ended June 30, 2010
Coal sales	$	729,914	$	264,863		$	481,392	$	—		$	1,476,169
Income (loss) from operations		49,738		26,306			91,672		(29,017	)		138,699
Total assets		2,331,449		682,565			725,588		1,150,938			4,890,540
Depreciation, depletion and amortization		89,054		38,760			47,755		709			176,278
Amortization of acquired sales contracts, net		15,967		—			—		—			15,967
Capital expenditures		4,450		33,804			24,609		109,095			171,958

Six months ended June 30, 2009
Coal sales	$	579,800	$	234,638		$	421,214	$	—		$	1,235,652
Income (loss) from operations		49,307		(12,112	)		55,833		(47,147	)		45,881
Total assets		1,658,045		709,319			784,199		877,434			4,028,997
Depreciation, depletion and amortization		57,021		38,674			45,050		943			141,688
Amortization of acquired sales contracts, net		141		(311	)		—		—			(170	)
Capital expenditures		41,871		43,506			30,529		130,656			246,562

A reconciliation of segment income from operations to consolidated income before income taxes is presented below.


	Three Months Ended						Six Months Ended
	June 30						June 30
	2010			2009			2010			2009
	(In thousands)
Income from operations	$	106,499		$	7,309		$	138,699		$	45,881
Interest expense		(35,125	)		(20,657	)		(70,208	)		(40,675	)
Interest income		623			417			961			6,885

Income (loss) before income taxes	$	71,997		$	(12,931	)	$	69,452		$	12,091

17. Subsequent Event

On August 2, 2010, the Company announced the offering of $500.0 million aggregate principal amount of 7.25% senior notes, due in 2020, at an issue price of 100% of the principal amount. The Company intends to use the net proceeds from the offering and cash on hand to fund the repurchase or redemption of $500.0 million aggregate principal amount of its outstanding 6.75% senior notes due in 2013 at a redemption price of 101.125%.

18. Supplemental Condensed Consolidating Financial Information

Pursuant to the indenture governing the 8.75% senior notes, certain wholly-owned subsidiaries of the Company have fully and unconditionally guaranteed the senior notes on a joint and several basis. The following tables present unaudited condensed consolidating financial information for (i) the issuer of the notes (Arch Coal), (ii) the guarantors under the notes, and (iii) the entities which are not guarantors under the notes:

Condensed Consolidating Statements of Income
Three Months Ended June 30, 2010
(in thousands)


				Guarantor			Non-Guarantor
	Parent/Issuer			Subsidiaries			Subsidiaries			Eliminations			Consolidated
Revenue
Coal Sales	$	—		$	282,817		$	481,478		$	—		$	764,295

Costs, expenses and other
Cost of coal sales		2,148			193,243			396,568			(21,098	)		570,861
Depreciation, depletion and amortization		725			46,941			40,093			—			87,759
Amortization of acquired sales contracts, net		—			—			5,214			—			5,214
Selling, general and administrative expenses		23,251			1,836			12,006			(1,749	)		35,344
Change in fair value of coal derivatives and coal trading activities, net		—			4,587			—			—			4,587
Gain on Knight Hawk transaction		—			(41,577	)		—			—			(41,577	)
Other operating (income) expense, net		(2,818	)		(26,202	)		1,781			22,847			(4,392	)

		23,306			178,828			455,662			—			657,796
Income from investment in subsidiaries		126,555			—			—			(126,555	)		—


Income from operations		103,249			103,989			25,816			(126,555	)		106,499

Interest expense, net:
Interest expense		(33,524	)		(780	)		(18,387	)		17,566			(35,125	)
Interest income		2,272			75			15,842			(17,566	)		623

		(31,252	)		(705	)		(2,545	)		—			(34,502	)


Income before income taxes		71,997			103,284			23,271			(126,555	)		71,997
Provision for income taxes		5,723			—			—			—			5,723


Net income		66,274			103,284			23,271			(126,555	)		66,274
Less: Net income attributable to noncontrolling interest		(118	)		—			—			—			(118	)


Net income attributable to Arch Coal	$	66,156		$	103,284		$	23,271		$	(126,555	)	$	66,156

Condensed Consolidating Statements of Income
Three Months Ended June 30, 2009
(in thousands)


				Guarantor			Non-Guarantor
	Parent/Issuer			Subsidiaries			Subsidiaries			Eliminations			Consolidated
Revenue
Coal Sales	$	—		$	193,805		$	360,807		$	—		$	554,612

Costs, expenses and other
Cost of coal sales		2,123			155,315			320,295			(10,212	)		467,521
Depreciation, depletion and amortization		903			31,190			36,326			—			68,419
Amortization of acquired sales contracts, net		—			—			58			—			58
Selling, general and administrative expenses		13,536			1,669			7,763			(1,341	)		21,627
Change in fair value of coal derivatives and coal trading activities, net		—			(6,458	)		—			—			(6,458	)
Costs related to acquisition of Jacobs Ranch		3,025			—			—			—			3,025
Other operating income, net		(330	)		(18,006	)		(106	)		11,553			(6,889	)

		19,257			163,710			364,336			—			547,303

Income from investment in subsidiaries		22,504			—			—			(22,504	)		—


Income (loss) from operations		3,247			30,095			(3,529	)		(22,504	)		7,309

Interest expense, net:
Interest expense		(18,139	)		(495	)		(16,550	)		14,527			(20,657	)
Interest income		1,961			128			12,855			(14,527	)		417

		(16,178	)		(367	)		(3,695	)		—			(20,240	)


Income (loss) before income taxes		(12,931	)		29,728			(7,224	)		(22,504	)		(12,931	)
Provision for income taxes		2,230			—			—			—			2,230


Net income (loss)		(15,161	)		29,728			(7,224	)		(22,504	)		(15,161	)
Less: Net loss attributable to noncontrolling interest		35			—			—			—			35


Net income (loss) attributable to Arch Coal	$	(15,126	)	$	29,728		$	(7,224	)	$	(22,504	)	$	(15,126	)

Condensed Consolidating Statements of Income
Six Months Ended June 30, 2010
(in thousands)


				Guarantor			Non-Guarantor
	Parent/Issuer			Subsidiaries			Subsidiaries			Eliminations			Consolidated
Revenue
Coal Sales	$	—		$	521,845		$	954,324		$	—		$	1,476,169

Costs, expenses and other
Cost of coal sales		4,976			361,961			794,079			(39,405	)		1,121,611
Depreciation, depletion and amortization		1,476			90,659			84,143			—			176,278
Amortization of acquired sales contracts, net		—			—			15,967			—			15,967
Selling, general and administrative expenses		41,894			3,642			20,409			(3,435	)		62,510
Change in fair value of coal derivatives and coal trading activities, net		—			10,464			—			—			10,464
Gain on Knight Hawk transaction		—			(41,577	)		—			—			(41,577	)
Other operating (income) expense, net		(4,778	)		(48,924	)		3,079			42,840			(7,783	)

		43,568			376,225			917,677			—			1,337,470

Income from investment in subsidiaries		173,820			—			—			(173,820	)		—


Income from operations		130,252			145,620			36,647			(173,820	)		138,699

Interest expense, net:
Interest expense		(64,955	)		(1,359	)		(36,503	)		32,609			(70,208	)
Interest income		4,155			164			29,251			(32,609	)		961

		(60,800	)		(1,195	)		(7,252	)		—			(69,247	)


Income before income taxes		69,452			144,425			29,395			(173,820	)		69,452
Provision for income taxes		4,948			—			—			—			4,948


Net income		64,504			144,425			29,395			(173,820	)		64,504
Less: Net income attributable to noncontrolling interest		(144	)		—			—			—			(144	)


Net income attributable to Arch Coal	$	64,360		$	144,425		$	29,395		$	(173,820	)	$	64,360

Condensed Consolidating Statements of Income
Six Months Ended June 30, 2009
(in thousands)


				Guarantor			Non-Guarantor
	Parent/Issuer			Subsidiaries			Subsidiaries			Eliminations			Consolidated
Revenue
Coal Sales	$	—		$	458,595		$	777,057		$	—		$	1,235,652

Costs, expenses and other
Cost of coal sales		1,495			353,272			681,667			(21,787	)		1,014,647
Depreciation, depletion and amortization		1,758			65,132			74,798			—			141,688
Amortization of acquired sales contracts, net		—			—			(170	)		—			(170	)
Selling, general and administrative expenses		27,633			3,804			18,151			(2,847	)		46,741
Change in fair value of coal derivatives and coal trading activities, net		—			(6,986	)		—			—			(6,986	)
Costs related to acquisition of Jacobs Ranch		6,375			—			—			—			6,375
Other operating (income) expense, net		(1,897	)		(35,907	)		646			24,634			(12,524	)

		35,364			379,315			775,092			—			1,189,771

Income from investment in subsidiaries		71,569			—			—			(71,569	)		—


Income from operations		36,205			79,280			1,965			(71,569	)		45,881

Interest expense, net:
Interest expense		(35,034	)		(1,205	)		(35,325	)		30,889			(40,675	)
Interest income		10,920			510			26,344			(30,889	)		6,885

		(24,114	)		(695	)		(8,981	)		—			(33,790	)


Income (loss) before income taxes		12,091			78,585			(7,016	)		(71,569	)		12,091
Benefit from income taxes		(3,320	)		—			—			—			(3,320	)


Net income (loss)		15,411			78,585			(7,016	)		(71,569	)		15,411
Less: Net loss attributable to noncontrolling interest		42			—			—			—			42


Net income (loss) attributable to Arch Coal	$	15,453		$	78,585		$	(7,016	)	$	(71,569	)	$	15,453

Condensed Consolidating Balance Sheets
June 30, 2010
(in thousands)


				Guarantor		Non-Guarantor
	Parent/Issuer			Subsidiaries		Subsidiaries		Eliminations			Consolidated
Assets
Cash and cash equivalents	$	24,396		$	64	$	32,506	$	—		$	56,966
Receivables		17,728			13,581		245,479		—			276,788
Inventories		—			84,365		153,952		—			238,317
Other		42,518			113,173		17,379		—			173,070

Total current assets		84,642			211,183		449,316		—			745,141

Property, plant and equipment, net		7,379			1,830,265		1,508,650		—			3,346,294
Investment in subsidiaries		4,317,283			—		—		(4,317,283	)		—
Intercompany receivables		(1,875,044	)		325,513		1,549,531		—			—
Other		444,984			340,273		13,848		—			799,105

Total other assets		2,887,223			665,786		1,563,379		(4,317,283	)		799,105

Total assets	$	2,979,244		$	2,707,234	$	3,521,345	$	(4,317,283	)	$	4,890,540


Liabilities and Stockholders’ Equity
Accounts payable	$	21,684		$	50,118	$	86,163	$	—		$	157,965
Accrued expenses and other current liabilities		47,732			39,540		146,663		—			233,935
Current maturities of debt and short-term borrowings		70,763			—		172,897		—			243,660

Total current liabilities		140,179			89,658		405,723		—			635,560

Long-term debt		586,264			—		954,099		—			1,540,363
Asset retirement obligations		656			30,333		286,268		—			317,257
Accrued pension benefits		26,360			4,714		36,178		—			67,252
Accrued postretirement benefits other than pension		16,064			—		29,377		—			45,441
Accrued workers’ compensation		10,684			13,419		3,573		—			27,676
Other noncurrent liabilities		37,605			24,905		33,049		—			95,559

Total liabilities		817,812			163,029		1,748,267		—			2,729,108
Redeemable noncontrolling interest		9,993			—		—		—			9,993
Stockholders’ equity		2,151,439			2,544,205		1,773,078		(4,317,283	)		2,151,439

Total liabilities and stockholders’ equity	$	2,979,244		$	2,707,234	$	3,521,345	$	(4,317,283	)	$	4,890,540

Condensed Consolidating Balance Sheets
December 31, 2009
(in thousands)


				Guarantor		Non-Guarantor
	Parent/Issuer			Subsidiaries		Subsidiaries		Eliminations			Consolidated
Assets
Cash and cash equivalents	$	54,255		$	64	$	6,819	$	—		$	61,138
Receivables		16,339			15,574		199,457		—			231,370
Inventories		—			75,126		165,650		—			240,776
Other		28,741			101,407		23,350		—			153,498

Total current assets		99,335			192,171		395,276		—			686,782

Property, plant and equipment, net		7,783			1,809,340		1,549,063		—			3,366,186
Investment in subsidiaries		4,127,075			—		—		(4,127,075	)		—
Intercompany receivables		(1,679,003	)		232,076		1,446,927		—			—
Other		455,972			317,486		14,170		—			787,628

Total other assets		2,904,044			549,562		1,461,097		(4,127,075	)		787,628

Total assets	$	3,011,162		$	2,551,073	$	3,405,436	$	(4,127,075	)	$	4,840,596


Liabilities and Stockholders’ Equity
Accounts payable	$	12,828		$	41,066	$	74,508	$	—		$	128,402
Accrued expenses and other current liabilities		54,957			36,394		144,510		—			235,861
Current maturities of debt and short-term borrowings		134,012			—		133,452		—			267,464

Total current liabilities		201,797			77,460		352,470		—			631,727

Long-term debt		585,441			—		954,782		—			1,540,223
Asset retirement obligations		927			29,253		274,914		—			305,094
Accrued pension benefits		29,001			4,742		34,523		—			68,266
Accrued postretirement benefits other than pension		15,046			—		28,819		—			43,865
Accrued workers’ compensation		10,595			14,448		4,067		—			29,110
Other noncurrent liabilities		44,287			27,213		26,743		—			98,243

Total liabilities		887,094			153,116		1,676,318		—			2,716,528
Redeemable noncontrolling interest		8,962			—		—		—			8,962
Stockholders’ equity		2,115,106			2,397,957		1,729,118		(4,127,075	)		2,115,106

Total liabilities and stockholders’ equity	$	3,011,162		$	2,551,073	$	3,405,436	$	(4,127,075	)	$	4,840,596

Condensed Consolidating Statements of Cash Flows
Six Months Ended June 30, 2010
(in thousands)


				Guarantor			Non-Guarantor
	Parent/Issuer			Subsidiaries			Subsidiaries			Consolidated
Cash provided by (used in) operating activities	$	(134,960	)	$	240,408		$	153,907		$	259,355

Investing Activities
Capital expenditures		(1,006	)		(123,761	)		(47,191	)		(171,958	)
Proceeds from dispositions of property, plant and equipment		—			155			74			229
Purchases of investments and advances to affiliates		(11,303	)		(2,946	)		—			(14,249	)
Additions to prepaid royalties		—			(20,831	)		(2,635	)		(23,466	)

Cash used in investing activities		(12,309	)		(147,383	)		(49,752	)		(209,444	)

Financing Activities
Net increase (decrease) in borrowings under lines of credit and commercial paper program		(55,000	)		—			39,445			(15,555	)
Net payments on other debt		(8,249	)		—			—			(8,249	)
Debt financing costs		(32	)		—			(405	)		(437	)
Dividends paid		(30,870	)		—			—			(30,870	)
Issuance of common stock under incentive plans		137									137
Contribution from noncontrolling interest		—			—			891			891
Transactions with affiliates, net		211,424			(93,025	)		(118,399	)		—

Cash provided by (used in) financing activities		117,410			(93,025	)		(78,468	)		(54,083	)

Increase (decrease) in cash and cash equivalents		(29,859	)		—			25,687			(4,172	)
Cash and cash equivalents, beginning of period		54,255			64			6,819			61,138

Cash and cash equivalents, end of period	$	24,396		$	64		$	32,506		$	56,966

Condensed Consolidating Statements of Cash Flows
Six Months Ended June 30, 2009
(in thousands)


				Guarantor			Non-Guarantor
	Parent/Issuer			Subsidiaries			Subsidiaries			Consolidated
Cash provided by (used in) operating activities	$	(71,820	)	$	131,919		$	100,092		$	160,191

Investing Activities
Capital expenditures		(2,026	)		(159,159	)		(85,377	)		(246,562	)
Proceeds from dispositions of property, plant and equipment		—			685			30			715
Purchases of investments and advances to affiliates		(8,000	)		(1,463	)		—			(9,463	)
Additions to prepaid royalties		—			(20,317	)		(2,207	)		(22,524	)
Reimbursement of deposits on equipment		—			—			3,209			3,209

Cash used in investing activities		(10,026	)		(180,254	)		(84,345	)		(274,625	)

Financing Activities
Net increase (decrease) in borrowings under lines of credit and commercial paper program		170,000			—			(35,651	)		134,349
Net payments on other debt		(9,763	)		—			—			(9,763	)
Debt financing costs		(4,449	)		—			(125	)		(4,574	)
Dividends paid		(25,725	)		—			—			(25,725	)
Issuance of common stock under incentive plans		58			—			—			58
Transactions with affiliates, net		(73,133	)		48,338			24,795			—

Cash provided by (used in) financing activities		56,988			48,338			(10,981	)		94,345

Increase (decrease) in cash and cash equivalents		(24,858	)		3			4,766			(20,089	)
Cash and cash equivalents, beginning of period		67,737			61			2,851			70,649

Cash and cash equivalents, end of period	$	42,879		$	64		$	7,617		$	50,560

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

This document contains “forward-looking statements” — that is, statements related to future, not past, events. In this context, forward-looking statements often address our expected future business and financial performance, and often contain words such as “expects,” “anticipates,” “intends,” “plans,” “believes,” “seeks,” or “will.” Forward-looking statements by their nature address matters that are, to different degrees, uncertain. For us, particular uncertainties arise from changes in the demand for our coal by the domestic electric generation industry; from legislation and regulations relating to the Clean Air Act and other environmental initiatives; from regulations relating to mine safety; from operational, geological, permit, labor and weather-related factors; from fluctuations in the amount of cash we generate from operations; from future integration of acquired businesses; and from numerous other matters of national, regional and global scale, including those of a political, economic, business, competitive or regulatory nature. These uncertainties may cause our actual future results to be materially different than those expressed in our forward-looking statements. We do not undertake to update our forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by law. For a description of some of the risks and uncertainties that may affect our future results, see “Risk Factors” under Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2009 and under Item 1A of our Quarterly Report on Form 10-Q for the quarter ended March 31, 2010.

Overview

We are one of the largest coal producers in the United States. We sell substantially all of our coal to power plants, steel mills and industrial facilities. The locations of our mines enable us to ship coal to most of the major coal-fueled power plants, steel mills and export facilities located in the United States. We also export coal, particularly the metallurgical coal that is used in the steel industry. Rapid economic expansion in China, India and other parts of Southeast Asia has significantly increased the demand for steel and, therefore, metallurgical coal in recent years.

Our three reportable business segments are based on the low-sulfur U.S. coal producing regions in which we operate — the Powder River Basin, the Western Bituminous region and the Central Appalachia region. These geographically distinct areas are characterized by geology, coal transportation routes to consumers, regulatory environments and coal quality. These regional similarities have caused market and contract pricing environments to develop by coal region and form the basis for the segmentation of our operations.

The Powder River Basin is located in northeastern Wyoming and southeastern Montana. The coal we mine from surface operations in this region has a very low sulfur content and a low heat value compared to the other regions in which we operate. The price of Powder River Basin coal is generally less than that of coal produced in other regions because Powder River Basin coal exists in greater abundance, is easier to mine and thus has a lower cost of production. In addition, Powder River Basin coal is generally lower in heat content, which requires some electric power generation facilities to blend it with higher Btu coal or retrofit some existing coal plants to accommodate lower Btu coal. The Western Bituminous region includes Colorado, Utah and southern Wyoming. Coal we mine from underground and surface mines in this region typically has a low sulfur content and varies in heat content. Central Appalachia includes eastern Kentucky, Tennessee, Virginia and southern West Virginia. Coal we mine from both surface and underground mines in this region generally has a high heat content and low sulfur content. In addition, we may sell a portion of the coal we produce in the Central Appalachia region as metallurgical coal, which has high heat content, low expansion pressure, low sulfur content and various other chemical attributes. As such, the prices at which we sell metallurgical coal to customers in the steel industry generally exceed the prices offered by power plants and industrial users for steam coal.

Favorable weather patterns, an improving U.S. economy, growth in global coal demand, and declining domestic coal production are all positively impacting coal markets. We witnessed better market conditions during the second quarter of 2010, and we estimate that coal markets during the remainder of 2010 will continue to reflect improvement over the weak domestic steam coal markets that prevailed in 2009. Year-to-date U.S. power generation increased approximately 4% through the third week in July, in response to slowly improving domestic and international economic conditions, as well as cold winter/hot summer weather in most of the U.S. We estimate that U.S. steam coal demand will grow in 2010, fueled by growth in power generation and declining generator stockpile levels. Despite a modest slowing of the metallurgical coal markets recently, we still expect to sell 6 million to 7 million tons of metallurgical coal in 2010.

We also expect positive price improvements in 2010 in the steam coal markets, due to improving demand. In addition to stronger demand in 2010, we expect steam coal markets to benefit from the crossover of high-quality steam coal into the metallurgical markets, and declining supply in the Eastern U.S. due to increasing regulatory pressures and degradation and depletion of the reserve base.

We temporarily suspended production at our Dugout Canyon mine in Carbon County, Utah, on April 29, 2010 after an increase in carbon monoxide levels resulted from a heating event in a previously mined area. After permanently sealing the area, we resumed full coal production on May 21, 2010. On June 22, 2010, an ignition event at our longwall resulted in a second evacuation of all underground employees at the mine. In both events, all employees were safely evacuated. We rendered the atmosphere inert and in early August began to reestablish ventilation at the longwall. The resumption of mining is dependent upon the time required to ventilate the longwall area, determine the cause of the ignition, implement preventive measures, and secure an MSHA-approved longwall ventilation plan. We expect that the outages resulted in a loss of income of approximately $6.5 million during the quarter.

In the second quarter of 2010, we exchanged 68.4 million tons of coal reserves in the Illinois Basin for an additional 9% ownership interest in Knight Hawk Holdings, LLC (Knight Hawk), increasing our ownership to 42%. We recognized a pre-tax gain of $41.6 million on the transaction, representing the difference between the fair value and net book value of the coal reserves, adjusted for our retained ownership interest in the reserves through the investment in Knight Hawk.

Results of Operations

Three Months Ended June 30, 2010 Compared to Three Months Ended June 30, 2009

Summary. Our improved results during the second quarter of 2010, when compared to the second quarter of 2009, were influenced primarily by increased sales volumes, including an increase in metallurgical coal volumes sold; lower production costs; and the gain on the Knight Hawk transaction. These were partially offset by higher selling, general and administrative costs and higher interest costs due to the issuance of our 8.75% senior notes in the third quarter of 2009 to finance, in part, the Jacobs Ranch acquisition.

Revenues. The following table summarizes information about coal sales for the three months ended June 30, 2010 and compares it with the information for the three months ended June 30, 2009:


					Increase (Decrease)
	Three Months Ended June 30				in Net Income
	2010		2009		Amount			%
	(Amounts in thousands, except per ton data and percentages)
Coal sales	$	764,295	$	554,612	$	209,683			37.8	%
Tons sold		38,340		27,658		10,682			38.6	%
Coal sales realization per ton sold	$	19.93	$	20.05	$	(0.12	)		(0.6	)%

Coal sales increased in the second quarter of 2010 from the second quarter of 2009 due to an increase in tons sold across all regions, particularly in the Powder River Basin region, as a result of the acquisition of the Jacobs Ranch mining complex in the fourth quarter of 2009. Our coal sales realizations per ton were lower in the 2010 quarter as lower pricing in the Powder River Basin and the impact on our average selling price of the increased Powder River Basin volumes offset the benefit from an increase in metallurgical coal sales volumes. We have provided more information about the tons sold and the coal sales realizations per ton by operating segment under the heading “Operating segment results”.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income for the three months ended June 30, 2010 and compares them with the information for the three months ended June 30, 2009:


							Increase (Decrease)
	Three Months Ended June 30						in Net Income
	2010			2009			$			%
	(Amounts in thousands, except percentages)
Cost of coal sales	$	570,861		$	467,521		$	(103,340	)		(22.1	)%
Depreciation, depletion and amortization		87,759			68,419			(19,340	)		(28.3	)
Amortization of acquired sales contracts, net		5,214			58			(5,156	)		N/A
Selling, general and administrative expenses		35,344			21,627			(13,717	)		(63.4	)
Change in fair value of coal derivatives and coal trading activities, net		4,587			(6,458	)		(11,045	)		(171.0	)
Gain on Knight Hawk transaction		(41,577	)		—			41,577			N/A
Costs related to acquisition of Jacobs Ranch		—			3,025			3,025			100.0
Other operating income, net		(4,392	)		(6,889	)		(2,497	)		(36.2	)

	$	657,796		$	547,303		$	(110,493	)		(20.2	)%

sold, due to the impact of the increased Powder River Basin volumes as well as lower per-ton production costs, exclusive of sales sensitive costs, across all regions. We have provided more information about our operating segments under the heading “Operating segment results”.

Depreciation, depletion and amortization and amortization of acquired sales contracts, net. When compared with the second quarter of 2009, higher depreciation and amortization costs in the second quarter of 2010 resulted primarily from the impact of the acquisition of the Jacobs Ranch mining complex in the fourth quarter of 2009.

Selling, general and administrative expenses. The increase in selling, general and administrative expenses from the second quarter of 2009 to the second quarter of 2010 is due primarily to compensation-related costs and a contribution to the Arch Coal Foundation of $5.0 million in 2010. In particular, our improved results resulted in higher costs of $4.0 million in 2010 related to our incentive compensation plans when compared to 2009. Also, costs related to our deferred compensation plan, where amounts recognized are impacted by changes in the value of our common stock and changes in the value of the underlying investments, increased $1.9 million.

Change in fair value of coal derivatives and coal trading activities, net. Net (gains) losses relate to the net impact of our coal trading activities and the change in fair value of other coal derivatives that have not been designated as hedge instruments in a hedging relationship. During the second quarter of 2010, rising coal prices resulted in unrealized losses on positions that we held in order to manage risk, but were not designated in a hedge relationship.

Gain on Knight Hawk transaction. Represents the gain recognized on our exchange of Illinois Basin reserves for an additional ownership interest in Knight Hawk, an equity method investee operating in the Illinois Basin.

Other operating income, net. The decrease in net other operating income from the second quarter of 2009 is primarily the result of a decrease in income from contract settlements and bookout transactions, partially offset by an increase in income from our investment in Knight Hawk.

Operating segment results. The following table shows results by operating segment for the three months ended June 30, 2010 and compares it with information for the three months ended June 30, 2009:


	Three Months Ended June 30					Increase (Decrease)
	2010		2009			$			%
Powder River Basin
Tons sold (in thousands)		30,951		21,304			9,647			45.3	%
Coal sales realization per ton sold ⁽¹⁾	$	11.88	$	12.56		$	(0.68	)		(5.4	)%
Operating margin per ton sold ⁽²⁾	$	1.05	$	0.72		$	0.33			45.8	%

Western Bituminous
Tons sold (in thousands)		3,996		3,475			521			15.0	%
Coal sales realization per ton sold ⁽¹⁾	$	30.09	$	29.93		$	0.16			0.5	%
Operating margin per ton sold ⁽²⁾	$	3.10	$	(1.56	)	$	4.66			298.7	%

Central Appalachia
Tons sold (in thousands)		3,393		2,879			514			17.9	%
Coal sales realization per ton sold ⁽¹⁾	$	71.46	$	58.54		$	12.92			22.1	%
Operating margin per ton sold ⁽²⁾	$	15.45	$	3.10		$	12.35			398.4	%


⁽¹⁾		Coal sales prices per ton exclude certain transportation costs that we pass through to our customers. We use these financial measures because we believe the amounts as adjusted better represent the coal sales prices we achieved within our operating segments. Since other companies may calculate coal sales prices per ton differently, our calculation may not be comparable to similarly titled measures used by those companies. For the three months ended June 30, 2010, transportation costs per ton were $0.09 for the Powder River Basin, $2.98 for the Western Bituminous region and $5.66 for Central Appalachia. For the three months ended June 30, 2009, transportation costs per ton were $0.05 for the Powder River Basin, $2.33 for the Western Bituminous region and $1.88 for Central Appalachia.

⁽²⁾		Operating margin per ton sold is calculated as coal sales revenues less cost of coal sales and depreciation, depletion and amortization divided by tons sold.

Powder River Basin — The increase in sales volume in the Powder River Basin in the second quarter of 2010 when compared with the second quarter of 2009 resulted from the acquisition of the Jacobs Ranch mining operations on October 1, 2009. Decreases in sales prices during the second quarter of 2010 when compared with the second quarter of 2009 primarily reflect the roll-off of contracts committed when market conditions were more favorable, as well as the effect of lower pricing on market-index priced tons. On a per-ton basis, operating margins in the second quarter of 2010 increased from the second quarter of 2009 due to a decrease in per-ton costs, which offset the impact of the lower per-ton sales prices. The decrease in per-ton costs resulted from efficiencies achieved from combining the acquired Jacobs Ranch mining

operations with our existing Black Thunder operations and our cost containment efforts, as well as a decrease in hedged diesel fuel costs.

Western Bituminous — In the Western Bituminous region, despite the two production outages at the Dugout Canyon mine, sales volumes in the second quarter of 2010 increased when compared to the second quarter of 2009, when quality issues at the West Elk mining complex in Colorado resulted in the decision to decrease production levels at the mine. Despite the detrimental impact in 2009 on our per-ton realizations of selling coal with a higher ash content, our realizations increased only slightly in 2010, due to ongoing soft steam coal market conditions in the region and an unfavorable mix of customer contracts. Effective cost control in the region resulted in the higher per-ton operating margins in the second quarter of 2010. In the second quarter of 2010, we continued to mine in more favorable geologic conditions at West Elk. To address any future quality issues that could result from sandstone intrusions similar to those we encountered previously, we are building a preparation plant at the mine, to be completed in late August 2010.

Central Appalachia — The increase in sales volumes in the second quarter of 2010, when compared with the second quarter of 2009, was due to the improvement in the metallurgical coal markets. We sold 1.5 million tons into metallurgical markets in the second quarter of 2010 compared to 0.3 million tons in the second quarter of 2009. Because metallurgical coal generally commands a higher price than steam coal, the increase had a favorable impact on our average realizations, as did the higher pricing on metallurgical tons sold, compared to the second quarter of 2009. The benefit from higher per-ton realizations, net of sales sensitive costs, drove the improvement in our operating margins over the second quarter of 2009.

Net interest expense. The following table summarizes our net interest expense for the three months ended June 30, 2010 and compares it with the information for the three months ended June 30, 2009:


							Increase (Decrease)
	Three Months Ended June 30						in Net Income
	2010			2009			$			%
	(Amounts in thousands, except percentages)
Interest expense	$	(35,125	)	$	(20,657	)	$	(14,468	)		(70.0	)%
Interest income		623			417			206			49.4

	$	(34,502	)	$	(20,240	)	$	(14,262	)		(70.5	)%

The increase in net interest expense in the second quarter of 2010 compared to the second quarter of 2009 is primarily due to the issuance of the 8.75% senior notes in the third quarter of 2009 to finance, in part, the acquisition of the Jacobs Ranch mining complex.

Income taxes. Our effective income tax rate is sensitive to changes in estimates of annual profitability and the deduction for percentage depletion. The following table summarizes our income taxes for the three months ended June 30, 2010 and compares it with information for the three months ended June 30, 2009:


	Three Months Ended June 30				Decrease in Net Income
	2010		2009		$			%
	(Amounts in thousands, except percentages)
Provision for income taxes	$	5,723	$	2,230	$	(3,493	)		(156.6	)%

The provision for income taxes for the three months ended June 30, 2010 and 2009 resulted from the allocation of the expected taxes to be recognized for the respective fiscal year, and were affected by the pretax income or loss for the quarter in relation to the expected income to be earned for the fiscal year. In addition, the second quarter of 2010 includes a tax benefit of $4.0 million related to the recognition of tax benefits based on settlements with taxing authorities.

Six Months Ended June 30, 2010 Compared to Six Months Ended June 30, 2009

Summary. Our improved results during the first half of 2010, when compared to the first half of 2009, were influenced primarily by increased sales volumes, including an increase in metallurgical coal volumes sold; lower production costs and the gain on the Knight Hawk transaction. These were partially offset by higher selling, general and administrative costs, unrealized losses on coal derivatives and higher interest costs due to the issuance of our 8.75% senior notes in the third quarter of 2009 to finance, in part, the Jacobs Ranch acquisition.

Revenues. The following table summarizes information about coal sales for the six months ended June 30, 2010 and compares it with the information for the six months ended June 30, 2009:


					Increase (Decrease)
	Six Months Ended June 30				in Net Income
	2010		2009		Amount			%
	(Amounts in thousands, except per ton data and percentages)
Coal sales	$	1,476,169	$	1,235,652	$	240,517			19.5	%
Tons sold		76,146		58,550		17,596			30.0	%
Coal sales realization per ton sold	$	19.39	$	21.10	$	(1.71	)		(8.1	)%

Coal sales increased in the first half of 2010 from the first half of 2009 primarily due to an increase in tons sold in the Powder River Basin region, resulting from the acquisition of the Jacobs Ranch mining complex in the fourth quarter of 2009. Our coal sales realizations per ton were lower in the first half of 2010 as lower pricing in the Powder River Basin and the impact on our average selling price of the higher Powder River Basin volumes offset the benefit of an increase in metallurgical coal sales volumes. We have provided more information about the tons sold and the coal sales realizations per ton by operating segment under the heading “Operating segment results”.

Costs, expenses and other. The following table summarizes costs, expenses and other components of operating income for the six months ended June 30, 2010 and compares them with the information for the six months ended June 30, 2009:


							Increase (Decrease)
	Six Months Ended June 30						in Net Income
	2010			2009			$			%
	(Amounts in thousands, except percentages)
Cost of coal sales	$	1,121,611		$	1,014,647		$	(106,964	)		(10.5	)%
Depreciation, depletion and amortization		176,278			141,688			(34,590	)		(24.4	)%
Amortization of acquired sales contracts, net		15,967			(170	)		(16,137	)		N/A
Selling, general and administrative expenses		62,510			46,741			(15,769	)		(33.7	)%
Change in fair value of coal derivatives and coal trading activities, net		10,464			(6,986	)		(17,450	)		N/A
Gain on Knight Hawk transaction		(41,577	)		—			41,577			N/A
Costs related to acquisition of Jacobs Ranch		—			6,375			6,375			100.0	%
Other operating income, net		(7,783	)		(12,524	)	$	(4,741	)		(37.9	)%

	$	1,337,470		$	1,189,771		$	(147,699	)		(12.4	)%

Cost of coal sales. Our cost of coal sales increased in the second quarter of 2010 from the second quarter of 2009 primarily due to the higher sales volumes discussed above, partially offset by the impact of a lower average cost per-ton sold, due to the impact of the increased Powder River Basin volumes as well as lower per-ton production costs in our Western regions. We have provided more information about our operating segments under the heading “Operating segment results”.

Depreciation, depletion and amortization and amortization of acquired sales contracts, net. When compared with the first half of 2009, higher depreciation and amortization costs in the first half of 2010 resulted primarily from the impact of the acquisition of the Jacobs Ranch mining complex in the fourth quarter of 2009.

Selling, general and administrative expenses. The increase in selling, general and administrative expenses from the first half of 2009 to the first half of 2010 is due primarily to compensation-related costs and a contribution to the Arch Coal Foundation of $5.0 million in 2010. In particular, our improved results were the primary driver of higher costs of approximately $4.9 million in 2010 related to our incentive compensation plans when compared to 2009. Costs related to our deferred compensation plan, where amounts recognized are impacted by changes in the value of our common stock and changes in the value of the underlying investments, also increased $3.4 million.

Change in fair value of coal derivatives and coal trading activities, net. Net (gains) losses relate to the net impact of our coal trading activities and the change in fair value of other coal derivatives that have not been designated as hedge instruments in a hedging relationship. During the first half of 2010, rising coal prices resulted in unrealized losses on positions that we held in order to manage risk, but were not designated in a hedge relationship.

Other operating income, net. The decrease in net other operating income in the first half of 2010 from the first half of 2009 is primarily the result of a decrease in income from contract settlements and bookout transactions of $4.6 million, a decrease in income from outlease royalties of $1.5 million, and a decrease in transloading fees of $1.0 million, partially offset by an increase in income from our investment in Knight Hawk.

Operating segment results. The following table shows results by operating segment for the six months ended June 30, 2010 and compares it with information for the six months ended June 30, 2009:


	Six Months Ended June 30					Increase (Decrease)
	2010		2009			$			%
Powder River Basin
Tons sold (in thousands)		61,596		44,437			17,159			38.6	%
Coal sales realization per ton sold ⁽³⁾	$	11.76	$	12.92		$	(1.16	)		(9.0	)%
Operating margin per ton sold ⁽⁴⁾	$	0.78	$	1.04		$	(0.26	)		(25.0	)%

Western Bituminous
Tons sold (in thousands)		8,125		7,426			699			9.4	%
Coal sales realization per ton sold ⁽³⁾	$	29.52	$	28.96		$	0.56			1.9	%
Operating margin per ton sold ⁽⁴⁾	$	2.84	$	(1.92	)	$	4.76			247.9	%

Central Appalachia
Tons sold (in thousands)		6,425		6,687			(262	)		(3.9	)%
Coal sales realization per ton sold ⁽³⁾	$	69.02	$	60.23		$	8.79			14.6	%
Operating margin per ton sold ⁽⁴⁾	$	13.70	$	7.39		$	6.31			85.4	%


⁽³⁾		Coal sales prices per ton exclude certain transportation costs that we pass through to our customers. We use these financial measures because we believe the amounts as adjusted better represent the coal sales prices we achieved within our operating segments. Since other companies may calculate coal sales prices per ton differently, our calculation may not be comparable to similarly titled measures used by those companies. For the six months ended June 30, 2010, transportation costs per ton were $0.09 for the Powder River Basin, $3.08 for the Western Bituminous region and $5.91 for Central Appalachia. For the six months ended June 30, 2009, transportation costs per ton were $0.13 for the Powder River Basin, $2.63 for the Western Bituminous region and $2.76 for Central Appalachia.

⁽⁴⁾		Operating margin per ton sold is calculated as coal sales revenues less cost of coal sales and depreciation, depletion and amortization divided by tons sold.

Powder River Basin — The increase in sales volume in the Powder River Basin in the first half of 2010 when compared with the first half of 2009 resulted from the acquisition of the Jacobs Ranch mining operations on October 1, 2009. Decreases in sales prices during the first half of 2010 when compared with the first half of 2009 primarily reflect the roll-off of contracts committed when market conditions were more favorable, as well as the effect of lower pricing on market-index priced tons. On a per-ton basis, operating margins in the first half of 2010 decreased from the first half of 2009 due to the lower sales prices, partially offset by a decrease in per-ton costs. The decrease in per-ton costs resulted from efficiencies achieved from combining the acquired Jacobs Ranch mining operations with our existing Black Thunder operations and our cost containment efforts, as well as a decrease in hedged diesel fuel costs.

Western Bituminous — In the Western Bituminous region, despite a soft steam coal market in the region and the two outages at the Dugout Canyon mine in the first half of 2010, sales volumes increased compared to the first half of 2009, when quality issues at the West Elk mining complex in Colorado resulted in the decision to decrease production levels at the mine. Despite the detrimental impact in 2009 on our per-ton realizations of selling coal with a higher ash content, our realizations increased only slightly in 2010, due to the soft steam coal market and an unfavorable mix of customer contracts. Effective cost control in the region resulted in the higher per-ton operating margins in the first half of 2010.

Central Appalachia — The decrease in sales volumes in the first half of 2010, when compared with the first half of 2009, was primarily due to continued weak steam coal demand, despite the improvement in metallurgical coal demand. We sold 2.4 million tons into metallurgical markets in the first half of 2010 compared to 0.7 million tons in the first half of 2009. Because metallurgical coal generally commands a higher price than steam coal, the increase had a favorable impact on our average realizations, as did the higher pricing on metallurgical tons sold, compared to the first half of 2009. The benefit from higher per-ton realizations in the first half of 2010, net of sales sensitive costs, drove the improvement in our operating margins over the first half of 2009, partially offset by an increase in our per-ton costs due to the lower production levels.

Net interest expense. The following table summarizes our net interest expense for the six months ended June 30, 2010 and compares it with the information for the six months ended June 30, 2009:


	Six Months Ended June 30						Decrease in Net Income
	2010			2009			$			%
	(Amounts in thousands, except percentages)
Interest expense	$	(70,208	)	$	(40,675	)	$	(29,533	)		(72.6	)%
Interest income		961			6,885			(5,924	)		(86.0	)

	$	(69,247	)	$	(33,790	)	$	(35,457	)		(104.9	)%

The increase in net interest expense in the first half of 2010 compared to the first half of 2009 is primarily due to the issuance of the 8.75% senior notes in the third quarter of 2009, to finance, in part, the acquisition of the Jacobs Ranch mining complex. In the first half of 2009, we also recorded interest income of $6.1 million related to a black lung excise tax refund.

Income taxes. Our effective income tax rate is sensitive to changes in estimates of annual profitability and the deduction for percentage depletion. The following table summarizes our income taxes for the six months ended June 30, 2010 and compares it with information for the six months ended June 30, 2009:


	Six Months Ended June 30					Decrease in Net Income
	2010		2009			$			%
	(Amounts in thousands, except percentages)
Provision for (benefit from) income taxes	$	4,948	$	(3,320	)	$	(8,268	)		(249.0	)%

The income tax provision (benefit) for the six months ended June 30, 2010 and 2009 resulted from the allocation of the expected taxes to be recognized for the respective fiscal year, and were affected by the pretax income or loss for the period in relation to the expected income to be earned for the fiscal year. In addition, the first half of 2010 includes a tax benefit of $4.0 million related to the recognition of tax benefits based on settlements with taxing authorities.

Liquidity and Capital Resources

Liquidity and capital resources

Our primary sources of cash include sales of our coal production to customers, borrowings under our credit facilities and other financing arrangements, and debt and equity offerings to finance significant transactions. Excluding any significant mineral reserve acquisitions, we generally satisfy our working capital requirements and fund capital expenditures and debt-service obligations with cash generated from operations or borrowings under our credit facility, accounts receivable securitization or commercial paper programs. The borrowings under these arrangements are classified as current if the underlying credit facilities expire within one year or if, based on cash projections and management plans, we do not have the intent to replace them on a long-term basis. Such plans are subject to change based on our cash needs.

We believe that cash generated from operations and borrowings under our credit facilities or other financing arrangements will be sufficient to meet working capital requirements, anticipated capital expenditures and scheduled debt payments for at least the next several years. We manage our exposure to changing commodity prices for our non-trading, long-term coal contract portfolio through the use of long-term coal supply agreements. We enter into fixed price, fixed volume supply contracts with terms greater than one year with customers with whom we have historically had limited collection issues. Our ability to satisfy debt service obligations, to fund planned capital expenditures, to make acquisitions, to repurchase our common shares and to pay dividends will depend upon our 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 our control.

On August 2, 2010, we announced the offering $500.0 million aggregate principal amount of 7.25% senior notes, due in 2020, at an issue price of 100% of the principal amount. We intend to use the net proceeds from the offering and cash on hand to fund the repurchase or redemption of $500.0 million aggregate principal amount of our outstanding 6.75% senior notes due in 2013 at a redemption price of 101.125%.

On March 19, 2010, we entered into an amendment to our $860.0 million secured revolving credit facility. The amendment allows for us to make intercompany loans to our subsidiary, Arch Western Resources LLC (“AWR”), without drawing down the existing loan from AWR to us. We had borrowings outstanding under the revolving credit facility of

$65.0 million at June 30, 2010 and $120.0 million at December 31, 2009. At June 30, 2010, we had availability of approximately $795.0 million under the revolving credit facility. Borrowings under the credit facility bear interest at a floating rate based on LIBOR determined by reference to our leverage ratio, as calculated in accordance with the credit agreement, as amended. Our revolving credit facility is secured by substantially all of our assets, as well as our ownership interests in substantially all of our subsidiaries, except our ownership interests in AWR. Financial covenants contained in our revolving credit facility, as amended, consist of a maximum leverage ratio, a maximum senior secured leverage ratio and a minimum interest coverage ratio. The leverage ratio requires that we not permit the ratio of total net debt (as defined in the facility) at the end of any calendar quarter to EBITDA (as defined in the facility) for the four quarters then ended to exceed a specified amount. The interest coverage ratio requires that we not permit the ratio of EBITDA (as defined in the facility) at the end of any calendar quarter to interest expense for the four quarters then ended to be less than a specified amount. The senior secured leverage ratio requires that we not permit the ratio of total net senior secured debt (as defined in the facility) at the end of any calendar quarter to EBITDA (as defined in the facility) for the four quarters then ended to exceed a specified amount. We were in compliance with all financial covenants at June 30, 2010.

On February 24, 2010, we entered into an amendment of our $175.0 million accounts receivable securitization program revising certain terms to expand the pool of receivables included in the program. Under the program, eligible trade receivables are sold, without recourse, to a multi-seller, asset-backed commercial paper conduit. The credit facility supporting the borrowings under the program is subject to renewal annually and currently expires on February 23, 2011. Under the terms of the program, eligible trade receivables consist of trade receivables generated by our operating subsidiaries. Actual borrowing capacity is based on the allowable amounts of accounts receivable as defined under the terms of the agreement. We had $110.9 million of borrowings outstanding under the program at June 30, 2010 and $84.0 million outstanding at December 31, 2009. We also had letters of credit outstanding under the securitization program of $64.0 million as of June 30, 2010. At June 30, 2010, we had no availability under the accounts receivable securitization program. Although the participants in the program bear the risk of non-payment of purchased receivables, we have agreed to indemnify the participants with respect to various matters. The participants under the program will be entitled to receive payments reflecting a specified discount on amounts funded under the program, including drawings under letters of credit, calculated on the basis of the base rate or commercial paper rate, as applicable. We pay facility fees, program fees and letter of credit fees (based on amounts of outstanding letters of credit) at rates that vary with our leverage ratio. Under the program, we are subject to certain affirmative, negative and financial covenants customary for financings of this type, including restrictions related to, among other things, liens, payments, merger or consolidation and amendments to the agreements underlying the receivables pool. A termination event would permit the administrator to terminate the program and enforce any and all rights, subject to cure provisions, where applicable. Additionally, the program contains cross-default provisions, which would allow the administrator to terminate the program in the event of non-payment of other material indebtedness when due and any other event which results in the acceleration of the maturity of material indebtedness.

On March 25, 2010, we entered into an amendment to our commercial paper program which decreased the maximum aggregate principal amount of the program to $75 million from $100 million. The commercial paper program is supported by a line of credit that expires on April 30, 2011. We had commercial paper outstanding of $62.0 million at June 30, 2010 and $49.5 million at December 31, 2009. Our commercial paper placement program provides short-term financing at rates that are generally lower than the rates available under our revolving credit facility.

Our subsidiary, Arch Western Finance LLC, has outstanding an aggregate principal amount of $950.0 million of 6.75% senior notes due on July 1, 2013. The notes are guaranteed by AWR and certain of its subsidiaries and are secured by an intercompany note from AWR to Arch Coal, Inc. The indenture under which the notes were issued contains certain restrictive covenants that limit AWR’s ability to, among other things, incur additional debt, sell or transfer assets and make certain investments. The notes may be redeemed as follows: at 101.125% of par for notes redeemed between July 1, 2010 and June 30, 2011, and at 100% for notes redeemed on or after July 1, 2011. As mentioned previously, we have announced the offering of $500.0 million aggregate principal amount of 7.25% senior notes, the proceeds of which will be used to redeem $500 million aggregate principal amount of the 6.75% senior notes.

We have outstanding a principal amount of $600.0 million of 8.75% senior notes due on August 1, 2016. At any time on or after August 1, 2013, we may redeem some or all of the notes. The redemption price, reflected as a percentage of the principal amount, is: 104.375% for notes redeemed between August 1, 2013 and July 31, 2014; 102.188% for notes redeemed between August 1, 2014 and July 31, 2015; and 100% for notes redeemed on or after August 1, 2015. The notes are guaranteed by most of our subsidiaries, except for AWR and its subsidiaries and Arch Receivable Company, LLC, among others.

We have filed a universal shelf registration statement on Form S-3 with the SEC that allows us to offer and sell from

time to time an unlimited amount of unsecured debt securities consisting of notes, debentures, and other debt securities, common stock, preferred stock, warrants, and/or units. Related proceeds could be used for general corporate purposes, including repayment of other debt, capital expenditures, possible acquisitions and any other purposes that may be stated in any related prospectus supplement.

The following is a summary of cash provided by or used in each of the indicated types of activities:


	Six Months Ended June 30
	2010			2009
	(in thousands)
Cash provided by (used in):
Operating activities	$	259,355		$	160,191
Investing activities		(209,444	)		(274,625	)
Financing activities		(54,083	)		94,345

Cash provided by operating activities increased in the first half of 2010 compared to the first half of 2009, primarily as a result of our improved operating performance in 2010.

Cash used in investing activities for the first half of 2010 was $65.2 million less than in the first half of 2009, primarily due to a $74.6 million reduction in capital expenditures. During the first half of 2010, we made payments of $85.8 million on our Montana leases and spent $18.4 million on the new preparation plant at the West Elk mine that we mentioned previously. In the first half of 2009, in addition to the last payment of $122.0 million on the Little Thunder federal coal lease, we spent approximately $19.0 million on additional longwall equipment at the West Elk mining complex in Colorado and approximately $85.0 million for a transition to a new reserve area in our West Elk mining complex.

Cash used in financing activities was $54.1 million during the first half of 2010, compared to cash provided by financing activities of $94.3 million during the first half of 2009. We repaid $15.6 million under our various financing arrangements during the first half of 2010, compared to borrowing $134.3 million during the first half of 2009. We paid dividends of $30.9 million in the first half of 2010, compared with $25.7 million in 2009, due to an increase in the dividend rate from $0.09 to $0.10 per share in April 2010. In the first half of 2009, in conjunction with amendments to our credit facility, we paid financing costs of $4.6 million.

Ratio of Earnings to Fixed Charges

The following table sets forth our ratios of earnings to combined fixed charges and preference dividends for the periods indicated:


	Six Months Ended June 30
	2010		2009
Ratio of earnings to combined fixed charges and preference dividends		1.96x		1.30x

Critical Accounting Policies

For a description of our critical accounting policies, see “Critical Accounting Policies” under Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2009. There have been no significant changes to our critical accounting policies during the three months ended June 30, 2010.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

We manage our commodity price risk for our non-trading, long-term coal contract portfolio through the use of long-term coal supply agreements, and to a limited extent, through the use of derivative instruments. At June 30, 2010, based on our expected production levels and current sales commitments, we have committed substantially all of our 2010 production, with 5 million tons not yet priced. Arch has uncommitted volumes of 55 million to 65 million tons in 2011, and uncommitted volumes of 90 million to 100 million tons in 2012, with roughly 20 million tons committed but not yet priced in both 2011 and 2012.

We are exposed to commodity price risk in our coal trading activities, which represents the potential future loss that could be caused by an adverse change in the market value of coal. Our coal trading portfolio included forward, swap and put and call option contracts at June 30, 2010. With respect to our coal trading portfolio at June 30, 2010, the potential for loss of future earnings resulting from changing coal prices was insignificant. The timing of the estimated future realization of the value of our trading portfolio is 46% in the remainder of 2010 and 54% in 2011.

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

VaR is a statistical one-tail confidence interval and down side risk estimate that relies on recent history to estimate how the value of the portfolio of positions will change if markets behave in the same way as they have in the recent past. While presenting VaR will provide a similar framework for discussing risk across companies, VaR estimates from two independent sources are rarely calculated in the same way. Without a thorough understanding of how each VaR model was calculated, it would be difficult to compare two different VaR calculations from different sources. The level of confidence is 95%. The time across which these possible value changes are being estimated is through the end of the next business day. A closed-form delta-neutral method used throughout the finance and energy sectors is employed to calculate this VaR. VaR is back tested to verify usefulness.

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

During the first half of 2010, VaR ranged from under $0.1 million to $0.5 million. The linear mean of each daily VaR was $0.2 million. The final VaR at June 30, 2010 was $0.3 million.

We are also exposed to the risk of fluctuations in cash flows related to our purchase of diesel fuel. We use approximately 50 million to 60 million gallons of diesel fuel annually in our operations. We enter into forward physical purchase contracts, as well as heating oil swaps and options, to reduce volatility in the price of diesel fuel for our operations. At June 30, 2010, the Company had protected the price of approximately 65% of its expected purchases for the remainder of fiscal year 2010 and 54% for fiscal year 2011, mostly through the use of the derivative instruments noted above. Since the changes in the price of heating oil are highly correlated to changes in the price of the hedged diesel fuel purchases, the heating oil swaps and purchased call options qualify for cash flow hedge accounting. Accordingly, changes in the fair value of the derivatives are recorded through other comprehensive income, with any ineffectiveness recognized immediately in income. At June 30, 2010, a $0.25 per gallon decrease in the price of heating oil would result in an approximate $14.2 million increase in our expense related to the heating oil derivatives, which, if realized, would be offset by a decrease in the cost of our physical diesel purchases.

We are exposed to market risk associated with interest rates due to our existing level of indebtedness. At June 30, 2010, of our $1.8 billion principal amount of debt outstanding, $237.9 million of outstanding borrowings have interest rates that fluctuate based on changes in the respective market rates. A one percentage point increase in the interest rates related to these borrowings would result in an annualized increase in interest expense of $2.4 million, based on borrowing levels at June 30, 2010.

Item 4. Controls and Procedures.

We performed an evaluation under the supervision and with the participation of our management, including our chief executive officer and chief financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures as of June 30, 2010. Based on that evaluation, our management, including our chief executive officer and chief financial officer, concluded that the disclosure controls and procedures were effective as of such date. There were no changes in internal control over financial reporting that occurred during our fiscal quarter ended June 30, 2010 that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II
OTHER INFORMATION

Item 1. Legal Proceedings

We are involved in various claims and legal actions in the ordinary course of business. In the opinion of management, the outcome of such ordinary course of business proceedings and litigation currently pending will not have a material adverse effect on our results of operations or financial results.

Permit Litigation Matters

As described in our Annual Report on Form 10-K for the year ended December 31, 2009, surface mines at our Mingo Logan and Coal-Mac mining operations were identified in an existing lawsuit brought by the Ohio Valley Environmental Coalition (“OVEC”) in the U.S. District Court for the Southern District of West Virginia as having been granted Clean Water Act §404 permits by the Army Corps of Engineers (“the Corps”), allegedly in violation of the Clean Water Act and the National Environmental Policy Act.

The lawsuit, brought by OVEC in September 2005, originally was filed against the Corps claiming that permits it had issued to four subsidiaries of a company unrelated to us or our operating subsidiaries did not comply with the National Environmental Policy Act and violated the Clean Water Act.

The court ruled on the claims associated with those four permits in orders of March 23 and June 13, 2007. In the first of those orders, the court rescinded the four permits, finding that the Corps had inadequately assessed the likely impact of valley fills on headwater streams and had relied on inadequate or unproven mitigation to offset those impacts. In the second order, the court entered a declaratory judgment that discharges of sediment from the valley fills into sediment control ponds constructed in-stream to control that sediment must themselves be permitted under a different provision of the Clean Water Act, § 402, and meet the effluent limits imposed on discharges from these ponds. Both of the district court rulings were appealed to the U.S. Court of Appeals for the Fourth Circuit.

Before the court entered its first order, the plaintiffs were permitted to amend their complaint to challenge the Coal-Mac and Mingo Logan permits. Plaintiffs sought preliminary injunctions against both operations, but later reached agreements with our operating subsidiaries that have allowed mining to progress in limited areas while the district court’s rulings were on appeal. The claims against Coal-Mac were thereafter dismissed.

On February 13, 2009, the Fourth Circuit reversed the District Court. The Fourth Circuit held that the Corps’ jurisdiction under Section 404 of the Clean Water Act is limited to the narrow issue of the filling of jurisdictional waters. The court also held that the Corps’ findings of no significant impact under the National Environmental Policy Act and no significant degradation under the Clean Water Act are entitled to deference. Such findings entitle the Corps to avoid preparing an environmental impact statement, the absence of which was one issue on appeal. These holdings also validated the type of mitigation projects proposed by our operations to minimize impacts and comply with the relevant statutes. Finally, the Fourth Circuit found that stream segments, together with the sediment ponds to which they connect, are unitary “waste treatment systems,” not “waters of the United States,” and that the Corps’ had not exceeded its authority in permitting them.

OVEC sought rehearing before the entire appellate court which was denied on May 29, 2009 and the decision was given legal effect on June 24, 2009. An appeal to the U.S. Supreme Court was then filed on August 26, 2009. On August 3, 2010 OVEC withdrew its appeal.

Mingo Logan filed a motion for summary judgment with the district court on July 17, 2009, asking that judgment be entered in its favor because no outstanding legal issues remained for decision as a result of the Fourth Circuit’s February decision. By a series of motions, the United States obtained extensions and stays of the obligation to respond to the motion in the wake of its letters to the Corps dated September 3 and October 16, 2009 (discussed below). By order dated April 22, 2010, the District Court stayed the case as to Mingo Logan for the shorter of either six months or the completion of the U.S. Environmental Protection Agency’s (the “EPA”) proposed action to deny Mingo Logan the right to use its Corps’ permit (as discussed below).

Potential EPA Prohibitions Related to Water Discharges from the Spruce Permit

As described in our Annual Report on Form 10-K for the year ended December 31, 2009, by letter of September 3, 2009, the EPA asked the Corps to suspend, revoke or modify the existing permit it issued in January 2007 to Mingo Logan under Section 404 of the Clean Water Act, claiming that “new information and circumstances have arisen which justify reconsideration of the permit.” By letter of September 30, 2009, the Corps advised the EPA that it would not reconsider its decision to issue the permit. By letter of October 16, 2009, the EPA advised the Corps that it has “reason to believe” that the Mingo Logan mine will have “unacceptable adverse impacts to fish and wildlife resources” and that it intends to issue a public notice of a proposed determination to restrict or prohibit discharges of fill material that already are approved by the Corps’ permit. By federal register publication dated April 2, 2010, EPA issued its “Proposed Determination to Prohibit, Restrict or Deny the Specification, or the Use for Specification of an Area as a Disposal Site: Spruce No. 1 Surface Mine, Logan County, WV” pursuant to Section 404 c of the Clean Water Act. EPA accepted written comments on its proposed action (sometimes known as a “veto proceeding”), through June 4, 2010 and conducted a public hearing, as well, on May 18, 2010. We submitted comments on the action during this period. EPA is in the process of reviewing the thousands of comments that it received. By separate action, Mingo Logan sued EPA on April 2, 2010 in federal court in Washington, D.C. seeking a ruling that EPA has no authority under the Clean Water Act to veto a previously issued permit (Mingo Logan Coal Company, Inc. v. USEPA, No. 1:10-cv-00541(D.D.C.)). EPA has moved to dismiss that action, and we have responded to that motion. The motion is now pending before the Court.

West Virginia Flooding Litigation

Over 2,000 plaintiffs sued us and more than 100 other defendants in Wyoming, Fayette, Kanawha, Raleigh, Boone and Mercer Counties, West Virginia, for property damage and personal injuries arising out of flooding that occurred in southern West Virginia on or about July 8, 2001. The plaintiffs sued coal, timber, oil and gas 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 of Appeals ruled that these cases, along with other flood damage cases not involving us, would be handled pursuant to the court’s mass litigation rules. As a result of that ruling, the cases were initially transferred to the Circuit Court of Raleigh County in West Virginia to be handled by a panel consisting of three circuit court judges. Trials for each watershed were initiated, to proceed in phases.

On May 2, 2006, following the Mullins/Ocean phase I trial, in which we were not involved, the jury returned a verdict against the two non-settling defendants. However, the trial court set aside that verdict and granted judgment in favor of those defendants. The plaintiffs in that trial group appealed that decision, and the Supreme Court of Appeals reinstated the verdict on June 26, 2008. The court also reversed the January 18, 2007 dismissal of the Coal River watershed claims, in which we were named. The claims were remanded to the Mass Litigation Panel (the “Panel”) on September 17, 2008.

The parties were ordered to mediate the case, and a confidential global settlement was reached on December 10, 2009. On March 23, 2010, the Panel conducted a hearing regarding the settlement agreements reached, including the global settlement. The Panel discussed the terms of the settlements and heard objections from certain individual plaintiffs and their representatives regarding the proposed distributions and allocations of the settlement amounts, and advised that an order as to whether the settlements would be approved would be issued within 30 days.

On April 14, 2010, the panel notified the parties that the global settlement had been approved and the objections that had been raised were overruled. On April 20, 2010, the Panel entered an order approving the global settlement that dismisses with prejudice all claims.

You should see Part I, Item 3 of our Annual Report on Form 10-K for the year ended December 31, 2009 for more information about some of the additional proceedings and litigation in which we are involved.

Item 1A. Risk Factors.

Our business inherently involves certain risks and uncertainties. The risks and uncertainties described in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2009 or in Item 1A of other Quarterly Reports on Form 10-Q that we have filed during the current year are not the only ones we face. Additional risks and uncertainties not presently known to us or that we currently deem immaterial may also impair our business operations. Should one or more of any of

these risks materialize, our business, financial condition, results of operations or liquidity could be materially adversely affected.

There have been no material changes to the risk factors disclosed under Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2009 or under Item 1A of other Quarterly Reports on Form 10-Q that we have filed during the current year.

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

In September 2006, our board of directors authorized a share repurchase program for the purchase of up to 14,000,000 shares of our common stock. There is no expiration date on the current authorization, and we have not made any decisions to suspend or cancel purchases under the program. As of June 30, 2010, there were 10,925,800 shares of our common stock available for purchase under this program. We did not purchase any shares of our common stock under this program during the quarter ended June 30, 2010. Based on the closing price of our common stock as reported on the New York Stock Exchange on August 2, 2010, the approximate dollar value of our common stock that may yet be purchased under this program was $271.3 million.

Item 3. Defaults Upon Senior Securities.

None

Item 4. Reserved.

Item 5. Other Information.

Mine Safety and Health Administration Safety Data

We believe that Arch Coal is one of the safest coal mining companies in the world. Safety is a core value at Arch Coal and at our subsidiary operations. We have in place a comprehensive safety program that includes extensive health & safety training for all employees, site inspections, emergency response preparedness, crisis communications training, incident investigation, regulatory compliance training and process auditing, as well as an open dialogue between all levels of employees. The goals of our processes are to eliminate exposure to hazards in the workplace, ensure that we comply with all mine safety regulations, and support regulatory and industry efforts to improve the health and safety of our employees along with the industry as a whole.

Under the recently enacted Dodd-Frank Wall Street Reform and Consumer Protection Act, each operator of a coal or other mine is required to include certain mine safety results in its periodic reports filed with the Securities and Exchange Commission. The operation of our mines is subject to regulation by the federal Mine Safety and Health Administration (“MSHA”) under the Federal Mine Safety and Health Act of 1977 (the “Mine Act”). Below we present the following items regarding certain mining safety and health matters, broken down by mining complex owned and operated by Arch Coal or our subsidiaries, for the three-month period ended June 30, 2010:

	•		Total number of violations of mandatory health or safety standards that could significantly and substantially contribute to the cause and effect of a coal or other mine safety or health hazard under section 104 of the Mine Act for which we have received a citation from MSHA;

	•		Total number of orders issued under section 104(b) of the Mine Act;

	•		Total number of citations and orders for unwarrantable failure of the mine operator to comply with mandatory health or safety standards under Section 104(d) of the Mine Act;

	•		Total number of imminent danger orders issued under section 107(a) of the Mine Act; and

	•		Total dollar value of proposed assessments from MSHA under the Mine Act.


	Mine Act
	Section 104						Mine Act
	Significant				Mine Act		Section 107(a)		Total Dollar Value of
	and		Mine Act		Section 104(d)		Imminent		Proposed MSHA
	Substantial		Section 104(b)		Unwarrantable Failure		Danger		Assessments
Mining complex(1)	Citations		Orders		Citations/Orders		Orders		(in thousands)(2)

Power River Basin:
Black Thunder		6		—		—		—	$	12
Coal Creek		2		—		—		—	$	—

Western Bituminous:
Arch of Wyoming		1		—		—		—	$	—
Dugout Canyon		16		1		—		—	$	10
Skyline		3		—		—		—	$	4
Sufco		16		—		—		—	$	22
West Elk		9		—		—		2	$	91

Central Appalachia:
Coal-Mac		3		—		—		—	$	2
Cumberland River		20		—		1		—	$	68
Lone Mountain		55		—		5		—	$	54
Mountain Laurel		27		—		—		—	$	43


⁽¹⁾		MSHA assigns an identification number to each coal mine and may or may not assign separate identification numbers to related facilities such as preparation plants. We are providing the information in this table by mining complex rather than MSHA identification number because we believe this format will be more useful to investors than providing information based on MSHA identification numbers. For descriptions of each of these mining operations, please refer to the descriptions under Item 1. Business, in Part I of our Annual Report on Form 10-K for the fiscal year ended December 31, 2009.

⁽²⁾		Amounts included under the heading “Proposed Assessments” are the total dollar amounts for proposed assessments received from MSHA on or before August 4, 2010, for citations and orders occurring during the three-month period ended June 30, 2010.

For the three-month period ended June 30, 2010, none of our mining complexes received written notice from MSHA of (i) a flagrant violation under section 110(b)(2) of the Mine Act; (ii) a pattern of violations of mandatory health or safety standards that are of such nature as could have significantly and substantially contributed to the cause and effect of coal or other mine health or safety hazards under section 104(e) of the Mine Act; or (iii) the potential to have such a pattern. For the three-month period ended June 30, 2010, we experienced one fatality at our Lone Mountain mining complex.

As of June 30, 2010, we have a total of ninety-two matters pending before the Federal Mine Safety and Health Review Commission. This includes legal actions that were initiated prior to the three-month period ended June 30, 2010 and which do not necessarily relate to the citations, orders or proposed assessments issued by MSHA during such three-month period.

In evaluating the above information regarding mine safety and health, investors should take into account factors such as: (i) the number of citations and orders will vary depending on the size of a coal mine, (ii) the number of citations issued will vary from inspector to inspector and mine to mine, and (iii) citations and orders can be contested and appealed, and during that process are often reduced in severity and amount, and are sometimes dismissed.

Item 6. Exhibits.

The following is a list of exhibits filed as part of this Quarterly Report on Form 10-Q:


Exhibit		Description
4.1		Third Supplemental Indenture, dated May 7, 2010, by and among Arch Coal, Inc., the subsidiary guarantors named therein and U.S. Bank National Association, as trustee (incorporated herein by reference to Exhibit 4.3 to Arch Coal, Inc.’s Quarterly Report on Form 10-Q for the period ended June 30, 2010).

10.1		Underwriting Agreement, dated August 2, 2010, by and among Arch Coal, Inc., the subsidiary guarantors named therein and Banc of America Securities LLC, Citigroup Global Markets Inc., Morgan Stanley & Co. Incorporated and J.P. Morgan Securities Inc., as representatives of the several underwriters named therein (incorporated herein by reference to Exhibit 1.1 to Arch Coal, Inc.’s Current Report on Form 8-K filed on August 3, 2010).

12.1		Computation of ratio of earnings to combined fixed charges and preference dividends.

31.1		Rule 13a-14(a)/15d-14(a) Certification of Steven F. Leer.

31.2		Rule 13a-14(a)/15d-14(a) Certification of John T. Drexler.

32.1		Section 1350 Certification of Steven F. Leer.

32.2		Section 1350 Certification of John T. Drexler.

101		Interactive Data File (Form 10-Q for the quarter ended June 30, 2010 furnished in XBRL). The financial information contained in the XBRL-related documents is “unaudited” and “unreviewed” and, in accordance with Rule 406T of Regulation S-T, is not deemed “filed” for purposes of Sections 11 and 12 of the Securities Act of 1933, as amended, and Section 18 of the Securities Exchange Act of 1934, as amended, or otherwise subject to liability under these sections.

Signatures

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


	Arch Coal, Inc.
	By:	/s/ John T. Drexler
		John T. Drexler
		Senior Vice President and Chief Financial Officer August 6, 2010