q2form10

q2form10_.htm

SECURITIES AND EXCHANGE COMMISSION

Washington, D. C. 20549

FORM 10-Q

R QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15 (d)

OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE QUARTERLY PERIOD ENDED JUNE 30, 2010

£ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15 (d)

OF THE SECURITIES EXCHANGE ACT OF 1934

FOR THE TRANSITION PERIOD FROM_____TO_____

1-5491

Commission File Number

ROWAN COMPANIES, INC.

(Exact name of registrant as specified in its charter)

Delaware	75-0759420
(State or other jurisdiction of	(I.R.S. Employer
incorporation or organization)	Identification No.)

2800 Post Oak Boulevard, Suite 5450 Houston, Texas	77056-6189
(Address of principal executive offices)	(Zip Code)

(713) 621-7800

Registrant's telephone number, including area code

Inapplicable

(Former name, former address and former fiscal year, if changed since last report)

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate website, 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 R No £

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. Large accelerated filer R Accelerated filer £ Non-accelerated filer £ Smaller reporting company £

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

The number of shares of common stock, $0.125 par value, outstanding at July 31, 2010, was 114,632,793.

Table of Contents

ROWAN COMPANIES, INC.

TABLE OF CONTENTS

		Page
PART I	FINANCIAL INFORMATION

Item 1.	Financial Statements (Unaudited):

	Condensed Consolidated Balance Sheets – June 30, 2010, and December 31, 2009	1

	Condensed Consolidated Statements of Income – Three and six months ended June 30, 2010 and 2009	3

	Condensed Consolidated Statements of Cash Flows – Six months ended June 30, 2010 and 2009	4

	Notes to Unaudited Condensed Consolidated Financial Statements	5

Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	12

Item 3.	Quantitative and Qualitative Disclosures About Market Risk	26

Item 4.	Controls and Procedures	27

PART II	OTHER INFORMATION

Item 1.	Legal Proceedings	27

Item 1A.	Risk Factors	27

Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	28

Item 6.	Exhibits	29

	SIGNATURES	30

Table of Contents

PART I. FINANCIAL INFORMATION

Item 1. Financial Statements

ROWAN COMPANIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except share amounts)

(Unaudited)

	June 30,		December 31,
	2010		2009
ASSETS

CURRENT ASSETS:
Cash and cash equivalents	$	610,939	$	639,681
Receivables, net - trade and other (Note 10)		352,988		343,642
Inventories, net - at cost:
Raw materials and supplies		275,760		309,682
Work-in-progress		105,289		141,036
Finished goods		460		941
Prepaid expenses and other current assets		75,791		76,744
Deferred tax assets - net		42,253		38,071
Total current assets		1,463,480		1,549,797

PROPERTY, PLANT AND EQUIPMENT - at cost:
Drilling equipment		4,202,076		3,975,006
Manufacturing plant and equipment		250,424		251,882
Construction in progress		502,819		528,669
Other property and equipment		147,077		144,337
Property, plant and equipment - gross		5,102,396		4,899,894
Less accumulated depreciation and amortization		1,403,954		1,320,409
Property, plant and equipment - net		3,698,442		3,579,485

Other assets		76,641		81,412

TOTAL ASSETS	$	5,238,563	$	5,210,694

See Notes to Unaudited Condensed Consolidated Financial Statements.

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS (continued)

(In thousands, except share amounts)

(Unaudited)

	June 30,			December 31,
	2010			2009
LIABILITIES AND STOCKHOLDERS' EQUITY

CURRENT LIABILITIES:
Current maturities of long-term debt	$	58,563		$	64,922
Accounts payable - trade		109,500			124,562
Deferred revenues		116,041			139,398
Billings in excess of costs and estimated profits on uncompleted contracts		21,602			25,226
Accrued compensation and related employee costs		59,887			110,526
Accrued income taxes		11,441			40,990
Accrued interest		19,198			20,100
Other current liabilities		42,128			42,548
Total current liabilities		438,360			568,272

Long-term debt - less current maturities		761,552			787,490
Other liabilities		289,794			278,862
Deferred income taxes - net		476,028			465,700
Commitments and contingent liabilities (Notes 7 and 8)		-			-

STOCKHOLDERS' EQUITY:
Preferred stock, $1.00 par value, 5,000,000 shares authorized, issuable in series:
Series A Junior Preferred Stock, 1,500,000 shares authorized, none issued		-			-
Common stock, $0.125 par value, 150,000,000 shares authorized;
114,518,371 shares and 113,885,661 shares issued at June 30, 2010 and December 31, 2009, respectively		14,315			14,237
Additional paid-in capital		1,087,756			1,078,337
Retained earnings		2,325,065			2,169,526
Cost of 142,066 and 52,342 treasury shares, respectively		(3,986	)		(1,409	)
Accumulated other comprehensive loss		(150,321	)		(150,321	)
Total stockholders' equity		3,272,829			3,110,370

TOTAL LIABILITIES AND STOCKHOLDERS' EQUITY	$	5,238,563		$	5,210,694

See Notes to Unaudited Condensed Consolidated Financial Statements.

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except per share amounts)

(Unaudited)


	Three Months Ended June 30,						Six Months Ended June 30,
	2010			2009			2010			2009

REVENUES:
Drilling services (Note 10)	$	328,277		$	320,807		$	659,261		$	701,177
Manufacturing sales and services		161,759			161,353			263,180			275,791
Total revenues		490,036			482,160			922,441			976,968

COSTS AND EXPENSES:
Drilling services (excluding items below)		139,008			136,840			275,555			282,221
Manufacturing sales and services (excluding items below)		138,102			147,388			222,672			238,196
Depreciation and amortization		46,458			42,609			91,950			83,108
Selling, general and administrative		36,077			24,720			61,874			49,296
Loss (gain) on disposals of property and equipment		34			60			(95	)		(4,641	)
Material charge - manufacturing inventories (Note 10)		-			-			42,024			-
Total costs and expenses		359,679			351,617			693,980			648,180

INCOME FROM OPERATIONS		130,357			130,543			228,461			328,788

OTHER INCOME (EXPENSE):
Interest expense		(12,903	)		(2,457	)		(25,873	)		(5,600	)
Interest capitalized		7,652			2,343			14,943			5,107
Interest income		253			201			434			532
Other - net		(1,443	)		2,422			102			3,836
Total other income (expense) - net		(6,441	)		2,509			(10,394	)		3,875

INCOME BEFORE INCOME TAXES		123,916			133,052			218,067			332,663
Provision for income taxes		33,000			36,469			62,528			104,380

NET INCOME	$	90,916		$	96,583		$	155,539		$	228,283

PER SHARE AMOUNTS:
Net income - basic	$	.80		$	.85		$	1.38		$	2.01
Net income - diluted	$	.79		$	.85		$	1.36		$	2.01

See Notes to Unaudited Condensed Consolidated Financial Statements.

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended June 30,
	2010			2009

CASH PROVIDED BY OPERATIONS:
Net income	$	155,539		$	228,283
Adjustments to reconcile net income to net cash provided by operations:
Depreciation and amortization		91,950			83,108
Deferred income taxes		6,146			42,225
Stock-based compensation expense		7,049			6,004
Provision for pension and postretirement benefits		19,329			23,431
Contributions to pension plans		(42,110	)		(16,685	)
Postretirement benefit claims paid		(1,713	)		(1,740	)
Gain on disposals of property, plant and equipment		(95	)		(4,641	)
Changes in current assets and liabilities:
Receivables - trade and other		(9,346	)		107,881
Inventories		70,597			24,397
Prepaid expenses and other current assets		953			(37,182	)
Accounts payable		(17,242	)		(156,294	)
Accrued income taxes		(29,549	)		(53,410	)
Deferred revenues		(23,357	)		15,344
Billings in excess of costs and estimated profits on uncompleted contracts		(3,624	)		(9,194	)
Other current liabilities		(12,873	)		(24,648	)
Net changes in other noncurrent assets and liabilities		(1,369	)		(1,949	)
Net cash provided by operations		210,285			224,930

CASH USED IN INVESTING ACTIVITIES:
Capital expenditures		(210,383	)		(210,265	)
Proceeds from disposals of property, plant and equipment		878			5,472
Net cash used in investing activities		(209,505	)		(204,793	)

CASH USED IN FINANCING ACTIVITIES:
Repayments of borrowings		(32,461	)		(32,461	)
Proceeds from stock option and convertible debenture plans and other		2,939			3,757
Net cash used in financing activities		(29,522	)		(28,704	)

DECREASE IN CASH AND CASH EQUIVALENTS		(28,742	)		(8,567	)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		639,681			222,428
CASH AND CASH EQUIVALENTS, END OF PERIOD	$	610,939		$	213,861

See Notes to Unaudited Condensed Consolidated Financial Statements.

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Note 1 – General

The condensed consolidated financial statements of Rowan Companies, Inc. (“Rowan” or the “Company”) included in this Form 10-Q have been prepared without audit in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and the rules and regulations of the Securities and Exchange Commission. Certain information and notes have been condensed or omitted as permitted by those rules and regulations. The unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements and related notes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2009.

Rowan believes the accompanying unaudited condensed consolidated financial statements contain all adjustments, which are of a normal recurring nature unless otherwise noted, necessary for a fair statement of the results for the interim periods presented. Rowan’s results of operations and cash flows for the interim periods are not necessarily indicative of results to be expected for the full year. (See discussion under “Material Charge” in Note 10.)

Note 2 – Segment Information

Rowan has three principal operating segments – Drilling Services, Drilling Products and Systems, and Mining, Forestry and Steel Products. The largest of these is the Drilling Services segment, which provides onshore and offshore oil and gas contract drilling services on a daily-rate basis. The Drilling Products and Systems segment manufactures equipment and parts for the drilling industry featuring jack-up rigs, rig kits and related components and parts, mud pumps, drawworks, top drives, rotary tables, other rig equipment, variable-speed motors, drives and other electrical components. The Mining, Forestry and Steel Products segment manufactures large-wheeled mining and timber equipment and related parts, and carbon and alloy steel plate. The Drilling Products and Systems and Mining, For estry and Steel Products segments operate under the Company’s wholly owned subsidiary, LeTourneau Technologies, Inc (“LeTourneau”).

The following table presents certain financial information by operating segment for the three and six months ended June 30, 2010 and 2009 (in millions):

	Three Months						Six Months
	Ended June 30,						Ended June 30,
	2010			2009			2010			2009

Revenues:
Drilling Services (Note 10)	$	328.3		$	320.8		$	659.3		$	701.2
Manufacturing:
Drilling Products and Systems		124.1			141.8			220.1			286.4
Mining, Forestry and Steel Products		90.1			54.7			141.2			98.0
Total manufacturing		214.2			196.5			361.3			384.4
Eliminations		(52.4	)		(35.1	)		(98.1	)		(108.6	)
Total revenues from external customers	$	490.1		$	482.2		$	922.5		$	977.0

Income (loss) from operations:
Drilling Services	$	121.8		$	127.2		$	256.6		$	312.7
Manufacturing:
Drilling Products and Systems (Note 10)		-			3.7			(38.4	)		30.2
Mining, Forestry and Steel Products		21.7			8.9			32.9			14.0
Total manufacturing		21.7			12.6			(5.5	)		44.2
Eliminations		(13.1	)		(9.2	)		(22.6	)		(28.1	)
Total income from operations	$	130.4		$	130.6		$	228.5		$	328.8

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Note 3 – Earnings Per Share

A reconciliation of basic and diluted shares for the three and six months ended June 30, 2010 and 2009 follows (in thousands):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2010		2009		2010		2009

Average common shares outstanding - basic		113,171		113,596		113,016		113,362
Add: Dilutive shares issuable under stock-based compensation plans		1,827		46		1,758		53
Average shares for diluted calculations		114,998		113,642		114,774		113,415

There were no adjustments to net income required for purposes of computing diluted earnings per share.

The following table sets forth the share effects of securities excluded from the diluted calculations for the three and six months ended June 30, 2010 and 2009, because they were antidilutive. Options and other potentially dilutive securities are antidilutive when the exercise or conversion price exceeds the average market price of the Company’s common stock during the period (in thousands):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2010		2009		2010		2009

Employee and director stock options		164		1,792		164		1,792
Stock appreciation rights		180		514		169		514
Shares issuable upon conversion of debentures		-		35		-		35
Total potentially dilutive shares		344		2,341		333		2,341

Note 4 – Pension and Other Postretirement Benefits

Rowan sponsors defined benefit pension plans covering substantially all of its employees, and provides health care and life insurance benefits upon retirement for certain employees.

Net periodic pension cost recognized for the three and six months ended June 30, 2010 and 2009 included the following components (in thousands):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2010			2009			2010			2009

Service cost	$	3,969		$	4,477		$	7,894		$	8,905
Interest cost		7,737			8,405			15,389			16,718
Expected return on plan assets		(7,611	)		(7,233	)		(15,138	)		(14,387	)
Recognized actuarial loss		5,318			4,040			10,621			8,056
Amortization of prior service cost		(1,665	)		(63	)		(3,312	)		(125	)
Total net pension cost	$	7,748		$	9,626		$	15,454		$	19,167

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Other postretirement benefit cost recognized for the three and six months ended June 30, 2010 and 2009 included the following components (in thousands):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2010			2009			2010			2009

Service cost	$	589		$	631		$	1,172		$	1,254
Interest cost		1,147			1,244			2,282			2,474
Recognized actuarial loss		98			155			195			310
Amortization of transition obligation		165			165			328			328
Amortization of prior service cost		(51	)		(51	)		(102	)		(101	)
Total other postretirement benefit cost	$	1,948		$	2,144		$	3,875		$	4,265

During the six months ended June 30, 2010, Rowan contributed $43.8 million to its pension and other postretirement benefit plans and expects to make additional contributions to such plans totaling approximately $16.9 million during the remainder of 2010.

Note 5 – Cash and Cash Equivalents

Certain of Rowan’s debt securities are government-guaranteed through the Title XI program of the U.S. Department of Transportation’s Maritime Administration (“MARAD”). At the Company’s request, MARAD waived certain windstorm insurance coverage requirements under the loan agreements, for which the Company agreed to maintain a minimum cash balance, which is currently $25 million. Rowan remains subject to restrictions on the use of certain insurance proceeds should the Company experience future windstorm losses. Each of these security provisions will be released by MARAD should Rowan be able to obtain windstorm coverage that satisfies the original terms of its debt agreements.

Note 6 – Construction Contracts in Process

The following table summarizes the status of long-term manufacturing contracts in process. Payments, revenues and costs are cumulative from inception of the contract through the date indicated. Payments include those received for contracts in progress or not yet begun and completed contracts with outstanding collections (in thousands):

	June 30,		December 31,
	2010		2009

Total contract value of long-term contracts in process or not yet begun	$	206,382	$	204,201
Payments received		162,992		119,653
Revenues recognized		145,282		102,155
Costs recognized		90,358		61,407
Payments received in excess of revenues recognized		17,710		17,498
Billings in excess of costs and estimated profits on uncompleted contracts (included in current liabilities)	$	21,602	$	25,226
Costs and estimated profits in excess of billings on uncompleted contracts (included in prepaid expenses and other current assets)	$	3,892	$	7,728

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

During the three months ended June 30, 2010, Rowan recognized approximately $25.2 million of manufacturing revenues and $17.4 million of manufacturing costs related to long-term construction contracts on the percentage-of-completion basis, as compared to $24.5 million of revenues and $19.3 million of costs for the comparable period of 2009.

During the six months ended June 30, 2010, Rowan recognized approximately $43.7 million of manufacturing revenues and $29.3 million of manufacturing costs on the percentage-of-completion basis, as compared to $50.6 million of revenues and $35.5 million of costs for the comparable period of 2009.

Note 7 – Commitments

The following table presents the status of all of the Company’s rigs under construction as of June 30, 2010, and includes the estimated amounts necessary to complete construction of the rigs to be acquired in the transaction to purchase Skeie Drilling & Production ASA (see Note 11 – Subsequent Events). Amounts include capitalized interest (in millions):

	Total estimated project costs		Total costs incurred through June 30, 2010		Projected costs for the remainder of 2010		Projected costs in 2011		Projected costs in 2012

Joe Douglas (240C)	$	246	$	130	$	51	$	65	$	-
EXL #2		194		166		28		-		-
EXL #3		197		149		48		-		-
EXL #4		197		58		66		41		32
Skeie rigs		725		-		483		242		-
Total rigs under construction	$	1,559	$	503	$	676	$	348	$	32

Projected costs for the Skeie rigs totaling $725 million per the table above includes amounts expected to be paid from cash and restricted cash held by Skeie totaling $269 million at June 30, 2010, and includes estimated capitalized interest of $12 million and $10 million in 2010 and 2011, respectively.

Rowan periodically employs letters of credit or other bank-issued guarantees in the normal course of its businesses, and had outstanding letters of credit of approximately $41.4 million at June 30, 2010.

Note 8 – Legal Proceedings

During 2005, Rowan lost four offshore rigs, including the Rowan-Halifax, and incurred significant damage on a fifth as a result of Hurricanes Katrina and Rita. The Company had leased the Rowan-Halifax under a charter agreement that commenced in 1984 and was scheduled to expire in March 2008. The rig was insured for $43.4 million, a value that Rowan believes to be more than sufficient to satisfy its obligations under the charter agreement, and by a margin sufficient to cover the $6.3 million carrying value of Rowan equipment installed on the rig. However, the parties holding interests in the rig under the charter claimed that the rig should have been insured for its fair market value and soug ht recovery from Rowan for compensation above the insured value. Thus, Rowan assumed no insurance proceeds related to the Rowan-Halifax and recorded a charge during 2005 for the full carrying value of its equipment. On November 3, 2005, the Company filed a declaratory judgment action styled Rowan Companies, Inc. vs. Textron Financial Corporation and Wilmington Trust Company as Owner Trustee of the Rowan-Halifax 116-C Jack-Up Rig in the 215th Judicial District Court of Harris County, Texas. The owner interests filed a counterclaim for a variety of relief, claiming a right to payment under the charter based on a post-casualty rig valuation of approximately $83 million. The insurance proceeds were placed in escrow. The district court ultimately granted judgment against Rowan for the difference between (a) what Rowan had already paid to the Owner Trus tee out of

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

the escrowed insurance proceeds and (b) that rig valuation. On March 31, 2009, the Court of Appeals for the 14th District of Texas reversed this judgment, holding that the Company’s interpretation of the charter was substantially correct, but directing Rowan to pay additional amounts due under the charter. The Company has since made this payment out of the escrowed insurance proceeds. In addition, the Court of Appeals remanded the case for further proceedings in the district court to resolve additional issues and to determine the parties’ respective rights to the balance of the escrowed insurance proceeds, which is currently $21.4 million. The owner interests filed a motion for rehearing of the Court of Appeals’ decision. On October 8, 2009, the Court of Appeals denied the motion, but issued a substitute opinion to clarify the scope of the remand. The Court of Appeals again held that the trial court is to resolve issues concerning the proper disposition of excess insurance proceeds. The Court of Appeals further held that the owner interests’ claim that Rowan breached the charter agreement by failing to maintain adequate insurance remains to be decided by the trial court. The owner interests filed another motion for rehearing, which motion was denied in January 2010. On March 22, 2010, the owner interests filed its petition for review in the Supreme Court of Texas. The Company believes that no further payment is owed to the opposing parties under the charter and intends to pursue that position vigorously in all subsequent court proceedings.

During 2004, Rowan learned that the Environmental and Natural Resources Division, Environmental Crimes Section of the U.S. Department of Justice (“DOJ”) had begun conducting a criminal investigation of environmental matters involving several of the Company’s offshore drilling rigs, including a rig known as the Rowan-Midland, which at various times operated in the Gulf of Mexico. In 2007, the Company entered into a plea agreement with the DOJ, as amended, under which the Company paid fines and made community service payments totaling $9 million and agreed to be subject to unsupervised probation for a period of three years, ending November 2010. During this period the Company must ensure that it commits no further criminal violation s of federal, state, or local laws or regulations and must also continue to implement its comprehensive Environmental Management System Plan. Subsequent to the conduct at issue, the Company sold the Rowan-Midland to a third party. Concurrent with the plea agreement, the Environmental Protection Agency approved a compliance agreement with Rowan which, among other things, contains a certification that the conditions giving rise to the violations to which the Company entered guilty pleas have been corrected. The Company believes that if it fully complies with the terms of the compliance agreement, it will not be suspended or debarred from entering into or participating in contracts with the U.S. Government or any of its agencies.

On January 3, 2008, a civil lawsuit styled State of Louisiana, ex. rel. Charles C. Foti, Jr., Attorney General vs. Rowan Companies, Inc. was filed in U.S District Court, Eastern District of Texas, Marshall Division, seeking damages, civil penalties and costs and expenses for alleged commission of maritime torts and violations of environmental and other laws and regulations involving the Rowan-Midland and other facilities in areas in or near Louisiana. Subsequently, the case was transferred to U.S. District Court, Southern District of Texas, Houston Division. On July 28, 2010, the District Court dismissed the claims of the plaintiff. At this time, the Company is not aware of any appeal by the plaintiff. The Company intends to vigorously defend its position in this case but cannot estimate any potential liability at this time.

In June 2007, Rowan received a subpoena for documents from the U.S. District Court, Eastern District of Louisiana, relating to a grand jury hearing. The agency requesting the information is the U.S. Department of the Interior, Office of Inspector General Investigations. The documents requested include all records relating to use of the Company’s entertainment facilities and entertainment expenses for a former employee of the Minerals Management Service, U.S. Department of Interior, and other records relating to items of value provided to any official or employee of the U.S. Government. The Company fully cooperated with the subpoena.

The construction of Rowan’s fourth Tarzan-class jack-up rig, the J.P. Bussell, was originally subcontracted to an outside Gulf of Mexico shipyard, Signal International LLC (“Signal”), and scheduled for delivery in the third quarter of 2007 at a total cost of approximately $145 million. As a result of various problems encountered on the project, Rowan exercised its right to take over the rig construction pursuant to the terms of the construction contract, and Signal turned the rig over to the Company in March 2008. The rig was later completed by the Company more than one year behind schedule, and its final cost was approximately 40% over the original estimate. Accordingly, R owan has declared Signal in breach of contract and initiated court proceedings styled Rowan Companies, Inc. and LeTourneau Technologies, Inc. vs. Signal International LLC in the 269th Judicial District Court of Harris County, Texas, to recover the cost to complete the rig over and above the agreed contract price and other damages, plus

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

interest. Signal filed a separate counterclaim against Rowan styled Signal International LLC vs. LeTourneau, Inc., in the U.S. District Court, Southern District of Texas, Houston Division, alleging breach of contract and claiming unspecified damages for cost overruns. That case has been administratively stayed in favor of the State Court proceeding filed by the Company. Signal reasserted its claimed damages for amounts owed and additional costs incurred, totaling approximately $88 million, as a counterclaim in the State Court suit. The Company intends to vigorously defend its rights under the contract. The Company does not believe that it is probable that Signal will prevail in its claim and has made no accrual for such at Ju ne 30, 2010.

During 2005, the Company learned that the DOJ was conducting an investigation of potential antitrust violations among helicopter transportation providers in the Gulf of Mexico. Rowan's former aviation subsidiary, which was sold effective December 31, 2004, received a subpoena in connection with the investigation. The Company has not been contacted by the DOJ, but the purchaser claimed that Rowan is responsible for any exposure it may have. The Company has disputed that claim. On August 6, 2009, the Company received a letter from the purchaser informing the Company that Rowan’s former aviation subsidiary has been named as a defendant in a purported class action lawsuit alleging antitrust violations and claiming that Rowan is responsible for any exposure the purchaser may have under the lawsuit. 0; The Company disputes that claim as well.

Rowan is involved in various other legal proceedings incidental to its businesses and is vigorously defending its position in all such matters. The Company believes that there are no other known contingencies, claims or lawsuits that could have a material adverse effect on its financial position, results of operations or cash flows.

Note 9 – Stock-Based Compensation

On March 5, 2010, the Company granted restricted stock awards and stock appreciation rights covering a total of 798,846 shares, which vest in one-third increments over a three-year service period, with a fair value aggregating approximately $17.7 million. Grant-date fair value, net of estimated forfeitures, was $17.1 million, which will be amortized on a straight-line basis over three years from the grant date.

At June 30, 2010, Rowan had approximately $30.5 million of unrecognized future stock-based compensation expense, which is expected to be recognized over a remaining weighted-average period of 1.5 years.

Note 10 – Other Financial Statement Disclosures

Receivables – Trade and Other – Due to a contract dispute with its Mexico agent, the Company has been unable to submit billings to or make collections from PEMEX for use of the Gorilla IV during 2010 and, as a result, had $30.8 million of accrued or unbilled revenues and related value added taxes included in trade accounts receivable at June 30, 2010. The Company believes all amounts due or accrued under the PEMEX contract will be collected.

Fair Values of Financial Instruments – The carrying amounts of the Company’s cash and cash equivalents, trade receivables and trade payables approximated their fair values due to their short maturities. As of June 30, 2010, the fair values of the Company’s debt, which had an aggregate carrying value of $820.1 million, approximated $890 million. Fair values of the Company’s debt was estimated based on quoted market prices for the same or similar issues or on the current rates offered to the Company for debt of the same remaining maturities.

Supplemental Cash Flow Information – Accrued capital expenditures, which are excluded from capital expenditures in the Condensed Consolidated Statements of Cash Flows until settlement, were $25.0 million and $39.9 million at June 30, 2010 and 2009, respectively.

Other Comprehensive Income – Rowan had no items of other comprehensive income during the three or six months ended June 30, 2010 or 2009.

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (Continued)

Material Charge – During the first quarter of 2010, the Drilling Products and Systems manufacturing segment performed an assessment of its Houston-based raw materials and supplies inventory. As a result, the Company increased its inventory valuation reserve by approximately $42.0 million and recorded a corresponding charge to its operations during the period to reflect a reduction in the estimated realizable value of items that were deemed to be nonconforming or slow-moving. Such amount is reflected in the Condensed Consolidated Statements of Income on the line, “Material charge – manufacturing inventories.”

Note 11 – Subsequent Events

On July 1, 2010, the Company entered into a Share Purchase Agreement (the “Purchase Agreement”) with certain shareholders of Skeie Drilling & Production ASA (“Skeie”) and obtained irrevocable commitments from two other shareholders of Skeie (collectively, the “Sellers”) for the purchase of their shares constituting 48.8% of the outstanding ordinary shares of Skeie. Rowan had previously acquired approximately 1.5% of Skeie’s outstanding ordinary shares in open market purchases for cash. As of July 19, 2010, the Company’s obligation to purchase the Sellers’ shares and to tender for the remaining outstanding shares of Skeie became unconditional.

Under the terms of the Purchase Agreement and irrevocable commitments, the Company will issue 0.00574167 shares of the Company’s common stock for each of the 1,037,006,792 ordinary shares of Skeie collectively owned by the Sellers, resulting in the issuance of 5,954,151 shares of the Company’s common stock. Rowan intends to commence a tender offer in August for the remaining 49.7% of outstanding shares of Skeie on the same terms, which would result in the issuance of approximately 6.1 million additional Rowan shares.

Skeie is a Norwegian entity that owns and manages the construction of three high-spec jack-up rigs, designated “N-Class,” designed and being built by Keppel FELS Ltd. in Singapore. The rigs are scheduled for delivery in September 2010, December 2010 and June 2011. Skeie has earned no revenues since its inception in 2006 and has not entered into any drilling contracts for the operation of its three rigs under construction.

As of June 30, 2010, Skeie had approximately $269 million in cash and restricted cash and $530 million of first and second lien debt outstanding, secured by the rigs. The Company expects the three rigs will require an additional $434 million for completion, net of cash and restricted cash acquired, plus approximately $22 million of capitalized interest. The Company currently anticipates funding the incremental amount from existing cash and operating cash flows. Assuming a Rowan stock price of $25.00 per share and the Company obtains 100% of the Skeie shares, the total cost to the Company would be approximately $1.3 billion, including estimated transaction costs. The actual consideration will depend upon the market prices of Rowan’s common stock at the time of issuance and the number of Skeie shares acquired.

The Company intends to account for the transaction as an asset acquisition and allocate the total purchase price to individual assets acquired and liabilities assumed based on relative fair values with no recognition of goodwill.

There were no other events or transactions that occurred subsequent to June 30, 2010, requiring recognition or disclosure in the financial statements.

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ROWAN COMPANIES, INC. AND SUBSIDIARIES

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

SUMMARY

In May 2010, the Company took delivery of the first newly constructed EXL-Class rig. The EXL#1 commenced operations in the U.S. Gulf of Mexico in late May under the first of two contracts for work through approximately July 2011. In June, we obtained a contract extension for the Gorilla V in the North Sea for an additional two years. We recently obtained a contract for one of our rigs currently under construction, the EXL#2, as more fully discussed below.

Although utilization of the Company’s offshore rigs improved in the first and second quarters of 2010 over the fourth quarter of 2009, leading day rates have yet to show significant improvement and remain well below peak levels, and our results of operations have continued to benefit from contracts executed prior to the global downturn that began in mid 2008. Although we have made significant increases to our drilling backlog in recent weeks, we can provide no assurance that we will continue to do so.

As of July 26, 2010, we had nine offshore rigs in the Middle East, nine in the U.S. Gulf of Mexico, two in the North Sea plus another en-route to the North Sea from West Africa, one each offshore Eastern Canada, Mexico and Egypt, and four under construction. Additionally, we had 29 actively marketed land rigs located in Texas, Louisiana and Alaska.

The Company’s second EXL-Class rig, which is currently under construction with expected delivery in September 2010, is expected to commence operations in Trinidad during the fourth quarter under a three-year contract following completion of construction in Brownsville, Texas, inspections and acceptance.

As previously reported, following the Deepwater Horizon incident, the Bureau of Ocean Energy Management, Regulation and Enforcement (formerly known as the Minerals Management Service) issued two Notices to Lessees (NTLs) implementing new safety regulations and information requirements applicable to shallow water drilling operations in the U.S. Gulf of Mexico. These NTLs impact the ability of our customers to obtain new permits on a timely basis and continue operations uninterrupted under existing permits. Although utilization of our rigs in the Gulf of Mexico declined slightly in the second quarter of 2010 as compared to the 2010 first quarter, we do not believe that our operations to date have been materially impacted by the issuance of these NTLs or the cu rrent regulatory environment. One of our Gulf rigs is under contract but is waiting on a permit. Another has been released from its contract, and we expect it to return to work in the Gulf on a well-to-well basis. The Company currently has nine jack-up drilling rigs located in the U.S. Gulf of Mexico which may be impacted from time to time by the requirements of these recent NTLs. We are working with our customers to meet these requirements. See further discussion under “Outlook – Drilling Operations.”

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RESULTS OF OPERATIONS

The following table highlights Rowan’s operating results for the three and six months ended June 30, 2010 and 2009 (dollars in millions):

	Three Months Ended June 30,									Six Months Ended June 30,
	2010			2009			% Change			2010			2009			% Change

Revenues:
Drilling	$	328.3		$	320.8			2	%	$	659.3		$	701.2			-6	%
Manufacturing:
Drilling Products and Systems		71.7			106.7			-33	%		122.0			177.8			-31	%
Mining, Forestry and Steel Products		90.1			54.7			65	%		141.2			98.0			44	%
Total Manufacturing		161.8			161.4			0	%		263.2			275.8			-5	%
Total revenues	$	490.1		$	482.2			2	%	$	922.5		$	977.0			-6	%

Costs and expenses:
Drilling	$	204.4		$	192.9			6	%	$	398.5		$	386.2			3	%
Manufacturing:
Drilling Products and Systems		86.9			112.9			-23	%		187.2			178.0			5	%
Mining, Forestry and Steel Products		68.4			45.8			49	%		108.3			84.0			29	%
Total Manufacturing		155.3			158.7			-2	%		295.5			262.0			13	%
Total costs and expenses	$	359.7		$	351.6			2	%	$	694.0		$	648.2			7	%

Operating income (loss):
Drilling	$	123.9		$	127.9			-3	%	$	260.8		$	315.0			-17	%
Manufacturing:
Drilling Products and Systems		(15.2	)		(6.2	)		145	%		(65.2	)		(0.2	)		32500	%
Mining, Forestry and Steel Products		21.7			8.9			144	%		32.9			14.0			135	%
Total Manufacturing		6.5			2.7			141	%		(32.3	)		13.8			-334	%
Total operating income	$	130.4		$	130.6			0	%	$	228.5		$	328.8			-31	%

Net income	$	90.9		$	96.6			-6	%	$	155.5		$	228.3			-32	%

Our consolidated operating income for the second quarter of 2010 was $130.4 million, which was relatively flat as compared to the second quarter of 2009. Revenues were higher by $7.9 million or 2% and operating costs were higher by $8.1 million or 2% compared to the prior year period.

Net income includes income tax expense of $33.0 million (26.6% effective rate) and $36.5 million (27.4% effective rate) for the second quarter of 2010 and 2009, respectively. During the second quarter of 2010, we adjusted the full year income tax rate to approximately 29% from 31% as a result of outbounding certain rigs into our offshore subsidiaries. This resulted in lowering our second quarter effective tax rate to 26.6%. In the second quarter of 2009, we recognized an $8 million tax benefit ($0.07 per diluted share) as a result of applying our facts to a 2009 third-party tax case that provides a more favorable tax treatment for certain foreign contracts entered into in prior years.

For the first six months of 2010, our consolidated operating income was $228.5 million, which was lower by $100.3 million or 31%, as compared to the comparable prior year period, on a $54.5 million or 6% decrease in revenues and a $45.8 million or 7% increase in costs. Included in operating income and costs for the six months ended June 30, 2010, was a $42.0 million manufacturing inventory charge discussed below.

During the first quarter of 2010, the Drilling Products and Systems manufacturing segment performed an assessment of its Houston-based raw materials and supplies inventory. As a result, the Company increased its inventory valuation reserve by approximately $42.0 million and recorded a corresponding charge to its operations during the period to reflect a reduction in the estimated realizable value of items that were deemed to be nonconforming or slow-moving. (See further discussion under “Results of Operations – Drilling Products and Systems.”)

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The income tax provision for the first six months of 2010 and 2009 was $62.5 million (28.7% effective rate) and $104.4 million (31.4% effective rate), respectively.

Drilling operations

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

The following table highlights the performance of our Drilling Services segment for the three months ended June 30, 2010 and 2009 (dollars in millions, except for average day rate):

	Three months ended June 30,
	2010						2009
	Amount			% of Revenues			Amount			% of Revenues

Revenues	$	328.3			100	%	$	320.8			100	%
Operating costs		(139.0	)		-42	%		(136.8	)		-43	%
Depreciation expense		(41.9	)		-13	%		(38.7	)		-12	%
Selling, general and administrative expenses		(23.5	)		-7	%		(17.4	)		-5	%
Net gain on property disposals		-			0	%		-			0	%
Operating income	$	123.9			38	%	$	127.9			40	%

Offshore fleet:
Average day rate	$	174,500					$	177,200
Rig utilization		75	%					78	%
Revenue-producing days		1,589						1,561

Land fleet:
Average day rate	$	19,800					$	22,400
Rig utilization		78	%					60	%
Revenue-producing days		2,265						1,721

Drilling revenues for the three months ended June 30, 2010 increased by $7.5 million or 2% compared to the second quarter of 2009 as a result of the following (in millions):

	Increase
	(Decrease)

Addition of the Ralph Coffman and EXL#11	$	19.0
Higher land rig utilization		10.7
Addition of one land rig in 20092		1.6
Higher revenues for reimbursable costs and other, net		0.4
Lower average offshore day rates		(0.9	)
Lower average land day rates		(6.0	)
Lower offshore rig utilization		(17.3	)
Net increase	$	7.5

__________________________________

1The Ralph Coffman and EXL#1 commenced operations in January and May 2010, respectively, and contributed 91 and 35 revenue-producing days, respectively, in the second quarter of 2010.

2The land rig added to the fleet in May 2009 contributed 62 incremental revenue-producing days in the second quarter of 2010.

Drilling operating costs for the second quarter of 2010 increased by $2.2 million, or 2%, from the second quarter of 2009 due to the addition of the Ralph Coffman and EXL#1 and incremental Norwegian operating costs for the Gorilla VI. Our operating margin (before depreciation and selling, general and administrative expenses) for the

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second quarter of 2010 increased slightly to 58% from 57% in the second quarter of 2009. Drilling depreciation expense increased by $3.2 million or 8% between periods due primarily to the addition of the Ralph Coffman and EXL#1. Selling, general and administrative expenses increased by $6.1 million or 35% between periods due primarily to a $4.5 million provision during the quarter for the expected cost of terminating the Company’s agency agreement in Mexico and to personnel related costs and professional fees.

The following table presents certain key performance measures by geographic area for our offshore fleet for the second quarters of 2010 and 2009. The number of rigs in each location is based on location for the majority of the period and includes active and idle rigs. Revenues include those received from customers for contract reimbursable costs. Average day rates are computed by dividing revenues recognized during the period, excluding revenues attributable to reimbursable costs, by the number of revenue-producing days. Rig utilization is computed as the number of revenue-producing days divided by total available rig days during the period.

	Three months ended June 30,
	2010			2009

Gulf of Mexico:
Number of rigs		9			9
Revenues	$	80,784,000		$	84,125,000
Average day rate	$	137,200		$	150,400
Utilization		76	%		66	%

Middle East:
Number of rigs		9			9
Revenues	$	67,123,000		$	102,324,000
Average day rate	$	142,700		$	144,700
Utilization		57	%		86	%

North Sea:
Number of rigs		2			2
Revenues	$	48,144,000		$	52,314,000
Average day rate	$	269,300		$	285,400
Utilization		96	%		100	%

Other international:
Number of rigs		4			2
Revenues	$	85,794,000		$	40,622,000
Average day rate	$	229,600		$	314,000
Utilization		100	%		71	%

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Six months ended June 30, 2010, compared to six months ended June 30, 2009

The following table highlights the performance of our Drilling Services segment for the six months ended June 30, 2010 and 2009 (dollars in millions, except for average day rate):

	Six months ended June 30,
	2010						2009
	Amount			% of Revenues			Amount			% of Revenues

Revenues	$	659.3			100	%	$	701.2			100	%
Operating costs		(275.6	)		-42	%		(282.2	)		-40	%
Depreciation expense		(83.4	)		-13	%		(75.5	)		-11	%
Selling, general and administrative expenses		(39.8	)		-6	%		(33.2	)		-5	%
Net gain on property disposals		0.3			0	%		4.7			1	%
Operating income	$	260.8			40	%	$	315.0			45	%

Offshore fleet:
Average day rate	$	178,800					$	175,200
Rig utilization		75	%					85	%
Revenue-producing days		3,145						3,402

Land fleet:
Average day rate	$	20,100					$	24,100
Rig utilization		74	%					67	%
Revenue-producing days		4,309						3,776

Drilling revenues for the six months ended June 30, 2010 decreased by $41.9 million or 6% compared to the comparable period of 2009 as a result of the following (in millions):

	Increase
	(Decrease)

Lower offshore rig utilization	$	(80.4	)
Lower average land day rates		(17.3	)
Lower revenues for reimbursable costs and other, net		(3.8	)
Addition of two land rigs in 20091		4.5
Higher land rig utilization		8.4
Higher average offshore day rates		18.4
Addition of the Ralph Coffman and EXL#12		28.3
Net decrease	$	(41.9	)

__________________________________

1The two land rigs added to the fleet in the first half of 2009 contributed 182 incremental revenue-producing days in the first six months of 2010.

2The Ralph Coffman and EXL#1 commenced operations in January and May 2010, respectively, and contributed 167 and 35 revenue-producing days, respectively, in the first six months of 2010.

Drilling operating costs for the first six months of 2010 decreased by $6.6 million or 2% from the same period of 2009 due to reduced operating costs on four idle rigs in the Middle East and one in the Gulf of Mexico. Lower costs of the stacked rigs were partially offset by the addition of the Ralph Coffman and EXL#1 in January and May 2010, respectively, and incremental Norwegian operating costs for the Gorilla VI. Our operating margin (before depreciation and selling, general and administrative expenses) for the first six months of 2010 declined slightly to 58% from 60% in the same period of 2009. Drilling depreciation expense increa sed by $7.9 million or 10% between periods due primarily to the addition of the Ralph Coffman and EXL#1. Selling, general and administrative expenses increased by $6.6 million or 20% over the comparable prior year period due primarily to a $4.5 million

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provision during the second quarter of 2010 for the expected cost of terminating the Company’s agency agreement in Mexico and to personnel related costs and professional fees.

The following table presents certain key performance measures by geographic area for our offshore fleet for the first six months of 2010 and 2009. The number of rigs in each location is based on location for the majority of the period and includes active and idle rigs. Revenues include those received from customers for contract reimbursable costs. Average day rates are computed by dividing revenues recognized during the period, excluding revenues attributable to reimbursable costs, by the number of revenue-producing days. Rig utilization is computed as the number of revenue-producing days divided by total available rig days during the period.

	Six months ended June 30,
	2010			2009

Gulf of Mexico:
Number of rigs		9			10
Revenues	$	162,079,000		$	208,269,000
Average day rate	$	139,600		$	153,400
Utilization		78	%		77	%

Middle East:
Number of rigs		9			9
Revenues	$	140,130,000		$	222,819,000
Average day rate	$	152,000		$	147,600
Utilization		56	%		92	%

North Sea:
Number of rigs		2			2
Revenues	$	100,341,000		$	102,425,000
Average day rate	$	278,600		$	282,600
Utilization		98	%		99	%

Other international:
Number of rigs		4			1
Revenues	$	167,641,000		$	71,478,000
Average day rate	$	226,800		$	320,400
Utilization		100	%		81	%

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Drilling Products and Systems

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

The following table highlights the performance of our Drilling Products and Systems segment for the second quarters of 2010 and 2009 (dollars in millions):

	Three months ended June 30,
	2010						2009
	Amount			% of Revenues			Amount			% of Revenues

Revenues	$	71.7			100	%	$	106.7			100	%
Operating costs		(76.4	)		-107	%		(107.7	)		-101	%
Depreciation expense		(2.6	)		-4	%		(2.2	)		-2	%
Selling, general and administrative expenses		(8.0	)		-11	%		(3.0	)		-3	%
Net loss on property disposals		0.1			0	%		-			0	%
Operating income (loss)	$	(15.2	)		-21	%	$	(6.2	)		-6	%

Revenues from Drilling Products and Systems decreased by $35.0 million or 33% between periods due to the following (in millions):

	Increase
	(Decrease)

Lower sales of land rigs and rig kits	$	(20.2	)
Lower sales of power system packages and motors		(13.0	)
Lower mud pump sales		(8.9	)
Lower parts sales		(4.6	)
Higher revenues recognized on offshore rig kits in progress		11.1
Other, net		0.6
Net decrease	$	(35.0	)

Revenues from Drilling Products and Systems include revenues recognized upon shipment as well as under the percentage-of-completion method of accounting. Our product revenues are therefore influenced by the timing of shipments and progress on long-term contracts in process, and profitability is highly impacted by the mix of product sales. Original-equipment sales, for example, have traditionally yielded lower margins than the related after-market parts sales.

Our average margin before depreciation and selling, general and administrative expenses declined to a negative 7% of revenues in 2010 from a negative 1% in 2009. The negative gross margins were primarily the result of certain inventory and cost of sales adjustments and significantly higher warranty costs coupled with low overall sales volumes and the increased concentration of lower-margin sales (i.e., land rigs), as compared to higher-margin sales (i.e., parts and offshore rig kits).

Selling, general and administrative costs increased by $5.0 million between periods due primarily to the addition of personnel in the fourth quarter of 2009 and first quarter of 2010 in connection with the quality initiative at the Company’s manufacturing operations and increases to the reserve for uncollectible trade receivables.

Our Drilling Products and Systems operating results for the 2010 second quarter excludes $52.4 million of revenues and $37.2 million of expenses in connection with sales of products and services to our Drilling Services segment, most of which was attributable to construction of the newbuild jack-up, Joe Douglas. Drilling Products and Systems operating results for the comparable quarter of 2009 excludes $35.1 million of revenues and $25.2 million of expenses, primarily for construction of the Ralph Coffman.

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Six months ended June 30, 2010, compared to six months ended June 30, 2009

The following table highlights the performance of our Drilling Products and Systems segment for the first six months of 2010 and 2009 (dollars in millions):

	Six months ended June 30,
	2010						2009
	Amount			% of Revenues			Amount			% of Revenues

Revenues	$	122.0			100	%	$	177.8			100	%
Operating costs		(127.0	)		-104	%		(166.5	)		-94	%
Depreciation expense		(4.7	)		-4	%		(4.4	)		-2	%
Selling, general and administrative expenses		(13.5	)		-11	%		(7.1	)		-4	%
Material charge - manufacturing inventories		(42.0	)		-34	%		-			0	%
Operating income (loss)	$	(65.2	)		-53	%	$	(0.2	)		0	%

Revenues from Drilling Products and Systems decreased by $55.8 million or 31% between periods due to the following (in millions):

	Increase
	(Decrease)

Lower mud pump sales	$	(21.0	)
Lower sales of power system packages and motors		(19.0	)
Lower parts sales		(11.1	)
Lower sales of land rigs and rig kits		(9.3	)
Higher revenues recognized on offshore rig kits in progress		6.5
Other, net		(1.9	)
Net decrease	$	(55.8	)

Our average margin before depreciation, selling, general and administrative expenses and the inventory charge discussed below declined to a negative 4% of revenues in 2010 from a 6% gross profit in 2009. The negative margin in 2010 was primarily the result of certain inventory and cost of sales adjustments and significantly higher warranty costs coupled with lower overall sales volumes.

Selling, general and administrative costs increased by $6.4 million between periods due primarily to the addition of personnel in the fourth quarter of 2009 and first quarter of 2010 in connection with the quality initiative at the Company’s manufacturing operations and increases to the reserve for uncollectible accounts.

During the first quarter of 2010, the Company’s Drilling Products and Systems segment performed an assessment of its Houston-based raw materials and supplies inventory. Management determined that a significant number of items had experienced some level of deterioration such that they were not within tolerance of original specifications or no longer conformed to minimum quality standards. Full provision was made for the cost of items that cannot be efficiently reworked. In addition, as the Company continued to work off existing drilling products backlog during the first quarter of 2010, the quantity and age of slow-moving inventory items was continuing to grow. Management expects this trend will continue for the foreseeable future. As a result, the Company increased its

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inventory valuation reserve by approximately $42.0 million and recorded a corresponding charge to its first quarter 2010 operations.

Our Drilling Products and Systems operating results for the six months ended June 30, 2010 excludes $98.1 million of revenues and $71.3 million of expenses in connection with sales of products and services to our Drilling Services segment, most of which was attributable to construction of the newbuild jack-up, Joe Douglas. Drilling Products and Systems operating results for the comparable period of 2009 excludes $108.6 million of revenues and $78.2 million of expenses, primarily for construction of the Ralph Coffman.

Mining, Forestry and Steel Products

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

The following table highlights the performance of our Mining, Forestry and Steel Products segment for the second quarters of 2010 and 2009 (dollars in millions):

	Three months ended June 30,
	2010						2009
	Amount			% of Revenues			Amount			% of Revenues

Revenues	$	90.1			100	%	$	54.7			100	%
Operating costs		(61.8	)		-69	%		(39.7	)		-73	%
Depreciation expense		(2.0	)		-2	%		(1.6	)		-3	%
Selling, general and administrative expenses		(4.6	)		-5	%		(4.5	)		-8	%
Operating income	$	21.7			24	%	$	8.9			16	%

Revenues from Mining, Forestry and Steel Products increased by $35.4 million or 65% between periods due to the following (in millions):

	Increase
	(Decrease)

Higher sales of mining loaders	$	18.9
Increase in parts sales		7.3
Higher sales of steel plate		6.0
Other, net		3.2
Net increase	$	35.4

Our average margin before depreciation and selling, general and administrative expenses increased to 31% of revenues in 2010 from 27% in 2009. The higher margins were attributable primarily to product sales mix, particularly a greater proportion of larger, higher-margin mining loaders and parts sales in 2010. Selling, general and administrative expenses were relatively flat between periods.

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Six months ended June 30, 2010, compared to six months ended June 30, 2009

The following table highlights the performance of our Mining, Forestry and Steel Products segment for the first six months of 2010 and 2009 (dollars in millions):

	Six months ended June 30,
	2010						2009
	Amount			% of Revenues			Amount			% of Revenues

Revenues	$	141.2			100	%	$	98.0			100	%
Operating costs		(95.7	)		-68	%		(71.7	)		-73	%
Depreciation expense		(3.9	)		-3	%		(3.1	)		-3	%
Selling, general and administrative expenses		(8.6	)		-6	%		(9.2	)		-9	%
Net loss on property disposals		(0.1	)		0	%		-			0	%
Operating income	$	32.9			23	%	$	14.0			14	%

Revenues from Mining, Forestry and Steel Products increased by $43.2 million or 44% between periods due to the following (in millions):

	Increase
	(Decrease)

Higher sales of mining loaders	$	25.5
Increase in parts sales		10.9
Higher sales of steel plate		3.4
Other, net		3.4
Net increase	$	43.2

Our average margin before depreciation and selling, general and administrative expenses increased to 32% of revenues in 2010 from 27% in 2009. The higher margins were attributable primarily to product sales mix, particularly a greater proportion of larger, higher-margin mining loaders and parts sales in 2010. Selling, general and administrative expenses decreased by $0.6 million or 7% between periods due primarily to cost-control efforts.

Outlook

Drilling Operations

Our drilling backlog by geographic area as of July 26, 2010 (the date of our most recent “Rig Fleet and Contract Status” report) and February 16, 2010 (the date reported in our Annual Report on Form 10-K for the year ended December 31, 2009), is set forth below (in millions):

	July 26, 2010		February 16, 2010

North Sea	$	336	$	327
Middle East		207		275
Gulf of Mexico		117		234
Other international		293		240
Subtotal - offshore		953		1,076
Land		198		234
Total drilling backlog	$	1,151	$	1,310

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We estimate our drilling backlog will be realized as follows (in millions):

	Offshore		Land		Total

2010	$	381	$	69	$	450
2011		385		66		451
2012		119		33		152
2013		68		14		82
2014 and later		-		16		16
Total drilling backlog	$	953	$	198	$	1,151

About 66% of our remaining available offshore rig days in 2010 and 29% of available days in 2011 are currently under contract, and most of our drilling contracts have termination penalties.

As of July 26, 2010, seven of our offshore rigs had drilling contracts estimated to complete in 2010, ten had contracts estimated to complete in 2011, one had a contract estimated to complete in 2012, two had contracts estimated to complete in 2013 including one under construction, and five were available. The four rigs under construction are expected to be delivered over the period from the third quarter of 2010 through the first quarter of 2012; three of the four are not yet contracted.

Although utilization of our rigs improved in the first and second quarters of 2010 over the fourth quarter of 2009, leading day rates have yet to show significant improvements and remain well below peak levels, and our results of operations have continued to benefit from long-term contracts with above-market day rates executed prior to the global downturn that began in mid 2008. As noted above, most of these contracts are scheduled to conclude in 2010 or 2011.

The Company currently has nine jack-up drilling rigs located in the U.S. Gulf of Mexico which may be impacted from time to time by the requirements of these recent NTLs. The Rowan Juneau and the Rowan Alaska are currently stacked and are unlikely to receive new contracts until the issuance of permits resumes. The Rowan Louisiana is under contract but is waiting on a permit. The Bob Palmer has been recently released from its contract, and we expect it to return to work in the Gulf on a well-to-well basis.

Permitted activities are expected to take the Rowan Mississippi and the Ralph Coffman through their contracted terms.

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Manufacturing Operations

Our external manufacturing backlog, which consists of executed contracts and customer commitments, was approximately $337 million at June 30, 2010, compared to $413 million at December 31, 2009, and consisted of the following (in millions):

	June 30, 2010

Offshore rig projects	$	162
Mining and Forestry equipment		61
Land rig projects		42
Drilling equipment		33
Drilling parts, power systems and other components		22
Other Mining and Forestry parts, and Steel products		17
Total manufacturing backlog	$	337

We expect that substantially all of our external backlog at June 30, 2010, will be realized as revenue in the following twelve months. We can provide no assurance we will be able to maintain or significantly increase our backlog going forward. We estimate that approximately $15.0 million or 4% of our June 30, 2010, manufacturing backlog is at moderate risk of being significantly delayed or canceled.

We currently have no further plans for rig construction at our Vicksburg shipyard following the delivery of our third 240C-class rig, the Joe Douglas, in 2011. Absent additional orders or sufficient prospects for future work, the activities at the facility would be significantly reduced at that time, in which case we would incur additional costs such as employee severance, among other charges. Closing or significantly reducing activity levels at the facility could result in the incurrence of cash charges ranging from $5 million to $6 million and noncash charges ranging from $7 million to $10 million.

LIQUIDITY AND CAPITAL RESOURCES

Acquisition of Skeie Drilling & Production ASA

On July 1, 2010, we entered into a Share Purchase Agreement (the “Purchase Agreement”) with certain shareholders of Skeie Drilling & Production ASA (“Skeie”) and obtained irrevocable commitments from two other shareholders of Skeie (collectively, the “Sellers”) for the purchase of their shares constituting 48.8% of the outstanding ordinary shares of Skeie. We had previously acquired approximately 1.5% of Skeie’s outstanding ordinary shares in open market purchases for cash. As of July 19, 2010, our obligation to purchase the Sellers’ shares and to tender for the remaining outstanding shares of Skeie became unconditional.

Under the terms of the Purchase Agreement and irrevocable commitments, we will issue 0.00574167 shares of Rowan common stock for each of the 1,037,006,792 ordinary shares of Skeie collectively owned by the Sellers, resulting in the issuance of 5,954,151 shares of the Company’s common stock. We intend to commence a tender offer in August for the remaining 49.7% of outstanding shares of Skeie on the same terms, which would result in the issuance of approximately 6.1 million additional Rowan shares.

As of June 30, 2010, Skeie had approximately $269 million in cash and restricted cash and $530 million of first and second lien debt outstanding, secured by the rigs. We expect the three rigs will require an additional $434 million for completion, net of cash and restricted cash acquired, plus approximately $22 million of capitalized interest. We currently anticipate funding the incremental amount from existing cash and operating cash flows. Assuming a Rowan stock price of $25.00 per share and we obtain 100% of the Skeie shares, our total cost would be

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approximately $1.3 billion, including estimated transaction costs. The actual consideration will depend upon the market prices of Rowan’s common stock at the time of issuance and the number of Skeie shares acquired.

General

A comparison of key balance sheet amounts and ratios as of June 30, 2010, and December 31, 2009, follows (dollars in millions):

	June 30,		December 31,
	2010		2009

Cash and cash equivalents	$	610.9	$	639.7
Current assets	$	1,463.5	$	1,549.8
Current liabilities	$	438.4	$	568.3
Current ratio		3.34		2.73
Current maturities of long-term debt	$	58.6	$	64.9
Long-term debt	$	761.5	$	787.5
Stockholders' equity	$	3,272.8	$	3,110.4
Long-term debt/total capitalization		0.19		0.20

Reflected in the comparison above are the effects of the following sources and uses of cash and cash equivalents during the six months ended June 30, 2010, together with amounts for the comparable period of 2009 (in millions):

	Six months ended June 30,
	2010			2009

Net operating cash flows	$	210.3		$	224.9
Proceeds from equity compensation and debenture plans and other		2.9			3.8
Net proceeds from asset disposals		0.9			5.5
Debt repayments		(32.5	)		(32.5	)
Capital expenditures		(210.3	)		(210.3	)
Total net uses	$	(28.7	)	$	(8.6	)

Our future sources and uses of cash are discussed below. We anticipate that our net cash flows from operations over the next twelve months plus available cash balances will be sufficient to meet our capital expenditures and debt service over the period, including capital expenditures expected to be incurred in connection with completion of the Skeie rigs currently under construction and related debt service.

Operating Cash Flows

Operating cash flows approximated $210.3 million for the first six months of 2010 as compared to $224.9 million for the comparable period of 2009. Our cash flows from operations have benefited and will continue to benefit from long-term drilling contracts entered into when rates were significantly higher than current market rates. Several of our offshore rigs are operating under contracts at above-market rates negotiated in periods of stronger demand. As a result, operating cash flows may be negatively affected in the future as these higher day-rate contracts are completed.

Due to a contract dispute with its Mexico agent, the Company has been unable to submit billings to or make collections from PEMEX for use of the Gorilla IV during 2010 and, as a result, had $30.8 million of accrued or unbilled revenues and related value added taxes included in trade accounts receivable at June 30, 2010. The Company believes all amounts due or accrued under the PEMEX contract will be collected.

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Capital Expenditures

Refer to Note 7 of Notes to Unaudited Condensed Consolidated Financial Statements in this Form 10-Q for a discussion of the status of our newbuild rig projects.

Capital expenditures for the first six months of 2010 included the following:

·	$97.8 million towards construction of the four EXL-class rigs;

·	$56.9 million towards construction of our third 240C-class rig, the Joe Douglas; and

·	$29.6 million for improvements to the existing offshore fleet.

For the remainder of 2010, we expect our capital expenditures to approximate $555 million, including $214 million towards construction of the Skeie rigs (net of an estimated $269 million of cash and restricted cash held by Skeie at June 30, 2010), $142 million towards construction of the three remaining EXL-class rigs under construction, $51 million towards construction of the Joe Douglas, $111 million for existing rigs, and $37 million for equipment spares, drill pipe and other. We expect to fund our capital expenditures from available cash and cash flows from operations. We will periodically review and adjust the capital budget as necessary based upon current and forecasted cash flows and liquidity, anticipated market conditions in our drilling and manufacturing businesses and alternative uses of capital to enhance shareholder value.

Long-Term Debt

As of June 30, 2010, we had $820.1 million of total debt, of which $58.6 million is due over the following twelve months. We were in compliance with each of our debt covenants at June 30, 2010, and we do not expect to encounter difficulty complying in the following twelve-month period. We had no borrowings outstanding under our $155 million revolving credit facility at June 30, 2010, and we believe that funding under the facility continues to be available, if necessary.

In connection with the acquisition of Skeie, we will assume first and second lien debt of Skeie in the amount of approximately $225 million and $305 million, respectively. The first lien debt bears interest at an annual rate of 12.0%, requires $20 million annual principal repayments beginning in May 2013 and matures in 2017. The second lien debt bears interest at 11.25%, though accrual of interest is abated through November 30, 2010, and is due in full at maturity in 2013. The first lien debt is callable at an initial price of 107% beginning May 2011, declining by one point annually thereafter; the second lien debt is callable at 106% in 2010, 104% in 2011 and 102% in 2012. We are evaluating options with respect to refinancing the Skeie debt.

Pension Obligations

Minimum contributions to our defined benefit pension plans are determined based upon actuarial calculations of pension assets and liabilities that involve, among other things, assumptions about long-term asset returns and interest rates. Similar calculations were used to estimate pension costs and obligations as reflected in our condensed consolidated financial statements. As of December 31, 2009, our financial statements reflected an aggregate unfunded pension liability of $195 million, most of which relates to our drilling employees’ plan. We will need to make significant pension contributions over the next several years, and additional funding would be required if asset values decline. During the first six months of 2010, Rowan contributed $42.1 million to its pension plans and expec ts to make additional contributions totaling $15.2 million during the remainder of 2010.

Contingent Liabilities

Refer to Note 8 of Notes to Unaudited Condensed Consolidated Financial Statements in this Form 10-Q for a discussion of the status of significant legal proceedings.

Critical Accounting Policies and Management Estimates

Rowan’s significant accounting policies are outlined in Note 2 of Notes to Consolidated Financial Statements included in our Form 10-K for the year ended December 31, 2009. These policies and management judgments, assumptions and estimates made in their application underlie reported amounts of assets and liabilities at the date of the financial statements and reported amounts of revenues and expenses during the reporting period. We believe

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that our most critical accounting policies and management estimates involve revenue recognition (primarily upfront service fees for equipment moves and modifications and longer-term manufacturing contracts), inventory (primarily valuation allowances for excess, slow moving and obsolete inventories), property and depreciation (particularly capitalizable costs, useful lives and salvage values), carrying values of long-lived assets, pension and other postretirement benefit liabilities and costs (specifically, assumptions used in actuarial calculations) and our reserves for income tax uncertainties.

Changes in judgments, assumptions or policies would produce significantly different amounts from those reported herein. During the six months ended June 30, 2010, there have been no material changes to the judgments, assumptions or policies upon which our critical accounting estimates are based, except for the material charge related to inventory disclosed in Note 10.

Recent Accounting Standards

In October 2009, the FASB issued Accounting Standards Update No. 2009-13, Revenue Recognition (Topic 605), Multiple-Deliverable Revenue Arrangements, a consensus of the FASB Emerging Issues Task Force. ASU No. 2009-13 addresses accounting by vendors who provide multiple products or services to customers at different points

in time or over different time periods. Specifically, ASU No. 2009-13 eliminates the residual method of allocating revenues to each activity and requires that revenue be allocated at inception of the arrangement to all deliverables using a relative selling price method. ASU No. 2009-13 is effective for fiscal years beginning on or after June 15, 2010 and may be applied prospectively for arrangements entered into after the effective date or retrospectively for all periods presented. We do not expect adoption to have a material effect on our financial position, results of operations, or cash flows.

FORWARD-LOOKING STATEMENTS

This report contains “forward-looking statements” as defined by the United States Securities and Exchange Commission (“SEC”), including, without limitation, statements as to the expectations, beliefs and future expected financial performance of the Company that are based on current expectations and are subject to certain risks, trends and uncertainties that could cause actual results to differ materially from those projected by the Company. Among the factors that could cause actual results to differ materially include oil and natural gas prices, the level of offshore expenditures by energy companies, energy demand, general economic conditions including inflation, weather conditions in the Company's principal operating areas and environmental and other laws and regulations. Please see the risk factors and forward-looking statement disclosure contained in our Annual Report on Form 10-K for the year ended December 31, 2009.

Item 3. Quantitative and Qualitative Disclosures About Market Risk

Our outstanding debt at June 30, 2010, consisted of an aggregate principal amount of $823.1 million of fixed-rate notes bearing a weighted-average annual interest rate of 6.3%. We believe that our exposure to risk of earnings loss due to changes in market interest rates is not material.

We have a $155 million revolving credit facility expiring in June 2011. There were no borrowings outstanding under the facility at June 30, 2010. We believe that funding under the credit facility continues to be available, if necessary.

The majority of our transactions are denominated in United States dollars. We have some exposure to currency exchange fluctuations primarily in Brazil and Australia as a result of LeTourneau’s presence in those countries. In order to reduce the impact of exchange rate fluctuations, we generally require customer payments to be in U.S. dollars and limit foreign currency holdings to the extent they are needed to pay liabilities denominated in such currencies.

Fluctuating commodity prices affect our future earnings materially to the extent that they influence demand for our products and services. As a general practice, we do not hold or issue derivative financial instruments and had no derivatives outstanding during the periods covered by this report.

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Item 4. Controls and Procedures

Under the supervision and with the participation of our principal executive officer and principal financial officer, management has evaluated the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934) as of the end of the period covered by this report. Based on that evaluation, our principal executive officer and our principal financial officer have concluded that our disclosure controls and procedures were effective as of June 30, 2010.

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

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

Refer to Note 8 of Notes to Unaudited Condensed Consolidated Financial Statements in this Form 10-Q for the status of significant legal proceedings.

Item 1A. Risk Factors

You should carefully consider the risk factors set forth in Part 1, Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2009, before deciding to invest in Rowan Common Stock. Except as set forth below, there have been no material changes to the risk factors disclosed in our Form 10-K report for the year ended December 31, 2009.

The acquisition of Skeie will result in us incurring substantially more debt. This could further increase our leverage and attendant risks.

In connection with the acquisition of Skeie, we plan to assume approximately $530 million of first and second lien debt secured by the three Skeie rigs under construction, which bears interest well above the average rate on our existing debt. We can provide no assurances that we can refinance this debt on more favorable terms. In addition, we may be able to incur substantial additional indebtedness in the future. The approximately $530 million of Skeie debt and any additional debt we incur will increase our leverage and may adversely affect our financial condition and our ability to access capital markets on favorable terms. An increase in our leverage may also result in us conducting an offering of our equity securities, which would dilute our existing shareholders.

Reduction of our credit ratings could have a material adverse effect on our business and our ability to attract capital investment.

Rowan currently has an investment grade credit rating. Credit rating agencies monitor our financial position, the overall oil and gas industry and the level of demand for drilling services. Our increased leverage from our assumption of Skeie’s debt may result in a reduction of our current credit ratings, which may reduce our access to the debt markets and unfavorably impact our overall cost of borrowing. Downgrades of our current credit ratings or significant worsening of our financial condition could also result in increased demands by our suppliers for accelerated payment terms or other more onerous contract terms.

Our inability to enter into drilling contracts for our idle rigs or rigs under construction will materially adversely affect our results of operations. Three of our four rigs under construction do not yet have drilling contracts.

The results of our operations could be materially adversely affected if we are unable to enter into contracts for our idle rigs or for our three rigs under construction (or six rigs including the three rigs under construction by Skeie).

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If we are unable to acquire or renew permits and approvals required for our operations, we may be forced to suspend or cease our operations, and our revenues from offshore operations may be reduced.

Crude oil and natural gas exploration and production operations in the United States and the Gulf of Mexico require numerous permits and approvals of Rowan and its customers from governmental agencies. If we or our customers are not able to obtain necessary permits and approvals, our operations will be adversely affected. Obtaining all necessary permits and approvals may necessitate substantial expenditures to comply with the requirements of these permits and approvals, future changes to these permits or approvals, or any adverse change in the interpretation of existing permits and approvals. In addition, such regulatory requirements and restrictions could also delay or curtail our operations and could have a significant impact on our financial condition or results of operations and may create a risk of expensive delays or loss of value if a project is unable to function as planned due to changing requirements.

On April 20, 2010, the Deepwater Horizon, a semisubmersible drilling rig owned by a competitor, exploded while working in the deepwater sector of the U.S. Gulf of Mexico, resulting in an oil spill. In response to this incident, the U.S. Secretary of the Interior on May 27, 2010, announced a moratorium on U.S. offshore deepwater drilling, which was enjoined by a U.S. district court on June 22, 2010. On July 12, 2010, the Secretary issued a revised moratorium, which is now the subject of litigation in the U.S. courts. In addition, the Bureau of Ocean Energy Management, Regulation and Enforcement (formerly known as the Minerals Management Service) has issued Notices to Lessees (NTLs) implementing new safety regulations and information requirements ap plicable to drilling operations in the Gulf of Mexico. These NTLs are also the subject of litigation in the U.S. courts. These NTLs adversely impact the ability of our customers to obtain necessary permits and approval on a timely basis and/or to continue operations uninterrupted under existing permits. As a result, both shallow water and deepwater drilling permits have been delayed. Compliance with the new regulatory requirements may result in interruption of operations and reduce revenues from our offshore operations. At July 26, 2010, we had nine rigs located in the U.S. Gulf of Mexico.

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

Issuer Purchases of Equity Securities

The following table presents information with respect to purchases of our common stock for the periods indicated:

Period ended	Total number of shares purchased 1		Average price paid per share		Total number of shares purchased as part of publicly announced plans or programs 2		Maximum number of shares that may yet be purchased under the plans or programs

April 1-30, 2010		20,748	$	30.05		-		1,524,600
May 1-31, 2010		72,878	$	28.53		-		1,524,600
June 1-30, 2010		5,810	$	25.57		-		1,524,600
Total		99,436	$	28.67		-

1 The total number of shares purchased includes (i) shares purchased, if any, pursuant to a publicly announced program described in footnote 2 below and (ii) shares withheld by us to satisfy tax withholding obligations in connection with stock-based compensation issued to employees. All shares acquired during the quarter ended June 30, 2010, were in connection with stock-based compensation.

2 In 1998, we announced that our Board of Directors authorized us to purchase up to eight million shares of our common stock. We last purchased shares under this program in 2002 and have no plans to purchase additional shares at the present time.

At June 30, 2010, we had approximately $586 million of cash available for distribution to stockholders under provisions of our debt agreements. We do not expect to pay dividends in the foreseeable future.

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Item 6. Exhibits

The following is a list of exhibits filed with this Form 10-Q. Each of the following exhibits is filed herewith, unless otherwise indicated below as being incorporated by reference to another filing of the Company:

31.1	Certification of Chief Executive Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2	Certification of Chief Financial Officer Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1	Certification of Chief Executive Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2	Certification of Chief Financial Officer Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS	XBRL Instance Document.
101.SCH	XBRL Taxonomy Extension Schema Document.
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB	XBRL Taxonomy Extension Label Linkbase Document.
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document.

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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.

		ROWAN COMPANIES, INC.
		(Registrant)


Date: August 4, 2010		/s/ W. H. WELLS
		W. H. Wells
		Senior Vice President,
		Chief Financial Officer and Treasurer


Date: August 4, 2010		/s/ GREGORY M. HATFIELD
		Gregory M. Hatfield
		Vice President and Controller
		(Chief Accounting Officer)

Date: August 4, 2010		/s/ W. MATT RALLS
		W. Matt Ralls
		President and Chief Executive Officer

Date: August 4, 2010		/s/ W. MATT RALLS
		W. Matt Ralls
		President and Chief Executive Officer