UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q


þ		QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended: ~~June~~September 30, 2011


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: 000-53604

NOBLE CORPORATION

(Exact name of registrant as specified in its charter)


Switzerland		98-0619597
(State or other jurisdiction of incorporation or organization)		(I.R.S. employer identification number)

Dorfstrasse 19A, Baar, Switzerland 6340
(Address of principal executive offices) (Zip Code)

Registrant’s Telephone Number, Including Area Code:41 (41) 761-65-55

Securities registered pursuant to Section 12(b) of the Act:


Title of each class		Name of each exchange on which registered

Shares, Par Value ~~3.67~~3.54 CHF per Share		New York Stock Exchange

Commission file number: 001-31306

NOBLE CORPORATION

(Exact name of registrant as specified in its charter)


Cayman Islands (State or other jurisdiction of incorporation or organization)		98-0366361 (I.R.S. employer identification number)

Suite 3D, Landmark Square, 64 Earth Close, P.O. Box 31327 George Town, Grand Cayman, Cayman Islands, KY1-1206

(Address of principal executive offices) (Zip Code)

Registrant’s Telephone Number, Including Area Code:(345) 938-0293

Securities registered pursuant to Section 12(b) of the Act:None

Indicate by check mark whether each 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. Yesþ Noo

Indicate by check mark whether each 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 (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yesþ Noo

Indicate by check mark whether each 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):


Noble-Swiss:	Large accelerated filerþ	Accelerated filero	~~Accelerated~~Non-accelerated filero	~~Non-accelerated filer~~o	Smaller reporting companyo
Noble-Cayman:	Large accelerated filero	Accelerated filero	~~Accelerated~~Non-accelerated fileroþ	~~Non-accelerated filer~~þ	Smaller reporting companyo

Indicate by check mark whether each registrant is a shell company (as defined in Rule 12b-2 of the Act). Yeso Noþ

Number of shares outstanding and trading at ~~July 29,~~October 28, 2011: Noble Corporation (Switzerland) — ~~252,390,953~~252,437,480

Number of shares outstanding at ~~July 29,~~October 28, 2011: Noble Corporation (Cayman Islands) — 261,245,693

Noble Corporation, a Cayman Islands company and a wholly owned subsidiary of Noble Corporation, a Swiss corporation, meets the conditions set forth in General Instructions H(1) (a) and (b) toForm 10-Q and is therefore filing thisForm 10-Q with the reduced disclosure format contemplated by paragraphs (b) and (c) of General Instruction H(2) ofForm ~~10-Q~~.10-Q.

TABLE OF CONTENTS


	Page
PART I FINANCIAL INFORMATION

Item 1 Financial Statements

Noble Corporation (Noble-Swiss) Financial Statements:

Consolidated Balance Sheet as of ~~June~~September 30, 2011 and December 31, 2010		3

Consolidated Statement of Income for the three and ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		4

Consolidated Statement of Cash Flows for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		5

Consolidated Statement of Equity for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		6

Consolidated Statement of Comprehensive Income for the three and ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		7

Noble Corporation (Noble-Cayman) Financial Statements:

Consolidated Balance Sheet as of ~~June~~September 30, 2011 and December 31, 2010		8

Consolidated Statement of Income for the three and ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		9

Consolidated Statement of Cash Flows for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		10

Consolidated Statement of Equity for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		11

Consolidated Statement of Comprehensive Income for the three and ~~six~~nine months ended ~~June~~September 30, 2011 and 2010		12

Notes to Combined Consolidated Financial Statements		13

Item 2 Management’s Discussion and Analysis of Financial Condition and Results of Operations		3938

Item 3 Quantitative and Qualitative Disclosures About Market Risk		5657

Item 4 Controls and Procedures		5758

PART II OTHER INFORMATION

Item 1 Legal Proceedings		5859

Item 1A Risk Factors		5859

Item 2 Unregistered Sales of Equity Securities and Use of Proceeds		5960

Item 6 Exhibits		5960

SIGNATURES		6061

Index to Exhibits		6162

Exhibit 3.1
Exhibit 31.1
Exhibit 31.2
Exhibit ~~31.3~~
~~Exhibit~~ 32.1
Exhibit 32.2
~~Exhibit 32.3~~
EX-101 INSTANCE DOCUMENT
EX-101 SCHEMA DOCUMENT
EX-101 CALCULATION LINKBASE DOCUMENT
EX-101 LABELS LINKBASE DOCUMENT
EX-101 PRESENTATION LINKBASE DOCUMENT
EX-101 DEFINITION LINKBASE DOCUMENT

This combined Quarterly Report on Form 10-Q is separately filed by Noble Corporation, a Swiss corporation (“Noble-Swiss”), and Noble Corporation, a Cayman Islands company (“Noble-Cayman”). Information in this filing relating to Noble-Cayman is filed by Noble-Swiss and separately by Noble-Cayman on its own behalf. Noble-Cayman makes no representation as to information relating to Noble-Swiss (except as it may relate to Noble-Cayman) or any other affiliate or subsidiary of Noble-Swiss. Since Noble-Cayman meets the conditions specified in General Instructions H(1)(a) and (b) to Form 10-Q, it is permitted to use the reduced disclosure format for wholly owned subsidiaries of reporting companies. Accordingly, Noble-Cayman has omitted from this report the information called for by Item 3 (Quantitative and Qualitative Disclosures about Market Risk) of Part I of Form 10-Q and the following items of Part II of Form 10-Q: Item 2 (Unregistered Sales of Equity Securities and Use of Proceeds) and Item 3 (Defaults upon Senior Securities).

This report should be read in its entirety as it pertains to each Registrant. Except where indicated, the Consolidated Financial Statements and related Notes are combined. References in this Quarterly Report on Form 10-Q to “Noble,” the “Company,” “we,” “us,” “our” and words of similar meaning refer collectively to Noble-Swiss and its consolidated subsidiaries, including Noble-Cayman.

PART I. FINANCIAL INFORMATION


Item 1.		Financial Statements

NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(In thousands)

(Unaudited)


	June 30,			December 31,			September 30,			December 31,
	2011			2010			2011			2010
ASSETS
Current assets
Cash and cash equivalents	$	230,877		$	337,871		$	197,015		$	337,871
Accounts receivable		510,019			387,414			601,161			387,414
Taxes receivable		80,815			81,066			57,335			81,066
Prepaid expenses		67,311			35,502			61,166			35,502
Other current assets		88,474			69,941			84,767			69,941

Total current assets		977,496			911,794			1,001,444			911,794


Property and equipment, at cost		13,926,052			12,643,866			14,420,267			12,643,866
Accumulated depreciation		(2,863,482	)		(2,595,779	)		(2,999,235	)		(2,595,779	)

Property and equipment, net		11,062,570			10,048,087			11,421,032			10,048,087


Other assets		398,172			342,506			529,057			342,506

Total assets	$	12,438,238		$	11,302,387		$	12,951,533		$	11,302,387


LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt	$	—		$	80,213		$	—		$	80,213
Accounts payable		303,902			374,814			320,053			374,814
Accrued payroll and related costs		114,736			125,663			124,317			125,663
Interest payable		58,328			40,260			22,129			40,260
Taxes payable		69,764			96,448			89,700			96,448
Other current liabilities		79,826			84,049			93,651			84,049

Total current liabilities		626,556			801,447			649,850			801,447


Long-term debt		3,521,770			2,686,484			3,811,866			2,686,484
Deferred income taxes		257,069			258,822			299,625			258,822
Other liabilities		212,475			268,000			218,523			268,000

Total liabilities		4,617,870			4,014,753			4,979,864			4,014,753


Commitments and contingencies

Shareholders’ equity
Shares; 262,668 and 262,415 shares outstanding		857,795			917,684
Treasury shares, at cost; 10,378 and 10,140 shares		(383,344	)		(373,967	)
Shares; 252,718 and 262,415 shares outstanding								796,067			917,684
Treasury shares, at cost; 285 and 10,140 shares								(10,531	)		(373,967	)
Additional paid-in capital		50,499			39,006			49,010			39,006
Retained earnings		6,739,078			6,630,500			6,549,441			6,630,500
Accumulated other comprehensive loss		(42,316	)		(50,220	)		(56,212	)		(50,220	)

Total shareholders’ equity		7,221,712			7,163,003			7,327,775			7,163,003


Noncontrolling interests		598,656			124,631			643,894			124,631

Total equity		7,820,368			7,287,634			7,971,669			7,287,634

Total liabilities and equity	$	12,438,238		$	11,302,387		$	12,951,533		$	11,302,387
												��

See accompanying notes to the unaudited consolidated financial statements.

NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF INCOME

(In thousands, except per share amounts)

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2011			2010			2011			2010			2011			2010			2011			2010
Operating revenues
Contract drilling services	$	589,550		$	687,510		$	1,132,155		$	1,496,156		$	704,892		$	584,919		$	1,837,047		$	2,081,075
Reimbursables		24,122			13,753			46,413			37,986			17,438			19,177			63,851			57,163
Labor contract drilling services		14,012			8,056			27,559			15,817			15,564			7,887			43,123			23,704
Other		313			603			758			814			8			635			766			1,449

		627,997			709,922			1,206,885			1,550,773			737,902			612,618			1,944,787			2,163,391

Operating costs and expenses
Contract drilling services		336,728			275,595			643,091			530,026			358,547			315,844			1,001,638			845,870
Reimbursables		18,723			10,365			35,826			30,108			13,971			14,351			49,797			44,459
Labor contract drilling services		8,750			5,380			17,273			11,268			8,053			5,302			25,326			16,570
Depreciation and amortization		163,119			126,227			321,241			242,084			166,213			143,282			487,454			385,366
Selling, general and administrative		21,632			23,808			45,347			45,779			27,536			25,482			72,883			71,261
Gain on contract extinguishments, net		—			—			(21,202	)		—			—			—			(21,202	)		—

		548,952			441,375			1,041,576			859,265			574,320			504,261			1,615,896			1,363,526


Operating income		79,045			268,547			165,309			691,508			163,582			108,357			328,891			799,865

Other income (expense)
Interest expense, net of amount capitalized		(14,829	)		(510	)		(33,870	)		(975	)		(11,530	)		(4,144	)		(45,400	)		(5,119	)
Interest income and other, net		(534	)		1,006			2,058			4,632			1,117			2,561			3,175			7,193

Income before income taxes		63,682			269,043			133,497			695,165			153,169			106,774			286,666			801,939
Income tax provision		(9,508	)		(51,118	)		(24,867	)		(106,514	)		(17,614	)		(20,287	)		(42,481	)		(126,801	)

Net income		54,174			217,925			108,630			588,651			135,555			86,487			244,185			675,138

Net income attributable to noncontrolling interests		(91	)		—			(52	)		—			(238	)		(467	)		(290	)		(467	)

Net income attributable to Noble Corporation	$	54,083		$	217,925		$	108,578		$	588,651		$	135,317		$	86,020		$	243,895		$	674,671


Net income per share
Basic	$	0.21		$	0.85		$	0.43		$	2.29		$	0.53		$	0.34		$	0.96		$	2.63
Diluted	$	0.21		$	0.85		$	0.43		$	2.28		$	0.53		$	0.34		$	0.96		$	2.62

See accompanying notes to the unaudited consolidated financial ~~statements~~.statements.

NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended						Nine Months Ended
	June 30,						September 30,
	2011			2010			2011			2010
Cash flows from operating activities
Net income	$	108,630		$	588,651		$	244,185		$	675,138
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization		321,241			242,084			487,454			385,366
Gain on contract extinguishments, net		(21,202	)		—			(21,202	)		—
Deferred income taxes		(1,753	)		(11,842	)		(34,549	)		(29,586	)
Share-based compensation expense		16,388			16,285			26,857			26,906
Net change in other assets and liabilities		(177,968	)		179,246			(228,299	)		227,873

Net cash from operating activities		245,336			1,014,424			474,446			1,285,697


Cash flows from investing activities
Capital expenditures		(1,428,783	)		(531,401	)		(1,987,988	)		(886,093	)
Change in accrued capital expenditures		(51,500	)		(17,848	)		(48,782	)		4,213
Refund from contract extinguishments		18,642			—			18,642			—
Acquisition of FDR Holdings, Ltd., net of cash acquired								—			(1,629,644	)

Net cash from investing activities		(1,461,641	)		(549,249	)		(2,018,128	)		(2,511,524	)


Cash flows from financing activities
Borrowings on bank credit facilities		625,000			—
Payments of bank credit facilities		(240,000	)		—
Increase in bank credit facilities, net								675,000			—
Proceeds from issuance of senior notes, net of debt issuance costs		1,087,833			—			1,087,833			1,238,074
Contributions from joint venture partners		436,000			—			481,000			35,000
Payments of joint venture debt		(693,494	)		—			(693,494	)		—
Settlement of interest rate swaps		(29,032	)		—			(29,032	)		(2,041	)
Par value reduction payments		(72,141	)		(23,306	)		(114,453	)		(193,869	)
Financing costs on credit facilities		(2,835	)		—			(2,835	)		—
Proceeds from employee stock transactions		7,357			3,711			9,018			9,703
Repurchases of employee shares surrendered for taxes		(9,377	)		(9,309	)		(10,211	)		(9,961	)
Repurchases of shares		—			(88,652	)		—			(219,330	)

Net cash from financing activities		1,109,311			(117,556	)		1,402,826			857,576

Net change in cash and cash equivalents		(106,994	)		347,619			(140,856	)		(368,251	)
Cash and cash equivalents, beginning of period		337,871			735,493			337,871			735,493

Cash and cash equivalents, end of period	$	230,877		$	1,083,112		$	197,015		$	367,242

See accompanying notes to the unaudited consolidated financial statements.

NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF EQUITY

(In thousands)

(Unaudited)


							Additional								Other																							Accumulated
	Shares						Paid-in			Retained		Treasury			Comprehensive			Noncontrolling		Total									Additional									Other
																							Shares						Paid-in			Retained			Treasury			Comprehensive			Noncontrolling		Total
																							Balance			Par Value			Capital			Earnings			Shares			Loss			Interests		Equity

Balance at December 31, 2009																								261,975		$	1,130,607		$	—		$	5,855,737		$	(143,031	)	$	(54,881	)	$	—	$	6,788,432

Employee related equity activity
Share-based compensation expense																								—			—			26,906			—			—			—			—		26,906
Issuance of share-based compensation shares																								77			335			(335	)		—			—			—			—		—
Contribution to employee benefit plans																								8			30			194			—			—			—			—		224
Exercise of stock options																								447			1,762			7,717			—			—			—			—		9,479
Tax benefit of stock options exercised																								—			—			5,556			—			—			—			—		5,556
Restricted shares forfeited or repurchased for taxes																								(183	)		(804	)		960			1,335			(11,452	)		—			—		(9,961	)
Repurchases of shares																								—			—			—			—			(219,330	)		—			—		(219,330	)
Net income																								—			—			—			674,671			—			—			467		675,138
Par value reduction payments																								—			(184,220	)		(9,648	)		(1	)		—			—			—		(193,869	)
Noncontrolling interests from FDR Holdings, Ltd. acquisition																								—			—			—			—			—			—			124,628		124,628
Other comprehensive income, net																								—			—			—			—			—			(6,113	)		—		(6,113	)

Balance at September 30, 2010																								262,324		$	947,710		$	31,350		$	6,531,742		$	(373,813	)	$	(60,994	)	$	125,095	$	7,201,090
	Balance			Par Value			Capital			Earnings		Shares			Loss			Interests		Equity

Balance at December 31, 2010		262,415		$	917,684		$	39,006		$	6,630,500	$	(373,967	)	$	(50,220	)	$	124,631	$	7,287,634			262,415		$	917,684		$	39,006		$	6,630,500		$	(373,967	)	$	(50,220	)	$	124,631	$	7,287,634

Employee related equity activity
Share-based compensation expense		—			—			16,388			—		—			—			—		16,388			—			—			26,857			—			—			—			—		26,857
Issuance of share-based compensation shares		176			606			(599	)		—		—			—			—		7			248			844			(837	)		—			—			—			—		7
Exercise of stock options		389			1,294			5,782			—		—			—			—		7,076			490			1,629			7,104			—			—			—			—		8,733
Tax benefit of stock options exercised		—			—			274			—		—			—			—		274			—			—			278			—			—			—			—		278

Restricted shares forfeited or repurchased for taxes		(312	)		(1,084	)		1,084			—		(9,377	)		—			—		(9,377	)		(319	)		(1,107	)		1,107			—			(10,211	)		—			—		(10,211	)
Retirement of treasury shares																								(10,116	)		(33,035	)		—			(340,612	)		373,647			—			—		—
Settlement of FIN 48 provision																								—			—			—			15,658			—			—			—		15,658
Net income		—			—			—			108,578		—			—			52		108,630			—			—			—			243,895			—			—			290		244,185
Equity contribution by joint venture partner		—			—			—			—		—			—			473,973		473,973			—			—			—			—			—			—			518,973		518,973
Par value reduction payments ($0.29 per Share)		—			(60,705	)		(11,436	)		—		—			—			—		(72,141	)
Par value reduction payments																								—			(89,948	)		(24,505	)		—			—			—			—		(114,453	)
Other comprehensive income, net		—			—			—			—		—			7,904			—		7,904			—			—			—			—			—			(5,992	)		—		(5,992	)

Balance at June 30, 2011		262,668		$	857,795		$	50,499		$	6,739,078	$	(383,344	)	$	(42,316	)	$	598,656	$	7,820,368
Balance at September 30, 2011																								252,718		$	796,067		$	49,010		$	6,549,441		$	(10,531	)	$	(56,212	)	$	643,894	$	7,971,669

See accompanying notes to the unaudited consolidated financial statements.

NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(In thousands)

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2011			2010			2011			2010			2011			2010			2011			2010

Net income	$	54,174		$	217,925		$	108,630		$	588,651		$	135,555		$	86,487		$	244,185		$	675,138

Other comprehensive income (loss), net of tax
Foreign currency translation adjustments		1,375			(1,980	)		4,382			(6,461	)		(4,929	)		4,198			(547	)		(2,263	)
Gain (loss) on foreign currency forward contracts		2,351			(1,009	)		2,513			(2,934	)		(9,654	)		4,762			(7,141	)		1,828
Loss on interest rate swaps		—			—			(366	)		—			—			(7,586	)		(366	)		(7,586	)
Amortization of deferred pension plan amounts		689			634			1,375			1,273			687			634			2,062			1,908

Other comprehensive income (loss), net		4,415			(2,355	)		7,904			(8,122	)		(13,896	)		2,008			(5,992	)		(6,113	)


Net comprehensive income attributable to noncontrolling interests		(91	)		—			(52	)		—			(238	)		(467	)		(290	)		(467	)


Comprehensive income attributable to Noble Corporation	$	58,498		$	215,570		$	116,482		$	580,529		$	121,421		$	88,028		$	237,903		$	668,558

See accompanying notes to the unaudited consolidated financial ~~statements~~.statements.

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEET

(In thousands)

(Unaudited)


							September 30,			December 31,
	June 30,			December 31,			2011			2010
	2011			2010
ASSETS
Current assets
Cash and cash equivalents	$	224,917		$	333,399		$	192,005		$	333,399
Accounts receivable		509,986			387,414			601,161			387,414
Taxes receivable		80,815			81,066			57,335			81,066
Prepaid expenses		64,677			33,232			57,531			33,232
Other current assets		88,035			69,821			82,690			69,821

Total current assets		968,430			904,932			990,722			904,932


Property and equipment, at cost		13,892,227			12,614,974			14,386,421			12,614,974
Accumulated depreciation		(2,859,227	)		(2,594,954	)		(2,994,486	)		(2,594,954	)

Property and equipment, net		11,033,000			10,020,020			11,391,935			10,020,020


Other assets		398,255			342,592			529,141			342,592

Total assets	$	12,399,685		$	11,267,544		$	12,911,798		$	11,267,544


LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt	$	—		$	80,213		$	—		$	80,213
Accounts payable		303,617			374,559			319,888			374,559
Accrued payroll and related costs		105,386			120,634			112,902			120,634
Interest payable		58,328			40,260			22,129			40,260
Taxes payable		66,764			94,132			86,321			94,132
Other current liabilities		79,277			83,759			93,184			83,759

Total current liabilities		613,372			793,557			634,424			793,557


Long-term debt		3,521,770			2,686,484			3,811,866			2,686,484
Deferred income taxes		257,069			258,822			299,625			258,822
Other liabilities		212,475			268,026			218,523			268,026

Total liabilities		4,604,686			4,006,889			4,964,438			4,006,889


Commitments and contingencies

Shareholder equity
Shareholders’ equity
Ordinary shares; 261,246 shares outstanding		26,125			26,125			26,125			26,125
Capital in excess of par value		426,460			416,232			447,040			416,232
Retained earnings		6,786,074			6,743,887			6,886,513			6,743,887
Accumulated other comprehensive loss		(42,316	)		(50,220	)		(56,212	)		(50,220	)

Total shareholder equity		7,196,343			7,136,024

Total shareholders’ equity								7,303,466			7,136,024

Noncontrolling interests		598,656			124,631			643,894			124,631

Total equity		7,794,999			7,260,655			7,947,360			7,260,655

Total liabilities and equity	$	12,399,685		$	11,267,544		$	12,911,798		$	11,267,544

See accompanying notes to the unaudited consolidated financial statements.

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF INCOME

(In thousands)

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2011			2010			2011			2010			2011			2010			2011			2010
Operating revenues
Contract drilling services	$	589,550		$	687,510		$	1,132,155		$	1,496,156		$	704,892		$	584,919		$	1,837,047		$	2,081,075
Reimbursables		24,122			13,753			46,413			37,986			17,438			19,177			63,851			57,163
Labor contract drilling services		14,012			8,056			27,559			15,817			15,564			7,887			43,123			23,704
Other		313			603			758			814			8			635			766			1,449

		627,997			709,922			1,206,885			1,550,773			737,902			612,618			1,944,787			2,163,391

Operating costs and expenses
Contract drilling services		330,204			271,084			631,036			523,865			349,626			315,787			980,662			839,652
Reimbursables		18,723			10,365			35,826			30,108			13,971			14,351			49,797			44,459
Labor contract drilling services		8,750			5,380			17,273			11,268			8,053			5,302			25,326			16,570
Depreciation and amortization		162,636			126,052			320,291			241,716			165,719			143,059			486,010			384,775
Selling, general and administrative		14,642			15,534			31,173			31,422			17,637			16,715			48,810			48,137
Gain on contract extinguishments, net		—			—			(21,202	)		—			—			—			(21,202	)		—

		534,955			428,415			1,014,397			838,379			555,006			495,214			1,569,403			1,333,593


Operating income		93,042			281,507			192,488			712,394			182,896			117,404			375,384			829,798

Other income (expense)
Interest expense, net of amount capitalized		(14,829	)		(510	)		(33,870	)		(975	)		(11,530	)		(4,147	)		(45,400	)		(5,122	)
Interest income and other, net		(147	)		1,503			2,094			5,110			1,884			1,210			3,978			6,320

Income before income taxes		78,066			282,500			160,712			716,529			173,250			114,467			333,962			830,996
Income tax provision		(9,157	)		(49,543	)		(24,182	)		(104,939	)		(17,298	)		(19,401	)		(41,480	)		(124,340	)

Net income		68,909			232,957			136,530			611,590			155,952			95,066			292,482			706,656

Net income attributable to noncontrolling interests		(91	)		—			(52	)		—			(238	)		(467	)		(290	)		(467	)

Net income attributable to Noble Corporation	$	68,818		$	232,957		$	136,478		$	611,590		$	155,714		$	94,599		$	292,192		$	706,189

See accompanying notes to the unaudited consolidated financial statements.

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF CASH FLOWS

(In thousands)

(Unaudited)


	Six Months Ended						Nine Months Ended
	June 30,						September 30,
	2011			2010			2011			2010
Cash flows from operating activities
Net income	$	136,530		$	611,590		$	292,482		$	706,656
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization		320,291			241,716			486,010			384,775
Gain on contract extinguishments, net		(21,202	)		—			(21,202	)		—
Deferred income taxes		(1,753	)		(11,843	)		(34,549	)		(29,586	)
Capital contribution by parent — share-based compensation		10,228			10,301			15,150			15,519
Net change in other assets and liabilities		(185,049	)		174,670			(235,017	)		203,384

Net cash from operating activities		259,045			1,026,434			502,874			1,280,748


Cash flows from investing activities
Capital expenditures		(1,423,850	)		(531,033	)		(1,983,034	)		(885,623	)
Change in accrued capital expenditures		(51,500	)		(17,848	)		(48,782	)		4,213
Refund from contract extinguishments		18,642			—			18,642			—
Acquisition of FDR Holdings, Ltd., net of cash acquired								—			(1,629,644	)

Net cash from investing activities		(1,456,708	)		(548,881	)		(2,013,174	)		(2,511,054	)


Cash flows from financing activities
Borrowings on bank credit facilities		625,000			—
Payments of bank credit facilities		(240,000	)		—
Increase in bank credit facilities, net								675,000			—
Proceeds from issuance of senior notes, net of debt issuance costs		1,087,833			—			1,087,833			1,238,074
Contributions from joint venture partners		436,000			—			481,000			35,000
Payments of joint venture debt		(693,494	)		—			(693,494	)		—
Settlement of interest rate swaps		(29,032	)		—			(29,032	)		(2,041	)
Financing costs on credit facilities		(2,835	)		—			(2,835	)		—
Distributions to parent company, net		(94,291	)		(128,315	)		(149,566	)		(422,537	)

Net cash from financing activities		1,089,181			(128,315	)		1,368,906			848,496

Net change in cash and cash equivalents		(108,482	)		349,238			(141,394	)		(381,810	)
Cash and cash equivalents, beginning of period		333,399			726,225			333,399			726,225

Cash and cash equivalents, end of period	$	224,917		$	1,075,463		$	192,005		$	344,415

See accompanying notes to the unaudited consolidated financial statements.

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF EQUITY

(In thousands)

(Unaudited)


										Accumulated																	Accumulated
					Capital in					Other												Capital in					Other
	Shares				Excess of		Retained			Comprehensive			Noncontrolling		Total			Shares				Excess of		Retained			Comprehensive			Noncontrolling		Total
																		Balance		Par Value		Par Value		Earnings			Loss			Interests		Equity
Balance at December 31, 2009																			261,246	$	26,125	$	368,374	$	6,609,578		$	(54,881	)	$	—	$	6,949,196
Net income																			—		—		—		706,189			—			467		706,656
Capital contributions by parent — share-based compensation																			—		—		15,519		—			—			—		15,519
Distributions to parent																			—		—		—		(422,537	)		—			—		(422,537	)
Noncontrolling interests from FDR Holdings, Ltd. acquisition																			—		—		—		—			—			124,628		124,628
Other comprehensive income (loss), net																			—		—		—		—			(6,113	)		—		(6,113	)

Balance at September 30, 2010																			261,246	$	26,125	$	383,893	$	6,893,230		$	(60,994	)	$	125,095	$	7,367,349
	Balance		Par Value		Par Value		Earnings			Loss			Interests		Equity

Balance at December 31, 2010		261,246	$	26,125	$	416,232	$	6,743,887		$	(50,220	)	$	124,631	$	7,260,655			261,246	$	26,125	$	416,232	$	6,743,887		$	(50,220	)	$	124,631	$	7,260,655
Net income		—		—		—		136,478			—			52		136,530			—		—		—		292,192			—			290		292,482
Capital contributions by parent — share-based compensation		—		—		10,228		—			—			—		10,228			—		—		15,150		—			—			—		15,150
Distributions to parent		—		—		—		(94,291	)		—			—		(94,291	)		—		—		—		(149,566	)		—			—		(149,566	)
Settlement of FIN 48 provision																			—		—		15,658		—			—			—		15,658
Noncontrolling interest contributions		—		—		—		—			—			473,973		473,973			—		—		—		—			—			518,973		518,973
Other comprehensive income, net		—		—		—		—			7,904			—		7,904
Other comprehensive income (loss), net																			—		—		—		—			(5,992	)		—		(5,992	)

Balance at June 30, 2011		261,246	$	26,125	$	426,460	$	6,786,074		$	(42,316	)	$	598,656	$	7,794,999
Balance at September 30, 2011																			261,246	$	26,125	$	447,040	$	6,886,513		$	(56,212	)	$	643,894	$	7,947,360

See accompanying notes to the unaudited consolidated financial ~~statements~~.statements.

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES

CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME

(In thousands)

(Unaudited)


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2011			2010			2011			2010			2011			2010			2011			2010

Net income	$	68,909		$	232,957		$	136,530		$	611,590		$	155,952		$	95,066		$	292,482		$	706,656

Other comprehensive income (loss), net of tax
Foreign currency translation adjustments		1,375			(1,980	)		4,382			(6,461	)		(4,929	)		4,198			(547	)		(2,263	)
Gain (loss) on foreign currency forward contracts		2,351			(1,009	)		2,513			(2,934	)		(9,654	)		4,762			(7,141	)		1,828
Loss on interest rate swaps		—			—			(366	)		—			—			(7,586	)		(366	)		(7,586	)
Amortization of deferred pension plan amounts		689			634			1,375			1,273			687			634			2,062			1,908

Other comprehensive income (loss), net		4,415			(2,355	)		7,904			(8,122	)		(13,896	)		2,008			(5,992	)		(6,113	)


Net comprehensive income attributable to noncontrolling interests		(91	)		—			(52	)		—			(238	)		(467	)		(290	)		(467	)

Comprehensive income attributable to Noble Corporation	$	73,233		$	230,602		$	144,382		$	603,468		$	141,818		$	96,607		$	286,200		$	700,076

See accompanying notes to the unaudited consolidated financial ~~statements~~.statements.

NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES
NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)

Note 1 — Organization and Basis of Presentation

Noble Corporation, a Swiss corporation, is a leading offshore drilling contractor for the oil and gas industry. At ~~June~~September 30, 2011, our fleet consisted of 7679 mobile offshore drilling units located worldwide as follows: 14 semisubmersibles, 1314 drillships, 4749 jackups and two submersibles. ~~In addition,~~Additionally, we have one floating production storage and offloading unit (“FPSO”). At ~~June~~September 30, 2011, we had ~~11 of our 76~~13 units under construction as follows:

•

~~two~~seven dynamically positioned, ultra-deepwater, harsh environment drillships, including twoGlobetrotter-class drillships

•

~~two dynamically positioned, ultra-deepwater, harsh environment~~ and oneBully-class ~~drillships,~~drillship, and

~~three dynamically positioned, ultra-deepwater harsh environment drillships, and~~

~~four~~six high-specification heavy duty, harsh environment jackup rigs.

~~Subsequent to June 30, 2011, we exercised options for the construction of two additional high-specification heavy duty, harsh environment jackup rigs.~~

Our global fleet is currently located in the following areas: the Middle East, India, the U.S. Gulf of Mexico, Mexico, the Mediterranean, the North Sea, Brazil, West Africa and the Asian Pacific. Noble and its predecessors have been engaged in the contract drilling of oil and gas wells since 1921.

Noble-Cayman is a direct, wholly-owned subsidiary of Noble-Swiss, our publicly-traded parent company. Noble-Swiss’ principal asset is all of the shares of Noble-Cayman. Noble-Cayman has no public equity outstanding. The consolidated financial statements of Noble-Swiss include the accounts of Noble-Cayman, and Noble-Swiss conducts substantially all of its business through Noble-Cayman and its subsidiaries.

The accompanying unaudited consolidated financial statements of Noble-Swiss and Noble-Cayman have been prepared pursuant to the rules and regulations of the U.S. Securities and Exchange Commission (“SEC”) as they pertain to Form 10-Q. Accordingly, certain information and disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) have been condensed or omitted pursuant to such rules and regulations. The unaudited financial statements reflect all adjustments which are, in the opinion of management, necessary for a fair statement of the financial position and results of operations for the interim periods, on a basis consistent with the annual audited consolidated financial statements. All such adjustments are of a normal recurring nature. The December 31, 2010 Consolidated Balance Sheets presented herein are derived from the December 31, 2010 audited consolidated financial statements. These interim financial statements should be read in conjunction with the consolidated financial statements and notes ~~thereto~~ included in our Annual Report on Form 10-K for the year ended December 31, 2010, filed by both Noble-Swiss and Noble-Cayman. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year.

Certain amounts in prior periods have been ~~revised~~reclassified to conform to the current year presentation. Taxes payable in the December 31, 2010 Consolidated Balance Sheets was reported net of approximately $81 million in taxes receivable. During the second quarter ~~ended June 30,~~of 2011, we determined that a right of offset in certain taxable jurisdictions did not exist for these receivables, and they are now being disclosed separately as a current asset. For the December 31, 2010 Consolidated Balance Sheets presented herein, these amounts have been ~~revised~~reclassified to conform to the current year presentation. We believe that this ~~revision~~reclassification is immaterial, as it did not have a material impact on our financial position, working capital, results of operations or cash flows from operations.

~~NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES~~
~~NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES~~
~~NOTES TO CONSOLIDATED FINANCIAL STATEMENTS~~
~~(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)~~

Note 2 — Acquisition of FDR Holdings Limited

On July 28, 2010, Noble-Swiss and Noble AM Merger Co., a Cayman Islands company and indirect wholly-owned subsidiary of Noble-Swiss (“Merger Sub”), completed the acquisition of FDR Holdings Limited, a Cayman Islands company (“Frontier”). Under the terms of the Agreement and Plan of Merger with Frontier and certain of Frontier’s shareholders, Merger Sub merged with and into Frontier, with Frontier surviving as an indirect wholly-owned subsidiary of Noble-Swiss and a wholly-owned subsidiary of Noble-Cayman. The Frontier acquisition was for a purchase price of approximately $1.7 billion in cash plus liabilities assumed and strategically expanded and enhanced our global ~~fleet by adding three dynamically positioned drillships (including two~~~~Bully~~-class joint venture-owned drillships under construction), two conventionally moored drillships, including one that is Arctic-class, a conventionally moored deepwater semisubmersible and one dynamically positioned FPSO.fleet. Frontier’s results of operations were included in our results beginning July 28, 2010. We funded the cash consideration paid at closing of approximately $1.7 billion using proceeds from our July 2010 offering of senior notes and existing cash on hand.

NOBLE CORPORATION (NOBLE-SWISS) AND SUBSIDIARIES
NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(Unless otherwise indicated, dollar amounts in tables are in thousands, except per share data)

The following unaudited pro forma financial information for the three and ~~six~~nine months ended ~~June~~September 30, 2010 gives effect to the Frontier acquisition as if it had occurred at January 1, 2009. The pro forma results are based on historical data and are not intended to be indicative of the results of future operations.


	Three months		Six months		Three months		Nine months
	ended		ended		ended		ended
	June 30, 2010		June 30, 2010		September 30, 2010		September 30, 2010
Total operating revenues	$	784,424	$	1,693,039	$	647,700	$	2,339,889
Net income		191,377		552,601		85,282		616,358
Net income per share	$	0.74	$	2.14	$	0.33	$	2.40

Note 3 — Consolidated Joint Ventures

In connection with the Frontier acquisition, we acquired Frontier’s 50 percent interest in two joint ventures, each with a subsidiary of Royal Dutch Shell, PLC (“Shell”), for the construction and operation of the twoBully-class drillships. Since these entities’ equity at risk is insufficient to permit them to carry on their activities without additional financial support, they each meet the criteria for a variable interest entity. We have determined that we are the primary beneficiary for accounting purposes. Accordingly, we consolidate the entities in our consolidated financial statements after eliminating intercompany transactions. Shell’s equity ~~interest is~~interests are presented as noncontrolling interests on our Consolidated Balance Sheets.

In the first quarter of 2011, the joint venture credit facilities, which had a combined outstanding balance of $693 million, were repaid in full through contributions to the joint ventures from Noble and Shell. Shell contributed $361 million in equity to fund their portion of the repayment of joint venture credit facilities and related interest rate swaps, which were settled concurrent with the repayment and termination of the joint venture credit facilities.

In January 2011, the Bully joint ventures issued notes to the joint venture partners totaling $70 million. The interest rate on these notes was 10%, payable semi-annually in arrears and in kind on June 30 and December 31 commencing in June 2011. The purpose of these notes was to provide additional liquidity to the joint ventures in connection with the shipyard construction of theBullyvessels.

In April 2011, the Bully joint venture partners entered into a subscription agreement, pursuant to which each partner was issued equity in each of the Bully joint ventures in exchange for the cancellation of all outstanding joint venture partner notes. The subscription agreement converted all joint venture partner notes into equity of the respective joint venture. The total capital contributed as a result of these agreements was $146 million, which included $142 million in outstanding notes, plus accrued interest. Our portion of the capital contribution, totaling $73 million, was eliminated in consolidation.

In April 2011, the Bully joint venture partners also entered into capital contribution agreements whereby capital calls up to a total of $360 million can be made for funds needed to complete the projects. As of September 30, 2011, the total capital contributed under these agreements was $170 million. Subsequent to the third quarter, an additional $60 million of capital was contributed under these agreements.

At ~~June~~September 30, 2011, the combined carrying amount of the drillships was ~~$1.1~~$1.3 billion, which was primarily funded through partner equity contributions. The joint venture partners entered into capital contribution agreements in April 2011 whereby capital calls can be made for funds needed to complete the projects. The total funding available to the Bully joint ventures under these agreements at June 30, 2011 was $280 million.

Note 4 — Share Data

Share capital

The following is a detail of Noble-Swiss’ share capital as of ~~June~~September 30, 2011 and December 31, 2010:


	June 30,		December 31,		September 30,		December 31,
	2011		2010		2011		2010

Shares outstanding and trading		252,290		252,275		252,433		252,275
Treasury shares		10,378		10,140		285		10,140

Total shares outstanding		262,668		262,415		252,718		262,415

Treasury shares held for share-based compensation plans		13,598		13,851		13,432		13,851

Total shares authorized for issuance		276,266		276,266		266,150		276,266


Par value per share (in Swiss Francs)		3.67		3.93		3.54		3.93

Shares authorized for issuance by Noble-Swiss at ~~June~~September 30, 2011 totaled ~~276.3~~266.2 million shares and include ~~10.4~~0.3 million shares held in treasury and ~~13.6~~13.4 million treasury shares held by a wholly-owned subsidiary. Repurchased treasury shares are recorded at cost, and include shares repurchased pursuant to our approved share repurchase program discussed below and shares surrendered by employees for taxes payable upon the vesting of restricted stock.

Share repurchases are made pursuant to the share repurchase program that our Board of Directors authorized and adopted. All shares repurchased under our share repurchase program are held in treasury. The number of shares that we may hold in treasury is limited under Swiss law. At September 30, 2011, 6.8 million shares remained available for repurchase under previous authorization by the Board of Directors. No shares have been repurchased under this authorization during the nine months ended September 30, 2011.

During July 2011, after making the required filings with the Swiss Commercial Register, 10.1 million repurchased shares held in treasury were cancelled and the total number of shares authorized for issuance was reduced to 266.2 million shares.

Our Board of Directors may further increase Noble-Swiss’ share capital through the issuance of up to 138.1 million conditionally authorized registered shares without obtaining shareholder approval. The issuance of these conditionally authorized registered shares is subject to certain conditions regarding their use.

~~Treasury shares/share repurchases~~

Share repurchases were made pursuant to the share repurchase program that our Board of Directors authorized and adopted. Subsequent to our 2009 Swiss migration, all shares repurchased under our share repurchase program are held in treasury. At June 30, 2011, 6.8 million shares remained available for repurchase under this authorization. Treasury shares held at June 30, 2011 include 9.9 million shares repurchased under our share repurchase program and 0.5 million shares surrendered by employees for taxes payable upon the vesting of restricted stock or exercise of stock options.

The number of shares that we may hold in treasury is limited under Swiss law. In April 2011, our shareholders approved the cancellation of 10.1 million shares held in treasury. During July 2011, after making the required filings with the Swiss Commercial Register, these 10.1 million treasury shares were cancelled and the total number of shares authorized for issuance was reduced to 266.2 million shares.

Earnings per share

The following table sets forth the computation of basic and diluted earnings per share for Noble-Swiss:


	Three months ended						Six months ended						Three months ended						Nine months ended
	June 30,						June 30,						September 30,						September 30,
	2011			2010			2011			2010			2011			2010			2011			2010
Allocation of net income
Basic
Net income attributable to Noble Corporation	$	54,083		$	217,925		$	108,578		$	588,651		$	135,317		$	86,020		$	243,895		$	674,671
Earnings allocated to unvested share-based payment awards		(572	)		(2,143	)		(1,083	)		(5,652	)		(1,415	)		(828	)		(2,487	)		(6,416	)

Net income to common shareholders — basic	$	53,511		$	215,782		$	107,495		$	582,999		$	133,902		$	85,192		$	241,408		$	668,255


Diluted
Net income attributable to Noble Corporation	$	54,083		$	217,925		$	108,578		$	588,651		$	135,317		$	86,020		$	243,895		$	674,671
Earnings allocated to unvested share-based payment awards		(572	)		(2,137	)		(1,082	)		(5,632	)		(1,412	)		(825	)		(2,481	)		(6,394	)

Net income to common shareholders — diluted	$	53,511		$	215,788		$	107,496		$	583,019		$	133,905		$	85,195		$	241,414		$	668,277


Weighted average shares outstanding — basic		251,368			254,224			251,198			254,671			251,580			252,513			251,327			253,944
Incremental shares issuable from assumed exercise of stock options		700			800			737			949			449			671			640			855

Weighted average shares outstanding — diluted		252,068			255,024			251,935			255,620			252,029			253,184			251,967			254,799


Weighted average unvested share-based payment awards		2,688			2,480			2,554			2,431			2,658			2,453			2,589			2,438


Earnings per share
Basic	$	0.21		$	0.85		$	0.43		$	2.29		$	0.53		$	0.34		$	0.96		$	2.63
Diluted	$	0.21		$	0.85		$	0.43		$	2.28		$	0.53		$	0.34		$	0.96		$	2.62

Only those items having a dilutive impact on our basic earnings per share are included in diluted earnings per share. At ~~June~~September 30, 2011, stock options totaling approximately ~~0.7~~1.1 million were excluded from the diluted earnings per share as they were not dilutive as compared to 0.8 million at ~~June~~September 30, 2010.

Note 5 — Property and Equipment

Property and equipment, at cost, as of ~~June~~September 30, 2011 and December 31, 2010 consisted of the following:


	2011		2010		2011		2010
Drilling equipment and facilities	$	9,824,335	$	8,900,266	$	9,908,049	$	8,900,266
Construction in progress		3,918,618		3,571,017		4,318,705		3,571,017
Other		183,099		172,583		193,513		172,583

	$	13,926,052	$	12,643,866	$	14,420,267	$	12,643,866

Capital expenditures, including capitalized interest, totaled ~~$1.4~~$2.0 billion and ~~$531~~$886 million for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010, respectively. Capital expenditures for 2010 do not include the fair value of assets acquired as part of the Frontier acquisition. Capital expenditures for 2011 consisted of the following:

$~~972 million~~1.3 billion for newbuild construction;

$~~293~~463 million for major projects, including ~~$82~~$130 million to upgrade two drillships currently operating in Brazil;

~~$108 million for other capitalized expenditures including major maintenance and regulatory expenditures which generally have useful lives ranging from 3 to 5 years; and~~

~~$56 million in capitalized interest.~~

Interest is capitalized on construction-in-progress at the weighted average cost of debt outstanding during the period of construction. Capitalized interest was $29 million and $56 million for the three and six months ended June 30, 2011, respectively, as compared to $13 million and $26 million for the three and six months ended June 30, 2010, respectively.

$156 million for other capitalized expenditures, including major maintenance and regulatory expenditures which generally have useful lives ranging from 3 to 5 years; and

$88 million in capitalized interest.

Interest is capitalized on construction-in-progress at the weighted average cost of debt outstanding during the period of construction. Capitalized interest was $32 million and $88 million for the three and nine months ended September 30, 2011, respectively, as compared to $25 million and $51 million for the three and nine months ended September 30, 2010, respectively.

Note 6 — Gain on contract extinguishments, net

In January 2011, we announced the signing of a Memorandum of Understanding (“MOU”) with Petroleo Brasileiro S.A. (“Petrobras”) regarding operations in Brazil. Under the terms of the MOU, we agreed to substitute theNoble Phoenix, then under contract with Shell in Southeast Asia, for theNoble Muravlenko. In January 2011, Shell agreed to release theNoble Phoenixfrom its contract, which was effective in March 2011. ~~The~~~~Noble Phoenix~~~~is undergoing limited contract preparations, after which the unit will mobilize to Brazil.~~ During the second quarter of 2011, Petrobras formally approved the rig substitution. We expect that acceptance of theNoble Phoenixwill take place in the ~~fourth~~first quarter of ~~2011.~~2012. In connection with the cancelation of the contract with Shell on theNoble Phoenix, we recognized a non-cash gain of approximately $52.5 million during the first quarter of 2011, which represented the unamortized fair value of the in-place contract assumed in connection with the Frontier acquisition.

Also in January 2011, as a result of the substitution discussed above, we reached a decision not to proceed with the previously announced reliability upgrade to theNoble Muravlenkothat was scheduled to take place in 2013. As a result, we incurred a non-cash charge of approximately $32.6 million related to the termination of outstanding shipyard contracts.

In February 2011, the outstanding balances of the Bully joint venture credit facilities, which totaled $693 million, were repaid in full and the credit facilities terminated using a portion of the proceeds from our February 2011 debt offering and equity contributions from our joint venture partner. In addition, the related interest rate swaps were settled and terminated concurrent with the repayment and termination of the credit facilities. As a result of these transactions, we recognized a gain of approximately $1.3 million during the first quarter of 2011.

Note 7 — Receivables from Customers

As noted in Note 13, in May 2010 Anadarko Petroleum Corporation (“Anadarko”) sent a letter asserting that the initial attempted deepwater drilling moratorium in the U.S. Gulf of Mexico was an event of force majeure under the drilling contract for theNoble Amos Runner. In June 2010, Anadarko filed a declaratory judgment action in Federal District Court in Houston, Texas seeking to have the court declare that a force majeure condition had occurred and that the drilling contract was terminated by virtue of the initial proclaimed moratorium. We disagree that a force majeure event occurred and that Anadarko had the right to terminate the contract. In August 2010, we filed a counterclaim seeking damages from Anadarko for breach of contract. Anadarko has also attempted to offset revenue that we had billed for services performed prior to their termination of the contract. At September 30, 2011, we had accounts receivable of approximately $13 million related to this attempted offset. We do not believe Anadarko has a basis to offset these invoiced amounts. While we will continue to litigate the matter to full resolution, we can make no assurances as to the outcome of this dispute.

In June 2010, a subsidiary of Frontier entered into a charter contract with a subsidiary of BP PLC (“BP”) for theSeilleanwith a term of a minimum of 100 days. The unit went on hire on July 23, 2010. In October 2010, BP initiated an arbitration proceeding against us claiming the contract wasvoid ab initio, or never existed, due to a fundamental breach and has made other claims and is demanding that we reimburse the amounts already paid to us under the charter. We believe BP owes us the amounts due under the charter. The charter ~~has~~contains a “hell or high water” provision requiring payment, and we believe we have satisfied our obligations under the charter. Outstanding receivables related to this charter totaled $35 million as of ~~June~~September 30, 2011. We believe that if BP were to be successful in claiming the contractvoid ab initio,we would have an indemnity claim against the former shareholders of ~~Frontier, and we~~Frontier. We have put ~~them~~the former owners of Frontier on notice ~~to that effect.~~of this potential claim. We can make no assurances as to the outcome of this dispute.

At ~~June~~September 30, 2011, we had accounts receivable of approximately $14 million related to theNoble Max Smithwhich are being disputed by our customer, Pemex Exploracion y Produccion (“Pemex”). The disputed amount relates to lost revenues due from Pemex for downtime that occurred when our rig was damaged after one of Pemex’s supply boats collided with our rig. WeWhile we believe ~~that~~ we are entitled to ~~these revenues and continue~~the disputed amounts, we can make no assurances as to ~~pursue resolution to~~the outcome of this ~~issue.~~

Note 8 — Debt

Total debt consisted of the following at ~~June~~September 30, 2011 and December 31, 2010:


	June 30,		December 31,			September 30,		December 31,
	2011		2010			2011		2010
Wholly-owned debt instruments:
5.875% Senior Notes due 2013	$	299,929	$	299,911		$	299,939	$	299,911
7.375% Senior Notes due 2014		249,574		249,506			249,610		249,506
3.45% Senior Notes due 2015		350,000		350,000			350,000		350,000
3.05% Senior Notes due 2016		299,931		—			299,934		—
7.50% Senior Notes due 2019		201,695		201,695			201,695		201,695
4.90% Senior Notes due 2020		498,726		498,672			498,754		498,672
4.625% Senior Notes due 2021		399,458		—			399,469		—
6.20% Senior Notes due 2040		399,889		399,889			399,890		399,889
6.05% Senior Notes due 2041		397,568		—			397,575		—
Credit facilities		425,000		40,000			715,000		40,000

Consolidated joint venture debt instruments:
Joint venture credit facilities	$	—	$	691,052		$	—	$	691,052
Joint venture partner notes		—		35,972			—		35,972

Total Debt		3,521,770		2,766,697			3,811,866		2,766,697

Less: Current Maturities		—		(80,213	)		—		(80,213	)

Long-term Debt	$	3,521,770	$	2,686,484		$	3,811,866	$	2,686,484

We have two separate revolving credit facilities in place which provide us with a total borrowing capacity of $1.2 billion. One credit facility, which has a capacity of $600 million, matures in 2013, and during the first quarter of 2011, we entered into an additional $600 million revolving credit facility which matures in 2015 (together referred to as the “Credit Facilities”). The covenants and events of default under the Credit Facilities are substantially similar, and each facility contains a covenant that limits our ratio of debt to total tangible capitalization, as defined in the Credit Facilities, to 0.60. We were in compliance with all covenants as of ~~June~~September 30, 2011.

In February 2011, we issued through our indirect wholly-owned subsidiary, Noble Holding International Limited (“NHIL”), $1.1 billion aggregate principal amount of senior notes in three separate tranches, comprising $300 million of 3.05% Senior Notes due 2016, $400 million of 4.625% Senior Notes due 2021, and $400 million of 6.05% Senior Notes due 2041. A portion of the net proceeds of approximately $1.09 billion, after expenses, was used to repay the outstanding balance on our revolving credit facility and to repay our portion of outstanding debt under the joint venture credit facilities discussed below.

In January 2011, the Bully joint ventures issued notes to the joint venture partners totaling $70 million. The interest rate on these notes was 10%, payable semi-annually in arrears, and in kind, on June 30 and December 31 commencing in June 2011. The purpose of these notes was to provide additional liquidity to the joint ventures in connection with the shipyard construction of theBullyvessels.

In April 2011, the Bully joint venture partners entered into a subscription agreement, pursuant to which each partner was issued equity in each of the Bully joint ventures in exchange for the cancellation of all outstanding joint venture partner notes. The subscription agreement has the effect of converting all joint venture partner notes into equity of the respective joint venture. The total capital contributed as a result of these agreements was $146 million, which included $142 million in outstanding notes, plus accrued interest. Our portion of the capital contribution, totaling $73 million, was eliminated in consolidation.

Fair Value of Debt

Fair value represents the amount at which an instrument could be exchanged in a current transaction between willing parties. The estimated fair value of our senior notes was based on the quoted market prices for similar issues or on the current rates offered to us for debt of similar remaining maturities. The following table presents the estimated fair value of our long-term debt as of ~~June~~September 30, 2011 and December 31, 2010.


	June 30, 2011				December 31, 2010				September 30, 2011				December 31, 2010
	Carrying		Estimated		Carrying		Estimated		Carrying		Estimated		Carrying		Estimated
	Value		Fair Value		Value		Fair Value		Value		Fair Value		Value		Fair Value
Wholly-owned debt instruments
5.875% Senior Notes due 2013	$	299,929	$	324,745	$	299,911	$	324,281	$	299,939	$	323,731	$	299,911	$	324,281
7.375% Senior Notes due 2014		249,574		285,298		249,506		282,078		249,610		283,353		249,506		282,078
3.45% Senior Notes due 2015		350,000		362,312		350,000		357,292		350,000		365,503		350,000		357,292
3.05% Senior Notes due 2016		299,931		302,553		—		—		299,934		305,919		—		—
7.50% Senior Notes due 2019		201,695		245,187		201,695		242,464		201,695		250,238		201,695		242,464
4.90% Senior Notes due 2020		498,726		517,933		498,672		516,192		498,754		537,513		498,672		516,192
4.625% Senior Notes due 2021		399,458		405,760		—		—		399,469		420,987		—		—
6.20% Senior Notes due 2040		399,889		421,767		399,889		423,345		399,890		456,403		399,889		423,345
6.05% Senior Notes due 2041		397,568		411,041		—		—		397,575		447,951		—		—
Credit facilities		425,000		425,000		40,000		40,000		715,000		715,000		40,000		40,000
Consolidated joint venture debt instruments
Joint venture credit facilities		—		—		691,052		691,052		—		—		691,052		691,052
Joint venture partner notes		—		—		35,972		35,972		—		—		35,972		35,972

Note 9 — Income Taxes

At December 31, 2010, the reserves for uncertain tax positions totaled $145 million (net of related tax benefits of $8 million). At ~~June~~September 30, 2011, the reserves for uncertain tax positions totaled ~~$141~~$122 million (net of related tax benefits of $9$8 million). If the ~~June~~September 30, 2011 reserves are not realized, the provision for income taxes would be reduced by ~~$124 million and equity would be directly increased by $17~~$122 million.

It is possible that our existing liabilities related to our reserve for uncertain tax position amounts may increase or decrease in the next twelve months primarily from the completion of open audits or the expiration of statutes of limitation. However, we cannot reasonably estimate a range of changes in our existing liabilities for various uncertainties, such as the unresolved nature of various audits.

Note 10 — Employee Benefit Plans

Pension costs include the following components:


	Three Months Ended June 30,
	2011						2010						Three Months Ended September 30,
	Non-U.S.			U.S.			Non-U.S.			U.S.			2011						2010
													Non-U.S.			U.S.			Non-U.S.			U.S.
Service cost	$	1,153		$	2,152		$	1,050		$	1,912		$	1,141		$	2,152		$	1,045		$	1,912
Interest cost		1,440			2,143			1,204			1,957			1,433			2,143			1,224			1,957
Return on plan assets		(1,454	)		(2,768	)		(1,302	)		(2,392	)		(1,449	)		(2,768	)		(1,331	)		(2,392	)
Amortization of prior service cost		—			57			—			57			—			57			—			57
Amortization of transition obligation		19			—			18			—			19			—			17			—
Recognized net actuarial loss		123			843			175			705			123			844			181			705

Net pension expense	$	1,281		$	2,427		$	1,145		$	2,239		$	1,267		$	2,428		$	1,136		$	2,239


	Six Months Ended June 30,
	2011						2010						Nine Months Ended September 30,
	Non-U.S.			U.S.			Non-U.S.			U.S.			2011						2010
													Non-U.S.			U.S.			Non-U.S.			U.S.
Service cost	$	2,246		$	4,304		$	2,166		$	3,824		$	3,387		$	6,456		$	3,211		$	5,736
Interest cost		2,823			4,286			2,470			3,914			4,256			6,428			3,694			5,871
Return on plan assets		(2,857	)		(5,536	)		(2,668	)		(4,784	)		(4,306	)		(8,304	)		(3,999	)		(7,176	)
Amortization of prior service cost		—			113			—			114			—			170			—			171
Amortization of transition obligation		37			—			36			—			56			—			53			—
Recognized net actuarial loss		243			1,687			356			1,410			366			2,531			537			2,115

Net pension expense	$	2,492		$	4,854		$	2,360		$	4,478		$	3,759		$	7,281		$	3,496		$	6,717

During the ~~three and six~~nine months ended ~~June~~September 30, 2011 and 2010, we made contributions to our pension plans totaling $2$7 million and $3$15 million, respectively. We expect the funding to our non-U.S. and U.S. plans in 2011, subject to applicable law, to be approximately ~~$10~~$11 million.

We sponsor the Noble Drilling Corporation 401(k) Savings Restoration Plan (“Restoration Plan”). The Restoration Plan is a nonqualified, unfunded employee benefit plan under which certain highly compensated employees may elect to defer compensation in excess of amounts deferrable under our 401(k) savings plan. The Restoration Plan has no assets, and amounts withheld for the Restoration Plan are kept by us for general corporate purposes. The investments selected by employees and the associated returns are tracked on a phantom basis. Accordingly, we have a liability to employees for amounts originally withheld plus phantom investment income or less phantom investment losses. We are at risk for phantom investment income and, conversely, we benefit should phantom investment losses occur. At ~~both June~~September 30, 2011 and December 31, 2010, our liability under the Restoration Plan totaled $5 million and $7 ~~million.~~million, respectively. We have purchased investments that closely correlate to the investment elections made by participants in the Restoration Plan in order to mitigate the impact of the phantom investment income and losses on our financial statements. The value of these investments held for our benefit totaled $4 million and $7 million at ~~both June~~September 30, 2011 and December 31, ~~2010.~~2010, respectively.

Note 11 — Derivative Instruments and Hedging Activities

We periodically enter into derivative instruments to manage our exposure to fluctuations in interest rates and foreign currency exchange rates. We have documented policies and procedures to monitor and control the use of derivative instruments. We do not engage in derivative transactions for speculative or trading purposes, nor ~~were~~are we a party to leveraged derivatives. During the period, we maintained certain foreign ~~exchange~~currency forward contracts that did not qualify under the Financial Accounting Standards Board (“FASB”) standards for hedge accounting treatment and therefore, changes in fair values were recognized as either income or loss in our consolidated income statement.

For foreign currency forward contracts, hedge effectiveness is evaluated at inception based on the matching of critical terms between derivative contracts and the hedged item. For interest rate swaps, we evaluate all material terms between the swap and the underlying debt obligation, known in FASB standards as the “long-haul method.” Any change in fair value resulting from ineffectiveness is recognized immediately in earnings.

Cash Flow Hedges

Our North Sea and Brazil operations have a significant amount of their cash operating expenses payable in local currencies. To limit the potential risk of currency fluctuations, we typically maintain short-term forward contracts settling monthly in their respective local currencies. The forward contract settlements in the remainder of 2011 represent approximately 5243 percent of these forecasted local currency requirements. The notional amount of the forward contracts outstanding, expressed in U.S. Dollars, was approximately ~~$113~~$71 million at ~~June~~September 30, 2011. Total unrealized ~~gains~~losses related to these forward contracts were $4$6 million as of ~~June~~September 30, 2011 and were recorded as part of “Accumulated other comprehensive loss” (“AOCL”).

Our two joint ventures had maintained interest rate swaps which were classified as cash flow hedges. The purpose of these hedges was to satisfy bank covenants of the then outstanding credit facilities and to limit exposure to changes in interest rates. In February 2011, the outstanding balances of the joint venture credit facilities and the related interest rate swaps were settled and terminated. As a result of these transactions we recognized a gain of $1 million during the ~~six~~nine months ended ~~June~~September 30, 2011.

The balance of the net unrealized gain/(loss) related to our cash flow hedges included in AOCL and related activity is as follows:


	Three Months Ended						Six Months Ended						Three Months Ended						Nine Months Ended
	June 30,						June 30,						September 30,						September 30,
	2011			2010			2011			2010			2011			2010			2011			2010

Net unrealized gain at beginning of period	$	1,766		$	(1,508	)	$	1,970		$	417
Net unrealized gain/(loss) at beginning of period													$	4,117		$	(2,517	)	$	1,970		$	417
Activity during period:
Settlement of foreign currency forward contracts during the period		(801	)		617			(1,382	)		(356	)		(2,054	)		1,395			(1,604	)		(417	)
Settlement of interest rate swaps during the period		—			—			(366	)		—			—			—			(366	)		—
Net unrealized gain/(loss) on outstanding foreign currency forward contracts		3,152			(1,626	)		3,895			(2,578	)		(7,600	)		3,367			(5,537	)		2,245
Net unrealized gain/(loss) on outstanding interest rate swaps														—			(7,586	)		—			(7,586	)

Net unrealized gain/(loss) at end of period	$	4,117		$	(2,517	)	$	4,117		$	(2,517	)	$	(5,537	)	$	(5,341	)	$	(5,537	)	$	(5,341	)

Fair Value Hedges

We ~~have~~ entered into a firm commitment for the construction of theNoble Globetrotter Idrillship. The drillship ~~is being~~was constructed in two phases, with the second phase being installation and commissioning of the topside equipment. The contract for this second phase of construction iswas denominated in Euros, and in order to mitigate the risk of fluctuations in foreign currency exchange rates, we entered into forward contracts to purchase Euros. As of ~~June~~September 30, 2011, all amounts related to the ~~aggregate notional amount of~~forward contracts have settled. We accounted for the ~~remaining outstanding~~ forward ~~contract was 10 million Euros. This forward contract settles in connection with a required payment under the construction contract. We are accounting for this forward contract~~contracts as a fair value ~~hedge. The~~hedges, and their fair market value ~~of this derivative instrument is~~was included in “Other current assets/liabilities” in the Consolidated Balance Sheets. Gains and losses from this fair value hedge would be recognized in earnings currently, along with the change in fair value of the hedged item attributable to the risk being hedged, if any portion was found to be ineffective. The fair market value of this outstanding forward contract totaled approximately $51,000 at June 30, 2011 and $3 million at December 31, 2010. No gain or loss was recognized in the income statement for the three and ~~six~~nine months ended ~~June~~September 30, 2011 or ~~2010, respectively.~~2010.

Foreign ~~Exchange~~Currency Forward Contracts

One of our joint ventures maintained foreign ~~exchange~~currency forward contracts to help mitigate the risk of currency fluctuation of the Singapore Dollar for the construction of theNoble Bully II drillship.These contracts were not designated for hedge accounting treatment under FASB standards, and therefore, changes in fair values were recognized as either income or loss in our Consolidated Income Statement. These contracts are referred to as non-designated derivatives in the tables to follow, and all were settled during the first quarter of 2011. For the ~~six~~nine months ended ~~June~~September 30, 2011, we recognized a loss of $0.5 million related to these foreign ~~exchange~~currency forward contracts.

Financial Statement Presentation

The following tables, together with Note 12, summarize the financial statement presentation and fair value of our derivative positions as of ~~June~~September 30, 2011 and December 31, 2010:


		Estimated fair value					Estimated fair value
	Balance sheet	June 30,		December 31,		Balance sheet	September 30,			December 31,
	classification	2011		2010		classification	2011			2010
Asset derivatives
Cash flow hedges
Short-term foreign currency forward contracts	Other current assets	$	4,260	$	2,015	Other current assets	$	—		$	2,015
Fair value hedges
Short-term foreign currency forward contracts	Other current liabilities		51		—	Other current liabilities		—			—
Non-designated derivatives
Short-term foreign currency forward contracts	Other current assets		—		2,603	Other current assets		—			2,603

Liability derivatives
Cash flow hedges
Short-term foreign currency forward contracts	Other current liabilities	$	143	$	412	Other current liabilities	$	(5,537	)	$	412
Short-term interest rate swaps	Other current liabilities		—		15,697	Other current liabilities		—			15,697
Long-term interest rate swaps	Other liabilities		—		10,893	Other liabilities		—			10,893
Fair value hedges
Short-term foreign currency forward contracts	Other current liabilities		—		3,306	Other current liabilities		—			3,306

To supplement the fair value disclosures in Note 12, the following summarizes the recognized gains and losses of cash flow hedges and non-designated derivatives through AOCL or through “other income” for the three months ended ~~June~~September 30, 2011 and 2010:

Gain/(loss) reclassified
Gain/(loss) recognized from AOCL to “other Gain/(loss) recognized
through AOCL income” through “other income”
2011 2010 2011 2010 2011 2010
Cash flow hedges

Foreign currency forward contracts $ 3,152 $ (1,626 ) $ 801 $ (617 ) $ — $ —

~~During the six months ended June 30, 2011, in connection with the settlement of our interest rate swaps, $1 million was reclassified from AOCL to gain on contract extinguishments.~~


							Gain/(loss) reclassified
	Gain/(loss) recognized						from AOCL to “other				Gain/(loss) recognized
	through AOCL						income”				through “other income”
	2011			2010			2011		2010		2011		2010
Cash flow hedges
Foreign currency forward contracts	$	(7,600	)	$	4,762		$	2,054	$	—	$	—	$	—
Interest rate swaps		—			(7,586	)		—		—		—		(261	)
Non-designated derivatives
Foreign currency forward contracts	$	—		$	—		$	—	$	—	$	—	$	1,234

The following summarizes the recognized gains and losses of cash flow hedges and non-designated derivatives through AOCL or through “other income” for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010:


							Gain/(loss) reclassified
	Gain/(loss) recognized						from AOCL to “other						Gain/(loss) recognized												Gain/(loss) reclassified
	through AOCL						income”						through “other income”						Gain/(loss) recognized						from AOCL to “other				Gain/(loss) recognized
	2011			2010			2011			2010			2011			2010			through AOCL						income”				through “other income”
			2011			2010			2011			2010			2011			2010
Cash flow hedges
Foreign currency forward contracts	$	3,895		$	(2,578	)	$	1,382		$	356		$	—		$	—		$	(5,537	)	$	1,828		$	1,604	$	—	$	—		$	—
Interest rate swaps																				—			(7,586	)		366		—		—			(261	)
Non-designated derivatives
Foreign currency forward contracts		—			—			—			—			(546	)		—		$	—		$	—		$	—	$	—	$	(546	)	$	1,234

During the nine months ended September 30, 2011, in connection with the settlement of our interest rate swaps, $1 million was reclassified from AOCL to gain on contract extinguishments.

For cash flow presentation purposes, cash outflows of $29 million were recognized in the financing activities section related to the settlement of interest rate swaps. All other amounts were recognized as changes in operating activities.

Note 12 — Fair Value of Financial Instruments

The following table presents the carrying amount and estimated fair value of our financial instruments recognized at fair value on a recurring basis:


	June 30, 2011								December 31, 2010				September 30, 2011										December 31, 2010
			Estimated Fair Value Measurements													Estimated Fair Value Measurements
			Quoted		Significant											Quoted		Significant
			Prices in		Other		Significant									Prices in		Other			Significant
			Active		Observable		Unobservable									Active		Observable			Unobservable
	Carrying		Markets		Inputs		Inputs		Carrying		Estimated		Carrying			Markets		Inputs			Inputs		Carrying		Estimated
	Amount		(Level 1)		(Level 2)		(Level 3)		Amount		Fair Value		Amount			(Level 1)		(Level 2)			(Level 3)		Amount		Fair Value
Assets -
Assets —
Marketable securities	$	7,178	$	7,178	$	—	$	—	$	6,854	$	6,854	$	4,294		$	4,294	$	—		$	—	$	6,854	$	6,854
Foreign currency forward contracts		4,311		—		4,311		—		4,618		4,618		—			—		—			—		4,618		4,618
Firm commitment		—		—		—		—		3,306		3,306		—			—		—			—		3,306		3,306

Liabilities -
Liabilities —
Interest rate swaps	$	—	$	—	$	—	$	—	$	26,590	$	26,590	$	—		$	—	$	—		$	—	$	26,590	$	26,590
Foreign currency forward contracts		143		—		143		—		3,718		3,718		(5,537	)		—		(5,537	)		—		3,718		3,718
Firm commitment		51		—		51		—		—		—

The derivative instruments have been valued using actively quoted prices and quotes obtained from the counterparties to the derivative instruments. Our cash and cash equivalents, accounts receivable and accounts payable are by their nature short-term. As a result, the carrying values included in the accompanying Consolidated Balance Sheets approximate fair value.

Note 13 — Commitments and Contingencies

InAs noted in Note 7, in May 2010 Anadarko ~~Petroleum Corporation (“Anadarko”)~~ sent a letter asserting that the initial attempted deepwater drilling moratorium in the U.S. Gulf of Mexico ~~issued on May 28, 2010 by U.S. Secretary of the Interior Ken Salazar,~~ was an event of force majeure under the drilling contract for theNoble Amos Runner. In June 2010, Anadarko filed a declaratory judgment action in Federal District Court in Houston, Texas seeking to have the court declare that a force majeure condition had occurred and that the drilling contract was terminated by virtue of the initial proclaimed moratorium. We disagree that a force majeure event occurred and that Anadarko had the right to terminate the contract. In August 2010, we filed a counterclaim seeking damages from Anadarko for breach of contract. Anadarko has also attempted to offset approximately $13 million that we had billed for services performed prior to their termination of the contract. We do not believe Anadarko has a basis to offset these invoiced amounts. ~~We do not believe the ultimate resolution of this matter will have a material adverse effect on our financial position, results of operations or cash flows.~~ As a result of the uncertainties noted above, we have not recognized any revenue under the portion of this contract relating to the period after termination and the matter could have a material positive effect on our results of operations or cash flows for the period in which the matter is ~~resolved.~~resolved should the court ultimately rule in our favor.

TheNoble Homer Ferringtonis under contract with a subsidiary of ExxonMobil Corporation (“ExxonMobil”), who entered into an assignment agreement with BP for a two well farm-out of the rig in Libya after successfully drilling two wells with the rig for ExxonMobil. In August 2010, BP attempted to terminate the assignment agreement claiming that the rig was not in the required condition. ExxonMobil has informed us that we must look to BP for payment of the dayrate during the assignment period. In August 2010, we initiated arbitration proceedings under the drilling contract against both BP and ExxonMobil. We do not believe BP had the right to terminate the assignment agreement and believe the rig continued to be fully ready to operate under the drilling contract. The rig has been operating under farm-out arrangements since March 2011. We believe we are owed dayrate by either or both of these clients. The operating dayrate was approximately $538,000 per day for the work in Libya. We are proceeding with the arbitration process and intend to vigorously pursue these claims. As a result of the uncertainties noted above, we have not recognized any revenue during the assignment period and the matter could have a material positive effect on our results of operations or cash flows in the period the matter is ~~resolved.~~resolved should the arbitration panel ultimately rule in our favor.

In August 2007, we entered into a drilling contract with Marathon Oil Company (“Marathon”) for theNoble Jim Dayto operate in the U.S. Gulf of Mexico. On January 1, 2011, Marathon provided notice that it was terminating the contract. Marathon’s stated reason for the termination was that the rig had not been accepted by Marathon by December 31, 2010, and Marathon also maintained that a force majeure condition existed under the contract. The contract contained a provision allowing Marathon to terminate if the rig had not commenced operations by December 31, 2010. We believe the rig was ready to commence operations and should have been accepted by Marathon. The contract term was for four years and represented approximately $752 million in contract backlog at the time of termination. No revenue has been recognized under this contract. In March 2011, we filed suit in Texas ~~state district court~~State District Court against Marathon seeking damages for its actions, and the suit is proceeding. We cannot provide assurance as to the outcome of this lawsuit.

During the fourth quarter of 2007, our Nigerian subsidiary received letters from the Nigerian Maritime Administration and Safety Agency (“NIMASA”) seeking to collect a two percent surcharge on contract amounts under contracts performed by “vessels,” within the meaning of Nigeria’s cabotage laws, engaged in the Nigerian coastal shipping trade. Although we do not believe that these laws apply to our ownership of drilling units, NIMASA is seeking to apply a provision of the Nigerian cabotage laws (which became effective on May 1, 2004) to our offshore drilling units by considering these units to be “vessels” within the meaning of those laws and therefore subject to the surcharge, which is imposed only upon “vessels.” Our offshore drilling units are not engaged in the Nigerian coastal shipping trade and are not in our view “vessels” within the meaning of Nigeria’s cabotage laws. In January 2008, we filed an originating summons against NIMASA and the Minister of Transportation in the Federal High Court of Lagos, Nigeria seeking, among other things, a declaration that our drilling operations do not constitute “coastal trade” or “cabotage” within the meaning of Nigeria’s cabotage laws and that our offshore drilling units are not “vessels” within the meaning of those laws. In February 2009, NIMASA filed suit against us in the Federal High Court of Nigeria seeking collection of the cabotage surcharge. In August 2009, the court issued a favorable ruling in response to our originating summons stating that drilling operations do not fall within the cabotage laws and that drilling rigs are not vessels for purposes of those laws. The court also issued an injunction against the defendants prohibiting their interference with our drilling rigs or drilling operations. NIMASA has appealed the court’s ruling, although the court dismissed NIMASA’s lawsuit filed against us in February 2009. We intend to take all further appropriate legal action to resist the application of Nigeria’s cabotage laws to our drilling units. The outcome of any such legal action and the extent to which we may ultimately be responsible for the surcharge is uncertain. If it is ultimately determined that offshore drilling units constitute vessels within the meaning of the Nigerian cabotage laws, we may be required to pay the surcharge and comply with other aspects of the Nigerian cabotage laws, which could adversely affect our operations in Nigerian waters and require us to incur additional costs of compliance.

NIMASA had also informed the Nigerian Content Division of its position that we are not in compliance with the cabotage laws. The Nigerian Content Division makes determinations of companies’ compliance with applicable local content regulations for purposes of government contracting, including contracting for services in connection with oil and gas concessions where the Nigerian national oil company is a partner. The Nigerian Content Division had originally barred us from participating in new tenders as a result of NIMASA’s allegations, although the Division reversed its actions based on the favorable Federal High Court ruling. However, no assurance can be given with respect to our ability to bid for future work in Nigeria until our dispute with NIMASA is resolved. Further, we continue to evaluate the local content regulations in Nigeria, which could also affect our ability to operate there and our profitability earned from Nigeria.

In November 2010, we concluded our contract for theNoble Duchess in Nigeria. Following the contract, we commenced the exportation process for the rig. ~~We continue to discuss~~The Nigerian Customs Service delayed departure of the rig while we discussed certain spare items that ~~the customs authorities claim are~~they claimed were unaccounted for and for which duty would be due. We ~~believe the value of such equipment is insignificant~~resolved this matter for an immaterial amount and ~~that the authorities are acting improperly. We have not been able to obtain clearance for~~exported the rig ~~although we believe we will ultimately be able to export~~during the ~~rig in a timely manner. However, if the Nigerian customs authorities persist in this manner, the timing~~third quarter of ~~the departure of the unit could be affected and could impede our marketing efforts.~~2011.

We are from time to time a party to various lawsuits that are incidental to our operations in which the claimants seek an unspecified amount of monetary damages for personal injury, including injuries purportedly resulting from exposure to asbestos on drilling rigs and associated facilities. At ~~June~~September 30, 2011, there were approximately 2122 asbestos related lawsuits in which we are one of many defendants. These lawsuits have been filed in the United States in the states of Louisiana, Mississippi and Texas. We intend to vigorously defend against the litigation. We do not believe the ultimate resolution of these matters will have a material adverse effect on our financial position, results of operations or cash flows.

We are a defendant in certain claims and litigation arising out of operations in the ordinary course of business, including certain disputes with customers over receivables discussed in Note 7, the resolution of which, in the opinion of management, will not be material to our financial position, results of operations or cash flows. There is inherent risk in any litigation or dispute and no assurance can be given as to the outcome of these claims.

We operate in a number of countries throughout the world and our income tax returns filed in those jurisdictions are subject to review and examination by tax authorities within those jurisdictions. Our 2008 tax return is currently under audit by the U.S. Internal Revenue Service. In addition, a U.S. subsidiary of Frontier is also under audit for its 2007 and 2008 tax returns. Furthermore, we are currently contesting several non-U.S. tax assessments and may contest future assessments when we believe the assessments are in error. We cannot predict or provide assurance as to the ultimate outcome of the existing or future assessments. We believe the ultimate resolution of the outstanding assessments, for which we have not made any accrual, will not have a material adverse effect on our consolidated financial statements. We recognize uncertain tax positions that we believe have a greater than 50 percent likelihood of being sustained.

Certain of our non-U.S. income tax returns have been examined for the 2002 through 2008 periods and audit claims have been assessed for approximately ~~$328~~$286 million (including interest and penalties), primarily in Mexico. We do not believe we owe these amounts and are defending our position. However, we expect increased audit activity in Mexico and anticipate the tax authorities will issue additional assessments and continue to pursue legal actions for all audit claims. We believe additional audit claims in the range of ~~$10~~$9 to ~~$12~~$10 million attributable to other business tax returns may be assessed against us. We have contested, or intend to contest, the audit findings, including through litigation if necessary, and we do not believe that there is greater than 50 percent likelihood that additional taxes will be incurred. Accordingly, no accrual has been made for such amounts.

We maintain certain insurance coverage against specified marine perils, including liability for physical damage to our drilling rigs, and loss of hire on certain of our rigs. The damage caused in 2005 and 2008 by Hurricanes Katrina, Rita and Ike negatively impacted the energy insurance market, resulting in more ~~restricted~~restrictive and ~~more~~ expensive coverage for U.S. named windstorm perils. Accordingly, effective March 2009, we elected to self-insure this exposure to our units in the U.S. portion of the Gulf of Mexico. Our rigs located in the Mexican portion of the Gulf of Mexico remain covered by commercial insurance for windstorm damage. In addition, we maintain physical damage deductibles of $25 million per occurrence for rigs located in the U.S., Mexico, Brazil, Southeast Asia, the North Sea, ~~and~~ New Zealand and Australia and $15 million per occurrence for rigs operating in West Africa, the Middle East, India, and the Mediterranean Sea. The loss of hire coverage applies only to our rigs operating under contract with a dayrate equal to or greater than $200,000 a day and is subject to a 45-day waiting period for each unit and each occurrence.

Although we maintain insurance in the geographic areas in which we operate, pollution, reservoir damage and environmental risks generally are not fully insurable. Our insurance policies and contractual rights to indemnity may not adequately cover our losses or may have exclusions of coverage for some losses. We do not have insurance coverage or rights to indemnity for all risks, including loss of hire insurance on most of the rigs in our fleet. Uninsured exposures may include expatriate activities prohibited by U.S. laws and regulations, radiation hazards, certain loss or damage to property on board our rigs and losses relating to shore-based terrorist acts or strikes. If a significant accident or other event occurs and is not fully covered by insurance or contractual indemnity, it could materially adversely affect our financial position, results of operations or cash flows. Additionally, there can be no assurance that those parties with contractual obligations to indemnify us will necessarily be financially able to indemnify us against all these risks.

In October 2011, we were assessed a fine by the Brazilian government in the amount of R$238,000 (approximately $135,000) in connection with the inadvertent discharge of approximately 200 barrels of drilling fluid from one of our vessels offshore Brazil in November 2010. We plan on appealing this judgment to the full extent permissible by law.

We carry protection and indemnity insurance covering marine third party liability exposures, which also includes coverage for employer’s liability resulting from personal injury to our offshore drilling crews. Our protection and indemnity policy currently has a standard deductible of $10 million per occurrence, with maximum liability coverage of $750 million.

In connection with our capital expenditure program, we had outstanding commitments, including shipyard and purchase commitments of approximately ~~$2.6~~$3.4 billion at ~~June~~September 30, 2011.

We have entered into agreements with certain of our executive officers, as well as certain other employees. These agreements become effective upon a change of control of Noble-Swiss (within the meaning set forth in the agreements) or a termination of employment in connection with or in anticipation of a change of control, and remain effective for three years thereafter. These agreements provide for compensation and certain other benefits under such circumstances.

Internal Investigation

In 2007, we began, and voluntarily contacted the SEC and the U.S. Department of Justice (“DOJ”) to advise them of an internal investigation of the legality under the United States Foreign Corrupt Practices Act (“FCPA”) and local laws of certain reimbursement payments made by our Nigerian affiliate to our customs agents in Nigeria. In 2010, we finalized settlements of this matter with each of the SEC and the DOJ. Pursuant to these settlements, we agreed to pay fines and penalties to the DOJ and the SEC and to certain undertakings, including refraining from violating the FCPA and other anti-corruption laws, self-reporting any violations of the FCPA or such laws to the DOJ and reporting to the DOJ on an annual basis our progress on anti-corruption compliance matters. Our ability to comply with the terms of the settlements is dependent on the success of our ongoing compliance program, including our ability to continue to manage our agents and supervise, train and retain competent employees, and the efforts of our employees to comply with applicable law and our code of business conduct and ethics.

Any similar investigations or charges and any additional sanctions we may incur as a result of any such investigation could damage our reputation and result in substantial fines, sanctions, civil and/or criminal penalties and curtailment of operations in certain jurisdictions and might adversely affect our business, results of operations or financial condition. Further, resolving any such investigation could be expensive and consume significant time and attention of our senior management.

As of ~~June~~September 30, 2011, all of our rigs operating in Nigeria were operating under temporary import permits. To date, we have been successful in obtaining new, or extending existing, temporary import permits. However, there can be no assurance that we will be able to obtain new permits or further extensions of permits necessary to continue the operation of our rigs in Nigeria. If we cannot obtain a new permit or an extension necessary to continue operations of any rig, we may need to cease operations under the drilling contract for such rig and relocate such rig from Nigerian waters. We cannot predict what impact these events may have on any such contract or our business in Nigeria, and we could face additional fines and sanctions in Nigeria. Furthermore, we cannot predict what changes, if any, relating to temporary import permit policies and procedures may be established or implemented in Nigeria in the future, or how any such changes may impact our business there.

Note 14 — Segment and Related Information

We report our contract drilling operations as a single reportable segment: Contract Drilling Services. The consolidation of our contract drilling operations into one reportable segment is attributable to how we manage our business, and the fact that all of our drilling fleet is dependent upon the worldwide oil and gas industry. The mobile offshore drilling units comprising our offshore rig fleet operate in a single, global market for contract drilling services and are often redeployed globally in response to changing demands of our customers, which consist largely of major non-U.S. and government owned/controlled oil and gas companies throughout the world. Our ~~contract drilling services~~Contract Drilling Services segment currently conducts contract drilling operations principally in the Middle East, India, the U.S. Gulf of Mexico, Mexico, the Mediterranean, the North Sea, Brazil, West Africa and the Asian Pacific.

We evaluate the performance of our operating segment primarily based on operating revenues and net income. Summarized financial information of our reportable segments for the three and ~~six~~nine months ended ~~June~~September 30, 2011 and 2010 is shown in the following table. The “Other” column includes results of labor contract drilling services in Canada and Alaska, as well as corporate related items.

Three Months Ended June 30,
2011 2010
Contract Contract
Drilling Drilling
Services Other Total Services Other Total

Revenues from external customers $ 612,845 $ 15,152 $ 627,997 $ 701,102 $ 8,820 $ 709,922
Depreciation and amortization 159,843 3,276 163,119 123,379 2,848 126,227
Segment operating income/ (loss) 77,309 1,736 79,045 268,941 (394 ) 268,547
Interest expense, net of amount capitalized (683 ) (14,146 ) (14,829 ) (235 ) (275 ) (510 )
Income tax (provision)/ benefit (11,418 ) 1,910 (9,508 ) (51,544 ) 426 (51,118 )
Segment profit/ (loss) 64,939 (10,856 ) 54,083 219,267 (1,342 ) 217,925
Total assets (at end of period) 12,046,536 391,702 12,438,238 7,761,724 1,141,778 8,903,502
Capital expenditures 810,723 3,736 814,459 181,505 11,132 192,637


	Six Months Ended June 30,																		Three Months Ended September 30,
	2011									2010									2011									2010
	Contract									Contract									Contract									Contract
	Drilling									Drilling									Drilling									Drilling
	Services			Other			Total			Services			Other			Total			Services			Other			Total			Services			Other			Total

Revenues from external customers	$	1,177,499		$	29,386		$	1,206,885		$	1,533,262		$	17,511		$	1,550,773		$	719,546		$	18,356		$	737,902		$	604,042		$	8,576		$	612,618
Depreciation and amortization		314,731			6,510			321,241			236,553			5,531			242,084			162,837			3,376			166,213			140,199			3,083			143,282
Segment operating income/ (loss)		162,025			3,284			165,309			692,885			(1,377	)		691,508			159,588			3,994			163,582			109,083			(726	)		108,357
Interest expense, net of amount capitalized		(1,768	)		(32,102	)		(33,870	)		(293	)		(682	)		(975	)		(122	)		(11,408	)		(11,530	)		(125	)		(4,019	)		(4,144	)
Income tax (provision)/ benefit		(30,281	)		5,414			(24,867	)		(107,136	)		622			(106,514	)		(18,380	)		766			(17,614	)		(20,876	)		589			(20,287	)
Segment profit/ (loss)		131,819			(23,241	)		108,578			591,304			(2,653	)		588,651			141,199			(5,882	)		135,317			89,001			(2,981	)		86,020
Total assets (at end of period)		12,046,536			391,702			12,438,238			7,761,724			1,141,778			8,903,502			12,472,018			479,515			12,951,533			9,625,999			1,380,425			11,006,424
Capital expenditures		1,423,711			5,072			1,428,783			517,088			14,313			531,401			555,434			3,771			559,205			352,347			2,345			354,692

2827


	Nine Months Ended September 30,
	2011									2010
	Contract									Contract
	Drilling									Drilling
	Services			Other			Total			Services			Other			Total

Revenues from external customers	$	1,897,045		$	47,742		$	1,944,787		$	2,137,304		$	26,087		$	2,163,391
Depreciation and amortization		477,568			9,886			487,454			376,754			8,612			385,366
Segment operating income/ (loss)		321,613			7,278			328,891			801,966			(2,101	)		799,865
Interest expense, net of amount capitalized		(1,890	)		(43,510	)		(45,400	)		(418	)		(4,701	)		(5,119	)
Income tax (provision)/ benefit		(48,661	)		6,180			(42,481	)		(128,012	)		1,211			(126,801	)
Segment profit/ (loss)		273,018			(29,123	)		243,895			680,302			(5,631	)		674,671
Total assets (at end of period)		12,472,018			479,515			12,951,533			9,625,999			1,380,425			11,006,424
Capital expenditures		1,979,145			8,843			1,987,988			869,435			16,658			886,093

Note 15 — Accounting Pronouncements

In October 2009, the FASB issued guidance that impacts the recognition of revenue in multiple-deliverable arrangements. The guidance establishes a selling-price hierarchy for determining the selling price of a deliverable. The goal of this guidance is to clarify disclosures related to multiple-deliverable arrangements and to align the accounting with the underlying economics of the multiple-deliverable transaction. This guidance is effective for fiscal years beginning on or after June 15, 2010. The adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In January 2010, the FASB issued guidance relating to the disclosure of the fair value of assets. This guidance calls for additional information to be given regarding the transfer of items in and out of respective categories. In addition, it requires additional disclosures regarding the purchase, sales, issuances, and settlements of assets that are classified as level three within the FASB fair value hierarchy. This guidance is generally effective for annual and interim periods ending after December 15, 2009. However, the disclosures about purchases, sales, issuances and settlements in the roll-forward activity in Level 3 fair value measurements were deferred until fiscal years beginning after December 15, 2010. The adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In December 2010, the FASB issued guidance that requires a public entity to disclose pro forma information for business combinations that occurred in the current reporting period. The disclosures include pro forma revenue and earnings of the combined entity for the current reporting period as though the acquisition date for all business combinations that occurred during the year had been as of the beginning of the annual reporting period. If comparative financial statements are presented, the pro forma revenue and earnings of the combined entity for the comparable prior reporting period should be reported as though the acquisition date for all business combinations that occurred during the current year had been as of the beginning of the comparable prior annual reporting period. The guidance is effective for annual reporting periods beginning on or after December 15, 2010. The adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In May 2011, the FASB issued guidance that modified the wording used to describe many of the requirements in accounting literature for measuring fair value and for disclosing information about fair value measurements. The goal of the amendment is to create consistency between the United States and international accounting standards. The guidance is effective for annual and interim reporting periods beginning on or after December 15, 2011. While we are still evaluating this guidance, the adoption of this guidance should not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In June 2011, the FASB issued guidance that allows an entity to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. The amendment no longer allows an entity to show changes to other comprehensive income solely through the statement of equity. For publicly traded entities, the guidance is effective for annual and interim reporting periods beginning on or after December 15, 2011. While we are still evaluating this guidance, the adoption of this guidance will not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

Note 16 — Net Change in Other Assets and Liabilities

The net effect of changes in other assets and liabilities on cash flows from operating activities is as follows:


	Noble-Swiss						Noble-Cayman						Noble-Swiss						Noble-Cayman
	Six months ended						Six months ended						Nine months ended						Nine months ended
	June 30,						June 30,						September 30,						September 30,
	2011			2010			2011			2010			2011			2010			2011			2010

Accounts receivable	$	(122,605	)	$	176,106		$	(122,572	)	$	176,106		$	(213,747	)	$	250,917		$	(213,747	)	$	250,924
Other current assets		(55,141	)		(43,555	)		(46,895	)		(43,136	)		(23,900	)		(22,962	)		(20,578	)		(21,001	)
Other assets		(776	)		(15,751	)		(3,253	)		(15,865	)		(21,755	)		(6,600	)		(24,233	)		(6,705	)
Accounts payable		(17,020	)		19,898			(17,050	)		15,470			(23,744	)		(12,635	)		(23,654	)		(20,773	)
Other current liabilities		1,544			10,340			(11,283	)		9,683			21,281			(9,105	)		13,655			(27,543	)
Other liabilities		16,030			32,208			16,004			32,412			33,566			28,258			33,540			28,482

	$	(177,968	)	$	179,246		$	(185,049	)	$	174,670		$	(228,299	)	$	227,873		$	(235,017	)	$	203,384

Note 17 — Guarantees of Registered Securities

Noble-Cayman and Noble Holding (U.S.) Corporation (“NHC”), a wholly-owned subsidiary of Noble-Cayman, are full and unconditional guarantors of NDC’s 7.50% Senior Notes due 2019 which had an outstanding principal balance at ~~June~~September 30, 2011 of $202 million. NDC is a direct, wholly-owned subsidiary of NHC. Noble Drilling Holding LLC (“NDH”), a wholly-owned subsidiary of Noble-Cayman, is also a co-obligor on (and effectively a guarantor of) the 7.50% Senior Notes. Noble Drilling Services 6 LLC (“NDS6”), also a wholly-owned subsidiary of Noble-Cayman, is a co-issuer of the 7.50% Senior Notes.

NDC and NHIL are full and unconditional guarantors of Noble-Cayman’s 5.875% Senior Notes due 2013, which had an outstanding principal balance of $300 million at ~~June~~September 30, 2011. The indenture governing the Senior Notes due 2013 provides that each guarantee may be released in connection with certain events, including upon a merger, consolidation or transfer of all of the assets of Noble Cayman or the guarantor with or to another person in compliance with the indenture (provided the acquiror assumes the guarantee), upon a liquidation of the guarantor in compliance with the indenture (provided any acquiror assumes the guarantee), or upon the guarantor’s ceasing to be a wholly-owned subsidiary of Noble-Cayman.

Noble-Cayman is a full and unconditional guarantor of NHIL’s 7.375% Senior Notes due 2014, which had an outstanding principal balance of $250 million at ~~June~~September 30, 2011.

Noble-Cayman is a full and unconditional guarantor of NHIL’s 3.45% Senior Notes due 2015, 4.90% Senior Notes due 2020 and 6.20% Senior Notes due 2040. The aggregate principal balance of these three tranches of senior notes at ~~June~~September 30, 2011 was $1.25 billion.

Noble-Cayman is a full and unconditional guarantor of NHIL’s 3.05% Senior Notes due 2016, 4.625% Senior Notes due 2021 and 6.05% Senior Notes due 2041. The aggregate principal balance of these three tranches of senior notes at ~~June~~September 30, 2011 was $1.1 billion.

~~NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES~~
~~CONDENSED CONSOLIDATING BALANCE SHEET~~
~~June 30, 2011~~
~~(in thousands)~~

The following consolidating financial statements of Noble-Cayman, NHC and NDH combined, NDC, NHIL, NDS6 and all other subsidiaries present investments in both consolidated and unconsolidated affiliates using the equity method of accounting.

Other
Non-guarantor
Noble- NHC and NDH Subsidiaries Consolidating
Cayman Combined NDC NHIL NDS6 of Noble Adjustments Total
ASSETS

Current assets
Cash and cash equivalents $ 41 $ 291 $ — $ — $ — $ 224,585 $ — $ 224,917
Accounts receivable — 12,143 3,115 — — 494,728 — 509,986
Prepaid expenses — 357 11 — — 64,309 — 64,677
Short-term notes receivable from affiliates — 119,476 — — — 100,500 (219,976 ) —
Accounts receivable from affiliates 1,115,706 — 799,688 1,276,324 — 4,371,467 (7,563,185 ) —
Other current assets 10,396 99,322 240 18,849 13,459 308,015 (281,431 ) 168,850

Total current assets 1,126,143 231,589 803,054 1,295,173 13,459 5,563,604 (8,064,592 ) 968,430

Property and equipment
Drilling equipment, facilities and other — 2,144,664 71,297 — — 11,676,266 — 13,892,227
Accumulated depreciation — (195,924 ) (51,632 ) — — (2,611,671 ) — (2,859,227 )

Total property and equipment, net — 1,948,740 19,665 — — 9,064,595 — 11,033,000

Notes receivable from affiliates 3,487,062 675,000 — 1,239,600 572,107 2,781,400 (8,755,169 ) —
Investments in affiliates 7,011,232 8,853,976 3,510,031 6,215,619 1,993,985 — (27,584,843 ) —
Other assets 4,090 10,302 2,081 19,691 941 361,150 — 398,255

Total assets
$ 11,628,527 $ 11,719,607 $ 4,334,831 $ 8,770,083 $ 2,580,492 $ 17,770,749 $ (44,404,604 ) $ 12,399,685

LIABILITIES AND EQUITY

Current liabilities
Short-term notes payables from affiliates $ 50,500 $ 50,000 $ — $ — $ — $ 119,476 $ (219,976 ) $ —
Accounts payable and accrued liabilities 1,767 21,747 9,818 52,149 4,412 523,479 — 613,372
Accounts payable to affiliates 1,864,559 3,590,781 24,770 86,840 20,058 2,257,608 (7,844,616 ) —

Total current liabilities 1,916,826 3,662,528 34,588 138,989 24,470 2,900,563 (8,064,592 ) 613,372

Long-term debt 724,929 — — 2,595,146 201,695 — 3,521,770
Notes payable to affiliates 1,770,500 1,147,500 85,000 975,000 811,000 3,966,169 (8,755,169 ) —
Other liabilities 19,929 46,253 25,796 — — 377,566 469,544

Total liabilities
4,432,184 4,856,281 145,384 3,709,135 1,037,165 7,244,298 (16,819,761 ) 4,604,686

Commitments and contingencies

Equity
7,196,343 6,863,326 4,189,447 5,060,948 1,543,327 10,526,451 (27,584,843 ) 7,794,999

Total liabilities and equity
$ 11,628,527 $ 11,719,607 $ 4,334,831 $ 8,770,083 $ 2,580,492 $ 17,770,749 $ (44,404,604 ) $ 12,399,685

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
September 30, 2011
(in thousands)


													Other
													Non-guarantor
	Noble-		NHC and NDH										Subsidiaries			Consolidating
	Cayman		Combined			NDC			NHIL		NDS6		of Noble			Adjustments			Total
ASSETS
Current assets
Cash and cash equivalents	$	—	$	292		$	—		$	—	$	—	$	191,713		$	—		$	192,005
Accounts receivable		—		10,757			3,472			—		—		586,932			—			601,161
Prepaid expenses		—		400			10			—		—		57,121			—			57,531
Short-term notes receivable from affiliates		—		119,476			—			—		—		110,000			(229,476	)		—
Accounts receivable from affiliates		1,182,035		92,282			847,880			150,144		15,737		5,705,679			(7,993,757	)		—
Other current assets		—		6,247			240			—		—		133,538			—			140,025

Total current assets		1,182,035		229,454			851,602			150,144		15,737		6,784,983			(8,223,233	)		990,722


Property and equipment
Drilling equipment, facilities and other		—		2,374,299			71,567			—		—		11,940,555			—			14,386,421
Accumulated depreciation		—		(207,832	)		(52,334	)		—		—		(2,734,320	)		—			(2,994,486	)

Total property and equipment, net		—		2,166,467			19,233			—		—		9,206,235			—			11,391,935


Notes receivable from affiliates		3,487,062		675,000			—			2,336,527		572,107		2,662,901			(9,733,597	)		—
Investments in affiliates		7,185,905		9,133,639			3,510,041			6,370,565		1,899,939		—			(28,100,089	)		—
Other assets		3,660		15,933			2,067			19,087		910		487,484			—			529,141

Total assets	$	11,858,662	$	12,220,493		$	4,382,943		$	8,876,323	$	2,488,693	$	19,141,603		$	(46,056,919	)	$	12,911,798


LIABILITIES AND EQUITY
Current liabilities
Short-term notes payables from affiliates	$	60,000	$	50,000		$	—		$	—	$	—	$	119,476		$	(229,476	)	$	—
Accounts payable and accrued liabilities		6,298		24,036			8,116			15,201		630		580,143			—			634,424
Accounts payable to affiliates		1,802,030		3,806,799			26,056			99,896		30,916		2,228,060			(7,993,757	)		—

Total current liabilities		1,868,328		3,880,835			34,172			115,097		31,546		2,927,679			(8,223,233	)		634,424


Long-term debt		1,014,939		—			—			2,595,232		201,695		—			—			3,811,866
Notes payable to affiliates		1,652,000		1,147,500			85,000			975,000		811,000		5,063,097			(9,733,597	)		—
Other liabilities		19,929		24,291			30,177			—		—		443,751			—			518,148

Total liabilities		4,555,196		5,052,626			149,349			3,685,329		1,044,241		8,434,527			(17,956,830	)		4,964,438


Commitments and contingencies

Equity		7,303,466		7,167,867			4,233,594			5,190,994		1,444,452		10,707,076			(28,100,089	)		7,947,360

Total liabilities and equity	$	11,858,662	$	12,220,493		$	4,382,943		$	8,876,323	$	2,488,693	$	19,141,603		$	(46,056,919	)	$	12,911,798

3130

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEET
December 31, 2010
(in thousands)


																																		Other
													Non-guarantor																					Non-guarantor
	Noble-		NHC and NDH										Subsidiaries			Consolidating						Noble-		NHC and NDH										Subsidiaries			Consolidating
	Cayman		Combined			NDC			NHIL		NDS6		of Noble			Adjustments			Total			Cayman		Combined			NDC			NHIL		NDS6		of Noble			Adjustments			Total
ASSETS
Current assets
Cash and cash equivalents	$	42	$	146		$	—		$	—	$	—	$	333,211		$	—		$	333,399		$	42	$	146		$	—		$	—	$	—	$	333,211		$	—		$	333,399
Accounts receivable		—		6,984			1,795			—		—		378,635			—			387,414			—		6,984			1,795			—		—		378,635			—			387,414
Prepaid expenses		—		310			—			—		—		32,922			—			33,232			—		310			—			—		—		32,922			—			33,232
Short-term notes receivable from affiliates		—		119,476			—			—		—		75,000			(194,476	)		—			—		119,476			—			—		—		75,000			(194,476	)		—
Accounts receivable from affiliates		607,207		—			751,623			199,235		1,958		3,659,570			(5,219,593	)		—			614,264		73,001			751,623			219,215		11,374		3,801,852			(5,471,329	)		—
Other current assets		7,057		89,736			240			19,980		9,416		276,194			(251,736	)		150,887			—		16,735			240			—		—		133,912			—			150,887

Total current assets		614,306		216,652			753,658			219,215		11,374		4,755,532			(5,665,805	)		904,932			614,306		216,652			753,658			219,215		11,374		4,755,532			(5,665,805	)		904,932


Property and equipment
Drilling equipment, facilities and other		—		1,254,482			70,945			—		—		11,289,547			—			12,614,974			—		1,254,482			70,945			—		—		11,289,547			—			12,614,974
Accumulated depreciation		—		(153,638	)		(50,250	)		—		—		(2,391,066	)		—			(2,594,954	)		—		(153,638	)		(50,250	)		—		—		(2,391,066	)		—			(2,594,954	)

Total property and equipment, net		—		1,100,844			20,695			—		—		8,898,481			—			10,020,020			—		1,100,844			20,695			—		—		8,898,481			—			10,020,020


Notes receivable from affiliates		3,507,062		675,000			—			1,239,600		479,107		2,492,900			(8,393,669	)		—			3,507,062		675,000			—			1,239,600		479,107		2,492,900			(8,393,669	)		—
Investments in affiliates		6,835,466		9,150,129			3,561,451			5,618,248		1,879,831		—			(27,045,125	)		—			6,835,466		9,150,129			3,561,451			5,618,248		1,879,831		—			(27,045,125	)		—
Other assets		1,872		7,700			2,451			11,336		1,001		318,232			—			342,592			1,872		7,700			2,451			11,336		1,001		318,232			—			342,592

Total assets	$	10,958,706	$	11,150,325		$	4,338,255		$	7,088,399	$	2,371,313	$	16,465,145		$	(41,104,599	)	$	11,267,544		$	10,958,706	$	11,150,325		$	4,338,255		$	7,088,399	$	2,371,313	$	16,465,145		$	(41,104,599	)	$	11,267,544


LIABILITIES AND EQUITY
Current liabilities
Short-term notes payables from affiliates	$	25,000	$	50,000		$	—		$	—	$	—	$	119,476		$	(194,476	)	$	—		$	25,000	$	50,000		$	—		$	—	$	—	$	119,476		$	(194,476	)	$	—
Current maturities of long-term debt		—		—			—			—		—		80,213			—			80,213			—		—			—			—		—		80,213			—			80,213
Accounts payable and accrued liabilities		1,473		19,218			8,779			31,973		4,413		647,488			—			713,344			1,473		19,218			8,779			31,973		4,413		647,488			—			713,344
Accounts payable to affiliates		1,601,869		2,708,598			30,095			64,192		7,134		1,059,441			(5,471,329	)		—			1,601,869		2,708,598			30,095			64,192		7,134		1,059,441			(5,471,329	)		—

Total current liabilities		1,628,342		2,777,816			38,874			96,165		11,547		1,906,618			(5,665,805	)		793,557			1,628,342		2,777,816			38,874			96,165		11,547		1,906,618			(5,665,805	)		793,557


Long-term debt		339,911		—			—			1,498,066		201,695		646,812			—			2,686,484			339,911		—			—			1,498,066		201,695		646,812			—			2,686,484
Notes payable to affiliates		1,834,500		1,092,000			120,000			550,000		811,000		3,986,169			(8,393,669	)		—			1,834,500		1,092,000			120,000			550,000		811,000		3,986,169			(8,393,669	)		—
Other liabilities		19,929		48,595			25,485			—		—		432,839			—			526,848			19,929		48,595			25,485			—		—		432,839			—			526,848

Total liabilities		3,822,682		3,918,411			184,359			2,144,231		1,024,242		6,972,438			(14,059,474	)		4,006,889			3,822,682		3,918,411			184,359			2,144,231		1,024,242		6,972,438			(14,059,474	)		4,006,889


Commitments and contingencies

Total Equity		7,136,024		7,231,914			4,153,896			4,944,168		1,347,071		9,492,707			(27,045,125	)		7,260,655
Equity																							7,136,024		7,231,914			4,153,896			4,944,168		1,347,071		9,492,707			(27,045,125	)		7,260,655

Total liabilities and equity	$	10,958,706	$	11,150,325		$	4,338,255		$	7,088,399	$	2,371,313	$	16,465,145		$	(41,104,599	)	$	11,267,544		$	10,958,706	$	11,150,325		$	4,338,255		$	7,088,399	$	2,371,313	$	16,465,145		$	(41,104,599	)	$	11,267,544

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF INCOME
Three Months Ended September 30, 2011
(in thousands)


																Other
																Non-guarantor
	Noble-			NHC and NDH												Subsidiaries			Consolidating
	Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	38,955		$	5,105		$	—		$	—		$	680,617		$	(19,785	)	$	704,892
Reimbursables		—			691			—			—			—			16,747			—			17,438
Labor contract drilling services		—			4			—			—			—			15,560			—			15,564
Other		—			—			—			—			—			8			—			8

Total operating revenues		—			39,650			5,105			—			—			712,932			(19,785	)		737,902


Operating costs and expenses
Contract drilling services		1,759			10,485			1,883			9,819			—			345,465			(19,785	)		349,626
Reimbursables		—			420			—			—			—			13,551			—			13,971
Labor contract drilling services		—			—			—			—			—			8,053			—			8,053
Depreciation and amortization		—			13,138			937			—			—			151,644			—			165,719
Selling, general and administrative		2,094			1,488			—			9,253			—			4,802			—			17,637
Gain on contract extinguishments, net		—			—			—			—			—			—			—			—

Total operating costs and expenses		3,853			25,531			2,820			19,072			—			523,515			(19,785	)		555,006


Operating income (loss)		(3,853	)		14,119			2,285			(19,072	)		—			189,417			—			182,896

Other income (expense)
Equity earnings in affiliates, net of tax		174,673			226,079			45,818			172,153			(20,624	)		—			(598,099	)		—
Interest expense, net of amounts capitalized		(16,721	)		(15,612	)		(1,285	)		(21,641	)		(7,106	)		(267	)		51,102			(11,530	)
Interest income and other, net		1,615			6,906			(40	)		15,813			2,277			26,415			(51,102	)		1,884


Income before income taxes		155,714			231,492			46,778			147,253			(25,453	)		215,565			(598,099	)		173,250
Income tax provision		—			487			—			—			—			(17,785	)		—			(17,298	)

Net Income		155,714			231,979			46,778			147,253			(25,453	)		197,780			(598,099	)		155,952

Net loss attributable to noncontrolling interests		—			—			—			—			—			(238	)		—			(238	)

Net income attributable to Noble Corporation	$	155,714		$	231,979		$	46,778		$	147,253		$	(25,453	)	$	197,542		$	(598,099	)	$	155,714

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF INCOME
~~Three~~Nine Months Ended ~~June~~September 30, 2011
(in thousands)


																Other																								Other
																Non-guarantor																								Non-guarantor
	Noble-			NHC and NDH												Subsidiaries			Consolidating						Noble-			NHC and NDH												Subsidiaries			Consolidating
	Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total			Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	35,090		$	4,705		$	—		$	—		$	566,145		$	(16,390	)	$	589,550		$	—		$	100,009		$	14,800		$	—		$	—		$	1,770,356		$	(48,118	)	$	1,837,047
Reimbursables		—			1,778			—			—			—			22,344			—			24,122			—			3,381			12			—			—			60,458			—			63,851
Labor contract drilling services		—			—			—			—			—			14,012			—			14,012			—			4			—			—			—			43,119			—			43,123
Other		—			—			—			—			—			313			—			313			—			—			—			—			—			766			—			766

Total operating revenues		—			36,868			4,705			—			—			602,814			(16,390	)		627,997			—			103,394			14,812			—			—			1,874,699			(48,118	)		1,944,787


Operating costs and expenses
Contract drilling services		1,598			12,085			1,975			8,236			—			322,700			(16,390	)		330,204			4,818			31,554			5,681			26,625			—			960,102			(48,118	)		980,662
Reimbursables		—			2,007			—			—			—			16,716			—			18,723			—			3,331			—			—			—			46,466			—			49,797
Labor contract drilling services		—			—			—			—			—			8,750			—			8,750			—			—			—			—			—			25,326			—			25,326
Depreciation and amortization		—			13,068			935			—			—			148,633			—			162,636			—			36,330			2,781			—			—			446,899			—			486,010
Selling, general and administrative		1,792			1,209			—			7,626			1			4,014			—			14,642			5,397			4,206			—			24,756			1			14,450			—			48,810
Gain on contract extinguishments, net		—			—			—			—			—			—			—			—						—			—			—			—			(21,202	)		—			(21,202	)

Total operating costs and expenses		3,390			28,369			2,910			15,862			1			500,813			(16,390	)		534,955			10,215			75,421			8,462			51,381			1			1,472,041			(48,118	)		1,569,403


Operating income (loss)		(3,390	)		8,499			1,795			(15,862	)		(1	)		102,001			—			93,042			(10,215	)		27,973			6,350			(51,381	)		(1	)		402,658			—			375,384

Other income (expense)
Equity earnings in affiliates, net of tax		88,486			64,434			19,176			122,310			71,736			—			(366,142	)		—			350,439			328,452			80,795			344,524			86,932			—			(1,191,142	)		—
Interest expense, net of amounts capitalized		(17,903	)		(15,323	)		(1,719	)		(23,530	)		(7,271	)		(886	)		51,803			(14,829	)		(52,985	)		(45,527	)		(4,824	)		(67,667	)		(22,048	)		(3,284	)		150,935			(45,400	)
Interest income and other, net		1,625			6,932			37			11,435			2,252			29,375			(51,803	)		(147	)		4,953			19,376			8			38,557			6,321			85,698			(150,935	)		3,978


Income before income taxes		68,818			64,542			19,289			94,353			66,716			130,490			(366,142	)		78,066			292,192			330,274			82,329			264,033			71,204			485,072			(1,191,142	)		333,962
Income tax provision		—			6,658												(15,815	)					(9,157	)		—			6,287			—			—			—			(47,767	)		—			(41,480	)

Net Income		68,818			71,200			19,289			94,353			66,716			114,675			(366,142	)		68,909			292,192			336,561			82,329			264,033			71,204			437,305			(1,191,142	)		292,482

Net loss attributable to noncontrolling interests		—			—			—			—			—			(91	)		—			(91	)		—			—			—			—			—			(290	)		—			(290	)


Net income attributable to Noble Corporation	$	68,818		$	71,200		$	19,289		$	94,353		$	66,716		$	114,584		$	(366,142	)	$	68,818		$	292,192		$	336,561		$	82,329		$	264,033		$	71,204		$	437,015		$	(1,191,142	)	$	292,192

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF INCOME
~~Six~~Three Months Ended ~~June~~September 30, ~~2011~~2010
(in thousands)


																Other																								Other
																Non-guarantor																								Non-guarantor
	Noble-			NHC and NDH												Subsidiaries			Consolidating						Noble-			NHC and NDH												Subsidiaries			Consolidating
	Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total			Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	61,054		$	9,695		$	—		$	—		$	1,089,739		$	(28,333	)	$	1,132,155		$	—		$	23,724		$	5,363		$	—		$	—		$	565,132		$	(9,300	)	$	584,919
Reimbursables		—			2,690			12			—			—			43,711			—			46,413			—			388			—			—			—			18,789			—			19,177
Labor contract drilling services		—			—			—			—			��			27,559			—			27,559			—			—			—			—			—			7,887			—			7,887
Other		—			—			—			—			—			758			—			758			—			(107	)		—			—			—			742			—			635

Total operating revenues		—			63,744			9,707			—			—			1,161,767			(28,333	)		1,206,885			—			24,005			5,363			—			—			592,550			(9,300	)		612,618


Operating costs and expenses
Contract drilling services		3,059			21,069			3,798			16,806			—			614,637			(28,333	)		631,036			18,924			8,475			1,657			—			—			296,031			(9,300	)		315,787
Reimbursables		—			2,911			—			—			—			32,915			—			35,826			—			127			—			—			—			14,224			—			14,351
Labor contract drilling services		—			—			—			—			—			17,273			—			17,273			—			—			—			—			—			5,302			—			5,302
Depreciation and amortization		—			23,192			1,844			—			—			295,255			—			320,291			—			9,494			924			—			—			132,641			—			143,059
Selling, general and administrative		3,303			2,718			—			15,503			1			9,648			—			31,173			—			605			94			(63	)		—			16,079			—			16,715
Gain on contract extinguishments, net		—			—			—			—			—			(21,202	)		—			(21,202	)

Total operating costs and expenses		6,362			49,890			5,642			32,309			1			948,526			(28,333	)		1,014,397			18,924			18,701			2,675			(63	)		—			464,277			(9,300	)		495,214


Operating income (loss)		(6,362	)		13,854			4,065			(32,309	)		(1	)		213,241			—			192,488			(18,924	)		5,304			2,688			63			—			128,273			—			117,404

Other income (expense)
Equity earnings in affiliates, net of tax		175,766			102,373			34,977			172,371			107,556			—			(593,043	)		—			124,218			155,504			38,484			136,039			35,842			—			(490,087	)		—
Interest expense, net of amounts capitalized		(36,264	)		(29,915	)		(3,539	)		(46,026	)		(14,942	)		(3,017	)		99,833			(33,870	)		(12,251	)		(14,845	)		(1,859	)		(12,645	)		(1,424	)		(2,668	)		41,545			(4,147	)
Interest income and other, net		3,338			12,470			48			22,744			4,044			59,283			(99,833	)		2,094			1,556			555			—			8,419			2,221			30,004			(41,545	)		1,210


Income before income taxes		136,478			98,782			35,551			116,780			96,657			269,507			(593,043	)		160,712			94,599			146,518			39,313			131,876			36,639			155,609			(490,087	)		114,467
Income tax provision		—			5,800			—			—			—			(29,982	)		—			(24,182	)		—			(18,445	)		—			—			—			(956	)					(19,401	)

Net Income		136,478			104,582			35,551			116,780			96,657			239,525			(593,043	)		136,530			94,599			128,073			39,313			131,876			36,639			154,653			(490,087	)		95,066

Net loss attributable to noncontrolling interests		—			—			—			—			—			(52	)		—			(52	)		—			—			—			—			—			(467	)		—			(467	)


Net income attributable to Noble Corporation	$	136,478		$	104,582		$	35,551		$	116,780		$	96,657		$	239,473		$	(593,043	)	$	136,478		$	94,599		$	128,073		$	39,313		$	131,876		$	36,639		$	154,186		$	(490,087	)	$	94,599

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF INCOME
~~Three~~Nine Months Ended ~~June~~September 30, 2010
(in thousands)


															Other																								Other
															Non-guarantor																								Non-guarantor
	Noble-			NHC and NDH											Subsidiaries			Consolidating						Noble-			NHC and NDH												Subsidiaries			Consolidating
	Cayman			Combined			NDC			NHIL			NDS6		of Noble			Adjustments			Total			Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	20,280		$	5,016		$	—		$	—	$	670,214		$	(8,000	)	$	687,510		$	—		$	72,313		$	12,847		$	—		$	—		$	2,026,515		$	(30,600	)	$	2,081,075
Reimbursables		—			340			61			—			—		13,352						13,753			—			978			61			—			—			56,124			—			57,163
Labor contract drilling services		—			—			—			—			—		8,056						8,056			—			—			—			—			—			23,704			—			23,704
Other		—			112			—			—			—		491						603			—			5			—			—			—			1,444			—			1,449

Total operating revenues		—			20,732			5,077			—			—		692,113			(8,000	)		709,922			—			73,296			12,908			—			—			2,107,787			(30,600	)		2,163,391


Operating costs and expenses
Contract drilling services		2			10,726			1,188			—			—		267,168			(8,000	)		271,084			18,931			27,082			4,793			—			—			819,446			(30,600	)		839,652
Reimbursables		—			988			61			—			—		9,316						10,365			—			1,226			61			—			—			43,172			—			44,459
Labor contract drilling services		—			—			—			—			—		5,380						5,380			—			—			—			—			—			16,570			—			16,570
Depreciation and amortization		—			9,044			874			—			—		116,134						126,052			—			27,321			2,536			—			—			354,918			—			384,775
Selling, general and administrative		—			49,773			88			76			—		(34,403	)					15,534			—			51,241			315			56			—			(3,475	)		—			48,137

Total operating costs and expenses		2			70,531			2,211			76			—		363,595			(8,000	)		428,415			18,931			106,870			7,705			56			—			1,230,631			(30,600	)		1,333,593


Operating income (loss)		(2	)		(49,799	)		2,866			(76	)		—		328,518			—			281,507			(18,931	)		(33,574	)		5,203			(56	)		—			877,156			—			829,798

Other income (expense)
Equity earnings in affiliates, net of tax		231,400			166,662			9,556			242,210			123,117		—			(772,945	)		—			732,956			497,191			47,602			768,130			336,350			—			(2,382,229	)		—
Interest expense, net of amounts capitalized		(174	)		(20,453	)		(1,839	)		(9,736	)		—		(2,739	)		34,431			(510	)		(12,838	)		(50,179	)		(5,516	)		(32,010	)		(1,424	)		(8,852	)		105,697			(5,122	)
Interest income and other, net		1,733			20,941			—			—			4,214		9,046			(34,431	)		1,503			5,002			23,312			—			8,419			8,373			66,911			(105,697	)		6,320


Income before income taxes		232,957			117,351			10,583			232,398			127,331		334,825			(772,945	)		282,500			706,189			436,750			47,289			744,483			343,299			935,215			(2,382,229	)		830,996
Income tax provision		—			(10,351	)		—			—			—		(39,192	)		—			(49,543	)		—			(27,537	)		—			—			—			(96,803	)		—			(124,340	)

Net Income	$	232,957		$	107,000		$	10,583		$	232,398		$	127,331	$	295,633		$	(772,945	)	$	232,957			706,189			409,213			47,289			744,483			343,299			838,412			(2,382,229	)		706,656

Net loss attributable to noncontrolling interests																									—			—			—			—			—			(467	)		—			(467	)


Net income attributable to Noble Corporation																								$	706,189		$	409,213		$	47,289		$	744,483		$	343,299		$	837,945		$	(2,382,229	)	$	706,189

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF ~~INCOME~~CASH FLOWS
~~Six~~Nine Months Ended ~~June~~September 30, ~~2010~~2011
(in thousands)

Other
Non-guarantor
Noble- NHC and NDH Subsidiaries Consolidating
Cayman Combined NDC NHIL NDS6 of Noble Adjustments Total
Operating revenues

Contract drilling services $ — $ 48,589 $ 7,484 $ — $ — $ 1,461,383 $ (21,300 ) $ 1,496,156
Reimbursables — 590 61 — — 37,335 — 37,986
Labor contract drilling services — — — — — 15,817 — 15,817
Other — 112 — — — 702 — 814

Total operating revenues — 49,291 7,545 — — 1,515,237 (21,300 ) 1,550,773

Operating costs and expenses

Contract drilling services 7 18,607 3,136 — — 523,415 (21,300 ) 523,865
Reimbursables — 1,099 61 — — 28,948 — 30,108
Labor contract drilling services — — — — — 11,268 — 11,268
Depreciation and amortization — 17,827 1,612 — — 222,277 — 241,716
Selling, general and administrative — 50,636 221 119 — (19,554 ) — 31,422

Total operating costs and expenses 7 88,169 5,030 119 — 766,354 (21,300 ) 838,379

Operating income (loss)
(7 ) (38,878 ) 2,515 (119 ) — 748,883 — 712,394

Other income (expense)

Equity earnings in affiliates, net of tax 608,738 341,687 9,118 632,091 300,508 — (1,892,142 ) —
Interest expense, net of amounts capitalized (587 ) (35,334 ) (3,657 ) (19,365 ) — (6,184 ) 64,152 (975 )
Interest income and other, net 3,446 22,757 — — 6,152 36,907 (64,152 ) 5,110

Income before income taxes
611,590 290,232 7,976 612,607 306,660 779,606 (1,892,142 ) 716,529
Income tax provision — (9,092 ) — — — (95,847 ) — (104,939 )

Net Income
$ 611,590 $ 281,140 $ 7,976 $ 612,607 $ 306,660 $ 683,759 $ (1,892,142 ) $ 611,590


																Other
																Non-guarantor
	Noble-			NHC and NDH												Subsidiaries			Consolidating
	Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total
Cash flows from operating activities
Net cash from operating activities	$	(40,060	)	$	23,345		$	7,041		$	(105,014	)	$	(19,420	)	$	636,982		$	—		$	502,874


Cash flows from investing activities
New construction and capital expenditures		—			(1,124,826	)		—			—			—			(906,990	)		—			(2,031,816	)
Notes receivable from affiliates		20,000			—			—			(1,096,927	)		—			200,000			876,927			—
Refund from contract extinguishments		—			—			—			—			—			18,642			—			18,642

Net cash from investing activities		20,000			(1,124,826	)		—			(1,096,927	)		—			(688,348	)		876,927			(2,013,174	)


Cash flows from financing activities
Increase in bank credit facilities, net		675,000			—			—			—			—			—			—			675,000
Proceeds from issuance of senior notes, net		—			—			—			1,087,833			—			—			—			1,087,833
Contributions from joint venture partners		—			—			—			—			—			481,000			—			481,000
Payments of joint venture debt		—			—			—			—			—			(693,494	)		—			(693,494	)
Settlement of interest rate swaps		—			—			—			—			—			(29,032	)		—			(29,032	)
Financing cost on credit facilities		(2,835	)		—			—			—			—			—			—			(2,835	)
Distributions to parent		(149,566	)		—			—			—			—			—			—			(149,566	)
Advances (to) from affiliates		(355,081	)		1,119,127			27,959			114,108			19,420			(925,533	)		—			—
Notes payable to affiliates		(147,500	)		(17,500	)		(35,000	)		—			—			1,076,927			(876,927	)		—

Net cash from financing activities		20,018			1,101,627			(7,041	)		1,201,941			19,420			(90,132	)		(876,927	)		1,368,906
															��
Net change in cash and cash equivalents		(42	)		146			—			—			—			(141,498	)		—			(141,394	)
Cash and cash equivalents, beginning of period		42			146			—			—			—			333,211			—			333,399

Cash and cash equivalents, end of period	$	—		$	292		$	—		$	—		$	—		$	191,713		$	—		$	192,005

NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS
~~Six~~Nine Months Ended ~~June~~September 30, ~~2011~~2010
(in thousands)


																Other																								Other
																Non-guarantor																								Non-guarantor
	Noble-			NHC and NDH												Subsidiaries			Consolidating						Noble-			NHC and NDH												Subsidiaries			Consolidating
	Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total			Cayman			Combined			NDC			NHIL			NDS6			of Noble			Adjustments			Total
Cash flows from operating activities
Net cash from operating activities	$	(30,984	)	$	20,555		$	2,807		$	(43,770	)	$	(10,840	)	$	321,277		$	—		$	259,045		$	(6,194	)	$	(57,507	)	$	(3,907	)	$	(26,975	)	$	3,258		$	1,372,073		$	—		$	1,280,748


Cash flows from investing activities
New construction and capital expenditures		—			(842,012	)		—			—			—			(633,338	)		—			(1,475,350	)		—			(381,928	)		—			—			—			(499,482	)		—			(881,410	)
Notes receivable from affiliates		20,000			—			—			—			—			91,000			(111,000	)		—			—			—			—			(1,239,600	)		—			(490,000	)		1,729,600			—
Refund from contract extinguishments		—			—			—			—			—			18,642			—			18,642
Acquisition of FDR Holdings, Ltd., net of cash acquired																										(1,629,644	)		—			—			—			—			—			—			(1,629,644	)

Net cash from investing activities		20,000			(842,012	)		—			—			—			(523,696	)		(111,000	)		(1,456,708	)		(1,629,644	)		(381,928	)		—			(1,239,600	)		—			(989,482	)		1,729,600			(2,511,054	)


Cash flows from financing activities
Borrowings on bank credit facilities		625,000			—			—			—			—			—			—			625,000
Payments of bank credit facilities		(240,000	)		—			—			—			—			—			—			(240,000	)
Proceeds from issuance of senior notes, net		—			—			—			1,087,833			—			—			—			1,087,833			—			—			—			1,238,074			—			—			—			1,238,074
Contributions from joint venture partners		—			—			—			—			—			436,000			—			436,000			—			—			—			—			—			35,000			—			35,000
Payments of joint venture debt		—			—			—			—			—			(693,494	)		—			(693,494	)
Settlement of interest rate swaps		—			—			—			—			—			(29,032	)		—			(29,032	)		—			—			—			—			—			(2,041	)		—			(2,041	)
Financing cost on credit facilities		(2,835	)		—			—			—			—			—			—			(2,835	)
Distributions to parent		(94,291	)		—			—			—			—			—			—			(94,291	)		(422,537	)																				(422,537	)
Advances (to) from affiliates		(238,391	)		839,102			32,193			(1,044,063	)		10,840			400,319			—			—			328,813			439,401			3,907			28,501			(3,258	)		(797,364	)		—			—
Notes payable to affiliates		(38,500	)		(17,500	)		(35,000	)		—			—			(20,000	)		111,000			—			1,729,600			—			—			—			—			—			(1,729,600	)		—

Net cash from financing activities		10,983			821,602			(2,807	)		43,770			10,840			93,793			111,000			1,089,181			1,635,876			439,401			3,907			1,266,575			(3,258	)		(764,405	)		(1,729,600	)		848,496

Net change in cash and cash equivalents		(1	)		145			—			—			—			(108,626	)		—			(108,482	)		38			(34	)		—			—			—			(381,814	)		—			(381,810	)
Cash and cash equivalents, beginning of period		42			146			—			—			—			333,211						333,399			3			268			—			—			—			725,954						726,225

Cash and cash equivalents, end of period	$	41		$	291		$	—		$	—		$	—		$	224,585		$	—		$	224,917		$	41		$	234		$	—		$	—		$	—		$	344,140		$	—		$	344,415

~~NOBLE CORPORATION (NOBLE-CAYMAN) AND SUBSIDIARIES~~
~~CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS~~
~~Six Months Ended June 30, 2010~~
~~(in thousands)~~

Other
Non-guarantor
Noble- NHC and NDH Subsidiaries Consolidating
Cayman Combined NDC NHIL NDS6 of Noble Adjustments Total
Cash flows from operating activities

Net cash from operating activities $ 10,138 $ (36,375 ) $ 3,592 $ (4,400 ) $ 60 $ 1,053,419 $ — $ 1,026,434

Cash flows from investing activities

New construction and capital expenditures — (184,963 ) — — — (363,918 ) — (548,881 )

Net cash from investing activities — (184,963 ) — — — (363,918 ) — (548,881 )

Cash flows from financing activities

Distributions to parent (128,315 ) — — — — — — (128,315 )
Advances (to) from affiliates 119,876 221,265 (3,592 ) 4,400 (60 ) (341,889 ) — —

Net cash from financing activities (8,439 ) 221,265 (3,592 ) 4,400 (60 ) (341,889 ) — (128,315 )

Net change in cash and cash equivalents 1,699 (73 ) — — — 347,612 — 349,238
Cash and cash equivalents, beginning of period 3 268 — — — 725,954 — 726,225

Cash and cash equivalents, end of period $ 1,702 $ 195 $ — $ — $ — $ 1,073,566 $ — $ 1,075,463


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

The following discussion is intended to assist you in understanding our financial position at ~~June~~September 30, 2011, and our results of operations for the three and ~~six~~nine months ended ~~June~~September 30, 2011 and 2010. The following discussion should be read in conjunction with the consolidated financial statements and related notes contained in this Quarterly Report on Form 10-Q and the consolidated financial statements and notes thereto included in the Annual Report on Form 10-K for the year ended December 31, 2010 filed by Noble Corporation, a Swiss corporation (“Noble-Swiss”), and Noble Corporation, a Cayman Islands company (“Noble-Cayman”).

Forward-Looking Statements

This Quarterly Report on Form 10-Q includes “forward-looking statements” within the meaning of Section 27A of the U.S. Securities Act of 1933, as amended, and Section 21E of the U.S. Securities Exchange Act of 1934, as amended. All statements other than statements of historical facts included in this report regarding the Frontier transaction and integration, contract backlog, fleet and benefits, our financial position, business strategy, backlog, completion and acceptance of our newbuild rigs, contract commitments, dayrates, contract commencements, extension or renewals, contract tenders, the outcome of any dispute, litigation or investigation, plans and objectives of management for future operations, foreign currency requirements, results of joint ventures, indemnity and other contract claims, construction of rigs, industry conditions including the effect of disruptions of drilling in the U.S. Gulf of Mexico, access to financing, impact of competition, taxes and tax rates, advantages of our worldwide internal restructuring, indebtedness covenant compliance, and timing for compliance with any new regulations are forward-looking statements. When used in this report, the words “anticipate,” “believe,” “estimate,” “expect,” “intend,” “may,” “plan,” “project,” “should” and similar expressions are intended to be among the statements that identify forward-looking statements. Although we believe that the expectations reflected in such forward-looking statements are reasonable, we cannot assure you that such expectations will prove to be correct. These forward-looking statements speak only as of the date of this report on Form 10-Q and we undertake no obligation to revise or update any forward-looking statement for any reason, except as required by law. We have identified factors including but not limited to operating hazards and delays, risks associated with operations outside the U.S., actions by regulatory authorities, customers, joint venture partners, contractors, lenders and other third parties, legislation and regulations affecting drilling operations, costs and difficulties relating to the integration of businesses, factors affecting the level of activity in the oil and gas industry, supply and demand of drilling rigs, factors affecting the duration of contracts, the actual amount of downtime, factors that reduce applicable dayrates, violations of anti-corruption laws, hurricanes and other weather conditions and the future price of oil and gas that could cause actual plans or results to differ materially from those included in any forward-looking statements. These factors include those referenced or described in Part I, Item 1A. “Risk Factors” of our Annual Report on Form 10-K for the year ended December 31, 2010, our Quarterly Reports on Form 10-Q and in our other filings with the U.S. Securities and Exchange Commission (“SEC”). We cannot control such risk factors and other uncertainties, and in many cases, we cannot predict the risks and uncertainties that could cause our actual results to differ materially from those indicated by the forward-looking statements. You should consider these risks and uncertainties when you are evaluating us.

Executive Overview

Noble is a leading offshore drilling contractor for the oil and gas industry. At ~~June~~September 30, 2011, our fleet consisted of 7679 mobile offshore drilling units located worldwide as follows: 14 semisubmersibles, 1314 drillships, 4749 jackups and two submersibles. ~~In addition,~~Additionally, we have one floating production storage and offloading unit (“FPSO”). At ~~June~~September 30, 2011, we had ~~11 of our 76~~13 units under construction. ~~Subsequent to June 30, 2011, we exercised options for the construction of two additional high-specification heavy duty, harsh environment jackup rigs.~~

Outlook

~~The overall~~During the third quarter of 2011, we began to see some stability in the offshore drilling market ~~has been volatile since the events occurring in connection with~~after a period of volatility, which occurred following theDeepwater Horizon,incident and the U.S. governmental response to the incident. In the U.S. Gulf of Mexico, the ~~lifting~~granting of ~~the moratorium~~permits and publication of new safety rules has led to ~~progress~~more stable activity levels within the industry itself, especially as it relates to the deepwater markets. This resumption of activity has led to greater investment within the Gulf of Mexico and is contributing to an improvement in ~~returning activity to more normal levels as indicated by the recent issuance of new drilling permits. However, while the issuance of a limited number of permits is a positive development,~~dayrates for deepwater and ultra-deepwater rigs worldwide. While there are ~~a number of ongoing~~still risks, ~~which make it difficult to predict whether or when industry activity in the U.S. Gulf will return to levels seen prior to the~~~~Deepwater Horizon~~ ~~incident. These risks include a current and ongoing risk of~~including potential third party environmental lawsuits targeting the permitting process, possible new drilling regulations, a failure of the Bureau of Ocean Energy Management Regulation and Enforcement (“BOEMRE”) to issue permits in a timely manner and the adoption by individual operators of new drilling or equipment standards exceeding those required by regulatory bodies. We believe those risks may be reduced as long as rigs continue to work without incident in the Gulf of Mexico.

~~Furthermore,~~The offshore drilling market displayed notable indications of improvement in the third quarter even though there ~~is continued~~continues to be uncertainty regarding the sustainability of the global economic recovery, which is proceeding unevenly in different geographic regions. In addition to the political instability in certain oil producing nations in the Middle East and North Africa, there is also uncertainty regarding ~~the sustainability of the~~ recovery in the credit markets, particularly in ~~Europe. In the U.S., the ongoing debate regarding debt levels has resulted in concerns around U.S. sovereign debt ratings, as well as a weakening of the dollar.~~Europe and North America. During the first ~~half~~nine months of 2011, oil ~~and gas~~ prices ~~increased~~fluctuated as a result of supply side concerns in response to political unrest in the Middle East and North Africa. Natural gas prices in the United States fluctuated during the first ~~half~~nine months of the year, but ended the period in-line with year-end 2010 pricing. We believe ~~these~~there continue to be competing factors ~~noted above may lead to instability~~which could impact the volatility in the ~~price~~offshore drilling market and the prices of ~~both~~oil and gas commodities for the foreseeable future.

~~Despite~~Even with the ~~increase~~instability in ~~commodity prices,~~the global economy noted above, we have ~~only recently~~ seen an increase in demand for offshore drilling ~~services. Developments~~services in the first nine months of 2011. While the risk of negative developments in the U.S. Gulf of Mexico ~~will~~could continue to have an impact on the deepwater market segment in the ~~short-term; however,~~short-term, we believe that the long-term outlook ~~is stronger.~~continues to strengthen. Market dayrates for new ultra-deepwater units remain generally above $450,000, which is significantly lower than the peak rates achieved in ~~2007-2008. However, short-term~~2007-2008, but higher than rates seen in 2010. Short-term fixtures for very high specification units ~~like the~~~~Noble Jim Day~~, have exceeded ~~$500,000.~~$500,000, and we believe this is an indication of where the market could be going should there continue to be a strong demand for ultra-deepwater drilling units. Although demand in the jackup segment decreased slightly during 2010, utilization rates for units ~~operating outside the U.S. Gulf of Mexico still averaged approximately 80 percent during~~stabilized in the first ~~half~~nine months of ~~2011.~~2011, especially for those units equipped with standard drilling features. We continue to see differentiation in the jackup market segment with newer units having utilization rates exceeding ~~90 percent, while~~those units that entered service before ~~2000 have utilization rates closer to 70 percent.~~2000. Likewise, there has been a bifurcation of dayrates between older and newer units in the jackup market with newer units earning a premium as customers display a preference for technologically advanced and efficient drilling alternatives. Dayrates for both older and newer units were relatively stable throughout the second half of 2010 and while we have seen some indications that rates in certain regions started to increase during the first half of 2011, rates in general are significantly lower than the peak rates reached in 2007 and 2008.

Demand for our drilling services generally depends on a variety of economic and political factors, including worldwide demand for oil and gas, the ability of the Organization of Petroleum Exporting Countries (“OPEC”) to set and maintain production levels and pricing, the level of production of non-OPEC countries and the policies of various governments addressing access to their oil and gas reserves. Our results of operations depend on offshore drilling activity worldwide. Historically, oil and gas prices and market expectations of potential changes in these prices have significantly affected that level of activity. Generally, higher oil and natural gas prices or our customers’ expectations of higher prices result in greater demand for our services. Demand for our services is also a function of the worldwide supply of mobile offshore drilling units. Industry analysts widely acknowledge that a significant expansion of industry supply of both jackups and ultra-deepwater units has commenced, the majority of which currently have no contract. The introduction of additional non-contracted rigs into the marketplace could have an adverse effect on demand for our services or the dayrates we are able to achieve.

In addition, as a result of exploration discoveries offshore Brazil, Petroleo Brasileiro S.A. (“Petrobras”), the Brazilian national oil company, announced a plan to construct up to 28 deepwater rigs in Brazil and accepted bids in 2010 to construct these units from a number of shipyards and drilling contractors. A deepwater drilling rig construction industry possessing the scope and experience to efficiently address this volume of work does not currently exist in Brazil and Noble did not participate in these bids primarily because we viewed the capital risk associated with constructing a unit in Brazil as inappropriate. Petrobras awarded the first tranche of seven drillships to a Brazilian shipyard for delivery beginning in 2015. In March 2011, Petrobras cancelled the bids for the remaining 21 newbuild units. In June 2011, Petrobras issued a new tender to build 21 ultra deepwater rigs in Brazil to operate with Petrobras under 10 to 15 year contracts with drilling operations commencing within 48 months after the contract is awarded. ~~Nevertheless,~~Petrobras opened the ~~future of Petrobras’ building program remains uncertain~~tenders late October 2011, receiving offers for the 21 rigs from local Brazilian and ~~the ultimate number of deepwater rigs to be built in Brazil is still unknown. While~~Norwegian based drillers, which Petrobras is currently ~~in the market tendering~~reviewing. Petrobras is also reviewing offers received for existing deepwater drilling ~~units, the~~units. The potential increase in supply from the Petrobras newbuilds could also adversely impact overall industry dayrates and economics.

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As of ~~June~~September 30, 2011, we ~~had 11 jackup units contracted~~have 12 rigs, including the deepwater semisubmersible rigNoble Max Smithunder contract in Mexico with Pemex Exploracion y Produccion (“Pemex”) ~~in Mexico, eight~~, and seven of ~~which~~these rigs have contracts scheduled to expire in 2011. Pemex ~~currently has outstanding tenders~~continues to tender for upadditional jackup rigs as they attempt to ~~20 jackup~~increase the number of working rigs. Some previous tenders published by Pemex contained a requirement that certain units must have entered service since the year 2000. While Pemex did not succeed in securing a significant number of newer rigs from those published tenders, we cannot predict whether this age requirement will be present in future Pemex tenders. If this requirement is present in future tenders, it could require us to seek work for our rigs in other locations, as the ages of our rigs currently operating in Mexico do not meet this requirement. If such work is not available, it could lead to additional idle time on some of our rigs. We cannot predict how many rigs might be affected or how long they could remain idle. We remain optimistic that many, if not all, of our rigs currently operating in Mexico will be able to continue to secure long-term work with Pemex.

In January 2011, we announced the signing of a Memorandum of Understanding (“MOU”) with Petrobras regarding operations in Brazil. Under the terms of the MOU, we would substitute the drillshipNoble Phoenix, then under contract with Royal Dutch Shell (“Shell”) in Southeast Asia, for the drillshipNoble Muravlenko. In January 2011, Shell agreed to release theNoble Phoenixfrom its contract, which was effective in March 2011. ~~The~~~~Noble Phoenix~~~~has undertaken limited contract preparations, after which the unit will mobilize to Brazil.~~ During the second quarter of 2011, Petrobras formally approved the rig substitution. We expect that acceptance of theNoble Phoenixwill take place in the ~~fourth~~first quarter of ~~2011.~~2012. In connection with the cancelation of the contract on theNoble Phoenix, we recognized a non-cash gain of approximately $52.5 million during the first quarter of 2011, which represents the unamortized fair value of the in-place contract assumed in connection with the Frontier acquisition.

In connection with our existing drilling contracts with Petrobras for two of our drillships operating in Brazil, we approved certain shipyard reliability upgrade projects for these drillships, theNoble Leo Segeriusand theNoble Roger Eason. These upgrade projects, planned through 2012, are designed to enhance the reliability and operational performance of these drillships. During the first quarter, theNoble Leo Segeriusentered a shipyard in Brazil for its reliability upgrade. There are a number of risks associated with shipyard projects of this nature, particularly in Brazil, including potential project delays and cost overruns because of labor, customs, local shipyard, local content and other issues. In addition, the drilling contracts for these vessels provide Petrobras with certain rights of termination in the event of excessive downtime, and it is possible that Petrobras could exercise this right in the future with respect to one or both of these drillships. We intend to continue to closely monitor and discuss with Petrobras the status of these projects and plan to take appropriate steps to mitigate identified risks, which depending upon the circumstances, could involve a variety of options.

~~On April 25, 2011, the~~~~Noble Discoverer~~~~was operating off the coast of New Zealand when a severe weather event occurred. In anticipation of the severe weather, and in accordance with established procedures for severe weather events, the~~~~Noble Discoverer~~suspended drilling operations and secured and disconnected from the well. As a result of severe weather, the riser and the lower marine riser package were damaged and released from the vessel. While we are still evaluating the extent of the equipment damage, we currently believe the damage will not be material. We believe we are entitled to continue receiving dayrate from our customer until repairs are complete, and we are discussing the implications of this event with our customer. We can make no assurances as to the outcome of this event. The~~Noble Discovereris currently anchored safely in a New Zealand harbor pending repairs.~~

While we cannot predict the future level of demand or dayrates for our drilling services or future conditions in the offshore contract drilling industry, we continue to believe we are well positioned within the industry and believe our acquisition of Frontier and recent newbuild announcements further strengthen our position, especially in deepwater drilling.

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Results and Strategy

In the ~~second~~third quarter of 2011, we recognized net income attributable to Noble-Swiss of ~~$54~~$135 million, or ~~$0.21~~$0.53 per diluted share, on total revenues of ~~$628~~$738 million. Sequential results of key metrics are as follows:


	Three Months Ended						Three Months Ended
	June 30,			March 31,			September 30,			June 30,
	2011			2011			2011			2011
Average dayrate	$	140,296		$	150,294		$	151,782		$	140,296
Average utilization		70	%		61	%		76	%		70	%
Daily contract drilling services costs	$	80,985		$	84,858		$	77,205		$	80,985
Contract drilling services margin		43	%		44	%		49	%		43	%

We have actively expanded our offshore drilling and deepwater capabilities in recent years through the construction of new rigs, and as part of this technical and operational expansion we plan to continue pursuing opportunities to ~~high-grade~~upgrade our ~~fleet.~~fleet to achieve greater technological capability, which would lead to increased drilling efficiencies. Our business strategy also focuses on the active expansion of our worldwide offshore drilling and deepwater capabilities through upgrades and modifications, acquisitions, divestitures of lower specification units and the deployment of our drilling assets in important oil and gas producing areas. At ~~June~~September 30, 2011, we continued our newbuild strategy with the following 1113 projects:

	•		two dynamically positioned, ultra-deepwater, harsh environmentGlobetrotter-class drillships, which are scheduled to be delivered in the fourth quarter of 2011 and the second quarter of 2013, respectively and complete acceptance testing in the first quarter of 2012 and the fourth quarter of 2013, respectively;

	•		~~two~~one dynamically positioned, ultra-deepwater, harsh environmentBully-class ~~drillships~~drillship owned through a joint venture with Shell which ~~are~~is scheduled to be delivered ~~and complete acceptance testing~~ in the fourth quarter of 2011 and complete acceptance testing in the first quarter of ~~2012, respectively;~~2012;

	•		three dynamically positioned, ultra-deepwater, harsh environment drillships under construction at Hyundai Heavy Industry which are estimated to be delivered from the shipyard and begin acceptance testing as follows: the second quarter of 2013, the fourth quarter of 2013, and the second quarter of 2014, respectively; and

	•		four high-specification heavy duty, harsh environment jackup rigs which are estimated to be delivered from the shipyard and begin acceptance testing as follows: first quarter of 2013, third quarter of 2013, fourth quarter of 2013 and first quarter of 2014, respectively.

four dynamically positioned, ultra-deepwater, harsh environment drillships under construction at Hyundai Heavy Industries Co. Ltd. which are estimated to be delivered from the shipyard to begin acceptance testing as follows: the second quarter of 2013, the fourth quarter of 2013, the second quarter of 2014, and the second half of 2014, respectively; and

six high-specification heavy duty, harsh environment jackup rigs which are estimated to be delivered from the shipyard to begin acceptance testing as follows: first quarter of 2013, third quarter of 2013, fourth quarter of 2013, first quarter of 2014, fourth quarter of 2014 and first quarter of 2015, respectively.

Of our 1113 rigs under construction as of ~~June~~September 30, 2011, ~~five~~four drillships and all six jackups are being constructed at a shipyard with a strong history of successful execution. Also, four of the drillships are contracted for five years or ~~more. The~~more, while the remaining ~~six~~nine rigs are being constructed without contracts. Subsequent to June 30, 2011, we exercised options for the construction of two additional high-specification heavy duty, harsh environment jackup rigs which are expected to be delivered from the shipyard during the third and fourth quarters of 2014; both rigs are currently being constructed without contracts. We have a priced option for an additional ultra-deepwater drillship.

As part of our business strategy, we continue to review our fleet and the strategic benefit of our lower specification units. ~~We believe that we need to continue to upgrade our fleet to achieve greater technological capability which would lead to increased drilling efficiencies.~~ As part of this process, we may ~~decide to~~ dispose of some of our lower specification units, and we are considering ~~a number of~~ potential options. We believe these units are maintained in a manner that would allow us to successfully continue to operate them should we decide this is the appropriate course of action based on available alternatives.

~~U.S. Gulf of Mexico Operations~~

~~Subsequent to the April 20, 2010 fire and explosion on the~~~~Deepwater Horizon~~, a competitor’s drilling rig in the U.S. Gulf of Mexico, U.S. governmental authorities implemented a moratorium on and suspension of specified types of drilling activities in the U.S. Gulf of Mexico.

The U.S. government lifted the moratorium following adoption of new regulations including a drilling safety rule and a workplace safety rule, each of which imposed multiple obligations relating to offshore drilling operations. These obligations relate to, among other things, additional certifications and verifications relating to compliance with applicable regulations; compatibility of blowout preventers with drilling rigs and well design; third-party inspections and design review of blowout preventers; testing of casing installations; minimum requirements for personnel operating blowout preventers; and training in deepwater well control.

In addition, the U.S. government has indicated that to receive a deepwater drilling permit, the operator must (i) demonstrate that containment resources are available promptly in the event of a deepwater blowout, (ii) have the chief executive officer of each operator certify that the operator has complied with all applicable regulations and (iii) allow the BOEMRE to conduct inspections of each deepwater drilling operation for compliance with the applicable regulations.

Our existing U.S. Gulf of Mexico operations have been, and will continue to be, negatively impacted by the events and governmental action described above. As of June 30, 2011, our U.S. Gulf of Mexico operations included seven deepwater drilling units. We have worked and continue to work closely with our customers for drilling services in the U.S. Gulf of Mexico to address the hardships imposed by the governmental actions described above. The discussion below briefly describes the current status of each of the seven drilling units.

	•		~~Noble Danny Adkins.~~The unit spent part of the second quarter operating under a permit and receiving full dayrate. However, during the quarter the rig was forced to make repairs to certain sub-sea equipment, resulting in significant down-time during the quarter.

	•		~~Noble Jim Day~~. In February 2011, this drilling unit went under contract for a subsidiary of Shell in the U.S. Gulf of Mexico, and received a reduced stand-by rate for the entire second quarter. On July 11, 2011, Shell received the necessary permits and this rig began operating under full dayrate.

	•		~~Noble Amos Runner.~~~~This unit recently completed its contract with LLOG Exploration, LLC and is currently seeking opportunities both inside and outside the U.S. Gulf of Mexico.~~

	•		~~Noble Jim Thompson.~~~~During April 2011, this unit began operating under its full operating dayrate with Shell following approval of the required drilling permits.~~

	•		~~Noble Paul Romano.~~~~The unit recently received a contract and is expected to begin operating outside the U.S. Gulf of Mexico in the fourth quarter of 2011.~~

	•		~~Noble Driller~~. This unit received its blow out preventer certification in July 2011 upon completion of a shipyard project. This unit is under contract with Shell and is receiving full dayrate as of August 1, 2011.

	•		~~Noble Lorris Bouzigard~~~~. This drilling unit is currently cold stacked, but is being actively marketed to potential customers.~~

Acquisition of FDR Holdings Limited

On July 28, 2010, Noble-Swiss and Noble AM Merger Co., a Cayman Islands company and indirect wholly-owned subsidiary of Noble-Swiss (“Merger Sub”), completed the acquisition of FDR Holdings Limited, a Cayman Islands company (“Frontier”). Under the terms of the Agreement and Plan of Merger with Frontier and certain of Frontier’s shareholders, Merger Sub merged with and into Frontier, with Frontier surviving as an indirect wholly-owned subsidiary of Noble-Swiss and a wholly-owned subsidiary of Noble-Cayman. The Frontier acquisition was for a purchase price of approximately $1.7 billion in cash plus liabilities assumed and strategically expanded and enhanced our global ~~fleet by adding three dynamically positioned drillships (including two~~~~Bully~~~~-class joint venture-owned drillships under construction), two conventionally moored drillships, including one that is Arctic-class, a conventionally moored deepwater semisubmersible and one FPSO.~~fleet. Frontier’s results of operations were included in our results beginning July 28, 2010. We funded the cash consideration paid at closing of approximately $1.7 billion using proceeds from our July 2010 offering of senior notes and existing cash on hand.

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Contract Drilling Services Backlog

We maintain a backlog (as defined below) of commitments for contract drilling services. The following table sets forth as of ~~June~~September 30, 2011 the amount of our contract drilling services backlog and the percent of available operating days committed for the periods indicated:


			Year Ending December 31,																	Year Ending December 31,
	Total		2011 (1)			2012			2013			2014			2015-2023			Total		2011 (1)			2012			2013			2014			2015-2023
	(In millions)																						(In millions)
Contract Drilling Services Backlog
Semisubmersibles/Drillships (2) (6) (7)	$	11,388	$	886		$	1,683		$	1,667		$	1,780		$	5,372		$	11,219	$	519		$	1,865		$	1,665		$	1,780		$	5,390
Jackups/Submersibles (3)		1,559		556			579			287			134			3			1,619		296			750			386			184			3
Other		—		—			—			—			—			—

Total (4)	$	12,947	$	1,442		$	2,262		$	1,954		$	1,914		$	5,375		$	12,838	$	815		$	2,615		$	2,051		$	1,964		$	5,393

Percent of Available Operating Days Committed (5)				73	%		43	%		28	%		22	%		5	%
Percent of Available Operating Days
Committed (5)																					81	%		53	%		33	%		24	%		5	%


(1)		Represents a ~~six-month~~three-month period beginning ~~July~~October 1, 2011.

(2)		Our drilling contracts with Petrobras provide an opportunity for us to earn performance bonuses based on downtime experienced for our rigs operating offshore Brazil. With respect to our semisubmersibles operating offshore Brazil for Petrobras, we have included in our backlog an amount equal to 75 percent of potential performance bonuses for such semisubmersibles, which amount is based on and generally consistent with our historical earnings of performance bonuses for these rigs. With respect to our drillships presently operating offshore Brazil for Petrobras, ~~offshore Brazil,~~ we (a) have not included in our backlog any performance bonuses for periods prior to the commencement of certain upgrade projects planned for 2011 through 2012, which projects are designed to enhance the reliability and operational performance of ~~our~~these drillships, and (b) have included in our backlog an amount equal to 75 percent of potential performance bonuses for periods after the estimated completion of such upgrade projects. Our backlog for semisubmersibles/drillships includes approximately ~~$278~~$266 million attributable to these performance bonuses.

		The drilling contracts with Shell for theNoble Globetrotter I,Noble Globetrotter II,Noble Jim Thompson,Noble Jim DayandNoble Clyde Boudreaux, as well as the letter of intent for the unnamedHHI Drillship I, provide opportunities for us to earn performance bonuses based on key performance indicators as defined by Shell. With respect to these contracts, we have included in our backlog an amount equal to 75 percent of the potential performance bonuses for these ~~rigs.~~rigs, except for theNoble Clyde Boudreauxwhere limited bonus is expected. Our backlog for these rigs includes approximately ~~$496~~$480 million attributable to these performance bonuses.

(3)		Our drilling contracts with Pemex for certain jackups operating offshore in Mexico are subject to price review and adjustment of the rig dayrate. Presently, the contract for one jackup has a dayrate indexed to the world average of the highest dayrates published by ODS-Petrodata. After an initial firm dayrate period, the dayrate is generally adjusted quarterly based on formulas calculated from the index. Our contract drilling services backlog has been calculated using the ~~May 31,~~September 30, 2011 index-based dayrate for periods subsequent to the firm dayrate period.


(4)		a) Pemex has the ability to cancel its drilling contracts on 30 days or less notice without Pemex’s making an early termination payment. ~~At June~~As of September 30, 2011, we had twelve rigs contracted to Pemex in Mexico, plus one additional rig scheduled to go to work for Pemex in late December 2011, and our backlog includes approximately ~~$251~~$387 million related to such ~~contracts. Also, our~~contracts at September 30, 2011.


b)		Our drilling contracts generally provide the customer an early termination right in the event we fail to meet certain performance standards, including downtime thresholds. For example, Petrobras has the right to terminate its contracts in the event of excessive downtime. While we do not currently anticipate any cancellations as a result of events that have occurred to date, clients may from time to time have the contractual right to do ~~so.~~so, which is the case with the drilling contracts for theNoble Dave Beardand theNoble Paul Wolff. However, we have not received any notification concerning contract cancellations to date.


(5)		Percentages take into account additional capacity from the estimated dates of deployment of our newbuild rigs that are scheduled to commence operations during 2011 through ~~2014.~~2015.

(6)		It is not possible to accurately determine the impact to our revenues or backlog resulting from efforts by operators to cancel or modify drilling contracts ~~because of the~~due to U.S. government imposed restrictions and the ~~vigorous~~rigorous scrutiny for issuance of new drilling permits, and other consequences of ~~the~~ actions by the U.S. government. At ~~June~~September 30, 2011, backlog related to our U.S. Gulf of Mexico deepwater rigs totaled $5.5 billion, ~~$334~~$206 million of which represents backlog for the ~~six-month~~three-month period ending December 31, 2011.

		We entered into an agreement with Shell, effective June 27, 2010, which provides that Shell may suspend the contracts on three of our units operating in the U.S. Gulf of Mexico during any period of regulatory restriction by paying reduced suspension dayrates in lieu of the normal operating dayrates. The term of the initial contract is also extended by the suspension period. The impact of this agreement is to shift backlog among periods with an immaterial increase to total backlog because of the reduced suspension rates.

(7)		Noble and a subsidiary of Shell are involved in joint venture agreements to build, operate, and own both theNoble Bully Iand theNoble Bully II. Pursuant to these agreements, each party has an equal 50 percent share in both vessels. As of ~~June~~September 30, 2011, the combined amount of backlog for these rigs ~~totals~~totaled $2.4 billion, all of which is included in our backlog. Noble’s net interest in the backlog for these rigs iswas $1.2 billion.

Our contract drilling services backlog reported above reflects estimated future revenues attributable to both signed drilling contracts and letters of intent that we expect will become binding contracts. A letter of intent is generally subject to customary conditions, including the execution of a definitive drilling contract. For a number of reasons, it is possible that some customers that have entered into letters of intent will not enter into signed drilling contracts. We calculate backlog for any given unit and period by multiplying the full contractual operating dayrate for such unit by the number of days remaining in the period. The reported contract drilling services backlog does not include amounts representing revenues for mobilization, demobilization and contract preparation, which are not expected to be significant to our contract drilling services revenues, amounts constituting reimbursables from customers or amounts attributable to uncommitted option periods under drilling contracts or letters of intent.

The amount of actual revenues earned and the actual periods during which revenues are earned may be different than the backlog amounts and backlog periods set forth in the table above for various factors, including, but not limited to, shipyard and maintenance projects, operational downtime, weather conditions, bonuses and other factors that result in applicable dayrates lower than the full contractual operating dayrate. In addition, amounts included in the backlog may change because drilling contracts may be varied or modified by mutual consent or customers may exercise early termination rights contained in some of our drilling contracts or decline to enter into a drilling contract after executing a letter of intent. As a result, our backlog as of any particular date may not be indicative of our actual operating results for the subsequent periods for which the backlog is calculated.

As of ~~June~~September 30, 2011, we estimate Shell and Petrobras represented approximately ~~64%~~63% and ~~23%~~22%, respectively, of our backlog.

Internal Investigation

In 2007, we began, and voluntarily contacted the SEC and the U.S. Department of Justice (“DOJ”) to advise them of, an internal investigation of the legality under the United States Foreign Corrupt Practices Act (“FCPA”) and local laws of certain reimbursement payments made by our Nigerian affiliate to our customs agents in Nigeria. In 2010, we finalized settlements of this matter with each of the SEC and the DOJ. Pursuant to these settlements, we agreed to pay fines and penalties to the DOJ and the SEC and to certain undertakings, including refraining from violating the FCPA and other anti-corruption laws, self-reporting any violations of the FCPA or such laws to the DOJ and reporting to the DOJ on an annual basis our progress on anti-corruption compliance matters. Our ability to comply with the terms of the settlements is dependent on the success of our ongoing compliance program, including our ability to continue to manage our agents and supervise, train and retain competent employees, and the efforts of our employees to comply with applicable law and our code of business conduct and ethics.

In January 2011, the Nigerian Economic and Financial Crimes Commission and the Nigerian Attorney General Office initiated an investigation into these same activities. A subsidiary of Noble-Swiss resolved this matter through the execution of a non-prosecution agreement dated January 28, 2011. Pursuant to this agreement, the subsidiary paid $2.5 million to resolve all charges and claims of the Nigerian Government. Any similar investigations or charges and any additional sanctions we may incur could damage our reputation and result in substantial fines, sanctions, civil and/or criminal penalties and curtailment of operations in certain jurisdictions and might adversely affect our business, results of operations or financial condition. Further, resolving any such investigation could be expensive and consume significant time and attention of our senior management.

In 2010, the Nigerian Oil and Gas Industry Content Development Bill was signed into law. The law is designed to create Nigerian content in operations and transactions within the Nigerian oil and gas industry. The law sets forth certain requirements for the utilization of Nigerian human resources and goods and services in oil and gas projects and creates a Nigerian Content Development and Monitoring Board (“NCD Board”) to implement and monitor the law and develop regulations pursuant to the law. The law also establishes a Nigerian Content Development Fund to fund the implementation of the law. The implementation of the law is ongoing and both the manner and timing of final implementation is uncertain. We have participated in a number of meetings with the NCD Board and are analyzing how we might reorganize our operations in Nigeria to meet these requirements, including creating third party ~~minority~~noncontrolling interests in our operating assets. We cannot predict the impact the new law may have on our existing or future operations in Nigeria, but our operations there could be significantly and adversely affected.

Results of Operations

For the Three Months Ended ~~June~~September 30, 2011 and 2010

General

Net income attributable to Noble Corporation (Noble-Swiss) for the three months ended ~~June~~September 30, 2011 (the “Current Quarter”) was ~~$54~~$135 million, or ~~$0.21~~$0.53 per diluted share, on operating revenues of ~~$628~~$738 million, compared to net income for the three months ended ~~June~~September 30, 2010 (the “Comparable Quarter”) of ~~$218~~$86 million, or ~~$0.85~~$0.34 per diluted share, on operating revenues of ~~$710~~$613 million.

The consolidated financial statements of Noble-Swiss include the accounts of Noble-Cayman, and Noble-Swiss conducts substantially all of its business through Noble-Cayman and its subsidiaries. As a result, the financial position and results of operations for Noble-Cayman, and the reasons for material changes in the amount of revenue and expense items between 2011 and 2010, would be the same as the information presented below regarding Noble-Swiss in all material respects, except operating income for Noble-Cayman for the three months ended ~~June~~September 30, 2011 was ~~$14~~$19 million higher than operating income for Noble-Swiss for the same period, primarily as a result of depreciation related to Swiss-owned assets and operating costs directly attributable to Noble-Swiss for stewardship related services.

Rig Utilization, Operating Days and Average Dayrates

Operating revenues and operating costs and expenses for our contract drilling services segment are dependent on three primary metrics — rig utilization, operating days and dayrates. The following table sets forth the average rig utilization, operating days and average dayrates for our rig fleet for the three months ended ~~June~~September 30, 2011 and 2010:


	Average Rig						Operating									Average
	Utilization (1)						Days (2)									Dayrates									Average Rig					Operating					Average
	Three Months Ended						Three Months Ended									Three Months Ended									Utilization (1)					Days (2)					Dayrates
	June 30,						June 30,									June 30,									Three Months Ended					Three Months Ended					Three Months Ended
	2011			2010			2011			2010			% Change			2011			2010			% Change			September 30,					September 30,					September 30,
			2011			2010			2011			2010			%Change			2011			2010			%Change
Jackups		71	%		81	%		2,797			3,183			-12	%	$	80,742		$	96,677			-16	%		82	%	77	%		3,229	3,032	6	%	$	89,352	$	90,791	-2	%
Semisubmersibles		85	%		94	%		1,088			1,023			6	%		269,798			328,286			-18	%		84	%	90	%		1,086	1,057	3	%		315,034		172,727	82	%
Drillships		58	%		67	%		317			182			74	%		220,953			242,045			-9	%		60	%	100	%		329	468	-30	%		225,669		229,963	-2	%
FPSO/Submersibles		0	%		0	%		—			—			—			—			—			—			0	%	26	%		—	64	—			—		304,000	—

Total		70	%		80	%		4,202			4,388			-4	%	$	140,296		$	156,683			-10	%		76	%	79	%		4,644	4,621	0	%	$	151,782	$	126,581	20	%


(1)		Information reflects our policy of reporting on the basis of the number of rigs in our fleet excluding newbuild rigs under construction.

(2)		Information reflects the number of days that our rigs were operating under contract.

Contract Drilling Services

The following table sets forth the operating revenues and the operating costs and expenses for our contract drilling services segment for the three months ended ~~June~~September 30, 2011 and 2010 (in thousands):


	Three Months Ended										Three Months Ended
	June 30,				Change						September 30,				Change
	2011		2010		$			%			2011		2010		$			%
Operating revenues:
Contract drilling services	$	589,550	$	687,510	$	(97,960	)		-14	%	$	704,892	$	584,919	$	119,973			21	%
Reimbursables (1)		22,982		12,989		9,993			77	%		14,646		18,488		(3,842	)		-21	%
Other		313		603		(290	)		-48	%		8		635		(627	)		-99	%

	$	612,845	$	701,102	$	(88,257	)		-13	%	$	719,546	$	604,042	$	115,504			19	%

Operating costs and expenses:
Contract drilling services	$	336,728	$	275,595	$	61,133			22	%	$	358,547	$	315,844	$	42,703			14	%
Reimbursables (1)		17,606		9,626		7,980			83	%		11,362		13,696		(2,334	)		-17	%
Depreciation and amortization		159,843		123,379		36,464			30	%		162,837		140,199		22,638			16	%
Selling, general and administrative		21,359		23,561		(2,202	)		-9	%		27,212		25,220		1,992			8	%
												559,958		494,959		64,999			13	%
		535,536		432,161		103,375			24	%

Operating income	$	77,309	$	268,941	$	(191,632	)		-71	%	$	159,588	$	109,083	$	50,505			46	%


(1)		We record reimbursements from customers for out-of-pocket expenses as operating revenues and the related direct costs as operating expenses. Changes in the amount of these reimbursables generally do not have a material effect on our financial position, results of operations or cash flows.

Operating Revenues.~~Decreases~~Increases in contract drilling services revenues for the Current Quarter as compared to the Comparable Quarter were driven by ~~reductions~~increases in both average dayrates and operating days. The 1020 percent ~~decline~~increase in average dayrates ~~reduced~~increased revenues by approximately ~~$69~~$117 million, and the ~~4 percent decline~~slight increase in operating days ~~decreased~~increased revenues by an additional ~~$29~~$3 million.

The ~~decrease~~increase in contract drilling services revenues primarily relates to our ~~jackups~~semisubmersibles and ~~semisubmersibles,~~jackups, which generated approximately ~~$82~~$160 million and ~~$42~~$13 million ~~less~~more revenue, respectively, in the Current Quarter.

The ~~decrease~~increase in ~~jackup~~semisubmersible average dayrates ~~of 16 percent~~ resulted in a ~~$45~~$155 million ~~decrease~~increase in revenues from the Comparable ~~Quarter. The reduction in dayrates was primarily from~~Quarter while the contractual re-pricing of rigs in the Middle East, the North Sea, and Mexico for changes in market conditions in the global shallow water market. The 12 percent decline in jackup operating days resulted in a $37 million decline in revenues. The decrease in utilization primarily related to rigs coming off of contract in Mexico and returning to work for only a portion of the Current Quarter.

~~The decrease in semisubmersible dayrates of 18 percent resulted in a $64 million decrease in revenues from the Comparable Quarter. This decline was partially offset by a 6 percent~~ increase in operating days ~~which added $22~~of three percent resulted in an additional $5 million increase in ~~revenue.~~revenues. The ~~decrease~~increase in semisubmersibles revenue is a result of drilling restrictions in the U.S. Gulf of Mexico in the Comparable Quarter, where lower standby rates replaced the standard operating dayrates for a majority of our contracts. The increase in operating days is primarily from theNoble Jim Dayand theNoble ~~Driller~~Homer Ferrington,which were added to the fleet subsequent to ~~June~~September 30, 2010.

The ~~decreases~~six percent increase in jackup operating days resulted in an $18 million increase in revenues, which was partially offset by a decrease in jackup average dayrates of two percent which resulted in a $5 million decrease in revenues from the Comparable Quarter. The increase in utilization primarily related to rigs in Mexico that commenced contracts in the second quarter of 2011 and operated for the entire Current Quarter. The reduction in average dayrates resulted primarily from the contractual re-pricing of rigs in the Middle East, the North Sea, and Mexico for changes in market conditions in the global shallow water market.

The increases in revenue for the above rig classes were partially offset by ~~higher~~lower revenues from our drillships ~~which increased $26~~and FPSO/submersibles. Revenue from our drillships decreased $33 million in the Current Quarter as compared to the Comparable Quarter. The ~~increase~~decrease was primarily attributable to a number of rigs being in the shipyard or stacked during the Current Quarter. Revenue from our FPSO, the ~~drillship~~Noble ~~Discoverer,~~Seillean~~which was added to~~, decreased $20 million as it did not operate in the ~~fleet as part of the Frontier acquisition and an increase in operating days amongst our drillships operating in Brazil.~~Current Quarter.

Operating Costs and Expenses.Contract drilling services operating costs and expenses increased ~~$61~~$43 million for the Current Quarter as compared to the Comparable Quarter. In addition to the ~~acquisition~~rigs added to the fleet as part of the Frontier ~~our newbuild rig,~~acquisition, theNoble Jim Day, was placed into service in January 2011. These additional units added approximately ~~$45~~$15 million of operating costs in the Current Quarter. Excluding the additional expenses related to these rigs, our contract drilling costs increased ~~$16~~$28 million in the Current Quarter from the Comparable Quarter. This change was primarily driven by an $8$11 million increase in ~~fuel,~~labor and a $10 million increase in mobilization, transportation and ~~start-up~~fuel costs ~~for~~related to rigs returning, or preparing to return, to work in the Current Quarter, a ~~$3 million increase in rotation costs, a $3 million increase in labor costs from salary increases and a $2~~$4 million increase in safety and training costs and a $3 million increase in rotation costs.

The increase in depreciation and amortization in the Current Quarter from the Comparable Quarter was primarily attributable to depreciation on theNoble Jim Day,,rigs added to the ~~addition~~fleet as part of the Frontier ~~rigs~~acquisition and additional depreciation related to other capital expenditures on our fleet since the Comparable Quarter.

Other

The following table sets forth the operating revenues and the operating costs and expenses for our other services for the three months ended ~~June~~September 30, 2011 and 2010:


	Three Months Ended										Three Months Ended
	June 30,					Change					September 30,					Change
	2011		2010			$		%			2011		2010			$		%
Operating revenues:
Labor contract drilling services	$	14,012	$	8,056		$	5,956		74	%	$	15,564	$	7,887		$	7,677		97	%
Reimbursables (1)		1,140		764			376		49	%		2,792		689			2,103		305	%

	$	15,152	$	8,820		$	6,332		72	%	$	18,356	$	8,576		$	9,780		114	%

Operating costs and expenses:
Labor contract drilling services	$	8,750	$	5,380		$	3,370		63	%	$	8,053	$	5,302		$	2,751		52	%
Reimbursables (1)		1,117		739			378		51	%		2,609		655			1,954		298	%
Depreciation and amortization		3,276		2,848			428		15	%		3,376		3,083			293		10	%
Selling, general and administrative		273		247			26		11	%		324		262			62		24	%
												14,362		9,302			5,060		54	%
		13,416		9,214			4,202		46	%

Operating (loss) income	$	1,736	$	(394	)	$	2,130		**		$	3,994	$	(726	)	$	4,720		*	*


(1)		We record reimbursements from customers for out-of-pocket expenses as operating revenues and the related direct costs as operating expenses. Changes in the amount of these reimbursables generally do not have a material effect on our financial position, results of operations or cash flows.

**		Not a meaningful percentage

Operating Revenues and Costs and Expenses.The increase in both revenue and expense primarily relates to the ~~recent expansion~~commencement of a refurbishment project with our customer, Shell, for one of its rigs to be operated under a labor contract ~~services~~ in Alaska, combined with operational increases and foreign ~~exchange~~currency fluctuations in our Canadian operations.

The increase in depreciation is for additional corporate-related assets placed in service since the Comparable Quarter.

Other Income and Expenses

Selling, General and Administrative Expenses.Consolidated selling, general and administrative expenses ~~decreased~~increased $2 million in the Current Quarter as compared to the Comparable Quarter. The ~~decrease~~increase relates to a $3 million increase in ongoing legal and tax expenses ~~of $5~~and a $2 million increase in employee-related and miscellaneous costs in the Current Quarter, partially offset by a $3 million decrease related to our FCPA investigation in the Comparable ~~Quarter, partially offset by a $3 million increase in legal, audit and other expenses in the Current~~ Quarter.

Interest Expense, net of amount capitalized.Interest expense, net of amount capitalized, increased ~~$14~~$7 million in the Current Quarter as compared to the Comparable Quarter. The increase is a result of $1.25 billion of debt issued in July 2010, which was used to partially fund the Frontier acquisition, ~~and~~ $1.1 billion of debt issued in February 2011, which was primarily used to repay the outstanding balance on our revolving credit facility and to repay our portion of outstanding debt under the joint venture credit facilities, and the $715 million currently drawn on our credit facilities.

Income Tax Provision.Our income tax provision decreased ~~$42~~$3 million in the Current Quarter primarily ~~from~~as a ~~decline in pre-tax earnings~~result of ~~approximately 76 percent, which reduced income tax expense by approximately $39 million in the Current Quarter. Contributing to the decrease was~~ a lower effective tax rate of 1512 percent in the Current Quarter as compared to 19 percent in the Comparable Quarter, which decreased income tax expense by approximately $3$12 million. The decrease in the effective tax rate was a result of certain discrete tax items totaling approximately $11 million. Partially offsetting the ~~resolution~~decrease is an increase in pre-tax earnings of ~~uncertain~~approximately 43 percent, which increased income tax ~~positions of~~expense by approximately $9 million ~~partially offset by changes in our geographic revenue mix primarily resulting from drilling restrictions~~ in the ~~U.S. Gulf of Mexico.~~Current Quarter.

4847

For the ~~Six~~Nine Months Ended ~~June~~September 30, 2011 and 2010

General

Net income attributable to Noble Corporation (Noble-Swiss) for the ~~six~~nine months ended ~~June~~September 30, 2011 (the “Current Period”) was ~~$109~~$244 million, or ~~$0.43~~$0.96 per diluted share, on operating revenues of ~~$1.2~~$1.9 billion, compared to net income for the ~~six~~nine months ended ~~June~~September 30, 2010 (the “Comparable Period”) of ~~$589~~$675 million, or ~~$2.28~~$2.62 per diluted share, on operating revenues of ~~$1.6~~$2.2 billion.

The consolidated financial statements of Noble-Swiss include the accounts of Noble-Cayman, and Noble-Swiss conducts substantially all of its business through Noble-Cayman and its subsidiaries. As a result, the financial position and results of operations for Noble-Cayman, and the reasons for material changes in the amount of revenue and expense items between 2011 and 2010, would be the same as the information presented below regarding Noble-Swiss in all material respects, except operating income for Noble-Cayman for the ~~six~~nine months ended ~~June~~September 30, 2011 was ~~$27~~$46 million higher than operating income for Noble-Swiss for the same period, primarily as a result of depreciation related to Swiss owned assets and operating costs directly attributable to Noble-Swiss for stewardship related services.

Rig Utilization, Operating Days and Average Dayrates

Operating revenues and operating costs and expenses for our contract drilling services segment are dependent on three primary metrics — rig utilization, operating days and dayrates. The following table sets forth the average rig utilization, operating days and average dayrates for our rig fleet for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010:


	Average Rig						Operating							Average							Average Rig						Operating							Average
	Utilization (1)						Days (2)							Dayrates							Utilization (1)						Days (2)							Dayrates
	Six Months Ended						Six Months Ended							Six Months Ended							Nine Months Ended						Nine Months Ended							Nine Months Ended
	June 30,						June 30,							June 30,							September 30,						September 30,							September 30,
	2011			2010			2011		2010		% Change			2011		2010		% Change			2011			2010			2011		2010		%Change			2011		2010		%Change
Jackups		67	%		81	%		5,178		6,324		-18	%	$	80,799	$	106,522		-24	%		72	%		80	%		8,407		9,357		-10	%	$	84,084	$	101,424		-17	%
Semisubmersibles		77	%		93	%		1,956		1,954		0	%		273,374		370,358		-26	%		80	%		92	%		3,042		3,010		1	%		288,246		300,971		-4	%
Drillships		62	%		79	%		678		429		58	%		263,905		230,679		14	%		61	%		89	%		1,007		897		12	%		251,421		230,306		9	%
FPSO/Submersibles		0	%		0	%		—		—		—			—		—		—			0	%		10	%		—		64		—			—		303,056		—

Total		65	%		81	%		7,812		8,707		-10	%	$	144,916	$	171,828		-16	%		69	%		80	%		12,456		13,328		-7	%	$	147,476	$	156,142		-6	%


(1)		Information reflects our policy of reporting on the basis of the number of rigs in our fleet excluding newbuild rigs under construction.

(2)		Information reflects the number of days that our rigs were operating under contract.

4948

Contract Drilling Services

The following table sets forth the operating revenues and the operating costs and expenses for our contract drilling services segment for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010 (in thousands):


	Six Months Ended											Nine Months Ended
	June 30,					Change						September 30,					Change
	2011			2010		$			%			2011			2010		$			%
Operating revenues:
Contract drilling services	$	1,132,155		$	1,496,156	$	(364,001	)		-24	%	$	1,837,047		$	2,081,075	$	(244,028	)		-12	%
Reimbursables (1)		44,586			36,292		8,294			23	%		59,232			54,780		4,452			8	%
Other		758			814		(56	)		-7	%		766			1,449		(683	)		-47	%

	$	1,177,499		$	1,533,262	$	(355,763	)		-23	%	$	1,897,045		$	2,137,304	$	(240,259	)		-11	%

Operating costs and expenses:
Contract drilling services	$	643,091		$	530,026	$	113,065			21	%	$	1,001,638		$	845,870	$	155,768			18	%
Reimbursables (1)		34,046			28,495		5,551			19	%		45,408			42,191		3,217			8	%
Depreciation and amortization		314,731			236,553		78,178			33	%		477,568			376,754		100,814			27	%
Selling, general and administrative		44,808			45,303		(495	)		-1	%		72,020			70,523		1,497			2	%
(Gain)/Loss on contract extinguishment		(21,202	)		—		(21,202	)		**			(21,202	)		—		(21,202	)		*	*

		1,015,474			840,377		175,097			21	%		1,575,432			1,335,338		240,094			18	%

Operating income	$	162,025		$	692,885	$	(530,860	)		-77	%	$	321,613		$	801,966	$	(480,353	)		-60	%


(1)		We record reimbursements from customers for out-of-pocket expenses as operating revenues and the related direct costs as operating expenses. Changes in the amount of these reimbursables generally do not have a material effect on our financial position, results of operations or cash flows.

**		Not a meaningful percentage

Operating Revenues.Decreases in contract drilling services revenues for the Current Period as compared to the Comparable Period were driven by reductions in both average dayrates and operating days. The 16six percent decrease in average dayrates reduced revenues by approximately ~~$210~~$108 million, and the 10seven percent decrease in operating days decreased revenues by an additional ~~$154~~$136 million.

The decrease in contract drilling services revenues primarily relates to our jackups, semisubmersibles and ~~semisubmersibles,~~FPSO/submersibles, which generated approximately ~~$255~~$242 million, $29 million and ~~$189~~$19 million less revenue, respectively, in the Current Period.

The decrease in jackup average dayrates of 2417 percent resulted in a ~~$133~~$146 million decrease in revenues from the Comparable Period. The reduction in average dayrates was primarily from the contractual re-pricing of rigs in the Middle East, the North Sea, and Mexico for changes in market conditions in the global shallow water market. The 1810 percent decline in jackup operating days resulted in a ~~$122~~$96 million decline in revenues. The decrease in utilization primarily related to rigs coming off of contract in Mexico during the first quarter of 2011, the majority of which did not return to work until ~~late in~~ the second quarter.

The decrease in semisubmersible dayrates of 26four percent resulted in the ~~$189~~$38 million decrease in revenues from the Comparable Period. The decrease in semisubmersibles revenue is a result of drilling restrictions in the U.S. Gulf of Mexico where lower standby rates replaced the standard operating dayrates for a majority of our ~~contracts.~~contracts during the first half of the year. These decreases were partially offset by a $9 million increase in revenues during the Current Period driven by 32 additional operating days.

Revenue from our FPSO, theNoble Seillean, decreased $19 million as it did not operate in the Current Period.

The decreases in revenue for the above rig classes were partially offset by ~~higher revenues~~an increase in revenue of $47 million from our ~~drillships,~~drillships. The increase was primarily attributable to a nine percent increase in average dayrates and 12 percent increase in operating days, which ~~increased $80 million~~contributed additional revenue in the Current Period ~~as compared to the Comparable Period.~~of $21 million and $25 million, respectively. The increase ~~was~~is primarily attributable to operations from the drillships~~Noble Discovererand the~~~~Noble Phoenix~~~~, which were~~ added to the fleet as part of the Frontier acquisition. ~~These drillships contributed an additional $60 million in revenue, while the drillships operating in Brazil added an additional $20 million in revenue.~~

Operating Costs and Expenses.Contract drilling services operating costs and expenses increased ~~$113~~$156 million for the Current Period as compared to the Comparable Period. In addition to the ~~acquisition~~rigs added to the fleet as part of the Frontier acquisition, theNoble Dave Beardand theNoble Jim Daywere placed into service in March 2010 and January 2011, respectively. These additions added approximately ~~$89~~$108 million of operating costs in the Current Period. Excluding the additional expenses related to these rigs, our contract drilling costs increased ~~$24~~$48 million in the Current Period from the Comparable Period. This change was primarily driven by ~~an $18~~a $13 million increase in maintenance and rig-related expense, $12 million increase in mobilization costs, $8 million increase in fuel and transportation costs and ~~start-up~~$3 million increase in labor costs related to our rigs returning, or preparing to return, to work in Brazil and Mexico, ~~coupled with an $11~~$6 million increase in ~~maintenance expense, partially offset by a $5~~rotation costs and $6 million ~~decrease~~increase in ~~labor~~safety and ~~other costs resulting from the decrease in overall rig utilization.~~training costs.

The increase in depreciation and amortization in the Current Period from the Comparable Period was primarily attributable to depreciation on newbuilds added to the fleet, the addition of the Frontier rigs and additional depreciation related to other capital expenditures on our fleet since the Comparable Period.

Other

The following table sets forth the operating revenues and the operating costs and expenses for our other services for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010:


	Six Months Ended										Nine Months Ended
	June 30,					Change					September 30,					Change
	2011		2010			$		%			2011		2010			$		%
Operating revenues:
Labor contract drilling services	$	27,559	$	15,817		$	11,742		74	%	$	43,123	$	23,704		$	19,419		82	%
Reimbursables (1)		1,827		1,694			133		8	%		4,619		2,383			2,236		94	%

	$	29,386	$	17,511		$	11,875		68	%	$	47,742	$	26,087		$	21,655		83	%

Operating costs and expenses:
Labor contract drilling services	$	17,273	$	11,268		$	6,005		53	%	$	25,326	$	16,570		$	8,756		53	%
Reimbursables (1)		1,780		1,613			167		10	%		4,389		2,268			2,121		94	%
Depreciation and amortization		6,510		5,531			979		18	%		9,886		8,612			1,274		15	%
Selling, general and administrative		539		476			63		13	%		863		738			125		17	%

		26,102		18,888			7,214		38	%		40,464		28,188			12,276		44	%

Operating (loss) income	$	3,284	$	(1,377	)	$	4,661		**		$	7,278	$	(2,101	)	$	9,379		*	*


(1)		We record reimbursements from customers for out-of-pocket expenses as operating revenues and the related direct costs as operating expenses. Changes in the amount of these reimbursables generally do not have a material effect on our financial position, results of operations or cash flows.

**		Not a meaningful percentage

Operating Revenues and Costs and Expenses.The increase in both revenue and expense primarily relates to the ~~recent expansion~~initial start-up costs and commencement of a refurbishment project with our customer, Shell, for one of its rigs to be operated under a labor contract ~~services~~ in Alaska, ~~during the Current Period,~~ combined with operational increases and foreign ~~exchange~~currency fluctuations in our existing Canadian operations.

The increase in depreciation is for additional corporate-related assets placed in service since the Comparable Period.

Other Income and Expenses

Selling, General and Administrative Expenses.Consolidated selling, general and administrative expenses increased $2 million in the Current Period as compared to the Comparable Period. The increase relates to a $5 million increase in ongoing legal and tax expenses and a $3 million increase in employee-related and miscellaneous costs in the Current Period, partially offset by a $6 million decrease related to our FCPA investigation in the Comparable Period.

Interest Expense, net of amount capitalized.Interest expense, net of amount capitalized, increased ~~$33~~$40 million in the Current Period as compared to the Comparable Period. The increase is a result of $1.25 billion of debt issued in July 2010, which was used to partially fund the Frontier acquisition, ~~and~~ $1.1 billion of debt issued in February 2011, which was primarily used to repay the outstanding balance on our revolving credit facility and to repay our portion of outstanding debt under the joint venture credit facilities, and Current Period drawdowns on the credit facilities.

Income Tax Provision.Our income tax provision decreased ~~$82~~$84 million in the Current Period primarily from a decline in pre-tax earnings of approximately 8164 percent, which reduced income tax expense by approximately ~~$86~~$81 million in the Current Period. ~~This~~The remaining $3 million decrease ~~was partially offset by~~is a ~~higher~~result of a lower effective tax rate of 1915 percent in the Current Period as compared to 1516 percent in the Comparable ~~Period, which increased income tax expense by approximately $4 million.~~Period. The ~~increase~~decrease in the effective tax rate was a result of certain discrete tax items totaling approximately $17 million, partially offset by a change in our geographic revenue mix primarily resulting from drilling restrictions in the U.S. Gulf of ~~Mexico, partially offset by the resolution of uncertain tax positions of $9 million.~~Mexico.

Liquidity and Capital Resources

Overview

Net cash from operating activities for the Current Period was ~~$245~~$474 million, which compared to ~~$1.0~~$1.3 billion in the Comparable Period. The decrease in net cash from operating activities in the Current Period was primarily attributable to a significant decline in net income coupled with an increase in accounts receivable. The increase in accounts receivable is primarily related to the increased fleet activity in 2011 and certain disputed amounts, which we believe will ultimately be collected. During the Current Period, we entered into an additional $600 million revolving credit facility, and at ~~June~~September 30, 2011 we had ~~$775~~$485 million available under our credit facilities. We had working capital of ~~$351~~$352 million and $110 million at ~~June~~September 30, 2011 and December 31, 2010, respectively. Primarily as a result of our $1.1 billion debt offering in February 2011 and an increase in net borrowings on our credit facilities during the Current Period of ~~$385~~$675 million, total debt as a percentage of total debt plus equity increased to ~~31.1~~32 percent at ~~June~~September 30, 2011 from ~~27.5~~28 percent at December 31, 2010. Additionally, at ~~June~~September 30, 2011, we had a total contract drilling services backlog of approximately ~~$13~~$12.8 billion. Our backlog as of ~~June~~September 30, 2011 reflects a commitment of 7381 percent of operating days for the remainder of 2011 and 4353 percent for 2012. See additional information regarding our backlog at “Contract Drilling Services Backlog.”

Our principal capital resource in the Current Period was ~~net cash from operating activities of $245 million,~~ cash generated from our $1.1 billion senior ~~note~~notes offering, ~~and~~ net borrowings under our bank credit facilities of ~~$385 million. Net~~$675 million and net cash ~~generated~~ from operating activities ~~in the Comparable Period totaled $1.0 billion.~~of $474 million.

As a result of the cash generated by our operations, our cash on hand and the availability under our bank credit facilities, we believe our liquidity and financial condition are sufficient to meet all of our reasonablyOur currently anticipated cash flow needs ~~including:~~include the following:

	•		normal recurring operating expenses;

	•		committed capital expenditures, including expenditures for ~~newbuilds and other miscellaneous~~newbuild projects currently underway;

	•		discretionary capital expenditures, including various capital upgrades; and

	•		payments of return of capital in the form of a reduction of par value of our shares (in lieu of dividends).

We currently expect to fund these cash flow needs with cash generated by our operations, cash on hand and borrowings under our existing bank credit facilities. However, given the level of expenditures we expect to incur through the end of 2012, a significant portion of which relates to our newbuild program, we may require capital in excess of the amount provided through these sources. Subject to market and other conditions, we may raise such additional capital in a number of ways, including accessing capital markets, obtaining additional lines of credit or disposing of assets. We also retain the flexibility to delay or cancel certain discretionary capital expenditures as necessary.

Capital Expenditures

Our primary liquidity requirement during 2011 is for capital expenditures. Capital expenditures, including capitalized interest, totaled ~~$1.4~~$2.0 billion and ~~$531~~$886 million for the ~~six~~nine months ended ~~June~~September 30, 2011 and 2010, respectively. Capital expenditures for 2010 do not include the fair value of assets acquired as part of the Frontier acquisition.

At ~~June~~September 30, 2011, we had 1113 rigs under construction, and capital expenditures for new construction ~~in 2011 totaled $972 million. Capital expenditures for newbuild rigs~~ during the first ~~six~~nine months of 2011 ~~consisted of the following~~totaled $1.3 billion, as follows (in millions):


Rig type/name
Wholly-owned drillships
Globetrotter class
Noble Globetrotter I			$	176.2
Noble Globetrotter II				78.3
	Capital
Project	Expenditures
Gusto P10,000
HHI Drillship I				161.1
HHI Drillship II				161.5
HHI Drillship III	$	161.0		161.6
HHI Drillship II		160.5
HHI Drillship I		160.3
Noble Globetrotter I		124.5
HHI Drillship IV				50.0

Joint venture owned drillships
GustoMSC Bully PRD 12,000
Noble Bully I		79.6		149.4
Noble Bully II		76.5		114.1
Noble Globetrotter II		76.5

Wholly-owned jackups
F&G JU-3000N
Noble Jackup I				43.5
Noble Jackup II				2.4
Noble Jackup III		42.9		45.1
Noble Jackup IV		42.9		44.4
Noble Jackup I		41.5
Noble Jackup II		1.0
Other		4.3
Noble Jackup V				44.4
Noble Jackup VI				44.4

Total	$	971.5
Other recently completed newbuilds				4.2

Total Newbuild Capital Expenditures			$	1,280.6

In addition to the newbuild expenditures noted above, capital expenditures during 2011 consisted ~~of the following:~~of:

	•		~~$293 million for major projects, including $82 million to upgrade two drillships currently operating in Brazil;~~

	•		~~$108 million for other capitalized expenditures including major maintenance and regulatory expenditures which generally have useful lives ranging from 3 to 5 years; and~~

	•		~~$56 million in capitalized interest.~~

$463 million for major projects, including $130 million to upgrade two drillships currently operating in Brazil;

$156 million for other capitalized expenditures, including major maintenance and regulatory expenditures which generally have useful lives ranging from 3 to 5 years; and

$88 million in capitalized interest.

Our total capital expenditure estimate for 2011 is approximately ~~$2.5~~$2.7 billion. In connection with our 2011 and future capital expenditure programs, as of ~~June~~September 30, 2011, we had outstanding commitments, including shipyard and purchase commitments, for approximately ~~$2.6~~$3.4 billion, of which ~~$900 million~~$1.1 billion is anticipated to be spent within the next twelve months. Our remaining 2011 capital expenditure budget and our 2012 capital expenditures will generally be spent at our discretion. We may accelerate or delay capital projects as needed.

From time to time we consider possible projects that would require expenditures that are not included in our capital budget, and such unbudgeted expenditures could be significant. In addition, we will continue to evaluate acquisitions of drilling units from time to time. Other factors that could cause actual capital expenditures to materially exceed plan include delays and cost overruns in shipyards (including costs attributable to labor shortages), shortages of equipment, latent damage or deterioration to hull, equipment and machinery in excess of engineering estimates and assumptions, changes in governmental regulations and requirements and changes in design criteria or specifications during repair or construction.

Share Repurchases and Dividends

At ~~June~~September 30, 2011, 6.8 million registered shares remained available under the existing Board authorization for our share repurchase program. No shares have been repurchased under this authorization during the nine months ended September 30, 2011. During the ~~six~~nine months ended ~~June~~September 30, 2011, we acquired approximately ~~0.2~~0.3 million shares surrendered by employees for taxes payable upon the vesting of restricted stock and exercises of options for $9$10 million. Future repurchases by Noble-Swiss will be subject to the requirements of Swiss law, including the requirement that Noble-Swiss and its subsidiaries may only repurchase shares if and to the extent that sufficient freely distributable reserves are available.

Our most recent quarterly payment to shareholders in the form of a capital reduction, which was paid on May 19, 2011 to holders of record on May 9, 2011, was 0.13 CHF per share, or an aggregate of approximately $37 million. The declaration and payment of dividends in the future by Noble-Swiss and the making of distributions of capital, including returns of capital in the form of par value reductions, require authorization of the shareholders of Noble-Swiss. The amount of such dividends, distributions and returns of capital will depend on our results of operations, financial condition, cash requirements, future business prospects, contractual restrictions and other factors deemed relevant by our Board of Directors and shareholders.

In April 2011, our shareholders approved the payment of a return of capital through a reduction of the par value of our shares in a total amount equal to 0.52 CHF per share to be paid in four equal installments scheduled for August 2011, November 2011, February 2012 and May 2012. The payments will be made in U.S. Dollars based on the CHF/USD exchange rate available approximately two business days prior to the payment date. Although the amount of the return of capital, expressed in Swiss francs, is fixed, the amount of the payment in U.S. Dollars will fluctuate based on the exchange rate. The exchange rate as published by the Swiss National Bank on ~~July 29,~~October 28, 2011 was ~~0.8017~~0.8625 CHF/1.0 USD. These returns of capital will require us to make total cash payments of approximately ~~$82~~$38 million during the remainder of 2011 (based on the exchange rate on ~~July 29,~~October 28, 2011).

Our most recent quarterly payment to shareholders in the form of a capital reduction, which was paid on August 18, 2011 to holders of record on August 8, 2011, was 0.13 CHF per share, or an aggregate of approximately $42 million. The declaration and payment of dividends in the future by Noble-Swiss and the making of distributions of capital, including returns of capital in the form of par value or additional paid-in capital reductions, require authorization of the shareholders of Noble-Swiss. The amount of such dividends, distributions and returns of capital will depend on our results of operations, financial condition, cash requirements, future business prospects, contractual restrictions and other factors deemed relevant by our Board of Directors and shareholders.

Credit Facilities and Long-Term Debt

The Credit Facilities provide us with the ability to issue up to $300 million in letters of credit in the aggregate. While the issuance of letters of credit does not increase our borrowings outstanding under the Credit Facilities, it does reduce the amount available. At ~~June~~September 30, 2011, we had borrowings of ~~$425~~$715 million outstanding and no letters of credit outstanding under the Credit Facilities. We believe that we maintain good relationships with our lenders under the Credit Facilities, and we believe that our lenders have the liquidity and capability to perform should the need arise for us to draw on the Credit Facilities.

The indentures governing our outstanding senior unsecured notes contain covenants that place restrictions on certain merger and consolidation transactions, unless we are the surviving entity or the other party assumes the obligations under the indenture, and on the ability to sell or transfer all or substantially all of our assets. In addition, there are restrictions on incurring or assuming certain liens and sale and lease-back transactions. At ~~June~~September 30, 2011, we were in compliance with all our debt covenants. We continually monitor compliance with the covenants under our Credit Facilities and senior notes and, based on our expectations for 2011, expect to remain in compliance during the year.

At ~~June~~September 30, 2011, we had letters of credit of ~~$84~~$74 million and performance and tax assessment bonds totaling ~~$347~~$295 million supported by surety bonds outstanding. Additionally, certain of our subsidiaries issue, from time to time, guarantees of the temporary import status of rigs or equipment imported into certain countries in which we operate. These guarantees are issued in lieu of payment of custom, value added or similar taxes in those countries.

Our long-term debt, including current maturities, was ~~$3.5~~$3.8 billion at ~~June~~September 30, 2011 as compared to $2.8 billion at December 31, 2010. The increase in debt is a result of the issuance of $1.1 billion aggregate principal amount of senior notes and ~~$385~~$675 million of additional net borrowings on our Credit Facilities, partially offset by the repayment of $693 million in joint venture credit facilities. For additional information on our long-term debt, see Note 8 to our consolidated financial statements.

In April 2011, the Bully joint venture partners entered into a subscription agreement, pursuant to which each partner was issued equity in each of the Bully joint ventures in exchange for the cancellation of all outstanding joint venture partner notes. The subscription agreement has the effect of converting all joint venture partner notes, including the contribution noted above, into equity of the respective joint venture. The total capital contributed as a result of these agreements was $146 million, which included $142 million in outstanding notes, plus accrued interest. Our portion of the capital contribution, totaling $73 million, was eliminated in consolidation.

New Accounting Pronouncements

In May 2011, the FASB issued guidance that modified the wording used to describe many of the requirements in accounting literature for measuring fair value and for disclosing information about fair value measurements. The goal of the amendment is to create consistency between the United States and international accounting standards. The guidance is effective for annual and interim reporting periods beginning on or after December 15, 2011. While we are still evaluating this guidance, the adoption of this guidance ~~should~~is not expected to have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In June 2011, the FASB issued guidance that allows an entity to present the total of comprehensive income, the components of net income, and the components of other comprehensive income either in a single continuous statement of comprehensive income or in two separate but consecutive statements. The amendment no longer allows an entity to show changes to other comprehensive income solely through the statement of equity. For publicly traded entities, the guidance is effective for annual and interim reporting periods beginning on or after December 15, 2011. While we are still evaluating this guidance, the adoption of this guidance ~~will~~is not expected to have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

5556


Item 3.		~~Item 3.~~ Quantitative and Qualitative Disclosures About Market Risk

Market risk is the potential for loss from a change in the value of a financial instrument as a result of fluctuations in interest rates, currency exchange rates or equity prices, as further described below.

Interest Rate Risk

We are subject to market risk exposure related to changes in interest rates on borrowings under the Credit Facilities. Interest on borrowings under the Credit Facilities is at an agreed upon percentage point spread over LIBOR, or a base rate stated in the agreements. At ~~June~~September 30, 2011, we had ~~$425~~$715 million outstanding under the Credit Facilities. Assuming our current level of debt, a change in LIBOR rates of ~~100 basis points~~one percent would increase our interest charges by approximately $4$7 million per year.

We maintain certain debt instruments at a fixed rate whose fair value will fluctuate based on changes in interest rates and market perceptions of our credit risk. The fair value of our total debt was ~~$3.7~~$3.4 billion and $2.9 billion at ~~June~~September 30, 2011 and December 31, 2010, respectively. The increase was primarily a result of our issuance of $1.1 billion in debt in February 2011 and ~~$385~~$675 million of additional net borrowings on the Credit Facilities, partially offset by the repayment of $693 million in joint venture credit facilities coupled with changes in fair value related to changes in interest rates and market perceptions of our credit risk.

Foreign Currency Risk

As a multinational company, we conduct business worldwide. Our functional currency is primarily the U.S. dollar, which is consistent with the oil and gas industry. However, outside the United States, a portion of our expenses are incurred in local currencies. Therefore, when the U.S. dollar weakens (strengthens) in relation to the currencies of the countries in which we operate, our expenses reported in U.S. dollars will increase (decrease).

We are exposed to risks on future cash flows to the extent that local currency expenses exceed revenues denominated in local currency that are different than the functional currency. To help manage this potential risk, we periodically enter into derivative instruments to manage our exposure to fluctuations in currency exchange rates, and we may conduct hedging activities in future periods to mitigate such exposure. These contracts are primarily accounted for as cash flow hedges, with the effective portion of changes in the fair value of the hedge recorded on the Consolidated Balance Sheet and in “Accumulated other comprehensive loss” (“AOCL”). Amounts recorded in AOCL are reclassified into earnings in the same period or periods that the hedged item is recognized in earnings. The ineffective portion of changes in the fair value of the hedged item is recorded directly to earnings. We have documented policies and procedures to monitor and control the use of derivative instruments. We do not engage in derivative transactions for speculative or trading purposes, nor are we a party to leveraged derivatives.

Our North Sea and Brazil operations have a significant amount of their cash operating expenses payable in local currencies. To limit the potential risk of currency fluctuations, we typically maintain short-term forward contracts settling monthly in their respective local currencies. The forward contract settlements in the remainder of 2011 represent approximately 5243 percent of these forecasted local currency requirements. The notional amount of the forward contracts outstanding, expressed in U.S. dollars, was approximately ~~$113~~$71 million at ~~June~~September 30, 2011. Total unrealized ~~gains~~losses related to these forward contracts were $4$6 million as of ~~June~~September 30, 2011 and were recorded as part of AOCL. A 10 percent change in the exchange rate for the local currencies would change the fair value of these forward contracts by approximately ~~$12~~$7 million.

We ~~have~~ entered into a firm commitment for the construction of theNoble Globetrotter Idrillship. The drillship ~~is being~~was constructed in two phases, with the second phase being installation and commissioning of the topside equipment. The contract for this second phase of construction iswas denominated in Euros, and in order to mitigate the risk of fluctuations in foreign currency exchange rates, we entered into forward contracts to purchase Euros. As of ~~June~~September 30, 2011, all amounts related to the ~~aggregate notional amount of~~forward contracts have settled. We accounted for the ~~remaining outstanding~~ forward ~~contract was 10 million Euros. This forward contract settles in connection with a required payment under the construction contract. We are accounting for this forward contract~~contracts as a fair value ~~hedge. The~~hedges, and their fair market value ~~of this derivative instrument is~~was included in “Other current assets/liabilities” in the Consolidated Balance Sheets. Gains and losses from this fair value hedge would be recognized in earnings currently, along with the change in fair value of the hedged item attributable to the risk being hedged, if any portion was found to be ineffective. The fair market value of this outstanding forward contract totaled approximately $51,000 at June 30, 2011. No gain or loss was recognized in the income statement for the three and ~~six~~nine months ended ~~June~~September 30, 2011 ~~respectively. A 10 percent change in the exchange rate for the Euro would change the fair value of this forward contract by approximately $1 million.~~or 2010.

5657

Market Risk

We sponsor the Noble Drilling Corporation 401(k) Savings Restoration Plan (“Restoration Plan”). The Restoration Plan is a nonqualified, unfunded employee benefit plan under which certain highly compensated employees may elect to defer compensation in excess of amounts deferrable under our 401(k) savings plan. The Restoration Plan has no assets, and amounts withheld for the Restoration Plan are kept by us for general corporate purposes. The investments selected by employees and the associated returns are tracked on a phantom basis. Accordingly, we have a liability to employees for amounts originally withheld plus phantom investment income or less phantom investment losses. We are at risk for phantom investment income and, conversely, benefit should phantom investment losses occur. At ~~June~~September 30, 2011, our liability under the Restoration Plan totaled $7$5 million. We previously purchased investments that closely correlate to the investment elections made by participants in the Restoration Plan in order to mitigate the impact of the phantom investment income and losses on our consolidated financial statements. The value of these investments held for our benefit totaled $7$4 million at ~~June~~September 30, 2011. A 10 percent change in the fair value of the phantom investments would change our liability by approximately ~~$0.7~~$0.4 million. Any change in the fair value of the phantom investments would be mitigated by a change in the investments held for our benefit.

We also have a U.S. noncontributory defined benefit pension plan that covers certain salaried employees and a U.S. noncontributory defined benefit pension plan that covers certain hourly employees, whose initial date of employment is prior to August 1, 2004 (collectively referred to as our “qualified U.S. plans”). These plans are governed by the Noble Drilling Corporation Retirement Trust. The benefits from these plans are based primarily on years of service and, for the salaried plan, employees’ compensation near retirement. These plans are designed to qualify under the Employee Retirement Income Security Act of 1974 (“ERISA”), and our funding policy is consistent with funding requirements of ERISA and other applicable laws and regulations. We make cash contributions, or utilize credits available to us, for the qualified U.S. plans when required. The benefit amount that can be covered by the qualified U.S. plans is limited under ERISA and the Internal Revenue Code (“IRC”) of 1986. Therefore, we maintain an unfunded, nonqualified excess benefit plan designed to maintain benefits for all employees at the formula level in the qualified U.S. plans.

In addition to the U.S. plans, each of Noble Drilling (Land Support) Limited, Noble Enterprises Limited and Noble Drilling (Nederland) B.V., all indirect, wholly-owned subsidiaries of Noble-Swiss, maintains a pension plan that covers all of its salaried, non-union employees (collectively referred to as our “non-U.S. plans”). Benefits are based on credited service and employees’ compensation near retirement, as defined by the plans.

Changes in market asset values related to the pension plans noted above could have a material impact upon our “Consolidated Statement of Comprehensive Income” and could result in material cash expenditures in future periods.


Item 4.		~~Item 4.~~ Controls and Procedures

David W. Williams, Chairman, President and Chief Executive Officer of Noble-Swiss, and ~~Thomas L. Mitchell, Senior Vice President, Chief~~Dennis J. Lubojacky, Principal Financial Officer ~~Treasurer~~ and ~~Controller~~Principal Accounting Officer of Noble-Swiss, have evaluated the disclosure controls and procedures of Noble-Swiss as of the end of the period covered by this report. On the basis of this evaluation, Mr. Williams and Mr. ~~Mitchell~~Lubojacky have concluded that Noble-Swiss’ disclosure controls and procedures were effective as of ~~June~~September 30, 2011. Noble-Swiss’ disclosure controls and procedures are designed to ensure that information required to be disclosed by Noble-Swiss in the reports that it files with or submits to the SEC is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and is accumulated and communicated to management as appropriate to allow timely decisions regarding required disclosure.

David W. Williams, President and Chief Executive Officer of Noble-Cayman, and Dennis J. Lubojacky, Vice President and Chief Financial Officer of Noble-Cayman, have evaluated the disclosure controls and procedures of Noble-Cayman as of the end of the period covered by this report. On the basis of this evaluation, Mr. Williams and Mr. Lubojacky have concluded that Noble-Cayman’s disclosure controls and procedures were effective as of ~~June~~September 30, 2011. Noble-Cayman’s disclosure controls and procedures are designed to ensure that information required to be disclosed by Noble-Cayman in the reports that it files with or submits to the SEC is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and is accumulated and communicated to management as appropriate to allow timely decisions regarding required disclosure.

5758

There was no change in either Noble-Swiss’ or Noble-Cayman’s internal control over financial reporting that occurred during the quarter ended ~~June~~September 30, 2011 that has materially affected, or is reasonably likely to materially affect, the internal control over financial reporting of each of Noble-Swiss or Noble-Cayman, respectively.

PART II. OTHER INFORMATION


Item 1.		~~Item 1.~~ Legal Proceedings

Information regarding legal proceedings is set forth in Note 13 to our consolidated financial statements included in Item 1 of Part I of this Quarterly Report on Form 10-Q and is incorporated herein by reference.


Item 1A.		~~Item 1A.~~ Risk Factors

Risks Relating to Our Business

The risk factor below updates and supplements the risks described under “Risk Factors Relating to Our Business” in Part I, Item 1A, “Risk Factors,” of our Annual Report on Form 10-K for the year ended December 31, 2010, and should be considered together with the risk factors described in that report.

We may have difficulty obtaining or maintaining insurance in the future and our insurance coverage and contractual indemnity rights may not protect us against all of the risks and hazards we face.

We generally identify the operational hazards for which we will procure insurance coverage based on the likelihood of loss, the potential magnitude of loss, the cost of coverage, the ~~requirement~~requirements of our customer contracts and applicable legal requirements. We do not procure insurance coverage for all of the potential risks and hazards we may face. Furthermore, no assurance can be given that we will be able to obtain insurance against all of the risks and hazards we face or that we will be able to obtain or maintain adequate insurance at rates and with deductibles or retention amounts that we consider commercially reasonable.

Although we maintain what we believe to be an appropriate level of insurance covering hazards and risks we currently encounter during our operations, we do not insure against all possible hazards and risks. Furthermore, our insurance carriers may interpret our insurance policies such that they do not cover losses for which we make claims. Our insurance policies may also have exclusions of coverage for some losses. Uninsured exposures may include expatriate activities prohibited by U.S. laws, radiation hazards, certain loss or damage to property onboard our rigs and losses relating to shore-based terrorist acts or strikes.

In addition, the damage sustained to offshore oil and gas assets as a result of hurricanes in recent years caused the insurance market for U.S. named windstorm perils to deteriorate significantly. Consequently, we currently ~~self insure~~self-insure U.S. named windstorm coverage for our units deployed in the U.S. Gulf of Mexico. If one or more future significant weather-related events occur in the Gulf of Mexico, or in any other geographic area in which we operate, we may experience increases in insurance costs, additional coverage restrictions or unavailability of certain insurance products.

Under our drilling contracts, liability with respect to personnel and property is customarily assigned on a “knock-for-knock” basis, which means that we and our customers assume liability for our respective personnel and property, irrespective of the fault or negligence of the party indemnified. Although our drilling contracts generally provide for indemnification from our customers for certain liabilities, including liabilities resulting from pollution or contamination originating below the surface of the water, enforcement of these contractual rights to indemnity may be limited by public policy and other considerations and, in any event, may not adequately cover our losses from such incidents. There can also be no assurance that those parties with contractual obligations to indemnify us will necessarily be in a financial position to do so.

If a significant accident or other event occurs and is not fully covered by our insurance or a contractual indemnity, it could materially adversely affect our financial position, results of operations or cash flows.

As a result of our significant cash flow needs, we may be required to incur additional indebtedness, or delay or cancel discretionary capital expenditures.

Our currently anticipated cash flow needs include the following:

normal recurring operating expenses;

committed capital expenditures, including expenditures for newbuild projects currently underway;

discretionary capital expenditures, including various capital upgrades; and

payments of return of capital in the form of a reduction of par value of our shares (in lieu of dividends).

In order to fund our capital expenditures, we may need funding beyond the amount available to us from cash generated by our operations, cash on hand and borrowings under our existing bank credit facilities. We may raise such additional capital in a number of ways, including accessing capital markets, obtaining additional lines of credit or disposing of assets. However, we can provide no assurance that any of these options will be available to us on terms acceptable to us or at all.

Our ability to obtain financing or to access the capital markets may be limited by our financial condition at the time of any such financing and the covenants in our existing debt agreements, as well as by adverse market conditions resulting from, among other things, general economic conditions and uncertainties that are beyond our control. Even if we are successful in obtaining additional capital through debt financings, incurring additional indebtedness may significantly increase our interest expense and may reduce our flexibility to respond to changing business and economic conditions or to fund working capital needs, because we will require additional funds to service our outstanding indebtedness.

If we fail to obtain the capital necessary to fund our capital expenditures, we may delay or cancel discretionary capital expenditures, which could have certain adverse consequences including delaying upgrades or equipment purchases that could make the affected rigs less competitive and negatively affect our ability to contract such rigs.


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

The following table sets forth for the periods indicated certain information with respect to purchases of shares by Noble-Swiss:

Total Number of Maximum Number
Shares Purchased of Shares that May
Total Number Average as Part of Publicly Yet Be Purchased
of Shares Price Paid Announced Plans Under the Plans
Period Purchased per Share or Programs⁽¹⁾ or Programs⁽¹⁾
April 2011 705 $ 43.33 ⁽²⁾ — 6,769,891
May 2011 60,000 $ 41.87 ⁽²⁾ — 6,769,891
June 2011 29,330 $ 37.45 ⁽²⁾ — 6,769,891


						Total Number of		Maximum Number
						Shares Purchased		of Shares that May
	Total Number		Average			as Part of Publicly		Yet Be Purchased
	of Shares		Price Paid			Announced Plans		Under the Plans
Period	Purchased		per Share			or Programs⁽¹⁾		or Programs⁽¹⁾
July 2011		17,429	$	36.89	⁽²⁾		—		6,769,891
August 2011		728	$	31.23	⁽²⁾		—		6,769,891
September 2011		—	$	0			—		6,769,891


(1)		All share purchases made in the open market and were pursuant to the share repurchase program which our Board of Directors authorized and adopted. Our repurchase program has no date of expiration.

(2)		Amounts represent shares surrendered by employees for withholding taxes payable upon the vesting of restricted stock or exercise of stock options.


Item 6.		~~Item 6.~~ Exhibits

The information required by this Item 6 is set forth in the Index to Exhibits accompanying this Quarterly Report on Form 10-Q and is incorporated herein by reference.

5960

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.

~~Noble Corporation~~~~, a Swiss corporation~~

Noble Corporation, a Swiss corporation



/s/ David W. Williams David W. Williams		~~August 8,~~November 2, 2011 Date
Chairman, President and Chief Executive Officer
(Principal Executive Officer)

/s/ ~~Thomas L. Mitchell~~Dennis. J. Lubojacky ~~Thomas L. Mitchell~~Dennis J. Lubojacky
~~Senior Vice President, Chief Financial Officer, Treasurer and Controller~~
(Principal Financial Officer and Principal Accounting Officer)

Noble Corporation, a Cayman Islands company

/s/ David W. Williams David W. Williams		~~August 8,~~November 2, 2011 Date
President and Chief Executive Officer
(Principal Executive Officer)

/s/ Dennis J. Lubojacky Dennis J. Lubojacky
Vice President and Chief Financial Officer
(Principal Financial Officer and Principal Accounting Officer)

6061

Index to Exhibits


Exhibit
Number			Exhibit

	2.1		Agreement and Plan of Merger, Reorganization and Consolidation, dated as of December 19, 2008, among Noble Corporation, a Swiss corporation (“Noble-Swiss”), Noble Corporation, a Cayman Islands company (“Noble-Cayman”), and Noble Cayman Acquisition Ltd. (filed as Exhibit 1.1 to Noble-Cayman’s Current Report on Form 8-K filed on December 22, 2008 and incorporated herein by reference).

	2.2		Amendment No. 1 to Agreement and Plan of Merger, Reorganization and Consolidation, dated as of February 4, 2009, among Noble-Swiss, Noble-Cayman and Noble Cayman Acquisition Ltd. (filed as Exhibit 2.2 to Noble-Cayman’s Current Report on Form 8-K filed on February 4, 2009 and incorporated herein by reference).

	3.1		Articles of Association of Noble-Swiss.

	3.2		By-laws of Noble-Swiss (filed as Exhibit 3.2 to Noble-Swiss’ Current Report on Form 8-K filed on March 27, 2009 and incorporated herein by reference).

	3.3		Memorandum and Articles of Association of Noble-Cayman (filed as Exhibit 3.1 to Noble-Cayman’s Current Report on Form 8-K filed on March 30, 2009 and incorporated herein by reference).

	4.1		Revolving Credit Agreement dated as of February 11, 2011 among Noble Corporation, a Cayman Islands company; the Lenders from time to time parties thereto; Wells Fargo Bank, National Association, as Administrative Agent, Swingline Lender and an Issuing Bank; Barclays Capital, a division of Barclays Bank PLC, and HSBC Securities (USA) Inc., as Co-Syndication Agents; and Wells Fargo Securities, LLC, Barclays Capital, a division of Barclays Bank PLC, and HSBC Securities (USA) Inc., as Joint Lead Arrangers and Joint Lead Bookrunners (filed as Exhibit 4.1 to Noble-Cayman’s Current Report on Form 8-K filed on February 17, 2011 and incorporated herein by reference).

	4.2		First Amendment to Revolving Credit Agreement dated as of March 11, 2011 among Noble Corporation, a Cayman Islands company; the Lenders from time to time parties thereto; Wells Fargo Bank, National Association, as Administrative Agent, Swingline Lender and an Issuing Bank; Barclays Capital, a division of Barclays Bank PLC, and HSBC Securities (USA) Inc., as Co-Syndication Agents; and Wells Fargo Securities, LLC, Barclays Capital, a division of Barclays Bank PLC, and HSBC Securities (USA) Inc., as Joint Lead Arrangers and Joint Lead Bookrunners (filed as Exhibit 4.2 to Noble-Cayman’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2011 and incorporated herein by reference).

	4.3		Indenture, dated as of November 21, 2008, between Noble Holding International Limited, as Issuer, and The Bank of New York Mellon Trust Company, N.A., as Trustee (filed as Exhibit 4.1 to Noble-Cayman’s Current Report on Form 8-K filed on November 21, 2008 and incorporated herein by reference).

	4.4		Third Supplemental Indenture, dated as of February 3, 2011, among Noble Holding International Limited, as Issuer, Noble Corporation, as Guarantor, and The Bank of New York Mellon Trust Company, N.A., as Trustee, relating to 3.05% Senior Notes due 2016 of Noble Holding International Limited, 4.625% Senior Notes due 2021 of Noble Holding International Limited, and 6.05% Senior Notes due 2041 of Noble Holding International Limited (filed as Exhibit 4.2 to Noble-Cayman’s Current Report on Form 8-K filed on July 26, 2010 and incorporated herein by reference).

	31.1		Certification of David W. Williams pursuant to the U.S. Securities Exchange Act of 1934, as amended, Rule 13a-14(a) or Rule 15d-14(a), for Noble-Swiss and for Noble-Cayman.

	31.2		Certification of ~~Thomas L. Mitchell pursuant to the U.S. Securities Exchange Act of 1934, as amended, Rule 13a-14(a) or Rule 15d-14(a), for Noble-Swiss.~~

	~~31.3~~		~~Certification of~~ Dennis J. Lubojacky pursuant to the U.S. Securities Exchange Act of 1934, as amended, Rule 13a- 14(a) or Rule 15d-14(a), for Noble-Swiss and Noble-Cayman.

	32.1	+	Certification of David W. Williams pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, for Noble-Swiss and for Noble-Cayman.

	32.2	+	Certification of ~~Thomas L. Mitchell pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, for Noble-Swiss.~~

	~~32.3~~	+	~~Certification of~~ Dennis J. Lubojacky pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, for Noble-Swiss and Noble-Cayman.

	101	+	Interactive Data File


+		Furnished in accordance with Item 601(b)(32)(ii) of Regulation S-K.

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