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

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. Yes x No ¨

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). Yes x No ¨

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):

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

Number of shares outstanding and trading at ~~April 30,~~July 31, 2012: Noble Corporation (Switzerland) — ~~252,387,216~~252,604,007

Number of shares outstanding at ~~April 30,~~July 31, 2012: 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) to Form 10-Q and is therefore filing this Form 10-Q with the reduced disclosure format contemplated by paragraphs (b) and (c) of General Instruction H(2) of Form 10-Q.

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.


	March 31,			December 31,			June 30,			December 31,
	2012			2011			2012			2011
ASSETS
Current assets
Cash and cash equivalents	$	208,840		$	239,196		$	275,293		$	239,196
Accounts receivable		738,835			587,163			693,533			587,163
Taxes receivable		95,308			75,284			97,900			75,284
Prepaid expenses		88,499			35,796			78,463			35,796
Other current assets		123,191			122,173			142,541			122,173

Total current assets		1,254,673			1,059,612			1,287,730			1,059,612

Property and equipment, at cost		15,371,823			15,037,112			16,055,168			15,540,178
Accumulated depreciation		(3,282,511	)		(3,139,645	)		(3,632,532	)		(3,409,833	)

Property and equipment, net		12,089,312			11,897,467			12,422,636			12,130,345

Other assets		551,216			538,080			325,650			305,202

Total assets	$	13,895,201		$	13,495,159		$	14,036,016		$	13,495,159

LIABILITIES AND EQUITY
Current liabilities
Accounts payable	$	335,276		$	436,006		$	277,647		$	436,006
Accrued payroll and related costs		111,251			117,907			125,603			117,907
Interest payable		28,540			54,419			73,208			54,419
Taxes payable		97,179			94,920			89,262			94,920
Dividends payable								132,679			—
Other current liabilities		108,911			123,928			108,714			123,928

Total current liabilities		681,157			827,180			807,113			827,180

Long-term debt		4,444,161			4,071,964			4,444,294			4,071,964
Deferred income taxes		240,341			242,791			238,045			242,791
Other liabilities		306,175			255,372			306,397			255,372

Total liabilities		5,671,834			5,397,307			5,795,849			5,397,307

Commitments and contingencies

Shareholders’ equity
Shares; 252,730 and 252,639 shares outstanding		737,633			766,595
Treasury shares, at cost; 463 and 287 shares		(17,004	)		(10,553	)
Shares; 253,076 and 252,639 shares outstanding								709,368			766,595
Treasury shares, at cost; 569 and 287 shares								(20,318	)		(10,553	)
Additional paid-in capital		52,180			48,356			60,991			48,356
Retained earnings		6,796,619			6,676,444			6,823,758			6,676,444
Accumulated other comprehensive loss		(70,560	)		(74,321	)		(75,461	)		(74,321	)

Total shareholders’ equity		7,498,868			7,406,521			7,498,338			7,406,521
Noncontrolling interests		724,499			691,331			741,829			691,331

Total equity		8,223,367			8,097,852			8,240,167			8,097,852

Total liabilities and equity	$	13,895,201		$	13,495,159		$	14,036,016		$	13,495,159


	Three Months Ended						Three Months Ended						Six Months Ended
	March 31,						June 30,						June 30,
	2012			2011			2012			2011			2012			2011
Operating revenues
Contract drilling services	$	746,310		$	542,605		$	848,237		$	589,550		$	1,594,547		$	1,132,155
Reimbursables		35,141			22,291			30,812			24,122			65,953			46,413
Labor contract drilling services		16,008			13,547			19,863			14,012			35,871			27,559
Other		231			445			11			313			242			758

		797,690			578,888			898,923			627,997			1,696,613			1,206,885

Operating costs and expenses
Contract drilling services		420,011			306,363			423,502			336,728			843,513			643,091
Reimbursables		30,601			17,103			24,970			18,723			55,571			35,826
Labor contract drilling services		9,232			8,523			11,847			8,750			21,079			17,273
Depreciation and amortization		171,077			158,122			183,615			163,119			354,692			321,241
Selling, general and administrative		23,126			23,715			25,404			21,632			48,530			45,347
Gain on contract extinguishments, net		—			(21,202	)
Loss on impairment								18,345			—			18,345			—
Gain on contract settlements/extinguishments, net								(33,255	)		—			(33,255	)		(21,202	)

		654,047			492,624			654,428			548,952			1,308,475			1,041,576

Operating income		143,643			86,264			244,495			79,045			388,138			165,309

Other income (expense)
Interest expense, net of amount capitalized		(10,496	)		(19,041	)		(20,652	)		(14,829	)		(31,148	)		(33,870	)
Interest income and other, net		1,785			2,592			1,188			(534	)		2,973			2,058

Income before income taxes		134,932			69,815			225,031			63,682			359,963			133,497
Income tax provision		(21,589	)		(15,359	)		(46,356	)		(9,508	)		(67,945	)		(24,867	)

Net income		113,343			54,456			178,675			54,174			292,018			108,630
Net loss attributable to noncontrolling interests		6,832			39
Net income attributable to noncontrolling interests								(18,857	)		(91	)		(12,025	)		(52	)

Net income attributable to Noble Corporation	$	120,175		$	54,495		$	159,818		$	54,083		$	279,993		$	108,578

Net income per share
Basic	$	0.47		$	0.22		$	0.63		$	0.21		$	1.10		$	0.43
Diluted	$	0.47		$	0.21		$	0.63		$	0.21		$	1.10		$	0.43


	Three Months Ended						Three Months Ended						Six Months Ended
	March 31,						June 30,						June 30,
	2012			2011			2012			2011			2012			2011
Net income	$	113,343		$	54,456		$	178,675		$	54,174		$	292,018		$	108,630

Other comprehensive income (loss), net of tax
Foreign currency translation adjustments		(41	)		3,040			(6,949	)		1,375			(7,027	)		4,382
Gain on foreign currency forward contracts		2,417			162			644			2,351			3,061			2,513
Loss on interest rate swaps		—			(366	)		—			—			—			(366	)
Amortization of deferred pension plan amounts (net of tax provision of $720 in 2012 and $353 in 2011)		1,385			653
Amortization of deferred pension plan amounts (net of tax provision of $647 and $353 for the three months ended June 30, 2012 and 2011, respectively, and $1,367 and $705 for the six months ended June 30, 2012 and 2011, respectively)								1,404			689			2,826			1,375

Other comprehensive income, net		3,761			3,489
Other comprehensive income/(loss), net								(4,901	)		4,415			(1,140	)		7,904

Net comprehensive income attributable to noncontrolling interests		6,832			40			(18,857	)		(91	)		(12,025	)		(52	)

Comprehensive income attributable to Noble Corporation	$	123,936		$	57,985		$	154,917		$	58,498		$	278,853		$	116,482


	Three Months Ended						Six Months Ended
	March 31,						June 30,
	2012			2011			2012			2011
Cash flows from operating activities
Net income	$	113,343		$	54,456		$	292,018		$	108,630
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization		171,077			158,122			354,692			321,241
Loss on impairment								18,345			—
Gain on contract extinguishments, net		—			(21,202	)		—			(21,202	)
Deferred income taxes		(4,075	)		2,819			(7,765	)		(1,753	)
Amortization of share-based compensation		8,753			8,271			17,840			16,388
Net change in other assets and liabilities		(185,390	)		(115,692	)		(139,184	)		(190,536	)

Net cash from operating activities		103,708			86,774			535,946			232,768

Cash flows from investing activities
Capital expenditures		(367,965	)		(614,324	)		(665,140	)		(1,416,215	)
Change in accrued capital expenditures		(127,393	)		(471	)		(159,134	)		(51,500	)
Refund from contract extinguishments		—			18,642			—			18,642

Net cash from investing activities		(495,358	)		(596,153	)		(824,274	)		(1,449,073	)

Cash flows from financing activities
Borrowings on bank credit facilities		365,000			200,000			325,000			625,000
Repayments on bank credit facilities		(1,190,000	)		(240,000	)		(1,150,000	)		(240,000	)
Proceeds from issuance of senior notes, net of debt issuance costs		1,186,636			1,087,833			1,186,636			1,087,833
Contributions from joint venture partners		40,000			396,000			40,000			436,000
Payments of joint venture debt		—			(693,494	)		—			(693,494	)
Settlement of interest rate swaps		—			(29,032	)		—			(29,032	)
Par value reduction payments		(36,370	)		(34,920	)		(71,897	)		(72,141	)
Financing costs on credit facilities		—			(2,835	)		(5,014	)		(2,835	)
Proceeds from employee stock transactions		2,479			2,337			9,465			7,357
Repurchases of employee shares surrendered for taxes		(6,451	)		(5,700	)		(9,765	)		(9,377	)

Net cash from financing activities		361,294			680,189			324,425			1,109,311

Net change in cash and cash equivalents		(30,356	)		170,810			36,097			(106,994	)
Cash and cash equivalents, beginning of period		239,196			337,871			239,196			337,871

Cash and cash equivalents, end of period	$	208,840		$	508,681		$	275,293		$	230,877


																																							Accumulated
																														Additional									Other
	Shares						Additional Paid-in			Retained		Treasury			Accumulated Other Comprehensive			Noncontrolling			Total			Shares						Paid-in			Retained			Treasury			Comprehensive			Noncontrolling			Total
	Balance			Par Value			Capital			Earnings		Shares			Loss			Interests			Equity			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
Amortization of share-based compensation		—			—			8,271			—		—			—			—			8,271			—			—			16,388			—			—			—			—			16,388
Issuance of share-based compensation shares		176			598			(598	)		—		—			—			—			—			176			606			(599	)		—			—			—			—			7
Exercise of stock options		167			566			2,890			—		—			—			—			3,456			389			1,294			5,782			—			—			—			—			7,076
Tax benefit of stock options exercised		—			—			(1,119	)		—		—			—			—			(1,119	)		—			—			274			—			—			—			—			274
Restricted shares forfeited or repurchased for taxes		(312	)		(1,074	)		1,074			—		(5,700	)		—			—			(5,700	)		(312	)		(1,084	)		1,084			—			(9,377	)		—			—			(9,377	)
Net income		—			—			—			54,495		—			—			(39	)		54,456			—			—			—			108,578			—			—			52			108,630
Par value reduction payments		—			(30,343	)		(4,577	)		—		—			—			—			(34,920	)		—			(60,705	)		(11,436	)		—			—			—			—			(72,141	)
Equity contribution by joint venture partner		—			—			—			—		—			—			361,000			361,000			—			—			—			—			—			—			473,973			473,973
Other comprehensive income, net		—			—			—			—		—			3,489			(1	)		3,488			—			—			—			—			—			7,904			—			7,904

Balance at March 31, 2011		262,446		$	887,431		$	44,947		$	6,684,995	$	(379,667	)	$	(46,731	)	$	485,591		$	7,676,566
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 December 31, 2011		252,639		$	766,595		$	48,356		$	6,676,444	$	(10,553	)	$	(74,321	)	$	691,331		$	8,097,852			252,639		$	766,595		$	48,356		$	6,676,444		$	(10,553	)	$	(74,321	)	$	691,331		$	8,097,852

Employee related equity activity
Amortization of share-based compensation		—			—			8,753			—		—			—			—			8,753			—			—			17,840			—			—			—			—			17,840
Issuance of share-based compensation shares		352			1,067			(1,067	)		—		—			—			—			—			364			1,104			(1,099	)		—			—			—			—			5
Exercise of stock options		113			329			2,292			—		—			—			—			2,621			447			1,277			8,735			—			—			—			—			10,012
Tax benefit of stock options exercised		—			—			(142	)		—		—			—			—			(142	)		—			—			(552	)		—			—			—			—			(552	)
Restricted shares forfeited or repurchased for taxes		(374	)		(1,138	)		1,138			—		(6,451	)		—			—			(6,451	)		(374	)		(1,138	)		1,138			—			(9,765	)		—			—			(9,765	)
Net income		—			—			—			120,175		—			—			(6,832	)		113,343			—			—			—			279,993			—			—			12,025			292,018
Equity contribution by joint venture partner		—			—			—			—		—			—			40,000			40,000			—			—			—			—			—			—			40,000			40,000
Other																									—			—			—			—			—			—			(1,527	)		(1,527	)
Par value reduction payments		—			(29,220	)		(7,150	)		—		—			—			—			(36,370	)		—			(58,470	)		(13,427	)		—			—			—			—			(71,897	)
Other comprehensive income, net		—			—			—			—		—			3,761			—			3,761
Dividends payable																									—			—			—			(132,679	)		—			—			—			(132,679	)
Other comprehensive loss, net																									—			—			—			—			—			(1,140	)		—			(1,140	)

Balance at March 31, 2012		252,730		$	737,633		$	52,180		$	6,796,619	$	(17,004	)	$	(70,560	)	$	724,499		$	8,223,367
Balance at June 30, 2012																									253,076		$	709,368		$	60,991		$	6,823,758		$	(20,318	)	$	(75,461	)	$	741,829		$	8,240,167


	March 31,			December 31,			June 30,			December 31,
	2012			2011			2012			2011
ASSETS
Current assets
Cash and cash equivalents	$	201,215		$	235,056		$	267,870		$	235,056
Accounts receivable		738,835			587,163			693,533			587,163
Taxes receivable		95,122			75,284			97,745			75,284
Prepaid expenses		86,241			33,105			76,630			33,105
Other current assets		122,297			120,109			142,541			120,109

Total current assets		1,243,710			1,050,717			1,278,319			1,050,717

Property and equipment, at cost		15,336,998			15,002,928			16,019,544			15,505,994
Accumulated depreciation		(3,276,762	)		(3,134,401	)		(3,626,272	)		(3,404,589	)

Property and equipment, net		12,060,236			11,868,527			12,393,272			12,101,405

Other assets		551,298			538,161			325,733			305,283

Total assets	$	13,855,244		$	13,457,405		$	13,997,324		$	13,457,405

LIABILITIES AND EQUITY
Current liabilities
Accounts payable	$	334,289		$	435,729		$	276,398		$	435,729
Accrued payroll and related costs		102,091			108,908			117,037			108,908
Interest payable		28,540			54,419			73,208			54,419
Taxes payable		93,200			91,190			84,893			91,190
Other current liabilities		108,890			123,399			108,676			123,399

Total current liabilities		667,010			813,645			660,212			813,645

Long-term debt		4,444,161			4,071,964			4,444,294			4,071,964
Deferred income taxes		240,341			242,791			238,045			242,791
Other liabilities		306,175			255,372			306,397			255,372

Total liabilities		5,657,687			5,383,772			5,648,948			5,383,772

Commitments and contingencies

Shareholder equity
Ordinary shares; 261,246 shares outstanding		26,125			26,125			26,125			26,125
Capital in excess of par value		455,686			450,616			461,054			450,616
Retained earnings		7,061,807			6,979,882			7,194,829			6,979,882
Accumulated other comprehensive loss		(70,560	)		(74,321	)		(75,461	)		(74,321	)

Total shareholder equity		7,473,058			7,382,302			7,606,547			7,382,302

Noncontrolling interests		724,499			691,331			741,829			691,331

Total equity		8,197,557			8,073,633			8,348,376			8,073,633

Total liabilities and equity	$	13,855,244		$	13,457,405		$	13,997,324		$	13,457,405


	Three Months Ended						Three Months Ended						Six Months Ended
	March 31,						June 30,						June 30,
	2012			2011			2012			2011			2012			2011
Operating revenues
Contract drilling services	$	746,310		$	542,605		$	848,237		$	589,550		$	1,594,547		$	1,132,155
Reimbursables		35,141			22,291			30,812			24,122			65,953			46,413
Labor contract drilling services		16,008			13,547			19,863			14,012			35,871			27,559
Other		231			445			11			313			242			758

		797,690			578,888			898,923			627,997			1,696,613			1,206,885

Operating costs and expenses
Contract drilling services		415,146			300,832			421,598			330,204			836,744			631,036
Reimbursables		30,601			17,103			24,970			18,723			55,571			35,826
Labor contract drilling services		9,232			8,523			11,847			8,750			21,079			17,273
Depreciation and amortization		170,573			157,655			183,103			162,636			353,676			320,291
Selling, general and administrative		14,010			16,531			15,467			14,642			29,477			31,173
Gain on contract extinguishments, net		—			(21,202	)
Loss on impairment								18,345			—			18,345			—
Gain on contract settlements/extinguishments, net								(33,255	)		—			(33,255	)		(21,202	)

		639,562			479,442			642,075			534,955			1,281,637			1,014,397

Operating income		158,128			99,446			256,848			93,042			414,976			192,488

Other income (expense)
Interest expense, net of amount capitalized		(10,496	)		(19,041	)		(20,652	)		(14,829	)		(31,148	)		(33,870	)
Interest income and other, net		1,399			2,241			1,608			(147	)		3,007			2,094

Income before income taxes		149,031			82,646			237,804			78,066			386,835			160,712
Income tax provision		(21,211	)		(15,025	)		(45,977	)		(9,157	)		(67,188	)		(24,182	)

Net income		127,820			67,621			191,827			68,909			319,647			136,530
Net loss attributable to noncontrolling interests		6,832			39
Net income attributable to noncontrolling interests								(18,857	)		(91	)		(12,025	)		(52	)

Net income attributable to Noble Corporation	$	134,652		$	67,660		$	172,970		$	68,818		$	307,622		$	136,478


	Three Months Ended						Three Months Ended						Six Months Ended
	March 31,						June 30,						June 30,
	2012			2011			2012			2011			2012			2011
Net income	$	127,820		$	67,621		$	191,827		$	68,909		$	319,647		$	136,530

Other comprehensive income (loss), net of tax
Foreign currency translation adjustments		(41	)		3,040			(6,949	)		1,375			(7,027	)		4,382
Gain on foreign currency forward contracts		2,417			162			644			2,351			3,061			2,513
Loss on interest rate swaps		—			(366	)		—			—			—			(366	)
Amortization of deferred pension plan amounts (net of tax provision of $720 in 2012 and $353 in 2011)		1,385			653
Amortization of deferred pension plan amounts (net of tax provision of $647 and $353 for the three months ended June 30, 2012 and 2011, respectively, and $1,367 and $705 for the six months ended June 30, 2012 and 2011, respectively)								1,404			689			2,826			1,375

Other comprehensive income, net		3,761			3,489
Other comprehensive income/(loss), net								(4,901	)		4,415			(1,140	)		7,904

Net comprehensive income attributable to noncontrolling interests		6,832			40			(18,857	)		(91	)		(12,025	)		(52	)

Comprehensive income attributable to Noble Corporation	$	138,413		$	71,150		$	168,069		$	73,233		$	306,482		$	144,382


	Three Months Ended						Six Months Ended
	March 31,						June 30,
	2012			2011			2012			2011
Cash flows from operating activities
Net income	$	127,820		$	67,621		$	319,647		$	136,530
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization		170,573			157,655			353,676			320,291
Loss on impairment								18,345			—
Gain on contract extinguishments, net		—			(21,202	)		—			(21,202	)
Deferred income taxes		(4,075	)		2,819			(7,765	)		(1,753	)
Capital contribution by parent—share-based compensation		5,070			5,151
Capital contribution by parent — share-based compensation								10,438			10,228
Net change in other assets and liabilities		(187,420	)		(118,545	)		(142,640	)		(197,617	)

Net cash from operating activities		111,968			93,499			551,701			246,477

Cash flows from investing activities
Capital expenditures		(367,325	)		(609,601	)		(663,700	)		(1,411,282	)
Change in accrued capital expenditures		(127,393	)		(471	)		(159,134	)		(51,500	)
Refund from contract extinguishments		—			18,642			—			18,642

Net cash from investing activities		(494,718	)		(591,430	)		(822,834	)		(1,444,140	)

Cash flows from financing activities
Borrowings on bank credit facilities		365,000			200,000			325,000			625,000
Repayments on bank credit facilities		(1,190,000	)		(240,000	)		(1,150,000	)		(240,000	)
Proceeds from issuance of senior notes, net of debt issuance costs		1,186,636			1,087,833			1,186,636			1,087,833
Contributions from joint venture partners		40,000			396,000			40,000			436,000
Payments of joint venture debt		—			(693,494	)		—			(693,494	)
Settlement of interest rate swaps		—			(29,032	)		—			(29,032	)
Financing costs on credit facilities		—			(2,835	)		(5,014	)		(2,835	)
Distributions to parent company, net		(52,727	)		(52,889	)		(92,675	)		(94,291	)

Net cash from financing activities		348,909			665,583			303,947			1,089,181

Net change in cash and cash equivalents		(33,841	)		167,652			32,814			(108,482	)
Cash and cash equivalents, beginning of period		235,056			333,399			235,056			333,399

Cash and cash equivalents, end of period	$	201,215		$	501,051		$	267,870		$	224,917


																												Accumulated
																							Capital in					Other
	Shares				Capital in Excess of		Retained			Accumulated Other Comprehensive			Noncontrolling			Total			Shares				Excess of		Retained			Comprehensive			Noncontrolling			Total
	Balance		Par Value		Par Value		Earnings			Loss			Interests			Equity			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		—		—		—		67,660			—			(39	)		67,621			—		—		—		136,478			—			52			136,530
Capital contributions by parent— share-based compensation		—		—		5,151		—			—			—			5,151
Capital contributions by parent — share-based compensation																				—		—		10,228		—			—			—			10,228
Distributions to parent		—		—		—		(52,889	)		—			—			(52,889	)		—		—		—		(94,291	)		—			—			(94,291	)
Noncontrolling interest contributions		—		—		—		—			—			361,000			361,000			—		—		—		—			—			473,973			473,973
Other comprehensive income (loss), net		—		—		—		—			3,489			(1	)		3,488
Other comprehensive income, net																				—		—		—		—			7,904			—			7,904

Balance at March 31, 2011		261,246	$	26,125	$	421,383	$	6,758,658		$	(46,731	)	$	485,591		$	7,645,026
Balance at June 30, 2011																				261,246	$	26,125	$	426,460	$	6,786,074		$	(42,316	)	$	598,656		$	7,794,999

Balance at December 31, 2011		261,246	$	26,125	$	450,616	$	6,979,882		$	(74,321	)	$	691,331		$	8,073,633			261,246	$	26,125	$	450,616	$	6,979,882		$	(74,321	)	$	691,331		$	8,073,633
Net income		—		—		—		134,652			—			(6,832	)		127,820			—		—		—		307,622			—			12,025			319,647
Capital contributions by parent— share-based compensation		—		—		5,070		—			—			—			5,070
Capital contributions by parent — share-based compensation																				—		—		10,438		—			—			—			10,438
Distributions to parent		—		—		—		(52,727	)		—			—			(52,727	)		—		—		—		(92,675	)		—			—			(92,675	)
Other																				—		—		—		—			—			(1,527	)		(1,527	)
Noncontrolling interest contributions		—		—		—		—			—			40,000			40,000			—		—		—		—			—			40,000			40,000
Other comprehensive income (loss), net		—		—		—		—			3,761			—			3,761
Other comprehensive loss, net																				—		—		—		—			(1,140	)		—			(1,140	)

Balance at March 31, 2012		261,246	$	26,125	$	455,686	$	7,061,807		$	(70,560	)	$	724,499		$	8,197,557
Balance at June 30, 2012																				261,246	$	26,125	$	461,054	$	7,194,829		$	(75,461	)	$	741,829		$	8,348,376

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

Noble Corporation, a Swiss corporation (“Noble-Swiss”), is a leading provider of offshore contract drilling services for the oil and gas industry. Our fleet of 79 mobile offshore drilling units consists of 14 semisubmersibles, 14 drillships, 49 jackups and two submersibles. Additionally, we have one floating production storage and offloading unit. Our fleet includes 11 units under construction as follows:

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

Noble Corporation, a Cayman Islands company (“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 recurring nature. The December 31, 2011 Consolidated Balance Sheets presented herein are derived from the December 31, 2011 audited consolidated financial statements. These interim financial statements should be read in conjunction with the consolidated financial statements and notes included in our Annual Report on Form 10-K for the year ended December 31, 2011, 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 reclassified to conform to the current year presentation. In connection with a review of the “Other Assets” caption in our financial statements, we determined that drilling equipment replacements and upgrades should be included in “Property and equipment”. As a result, we reclassified these amounts in our consolidated balance sheet for the year ended December 31, 2011. This reclassification is immaterial to the prior period financial statements.

We own a 50 percent interest in two joint ventures, each with a subsidiary of Royal Dutch Shell, PLC (“Shell”), for the construction and operation of our two Bully-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 interests are presented as noncontrolling interests on our Consolidated Balance Sheets.

In April 2011, the Bully joint venture partners entered into capital contribution agreements whereby capital calls up to a total of $360 million can be made for funds needed to complete the construction of the drillships. All contributions under these agreements were made during 2011 and the first quarter of 2012. No amounts remain available under these agreements.

At ~~March 31,~~June 30, 2012, the combined carrying amount of the drillships was $1.4 billion, which was primarily funded through ~~partner~~partners’ equity contributions.

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

The following is a detail of Noble-Swiss’ authorized share capital as of ~~March 31,~~June 30, 2012 and December 31, 2011:


					June 30,		December 31,
	March 31, 2012		December 31, 2011		2012		2011
Shares outstanding and trading		252,267		252,352		252,507		252,352
Treasury shares		463		287		569		287

Total shares outstanding		252,730		252,639		253,076		252,639

Treasury shares held for share-based compensation plans		13,420		13,511		13,074		13,511

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

Par value per share (in Swiss Francs)		3.28		3.41		3.15		3.41

Shares authorized for issuance by Noble-Swiss at March 31, 2012 totaled 266.2 million shares and include 0.5 million shares held in treasury and 13.4 million treasury shares held by a wholly-owned subsidiary. Repurchased treasury shares are recorded at cost, and include both shares repurchased pursuant to our Board of Directors 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 ~~March 31,~~June 30, 2012, 6.8 million shares remained available for repurchase under ~~previous~~the authorization by the Board of ~~Directors.~~Directors noted above. No shares were repurchased under this authorization during the ~~three~~six months ended ~~March 31,~~June 30, 2012.

Our Board of Directors may further increase Noble-Swiss’ share capital through the issuance of up to 133.1 million authorized registered shares without obtaining shareholder approval. The issuance of these authorized registered shares is subject to certain conditions regarding their use.

In April 2012, our shareholders approved the payment of a dividend funded from our capital contribution reserve ~~in a total amount equal to~~aggregating $0.52 per share to be paid in four equal installments scheduled for August 2012, November 2012, February 2013 and May 2013. These dividends will require us to make ~~total~~ cash payments of approximately $66 million in 2012, based on the number of shares currently outstanding. In connection with this approval and the resulting obligation to shareholders, we recorded dividends payable of approximately $133 million during the second quarter of ~~2012, we will record a payable of approximately $133 million, which represents this obligation to shareholders.~~2012. Any additional issuances of shares would further increase ~~this~~our obligation.

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

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 March 31,						June 30,						June 30,
	2012			2011			2012			2011			2012			2011
Allocation of net income
Basic
Net income attributable to Noble Corporation	$	120,175		$	54,495		$	159,818		$	54,083		$	279,993		$	108,578
Earnings allocated to unvested share-based payment awards		(1,126	)		(509	)		(1,694	)		(572	)		(2,797	)		(1,083	)

Net income to common shareholders—basic	$	119,049		$	53,986
Net income to common shareholders — basic							$	158,124		$	53,511		$	277,196		$	107,495

Diluted
Net income attributable to Noble Corporation	$	120,175		$	54,495		$	159,818		$	54,083		$	279,993		$	108,578
Earnings allocated to unvested share-based payment awards		(1,125	)		(509	)		(1,692	)		(572	)		(2,793	)		(1,082	)

Net income to common shareholders—diluted	$	119,050		$	53,986
Net income to common shareholders — diluted							$	158,126		$	53,511		$	277,200		$	107,496

Weighted average shares outstanding—basic		251,971			251,026
Weighted average shares outstanding — basic								252,387			251,368			252,179			251,198
Incremental shares issuable from assumed exercise of stock options		491			775			358			700			425			737

Weighted average shares outstanding—diluted		252,462			251,801
Weighted average shares outstanding — diluted								252,745			252,068			252,604			251,935

Weighted average unvested share-based payment awards		2,407			2,419			2,704			2,688			2,555			2,554

Earnings per share
Basic	$	0.47		$	0.22		$	0.63		$	0.21		$	1.10		$	0.43
Diluted	$	0.47		$	0.21		$	0.63		$	0.21		$	1.10		$	0.43

Only those items having a dilutive impact on our basic earnings per share are included in diluted earnings per share. At ~~March 31,~~June 30, 2012, stock options totaling approximately 1.2 million were excluded from the diluted earnings per share as they were not dilutive as compared to 0.7 million at ~~March 31,~~June 30, 2011.

Property and equipment, at cost, as of ~~March 31,~~June 30, 2012 and December 31, 2011 consisted of the following:


					June 30,		December 31,
	March 31, 2012		December 31, 2011		2012		2011
Drilling equipment and facilities	$	11,277,790	$	10,471,877	$	12,572,630	$	10,974,943
Construction in progress		3,893,858		4,367,750		3,289,005		4,367,750
Other		200,175		197,485		193,533		197,485

	$	15,371,823	$	15,037,112	$	16,055,168	$	15,540,178

Capital expenditures, including capitalized interest, totaled ~~$368~~$665 million and ~~$614 million~~$1.4 billion for the ~~three~~six months ended ~~March 31,~~June 30, 2012 and 2011, respectively. Capital expenditures for 2012 consisted of the following:

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

Interest is capitalized on construction-in-progress at the weighted average cost of debt outstanding during the period of construction. Capitalized interest was ~~$41~~$36 million and ~~$27~~$77 million for the three and six months ended June 30, 2012, respectively, as compared to $29 million and $56 million for the three and six months ended June 30, 2011.

During the second quarter of 2012, we determined that our submersible rig fleet, consisting of two cold stacked rigs, was partially impaired due to the declining market outlook for drilling services for this rig type. We estimated the fair value of the rigs based on the salvage value of the rigs and a recent transaction involving a similar unit owned by a peer company (Level 2 fair value measurement). Based on these estimates, we recognized a charge of approximately $13 million for the three months ended ~~March 31,~~June 30, 2012.

Also, during the second quarter of 2012, we determined that certain corporate assets were partially impaired due to a declining market for, and ~~2011, respectively.~~the potential disposal of, the assets. We estimated the fair value of the asset based on recent transactions involving similar units in the market (Level 2 fair value measurement). Based on these estimates, we recognized a charge of approximately $5 million for the three months ended June 30, 2012.

Note 56 — Gain on ~~contract extinguishments,~~Contract Settlements/Extinguishments, net

During the second quarter of 2012, we received approximately $5 million from the settlement of a claim relating to theNoble David Tinsley, which had experienced a “punch-through” while being positioned on location in 2009. We had originally recorded a $17 million charge during 2009 related to this incident. Additionally, during the second quarter of 2012, we settled an action against certain vendors for damages sustained during Hurricane Ike. We recognized a net gain of approximately $28 million related to this settlement. We also resolved all outstanding matters with Anadarko Petroleum Company (“Anadarko”) related to the previously disclosed force majeure action, Hurricane Ike matters and receivables relating to theNoble Amos Runner during the quarter.

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 connection with the cancellation of the contract 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 at acquisition. As a result of the substitution, we reached a decision not to proceed with the previously announced reliability upgrade to theNoble Muravlenko that 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. We expect the actual substitution to take place in the third quarter of 2012 after theNoble Phoenix completes its shipyard work.

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.

As discussed in Note 12, 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 the~~Noble 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. This matter is currently set for trial during the second quarter of 2012. Anadarko has also attempted to offset revenue that we had billed for services performed prior to their termination of the contract against other amounts it claims are owed relating to costs Anadarko incurred after Hurricane Ike, and that are the subject of a separate dispute (the “Hurricane Ike Case”). At March 31, 2012, 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 collection of these amounts or the outcome of this dispute.

In June 2010, a subsidiary of Frontier, which we acquired in July 2010, entered into a charter contract with a subsidiary of BP PLC (“BP”) for theSeillean with 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 was void 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 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 ~~March 31,~~June 30, 2012. ~~These~~While we recently received a favorable arbitration ruling, this matter has not been finally resolved and these receivables ~~have been~~continue to be classified as long-term and are included in “Other assets” on our Consolidated Balance Sheet at ~~March 31,~~June 30, 2012. We believe that if BP were to be successful in claiming the contractvoid ab initio, we ~~would~~may have an indemnity claim against the former shareholders of Frontier. We have put the former ~~owners~~shareholders of Frontier on notice of this potential claim. We can make no assurances as to the outcome of this dispute.

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

At ~~March 31,~~June 30, 2012, we had receivables of approximately $14 million related to theNoble Max Smith, which are being disputed by our customer, Pemex Exploracion y Produccion (“Pemex”). These receivables have been classified as long-term and are included in “Other assets” on our Consolidated Balance Sheet at ~~March 31,~~June 30, 2012. The disputed amount relates to lost revenues due from Pemex for downtime that occurred after our rig was damaged when one of Pemex’s supply boats collided with our rig. In January 2012, we filed a lawsuit against Pemex in Mexican court seeking recovery of these amounts. While we ~~believe we are entitled to the disputed amounts, we~~ can make no assurances as to the outcome of this ~~dispute.~~

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

Total debt consisted of the following at ~~March 31,~~June 30, 2012 and December 31, 2011:


					June 30,		December 31,
	March 31, 2012		December 31, 2011		2012		2011
Wholly-owned debt instruments:
5.875% Senior Notes due 2013	$	299,957	$	299,949	$	299,966	$	299,949
7.375% Senior Notes due 2014		249,684		249,647		249,722		249,647
3.45% Senior Notes due 2015		350,000		350,000		350,000		350,000
3.05% Senior Notes due 2016		299,941		299,938		299,945		299,938
2.50% Senior Notes due 2017		299,827		—		299,836		—
7.50% Senior Notes due 2019		201,695		201,695		201,695		201,695
4.90% Senior Notes due 2020		498,811		498,783		498,840		498,783
4.625% Senior Notes due 2021		399,492		399,480		399,503		399,480
3.95% Senior Notes due 2022		399,035		—		399,054		—
6.20% Senior Notes due 2040		399,891		399,890		399,891		399,890
6.05% Senior Notes due 2041		397,590		397,582		397,598		397,582
5.25% Senior Notes due 2042		498,238		—		498,244		—
Credit facilities		150,000		975,000		150,000		975,000

Total long-term debt	$	4,444,161	$	4,071,964	$	4,444,294	$	4,071,964

During June 2012, we replaced our $575 million credit facility, which was scheduled to mature in 2013, with a new $1.2 billion credit facility which matures in 2017. We ~~have two separate revolving~~continue to maintain our $600 million credit ~~facilities~~facility, which matures in ~~place~~2015, which ~~provide~~combined with our new facility, gives us ~~with~~ a total borrowing capacity ~~of approximately $1.18 billion. One credit facility, which has a capacity of $575 million, matures in 2013, and~~under the ~~other facility, which has a capacity of $600 million, matures in 2015~~two facilities (together referred to as the “Credit Facilities”). of $1.8 billion. 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. At ~~March 31,~~June 30, 2012, our ratio of debt to total tangible capitalization was ~~less than 0.36 for the Credit Facilities.~~0.35. We were in compliance with all covenants under the Credit Facilities as of ~~March 31,~~June 30, 2012.

In February 2012, we issued, through our indirect wholly-owned subsidiary, Noble Holding International Limited (“NHIL”), $1.2 billion aggregate principal amount of senior notes in three separate tranches, with $300 million of 2.50% Senior Notes due 2017, $400 million of 3.95% Senior Notes due 2022, and $500 million of 5.25% Senior Notes due 2042. The weighted average coupon of all three tranches is 4.13%. The net proceeds of approximately $1.19 billion, after expenses, were primarily used to repay the then outstanding balance on our Credit Facilities.

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

Our 5.875% Senior Notes mature during the second quarter of 2013. We anticipate using availability under our Credit Facilities to repay the outstanding balance; therefore, we have continued to report the balance as long-term on our June 30, 2012 Consolidated Balance Sheet.

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 ~~March 31,~~June 30, 2012, 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 2012, expect to remain in compliance during the year.

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

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 (Level 2 measurement). The following table presents the estimated fair value of our long-term debt as of ~~March 31,~~June 30, 2012 and December 31, 2011.


									June 30, 2012				December 31, 2011
	March 31, 2012				December 31, 2011				Carrying		Estimated		Carrying		Estimated
	Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value		Value		Fair Value		Value		Fair Value
Wholly-owned debt instruments
5.875% Senior Notes due 2013	$	299,957	$	316,003	$	299,949	$	317,586	$	299,966	$	312,362	$	299,949	$	317,586
7.375% Senior Notes due 2014		249,684		277,685		249,647		278,966		249,722		274,275		249,647		278,966
3.45% Senior Notes due 2015		350,000		367,520		350,000		363,571		350,000		367,465		350,000		363,571
3.05% Senior Notes due 2016		299,941		308,804		299,938		306,057		299,945		309,804		299,938		306,057
2.50% Senior Notes due 2017		299,827		301,653		—		—		299,836		303,649		—		—
7.50% Senior Notes due 2019		201,695		246,435		201,695		248,623		201,695		248,719		201,695		248,623
4.90% Senior Notes due 2020		498,811		536,850		498,783		531,437		498,840		538,532		498,783		531,437
4.625% Senior Notes due 2021		399,492		424,808		399,480		416,847		399,503		424,232		399,480		416,847
3.95% Senior Notes due 2022		399,035		400,535		—		—		399,054		404,017		—		—
6.20% Senior Notes due 2040		399,891		440,619		399,890		450,017		399,891		444,713		399,890		450,017
6.05% Senior Notes due 2041		397,590		433,771		397,582		443,308		397,598		436,205		397,582		443,308
5.25% Senior Notes due 2042		498,238		494,298		—		—		498,244		496,435		—		—
Credit facilities		150,000		150,000		975,000		975,000
Credit Facilities										150,000		150,000		975,000		975,000

Total long-term debt	$	4,444,161	$	4,698,981	$	4,071,964	$	4,331,412	$	4,444,294	$	4,710,408	$	4,071,964	$	4,331,412

At December 31, 2011, the reserves for uncertain tax positions totaled $118 million (net of related tax benefits of $8 million). At ~~March 31,~~June 30, 2012, the reserves for uncertain tax positions totaled ~~$125~~$115 million (net of related tax benefits of $9$8 million). If the ~~March 31,~~June 30, 2012 reserves are not realized, the provision for income taxes would be reduced by ~~$125 million.~~$115 million in future periods.

It is possible that our existing liabilities related to our reserve for uncertain tax positions may increase or decrease in the next twelve months primarily due to 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 due to various uncertainties, such as the unresolved nature of various audits.

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

During the three and six months ended ~~March 31,~~June 30, 2012, ~~and 2011,~~ we made contributions to our pension plans totaling $4$6 million and $2$10 million, respectively. We expect the funding to our non-U.S. and U.S. plans in 2012, subject to applicable law, to be approximately ~~$19~~$21 million.

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 are we a party to leveraged derivatives. During the ~~three~~six months ended ~~March 31,~~June 30, 2011, we maintained certain foreign 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.

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~~have historically maintained short-term forward contracts settling monthly in their respective local currencies. ~~The forward contract settlements in the remainder of~~At June 30, 2012, ~~represent approximately 10 percent of these forecasted local currency requirements. The notional amount of the forward contracts~~we had no outstanding expressed in U.S. Dollars, was approximately $13 million at March 31, 2012. Total unrealized loss related to these forward contracts was $0.6 million as of March 31, 2012 and was recorded as part of “Accumulated other comprehensive loss” (“AOCL”).derivative contracts.

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

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

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

The following tables, together with Note ~~11,~~12, summarize the financial statement presentation and fair value of our derivative positions as of ~~March 31,~~June 30, 2012 and December 31, 2011:

Estimated fair value

Balance sheet
classification

March 31,
2012

December 31,
2011

Balance sheet
classification

June 30, 2012

December 31,
2011

Liability derivatives

Cash flow hedges

Short-term foreign currency forward contracts

Other current liabilities

644

3,061

Other current liabilities

—

3,061

To supplement the fair value disclosures in Note ~~11,~~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 ~~March 31,~~June 30, 2012 and 2011:


	Gain/(loss) recognized through AOCL				Gain/(loss) reclassified from AOCL to “other income”					Gain/(loss) recognized through “other income”					Gain/(loss) recognized through AOCL				Gain/(loss) reclassified from AOCL to “other income”					Gain/(loss) recognized through “other income”
	2012		2011		2012			2011		2012		2011			2012		2011		2012			2011		2012		2011
Cash flow hedges
Foreign currency forward contracts	$	299	$	1,314	$	(2,118	)	$	1,152	$	—	$	—		$	—	$	3,152	$	(644	)	$	801	$	—	$	—
Non-designated derivatives
Foreign currency forward contracts	$	—	$	—	$	—		$	—	$	—	$	(546	)

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

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 six months ended June 30, 2012 and 2011:

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


	March 31, 2012								December 31, 2011				June 30, 2012								December 31, 2011
			Estimated Fair Value Measurements												Estimated Fair Value Measurements
	Carrying Amount		Quoted Prices in Active Markets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Carrying Amount		Estimated Fair Value				Quoted		Significant
Assets—
															Prices in		Other		Significant
															Active		Observable		Unobservable
													Carrying		Markets		Inputs		Inputs		Carrying		Estimated
													Amount		(Level 1)		(Level 2)		(Level 3)		Amount		Fair Value
Assets -
Marketable securities	$	5,346	$	5,346	$	—	$	—	$	4,701	$	4,701	$	5,247	$	5,247	$	—	$	—	$	4,701	$	4,701
Liabilities—
Liabilities -
Foreign currency forward contracts	$	644	$	—	$	644	$	—	$	3,061	$	3,061	$	—	$	—	$	—	$	—	$	3,061	$	3,061

~~The~~At the time of valuation, the derivative instruments ~~have been~~were 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.

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

As discussed in Note 6, in May 2010 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 the~~Noble 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. This matter is currently set for trial during the second quarter of 2012. 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 should the court ultimately rule in our favor.

A separate dispute with Anadarko relating to Hurricane Ike costs is the subject of a lawsuit brought by Anadarko after the initiation of the force majeure action described above. In the Hurricane Ike Case, which was filed in August 2010, Anadarko is seeking to recover various costs and damages including damages to recover two of our rigs under contract to Anadarko, costs that it may incur in the future to recover mooring components from the sea floor and costs Anadarko claims were incurred for a mooring upgrade of the two rigs. The Hurricane Ike Case had been consolidated in the Federal District Court in Houston, Texas with an action we initiated in September 2009 against a manufacturer of wire ropes, Bridon-American Corp. and Bridon International, Ltd (collectively, “Bridon”), and their distributor, Certex USA Inc., for damages we sustained after Bridon wire ropes parted on several of our drilling rigs during Hurricane Ike. The court granted our motion for summary judgment against Anadarko in this case. This ruling can be appealed by Anadarko. We do not believe Anadarko’s claims in the Hurricane Ike Case are meritorious and believe the likelihood of success by Anadarko is remote for the vast majority of damages it seeks in that case. The consolidated Bridon/Certex case is currently set for trial in the second quarter of 2012. While we do not believe Anadarko’s claims in this case are meritorious, we can make no assurances as to the outcome of this dispute.

~~The~~Noble Homer Ferrington iswas under contract with a subsidiary of ExxonMobil Corporation (“ExxonMobil”), ~~who~~which entered into an assignment agreement with BP for a two well farmout 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 ~~continues to be~~was fully ready to operate under the drilling contract. The rig ~~has been operating~~operated under ~~farm-out~~farmout arrangements ~~since~~from March ~~2011.~~2011 to the conclusion of the contract in the second quarter of 2012. 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~~The arbitration process is proceeding, and we 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 should the arbitration panel ultimately rule in our favor.

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

In August 2007, we entered into a drilling contract with Marathon Oil Company (“Marathon”) for theNoble Jim Day to 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. No revenue has been recognized under this contract. We have contracted the rig for much of the original term with other customers. In March 2011, we filed suit in Texas 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.

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

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 previously informed the Nigerian Content Division of its position that we were 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 previously 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.

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 ~~March 31,~~June 30, 2012, there were 2426 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 6,7, 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. The U.S. Internal Revenue Service (“IRS”) has completed its audit examination of our 2008 U.S. tax return and proposed adjustments and deficiencies with respect to certain items that were reported by us for the 2008 tax year. We believe that we have accurately reported all amounts in our 2008 tax return, and have filed protests with the IRS Office of Appeals contesting the examination team’s proposed adjustments. We intend to vigorously defend our reported positions. ~~We have recently been informed by the IRS that our~~Our 2009 tax return is under ~~audit. We~~audit, and we expect to receive ~~more~~additional Information Document Requests in the coming months. In addition, a U.S. subsidiary of Frontier is also under audit by the IRS 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 disagree with those assessments based on the technical merits of the positions established at the time of the filing of the tax return. 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. We cannot predict or provide assurance as to the ultimate outcome of the existing or future assessments.

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

~~Certain of our non-U.S.~~Our Mexican income tax returns have been examined for the 2002 through ~~2008~~2007 periods and audit claims have been assessed for approximately ~~$279~~$297 million (including interest and penalties)~~, primarily in Mexico. In Mexico, these assessments total approximately $266 million. We recently~~. During 2011, we received from the Regional Chamber of the Federal Tax Court adverse decisions with respect to approximately $6$5 million in assessments related to depreciation deductions, which we are appealing. We are also contesting all other assessments in Mexico. Tax authorities in Mexico and other jurisdictions may issue additional assessments or pursue legal actions as a result of tax audits and we cannot predict or provide assurance as to the ultimate outcome of such assessments and legal actions.

Additional audit claims of approximately ~~$83~~$75 million attributable to customs and other business taxes have been assessed against us in other jurisdictions. We have contested, or intend to contest, these assessments, including through litigation if necessary, and we believe the ultimate resolution, for which we have not made any accrual, will not have a material adverse effect on our consolidated financial statements.

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

We maintain certain insurance coverage against specified marine perils which includes physical damage and loss of hire. Damage caused by hurricanes has negatively impacted the energy insurance market, resulting in more restrictive and expensive coverage for U.S. named windstorm perils. Accordingly, we have elected to significantly reduce the named windstorm insurance on our rigs operating in the U.S. Gulf of Mexico. Presently we insure theNoble Jim Thompson,Noble Amos Runner andNoble ~~Drille~~Drillerr for “total loss only” when caused by a named windstorm. Our customer assumes the risk of loss on theNoble Bully I due to a named windstorm event up to $450 million per occurrence pursuant to the terms of the drilling contract relating to such vessel, provided that we are responsible for the first $25 million per occurrence for such named windstorm events. The remaining rigs in the U.S. Gulf of Mexico are self-insured for named windstorm perils. Our rigs located in the Mexico portion of the Gulf of Mexico remain covered by commercial insurance for windstorm damage. In addition, we maintain physical damage deductibles on our rigs ranging from $15 million to $25 million per occurrence, depending on location. 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 January 2012, we were assessed a fine by the Brazilian government in the amount of R$1.8 million (approximately ~~$950,000)~~$900,000) in connection with the inadvertent discharge of drilling fluid from one of our rigs offshore Brazil in September 2011. We have accepted the assessment.

In October 2011, we were assessed a fine by the Brazilian government in the amount of R$238,000 (approximately ~~$135,000)~~$120,000) in connection with the inadvertent discharge of drilling fluid from one of our rigs offshore Brazil in November 2010. We have accepted the assessment.

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 ~~$3.0~~$3.1 billion at ~~March 31,~~June 30, 2012.

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

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.

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

As previously disclosed, in November 2010 we finalized settlements with the SEC and the Department of Justice as the result 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 January 2011, a subsidiary of Noble-Swiss resolved an investigation by the Nigerian Economic and Financial Crimes Commission and the Nigerian Attorney General Office into these same activities. Any additional investigation by these or other agencies 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 additional investigations could be expensive and consume significant time and attention of our senior management.

As of March 31, 2012, all four 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.

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

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 segment currently conducts contract drilling operations principally in the U.S. Gulf of Mexico, Mexico, Brazil, the North Sea, the Mediterranean, West Africa, the Middle East, India 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 months ended March 31, 2012 and 2011 for Noble-Swiss and Noble-Cayman are 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.

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

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 months ended June 30, 2012 and 2011 for Noble-Swiss and Noble-Cayman are 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.

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

In May 2011, the FASB issued Accounting Standards Update (“ASU”) No. 2011-04, which amends FASB Accounting Standards Codification (“ASC”) Topic 820, “Fair Value Measurements and Disclosures.” This amended guidance clarifies 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. Our adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In June 2011, the FASB issued ASU No. 2011-05, which amends ASC Topic 220, “Comprehensive Income.” This ASU 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. Our adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

~~The net effect of changes in other assets and liabilities on cash flows from Noble-Swiss’ operating activities are as follows:~~

~~The net effect of changes in other assets and liabilities on cash flows from Noble-Cayman’s operating activities are as follows:~~

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

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

Noble-Cayman, or one or more subsidiaries of Noble-Cayman, are a co-issuer or guarantor or otherwise obligated as of ~~March 31,~~June 30, 2012 as follows:

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																					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	$	146	$	385		$	—		$	—	$	—	$	234,525		$	—		$	235,056		$	146	$	385		$	—		$	—	$	—	$	234,525		$	—		$	235,056
Accounts receivable		—		10,810			3,371			—		—		572,982			—			587,163			—		10,810			3,371			—		—		572,982			—			587,163
Taxes receivable		—		4,566			—			—		—		70,718			—			75,284			—		4,566			—			—		—		70,718			—			75,284
Prepaid expenses		—		453			19			—		—		32,633			—			33,105			—		453			19			—		—		32,633			—			33,105
Short-term notes receivable from affiliates		—		119,476			—			—		—		122,298			(241,774	)		—			—		119,476			—			—		—		122,298			(241,774	)		—
Accounts receivable from affiliates		1,683,740		99,202			879,581			159,132		33,905		6,372,657			(9,228,217	)		—			1,683,740		99,202			879,581			159,132		33,905		6,372,657			(9,228,217	)		—
Other current assets		—		643			196			93		—		119,177			—			120,109			—		643			196			93		—		119,177			—			120,109

Total current assets		1,683,886		235,535			883,167			159,225		33,905		7,524,990			(9,469,991	)		1,050,717			1,683,886		235,535			883,167			159,225		33,905		7,524,990			(9,469,991	)		1,050,717

Property and equipment, at cost		—		2,718,186			71,381			—		—		12,213,361			—			15,002,928			—		2,737,764			75,001			—		—		12,693,229			—			15,505,994
Accumulated depreciation		—		(220,662	)		(53,037	)		—		—		(2,860,702	)		—			(3,134,401	)		—		(232,621	)		(54,599	)		—		—		(3,117,369	)		—			(3,404,589	)

Property and equipment, net		—		2,497,524			18,344			—		—		9,352,659			—			11,868,527			—		2,505,143			20,402			—		—		9,575,860			—			12,101,405

Notes receivable from affiliates		3,842,062		675,000			—			2,336,527		572,107		2,678,192			(10,103,888	)		—			3,842,062		675,000			—			2,336,527		572,107		2,678,192			(10,103,888	)		—
Investments in affiliates		6,969,201		9,101,938			3,450,212			6,605,771		2,141,450		—			(28,268,572	)		—			6,969,201		9,101,938			3,450,212			6,605,771		2,141,450		—			(28,268,572	)		—
Other assets		3,230		8,092			2,541			18,548		880		504,870			—			538,161			3,230		473			483			18,548		880		281,669			—			305,283

Total assets	$	12,498,379	$	12,518,089		$	4,354,264		$	9,120,071	$	2,748,342	$	20,060,711		$	(47,842,451	)	$	13,457,405		$	12,498,379	$	12,518,089		$	4,354,264		$	9,120,071	$	2,748,342	$	20,060,711		$	(47,842,451	)	$	13,457,405

LIABILITIES AND EQUITY
Current liabilities
Short-term notes payables from affiliates	$	72,298	$	50,000		$	—		$	—	$	—	$	119,476		$	(241,774	)	$	—		$	72,298	$	50,000		$	—		$	—	$	—	$	119,476		$	(241,774	)	$	—
Accounts payable		—		5,577			985			—		—		429,167			—			435,729			—		5,577			985			—		—		429,167			—			435,729
Accrued payroll and related costs		—		2,897			6,518			—		—		99,493			—			108,908			—		2,897			6,518			—		—		99,493			—			108,908
Accounts payable to affiliates		2,079,719		4,166,021			27,341			112,953		34,107		2,808,076			(9,228,217	)		—			2,079,719		4,166,021			27,341			112,953		34,107		2,808,076			(9,228,217	)		—
Interest payable		1,891		—			—			48,116		4,412		—			—			54,419			1,891		—			—			48,116		4,412		—			—			54,419
Taxes payable		—		10,032			—			—		—		81,158			—			91,190			—		10,032			—			—		—		81,158			—			91,190
Other current liabilities		—		—			240			—		—		123,159			—			123,399			—		—			240			—		—		123,159			—			123,399

Total current liabilities		2,153,908		4,234,527			35,084			161,069		38,519		3,660,529			(9,469,991	)		813,645			2,153,908		4,234,527			35,084			161,069		38,519		3,660,529			(9,469,991	)		813,645

Long-term debt		1,274,949		—			—			2,595,320		201,695		—			—			4,071,964			1,274,949		—			—			2,595,320		201,695		—			—			4,071,964
Notes payable to affiliates		1,667,291		1,147,500			85,000			975,000		811,000		5,418,097			(10,103,888	)		—			1,667,291		1,147,500			85,000			975,000		811,000		5,418,097			(10,103,888	)		—
Deferred income taxes		—		—			15,731			—		—		227,060			—			242,791			—		—			15,731			—		—		227,060			—			242,791
Other liabilities		19,929		24,878			—			—		—		210,565			—			255,372			19,929		24,878			—			—		—		210,565			—			255,372

Total liabilities		5,116,077		5,406,905			135,815			3,731,389		1,051,214		9,516,251			(19,573,879	)		5,383,772			5,116,077		5,406,905			135,815			3,731,389		1,051,214		9,516,251			(19,573,879	)		5,383,772

Commitments and contingencies

Total shareholder equity		7,382,302		7,111,184			4,218,449			5,388,682		1,697,128		9,853,129			(28,268,572	)		7,382,302			7,382,302		7,111,184			4,218,449			5,388,682		1,697,128		9,853,129			(28,268,572	)		7,382,302
Noncontrolling interest		—		—			—			—		—		691,331			—			691,331			—		—			—			—		—		691,331			—			691,331

Total equity		7,382,302		7,111,184			4,218,449			5,388,682		1,697,128		10,544,460			(28,268,572	)		8,073,633			7,382,302		7,111,184			4,218,449			5,388,682		1,697,128		10,544,460			(28,268,572	)		8,073,633

Total liabilities and equity	$	12,498,379	$	12,518,089		$	4,354,264		$	9,120,071	$	2,748,342	$	20,060,711		$	(47,842,451	)	$	13,457,405		$	12,498,379	$	12,518,089		$	4,354,264		$	9,120,071	$	2,748,342	$	20,060,711		$	(47,842,451	)	$	13,457,405


																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	$	—		$	42,991		$	5,061		$	—		$	—		$	718,076		$	(19,818	)	$	746,310		$	—		$	38,348		$	4,819		$	—		$	—		$	824,684		$	(19,614	)	$	848,237
Reimbursables		—			5,308			—			—			—			29,833			—			35,141			—			502			—			—			—			30,310			—			30,812
Labor contract drilling services		—			—			—			—			—			16,008			—			16,008			—			—			—			—			—			19,863			—			19,863
Other		—			—			—			—			—			231			—			231			—			—			—			—			—			943			(932	)		11

Total operating revenues		—			48,299			5,061			—			—			764,148			(19,818	)		797,690			—			38,850			4,819			—			—			875,800			(20,546	)		898,923

Operating costs and expenses
Contract drilling services		1,183			14,319			1,771			17,633			—			400,058			(19,818	)		415,146			1,256			14,375			1,839			18,779			—			405,895			(20,546	)		421,598
Reimbursables		—			5,087			—			—			—			25,514			—			30,601			—			338			—			—			—			24,632			—			24,970
Labor contract drilling services		—			—			—			—			—			9,232			—			9,232			—			—			—			—			—			11,847			—			11,847
Depreciation and amortization		—			14,839			1,036			—			—			154,698			—			170,573			—			15,238			1,061			—			—			166,804			—			183,103
Selling, general and administrative		357			1,346			—			8,819			—			3,488			—			14,010			454			1,465			—			9,618			—			3,930			—			15,467
Loss on impairment																										—			—			—			—			—			18,345			—			18,345
Gain on contract settlements/extinguishments, net																										—			(4,869	)		—			—			—			(28,386	)		—			(33,255	)

Total operating costs and expenses		1,540			35,591			2,807			26,452			—			592,990			(19,818	)		639,562			1,710			26,547			2,900			28,397			—			603,067			(20,546	)		642,075

Operating income (loss)		(1,540	)		12,708			2,254			(26,452	)		—			171,158			—			158,128			(1,710	)		12,303			1,919			(28,397	)		—			272,733			—			256,848

Other income (expense)
Equity earnings in affiliates, net of tax		155,412			134,585			45,802			179,928			75,861			—			(591,588	)		—			197,409			154,580			10,078			230,830			69,542			—			(662,439	)		—
Interest expense, net of amounts capitalized		(20,606	)		(14,914	)		(1,346	)		(20,972	)		(7,783	)		(19,896	)		75,021			(10,496	)		(25,294	)		(14,003	)		(842	)		(29,494	)		(11,405	)		(20,076	)		80,462			(20,652	)
Interest income and other, net		1,386			7,824			16			29,254			3,110			34,830			(75,021	)		1,399			2,565			10,867			(21	)		32,925			2,815			32,919			(80,462	)		1,608

Income before income taxes		134,652			140,203			46,726			161,758			71,188			186,092			(591,588	)		149,031			172,970			163,747			11,134			205,864			60,952			285,576			(662,439	)		237,804
Income tax provision		—			(8,776	)		—			—			—			(12,435	)		—			(21,211	)		—			(13,487	)		—			—			—			(32,490	)		—			(45,977	)

Net Income		134,652			131,427			46,726			161,758			71,188			173,657			(591,588	)		127,820			172,970			150,260			11,134			205,864			60,952			253,086			(662,439	)		191,827
Net loss attributable to noncontrolling interests		—			—			—			—			—			6,832			—			6,832
Net income attributable to noncontrolling interests																										—			—			—			—			—			(18,857	)		—			(18,857	)

Net income attributable to Noble Corporation		134,652			131,427			46,726			161,758			71,188			180,489			(591,588	)		134,652			172,970			150,260			11,134			205,864			60,952			234,229			(662,439	)		172,970

Other comprehensive income, net		3,761			—			—			—			—			3,761			(3,761	)		3,761
Other comprehensive loss, net																										(4,901	)		—			—			—			—			(4,901	)		4,901			(4,901	)

Comprehensive income attributable to Noble Corporation	$	138,413		$	131,427		$	46,726		$	161,758		$	71,188		$	184,250		$	(595,349	)	$	138,413		$	168,069		$	150,260		$	11,134		$	205,864		$	60,952		$	229,328		$	(657,538	)	$	168,069


																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	$	—		$	25,964		$	4,990		$	—		$	—		$	523,594		$	(11,943	)	$	542,605		$	—		$	35,090		$	4,705		$	—		$	—		$	566,145		$	(16,390	)	$	589,550
Reimbursables		—			912			12			—			—			21,367			—			22,291			—			1,778			—			—			—			22,344			—			24,122
Labor contract drilling services		—			—			—			—			—			13,547			—			13,547			—			—			—			—			—			14,012			—			14,012
Other		—			—			—			—			—			445			—			445			—			—			—			—			—			313			—			313

Total operating revenues		—			26,876			5,002			—			—			558,953			(11,943	)		578,888			—			36,868			4,705			—			—			602,814			(16,390	)		627,997

Operating costs and expenses
Contract drilling services		1,461			8,984			1,823			8,570			—			291,937			(11,943	)		300,832			1,598			12,085			1,975			8,236			—			322,700			(16,390	)		330,204
Reimbursables		—			904			—			—			—			16,199			—			17,103			—			2,007			—			—			—			16,716			—			18,723
Labor contract drilling services		—			—			—			—			—			8,523			—			8,523			—			—			—			—			—			8,750			—			8,750
Depreciation and amortization		—			10,124			909			—			—			146,622			—			157,655			—			13,068			935			—			—			148,633			—			162,636
Selling, general and administrative		1,511			1,509			—			7,877			—			5,634			—			16,531			1,792			1,209			—			7,626			1			4,014			—			14,642
Gain on contract extinguishments, net		—			—			—			—			—			(21,202	)		—			(21,202	)		—			—			—			—			—			—			—			—

Total operating costs and expenses		2,972			21,521			2,732			16,447			—			447,713			(11,943	)		479,442			3,390			28,369			2,910			15,862			1			500,813			(16,390	)		534,955

Operating income (loss)		(2,972	)		5,355			2,270			(16,447	)		—			111,240			—			99,446			(3,390	)		8,499			1,795			(15,862	)		(1	)		102,001			—			93,042

Other income (expense)
Equity earnings in affiliates, net of tax		87,280			37,939			15,801			50,061			35,820			—			(226,901	)		—			88,486			64,434			19,176			122,310			71,736			—			(366,142	)		—
Interest expense, net of amounts capitalized		(18,361	)		(14,592	)		(1,820	)		(22,496	)		(7,671	)		(2,131	)		48,030			(19,041	)		(17,903	)		(15,323	)		(1,719	)		(23,530	)		(7,271	)		(886	)		51,803			(14,829	)
Interest income and other, net		1,713			5,538			11			11,309			1,792			29,908			(48,030	)		2,241			1,625			6,932			37			11,435			2,252			29,375			(51,803	)		(147	)

Income before income taxes		67,660			34,240			16,262			22,427			29,941			139,017			(226,901	)		82,646			68,818			64,542			19,289			94,353			66,716			130,490			(366,142	)		78,066
Income tax provision		—			(858	)		—			—			—			(14,167	)		—			(15,025	)		—			6,658			—			—			—			(15,815	)		—			(9,157	)

Net Income		67,660			33,382			16,262			22,427			29,941			124,850			(226,901	)		67,621			68,818			71,200			19,289			94,353			66,716			114,675			(366,142	)		68,909
Net loss attributable to noncontrolling interests		—			—			—			—			—			39			—			39
Net income attributable to noncontrolling interests																										—			—			—			—			—			(91	)		—			(91	)

Net income attributable to Noble Corporation		67,660			33,382			16,262			22,427			29,941			124,889			(226,901	)		67,660			68,818			71,200			19,289			94,353			66,716			114,584			(366,142	)		68,818

Other comprehensive income, net		3,489			—			—			—			—			3,489			(3,489	)		3,489			4,415			—			—			—			—			4,415			(4,415	)		4,415
Net comprehensive loss attributable to noncontrolling interest		—			—			—			—			—			1			—			1

Comprehensive income attributable to Noble Corporation	$	71,149		$	33,382		$	16,262		$	22,427		$	29,941		$	128,379		$	(230,390	)	$	71,150		$	73,233		$	71,200		$	19,289		$	94,353		$	66,716		$	118,999		$	(370,557	)	$	73,233


																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	$	(11,189	)	$	9,223	��	$	4,529		$	(53,966	)	$	(8,425	)	$	171,796		$	—		$	111,968		$	(39,135	)	$	8,929		$	4,457		$	(32,947	)	$	(13,203	)	$	623,600		$	—		$	551,701

Cash flows from investing activities
Capital expenditures		—			(136,890	)		—			—			—			(230,435	)		—			(367,325	)		—			(182,619	)		(306	)		—			—			(480,775	)		—			(663,700	)
Change in accrued capital expenditures		—			—			—			—			—			(127,393	)		—			(127,393	)		—			—			—			—			—			(159,134	)		—			(159,134	)
Notes receivable from affiliates		—			—			—			(1,188,287	)		—			—			1,188,287			—			—			—			—			(1,188,287	)		—			—			1,188,287			—

Net cash from investing activities		—			(136,890	)		—			(1,188,287	)		—			(357,828	)		1,188,287			(494,718	)		—			(182,619	)		(306	)		(1,188,287	)		—			(639,909	)		1,188,287			(822,834	)

Cash flows from financing activities
Borrowings on bank credit facilities		365,000			—			—			—			—			—			—			365,000			325,000			—			—			—			—			—			—			325,000
Repayments on bank credit facilities		(1,190,000	)		—			—			—			—			—			—			(1,190,000	)		(1,150,000	)		—			—			—			—			—			—			(1,150,000	)
Proceeds from issuance of senior notes, net		—			—			—			1,186,636			—			—			—			1,186,636			—			—			—			1,186,636			—			—			—			1,186,636
Contributions from joint venture partners		—			—			—			—			—			40,000			—			40,000			—			—			—			—			—			40,000			—			40,000
Financing costs on credit facilities																										(5,014	)		—			—			—			—			—			—			(5,014	)
Distributions to parent		(52,727	)		—			—			—			—			—			—			(52,727	)		(92,675	)		—			—			—			—			—			—			(92,675	)
Advances (to) from affiliates		(274,544	)		127,546			(4,529	)		55,621			8,425			87,481			—			—			(226,514	)		173,636			(4,151	)		34,602			13,203			9,224			—			—
Notes payable to affiliates		1,188,287			—			—			—			—			—			(1,188,287	)		—			1,188,287			—			—			—			—			—			(1,188,287	)		—

Net cash from financing activities		36,016			127,546			(4,529	)		1,242,257			8,425			127,481			(1,188,287	)		348,909			39,084			173,636			(4,151	)		1,221,238			13,203			49,224			(1,188,287	)		303,947

Net change in cash and cash equivalents		24,827			(121	)		—			4			—			(58,551	)		—			(33,841	)		(51	)		(54	)		—			4			—			32,915			—			32,814
Cash and cash equivalents, beginning of period		146			385			—			—			—			234,525			—			235,056			146			385			—			—			—			234,525			—			235,056

Cash and cash equivalents, end of period	$	24,973		$	264		$	—		$	4		$	—		$	175,974		$	—		$	201,215		$	95		$	331		$	—		$	4		$	—		$	267,440		$	—		$	267,870


																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	$	(12,580	)	$	6,411		$	2,762		$	(48,978	)	$	(9,633	)	$	155,517		$	—		$	93,499		$	(30,984	)	$	23,361		$	2,591		$	(43,770	)	$	(10,840	)	$	306,119		$	—		$	246,477

Cash flows from investing activities
Capital expenditures		—			(318,916	)		—			—			—			(290,685	)		—			(609,601	)		—			(846,292	)		(197	)		—			—			(564,793	)		—			(1,411,282	)
Change in accrued capital expenditures		—			—			—			—			—			(471	)		—			(471	)		—			—			—			—			—			(51,500	)		—			(51,500	)
Notes receivable from affiliates		—			—			—			—			—			2,000			(2,000	)		—			20,000			—			—			—			—			91,000			(111,000	)		—
Refund from contract extinguishments		—			—			—			—			—			18,642			—			18,642			—			—			—			—			—			18,642			—			18,642

Net cash from investing activities		—			(318,916	)		—			—			—			(270,514	)		(2,000	)		(591,430	)		20,000			(846,292	)		(197	)		—			—			(506,651	)		(111,000	)		(1,444,140	)

Cash flows from financing activities
Borrowings on bank credit facilities		200,000			—			—			—			—			—			—			200,000			625,000			—			—			—			—			—			—			625,000
Repayments on bank credit facilities		(240,000	)		—			—			—			—			—			—			(240,000	)		(240,000	)		—			—			—			—			—			—			(240,000	)
Proceeds from issuance of senior notes, net		—			—			—			1,087,833			—			—			—			1,087,833			—			—			—			1,087,833			—			—			—			1,087,833
Contributions from joint venture partners		—			—			—			—			—			396,000			—			396,000			—			—			—			—			—			436,000			—			436,000
Payments of joint venture debt		—			—			—			—			—			(693,494	)		—			(693,494	)		—			—			—			—			—			(693,494	)		—			(693,494	)
Settlement of interest rate swaps		—			—			—			—			—			(29,032	)		—			(29,032	)		—			—			—			—			—			(29,032	)		—			(29,032	)
Financing costs on credit facilities		(2,835	)		—			—			—			—			—			—			(2,835	)		(2,835	)		—			—			—			—			—			—			(2,835	)
Distributions to parent		(52,889	)		—			—			—			—			—			—			(52,889	)		(94,291	)		—			—			—			—			—			—			(94,291	)
Advances (to) from affiliates		92,838			330,187			(2,762	)		(1,038,855	)		9,633			608,959			—			—			(238,391	)		840,576			32,606			(1,044,063	)		10,840			398,432			—			—
Notes payable to affiliates		15,500			(17,500	)		—			—			—			—			2,000			—			(38,500	)		(17,500	)		(35,000	)		—			—			(20,000	)		111,000			—

Net cash from financing activities		12,614			312,687			(2,762	)		48,978			9,633			282,433			2,000			665,583			10,983			823,076			(2,394	)		43,770			10,840			91,906			111,000			1,089,181

Net change in cash and cash equivalents		34			182			—			—			—			167,436			—			167,652			(1	)		145			—			—			—			(108,626	)		—			(108,482	)
Cash and cash equivalents, beginning of period		42			146			—			—			—			333,211			—			333,399			42			146			—			—			—			333,211			—			333,399

Cash and cash equivalents, end of period	$	76		$	328		$	—		$	—		$	—		$	500,647		$	—		$	501,051		$	41		$	291		$	—		$	—		$	—		$	224,585		$	—		$	224,917

~~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 ~~March 31,~~June 30, 2012, and our results of operations for the three and six months ended ~~March 31,~~June 30, 2012 and 2011. 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, 2011 filed by Noble Corporation, a Swiss corporation (“Noble-Swiss”), and Noble Corporation, a Cayman Islands company (“Noble-Cayman”).

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 contract backlog, fleet status, our financial position, business strategy, timing or results of acquisitions or dispositions, repayment of debt, borrowings under our Credit Facilities (as defined below), 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 and upgrade of rigs, industry conditions including the effect of disruptions of drilling in the U.S. Gulf of Mexico, access to financing, impact of competition, governmental regulations and permitting, availability of labor, worldwide economic conditions, taxes and tax rates, 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, 2011, 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.

Noble-Swiss is a leading provider of offshore contract drilling services for the oil and gas industry. Our fleet of 79 mobile offshore drilling units consists of 14 semisubmersibles, 14 drillships, 49 jackups and two submersibles. Additionally, we have one floating production storage and offloading unit. Our fleet includes 11 units under construction as follows:

During the first ~~three~~six months of 2012, we continued to see stability in the offshore drilling ~~market.~~market even as underlying commodity markets were volatile. In the U.S. Gulf of Mexico, the granting of permits and publication of new safety rules has led to more stable activity levels within the industry, especially as it relates to the deepwater markets. The continued stable activity has led to greater investment and has contributed to an improvement in dayrates for deepwater and ultra-deepwater rigs worldwide. While there are still risks, including potential third party environmental lawsuits targeting the permitting process, possible new drilling regulations, a failure of the federal agencies of the U.S. government 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~~the potential for these risks ~~can~~will be reduced as long as rigs continue to work without incident in the U.S. Gulf of Mexico.

There continues to be uncertainty regarding the sustainability of the global economic recovery, which is proceeding unevenly in different geographic regions. In addition to political instability in certain oil producing nations in the Middle East and North Africa, there is also uncertainty regarding recovery in the credit markets, particularly in Europe, which some analysts predict could be the catalyst for a worldwide recession. ~~Oil~~As a result, oil prices during 2012 have ~~remained at high levels as a result of supply~~been volatile. Supply side concerns in response to continued political unrest in the Middle East and North Africa ~~coupled with anticipated demand growth from emerging markets.~~are weighed against global recession fears. Natural gas prices in the United States continue to be at low levels based on current oversupply. We believe ~~there continue to be~~these competing factors ~~that could~~will impact the volatility in the offshore drilling market and the prices of oil and gas commodities for the foreseeable future.

Despite the instability in the global economy and commodity prices noted above, the market for offshore drilling services has continued ~~its~~the upward trend that began in 2011. We believe both the short-term and long-term outlook for the ~~deepwater market~~deep and ultra-deepwater markets continues to strengthen. Market dayrates for new ultra-deepwater units remain generally above $500,000, which is ~~lower than the peak rates achieved in 2007 and 2008, but~~ higher than rates seen in recent years. ~~Short-term~~A number of fixtures ~~for very high specification units~~ have exceeded $550,000, and in certain cases even exceeded $600,000. ~~We believe this~~Our market analysis indicates that there is ~~an indication~~little, if any, availability of ~~where the market could be going should there continue to be a strong demand~~ultra-deepwater units for ~~ultra-deepwater drilling units.~~2012, and 2013 availability is rapidly decreasing. Utilization rates for jackup units stabilized in 2011, and improved in most regions during the first ~~quarter~~half of 2012. While we currently have ~~several~~certain jackup rigs idle, we have seen tangible market activity and anticipate a favorable environment for these rigs in the short-term. We continue to see differentiation in the jackup market with newer units having utilization rates and dayrates exceeding those for units that entered service before ~~2000, as customers display~~2000. However, we continue to see improvement in the older jack-up market with increased utilization and competitive dayrates. While we have several of these units idle, we have seen tangible market activity and are actively pursuing a ~~preference~~number of opportunities for ~~technologically advanced and efficient drilling alternatives.~~these rigs.

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 regarding 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 and lower oil and gas prices result in reduced demand for our services. Demand for our services is also a function of the worldwide supply of mobile offshore drilling units. Industry analysts widely report that a significant expansion of industry supply of both jackups and ultra-deepwater units is underway. 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.

As a result of exploration discoveries offshore Brazil, Petroleo Brasileiro S.A. (“Petrobras”), the Brazilian national oil company, recently announced that it had approved contracts with two contractors to lease a total of 26 drilling rigs, which are expected to be delivered in the next 48 to 90 months. The potential increase in supply from the Petrobras newbuilds could adversely impact overall industry dayrates and economics.

We currently have ~~ten~~twelve rigs ~~under contract, or preparing for contracts,~~contracted in Mexico with Pemex Exploracion y Produccion (“Pemex”), and three of these rigs have contracts scheduled to expire in the fourth quarter of 2012. Pemex continues to tender for additional jackup rigs as it attempts to 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 ~~the majority 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 agreed to substitute the~~~~Noble Phoenix~~~~, then under contract with Shell in Southeast Asia, for the~~~~Noble Muravlenko~~~~. In connection with the cancellation of the contract on the~~~~Noble 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 at acquisition. As a result of the substitution, we reached a decision not to proceed with the previously announced reliability upgrade to the~~Noble Muravlenko~~ that 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. We expect the actual substitution to take place in the third quarter of 2012 after the~~Noble Phoenix~~ ~~completes its shipyard work.~~

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 Segerius and 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 of 2012, theNoble Leo Segerius completed the shipyard portion of its reliability upgrade and departed the shipyard in Brazil for seatrials, final commissioning and customer acceptance activities. TheNoble Leo Segerius is currently scheduled to return to work in the ~~second~~third quarter of 2012. TheNoble Roger Eason ~~is expected to enter~~entered the shipyard for its reliability upgrade in the second quarter of 2012, which is expected to take approximately ~~270~~300 days to complete. 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.

Our business strategy focuses on the active expansion of our ~~worldwide deepwater capabilities~~fleet through construction, upgrades and modifications, and acquisitions of drilling units, as well as the deployment of our drilling assets in important oil and gas producing areas. 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 upgrade our fleet to achieve greater technological capability, which we believe will lead to increased drilling efficiencies.

We may dispose of some, or all, of our lower specification units and related assets and operations in one or more transactions. These dispositions may include sales of assets to third parties, a spin-off or other distribution or separation of assets. In analyzing any disposition, we will consider the strategic benefit of the potential transaction while seeking to secure what we consider appropriate ~~value.~~value to our shareholders. To date, no potential disposition has provided the results we seek. The drilling market for lower specification units has recently ~~improved, and~~improved. While we ~~have experienced~~expect the increased utilization and dayrates experienced in most regions for these assets ~~in certain areas. Therefore, while we continue~~ to ~~evaluate disposition options, we believe these units should provide a positive contribution~~contribute positively to our overall results under current market ~~conditions.~~conditions, we do continue to analyze strategic options for these lower specification units. We can provide no assurance as to whether, or when, any disposition transaction will occur or what form it may take.

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 upgrade our 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 ~~March 31,~~June 30, 2012, we continued our newbuild strategy with the following 11 projects:

Of our 11 rigs under construction as of ~~March 31,~~June 30, 2012, two of the drillships are ~~contracted~~committed for five years or more. ~~In addition, we~~We also recently received ~~a letter of intent to enter into~~ an 18-month contract on one ~~jackup.~~jackup, theNoble Regina Allen,and a three-year contract on one drillship, the Noble Bob Douglas. The remaining ~~eight~~ rigs are currently being constructed without contracts.

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 our newbuild program will further strengthen our position, especially in ~~deepwater drilling.~~the ultra-deepwater and high-specification jackup markets.

In the ~~first~~second quarter of 2012, we recognized net income attributable to Noble-Swiss of ~~$120~~$160 million, or ~~$0.47~~$0.63 per diluted share, on total revenues of ~~$798~~$899 million. Sequential results of key metrics are as follows:


							Three Months Ended
	Three Months Ended						June 30,			March 31,
	March 31, 2012			December 31, 2011			2012			2012
Average dayrate	$	167,124		$	150,027		$	181,663		$	167,124
Average utilization		74	%		79	%		76	%		74	%
Daily contract drilling services costs	$	94,055		$	79,747		$	90,699		$	94,055
Contract drilling services margin		44	%		47	%		50	%		44	%

We maintain a backlog (as defined below) of commitments for contract drilling services. The following table sets forth, as of ~~March 31,~~June 30, 2012, 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		2012⁽¹⁾			2013			2014			2015			2016-2023			Total		2012⁽¹⁾			2013			2014			2015			2016-2023
	(In millions)																	(In millions)
Contract Drilling Services Backlog
Semisubmersibles/Drillships^{(2) (6) (7)}	$	12,567	$	1,721		$	2,457		$	2,415		$	1,625		$	4,349
Semisubmersibles/Drillships^{(2) (4) (6)}																		$	12,255	$	1,219		$	2,591		$	2,459		$	1,613		$	4,373
Jackups/Submersibles⁽³⁾		1,944		840			647			370			80			7			2,159		639			927			496			97			—

Total⁽⁴⁾	$	14,511	$	2,561		$	3,104		$	2,785		$	1,705		$	4,356		$	14,414	$	1,858		$	3,518		$	2,955		$	1,710		$	4,373

Percent of Available Operating Days
Committed⁽⁵⁾				73	%		51	%		36	%		16	%		4	%
Percent of Available Operating Days Committed⁽⁵⁾																					79	%		61	%		40	%		17	%		4	%

The drilling contracts with Shell for theNoble Globetrotter I,Noble Globetrotter II,Noble Jim Thompson,Noble Jim Day andNoble Clyde Boudreaux, as well as the ~~letter~~letters of intent for theNoble Don Taylor ~~(formerly unnamed HHI Drillship I)~~andNoble Max Smith, 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 7550 percent of the potential performance bonuses for these rigs, except for theNoble Clyde Boudreaux,while it is working in Brazil, where limited bonus is expected. Our backlog for these rigs includes approximately ~~$582~~$418 million attributable to these performance bonuses.

(4)

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 have exceeded downtime thresholds on theNoble Dave Beard and theNoble Paul Wolff,we have not received any notification concerning contract cancellations to date nor do we anticipate receiving any such notifications.

(5)	Percentages take into account additional capacity from the estimated dates of deployment of our newbuild rigs that are scheduled to commence operations during 2012 through 2015.

(6)

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,~~own and operate ~~and own~~ both theNoble Bully I and the~~the~~ Noble Bully II. Pursuant to these agreements, each party has an equal 50 percent share in both vessels. As of ~~March 31,~~June 30, 2012, the combined amount of backlog for these rigs totaled ~~$2.49~~$2.5 billion, all of which is included in our backlog. Noble’s ~~net~~proportionate interest in the backlog for these rigs was ~~$1.24~~$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 as a result of government-imposed restrictions or delays in the issuance of drilling permits. Furthermore, 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 ~~March 31,~~June 30, 2012, we estimate Shell and Petrobras represented approximately ~~66%~~64% and ~~17%~~16%, respectively, of our backlog.

As of ~~March 31,~~June 30, 2012, ~~all four of~~ our three 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.

In April 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 (“NCDMB”) to implement and monitor the law and develop regulations pursuant to the law. The ~~Nigerian Content Development and Monitoring Board~~NCDMB has indicated that it will require all non-Nigerian offshore drilling companies to reorganize their local operations to include Nigerian indigenous minority interests in the operating assets and to obtain the approval of the ~~Nigerian Content Development and Monitoring Board~~NCDMB for future work in Nigeria. The NCDMB actively monitors awards for future work and reviews plans for local content and development of Nigerian interests. The law also ~~establishes~~established a Nigerian Content Development Fund to fund the implementation of the law, and requires that one percent of the value of every contract awarded in the Nigerian oil and gas industry be paid into the fund. We cannot predict what impact the ~~new~~ law may have on our existing or future operations in Nigeria, but the effect on our operations there could be significant.

Net income attributable to Noble Corporation (“Noble-Swiss”) for the three months ended ~~March 31,~~June 30, 2012 (the “Current Quarter”) was ~~$120~~$160 million, or ~~$0.47~~$0.63 per diluted share, on operating revenues of ~~$798~~$899 million, compared to net income for the three months ended ~~March 31,~~June 30, 2011 (the “Comparable Quarter”) of $54 million, or $0.21 per diluted share, on operating revenues of ~~$579~~$628 million.

The consolidated financial statements of Noble-Swiss include the accounts of ~~Noble-Cayman, and~~Noble-Cayman; 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 2012 and 2011, 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 ~~March 31,~~June 30, 2012 was ~~$14~~$12 million higher than operating income for Noble-Swiss for the same ~~period,~~period. The operating income difference is primarily as a result of executive costs directly attributable to Noble-Swiss for operations support and stewardship related services.

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 ~~March 31,~~June 30, 2012 and 2011:


																					Average Rig						Operating							Average
	Average Rig Utilization (1)						Operating Days (2)							Average Dayrates							Utilization (1)						Days (2)							Dayrates
	Three Months Ended March 31,						Three Months Ended March 31,							Three Months Ended March 31,							Three Months Ended June 30,						Three Months Ended June 30,							Three Months Ended June 30,
	2012			2011			2012		2011		% Change			2012		2011		% Change			2012			2011			2012		2011		% Change			2012		2011		% Change
Jackups		79	%		62	%		3,089		2,381		30	%	$	90,382	$	80,866		12	%		79	%		71	%		3,073		2,797		10	%	$	97,612	$	80,742		21	%
Semisubmersibles		86	%		69	%		1,092		868		26	%		355,098		277,859		28	%		88	%		85	%		1,127		1,088		4	%		349,163		269,798		29	%
Drillships		51	%		70	%		285		361		-21	%		278,693		301,647		-8	%		65	%		58	%		469		317		48	%		329,761		220,953		49	%
Other																						0	%		0	%		—		—		—			—		—		—

Total		74	%		61	%		4,466		3,610		24	%	$	167,124	$	150,294		11	%		76	%		70	%		4,669		4,202		11	%	$	181,663	$	140,296		29	%

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 ~~March 31,~~June 30, 2012 and 2011 (in thousands):

~~Operating Revenues~~ — Changes in contract drilling services revenues for the Current Quarter as compared to the Comparable Quarter were driven by increases in both average dayrates and operating days. The 24 percent increase in operating days increased revenue by $129 million while the 11 percent increase in average dayrates increased revenues by approximately $75 million.

The change in contract drilling services revenues primarily relates to our semisubmersibles and jackups, which generated approximately $147 million and $87 million more revenue, respectively, in the Current Quarter. These amounts were offset by decreases in revenues from our drillships, which declined $30 million from the Comparable Quarter.

The 28 percent increase in semisubmersible average dayrates resulted in an $85 million increase in revenues from the Comparable Quarter while the increase in operating days of 26 percent resulted in an additional $62 million increase in revenues. The 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 the~~Noble Jim Day,~~ ~~the~~~~Noble Homer Ferrington,~~~~the~~~~Noble Paul Romano~~~~and the~~ ~~Noble Clyde Boudreaux~~~~, which all operated at full capacity during the Current Quarter after being off contract for the majority of the Comparable Quarter.~~

The 30 percent increase in jackup operating days resulted in a $57 million increase in revenues, which was coupled with a 12 percent increase in jackup average dayrates, resulting in a $30 million increase in revenues from the Comparable Quarter. The increase in utilization primarily related to rigs in Mexico and the Middle East, which were operating during the Current Quarter but not in the Comparable Quarter. The increase in average dayrates resulted from improved market conditions in the global shallow water market and was spread throughout the jackup fleet.

~~The decrease in drillship revenues of $30 million primarily relates to the~~~~Noble Phoenix~~ ~~and the~~~~Noble Leo Segerius,~~ ~~which were off contract for the Current Quarter but maintained operating time during the Comparable Quarter, partially offset by the~~~~Noble Bully I~~ ~~beginning its contract with Shell in late March 2012.~~

~~Operating Costs and Expenses~~—Contract drilling services operating costs and expenses increased $114 million for the Current Quarter as compared to the Comparable Quarter. A portion of the increase is due to the crew-up expenses for the recently completed rigs, which have added approximately $28 million in expense during the Current Quarter. Excluding the additional expenses related to these rigs, our contract drilling costs increased $86 million in the Current Quarter from the Comparable Quarter. This change was primarily driven by a $30 million increase in labor, the majority of which is due to salary increases effective in the second quarter of the prior year, a $22 million increase in mobilization due to the amortization of certain rig moves and the demobilization of rigs in Mexico, a $10 million increase related to shorebase support, a $6 million increase in repair and maintenance, a $6 million increase in safety, training and regulatory inspections, a $3 million increase in rotation costs, a $3 million increase in insurance costs related to increased premiums on our new policy renewed in March 2012, a $3 million increase for rig communications and rental equipment and $3 million for rig catering and other miscellaneous expenses.

~~The increase in depreciation and amortization in the Current Quarter from the Comparable Quarter was primarily attributable to an additional calendar day during the Current Quarter coupled with the~~~~Noble Bully I,~~ ~~which was placed in service in March 2012.~~

~~The following table sets forth the operating revenues and the operating costs and expenses for our other services for the three months ended March 31, 2012 and 2011:~~


											Three Months Ended
	Three Months Ended March 31,				Change						June 30,					Change
	2012		2011		$			%			2012			2011		$			%
Operating revenues:
Labor contract drilling services	$	16,008	$	13,547	$	2,461			18	%
Contract drilling services											$	848,237		$	589,550	$	258,687			44	%
Reimbursables (1)		439		687		(248	)		-36	%		30,124			22,982		7,142			31	%
Other												11			313		(302	)		-96	%

	$	16,447	$	14,234	$	2,213			16	%	$	878,372		$	612,845	$	265,527			43	%

Operating costs and expenses:
Labor contract drilling services	$	9,232	$	8,523	$	709			8	%
Contract drilling services											$	423,502		$	336,728	$	86,774			26	%
Reimbursables (1)		428		663		(235	)		-35	%		24,307			17,606		6,701			38	%
Depreciation and amortization		3,129		3,234		(105	)		-3	%		180,112			159,843		20,269			13	%
Selling, general and administrative		282		266		16			6	%		24,835			21,359		3,476			16	%
Loss on impairment												12,710			—		12,710			**
Gain on contract settlements/extinguishments, net												(33,255	)		—		(33,255	)		**

		13,071		12,686		385			3	%		632,211			535,536		96,675			18	%

Operating (loss) income	$	3,376	$	1,548	$	1,828			**
Operating income											$	246,161		$	77,309	$	168,852			218	%

Operating Revenues — Changes in contract drilling services revenues for the Current Quarter as compared to the Comparable Quarter were driven by increases in both average dayrates and operating days. The 29 percent increase in average dayrates increased revenue by $193 million while the 11 percent increase in operating days increased revenues by approximately $66 million.

The change in contract drilling services revenues relates to our semisubmersibles, drillships and jackups, which generated approximately $100 million, $85 million and $74 million more revenue, respectively, in the Current Quarter.

The 29 percent increase in semisubmersible average dayrates resulted in an $89 million increase in revenues from the Comparable Quarter while the four percent increase in operating days resulted in an additional $11 million increase in revenues. The increase in semisubmersibles revenue is a result of our rigs returning to standard operating dayrates after experiencing lower standby rates due to drilling restrictions in the U.S. Gulf of Mexico in the Comparable Quarter, as well as theNoble Paul Romano returning to work after being stacked in the Comparable Quarter. The increase in operating days is primarily from theNoble Jim Day, theNoble Homer Ferrington,theNoble Paul Romanoand the Noble Clyde Boudreaux, which all operated at full capacity during the Current Quarter after being off contract for the majority of the Comparable Quarter.

The increase in drillship revenues was driven by a 49 percent increase in average dayrates and a 48 percent increase in operating days, resulting in a $51 million and a $34 million increase in revenues, respectively, from the Comparable Quarter. The increase in both average dayrates and operating days was the result of theNoble Bully I andNoble Bully II, which commenced their contracts with Shell in March 2012 and April 2012, respectively.

The 21 percent increase in jackup average dayrates resulted in a $52 million increase in revenues, which was coupled with a 10 percent increase in jackup operating days, resulting in a $22 million increase in revenues from the Comparable Quarter. The increase in average dayrates resulted from improved market conditions in the global shallow water market throughout the jackup fleet. The increase in utilization primarily related to rigs in Mexico and the Middle East, which experienced increased operating days during the Current Quarter.

Operating Costs and Expenses — Contract drilling services operating costs and expenses increased $87 million for the Current Quarter as compared to the Comparable Quarter. A portion of the increase is due to the crew-up and operating expenses for the recently completed rigs, which added approximately $25 million in expense during the Current Quarter. Excluding the additional expenses related to these rigs, our contract drilling costs increased $62 million in the Current Quarter from the Comparable Quarter. This change was primarily driven by a $16 million increase in labor, a $14 million increase related to shorebase support, a $7 million increase in insurance costs related to increased premiums on our new policy renewed in March 2012, a $7 million increase in mobilization due to the commencement of amortization of certain rig moves and the demobilization of rigs in Mexico, a $5 million increase in repair and maintenance, a $5 million increase in rig communications, transportation and rotation costs, a $5 million increase in rig catering and other miscellaneous expenses and a $3 million increase in safety, training and regulatory inspections.

The increase in depreciation and amortization in the Current Quarter from the Comparable Quarter was primarily attributable to assets placed in service, including theNoble Bully I andNoble Bully II.

Loss on impairment during the Current Quarter related to an impairment charge on our submersible fleet, primarily as a result of the declining market outlook for drilling services for this rig type.

Gain on contract settlements/extinguishments during the Current Quarter related to a $28 million gain on the settlement of an action with certain vendors for damages sustained during Hurricane Ike. Additionally, we received $5 million from a claims settlement on theNoble David Tinsley, which had experienced a “punch-through” while being positioned on location in 2009.

The following table sets forth the operating revenues and the operating costs and expenses for our other services for the three months ended June 30, 2012 and 2011:

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

Loss on impairment during the Current Quarter related to an impairment charge on certain corporate assets, as a result of a declining market for, and the potential disposal of, the assets.

Interest Expense, net of amount capitalized—Interest expense, net of amount capitalized, ~~decreased $9~~increased $6 million in the Current Quarter as compared to the Comparable Quarter. The increase is a result of the $1.2 billion of senior notes issued in February 2012, partially offset by higher capitalized interest related to the continued construction under our newbuild program.

Income Tax Provision — Our income tax provision increased $37 million in the Current Quarter as a result of increased pre-tax income and a higher effective tax rate during the Current Quarter. The increase in pre-tax earnings generated a $24 million increase in tax expense while the increase in the income tax rate during the Current Quarter increased the income tax provision by $13 million. The increase in the income tax rate was primarily due to the net gain from the settlements and impairment charges, primarily subject to tax in the United States, coupled with other discrete tax items recognized during the Current Quarter.

Net income attributable to Noble Corporation (“Noble-Swiss”) for the six months ended June 30, 2012 (the “Current Period”) was $280 million, or $1.10 per diluted share, on operating revenues of $1.7 billion, compared to net income for the six months ended June 30, 2011 (the “Comparable Period”) of $109 million, or $0.43 per diluted share, on operating revenues of $1.2 billion.

The consolidated financial statements of Noble-Swiss include the accounts of Noble-Cayman; 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 2012 and 2011, 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 months ended June 30, 2012 was $27 million higher than operating income for Noble-Swiss for the same period. The operating income difference is primarily a result of executive costs directly attributable to Noble-Swiss for operations support and stewardship related services.

The following table sets forth the operating revenues and the operating costs and expenses for our contract drilling services segment for the six months ended June 30, 2012 and 2011 (in thousands):

Operating Revenues — Changes in contract drilling services revenues for the Current Period as compared to the Comparable Period were driven by increases in both average dayrates and operating days. The 20 percent increase in average dayrates increased revenues by approximately $270 million while the 17 percent increase in operating days increased revenue by $192 million.

The change in contract drilling services revenues relates to our semisubmersibles, jackups and drillships, which generated approximately $247 million, $161 million and $55 million more revenue, respectively, in the Current Period.

The 29 percent increase in semisubmersible average dayrates resulted in a $175 million increase in revenues from the Comparable Period while the increase in operating days of 13 percent resulted in an additional $72 million increase in revenues. The increase in semisubmersibles revenue is a result of our rigs returning to standard operating dayrates after experiencing lower standby rates due to drilling restrictions in the U.S. Gulf of Mexico in the Comparable Period, as well as theNoble Paul Romano returning to work after being stacked in the Comparable Period. The increase in operating days is primarily from theNoble Jim Day, theNoble Homer Ferrington,theNoble Paul Romanoand the Noble Clyde Boudreaux, which all operated at full capacity during the Current Period after being off contract for the majority of the Comparable Period.

The 16 percent increase in jackup average dayrates resulted in an $81 million increase in revenues, which was coupled with a 19 percent increase in operating days, resulting in an $80 million increase in revenues from the Comparable Period. The increase in average dayrates resulted from improved market conditions in the global shallow water market throughout the jackup fleet. The increase in utilization primarily related to rigs in Mexico and the Middle East, which experienced increased operating days during the Current Period.

The increase in drillship revenues was driven by an 18 percent increase in average dayrates and an 11 percent increase in operating days, resulting in a $35 million and a $20 million increase in revenues, respectively, from the Comparable Period. The increase in both average dayrates and operating days was the result of theNoble Bully I andNoble Bully II, which commenced their contracts with Shell in March 2012 and April 2012, respectively, partially offset by theNoble Phoenix, which is completing its shipyard project in anticipation of substitution for theNoble Muravlenko in Brazil.

Operating Costs and Expenses — Contract drilling services operating costs and expenses increased $200 million for the Current Period as compared to the Comparable Period. A portion of the increase is due to the crew-up and operating expenses for the recently completed rigs, which have added approximately $53 million in expense during the Current Period. Excluding the additional expenses related to these rigs, our contract drilling costs increased $147 million in the Current Period from the Comparable Period. This change was primarily driven by a $46 million increase in labor, the majority of which is due to salary increases effective in the second quarter of the prior year, a $29 million increase in mobilization due to the amortization of certain rig moves and the demobilization of rigs in Mexico, a $25 million increase related to shorebase support, an $11 million increase in repair and maintenance, a $9 million increase in rig catering and other miscellaneous expenses, a $9 million increase in insurance costs related to increased premiums on our new policy renewed in March 2012, an $8 million increase in safety, training and regulatory inspections, a $5 million increase in rotation costs and a $5 million increase for rig communications and rental equipment.

The increase in depreciation and amortization in the Current Period from the Comparable Period was primarily attributable to assets placed in service during the Current Period, including theNoble Bully I andNoble Bully II.

Loss on impairment during the Current Period related to an impairment charge on our submersible fleet, primarily as a result of the declining market outlook for drilling services for this rig type.

Gain on contract settlements/extinguishments during the Current Period related to a $28 million gain on the settlement of an action with certain vendors for damages sustained during Hurricane Ike. Additionally, we received $5 million from a claims settlement on theNoble David Tinsley, which had experienced a “punch-through” while being positioned on location in 2009.

The following table sets forth the operating revenues and the operating costs and expenses for our other services for the six months ended June 30, 2012 and 2011:

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

Loss on impairment during the Current Period related to an impairment charge on certain corporate assets, as a result of a declining market for, and the potential disposal of, the assets.

Interest Expense, net of amount capitalized — Interest expense, net of amount capitalized, decreased $3 million in the Current Period as compared to the Comparable Period. The decrease is a result of higher capitalized interest in the Current ~~Quarter~~Period as compared to the Comparable ~~Quarter~~Period due primarily to the continued construction under our newbuild ~~program.~~program, which was partially offset by the issuance of $1.2 billion in senior notes in February 2012. During the Current ~~Quarter,~~Period, we capitalized approximately 8071 percent of total interest charges versus approximately 5862 percent during the Comparable ~~Quarter.~~Period.

Income Tax Provision—Our income tax provision increased $6$43 million in the Current ~~Quarter~~Period primarily as a result of a higher pre-tax income and effective tax rate during the Current ~~Quarter, partially offset by a lower tax rate in the Current Quarter.~~Period. The ~~93 percent~~ increase in pre-tax earnings generated a ~~$14~~$42 million increase in tax expense while the ~~6 percent decrease~~increase in the income tax rate during the Current ~~Quarter decreased~~Period increased the income tax provision by $8$1 million. The ~~decrease~~increase in the income tax rate was primarily due to ~~fluctuations on foreign exchange rates on our~~the net gain from the settlements and impairment charges, primarily subject to tax ~~balances~~in the United States, coupled with ~~a geographic shift~~other discrete tax items recognized in the ~~make-up of our revenues.~~Current Period.

Net cash from operating activities for the Current ~~Quarter was $104~~Period increased to $536 million ~~and $87~~from $233 million in the Comparable ~~Quarter.~~Period. The increase in net cash from operating activities in the Current ~~Quarter~~Period was primarily attributable to a significant increase in net ~~income, partially offset by an increase in accounts receivable. The increase in accounts receivable is related to the increased fleet activity in 2012 and Current Quarter mobilization billings.~~income. We had working capital of ~~$574~~$481 million and $232 million at ~~March 31,~~June 30, 2012 and December 31, 2011, respectively. As a result of our $1.2 billion debt offering in February 2012 and outstanding borrowings of $150 million on our ~~credit facilities~~Credit Facilities at ~~March 31,~~June 30, 2012, total debt as a percentage of total debt plus equity increased to 35 percent at ~~March 31,~~June 30, 2012 from 34 percent at December 31, 2011.

At ~~March 31,~~June 30, 2012, we had a total contract drilling services backlog of approximately ~~$14.5~~$14.4 billion. Our backlog as of ~~March 31,~~June 30, 2012 reflects a commitment of 7379 percent of available operating days for the remainder of 2012 and 5161 percent for 2013. See additional information regarding our backlog at “Contract Drilling Services Backlog.”

Our principal capital resource in the Current ~~Quarter~~Period was cash generated from our $1.2 billion senior notes offering and net cash from operating activities of ~~$104~~$536 million. Cash generated during the Current ~~Quarter~~Period was primarily used to repay borrowings outstanding under our ~~bank credit facilities~~Credit Facilities and to fund our capital expenditure program.

We currently expect to fund these cash flow needs with cash generated by our operations, cash on hand and borrowings under our existing credit facilities. However, to adequately cover our expected cash flow needs, we may require capital in excess of the amount provided through these sources, and we may delay or cancel certain discretionary capital expenditures as necessary.Credit Facilities.

Our primary use of available liquidity ~~requirement~~ during 2012 is for capital expenditures. Capital expenditures, including capitalized interest, totaled ~~$368~~$665 million and ~~$614 million~~$1.4 billion for the ~~three~~six months ended ~~March 31,~~June 30, 2012 and 2011, respectively.

At ~~March 31,~~June 30, 2012, we had 11 rigs under construction, and capital expenditures, excluding capitalized interest, for new construction during the first ~~three~~six months of 2012 totaled ~~$133~~$162 million, as follows (in millions):


Rig type/name
Currently under construction
Drillships
Noble Don Taylor (formerly HHI Drillship I)	$	53.2	$	56.2
Noble Globetrotter II		30.0		37.7
Noble Bob Douglas (formerly HHI Drillship II)		1.1		4.2
Noble Sam Croft (formerly HHI Drillship III)		0.6		1.8
HHI Drillship IV		0.4		1.2
Jackups
Noble Regina Allen (formerly Noble Jackup I)		2.7		3.4
Noble Mick O'Brien (formerly Noble Jackup II)		2.2
Noble Mick O’Brien (formerly Noble Jackup II)				2.7
Noble Houston Colbert (formerly Noble Jackup III)		1.7		1.8
Noble Sam Turner (formerly Noble Jackup IV)		1.4		1.5
Noble Tom Prosser (formerly Noble Jackup V)		1.4		1.5
Noble Jackup VI		1.4		1.5
Recently completed construction projects
Noble Bully II		19.0		17.9
Noble Globetrotter I		15.8		25.4
Noble Bully I		2.2		4.7

Total Newbuild Capital Expenditures	$	133.1	$	161.5

In addition to the newbuild expenditures noted above, capital expenditures ~~during~~for the ~~first quarter of~~six months ended June 30, 2012 consisted ~~of:~~of the following:

Our total capital expenditure estimate for 2012 is approximately $1.9 ~~billion. In addition, we anticipate additional charges related to~~billion, including capitalized interest, which may fluctuate as a result of the timing of completion of ongoing projects.

In connection with our capital expenditure program, as of ~~March 31,~~June 30, 2012, we had outstanding commitments, including shipyard and purchase commitments, for approximately ~~$3.0~~$3.1 billion, of which we expect to spend approximately ~~$1.3~~$1.6 billion within the next twelve months.

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~~expected amounts 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.

Our most recent quarterly payment to shareholders, totaling approximately $36 million (or 0.13 CHF per share), in the form of a ~~capital~~par value reduction, was declared on ~~February 3,~~April 27, 2012 and paid on ~~February 23,~~May 16, 2012 to holders of record on ~~February 13,~~May 7, 2012. ~~We anticipate~~This payment represented the final tranche of our ~~annual payments~~previously approved payment to shareholders in the form of a par value reduction.

In April 2012, our shareholders approved the payment of a dividend funded from our capital ~~reduction~~contribution reserve aggregating $0.52 per share to be paid in four equal installments scheduled for August 2012, November 2012, February 2013 and May 2013. These dividends will ~~be made~~require us to make cash payments of approximately $66 million in 2012, based on the number of shares currently outstanding. In connection with this approval and the resulting obligation to shareholders, we recorded dividends payable of approximately $133 million during ~~May~~the second quarter of 2012. Any additional issuances of shares would further increase our obligation.

The declaration and payment of dividends in the future by Noble-Swiss ~~and~~or 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 2012, our shareholders approved the payment of a dividend funded from capital contribution reserve in a total amount equal to $0.52 per share to be paid in four equal installments scheduled for August 2012, November 2012, February 2013 and May 2013. These dividends will require us to make total cash payments of approximately $66 million in 2012, based on the number of shares currently outstanding. In connection with this approval, during the second quarter of 2012, we will record a payable of approximately $133 million, which represents this obligation to shareholders. Any additional issuances of shares would further increase this obligation.

During June 2012, we replaced our $575 million credit facility, which was scheduled to mature in 2013, with a new $1.2 billion credit facility which matures in 2017. We ~~have two separate revolving~~continue to maintain our $600 million credit ~~facilities~~facility, which matures in ~~place~~2015, which ~~provide~~combined with our new facility, gives us ~~with~~ a total borrowing capacity ~~of approximately $1.18 billion, of which $150 million was outstanding as of March 31, 2012. One credit facility, which has a capacity of $575 million, matures in 2013, and~~under the ~~other facility, which has a capacity of $600 million, matures in 2015~~two facilities (together referred to as the “Credit Facilities”). of $1.8 billion. 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. At ~~March 31,~~June 30, 2012, our ratio of debt to total tangible capitalization was ~~less than 0.36 for the Credit Facilities.~~0.35. We were in compliance with all covenants under the Credit Facilities as of ~~March 31,~~June 30, 2012.

The Credit Facilities provide us with the ability to issue up to ~~$300~~$375 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 ~~March 31,~~June 30, 2012, we had 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.

At ~~March 31,~~June 30, 2012, we had letters of credit of ~~$59~~$50 million and performance and tax assessment bonds totaling ~~$304~~$306 million supported by surety bonds outstanding. Of the letters of credit outstanding, ~~$27~~$19 million were issued to support bank bonds in connection with our drilling units in Nigeria. 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 was $4.4 billion at ~~March 31,~~June 30, 2012 as compared to $4.1 billion at December 31, 2011. The increase in debt is a result of the issuance of $1.2 billion aggregate principal amount of senior notes, partially offset by the net repayment of $825 million on the Credit Facilities. For additional information on our long-term debt, see Note 78 to our consolidated financial statements.

In May 2011, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) No. 2011-04, which amends FASB Accounting Standards Codification (“ASC”) Topic 820, “Fair Value Measurements and Disclosures.” This amended guidance clarifies 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. Our adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

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.

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 ~~March 31,~~June 30, 2012, we had $150 million outstanding under the Credit Facilities. Assuming our current level of debt, a change in LIBOR rates of one percent would increase our interest charges by approximately $2 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 long-term debt was $4.7 billion and $4.3 billion at ~~March 31,~~June 30, 2012 and December 31, 2011, respectively. The increase was primarily a result of our issuance of $1.2 billion in debt in February 2012, partially offset by the net repayment of $825 million on our Credit Facilities, coupled with changes in fair value related to changes in interest rates and market perceptions of our credit 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,~~At June 30, 2012, we ~~typically maintain~~had no outstanding derivative contracts. Depending on market conditions, we may elect to utilize short-term forward currency contracts ~~settling monthly in their respective local currencies. The forward contract settlements~~ in the remainder of 2012 represent approximately 10 percent of these forecasted local currency requirements. The notional amount of the forward contracts outstanding, expressed in U.S. dollars, was approximately $13 million at March 31, 2012. Total unrealized losses related to these forward contracts were $0.6 million as of March 31, 2012 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 $1 million.future.

We 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.~~1986, as amended. 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”).~~employees. 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.

David W. Williams, Chairman, President and Chief Executive Officer of Noble-Swiss, and James A. MacLennan, Senior Vice President and Chief Financial 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. MacLennan have concluded that Noble-Swiss’ disclosure controls and procedures were effective as of ~~March 31,~~June 30, 2012. 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 ~~March 31,~~June 30, 2012. 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.

There was no change in either ~~Noble-Swiss’~~Noble-Swiss�� or Noble-Cayman’s internal control over financial reporting that occurred during the quarter ended ~~March 31,~~June 30, 2012 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.

Information regarding legal proceedings is set forth in ~~Note 12~~Notes 6, 7 and 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.

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

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.

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.


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)


Noble-Swiss:	Large accelerated filer x	Accelerated filer ¨	Non-accelerated filer ¨	Smaller reporting company ¨
Noble-Cayman:	Large accelerated filer¨	Accelerated filer¨	Non-accelerated filerx	Smaller reporting company¨


	Page
PART I FINANCIAL INFORMATION
Item 1 Financial Statements

Noble Corporation (Noble-Swiss) Financial Statements:
Consolidated Balance Sheet as of ~~March 31,~~June 30, 2012 and December 31, 2011		3
Consolidated Statement of Income for the three and six months ended ~~March 31,~~June 30, 2012 and 2011		4
Consolidated Statement of Comprehensive Income for the three and six months ended ~~March 31,~~June 30, 2012 and 2011		5
Consolidated Statement of Cash Flows for the ~~three~~six months ended ~~March 31,~~June 30, 2012 and 2011		6
Consolidated Statement of Equity for the ~~three~~six months ended ~~March 31,~~June 30, 2012 and 2011		7

Noble Corporation (Noble-Cayman) Financial Statements:
Consolidated Balance Sheet as of ~~March 31,~~June 30, 2012 and December 31, 2011		8
Consolidated Statement of Income for the three and six months ended ~~March 31,~~June 30, 2012 and 2011		9
Consolidated Statement of Comprehensive Income for the three and six months ended ~~March 31,~~June 30, 2012 and 2011		10
Consolidated Statement of Cash Flows for the ~~three~~six months ended ~~March 31,~~June 30, 2012 and 2011		11
Consolidated Statement of Equity for the ~~three~~six months ended ~~March 31,~~June 30, 2012 and 2011		12

Notes to Combined Consolidated Financial Statements		13

Item 2 Management’s Discussion and Analysis of Financial Condition and Results of Operations		3436
Item 3 Quantitative and Qualitative Disclosures About Market Risk		4550
Item 4 Controls and Procedures		4751
PART II OTHER INFORMATION
Item 1 Legal Proceedings		4752
Item 2 Unregistered Sales of Equity Securities and Use of Proceeds		4752
Item 6 Exhibits		4752
SIGNATURES		4853
Index to Exhibits		4954


	Three Months Ended March 31,
	2012						2011
	Non-U.S.			U.S.			Non-U.S.			U.S.
Service cost	$	1,123		$	2,431		$	1,093		$	2,152
Interest cost		1,358			2,196			1,383			2,143
Return on plan assets		(1,346	)		(2,793	)		(1,403	)		(2,768	)
Amortization of prior service cost		—			57			—			56
Amortization of transition obligation		—			—			18			—
Recognized net actuarial loss		200			1,885			120			844

Net pension expense	$	1,335		$	3,776		$	1,211		$	2,427


	Three Months Ended June 30,
	2012						2011
	Non-U.S.			U.S.			Non-U.S.			U.S.
Service cost	$	1,111		$	2,375		$	1,153		$	2,152
Interest cost		1,350			2,164			1,440			2,143
Return on plan assets		(1,342	)		(2,793	)		(1,454	)		(2,768	)
Amortization of prior service cost		—			57			—			57
Amortization of transition obligation		—			—			19			—
Recognized net actuarial loss		201			1,793			123			843

Net pension expense	$	1,320		$	3,596		$	1,281		$	2,427


	Six Months Ended June 30,
	2012						2011
	Non-U.S.			U.S.			Non-U.S.			U.S.
Service cost	$	2,234		$	4,806		$	2,246		$	4,304
Interest cost		2,708			4,360			2,823			4,286
Return on plan assets		(2,688	)		(5,586	)		(2,857	)		(5,536	)
Amortization of prior service cost		—			114			—			113
Amortization of transition obligation		—			—			37			—
Recognized net actuarial loss		401			3,678			243			1,687

Net pension expense	$	2,655		$	7,372		$	2,492		$	4,854


	Noble-Swiss
	Three Months Ended March 31,
	2012									2011
	Contract									Contract
	Drilling									Drilling
	Services			Other			Total			Services			Other			Total
Revenues from external customers	$	781,243		$	16,447		$	797,690		$	564,654		$	14,234		$	578,888
Depreciation and amortization		167,948			3,129			171,077			154,888			3,234			158,122
Segment operating income		140,267			3,376			143,643			84,716			1,548			86,264
Interest expense, net of amount capitalized		(89	)		(10,407	)		(10,496	)		(1,085	)		(17,956	)		(19,041	)
Income tax (provision)/ benefit		(22,600	)		1,011			(21,589	)		(18,863	)		3,504			(15,359	)
Segment profit/ (loss)		125,484			(5,309	)		120,175			66,880			(12,385	)		54,495
Total assets (at end of period)		13,248,321			646,880			13,895,201			11,716,530			213,355			11,929,885


	Noble-Cayman
	Three Months Ended March 31,
	2012									2011
	Contract									Contract
	Drilling									Drilling
	Services			Other			Total			Services			Other			Total
Revenues from external customers	$	781,243		$	16,447		$	797,690		$	564,654		$	14,234		$	578,888
Depreciation and amortization		167,948			2,625			170,573			154,888			2,767			157,655
Segment operating income		140,267			17,861			158,128			84,716			14,730			99,446
Interest expense, net of amount capitalized		(89	)		(10,407	)		(10,496	)		(1,085	)		(17,956	)		(19,041	)
Income tax (provision)/ benefit		(22,600	)		1,389			(21,211	)		(18,863	)		3,838			(15,025	)
Segment profit		125,484			9,168			134,652			66,880			780			67,660
Total assets (at end of period)		13,248,321			606,923			13,855,244			11,716,530			174,891			11,891,421


	Issuer
Notes	(Co-Issuer(s))	Guarantor(s)
$300 million 5.875% Senior Notes due 2013	Noble-Cayman	Noble Drilling Corporation ~~("NDC"~~(“NDC”);
		NHIL
$250 million 7.375% Senior Notes due 2014	NHIL	Noble-Cayman
$350 million 3.45% Senior Notes due 2015	NHIL	Noble-Cayman
$300 million 3.05% Senior Notes due 2016	NHIL	Noble-Cayman
$300 million 2.50% Senior Notes due 2017	NHIL	Noble-Cayman
$202 million 7.50% Senior Notes due 2019	~~NDC;~~NDC	~~Noble-Cayman;~~Noble-Cayman
	Noble Drilling Services 6 LLC (“NDS6”)	Noble Holding (U.S.) Corporation (“NHC”)
		Noble Drilling Holding LLC ~~("NDH"~~(“NDH”);	~~Noble Holding (U.S.) Corporation ("NHC")~~
	~~Noble Drilling Services 6 LLC ("NDS6")~~
$500 million 4.90% Senior Notes due 2020	NHIL	Noble-Cayman
$400 million 4.625% Senior Notes due 2021	NHIL	Noble-Cayman
$400 million 3.95% Senior Notes due 2022	NHIL	Noble-Cayman
$400 million 6.20% Senior Notes due 2040	NHIL	Noble-Cayman
$400 million 6.05% Senior Notes due 2041	NHIL	Noble-Cayman
$500 million 5.25% Senior Notes due 2042	NHIL	Noble-Cayman


Noble Corporation, a Swiss corporation

/s/ David W. Williams				~~May 7,~~August 6, 2012
David W. Williams				Date
Chairman, President and Chief Executive Officer ~~(Principal Executive Officer)~~
(Principal Executive Officer)

/s/ James A. MacLennan
James A. MacLennan
Senior Vice President and Chief Financial Officer ~~(Principal Financial Officer)~~
(Principal Financial Officer)

Noble Corporation, a Cayman Islands company

/s/ David W. Williams				~~May 7,~~August 6, 2012
David W. Williams				Date
President and Chief Executive Officer ~~(Principal Executive Officer)~~
(Principal Executive Officer)

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


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 (filed as Exhibit 3.1 to Noble-Swiss’ Annual Report on Form 10-K filed on February 27, 2012 and incorporated herein by reference).~~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		~~Indenture,~~Revolving Credit Agreement dated as of ~~November 21, 2008, between~~June 8, 2012 among Noble ~~Holding International Limited,~~Corporation, a Cayman Islands company; the Lenders from time to time parties thereto; Wells Fargo Bank, National Association, as ~~Issuer,~~Administrative Agent, Swingline Lender and an Issuing Bank; SunTrust Bank, as Syndication Agent; Barclays Bank PLC, HSBC Securities (USA) Inc. and The Bank of ~~New York Mellon Trust Company, N.A.~~Tokyo-Mitsubishi UFJ, Ltd., as ~~Trustee~~Co-Documentation Agents; and Wells Fargo Securities, LLC, SunTrust Robinson Humphrey, Inc., Barclays Bank PLC, HSBC Securities (USA) Inc. and The Bank of Tokyo-Mitsubishi UFJ, Ltd., as Joint Lead Arrangers and Joint Lead Bookrunners (filed as Exhibit 4.1 to ~~Noble-Cayman’s~~Noble-Swiss’ Current Report on Form 8-K filed on ~~November 21, 2008~~June 11, 2012 and incorporated herein by reference).

4.2		~~Fourth Supplemental Indenture,~~Guaranty Agreement dated as of ~~February 10,~~June 8, 2012 ~~among~~between Noble ~~Holding International Limited, as Issuer, Noble~~Drilling Corporation, ~~as Guarantor,~~a Delaware corporation, and ~~The~~Wells Fargo Bank, of New York Mellon Trust Company, N.A., as Trustee, relating to 2.5% Senior Notes due 2017 of Noble Holding International Limited, 3.95% Senior Notes due 2022 of Noble Holding International Limited, and 5.25% Senior Notes due 2042 of Noble Holding International LimitedNational Association (filed as Exhibit 4.2 to ~~Noble-Cayman’s~~Noble-Swiss’ Current Report on Form 8-K filed on ~~February 13,~~June 11, 2012 and incorporated herein by reference).

10.1*4.3		~~Third Amendment to the Noble Corporation 1991 Stock Option and Restricted Stock Plan, effective~~Guaranty Agreement dated as of ~~February 3,~~June 8, 2012 ~~(Filed~~between Noble Holding International Limited, a Cayman Islands company, and Wells Fargo Bank, National Association (filed as ~~exhibit 10.2~~Exhibit 4.3 to ~~Noble Cayman’s~~Noble-Swiss’ Current Report on Form 8-K filed on ~~February 7,~~June 11, 2012 and incorporated herein by reference).

10.2*		Form of Noble Corporation Time-Vested Restricted Stock Unit Agreement under the Noble Corporation 1991 Stock Option and Restricted Stock Plan (filed as Exhibit 10.2 to Noble-Cayman’s Current Report on Form 8-K filed on January 13, 2012 and incorporated herein by reference).

10.3*		Form of Noble Corporation Nonqualified Stock Option Agreement under the Noble Corporation 1991 Stock Option and Restricted Stock Plan (filed as Exhibit 10.3 to Noble-Cayman’s Current Report on Form 8-K filed on January 13, 2012 and incorporated herein by reference).

10.4*		~~Form of Employment Agreement and Guaranty Agreement (filed as Exhibit 10.1 to Noble-Cayman’s Current Report on Form 8-K filed on January 13, 2012 and incorporated herein by reference).~~

10.5*		~~Form of Employment Agreement and Guaranty Agreement (filed as Exhibit 10.1 to Noble-Cayman’s Current Report on Form 8-K filed on February 7, 2012 and incorporated herein by reference).~~

10.6*		~~Noble Corporation 2012 Short Term Incentive Plan.~~

10.7*		~~Form of Noble Corporation Performance Restricted Stock Unit Agreement under the Noble Cayman 1991 Stock Option and Restricted Stock Plan.~~

10.810.1		Amended and Restated 1991 Stock Option and Restricted Stock Plan (filed as Exhibit 10.2 to Noble Cayman’s Current Report on Form 8-K filed on April 30, 2012 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 James A. MacLennan 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-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 James A. MacLennan 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-Cayman.

101+		Interactive Data File