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 R No o

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 R No o

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 o No R

Number of shares outstanding and trading at ~~October 23, 2015:~~July 22, 2016: Noble Corporation plc ~~—241,971,945~~—243,218,134

Noble Corporation, a Cayman Islands company and a wholly owned subsidiary of Noble Corporation plc, a public limited company incorporated under the laws of England and Wales, meets the conditions set forth in General Instructions H(1) (a) and (b) to Form 10-Q and is therefore filing this Quarterly Report on 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 plc, a public limited company incorporated under the laws of England and Wales (“Noble-UK”), and Noble Corporation, a Cayman Islands company (“Noble-Cayman”). Information in this filing relating to Noble-Cayman is filed by Noble-UK and separately by Noble-Cayman on its own behalf. Noble-Cayman makes no representation as to information relating to Noble-UK (except as it may relate to Noble-Cayman) or any other affiliate or subsidiary of Noble-UK. 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 as stated in General Instructions H(2). 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-UK and its consolidated subsidiaries, including Noble-Cayman.

	September 30,			December 31,			June 30,			December 31,
	2015			2014			2016			2015
ASSETS
Current assets
Cash and cash equivalents	$	164,430		$	68,510		$	822,978		$	512,245
Accounts receivable		530,401			569,096			353,677			498,931
Taxes receivable		66,852			107,490			33,469			55,525
Prepaid expenses and other current assets		174,194			183,466			120,452			173,917
Total current assets		935,877			928,562			1,330,576			1,240,618
Property and equipment, at cost		14,717,312			14,442,922			14,135,376			14,056,323
Accumulated depreciation		(2,798,645	)		(2,330,413	)		(2,859,370	)		(2,572,700	)
Property and equipment, net		11,918,667			12,112,509			11,276,006			11,483,623
Other assets		203,474			245,751			132,862			141,404
Total assets	$	13,058,018		$	13,286,822		$	12,739,444		$	12,865,645
LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt	$	299,993		$	—		$	299,642		$	299,924
Accounts payable		207,892			265,389			138,659			223,221
Accrued payroll and related costs		90,052			102,520			50,460			81,464
Taxes payable		154,295			94,230			152,943			87,940
Interest payable		44,922			61,964			73,798			72,961
Other current liabilities		107,042			144,571			80,058			98,074
Total current liabilities		904,196			668,674			795,560			863,584
Long-term debt		4,188,727			4,869,020			3,829,416			4,162,638
Deferred income taxes		46,366			120,589			4,888			92,797
Other liabilities		325,956			341,505			289,799			324,396
Total liabilities		5,465,245			5,999,788			4,919,663			5,443,415
Commitments and contingencies
Shareholders' equity
Shares; 241,970 and 247,501 shares outstanding		2,420			2,475
Shares; 243,218 and 241,977 shares outstanding								2,432			2,420
Additional paid-in capital		618,808			695,638			638,964			628,483
Retained earnings		6,320,833			5,936,035			6,517,161			6,131,501
Accumulated other comprehensive loss		(72,032	)		(69,418	)		(61,870	)		(63,175	)
Total shareholders' equity		6,870,029			6,564,730			7,096,687			6,699,229
Noncontrolling interests		722,744			722,304			723,094			723,001
Total equity		7,592,773			7,287,034			7,819,781			7,422,230
Total liabilities and equity	$	13,058,018		$	13,286,822		$	12,739,444		$	12,865,645

	Three Months Ended						Nine Months Ended						Three Months Ended						Six Months Ended
	September 30,						September 30,						June 30,						June 30,
	2015			2014			2015			2014			2016			2015			2016			2015
Operating revenues
Contract drilling services	$	873,813		$	810,200		$	2,424,481		$	2,360,205		$	876,697		$	771,307		$	1,468,064		$	1,550,668
Reimbursables		22,858			18,595			70,087			67,558			17,933			22,248			38,539			47,229
Other		—			1			—			1			153			—			153			—
		896,671			828,796			2,494,568			2,427,764			894,783			793,555			1,506,756			1,597,897
Operating costs and expenses
Contract drilling services		293,067			385,674			934,024			1,109,456			244,176			319,207			495,424			640,957
Reimbursables		17,783			13,641			55,592			52,877			14,298			17,652			30,304			37,809
Depreciation and amortization		160,652			161,246			473,913			460,306			150,946			159,123			300,665			313,261
General and administrative		15,196			24,602			61,558			77,319			19,033			22,424			38,573			46,362
Loss on impairment														16,616			—			16,616			—
		486,698			585,163			1,525,087			1,699,958			445,069			518,406			881,582			1,038,389
Operating income		409,973			243,633			969,481			727,806			449,714			275,149			625,174			559,508
Other income (expense)
Interest expense, net of amount capitalized		(54,687	)		(37,751	)		(161,196	)		(114,494	)		(57,306	)		(57,465	)		(114,406	)		(106,509	)
Gain on extinguishment of debt, net														11,066			—			11,066			—
Interest income and other, net		30,934			2,760			37,085			131			(1,253	)		(431	)		(1,983	)		6,151
Income from continuing operations before income taxes		386,220			208,642			845,370			613,443
Income before income taxes														402,221			217,253			519,851			459,150
Income tax provision		(41,789	)		(40,782	)		(124,641	)		(110,625	)		(56,822	)		(39,405	)		(50,319	)		(82,852	)
Net income from continuing operations		344,431			167,860			720,729			502,818
Net (loss) income from discontinued operations, net of tax		—			(20,214	)		—			175,532
Net income		344,431			147,646			720,729			678,350			345,399			177,848			469,532			376,298
Net income attributable to noncontrolling interests		(18,624	)		(20,471	)		(57,488	)		(60,290	)		(22,533	)		(18,817	)		(41,181	)		(38,864	)
Net income attributable to Noble Corporation plc	$	325,807		$	127,175		$	663,241		$	618,060		$	322,866		$	159,031		$	428,351		$	337,434
Net income attributable to Noble Corporation plc
Income from continuing operations	$	325,807		$	147,389		$	663,241		$	442,528
(Loss)/income from discontinued operations		—			(20,214	)		—			175,532
Net income attributable to Noble Corporation plc	$	325,807		$	127,175		$	663,241		$	618,060
Per share data:
Basic:													$	1.28		$	0.64		$	1.70		$	1.36
Income from continuing operations	$	1.32		$	0.57		$	2.68		$	1.71
(Loss)/income from discontinued operations		—			(0.08	)		—			0.68
Net income attributable to Noble Corporation plc	$	1.32		$	0.49		$	2.68		$	2.39
Diluted:													$	1.28		$	0.64		$	1.70		$	1.36
Income from continuing operations	$	1.32		$	0.57		$	2.68		$	1.71
(Loss)/income from discontinued operations		—			(0.08	)		—			0.68
Net income attributable to Noble Corporation plc	$	1.32		$	0.49		$	2.68		$	2.39

	Nine Months Ended						Six Months Ended
	September 30,						June 30,
	2015			2014			2016			2015
Cash flows from operating activities
Net income	$	720,729		$	678,350		$	469,532		$	376,298
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization		473,913			696,380			300,665			313,261
Loss on impairment								16,616			—
Gain on extinguishment of debt, net								(11,066	)		—
Deferred income taxes		(76,012	)		23,380			(100,408	)		(17,312	)
Amortization of share-based compensation		30,296			37,432			19,565			21,147
Net change in other assets and liabilities		103,299			(47,244	)		166,653			74,484
Net cash from operating activities		1,252,225			1,388,298			861,557			767,878
Cash flows from investing activities
Capital expenditures		(280,048	)		(1,747,495	)		(120,531	)		(170,283	)
Change in accrued capital expenditures		(43,440	)		(52,466	)		(38,378	)		(38,408	)
Proceeds from disposal of assets		2,535			—			21,190			—
Net cash from investing activities		(320,953	)		(1,799,961	)		(137,719	)		(208,691	)
Cash flows from financing activities
Net change in borrowings outstanding on bank credit facilities		(1,123,495	)		(569,489	)		—			(1,123,495	)
Issuance of senior notes								—			1,092,728
Debt issuance costs on senior notes and credit facilities								—			(16,070	)
Repayment of long-term debt		(350,000	)		(250,000	)		(300,000	)		—
Issuance of senior notes		1,092,728			—
Long-term borrowings of Paragon Offshore		—			1,726,750
Financing costs on long-term borrowings of Paragon Offshore		—			(30,876	)
Cash balances of Paragon Offshore in Spin-off		—			(104,152	)
Debt issuance costs on senior notes and credit facilities	��	(16,070	)		(386	)
Early repayment of long-term debt								(22,207	)		—
Premiums paid on early repayment of long-term debt								(1,781	)		—
Dividend payments								(42,542	)		(185,669	)
Dividends paid to noncontrolling interests		(57,048	)		(64,339	)		(41,088	)		(44,484	)
Repurchases of shares		(100,630	)		(52,701	)		—			(100,630	)
Dividend payments		(278,443	)		(290,643	)
Employee stock transactions		(2,394	)		1,395			(5,487	)		(2,394	)
Net cash from financing activities		(835,352	)		365,559			(413,105	)		(380,014	)
Net change in cash and cash equivalents		95,920			(46,104	)		310,733			179,173
Cash and cash equivalents, beginning of period		68,510			114,458			512,245			68,510
Cash and cash equivalents, end of period	$	164,430		$	68,354		$	822,978		$	247,683

													Accumulated
							Additional						Other
	Shares						Paid-in			Retained			Comprehensive			Noncontrolling			Total
	Balance			Par Value			Capital			Earnings			Loss			Interests			Equity
Balance at December 31, 2014		247,501		$	2,475		$	695,638		$	5,936,035		$	(69,418	)	$	722,304		$	7,287,034
Employee related equity activity
Amortization of share-based compensation		—			—			21,147			—			—			—			21,147
Issuance of share-based compensation shares		678			7			(4,149	)		—			—			—			(4,142	)
Tax benefit of equity transactions		—			—			(2,401	)		—			—			—			(2,401	)
Repurchases of shares		(6,209	)		(62	)		(100,568	)		—			—			—			(100,630	)
Net income		—			—			—			337,434			—			38,864			376,298
Dividends paid to noncontrolling interests		—			—			—			—			—			(44,484	)		(44,484	)
Dividends		—			—			—			(185,669	)		—			—			(185,669	)
Other comprehensive income, net		—			—			—			—			245			—			245
Balance at June 30, 2015		241,970		$	2,420		$	609,667		$	6,087,800		$	(69,173	)	$	716,684		$	7,347,398
Balance at December 31, 2015		241,977		$	2,420		$	628,483		$	6,131,501		$	(63,175	)	$	723,001		$	7,422,230
Employee related equity activity
Amortization of share-based compensation		—			—			19,565			—			—			—			19,565
Issuance of share-based compensation shares		1,241			12			(3,585	)		—			—			—			(3,573	)
Tax benefit of equity transactions		—			—			(5,499	)		—			—			—			(5,499	)
Net income		—			—			—			428,351			—			41,181			469,532
Dividends paid to noncontrolling interests		—			—			—			—			—			(41,088	)		(41,088	)
Dividends		—			—			—			(42,691	)		—			—			(42,691	)
Other comprehensive income, net		—			—			—			—			1,305			—			1,305
Balance at June 30, 2016		243,218		$	2,432		$	638,964		$	6,517,161		$	(61,870	)	$	723,094		$	7,819,781

Accumulated

Additional

Other

Shares

Paid-in

Retained

Comprehensive

Noncontrolling

Total

Balance

Par Value

Capital

Earnings

Loss

Interests

Equity

Balance at December 31, 2013

253,448

$
2,534

$
810,286

$
7,591,927

$
(82,164
)

$
727,445

$
9,050,028

Employee related equity activity

Amortization of share-based
   compensation

—

—

37,432

—

—

—

37,432

Issuance of share-based
   compensation shares

689

6

(9,049
)

—

—

—

(9,043
)
Exercise of stock options

131

3

2,644

—

—

—

2,647

Tax benefit of equity transactions

—

—

(1,258
)

—

—

—

(1,258
)
Repurchases of shares

(2,010
)

(20
)

(52,681
)

—

—

—

(52,701
)
Net income

—

—

—

618,060

—

60,290

678,350

Dividends paid to noncontrolling
   interests

—

—

—

—

—

(64,339
)

(64,339
)
Dividends

—

—

—

(162,294
)

—

—

(162,294
)
Spin-off of Paragon Offshore

—

—

—

(1,413,499
)

34,478

—

(1,379,021
)
Other comprehensive income, net

—

—

—

—

1,918

—

1,918

Balance at September 30, 2014

252,258

$
2,523

$
787,374

$
6,634,194

$
(45,768
)

$
723,396

$
8,101,719

Balance at December 31, 2014

247,501

$
2,475

$
695,638

$
5,936,035

$
(69,418
)

$
722,304

$
7,287,034

Employee related equity activity

Amortization of share-based
   compensation

—

—

30,296

—

—

—

30,296

Issuance of share-based
   compensation shares

678

7

(4,157
)

—

—

—

(4,150
)
Tax benefit of equity transactions

—

—

(2,401
)

—

—

—

(2,401
)
Repurchases of shares

(6,209
)

(62
)

(100,568
)

—

—

—

(100,630
)
Net income

—

—

—

663,241

—

57,488

720,729

Dividends paid to noncontrolling
   interests

—

—

—

—

—

(57,048
)

(57,048
)
Dividends

—

—

—

(278,443
)

—

—

(278,443
)
Other comprehensive loss, net

—

—

—

—

(2,614
)

—

(2,614
)
Balance at September 30, 2015

241,970

$
2,420

$
618,808

$
6,320,833

$
(72,032
)

$
722,744

$
7,592,773

Accumulated

Capital in

Other

Shares

Excess of

Retained

Comprehensive

Noncontrolling

Total

Balance

Par Value

Par Value

Earnings

Loss

Interests

Equity

Balance at December 31, 2013

261,246

$
26,125

$
497,316

$
7,986,762

$
(82,164
)

$
727,445

$
9,155,484

Distributions to parent company, net

—

—

—

(421,801
)

—

—

(421,801
)
Capital contribution by parent - share-based
compensation

—

—

26,715

—

—

—

26,715

Net income

—

—

—

723,788

—

60,290

784,078

Dividends paid to noncontrolling interests

—

—

—

—

—

(64,339
)

(64,339
)
Spin-off of Paragon Offshore

—

—

—

(1,467,657
)

34,478

—

(1,433,179
)
Other comprehensive income, net

—

—

—

—

1,918

—

1,918

Balance at September 30, 2014

261,246

$
26,125

$
524,031

$
6,821,092

$
(45,768
)

$
723,396

$
8,048,876

Balance at December 31, 2014

261,246

$
26,125

$
530,657

$
6,009,114

$
(69,418
)

$
722,304

$
7,218,782

Distributions to parent company, net

—

—

—

(372,799
)

—

—

(372,799
)
Capital contribution by parent - share-based
compensation

—

—

21,875

—

—

—

21,875

Net income

—

—

—

690,879

—

57,488

748,367

Dividends paid to noncontrolling interests

—

—

—

—

—

(57,048
)

(57,048
)
Other comprehensive loss, net

—

—

—

—

(2,614
)

—

(2,614
)
Balance at September 30, 2015

261,246

$
26,125

$
552,532

$
6,327,194

$
(72,032
)

$
722,744

$
7,556,563

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

Noble Corporation plc, a public limited company incorporated under the laws of England and Wales (“Noble-UK”), is a leading offshore drilling contractor for the oil and gas industry. We perform contract drilling services with our global fleet of mobile offshore drilling units. As of the filing date of this Quarterly Report on Form 10-Q, our fleet consisted of 1514 jackups, ~~nine~~eight drillships and eight ~~semisubmersibles, including one high-specification, harsh environment jackup under construction.~~semisubmersibles.

We report our contract drilling operations as a single reportable segment, Contract Drilling Services, which reflects 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 global market for contract drilling services and are often redeployed to different regions due to changing demands of our customers, which consist largely of major independent and government owned/controlled oil and gas companies throughout the world. As of ~~September~~June 30, ~~2015,~~2016, our contract drilling services segment conducted operations in the United States, ~~Brazil, Argentina,~~ the North Sea, the Mediterranean, the Black Sea, ~~West Africa,~~ the Middle East, Asia and Australia. 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 an indirect, wholly-owned subsidiary of Noble-UK, our publicly-traded parent company. Noble-UK’s principal asset is all of the shares of Noble-Cayman. Noble-Cayman has no public equity outstanding. The consolidated financial statements of Noble-UK include the accounts of Noble-Cayman, and Noble-UK conducts substantially all of its business through Noble-Cayman and its subsidiaries.

The accompanying unaudited consolidated financial statements of Noble-UK 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 Quarterly Reports on 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, ~~2014~~2015 Consolidated Balance Sheets presented herein are derived from the December 31, ~~2014~~2015 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, ~~2014,~~2015, filed by both Noble-UK 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 accordance with our adoption of Accounting Standards Update (“ASU”) No. 2015-03 on January 1, 2016, unamortized debt issuance costs related to our senior notes of approximately $26 million as of December 31, 2015, which were previously included in “Other assets,” are included in either “Current maturities of long-term debt” or “Long-term debt” in the accompanying Consolidated Balance Sheets, based upon the maturity date of the respective senior notes.

On August 1, 2014, Noble-UK completed the separation and spin-off of a majority of its standard specification offshore drilling business (the “Spin-off”) through a pro rata distribution of all of the ordinary shares of its wholly-owned subsidiary, Paragon Offshore, to the holders of Noble’s ordinary shares. ~~Our shareholders received one share of Paragon Offshore~~

In February 2016, we entered into an agreement in principle for every three shares of Noble owned as of July 23, 2014, the record date for the distribution. Through the Spin-off, we disposed of most of our standard specification drilling units and related assets, liabilities and business. Prior to the Spin-off, Paragon Offshore issued approximately $1.7 billion of long-term debt. We used the proceeds from this debt to repay certain amounts outstanding under our commercial paper program. Paragon Offshore recently announced that it had retained an investment banking firm and a law firm to “consider strategic alternatives related to its capital structure.” Depending on what “strategic alternative”, if any, that Paragon Offshore elects to pursue, our ability to collect amounts due to us fromsettlement with Paragon Offshore under which, in exchange for a full and unconditional release of any claims by Paragon Offshore in connection with the ~~agreements below~~Spin-off (including certain claims that could be brought on behalf of Paragon Offshore’s creditors), we agreed to assume the administration of Mexican tax claims for specified years up to and including 2010, as well as the related bonding obligations and certain of the related tax liabilities. The settlement agreement with Paragon Offshore, which was signed by the parties on April 29, 2016, is subject to the approval of Paragon Offshore’s bankruptcy plan by a bankruptcy court. The court is not expected to rule on the plan until late September 2016 (see Note ~~14) could be adversely impacted and Paragon Offshore could become adverse to us in any potential litigation relating to the Spin-off.~~14 for additional information).

Prior to the completion of the Spin-off, Noble and Paragon Offshore entered into a series of agreements to effect the separation and Spin-off and govern the relationship between the parties after the Spin-off.

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

The general terms and conditions relating to the separation and Spin-off are set forth in the MSA. The MSA identifies the assets transferred, liabilities assumed and contracts assigned either to Paragon Offshore by us or by Paragon Offshore to us in the separation and describes when and how these transfers, assumptions and assignments would occur. The MSA provides for, among other things, Paragon Offshore’s responsibility for liabilities relating to its business and the responsibility of Noble for liabilities related to our, and in certain limited cases, Paragon Offshore’s business, in each case irrespective of when the liability arose. The MSA also contains indemnification obligations and ongoing commitments by us and Paragon Offshore.

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

The EMA allocates liabilities and responsibilities between us and Paragon Offshore relating to employment, compensation and benefits and other employment related matters.

The TSA provides for the allocation of tax liabilities and benefits between us and Paragon Offshore and governs the parties’ assistance with tax-related claims.

Under two transition services agreements, we agreed to continue, for a limited period of time, to provide various interim support services to Paragon Offshore, and Paragon Offshore agreed to provide various interim support services to us, including providing operational and administrative support for our remaining Brazilian operations.

Paragon Offshore, which had been reflected as continuing operations in our consolidated financial statements prior to the Spin-off, meets the criteria for being reported as discontinued operations and was reclassified as such in our results of operations. The results of discontinued operations for the three and nine months ended September 30, 2014 include the historical results of Paragon Offshore, including $31 million and $49 million, respectively, of non-recurring costs incurred by Noble related to the Spin-off.

~~Prior to the Spin-off, Paragon Offshore issued approximately $1.7 billion of debt consisting of:~~

We allocated interest expense on this debt, which is directly related to Paragon Offshore, to discontinued operations. For both the three and nine months ended September 30, 2014, we allocated approximately $4 million of interest expense related to such debt.

~~The following table provides the components of net income from discontinued operations, net of tax for Noble-UK for the three and nine months ended September 30, 2014:~~

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

We maintain a 50 percent interest in two joint ventures, each with a subsidiary of Royal Dutch Shell plc (“Shell”), that own and operate the two Bully-class drillships. We have determined that we are the primary beneficiary of the joint ventures. 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.

During the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014,~~2015, the Bully joint ventures approved and paid dividends totaling ~~$114~~$82 million and ~~$129~~$89 million, respectively. Of these amounts, 50 percent ~~were~~was paid to our joint venture partner.

The combined carrying amount of the Bully-class drillships at both ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014~~2015 totaled $1.4 billion. These assets were primarily funded through partner equity contributions. Cash held by the Bully joint ventures ~~was~~totaled approximately $52 million at ~~September~~June 30, ~~2015~~2016 as compared to approximately ~~$47~~$50 million at December 31, ~~2014.~~2015.

(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-UK:

Three months ended

Nine months ended

September 30,

September 30,

2015

2014

2015

2014

Numerator:

Basic

Income from continuing operations

$
325,807

$
147,389

$
663,241

$
442,528

Earnings allocated to unvested share-based payment awards

(7,143
)

(2,286
)

(14,661
)

(7,053
)
Income from continuing operations to common
   shareholders

318,664

145,103

648,580

435,475

(Loss)/income from discontinued operations

—

(20,214
)

—

175,532

Earnings allocated to unvested share-based payment awards

—

314

—

(2,798
)
(Loss)/income from discontinued operations, net of tax to
   common shareholders

—

(19,900
)

—

172,734

Net income attributable to Noble-UK

325,807

127,175

663,241

618,060

Earnings allocated to unvested share-based payment awards

(7,143
)

(1,972
)

(14,661
)

(9,851
)
Net income to common shareholders - basic

$
318,664

$
125,203

$
648,580

$
608,209

Diluted

Income from continuing operations

$
325,807

$
147,389

$
663,241

$
442,528

Earnings allocated to unvested share-based
   payment awards

(7,143
)

(2,285
)

(14,661
)

(7,050
)
Income from continuing operations to common
   shareholders

318,664

145,104

648,580

435,478

(Loss)/income from discontinued operations

—

(20,214
)

—

175,532

Earnings allocated to unvested share-based payment awards

—

313

—

(2,796
)
(Loss)/income from discontinued operations, net of
   tax to common shareholders

—

(19,901
)

—

172,736

Net income attributable to Noble-UK

325,807

127,175

663,241

618,060

Earnings allocated to unvested share-based
   payment awards

(7,143
)

(1,972
)

(14,661
)

(9,846
)
Net income to common shareholders - diluted

$
318,664

$
125,203

$
648,580

$
608,214

Denominator:

Weighted average shares outstanding - basic

241,970

253,842

242,204

254,006

Incremental shares issuable from assumed exercise
   of stock options

—

107

—

114

Weighted average shares outstanding - diluted

241,970

253,949

242,204

254,120

Weighted average unvested share-based
   payment awards

5,424

3,999

5,475

4,114

Earnings per share

Basic

Continuing operations

1.32

$
0.57

2.68

$
1.71

Discontinued operations

—

(0.08
)

—

0.68

Net income attributable to Noble-UK

1.32

$
0.49

2.68

$
2.39

Diluted

Continuing operations

1.32

$
0.57

2.68

$
1.71

Discontinued operations

—

(0.08
)

—

0.68

Net income attributable to Noble-UK

1.32

$
0.49

2.68

$
2.39

Dividends per share

$
0.375

$
0.375

$
1.125

$
1.125

	Three months ended						Six months ended
	June 30,						June 30,
	2016			2015			2016			2015
Numerator:
Basic
Net income attributable to Noble-UK	$	322,866		$	159,031		$	428,351		$	337,434
Earnings allocated to unvested share-based payment awards		(11,678	)		(3,555	)		(15,516	)		(7,489	)
Net income to common shareholders - basic	$	311,188		$	155,476		$	412,835		$	329,945
Diluted
Net income attributable to Noble-UK	$	322,866		$	159,031		$	428,351		$	337,434
Earnings allocated to unvested share-based payment awards		(11,678	)		(3,555	)		(15,516	)		(7,489	)
Net income to common shareholders - diluted	$	311,188		$	155,476		$	412,835		$	329,945
Denominator:
Weighted average shares outstanding - basic		243,217			241,966			243,021			242,324
Incremental shares issuable from assumed exercise of stock options		—			—			—			—
Weighted average shares outstanding - diluted		243,217			241,966			243,021			242,324
Weighted average unvested share-based payment awards		9,127			5,533			9,134			5,500
Earnings per share
Basic	$	1.28		$	0.64			1.70			1.36
Diluted	$	1.28		$	0.64			1.70			1.36
Dividends per share	$	0.02		$	0.375		$	0.17		$	0.75

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

Only those items having a dilutive impact on our basic earnings per share are included in diluted earnings per share. For the three months ended ~~September~~June 30, 2016 and 2015, ~~and 2014,~~ approximately ~~1.7~~1.6 million and ~~1.3~~1.7 million shares underlying stock options, respectively, were excluded from the diluted earnings per share as such stock options were not dilutive.

As of ~~September~~June 30, ~~2015,~~2016, Noble-UK had approximately ~~242.0~~243.2 million shares outstanding and trading as compared to approximately ~~247.5~~242.0 million shares outstanding and trading at December 31, ~~2014. The decrease in shares outstanding is primarily related to the repurchase of 6.2 million shares pursuant to our approved share repurchase program, discussed below.~~2015. Our Board of Directors may increase our share capital through the issuance of up to 53 million authorized shares (at current nominal value of $0.01 per share) without obtaining shareholder approval.

Our most recent quarterly dividend payment to shareholders, totaling approximately ~~$93~~$5 million (or ~~$0.375~~$0.02 per share), was declared on ~~July 24, 2015~~April 22, 2016 and paid on ~~August 10, 2015~~May 9, 2016 to holders of record on ~~August 3, 2015.~~May 2, 2016.

On July 22, 2016, our Board of Directors approved the payment of a quarterly dividend to shareholders of $0.02 per share. The payment is expected to total approximately $5 million, based on the number of shares currently outstanding.

The declaration and payment of dividends require authorization of the Board of Directors of Noble-UK, provided that such dividends on issued share capital may be paid only out of Noble-UK’s “distributable reserves” on its statutory balance sheet. Noble-UK is not permitted to pay dividends out of share capital, which includes share premiums. The payment of future dividends 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.

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

Under UK law, the Company is only permitted to purchase its own shares by way of an “off-market purchase” in a plan approved by shareholders. In December 2014, we received shareholder approval to repurchase up to ~~37,000,000~~37 million ordinary shares, or approximately 15 percent of our outstanding ordinary shares at the time of the shareholder approval. ~~Any repurchases are expected to be funded using cash on hand, cash from operations or borrowings under our Credit Facilities.~~ The authority to make such repurchases ~~will expire on the later of April 2016 or~~expired at the end of the Company’s 2016 annual general meeting of shareholders, at which ~~time we could seek shareholder approval for further repurchases.~~was held on April 22, 2016. During ~~the nine months ended September 30,~~ 2015, we repurchased 6.2 million of our ordinary shares covered by this authorization for a total cost of approximately $101 million. During the ~~three~~six months ended ~~September~~June 30, ~~2015,~~2016, we did not repurchase any of our shares.

Note 5 — Contract Settlement and Termination Agreement with Freeport-McMoRan Inc.

On May 10, 2016, Freeport-McMoRan Inc. (“FCX”), Freeport-McMoRan Oil & Gas LLC and one of our subsidiaries entered into an agreement terminating the contracts on the Noble Sam Croft and the Noble Tom Madden (“FCX Settlement”), which were scheduled to end in July 2017 and November 2017, respectively. For the three and six months ended June 30, 2016, Noble recognized approximately $379 million in “Contract drilling services revenue” associated with the FCX Settlement, which included $348 million recorded as a termination fee and $31 million for the accelerated recognition of other deferred contractual items. For the three and six months ended June 30, 2016, $11 million was recognized in “Contract drilling services expense” for the accelerated recognition of deferred mobilization and other expenses.

Pursuant to the FCX Settlement, Noble may receive payments from FCX contingent upon the average price of oil over a 12 month period from June 30, 2016 through June 30, 2017. These contingent payments were not designated for hedge accounting treatment under FASB standards, and therefore, changes in fair value are recognized as either income or loss in the accompanying Consolidated Statements of Income. On May 10, 2016, we recognized approximately $14 million in “Contract drilling services revenue” resulting from the contract termination date valuation of these contingent payments. On June 30, 2016, we recognized an additional $4 million in “Contract drilling services revenue,” which represents the change in valuation of these contingent payments from the termination date (May 10, 2016) to June 30, 2016 (see Note 11 for additional information).

At ~~September~~June 30, ~~2015,~~2016, we had receivables of approximately $14 million related to the Noble Max Smith, ~~that~~which are being disputed by our former customer, Petróleos Mexicanos (“Pemex”). These receivables have been classified as long-term and are included in “Other assets” on our Consolidated Balance Sheet. The disputed amounts relate to lost revenues for downtime that occurred after our rig was damaged when one of Pemex’s supply boats collided with our rig in 2010. In January 2012, we filed a lawsuit against Pemex in a Mexican court seeking recovery of these amounts. While we can make no assurances as to the outcome of this dispute, we believe we are entitled to the disputed amounts.

Property and equipment, at cost, as of ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014~~2015 for Noble-UK consisted of the following:

	September 30,		December 31,		June 30,		December 31,
	2015		2014		2016		2015
Drilling equipment and facilities	$	13,767,751	$	13,254,240	$	13,471,029	$	13,074,804
Construction in progress		714,913		969,985		462,420		761,347
Other		234,648		218,697		201,927		220,172
Property and equipment, at cost	$	14,717,312	$	14,442,922	$	14,135,376	$	14,056,323

Capital expenditures, including capitalized interest, totaled ~~$280~~$121 million and ~~$1.7 billion~~$170 million for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014,~~2015, respectively. Capitalized interest was $7$3 million and ~~$18~~$7 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, respectively, as compared to ~~$11~~$6 million and ~~$39~~$12 million for the three and ~~nine~~six months ended ~~September~~June 30, ~~2014.~~2015, respectively.

~~Capital expenditures~~During the six months ended June 30, 2016, we completed the sale of certain corporate assets and the previously retired rigs, the jackup Noble Charles Copeland and the drillship Noble Discoverer. In connection with the sale of these assets, we received proceeds of approximately $21 million.

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

Also during the six months ended June 30, 2016, we recorded an impairment charge of $17 million as a result of our decision to dispose of certain capital spare equipment.

Our total debt consisted of the following at June 30, 2016 and December 31, 2015:

In accordance with our adoption of ASU No. 2015-03 on January 1, 2016, unamortized debt issuance costs related to ~~Paragon Offshore~~our senior notes are shown as a direct reduction of the carrying amount of the related debt. The debt issuance costs previously included in “Other assets,” are included in either “Current maturities of long-term debt” or “Long-term debt” in the accompanying Consolidated Balance Sheets, based upon the maturity date of the respective senior notes.

We currently have a five-year $2.4 billion senior unsecured credit facility that matures in January 2020. The credit facility provides us with the ability to issue up to $500 million in letters of credit. The issuance of letters of credit under the facility reduces the amount available for borrowing. At June 30, 2016, we had no letters of credit issued under the ~~nine months ended September 30, 2014 totaled $150 million. Depreciation expense for Paragon Offshore~~facility.

We also have a commercial paper program that ~~was~~allows us to issue up to $2.4 billion in unsecured commercial paper notes. Amounts issued under the commercial paper program are supported by the unused capacity under our credit facility and, therefore, are classified as ~~discontinued operations totaled $35 million and $236 million, respectively, for~~long-term on our Consolidated Balance Sheet. The outstanding amounts of commercial paper reduce availability under our credit facility. Access to our commercial paper program is dependent upon our credit ratings. As our credit ratings are below investment grade, we are currently prohibited from accessing the ~~three and nine months ended September 30, 2014.~~commercial paper market.

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

~~During the three months ended September~~As of June 30, ~~2015, we sold for scrap the previously retired semisubmersible rigs, the~~ ~~Noble Driller~~ ~~and the~~ ~~Noble Jim Thompson. In connection with the sale of these rigs, we received proceeds of approximately $3 million.~~

~~Long-term debt consisted of the following at September 30, 2015 and December 31, 2014:~~

We currently have two credit facilities with an aggregate maximum capacity of $2.7 billion, which are comprised of a five year $2.4 billion senior unsecured credit facility that matures in January 2020 and a $225 million 364-day senior unsecured credit facility that matures in January 2016, ~~(together, the “Credit Facilities”).~~

We have a commercial paper program that allows us to issue up to $2.4 billion in unsecured commercial paper notes. Amounts issued under the commercial paper program are supported by the unused capacity under our Credit Facilities and, therefore, are classified as long-term on our Consolidated Balance Sheet. The outstanding amounts of commercial paper reduce availability under our Credit Facilities.

The $2.4 billion facility provides us with the ability to issue up to $500 million in letters of credit. The issuance of letters of credit under the facility reduces the amount available for borrowing. At September 30, 2015, we had no ~~letters~~amounts drawn on our credit facility.

Our credit facility and certain of our senior notes, as discussed below, have provisions which vary the applicable interest rates based upon our credit ~~issued under the facility.~~ratings.

In ~~March 2015,~~February 2016, as a result of a reduction in our indirect wholly-owned subsidiary, Noble Holding International Limited (“NHIL”), issued $1.1 billion aggregate principal amount of senior notes in three separate tranches, comprised of $250 million of 4.00%debt rating below investment grade by Moody’s Investors Service, the interest rates on our Senior Notes due 2018, ~~$450 million of 5.95%~~ Senior Notes due 2025 and ~~$400 million of 6.95%~~ Senior Notes due ~~2045. The weighted average coupon~~2045 were increased 1.00% each to 5.00%, 6.95% and 7.95%, respectively, effective the first day of ~~all three tranches is 5.87%.~~each interest period after which the downgrade occurred. As a result of an additional downgrade by S&P Global Ratings in July 2016, the interest rates on these Senior Notes were further increased by 0.25% each to 5.25%, 7.20% and 8.20%, respectively, effective the first day of each interest period after which the downgrade occurred. The interest ~~rate~~rates on these Senior Notes may be further increased if our debt rating were to be downgraded further (up to a maximum of an additional 75 basis points). Our other outstanding senior notes ~~may be increased if the~~do not contain provisions varying applicable interest rates based upon our credit rating applicable to the notes is downgraded below certain specified levels. The net proceeds of approximately $1.08 billion, after expenses, were used to repay indebtedness outstanding under our Credit Facilities and commercial paper program.

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

In ~~August 2015,~~March 2016, we repaid our ~~$350~~maturing $300 million ~~3.45%~~3.05% Senior Notes using cash on hand.

In March 2016, we commenced cash tender offers for our 4.90% Senior Notes due 2020, of which $500 million principal amount was outstanding, and our 4.625% Senior Notes due 2021, of which $400 million principal amount was outstanding. On April 1, 2016, we purchased $36 million of these Senior Notes for $24 million, plus accrued interest, using cash on hand. As a result of this transaction, we recognized a net gain of approximately $11 million during the three and six months ended June 30, 2016, which is reflected as “Gain on extinguishment of debt, net” in the accompanying Consolidated Statements of Income.

Our $300 million ~~3.05%~~2.50% Senior Notes mature during the first quarter of ~~2016.~~2017. We anticipate using cash on hand to repay the outstanding ~~balances; therefore, we have classified these balances as “Current maturities of long-term debt” on our Consolidated Balance Sheet as of September 30, 2015.~~balances.

The ~~Credit Facilities are~~credit facility is guaranteed by ~~NHIL~~Noble Holding International Limited (“NHIL”) and Noble Holding Corporation (“NHC”). The ~~covenants and events of default under the two Credit Facilities are substantially similar, and each~~credit facility contains a covenant that limits our ratio of debt to total tangible capitalization, as defined in the ~~Credit Facilities,~~credit facility, to 0.60. At ~~September~~June 30, ~~2015,~~2016, our ratio of debt to total tangible capitalization was approximately ~~0.37.~~0.35. We were in compliance with all covenants under the ~~Credit Facilities~~credit facility as of ~~September~~June 30, ~~2015.~~2016.

In addition to the covenants from the ~~Credit Facilities~~credit facility noted above, 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 on entering into sale and lease-back transactions. At ~~September~~June 30, ~~2015,~~2016, we were in compliance with all of our debt covenants. We continually monitor compliance with the covenants under our notes and expect to remain in compliance during the remainder of ~~2015.~~2016.

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). All remaining fair value disclosures are presented in Note 12.

~~The following table presents the estimated fair value of our total debt as of September 30, 2015 and December 31, 2014, respectively:~~

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

The following table presents the estimated fair value of our total debt, not including the effect of unamortized debt issuance costs, as of June 30, 2016 and December 31, 2015, respectively:

At ~~September~~June 30, ~~2015,~~2016, the reserves for uncertain tax positions totaled ~~$143~~$167 million (net of related tax benefits of ~~$13~~$1 million). If the ~~September~~June 30, ~~2015~~2016 reserves are not realized, the provision for income taxes would be reduced by ~~$143~~$167 million. At December 31, ~~2014,~~2015, the reserves for uncertain tax positions totaled ~~$116~~$166 million (net of related tax benefits of $1$14 million).

It is reasonably possible that our existing liabilities related to our reserve for uncertain tax positions may fluctuate in the next 12 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.

Pension costs include the following components for the three months ended ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

	Three Months Ended September 30,												Three Months Ended June 30,
	2015						2014						2016						2015
	Non-U.S.			U.S.			Non-U.S.			U.S.			Non-U.S.			U.S.			Non-U.S.			U.S.
Service cost	$	862		$	2,149		$	1,016		$	2,541		$	799		$	1,662		$	846		$	2,149
Interest cost		653			2,300			1,022			2,714			641			2,389			632			2,300
Return on plan assets		(942	)		(3,286	)		(1,397	)		(3,846	)		(904	)		(3,097	)		(911	)		(3,286	)
Amortization of prior service cost		26			36			(2	)		56			27			29			26			36
Recognized net actuarial loss		80			1,539			119			651			38			1,100			110			1,539
Curtailment expense		—			—			—			241
Settlement expense		—			—			—			310
Net pension expense	$	679		$	2,738		$	758		$	2,667		$	601		$	2,083		$	703		$	2,738

(Unless otherwise indicated, dollar amounts in net pension expense for the three months ended September 30, 2014 for our non-U.S. and U.S. plans was approximately $0.2 million each related to Paragon Offshore that was classified as discontinued operations.tables are in thousands, except per share data)

Pension costs include the following components for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

	Nine Months Ended September 30,												Six Months Ended June 30,
	2015						2014						2016						2015
	Non-U.S.			U.S.			Non-U.S.			U.S.			Non-U.S.			U.S.			Non-U.S.			U.S.
Service cost	$	2,582		$	6,447		$	3,869		$	7,623		$	1,574		$	3,324		$	1,720		$	4,298
Interest cost		1,927			6,899			3,950			8,142			1,275			4,778			1,274			4,599
Return on plan assets		(2,779	)		(9,859	)		(5,088	)		(11,538	)		(1,799	)		(6,194	)		(1,837	)		(6,573	)
Amortization of prior service cost		79			107			(12	)		168			53			58			53			71
Recognized net actuarial loss		235			4,618			748			1,953			75			2,200			155			3,079
Curtailment expense		—			—			—			241
Settlement expense		—			—			—			310
Net pension expense	$	2,044		$	8,212		$	3,467		$	6,899		$	1,178		$	4,166		$	1,365		$	5,474

Included in net pension expense for the nine months ended September 30, 2014 for our non-U.S. and U.S. plans was approximately $2 million and $1 million, respectively, related to Paragon Offshore that was classified as discontinued operations.

During ~~both~~ the three and ~~nine~~six months ended ~~September~~June 30, ~~2015,~~2016, we made contributions to our pension plans totaling approximately $2$3 million.

We periodically enter into derivative instruments to manage our exposure to fluctuations in 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.

~~(Unless otherwise indicated, dollar amounts~~The FCX Settlement includes two contingent payments, which are further discussed below. We are accounting for these contingent payments as derivative instruments that do not qualify under the Financial Accounting Standards Board (“FASB”) standards for hedge accounting treatment, and therefore, changes in ~~tables~~fair values are recognized as either income or loss in ~~thousands, except per share data)~~

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. Any change in fair value resulting from ineffectiveness is recognized immediately in earnings.

Several of our regional shorebases, including our North Sea ~~Australian~~ and ~~Brazilian~~Australian operations, have a significant amount of their cash operating expenses payable in local currencies. To limit the potential risk of currency fluctuations, we periodically enter into forward contracts, which settle monthly in the operations’ respective local currencies. All of these contracts have a maturity of less than 12 months. The forward contract settlements in the remainder of ~~2015~~2016 represent approximately 60 percent of these forecasted local currency requirements. The notional amount of the forward contracts outstanding, expressed in U.S. Dollars, was approximately ~~$23~~$25 million at ~~September~~June 30, ~~2015.~~2016. Total unrealized losses related to these forward contracts were approximately $1 million as of ~~September~~June 30, ~~2015~~2016 and were recorded as part of “Accumulated other comprehensive loss” (“AOCL”).

As discussed in Note 5, pursuant to the FCX Settlement, Noble may receive contingent payments from FCX on September 30, 2017, depending on the average price of oil over a 12 month period from June 30, 2016 through June 30, 2017. The average price of oil will be calculated using the daily closing price of West Texas Intermediate crude oil (“WTI”) (CL1) on the New York Mercantile Exchange for the period of June 30, 2016 through June 30, 2017. If the price of WTI averages more than $50 per barrel during such period, FCX will pay $25 million to Noble. In addition to the $25 million contingent payment, if the price of WTI averages more than $65 per barrel during such period, FCX will pay an additional $50 million to Noble. These contingent payments do not qualify for hedge accounting treatment under FASB standards, and therefore, changes in fair values are recognized as either income or loss in the accompanying Consolidated Statements of Income. These contingent payments are referred to as non-designated derivatives in the following tables. On May 10, 2016, we recognized approximately $14 million in “Contract drilling services revenue” resulting from the contract termination date valuation of these contingent payments. On June 30, 2016, we recognized an additional $4 million in “Contract drilling services revenue,” which represents the change in valuation of these contingent payments from the termination date (May 10, 2016) to June 30, 2016.

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

The following table, together with Note 12, summarizes the financial statement presentation and fair value of our derivative positions as of ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014:~~2015:

		Estimated fair value					Estimated fair value
	Balance sheet classification	September 30, 2015		December 31, 2014		Balance sheet classification	June 30, 2016		December 31, 2015
Asset derivatives
Cash flow hedges
Short-term foreign currency forward contracts	Prepaid expenses and other current assets	$	45	$	—	Prepaid expenses and other current assets	$	428	$	—
Non-designated derivatives
FCX Settlement						Other assets		17,600		—
Liability derivatives
Cash flow hedges
Short-term foreign currency forward contracts	Other current liabilities	$	1,407	$	—	Other current liabilities	$	1,496	$	—

To supplement the fair value disclosures in Note 12, the following table summarizes the recognized gains and losses of cash flow hedges and non-designated derivatives through AOCL or ~~through~~as “contract drilling services” revenue or expense for the three months ended ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

	Gain/(loss) recognized through AOCL						Gain/(loss) reclassified from AOCL to "contract drilling services" expense					Gain/(loss) recognized through "contract drilling services" expense				Gain/(loss) recognized through AOCL					Gain/(loss) reclassified from AOCL to "contract drilling services" expense					Gain/(loss) recognized through "contract drilling services" revenue
	2015			2014			2015			2014		2015		2014		2016			2015		2016		2015			2016		2015
Cash flow hedges
Foreign currency forward contracts	$	(747	)	$	(2,125	)	$	(615	)	$	1,852	$	—	$	—	$	(1,358	)	$	479	$	290	$	(570	)	$	—	$	—
Non-designated derivatives
FCX Settlement																$	—		$	—	$	—	$	—		$	17,600	$	—

To supplement the fair value disclosures in Note 12, the following table summarizes the recognized gains and losses of cash flow hedges and non-designated derivatives through AOCL or ~~through~~as “contract drilling services” revenue or expense for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

	Gain/(loss) recognized through AOCL						Gain/(loss) reclassified from AOCL to "contract drilling services" expense					Gain/(loss) recognized through "contract drilling services" expense				Gain/(loss) recognized through AOCL					Gain/(loss) reclassified from AOCL to "contract drilling services" expense					Gain/(loss) recognized through "contract drilling services" revenue
	2015			2014			2015			2014		2015		2014		2016			2015		2016		2015			2016		2015
Cash flow hedges
Foreign currency forward contracts	$	(143	)	$	(4,904	)	$	(1,219	)	$	4,631	$	—	$	—	$	(1,450	)	$	513	$	382	$	(604	)	$	—	$	—
Non-designated derivatives
FCX Settlement																$	—		$	—	$	—	$	—		$	17,600	$	—

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

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

	September 30, 2015								June 30, 2016
			Estimated Fair Value Measurements								Estimated Fair Value Measurements
			Quoted		Significant						Quoted		Significant
			Prices in		Other		Significant				Prices in		Other		Significant
			Active		Observable		Unobservable				Active		Observable		Unobservable
	Carrying		Markets		Inputs		Inputs		Carrying		Markets		Inputs		Inputs
	Amount		(Level 1)		(Level 2)		(Level 3)		Amount		(Level 1)		(Level 2)		(Level 3)
Assets -
Marketable securities	$	6,275	$	6,275	$	—	$	—	$	6,677	$	6,677	$	—	$	—
Foreign currency forward contracts		45		—		45		—		428		—		428		—
FCX Settlement										17,600		—		—		17,600
Liabilities -
Foreign currency forward contracts	$	1,407	$	—	$	1,407	$	—	$	1,496	$	—	$	1,496	$	—

December 31, 2014

December 31, 2015

Estimated Fair Value Measurements

Quoted

Significant

Quoted

Significant

Prices in

Other

Significant

Prices in

Other

Significant

Active

Observable

Unobservable

Active

Observable

Unobservable

Carrying

Markets

Inputs

Carrying

Markets

Inputs

Amount

(Level 1)

(Level 2)

(Level 3)

Amount

(Level 1)

(Level 2)

(Level 3)

Assets -

Marketable securities

6,175

—

6,352

—

~~The foreign currency forward contracts have been valued using actively quoted prices and quotes obtained from the counterparties to the contracts.~~ 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. The foreign currency forward contracts have been valued using actively quoted prices and quotes obtained from the counterparties to the contracts. The FCX Settlement has been valued using a Monte Carlo Simulation Model based on the following assumptions as of June 30, 2016:

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

The following tables set forth the components of, and changes in the accumulated balances for each component of, AOCL for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014.~~2015. All amounts within the tables are shown net of tax.

Gains /

Defined

(Losses) on

Benefit

Foreign

Cash Flow

Pension

Currency

Hedges⁽¹⁾

Items⁽²⁾

Items

Total

Balance at December 31, 2013

$
—

$
(58,598
)

$
(23,566
)

$
(82,164
)
Activity during period:

Other comprehensive income before reclassifications

4,358

—

1,143

5,501

Amounts reclassified from AOCL

(4,631
)

1,048

—

(3,583
)
Net other comprehensive income (loss)

(273
)

1,048

1,143

1,918

Spin-off of Paragon Offshore⁽³⁾

—

21,772

12,706

34,478

Balance at September 30, 2014

$
(273
)

$
(35,778
)

$
(9,717
)

$
(45,768
)
Balance at December 31, 2014

$
—

$
(58,440
)

$
(10,978
)

$
(69,418
)
Activity during period:

Other comprehensive loss before reclassifications

(2,581
)

—

(4,568
)

(7,149
)
Amounts reclassified from AOCL

1,219

3,316

—

4,535

Net other comprehensive income (loss)

(1,362
)

3,316

(4,568
)

(2,614
)
Balance at September 30, 2015

$
(1,362
)

$
(55,124
)

$
(15,546
)

$
(72,032
)

	Gains /			Defined
	(Losses) on			Benefit			Foreign
	Cash Flow			Pension			Currency
	Hedges⁽¹⁾			Items⁽²⁾			Items			Total
Balance at December 31, 2014	$	—		$	(58,440	)	$	(10,978	)	$	(69,418	)
Activity during period:
Other comprehensive income/(loss) before reclassifications		513			—			(1,874	)		(1,361	)
Amounts reclassified from AOCL		(604	)		2,210			—			1,606
Net other comprehensive income/(loss)		(91	)		2,210			(1,874	)		245
Balance at June 30, 2015	$	(91	)	$	(56,230	)	$	(12,852	)	$	(69,173	)
Balance at December 31, 2015	$	—		$	(46,919	)	$	(16,256	)	$	(63,175	)
Activity during period:
Other comprehensive income/(loss) before reclassifications		(1,450	)		—			806			(644	)
Amounts reclassified from AOCL		382			1,567			—			1,949
Net other comprehensive income/(loss)		(1,068	)		1,567			806			1,305
Balance at June 30, 2016	$	(1,068	)	$	(45,352	)	$	(15,450	)	$	(61,870	)

~~The~~ ~~Noble Homer Ferrington~~ was under contract with a subsidiary of Exxon Mobil Corporation (“Exxon”), which entered into an assignment agreement with British Petroleum plc (“BP”) for a two-well farmout of the rig in Libya after successfully drilling two wells with the rig for Exxon. In August 2010, BP attempted to terminate the assignment agreement claiming that the rig was not in the required condition, and Exxon 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 the Libyan operating subsidiaries of both BP and Exxon (the “Defendants”). The arbitration panel issued an award in our favor for dayrate revenues plus interest and fees. During the third quarter of 2015, BP paid us $150 million and Exxon paid us $27 million under the award, of which approximately $137 million was recognized as contract drilling services revenues, $30 million as interest income, and $10 million for the reimbursement of costs and fees as a reduction of contract drilling services costs.

In December 2014, one of our subsidiaries reached a settlement with the U.S. Department of Justice (“DOJ”) regarding our former drillship, the Noble Discoverer, and the Kulluk,a rig we were providing contract labor services for, in respect of violations of applicable law discovered in connection with a 2012 ~~coast guard~~Coast Guard inspection in Alaska and our own subsequent internal investigation. Under the terms of the agreement, the subsidiary pled guilty to oil record book, ballast record and required hazardous condition reporting violations with respect to the Noble Discoverer and an oil record book violation with respect to the Kulluk. The subsidiary paid $8.2 million in fines and $4 million in community service payments and was placed on probation for four years, provided that we may petition the court for early dismissal of probation after three years. If, during the term of probation, the subsidiary fails to adhere to the terms of the plea agreement, the DOJ may withdraw from the plea agreement and would be free to prosecute the subsidiary on all charges arising out of its investigation, including any charges dismissed pursuant to the terms of the plea agreement, as well as potentially other charges. We also implemented a comprehensive environmental compliance plan in connection with the settlement.

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

We have used a commercial agent in Brazil in connection with our Petróleo Brasileiro S.A. (“Petrobras”) drilling contracts. We understand that this agent has represented a number of different companies in Brazil over many years, including several offshore drilling contractors. ~~This~~In November 2015, this agent ~~has~~ pled guilty in Brazil in connection with the award of a drilling contract to a competitor and ~~has~~ implicated a Petrobras official as part of a wider investigation of Petrobras’ business practices. ~~We are not aware of any improper activity by Noble~~Following news reports relating to the agent’s involvement in the Brazil investigation in connection with ~~contracts that Noble has entered into~~his activities with ~~Petrobras, and~~other companies, we have ~~not~~ been ~~contacted by any~~conducting a review, which is now substantially complete, of our relationship with the agent and with Petrobras. We are in contact with the SEC, the Brazilian federal prosecutor’s office and the DOJ about this matter. We are cooperating with these agencies and they are aware of our internal review. To our knowledge, neither the agent, nor the government authorities ~~regarding such~~investigating the matter, has alleged that the agent or Noble acted improperly in connection with our contracts ~~or the investigation into Petrobras’ business practices.~~with Petrobras.

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

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 ~~September~~June 30, ~~2015,~~2016, there were 4542 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 and Mississippi. 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, 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 tax returns filed in those jurisdictions are subject to review and examination by tax authorities within those jurisdictions. ~~During~~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 ~~first quarter~~ultimate outcome of any existing or future assessments.

During 2014, the IRS began its examination of our tax reporting in the U.S. for the taxable years ended December 31, 2010 and 2011. We believe that we have accurately reported all amounts in our 2010 and 2011 tax returns. We believe the ultimate resolution of the ~~outstanding assessments in the U.S., for which we have not made any accrual,~~IRS examination will not have a material adverse effect on our consolidated financial statements. ~~We recognize uncertain~~

Under the TSA entered into at the time of the Spin-off, Noble and Paragon Offshore are each responsible for the taxes that relate to their respective business (whether such taxes were incurred through a Noble-retained or a Paragon-retained entity) and provide a corresponding indemnity. In addition, in February 2016, we entered into an agreement in principle with Paragon Offshore relating to tax ~~positions~~matters in Mexico described below in exchange for a full and unconditional release of any claims by Paragon Offshore in connection with the Spin-off (including any claims that ~~we believe have a greater than 50 percent likelihood~~could be brought on behalf of ~~being sustained. We cannot predict or provide assurance as~~its creditors). The settlement agreement with Paragon Offshore, which was signed by the parties on April 29, 2016, is subject to the ~~ultimate outcome~~approval of ~~any existing or future assessments.~~Paragon Offshore’s bankruptcy plan by a bankruptcy court. The court is not expected to rule on the plan until late September 2016 (see Note 2 for additional information).

Audit claims of approximately ~~$96~~$164 million attributable to income ~~customs~~ and other business taxes have been assessed against us in Mexico, ~~and Brazil,~~ as detailed below. Under our settlement agreement with Paragon Offshore, we agreed to assume the administration of Paragon Offshore’s Mexican income and value-added taxes for the years 2005 through 2010 and for Paragon Offshore’s Mexican customs taxes through 2010, as well as the related bonding obligations and certain of the tax related liabilities. In addition, under the agreement with Paragon Offshore, we agreed to (i) pay all of the ultimate resolved amount of Mexican income and value-added taxes related to Paragon Offshore’s business that were incurred through a Noble-retained entity, (ii) pay 50 percent of the ultimate resolved amount of Mexican income and value-added taxes related to Paragon Offshore’s business that were incurred through a Paragon Offshore-retained entity, (iii) pay 50 percent of the ultimate resolved amount of Mexican custom taxes related to Paragon Offshore’s business, and (iv) be required to post any tax appeal bond that may be required to challenge a final assessment. Paragon Offshore also agreed to pay 50 percent of the third party costs incurred by us in the administration of the tax claims. In connection with Paragon Offshore’s revised reorganization plan filed on August 5, 2016, we agreed to allow Paragon Offshore to pay up to $5 million of the Mexican tax and administrative costs described above that become owed to us in the form of an interest bearing note, which will be due at the end of the four year period following approval of their plan. Tax assessments of approximately $47 million for income and value-added taxes have been made against Noble entities in ~~Mexico, of which approximately $34 million relates to Paragon Offshore assets that operated through Noble-retained entities in Mexico prior to the Spin-off. Paragon Offshore has received tax~~Mexico. Tax assessments for income and value-added taxes of approximately ~~$203~~$191 million have been made against Paragon Offshore entities in Mexico, of which approximately ~~$47~~$44 million relates to ~~Noble assets~~Noble’s business that operated through Paragon Offshore-retained entities in Mexico prior to the Spin-off. We will only be obligated to post a tax appeal bond in the event a final assessment is made by Mexican authorities. As of July 15, 2016, there have been $3 million in final assessments that have been bonded.

In Brazil, Paragon Offshore has received tax assessments of approximately $116 million, of which $36 million relates to Noble assets that operated through a Paragon Offshore-retained entity in Brazil prior to the Spin-off. Under the TSA, Paragon Offshore must indemnify us for all assessed amounts that are related to Paragon Offshore’s Mexico assets, approximately $34 million as noted above, and we must indemnify Paragon Offshore for all assessed amounts that are related to Noble’s Mexico and Brazil assets, approximately $47 million and $36 million, respectively, as noted above, if and when such payments become due.

We have contested, or intend to contest or cooperate with Paragon Offshore where it is contesting, the assessments described above, 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. Tax authorities 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 or our ability to collect indemnities from Paragon Offshore under the TSA.

On January ~~23,~~ 2015, Noble received an official notification of a ruling from the Second Chamber of the Supreme Court in Mexico. The ruling settled an ongoing dispute in Mexico relating to the classification of a Noble subsidiary’s business activity and the applicable rate of depreciation under the Mexican law applicable to the activities of that subsidiary. The ruling did not result in any additional tax liability to Noble. Additionally, the ruling is only applicable to the Noble subsidiary named in the ruling and, therefore, does not establish the depreciation rate applicable to the assets of other Noble subsidiaries. ~~We will continue~~Under the recent agreement with Paragon Offshore, we agreed to ~~contest future assessments received. Any claim by the~~be responsible for any tax ~~authorities relating to this~~liability ultimately incurred because these depreciation ~~issue~~liabilities would be ~~related to the businesses transferred to Paragon Offshore in the Spin-off and, therefore, would be subject to indemnification by Paragon Offshore under the TSA.~~incurred

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

by Noble-retained entities, and such amounts are reflected in the discussion of Mexican audit claims in the preceding paragraph. We will continue to contest future assessments received, and do not believe we are liable for additional tax.

Paragon Offshore has received tax assessments of approximately $150 million attributable to income, customs and other business taxes in Brazil, of which $43 million relates to Noble’s business that operated through a Paragon Offshore-retained entity in Brazil prior to the Spin-off. Under the TSA, we must indemnify Paragon Offshore for all assessed amounts that are related to Noble’s Brazil business, approximately $43 million, if and when such payments become due.

We have contested, or intend to contest or cooperate with Paragon Offshore in Brazil where it is contesting, the assessments described above, 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. Tax authorities 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 or our ability to collect indemnities from Paragon Offshore under the TSA or the recent agreement with Paragon Offshore.

We have been notified by Petrobras that it is currently challenging assessments by Brazilian tax authorities of withholding taxes associated with the provision of drilling rigs for its operations in Brazil during 2008 and 2009. Petrobras has also notified us that if Petrobras must ultimately pay such withholding taxes, it will seek reimbursement from us for the portion allocable to our drilling rigs. The amount of withholding tax that Petrobras indicates may be allocable to Noble drilling rigs is ~~R$79 million (approximately $19 million).~~approximately $24 million. We believe that our contract with Petrobras requires Petrobras to indemnify us for these withholding taxes. We will, if necessary, vigorously defend our rights.

We maintain certain insurance coverage against specified marine perils, which includes physical damage and loss of ~~hire. The~~hire to our drilling rigs along with other associated coverage common in ~~the U.S. Gulf of Mexico are self-insured for named windstorm perils. In addition, we~~our industry. We maintain a physical damage deductible on our rigs of $25 million per occurrence. With respect to the U.S. Gulf of Mexico, hurricane risk has generally resulted in more restrictive and expensive coverage for U.S. named windstorm perils, and we have opted in certain years to maintain limited or no windstorm coverage. Our current program provides for $500 million in named windstorm coverage in the U.S. Gulf of Mexico. For the Noble Bully I, our customer assumes the risk of loss due to a named windstorm event, pursuant to the terms of the drilling contract, through the purchase of insurance coverage (provided that we are responsible for any deductible under such policy) or, at its option, the assumption of the risk of loss up to the insured value in lieu of the purchase of such insurance. 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, strikes or cyber risks. 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.

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 as of June 30, 2016, we had outstanding commitments, including shipyard and purchase commitments of approximately ~~$676 million at September 30, 2015.~~$559 million.

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-UK (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.

In April 2014, the FASB issued Accounting Standards Update (“ASU”) No. 2014-08, which amends FASB Accounting Standards Codification (“ASC”) Topic 205, “Presentation of Financial Statements” and ASC Topic 360, “Property, Plant, and Equipment.” This ASU alters the definition of a discontinued operation to cover only asset disposals that are a strategic shift with a major effect on an entity’s operations and finances, and calls for more extensive disclosures about a discontinued operation’s assets, liabilities, income and expenses. The guidance is effective for all disposals, or classifications as held-for-sale, of components of an entity that occur within annual periods beginning on or after December 15, 2014. This standard was not early adopted in connection with the Spin-off. The adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In May 2014, the FASB issued ASU No. 2014-09, which amends ASC Topic 606, “Revenue from Contracts with Customers.” The amendments in this ASU are intended to provide a more robust framework for addressing revenue issues, improve comparability of revenue recognition practices and improve disclosure requirements. In August 2015, the FASB issued ASU No. 2015-14, which defers the effective date of the new guidance by one year to interim and annual reporting periods beginning after December 15, 2017. We are evaluating what impact, if any, the adoption of this guidance will have on our financial condition, results of operations, cash flows or financial disclosures.

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

In May 2014, the FASB issued ASU No. 2014-09, which creates Accounting Standards Codification (“ASC”) Topic 606, “Revenue from Contracts with Customers,” and supersedes the revenue recognition requirements in Topic 605, “Revenue Recognition,” including most industry-specific revenue recognition guidance throughout the Industry Topics of the Codification. In addition, ASU No. 2014-09 supersedes the cost guidance in Subtopic 605-35, “Revenue Recognition—Construction-Type and Production-Type Contracts,” and creates new Subtopic 340-40, “Other Assets and Deferred Costs—Contracts with Customers.” In summary, the core principle of Topic 606 is to recognize revenue when promised goods or services are transferred to customers in an amount that reflects the consideration that is expected to be received for those goods or services. Companies are allowed to select between two transition methods: (1) a full retrospective transition method with the application of the new guidance to each prior reporting period presented, or (2) a retrospective transition method that recognizes the cumulative effect on prior periods at the date of adoption together with additional footnote disclosures. The amendments in ASU No. 2014-09 are effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period, and early application is not permitted. A number of amendments have been issued in connection with ASU No. 2014-09, all of which are effective upon adoption of Topic 606. In March 2016 and April 2016, the FASB issued clarification amendments ASU No. 2016-08 and ASU No. 2016-10 which clarify the implementation guidance on principle versus agent considerations and identify performance obligations and the licensing implementation guidance, respectively. In May 2016, the FASB issued ASU No. 2016-11 and ASU No. 2016-12 which rescind certain SEC Staff Observer comments that are codified in Topic 605, “Revenue Recognition,” and Topic 932, “Extractive Activities—Oil and Gas” and provide improvements to narrow aspects of ASU No. 2014-09, respectively. We are currently evaluating the impact the adoption of this guidance will have on our consolidated financial statements and have not made any decision on the method of adoption.

In June 2014, the FASB issued ASU No. 2014-12, which amends ASC Topic 718, “Compensation-Stock Compensation.” The guidance requires that a performance target that affects vesting and that could be achieved after the requisite service period be treated as a performance condition and should not be reflected in the estimate of the grant-date fair value of the award. The guidance is effective for annual periods beginning after December 15, 2015. The guidance can be applied prospectively for all awards granted or modified after the effective date or retrospectively to all awards with performance targets outstanding as of the beginning of the earliest annual period presented in the financial statements and to all new or modified awards thereafter. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

In August 2014, the FASB issued ASU No. 2014-15, which amends ASC Subtopic 205-40, “Disclosure of Uncertainties about an Entity’s Ability to continue as a Going Concern.” The amendments in this ASU provide guidance related to management’s responsibility to evaluate whether there is substantial doubt about an entity’s ability to continue as a going concern and to provide related footnote disclosures. The amendments are effective for the annual period ending after December 15, 2016, and for annual periods and interim periods thereafter. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~is not anticipated to have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

In January 2015, the FASB issued ASU No. 2015-01, which amends ASC Subtopic 225-20, “Income Statement – Extraordinary and Unusual Items.” The amendment in this ASU eliminates from GAAP the concept of extraordinary items. The amendments in this update are effective for interim and annual reporting periods beginning after December 15, 2015. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

In February 2015, the FASB issued ASU No. 2015-02, which amends ASC Subtopic 810, “Consolidations.” This amendment affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. Specifically, the amendments modify the evaluation of whether limited partnerships and similar legal entities are ~~VIEs~~variable interest entities (“VIEs”) or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs, particularly those that have fee arrangements and related party relationships. The standard is effective for interim and annual reporting periods beginning after December 15, 2015. The standard may be applied retrospectively or through a cumulative effect adjustment to retained earnings as of the beginning of the year of adoption. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

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

The standard is effective for interim and annual reporting periods beginning after December 15, 2015. ~~Early adoption is permitted for financial statements that have not been previously issued. The new guidance will be applied on a retrospective basis.~~ In August 2015, the FASB issued ASU No. 2015-15 which amends ASC Subtopic 835-30, “Interest – Imputation of Interest.” The guidance allows a debt issuance cost related to a line-of-credit to be presented in the balance sheet as an asset and subsequently amortized ratably over the term of the line-of credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. ~~We are evaluating what impact the~~The new guidance is applied on a retrospective basis. In accordance with our adoption of ~~this guidance will have on~~ASU No. 2015-03, unamortized debt issuance costs related to our ~~financial condition, results~~senior notes of ~~operations, cash flows~~approximately $26 million as of December 31, 2015, which were previously included in “Other assets,” are included in either “Current maturities of long-term debt” or ~~financial disclosures.~~“Long-term debt” in the accompanying Consolidated Balance Sheets, based upon the maturity date of the respective senior notes.

In April 2015, the FASB issued ASU No. 2015-04, which amends ASC Topic 715, “Compensation – Retirement Benefits.” The guidance gives an employer whose fiscal year end does not coincide with a calendar month end the ability, as a practical expedient, to measure defined benefit retirement obligations and related plan assets as of the month end that is closest to its fiscal year end. The ASU also provides a similar practical expedient for interim remeasurements of significant events. The standard is effective for interim and annual reporting periods beginning after December 15, 2015. Early adoption is permitted. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

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

measure defined benefit plan assets on a month-end date that is nearest to the year’s fiscal year-end when the fiscal period does not coincide with a month-end. Parts I and II of the new guidance should be applied on a retrospective basis. Part III of the new guidance should be applied on a prospective basis. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

In September 2015, the FASB issued ASU 2015-16, which amends Topic 805, “Business Combinations.” This amendment eliminates the requirement to retrospectively account for adjustments made to provisional amounts recognized in a business combination at the acquisition date with a corresponding adjustment to goodwill, and revise comparative information for prior periods presented in financial statements. Those adjustments are required when new information about circumstances that existed as of the acquisition date would have affected the measurement of the amount initially recognized. This update requires an entity to recognize these adjustments in the reporting period in which the adjustment amounts are determined. An acquirer must record the effect on earnings of changes in depreciation, amortization, or other income effects, calculated as if the accounting had been completed at the acquisition date. An entity must present separately on the face of the income statement, or disclose in the notes the portion of the amount recorded in current-period earnings by line item that would have been recorded in previous reporting periods if the adjustment had been recognized as of the acquisition date. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015. The adoption of this guidance did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

In November 2015, the FASB issued ASU No. 2015-17, which amends ASC Topic 740, “Income Taxes.” This amendment aligns the presentation of deferred income tax assets and liabilities with International Financial Reporting Standards. International Accounting Standard 1, Presentation of Financial Statements, requires deferred tax assets and liabilities to be classified as noncurrent in a classified statement of financial position. The current requirement that deferred tax liabilities and assets be offset and presented as a single amount is not affected by the amendments in this update. The standard is effective for interim and annual reporting periods beginning after December 15, 2016. Early adoption is permitted for all entities as of the beginning of an interim or annual reporting period. The amendments in this update may be applied either prospectively to all deferred tax liabilities and assets or retrospectively to all periods presented. We are evaluating what impact, if any, the adoption of this guidance will have on our financial condition, results of operations, cash flows or financial disclosures.

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

after December 15, 2018. We are evaluating what impact, if any, the adoption of this guidance will have on our financial condition, results of operations, cash flows or financial disclosures.

In March 2016, the FASB issued ASU No. 2016-05, which amends ASC Topic 815, “Derivatives and Hedging.” This amendment clarifies that a change in the counterparty to a derivative instrument that has been designated as a hedging instrument under Topic 815 does not, in and of itself, require dedesignation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016 and may be applied on either a prospective basis or a modified retrospective basis. We are evaluating what impact, if any, the adoption of this guidance will have on our financial condition, results of operations, cash flows or financial disclosures.

In March 2016, the FASB issued ASU No. 2016-09, which amends ASC Topic 718, “Compensation – Stock Compensation.” This amendment simplifies several aspects of the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. This guidance is effective for interim and annual reporting periods beginning after December 15, 2016. We are evaluating what impact, if any, the adoption of this guidance will have on our financial condition, results of operations, cash flows or financial disclosures.

Deferred revenues from drilling contracts totaled ~~$204~~$141 million and ~~$263~~$180 million at ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014,~~2015, respectively. Such amounts are included in either “Other current liabilities” or “Other liabilities” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition. Related expenses deferred under drilling contracts totaled ~~$87~~$55 million at ~~September~~June 30, ~~2015~~2016 as compared to ~~$94~~$78 million at December 31, ~~2014,~~2015, and are included in either “Prepaid expenses and other current assets” or “Other assets” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition.

In April 2015, we agreed to contract dayrate reductions for five rigs working for Saudi Arabian Oil Company (“Saudi Aramco”), which ~~are~~were effective from January 1, 2015 through December 31, 2015. During the first quarter of 2016, we agreed to further contract dayrate reductions for the remaining four contracted rigs through the end of 2016. Given current market conditions and based on discussions with the customer, we do not expect the rates to return to the original contract rates. In accordance with accounting guidance, we are recognizing the reductions on a straight-line basis over the remaining life of the existing Saudi Aramco contracts. At ~~September~~June 30, 2016 and December 31, 2015, revenues recorded in excess of billings as a result of this recognition totaled $35 million and $53 million, respectively, and are included in either “Prepaid expenses and other current assets” or “Other assets” in the accompanying Consolidated Balance Sheets, based upon our expected time of recognition.

The net effect of changes in other assets and liabilities on cash flows from operating activities is as follows. ~~Amounts for 2014 are shown net of Paragon Offshore, which was distributed to shareholders in a non-cash transaction.~~

	Noble-UK						Noble-Cayman						Noble-UK						Noble-Cayman
	Nine months ended						Nine months ended						Six months ended						Six months ended
	September 30,						September 30,						June 30,						June 30,
	2015			2014			2015			2014			2016			2015			2016			2015
Accounts receivable	$	38,695		$	(15,968	)	$	38,695		$	(15,968	)	$	147,454		$	28,673		$	147,454		$	28,673
Other current assets		48,548			(65,075	)		28,415			(71,784	)		75,949			68,667			73,543			48,106
Other assets		61,610			(51,887	)		41,314			(51,871	)		104,416			39,132			102,335			18,838
Accounts payable		(20,666	)		74,349			(18,743	)		33,909			(50,663	)		(9,915	)		(48,719	)		(7,947	)
Other current liabilities		(2,733	)		(23,882	)		11,295			(4,294	)		(71,913	)		(19,481	)		(67,843	)		(10,350	)
Other liabilities		(22,155	)		35,219			(22,155	)		51,346			(38,590	)		(32,592	)		(39,933	)		(32,594	)
	$	103,299		$	(47,244	)	$	78,821		$	(58,662	)	$	166,653		$	74,484		$	166,837		$	44,726

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

Noble-Cayman, or one or more wholly-owned subsidiaries of Noble-Cayman, are a co-issuer or full and unconditional guarantor or otherwise obligated as of ~~September~~June 30, ~~2015~~2016 as follows:

The following condensed consolidating financial statements of Noble-Cayman, NHC, NDH, 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 -											Subsidiaries			Consolidating						Noble -											Subsidiaries			Consolidating
	Cayman		NHC		NDH			NHIL		NDS6		of Noble			Adjustments			Total			Cayman		NHC		NDH			NHIL		NDS6		of Noble			Adjustments			Total
ASSETS
Current assets
Cash and cash equivalents	$	4	$	—	$	135		$	—	$	—	$	164,101		$	—		$	164,240		$	228	$	—	$	176		$	—	$	—	$	822,573		$	—		$	822,977
Accounts receivable		—		—		13,816			—		—		516,585			—			530,401			—		—		23,827			—		—		329,850			—			353,677
Taxes receivable		—		12,124		26			—		—		54,173			—			66,323			—		12,124		—			—		—		21,345			—			33,469
Short-term notes receivable from affiliates		—		—		119,476			—		—		171,925			(291,401	)		—			—		—		124,601			—		729,893		171,925			(1,026,419	)		—
Accounts receivable from affiliates		617,430		451,674		124,763			832,288		67,170		3,256,189			(5,349,514	)		—			678,787		10,090		138,928			66,508		77,570		3,061,317			(4,033,200	)		—
Prepaid expenses and other current assets		1,756		—		4,857			—		—		144,245			—			150,858			41		—		1,866			—		—		115,420			—			117,327
Total current assets		619,190		463,798		263,073			832,288		67,170		4,307,218			(5,640,915	)		911,822			679,056		22,214		289,398			66,508		807,463		4,522,430			(5,059,619	)		1,327,450
Property and equipment, at cost		—		—		1,846,298			—		—		12,833,307			—			14,679,605			—		—		1,928,307			—		—		12,207,069			—			14,135,376
Accumulated depreciation		—		—		(330,361	)		—		—		(2,456,068	)		—			(2,786,429	)		—		—		(387,699	)		—		—		(2,471,671	)		—			(2,859,370	)
Property and equipment, net		—		—		1,515,937			—		—		10,377,239			—			11,893,176			—		—		1,540,608			—		—		9,735,398			—			11,276,006
Notes receivable from affiliates		3,304,653		—		236,921			1,614,802		5,000		1,516,702			(6,678,078	)		—			3,304,672		—		112,705			69,564		5,000		1,995,607			(5,487,548	)		—
Investments in affiliates		5,306,418		1,413,824		2,973,478			9,384,951		6,951,400		—			(26,030,071	)		—			4,007,798		2,356,033		2,311,826			9,333,929		6,832,184		—			(24,841,770	)		—
Other assets		6,369		—		7,264			26,788		424		159,428			—			200,273			5,123		—		7,310			—		—		113,427			—			125,860
Total assets	$	9,236,630	$	1,877,622	$	4,996,673		$	11,858,829	$	7,023,994	$	16,360,587		$	(38,349,064	)	$	13,005,271		$	7,996,649	$	2,378,247	$	4,261,847		$	9,470,001	$	7,644,647	$	16,366,862		$	(35,388,937	)	$	12,729,316
LIABILITIES AND EQUITY
Current liabilities
Short-term notes payables from affiliates	$	—	$	171,925	$	—		$	—	$	—	$	119,476		$	(291,401	)	$	—		$	—	$	—	$	—		$	—	$	—	$	—		$	—		$	—
Current maturities of long-term debt		—		—		—			299,993		—		—			—			299,993			—		171,925		—			299,642		—		854,494			(1,026,419	)		299,642
Accounts payable		—		—		5,251			—		—		200,187			—			205,438			—		—		3,786			—		—		134,673			—			138,459
Accrued payroll and related costs		—		—		8,004			—		—		78,108			—			86,112			—		—		4,999			—		—		45,436			—			50,435
Accounts payable to affiliates		837,540		67,191		2,274,884			87,104		5,706		2,077,089			(5,349,514	)		—			882,039		79,542		1,933,446			176,010		—		962,163			(4,033,200	)		—
Taxes payable		—		35,743		—			—		—		116,393			—			152,136			—		2,028		—			—		—		150,213			—			152,241
Interest payable		—		—		—			44,292		630		—			—			44,922			1,700		—		—			67,686		4,412		—			—			73,798
Other current liabilities		103		—		4,824			—		—		99,672			—			104,599			—		—		3,501			—		—		75,945			—			79,446
Total current liabilities		837,643		274,859		2,292,963			431,389		6,336		2,690,925			(5,640,915	)		893,200			883,739		253,495		1,945,732			543,338		4,412		2,222,924			(5,059,619	)		794,021
Long-term debt		—		—		—			3,987,032		201,695		—			—			4,188,727			—		—		—			3,628,055		201,361		—			—			3,829,416
Notes payable to affiliates		1,545,239		—		460,227			1,169,180		124,216		3,379,216			(6,678,078	)		—			—		900,000		464,132			744,180		—		3,379,236			(5,487,548	)		—
Deferred income taxes		—		—		—			—		—		46,366			—			46,366			—		—		1,064			—		—		3,824			—			4,888
Other liabilities		19,929		—		26,361			—		—		274,125			—			320,415			19,929		—		23,427			—		—		241,560			—			284,916
Total liabilities		2,402,811		274,859		2,779,551			5,587,601		332,247		6,390,632			(12,318,993	)		5,448,708			903,668		1,153,495		2,434,355			4,915,573		205,773		5,847,544			(10,547,167	)		4,913,241
Commitments and contingencies		—		—		—			—		—		—			—			—			—		—		—			—		—		—			—			—
Total shareholder equity		6,833,819		1,602,763		2,217,122			6,271,228		6,691,747		8,810,922			(25,593,782	)		6,833,819			7,092,981		1,224,752		1,827,492			4,554,428		7,438,874		9,336,099			(24,381,645	)		7,092,981
Noncontrolling interests		—		—		—			—		—		1,159,033			(436,289	)		722,744			—		—		—			—		—		1,183,219			(460,125	)		723,094
Total equity		6,833,819		1,602,763		2,217,122			6,271,228		6,691,747		9,969,955			(26,030,071	)		7,556,563			7,092,981		1,224,752		1,827,492			4,554,428		7,438,874		10,519,318			(24,841,770	)		7,816,075
Total liabilities and equity	$	9,236,630	$	1,877,622	$	4,996,673		$	11,858,829	$	7,023,994	$	16,360,587		$	(38,349,064	)	$	13,005,271		$	7,996,649	$	2,378,247	$	4,261,847		$	9,470,001	$	7,644,647	$	16,366,862		$	(35,388,937	)	$	12,729,316

													Other																				Other
													Non-guarantor																				Non-guarantor
	Noble-												Subsidiaries			Consolidating						Noble-											Subsidiaries			Consolidating
	Cayman		NHC			NDH			NHIL		NDS6		of Noble			Adjustments			Total			Cayman		NHC		NDH			NHIL		NDS6		of Noble			Adjustments			Total
ASSETS
Current assets
Cash and cash equivalents	$	5	$	—		$	254		$	—	$	—	$	65,521		$	—		$	65,780		$	1,627	$	—	$	2,101		$	—	$	—	$	508,067		$	—		$	511,795
Accounts receivable		—		—			37,655			2,336		—		529,105			—			569,096			—		—		9,381			—		—		489,550			—			498,931
Taxes receivable		—		63,373			752			—		—		43,164			—			107,289			—		12,124		27			—		—		43,291			—			55,442
Short-term notes receivable from affiliates		123,449		—			1,077,965			—		333,966		171,925			(1,707,305	)		—			—		—		119,476			—		—		171,925			(291,401	)		—
Accounts receivable from affiliates		2,019,319		374,012			192,771			157,164		125,834		4,191,406			(7,060,506	)		—			626,305		451,201		128,457			811,785		67,684		3,445,590			(5,531,022	)		—
Prepaid expenses and other current assets		14,274		—			1,764			—		—		123,631			—			139,669			246		—		1,696			—		—		166,527			—			168,469
Total current assets		2,157,047		437,385			1,311,161			159,500		459,800		5,124,752			(8,767,811	)		881,834			628,178		463,325		261,138			811,785		67,684		4,824,950			(5,822,423	)		1,234,637
Property and equipment, at cost		—		—			2,040,168			—		—		12,364,203			—			14,404,371			—		—		1,877,520			—		—		12,177,038			—			14,054,558
Accumulated depreciation		—		—			(278,147	)		—		—		(2,040,073	)		—			(2,318,220	)		—		—		(344,591	)		—		—		(2,227,740	)		—			(2,572,331	)
Property and equipment, net		—		—			1,762,021			—		—		10,324,130			—			12,086,151			—		—		1,532,929			—		—		9,949,298			—			11,482,227
Notes receivable from affiliates		3,304,654		—			236,921			1,980,391		5,000		1,581,429			(7,108,395	)		—			3,304,652		—		236,921			1,587,927		5,000		2,435,154			(7,569,654	)		—
Investments in affiliates		4,567,335		1,318,239			2,921,452			8,266,444		6,290,918		—			(23,364,388	)		—			5,159,064		2,174,480		3,001,327			9,752,912		7,438,397		—			(27,526,180	)		—
Other assets		2,908		—			6,212			19,826		517		192,791			—			222,254			5,954		—		7,496			—		—		118,869			—			132,319
Total assets	$	10,031,944	$	1,755,624		$	6,237,767		$	10,426,161	$	6,756,235	$	17,223,102		$	(39,240,594	)	$	13,190,239		$	9,097,848	$	2,637,805	$	5,039,811		$	12,152,624	$	7,511,081	$	17,328,271		$	(40,918,257	)	$	12,849,183
LIABILITIES AND EQUITY
Current liabilities
Short-term notes payables from affiliates	$	—	$	171,925		$	—		$	—	$	371,720	$	1,163,660		$	(1,707,305	)	$	—		$	—	$	171,925	$	—		$	—	$	—	$	119,476		$	(291,401	)	$	—
Current maturities of long-term debt																							—		—		—			299,924		—		—			—			299,924
Accounts payable		600		—	��		10,130			—		—		250,282			—			261,012			—		—		10,676			—		—		210,401			—			221,077
Accrued payroll and related costs		—		—			7,738			—		—		83,749			—			91,487			—		—		6,584			—		—		74,780			—			81,364
Accounts payable to affiliates		606,224		63,602			3,513,705			61,982		16,869		2,798,124			(7,060,506	)		—			868,046		60,100		2,440,965			96,543		6,426		2,058,942			(5,531,022	)		—
Taxes payable		—		—			—			—		—		91,471			—			91,471			—		917		—			—		—		87,191			—			88,108
Interest payable		499		—			—			57,053		4,412		—			—			61,964			—		—		—			68,549		4,412		—			—			72,961
Other current liabilities		15,651		—			13,409			—		—		110,890			—			139,950			40		—		4,108			—		—		92,183			—			96,331
Total current liabilities		622,974		235,527			3,544,982			119,035		393,001		4,498,176			(8,767,811	)		645,884			868,086		232,942		2,462,333			465,016		10,838		2,642,973			(5,822,423	)		859,765
Long-term debt		1,123,495		—			—			3,543,830		201,695		—			—			4,869,020			—		—		—			3,961,338		201,300		—			—			4,162,638
Notes payable to affiliates		1,769,068		—			598,715			1,169,180		192,216		3,379,216			(7,108,395	)		—			1,518,363		—		461,379			2,086,480		124,216		3,379,216			(7,569,654	)		—
Deferred income taxes		—		—			—			—		—		120,589			—			120,589			—		—		1,529			—		—		91,268			—			92,797
Other liabilities		19,929		—			29,093			—		—		286,942			—			335,964			19,929		—		25,312			—		—		274,271			—			319,512
Total liabilities		3,535,466		235,527			4,172,790			4,832,045		786,912		8,284,923			(15,876,206	)		5,971,457			2,406,378		232,942		2,950,553			6,512,834		336,354		6,387,728			(13,392,077	)		5,434,712
Commitments and contingencies
Total shareholder equity		6,496,478		1,520,097			2,064,977			5,594,116		5,969,323		7,812,656			(22,961,169	)		6,496,478			6,691,470		2,404,863		2,089,258			5,639,790		7,174,727		9,781,284			(27,089,922	)		6,691,470
Noncontrolling interests		—		—			—			—		—		1,125,523			(403,219	)		722,304			—		—		—			—		—		1,159,259			(436,258	)		723,001
Total equity		6,496,478		1,520,097			2,064,977			5,594,116		5,969,323		8,938,179			(23,364,388	)		7,218,782			6,691,470		2,404,863		2,089,258			5,639,790		7,174,727		10,940,543			(27,526,180	)		7,414,471
Total liabilities and equity	$	10,031,944	$	1,755,624		$	6,237,767		$	10,426,161	$	6,756,235	$	17,223,102		$	(39,240,594	)	$	13,190,239		$	9,097,848	$	2,637,805	$	5,039,811		$	12,152,624	$	7,511,081	$	17,328,271		$	(40,918,257	)	$	12,849,183

																Other
																Non-guarantor
	Noble-															Subsidiaries			Consolidating
	Cayman			NHUS			NDH			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	—		$	64,839		$	—		$	—		$	838,984		$	(27,126	)	$	876,697
Reimbursables		—			—			2,622			—			—			15,311			—			17,933
Other		—			—			—			—			—			253			—			253
Total operating revenues		—			—			67,461			—			—			854,548			(27,126	)		894,883
Operating costs and expenses
Contract drilling services		972			4,318			11,960			19,290			—			232,820			(27,126	)		242,234
Reimbursables		—			—			2,345			—			—			11,953			—			14,298
Depreciation and amortization		—			—			22,309			—			—			128,629			—			150,938
General and administrative		306			2,340			—			10,920			1			286			—			13,853
Loss on impairment		—			—			—			—			—			16,616			—			16,616
Total operating costs and expenses		1,278			6,658			36,614			30,210			1			390,304			(27,126	)		437,939
Operating income (loss)		(1,278	)		(6,658	)		30,847			(30,210	)		(1	)		464,244			—			456,944
Other income (expense)
Income (loss) of unconsolidated affiliates		245,695			(13,250	)		(44,699	)		454,402			461,434			—			(1,103,582	)		—
Interest expense, net of amounts capitalized		(5,228	)		(21,339	)		(2,816	)		(59,812	)		(4,189	)		(95,104	)		131,182			(57,306	)
Gain on extinguishment of debt, net		—			—			—			11,066			—			—			—			11,066
Interest income and other, net		91,659			54			3,427			4,039			693			30,107			(131,182	)		(1,203	)
Income before income taxes		330,848			(41,193	)		(13,241	)		379,485			457,937			399,247			(1,103,582	)		409,501
Income tax provision		—			(23,656	)		(173	)		—			—			(32,291	)		—			(56,120	)
Net income		330,848			(64,849	)		(13,414	)		379,485			457,937			366,956			(1,103,582	)		353,381
Net income attributable to noncontrolling interests		—			—			—			—			—			(42,231	)		19,698			(22,533	)
Net income attributable to Noble Corporation		330,848			(64,849	)		(13,414	)		379,485			457,937			324,725			(1,083,884	)		330,848
Other comprehensive loss, net		(1,232	)		—			—			—			—			(1,232	)		1,232			(1,232	)
Comprehensive income attributable to Noble Corporation	$	329,616		$	(64,849	)	$	(13,414	)	$	379,485		$	457,937		$	323,493		$	(1,082,652	)	$	329,616

																Other
																Non-guarantor
	Noble-															Subsidiaries			Consolidating
	Cayman			NHUS			NDH			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	—		$	117,046		$	—		$	—		$	1,396,458		$	(45,440	)	$	1,468,064
Reimbursables		—			—			3,368			—			—			35,171			—			38,539
Other		—			—			—			—			—			853			—			853
Total operating revenues		—			—			120,414			—			—			1,432,482			(45,440	)		1,507,456
Operating costs and expenses
Contract drilling services		2,717			11,713			26,518			51,604			—			444,412			(45,440	)		491,524
Reimbursables		—			—			2,887			—			—			27,417			—			30,304
Depreciation and amortization		—			—			43,770			—			—			256,841			—			300,611
General and administrative		725			5,655			—			25,465			1			(7,388	)		—			24,458
Loss on impairment		—			—			—			—			—			16,616			—			16,616
Total operating costs and expenses		3,442			17,368			73,175			77,069			1			737,898			(45,440	)		863,513
Operating income (loss)		(3,442	)		(17,368	)		47,239			(77,069	)		(1	)		694,584			—			643,943
Other income (expense)
Income (loss) of unconsolidated affiliates		380,787			40,605			(58,282	)		630,756			598,805			—			(1,592,671	)		—
Interest expense, net of amounts capitalized		(22,784	)		(22,666	)		(5,564	)		(121,221	)		(8,464	)		(99,503	)		165,796			(114,406	)
Gain on extinguishment of debt, net		—			—			—			11,066			—			—			—			11,066
Interest income and other, net		93,308			50			6,903			19,360			762			43,477			(165,796	)		(1,936	)
Income before income taxes		447,869			621			(9,704	)		462,892			591,102			638,558			(1,592,671	)		538,667
Income tax provision		—			(33,738	)		(378	)		—			—			(15,501	)		—			(49,617	)
Net income		447,869			(33,117	)		(10,082	)		462,892			591,102			623,057			(1,592,671	)		489,050
Net income attributable to noncontrolling interests		—			—			—			—			—			(65,047	)		23,866			(41,181	)
Net income attributable to Noble Corporation		447,869			(33,117	)		(10,082	)		462,892			591,102			558,010			(1,568,805	)		447,869
Other comprehensive income, net		1,305			—			—			—			—			1,305			(1,305	)		1,305
Comprehensive income attributable to Noble Corporation	$	449,174		$	(33,117	)	$	(10,082	)	$	462,892		$	591,102		$	559,315		$	(1,570,110	)	$	449,174

																Other																								Other
																Non-guarantor																								Non-guarantor
	Noble-															Subsidiaries			Consolidating						Noble-															Subsidiaries			Consolidating
	Cayman			NHC			NDH			NHIL			NDS6			of Noble			Adjustments			Total			Cayman			NHC			NDH			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	—		$	37,659		$	—		$	—		$	856,145		$	(19,991	)	$	873,813		$	—		$	—		$	64,269		$	—		$	—		$	755,585		$	(48,547	)	$	771,307
Reimbursables		—			—			4,662			—			—			18,196			—			22,858			—			—			8,537			—			—			13,711			-			22,248
Total operating revenues		—			—			42,321			—			—			874,341			(19,991	)		896,671			—			—			72,806			—			—			769,296			(48,547	)		793,555
Operating costs and expenses
Contract drilling services		850			3,630			32,370			14,850			—			260,770			(19,991	)		292,479			2,792			8,302			17,864			23,389			—			315,167			(48,547	)		318,967
Reimbursables		—			—			8,414			—			—			9,369			—			17,783			—			—			3,299			—			—			14,353			—			17,652
Depreciation and amortization		—			—			20,690			—			—			139,693			—			160,383			—			—			20,683			—			—			138,114			—			158,797
General and administrative		192			1,866			—			7,524			—			794			—			10,376			482			3,672			—			9,045			1			309			—			13,509
Total operating costs and expenses		1,042			5,496			61,474			22,374			—			410,626			(19,991	)		481,021			3,274			11,974			41,846			32,434			1			467,943			(48,547	)		508,925
Operating income (loss)		(1,042	)		(5,496	)		(19,153	)		(22,374	)		—			463,715			—			415,650			(3,274	)		(11,974	)		30,960			(32,434	)		(1	)		301,353			—			284,630
Other income (expense)
Income (loss) of unconsolidated affiliates		334,441			130,794			70,445			344,840			132,616			—			(1,013,136	)		—
Total income (loss) of unconsolidated affiliates																										187,575			34,898			37,017			248,725			164,049			—			(672,264	)		—
Interest expense, net of amounts capitalized		(17,914	)		(1,342	)		(3,204	)		(58,129	)		(7,522	)		(37,611	)		71,035			(54,687	)		(21,133	)		(1,229	)		(3,310	)		(60,552	)		(7,753	)		(14,215	)		50,727			(57,465	)
Interest income and other, net		16,052			4			22,837			17,876			2,283			43,049			(71,035	)		31,066			3,743			(1	)		14,275			21,011			1,414			8,384			(50,727	)		(1,901	)
Income before income taxes		331,537			123,960			70,925			282,213			127,377			469,153			(1,013,136	)		392,029			166,911			21,694			78,942			176,750			157,709			295,522			(672,264	)		225,264
Income tax provision		—			(53,518	)		(1,198	)		—			—			12,848			—			(41,868	)		—			(17,592	)		(1,397	)		—			—			(20,547	)		—			(39,536	)
Net Income		331,537			70,442			69,727			282,213			127,377			482,001			(1,013,136	)		350,161
Net income																										166,911			4,102			77,545			176,750			157,709			274,975			(672,264	)		185,728
Net income attributable to noncontrolling interests		—			—			—			—			—			(32,733	)		14,109			(18,624	)		—			—			—			—			—			(27,360	)		8,543			(18,817	)
Net income attributable to Noble Corporation		331,537			70,442			69,727			282,213			127,377			449,268			(999,027	)		331,537			166,911			4,102			77,545			176,750			157,709			247,615			(663,721	)		166,911
Other comprehensive loss, net		(2,859	)		—			—			—			—			(2,859	)		2,859			(2,859	)
Other comprehensive income, net																										5,608			—			—			—			—			5,608			(5,608	)		5,608
Comprehensive income attributable to Noble Corporation	$	328,678		$	70,442		$	69,727		$	282,213		$	127,377		$	446,409		$	(996,168	)	$	328,678		$	172,519		$	4,102		$	77,545		$	176,750		$	157,709		$	253,223		$	(669,329	)	$	172,519

																Other																								Other
																Non-guarantor																								Non-guarantor
	Noble-															Subsidiaries			Consolidating						Noble-															Subsidiaries			Consolidating
	Cayman			NHC			NDH			NHIL			NDS6			of Noble			Adjustments			Total			Cayman			NHC			NDH			NHIL			NDS6			of Noble			Adjustments			Total
Operating revenues
Contract drilling services	$	—		$	—		$	176,987		$	—		$	—		$	2,349,537		$	(102,043	)	$	2,424,481		$	—		$	—		$	139,328		$	—		$	—		$	1,493,392		$	(82,052	)	$	1,550,668
Reimbursables		—			—			15,578			—			—			54,509			—			70,087			—			—			10,916			—			—			36,313			—			47,229
Total operating revenues		—			—			192,565			—			—			2,404,046			(102,043	)		2,494,568			—			—			150,244			—			—			1,529,705			(82,052	)		1,597,897
Operating costs and expenses
Contract drilling services		5,457			20,223			79,612			61,078			—			866,598			(102,043	)		930,925			4,607			16,593			47,242			46,228			—			605,828			(82,052	)		638,446
Reimbursables		—			—			13,195			—			—			42,397			—			55,592			—			—			4,781			—			—			33,028			—			37,809
Depreciation and amortization		—			—			58,741			—			—			414,305			—			473,046			—			—			38,051			—			—			274,612			—			312,663
General and administrative		1,131			8,926			—			24,918			1			1,117			—			36,093			939			7,060			-			17,394			1			323			—			25,717
Total operating costs and expenses		6,588			29,149			151,548			85,996			1			1,324,417			(102,043	)		1,495,656			5,546			23,653			90,074			63,622			1			913,791			(82,052	)		1,014,635
Operating income (loss)		(6,588	)		(29,149	)		41,017			(85,996	)		(1	)		1,079,629			—			998,912			(5,546	)		(23,653	)		60,170			(63,622	)		(1	)		615,914			—			583,262
Other income (expense)																																										��
Income (loss) of unconsolidated affiliates		738,742			197,773			162,486			883,323			475,715			—			(2,458,039	)		—
Total income (loss) of unconsolidated affiliates																										404,301			66,979			92,041			538,483			343,099			—			(1,444,903	)		—
Interest expense, net of amounts capitalized		(63,800	)		(3,590	)		(9,769	)		(167,017	)		(21,491	)		(65,553	)		170,024			(161,196	)		(45,886	)		(2,248	)		(6,565	)		(108,888	)		(13,969	)		(27,942	)		98,989			(106,509	)
Interest income and other, net		22,525			4,835			49,824			59,666			5,096			63,691			(170,024	)		35,613			6,473			4,831			26,987			41,790			2,813			20,642			(98,989	)		4,547
Income before income taxes		690,879			169,869			243,558			689,976			459,319			1,077,767			(2,458,039	)		873,329			359,342			45,909			172,633			407,763			331,942			608,614			(1,444,903	)		481,300
Income tax provision		—			(87,203	)		(2,974	)		—			—			(34,785	)		—			(124,962	)		—			(33,685	)		(1,776	)		—			—			(47,633	)		—			(83,094	)
Net Income		690,879			82,666			240,584			689,976			459,319			1,042,982			(2,458,039	)		748,367
Net income																										359,342			12,224			170,857			407,763			331,942			560,981			(1,444,903	)		398,206
Net income attributable to noncontrolling interests		—			—			—			—			—			(90,557	)		33,069			(57,488	)		—			—			—			—			—			(57,824	)		18,960			(38,864	)
Net income attributable to Noble Corporation		690,879			82,666			240,584			689,976			459,319			952,425			(2,424,970	)		690,879			359,342			12,224			170,857			407,763			331,942			503,157			(1,425,943	)		359,342
Other comprehensive loss, net		(2,614	)		—			—			—			—			(2,614	)		2,614			(2,614	)
Other comprehensive income, net																										245			—			—			—			—			245			(245	)		245
Comprehensive income attributable to Noble Corporation	$	688,265		$	82,666		$	240,584		$	689,976		$	459,319		$	949,811		$	(2,422,356	)	$	688,265		$	359,587		$	12,224		$	170,857		$	407,763		$	331,942		$	503,402		$	(1,426,188	)	$	359,587

Other

Non-guarantor

Noble-

Subsidiaries

Consolidating

Cayman

NHC

NDH

NHIL

NDS6

of Noble

Adjustments

Total

Operating revenues

Contract drilling services

$
—

$
—

$
81,834

$
—

$
—

$
866,699

$
(138,333
)

$
810,200

Reimbursables

—

—

1,495

—

—

17,100

—

18,595

Other

—

—

—

—

—

1

—

1

Total operating revenues

—

—

83,329

—

—

883,800

(138,333
)

828,796

Operating costs and expenses

Contract drilling services

3,571

9,239

27,593

25,489

—

456,352

(138,333
)

383,911

Reimbursables

—

—

1,112

—

—

12,529

—

13,641

Depreciation and amortization

—

—

16,922

—

—

143,333

—

160,255

General and administrative

397

2,348

—

6,530

—

3,782

—

13,057

Total operating costs and
   expenses

3,968

11,587

45,627

32,019

—

615,996

(138,333
)

570,864

Operating income (loss)

(3,968
)

(11,587
)

37,702

(32,019
)

—

267,804

—

257,932

Other income (expense)

Income (loss) of unconsolidated
   affiliates

(2,716,832
)

(20,299
)

(130,556
)

283,190

182,350

—

2,402,147

—

Income (loss) of unconsolidated affiliates - discontinued
   operations, net of tax

10,413

(3,921
)

(10,045
)

2,021

124

—

1,408

—

Total income (loss) of
   unconsolidated affiliates

(2,706,419
)

(24,220
)

(140,601
)

285,211

182,474

—

2,403,555

—

Interest expense, net of amounts
   capitalized

(22,352
)

(1,042
)

(8,729
)

(40,423
)

(10,573
)

(3,109,995
)

3,155,363

(37,751
)
Interest income and other, net

2,905,973

—

208,241

21,240

1,249

22,445

(3,155,363
)

3,785

Income from continuing operations
   before income taxes

173,234

(36,849
)

96,613

234,009

173,150

(2,819,746
)

2,403,555

223,966

Income tax provision

—

(11,352
)

(766
)

—

—

(28,556
)

—

(40,674
)
Net income from continuing
   operations

173,234

(48,201
)

95,847

234,009

173,150

(2,848,302
)

2,403,555

183,292

Net income from discontinued
   operations, net of tax

—

—

—

—

—

10,413

—

10,413

Net Income

173,234

(48,201
)

95,847

234,009

173,150

(2,837,889
)

2,403,555

193,705

Net income attributable to
   noncontrolling interests

—

—

—

—

—

(31,612
)

11,141

(20,471
)
Net income attributable to Noble
   Corporation

173,234

(48,201
)

95,847

234,009

173,150

(2,869,501
)

2,414,696

173,234

Other comprehensive loss, net

(8,982
)

—

—

—

—

(8,982
)

8,982

(8,982
)
Comprehensive income
   attributable to Noble Corporation

$
164,252

$
(48,201
)

$
95,847

$
234,009

$
173,150

$
(2,878,483
)

$
2,423,678

$
164,252

Other

Non-guarantor

Noble-

Subsidiaries

Consolidating

Cayman

NHC

NDH

NHIL

NDS6

of Noble

Adjustments

Total

Operating revenues

Contract drilling services

$
—

$
—

$
244,451

$
—

$
—

$
2,328,611

$
(212,857
)

$
2,360,205

Reimbursables

—

—

4,748

—

—

62,810

—

67,558

Other

—

—

—

—

—

1

—

1

Total operating revenues

—

—

249,199

—

—

2,391,422

(212,857
)

2,427,764

Operating costs and expenses

Contract drilling services

16,257

29,725

88,683

86,819

—

1,089,067

(212,857
)

1,097,694

Reimbursables

—

—

3,605

—

—

49,272

—

52,877

Depreciation and amortization

—

—

47,267

—

—

410,833

—

458,100

General and administrative

1,304

7,351

—

21,754

1

6,068

—

36,478

Total operating costs and
   expenses

17,561

37,076

139,555

108,573

1

1,555,240

(212,857
)

1,645,149

Operating income (loss)

(17,561
)

(37,076
)

109,644

(108,573
)

(1
)

836,182

—

782,615

Other income (expense)

Income (loss) of unconsolidated
   affiliates

(2,325,832
)

90,411

(9,789
)

703,700

466,521

—

1,074,989

—

Income (loss) of unconsolidated
   affiliates - discontinued
   operations, net of tax

225,022

49,146

94,515

183,347

6,249

—

(558,279
)

—

Total income (loss) of
   unconsolidated affiliates

(2,100,810
)

139,557

84,726

887,047

472,770

—

516,710

—

Interest expense, net of amounts
   capitalized

(70,702
)

(2,005
)

(21,703
)

(126,914
)

(26,477
)

(3,134,741
)

3,268,048

(114,494
)
Interest income and other, net

2,912,861

—

234,990

68,208

1,879

51,252

(3,268,048
)

1,142

Income from continuing
   operations before income taxes

723,788

100,476

407,657

719,768

448,171

(2,247,307
)

516,710

669,263

Income tax provision

—

(49,945
)

(2,972
)

—

(1,547
)

(55,743
)

—

(110,207
)
Net income from continuing
   operations

723,788

50,531

404,685

719,768

446,624

(2,303,050
)

516,710

559,056

Net income from discontinued
   operations, net of tax

—

(18,655
)

6,634

—

—

237,043

—

225,022

Net Income

723,788

31,876

411,319

719,768

446,624

(2,066,007
)

516,710

784,078

Net income attributable to
   noncontrolling interests

—

—

—

—

—

(95,253
)

34,963

(60,290
)
Net income attributable to Noble
   Corporation

723,788

31,876

411,319

719,768

446,624

(2,161,260
)

551,673

723,788

Other comprehensive income,
   net

1,918

—

—

—

—

1,918

(1,918
)

1,918

Comprehensive income
   attributable to Noble
   Corporation

$
725,706

$
31,876

$
411,319

$
719,768

$
446,624

$
(2,159,342
)

$
549,755

$
725,706

																Other
																Non-guarantor
	Noble-															Subsidiaries			Consolidating
	Cayman			NHC			NDH			NHIL			NDS6			of Noble			Adjustments		Total
Cash flows from operating activities
Net cash from operating activities	$	87,431		$	(72,611	)	$	66,135		$	(179,793	)	$	(7,703	)	$	985,834		$	—	$	879,293
Cash flows from investing activities
Capital expenditures		—			—			(44,139	)		—			—			(114,770	)		—		(158,909	)
Proceeds from disposal of assets		—			—			—			—			—			21,190			—		21,190
Net cash from investing activities		—			—			(44,139	)		—			—			(93,580	)		—		(137,719	)
Cash flows from financing activities
Repayment of long-term debt		—			—			—			(300,000	)		—			—			—		(300,000	)
Early repayment of long-term debt		—			—			—			(22,207	)		—			—			—		(22,207	)
Premiums paid on early repayment of long-term debt		—			—			—			(1,781	)		—			—			—		(1,781	)
Dividends paid to noncontrolling interests		—			—			—			—			—			(41,088	)		—		(41,088	)
Distributions to parent company, net		(65,316	)		—			—			—			—			—			—		(65,316	)
Advances (to) from affiliates		(23,514	)		72,611			(23,921	)		503,781			7,703			(536,660	)		—		—
Net cash from financing activities		(88,830	)		72,611			(23,921	)		179,793			7,703			(577,748	)		—		(430,392	)
Net change in cash and cash equivalents		(1,399	)		—			(1,925	)		—			—			314,506			—		311,182
Cash and cash equivalents, beginning of period		1,627			—			2,101			—			—			508,067			—		511,795
Cash and cash equivalents, end of period	$	228		$	—		$	176		$	—		$	—		$	822,573		$	—	$	822,977

Other

Non-guarantor

Noble-

Subsidiaries

Consolidating

Cayman

NHC

NDH

NHIL

NDS6

of Noble

Adjustments

Total

Cash flows from operating activities

Net cash from operating activities

$
(33,578
)

$
(28,115
)

$
141,329

$
(210,734
)

$
(20,085
)

$
1,397,280

$
—

$
1,246,097

Cash flows from investing activities

Capital expenditures

—

—

(80,743
)

—

—

(242,745
)

—

(323,488
)
Proceeds from disposal of assets

—

—

—

2,535

—

2,535

Notes receivable from affiliates

124,951

—

608,771

—

(733,722
)

—

Net cash from investing activities

124,951

—

(80,743
)

608,771

—

(240,210
)

(733,722
)

(320,953
)
Cash flows from financing activities

Net change in borrowings outstanding
   on bank credit facilities

(1,123,495
)

—

—

—

—

—

—

(1,123,495
)
Repayment of long-term debt

—

—

—

(350,000
)

—

—

—

(350,000
)
Issuance of senior notes

—

—

—

1,092,728

—

—

—

1,092,728

Debt issuance costs on senior notes
   and credit facilities

(6,450
)

—

—

(9,620
)

—

—

—

(16,070
)
Dividends paid to noncontrolling
   interests

—

—

—

—

—

(57,048
)

—

(57,048
)
Distributions to parent company, net

(372,799
)

—

—

—

—

—

—

(372,799
)
Advances (to) from affiliates

2,020,141

28,115

(60,705
)

(1,131,145
)

20,085

(876,491
)

—

—

Notes payable to affiliates

(608,771
)

—

—

—

—

(124,951
)

733,722

—

Net cash from financing activities

(91,374
)

28,115

(60,705
)

(398,037
)

20,085

(1,058,490
)

733,722

(826,684
)
Net change in cash and cash
   equivalents

(1
)

—

(119
)

—

—

98,580

—

98,460

Cash and cash equivalents, beginning
   of period

5

—

254

—

—

65,521

—

65,780

Cash and cash equivalents, end of period

$
4

$
—

$
135

$
—

$
—

$
164,101

$
—

$
164,240

																Other			��
																Non-guarantor
	Noble-															Subsidiaries				Consolidating
	Cayman			NHC			NDH			NHIL			NDS6			of Noble				Adjustments		Total
Cash flows from operating activities
Net cash from operating activities	$	(37,768	)	$	(7,445	)	$	123,844		$	(117,391	)	$	(11,095	)	$	802,833			$	—	$	752,978
Cash flows from investing activities
Capital expenditures		—			—			(48,227	)		—			—			(160,464	)			—		(208,691	)
Net cash from investing activities		—			—			(48,227	)		—			—			(160,464	)			—		(208,691	)
Cash flows from financing activities
Net change in borrowings outstanding on bank credit facilities		(1,123,495	)		—			—			—			—			—				—		(1,123,495	)
Issuance of senior notes		—			—			—			1,092,728			—			—				—		1,092,728
Debt issuance costs on senior notes and credit facilities		(6,450	)		—			—			(9,620	)		—			—				—		(16,070	)
Dividends paid to noncontrolling interests		—			—			—			—			—			(44,484	)			—		(44,484	)
Distributions to parent company, net		(273,626	)		—			—			—			—			—				—		(273,626	)
Advances (to) from affiliates		1,441,363			7,445			(75,745	)		(965,717	)		11,095			(418,441	)			—		—
Net cash from financing activities		37,792			7,445			(75,745	)		117,391			11,095			(462,925	)			—		(364,947	)
Net change in cash and cash equivalents		24			—			(128	)		—			—			179,444				—		179,340
Cash and cash equivalents, beginning of period		5			—			254			—			—			65,521				—		65,780
Cash and cash equivalents, end of period	$	29		$	—		$	126		$	—		$	—		$	244,965			$	—	$	245,120

Other

Non-guarantor

Noble-

Subsidiaries

Consolidating

Cayman

NHC

NDH

NHIL

NDS6

of Noble

Adjustments

Total

Cash flows from operating
   activities

Net cash from operating
   activities

$
2,858,748

$
(127,706
)

$
370,512

$
(211,228
)

$
(29,835
)

$
(1,390,805
)

$
—

$
1,469,686

Cash flows from investing
   activities

Capital expenditures

—

—

(1,245,121
)

—

—

(554,706
)

—

(1,799,827
)
Notes receivable from
   affiliates

50

—

—

273,744

—

—

(273,794
)

—

Net cash from investing
   activities

50

—

(1,245,121
)

273,744

—

(554,706
)

(273,794
)

(1,799,827
)
Cash flows from financing
   activities

Net change in borrowings
   outstanding on bank credit
   facilities

(569,489
)

—

—

—

—

—

—

(569,489
)
Repayment of long-term
   debt

—

—

—

(250,000
)

—

—

—

(250,000
)
Debt issuance costs on
   senior notes and credit
   facilities

(386
)

—

—

—

—

—

—

(386
)
Long-term borrowings
   of Paragon Offshore

—

—

—

—

—

1,726,750

1,726,750

Financing costs on long-
   term borrowings of
   Paragon Offshore

—

—

—

—

—

(30,876
)

(30,876
)
Cash balances of Paragon
   Offshore in Spin-off

—

—

—

—

(104,152
)

(104,152
)
Dividends paid to
   noncontrolling interests

—

—

—

—

—

(64,339
)

—

(64,339
)
Distributions to parent
   company, net

(421,801
)

—

—

—

—

—

—

(421,801
)
Advances (to) from
   affiliates

(1,593,374
)

127,706

874,565

187,480

29,835

373,788

—

—

Notes payable to affiliates

(273,744
)

—

—

—

—

(50
)

273,794

—

Net cash from financing
   activities

(2,858,794
)

127,706

874,565

(62,520
)

29,835

1,901,121

273,794

285,707

Net change in cash and
   cash equivalents

4

—

(44
)

(4
)

—

(44,390
)

—

(44,434
)
Cash and cash equivalents,
   beginning of period

1

—

402

4

—

109,975

—

110,382

Cash and cash equivalents,
   end of period

$
5

$
—

$
358

$
—

$
—

$
65,585

$
—

$
65,948

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 ~~September~~June 30, ~~2015,~~2016, and our results of operations for the three and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014.~~2015. 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, ~~2014~~2015 filed by Noble Corporation plc, a public limited company incorporated under the laws of England and Wales (“Noble-UK”), and Noble Corporation, a Cayman Islands company (“Noble-Cayman”).

As a result of the spin-off of Paragon Offshore plc, a public limited company incorporated under the laws of England and Wales (“Paragon Offshore”), on August 1, 2014, the results of operations for Paragon Offshore are reported as discontinued operations in this report. The terms “earnings” and “loss” as used in this “Management’s Discussion and Analysis of Financial Condition and Results of Operations” refer to income/(loss) from continuing operations. Income/ (loss) from continuing operations is representative of the Company’s current business operations and focus.

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 ~~including those~~ regarding rig demand, the offshore drilling market, oil prices, contract backlog, fleet status, our financial position, business strategy, impairments, ~~level of debt,~~ repayment of debt, ~~costs, expense management, timing or number of share repurchases,~~credit ratings, borrowings under our credit ~~facilities~~facility or other instruments, sources of funds, ~~completion, delivery dates and acceptance of our newbuild rigs,~~ future capital expenditures, contract commitments, dayrates, contract ~~amendments,~~ commencements, ~~extensions,~~extension or renewals, ~~renegotiations or terminations,~~ contract tenders, the outcome of any dispute, litigation, audit 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, access to financing, credit ratings, the collectability of indemnifiable amounts from Paragon Offshore or the possible effects on us of the potential pursuit by Paragon Offshore of strategic alternatives related to its capital structure, impact of competition, governmental regulations and permitting, availability of labor, worldwide economic conditions, taxes and tax rates, indebtedness covenant compliance, ~~dividend levels~~dividends and distributable reserves, timing or results of acquisitions or dispositions, 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, credit rating agencies, customers, joint venture partners, contractors, lenders and other third parties, market conditions, ~~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, operating hazards and delays, risks associated with operations outside the U.S., actions by regulatory authorities, credit rating agencies, customers, joint venture partners, contractors, lenders and other third parties, legislation and regulations affecting drilling operations, 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, ~~2014,~~2015, 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.

We are a leading offshore drilling contractor for the oil and gas industry. We perform contract drilling services with our global fleet of mobile offshore drilling units. As of the filing date of this Quarterly Report on Form 10-Q, our fleet consisted of 1514 jackups, ~~nine~~eight drillships and eight ~~semisubmersibles, including one high-specification, harsh environment jackup under construction.~~semisubmersibles.

We report our contract drilling operations as a single reportable segment, Contract Drilling Services, which reflects 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 global market for contract drilling services and are often redeployed to different regions due to changing demands of our customers, which consist largely of major independent and government owned/controlled oil and gas companies throughout the world. As of ~~September~~June 30, ~~2015,~~2016, our contract drilling services segment conducted operations in the United States, ~~Brazil, Argentina,~~ the North Sea, the Mediterranean, the Black Sea, the Middle East, Asia and Australia. Noble and its predecessors have been engaged in the contract drilling of oil and gas wells since 1921.

The business environment for offshore drillers during the first ~~nine~~six months of ~~2015~~2016 remained challenging. The rig capacity imbalance, caused in part by the addition of newbuild units and rigs completing current contracts, ~~increased~~continued to increase while customer demand for these rigs has ~~decreased.~~remained weak. Beginning in June 2014, the price of oil, a key factor in determining customer activity levels, began to decline rapidly, with the Brent crude price declining from approximately $112 per barrel on June 30, 2014 to ~~approximately $49~~as low as $30 per barrel in January 2016, before improving to $50 per barrel on ~~September~~June 30, ~~2015. In this environment,~~2016. The price improvement during the first

six months of 2016 from the January lows is not expected to stimulate customer spending on offshore projects in 2016. The offshore drilling programs of operators ~~have~~are expected to remain curtailed, ~~drilling programs,~~ especially exploration activity, ~~resulting~~until higher, sustainable prices are achieved. Until then, further deterioration in rig utilization and dayrates is possible. While there have been a ~~dramatic reduction in dayrates for new contracts as well as lower rig utilization. The industry has responded by accelerating the pace~~number of rig retirements in the industry since 2014, and ~~reducing~~more are expected over the ~~supply of marketed rigs across~~next two years, the ~~worldwide fleet.~~rig capacity imbalance has not been eliminated and is expected to be exacerbated by the remaining newbuild units that have yet to be delivered.

We expect that the business environment for the remainder of ~~2015~~2016 and ~~2016~~into 2017 will remain challenging and could potentially deteriorate further. The present level of global economic activity, ~~high levels of U.S. onshore oil production, the potential increase of oil supply from Iran and~~ a lack of production cuts within the Organization of Petroleum Exporting Countries (“OPEC”), the incremental production capacity in non-OPEC countries, including the U.S., and the recent Brexit vote in the UK are contributing to an uncertain oil price environment, leading to a persistent disruption in our customers’ exploration and production spending plans. ~~Current~~Capital expenditures undertaken by the offshore drilling industry in recent years have increased the supply of drilling rigs, and current and expected demand from customers ~~over~~during the remainder of ~~2015 and~~ 2016 is not expected to support ~~the~~this current ~~supply of offshore drilling rigs resulting from capital expenditures that the offshore drilling industry has undertaken~~supply. In general, recent contract awards have been short-term in ~~recent years.~~nature and subject to an extremely competitive bidding process. We cannot give any assurances as to when ~~these~~ conditions in the offshore drilling market will improve, or when there will be higher demand for contract drilling services or a decline in the supply of available drilling rigs. While current market conditions persist, we will continue to focus on operating efficiency, cost control and ~~operating margin preservation, which~~managing liquidity and could ~~include the stacking~~stack or ~~scrapping of~~retire additional drilling rigs.

We believe in the long-term fundamentals for the industry, especially for those contractors with a modern fleet of high-specification rigs like ours. Also, we believe the ultimate market recovery will benefit from any sustained under-investment by customers during this current phase of the market ~~phase.~~cycle.

Consistent with our policy, we evaluate property and equipment for impairment on an annual basis or whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. Further declines in the offshore drilling market, or lack of recovery in market conditions, to the extent actual results do not meet our estimated assumptions, may lead to potential impairments in the future.

Our business strategy focuses on deepwater drilling and high-specification jackups and the deployment of our drilling rigs in important oil and gas basins around the world.

WeOver the past five years, we have ~~actively~~ expanded our offshore deepwater drilling and high-specification jackup capabilities ~~in recent years~~ through the construction of rigs. ~~Currently, we have one~~We took delivery of our remaining newbuild project, ~~remaining,~~ the heavy-duty, harsh environment jackup, Noble Lloyd Noble, ~~which~~ on July 15, 2016. The Noble Lloyd Noble is scheduled to commence operations under a four-year contract in the North Sea during the ~~third~~fourth quarter of 2016. Although we plan to focus on capital preservation and liquidity based on current market conditions, we also plan to continue to evaluate opportunities as they arise from time to time to enhance our fleet, ~~to achieve greater technological capability, which we believe will lead to increased drilling efficiencies and an enhanced ability~~particularly focusing on higher specification rigs, to execute the increasingly more complex drilling programs required by our customers.

While we cannot predict the future level of demand or dayrates for our services, or future conditions in the offshore contract drilling industry, we believe we are strategically well positioned.

In February 2016, we entered into an agreement in principle for every three shares of Noble owned as of July 23, 2014, the record date for the distribution. Through the Spin-off, we disposed of most of our standard specification drilling units and related assets, liabilities and business. Prior to the Spin-off, Paragon Offshore issued approximately $1.7 billion of long-term debt. We used the proceeds from this debt to repay certain amounts outstanding under our commercial paper program. Paragon Offshore recently announced that it had retained an investment banking firm and a law firm to “consider strategic alternatives related to its capital structure.” Depending on what “strategic alternative”, if any, that Paragon Offshore elects to pursue, our ability to collect amounts due to us fromsettlement with Paragon Offshore under which, in exchange for a full and unconditional release of any claims by Paragon Offshore in connection with the ~~agreements below (see Note 14)~~Spin-off (including certain claims that could be ~~adversely impacted~~brought on behalf of Paragon Offshore’s creditors), we agreed to assume the administration of Mexican tax claims for specified years up to and including 2010, as well as the related bonding obligations and certain of the related tax liabilities. The settlement agreement with Paragon Offshore, ~~could become adverse to us in any potential litigation relating~~which was signed by the parties on April 29, 2016, is subject to the ~~Spin-off.~~ approval of Paragon Offshore’s bankruptcy plan by a bankruptcy court. The ~~results of operations for Paragon Offshore prior~~court is not expected to rule on the ~~Spin-off date and incremental Spin-off related costs have been classified as discontinued operations for~~

~~all periods presented in this Quarterly Report on Form 10-Q.~~ plan until late September 2016. For additional information regarding the Spin-off and the settlement agreement with Paragon Offshore, see Note 2 and Note 14 to the consolidated financial statements included in this report.

We maintain a backlog (as defined below) of commitments for contract drilling services. The following table sets forth, as of June 30, 2016, the amount of our contract drilling services backlog and the percent of available operating days committed for the periods indicated:

Our contract drilling services backlog reflects estimated future revenues attributable to both signed drilling contracts and letters of intent that we expect to result in binding drilling contracts. A letter of intent is generally subject to customary conditions, including the execution of a definitive drilling contract. It is possible that some customers that have entered into letters of intent will not enter into signed drilling contracts. As of June 30, 2016, our contract drilling services backlog did not include any letters of intent.

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 materially different than the backlog amounts and backlog periods set forth in the table above due to various factors, including, but not limited to, shipyard and maintenance projects, unplanned downtime, the operation of market benchmarks for dayrate resets, achievement of bonuses, weather conditions, reduced standby or mobilization rates and other factors that result in applicable dayrates lower than the full contractual operating dayrate. In addition, amounts included in the backlog may change because drilling contracts may be varied or modified by mutual consent or customers may exercise early termination rights contained in some of our drilling contracts or decline to enter into a drilling contract after executing a letter of intent. As a result, our backlog as of any particular date may not be indicative of our actual operating results for the periods for which the backlog is calculated. See Part I, Item 1A, “Risk Factors – We can provide no assurance that our current backlog of contract drilling revenue will be ultimately realized” in our Annual Report on Form 10-K for the year ended December 31, 2015.

As of June 30, 2016, Shell and Statoil ASA represented approximately 73 percent and 12 percent of our backlog, respectively.

Net income ~~from continuing operations~~ attributable to Noble-UK for the three months ended ~~September~~June 30, ~~2015~~2016 (the “Current Quarter”) was ~~$326~~$323 million, or ~~$1.32~~$1.28 per diluted share, on operating revenues of ~~$897~~$895 million, compared to net income ~~from continuing operations~~ for the three months ended ~~September~~June 30, ~~2014~~2015 (the “Comparable Quarter”) of ~~$147~~$159 million, or ~~$0.57~~$0.64 per diluted share, on operating revenues of ~~$829~~$794 million. ~~The Current Quarter results include amounts from the~~ ~~Noble Homer Ferrington~~ arbitration award from British Petroleum plc and a subsidiary of Exxon Mobil Corporation. The arbitration award totaled approximately $177 million, of which $137 million was recognized as contract drilling services revenues, $30 million as interest income, and $10 million for the reimbursement of costs and fees as a reduction of contract drilling services costs.

As a result of Noble-UK conducting all of its business through Noble-Cayman and its subsidiaries, 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 the Current Quarter and the Comparable Quarter, would be the same as the information presented below regarding Noble-UK in all material respects, except operating income for Noble-Cayman for the three months ended ~~September~~June 30, 2016 and 2015 ~~and 2014~~ was $6$7 million and ~~$14~~$9 million higher, respectively, than operating income for Noble-UK for the same periods. The operating income difference is primarily a result of executive costs directly attributable to Noble-UK for operations support and stewardship related services. ~~In addition, we had non-recurring costs of $31 million during the Comparable Quarter related to the Spin-off, which we recognized as part of discontinued operations at the Noble-UK level.~~

Operating results ~~from continuing operations~~ 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 ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

	Average Rig						Operating							Average							Average Rig						Operating							Average
	Utilization (1)						Days (2)							Dayrates							Utilization ⁽¹⁾						Days ⁽²⁾							Dayrates
	Three Months Ended						Three Months Ended							Three Months Ended							Three Months Ended						Three Months Ended							Three Months Ended
	September 30,						September 30,							September 30,							June 30,						June 30,							June 30,
	2015			2014			2015		2014		% Change			2015		2014		% Change			2016			2015			2016		2015		% Change			2016			2015		% Change
Jackups		84	%		91	%		1,005		951		6	%	$	159,745	$	182,128		-12	%		83	%		84	%		981		993		-1	%	$	136,041		$	171,482		-21	%
Semisubmersibles ~~(3)~~		59	%		67	%		432		674		-36	%		698,512		435,782		60	%		16	%		63	%		115		455		-75	%		290,106			403,319		-28	%
Drillships		100	%		100	%		828		712		16	%		497,147		482,053		3	%		86	%		100	%		626		819		-24	%		1,134,011	⁽³⁾		509,783		122	%
Total		82	%		85	%		2,265		2,337		-3	%	$	385,755	$	346,699		11	%		65	%		83	%		1,722		2,267		-24	%	$	509,145	⁽³⁾	$	340,217		50	%

The following table sets forth the operating results ~~from continuing operations~~ for our contract drilling services segment for the three months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015 (dollars in thousands):

	Three Months Ended										Three Months Ended
	September 30				Change						June 30				Change
	2015		2014		$			%			2016		2015		$			%
Operating revenues:
Contract drilling services	$	873,813	$	810,200	$	63,613			8	%	$	876,697	$	771,307	$	105,390			14	%
Reimbursables (1)		22,858		18,514		4,344			23	%		17,933		22,248		(4,315	)		-19	%
Other		—		1		(1	)	**				153		—		153		**
	$	896,671	$	828,715	$	67,956			8	%	$	894,783	$	793,555	$	101,228			13	%
Operating costs and expenses:
Contract drilling services	$	293,067	$	385,674	$	(92,607	)		-24	%	$	244,176	$	319,207	$	(75,031	)		-24	%
Reimbursables (1)		17,783		12,979		4,804			37	%		14,298		17,652		(3,354	)		-19	%
Depreciation and amortization		155,180		156,213		(1,033	)		-1	%		145,237		153,579		(8,342	)		-5	%
General and administrative		15,196		24,552		(9,356	)		-38	%		19,033		22,424		(3,391	)		-15	%
Loss on impairment												16,616		—		16,616		**
		481,226		579,418		(98,192	)		-17	%		439,360		512,862		(73,502	)		-14	%
Operating income	$	415,445	$	249,297	$	166,148			67	%	$	455,423	$	280,693	$	174,730			62	%

Operating Revenues. Changes in contract drilling services revenues for the Current Quarter as compared to the Comparable Quarter were driven by ~~an increase in average dayrates, partially offset by~~ a ~~decrease in operating days. The 11~~50 percent increase in average dayrates, which increased revenues by ~~$89 million, which was partially offset by~~$290 million. As indicated above, excluding the 3impact of the FCX Settlement, our average dayrates actually decreased in the Current Quarter as compared to the Comparable Quarter. Additionally, a 24 percent decrease in operating days ~~which decreased~~reduced revenues by ~~$25~~$185 million.

The increase in contract drilling services revenues ~~was~~ related to our drillships, ~~and semisubmersibles,~~ which generated ~~$69 million and $8~~$292 million more revenue ~~respectively,~~ than in the Comparable Quarter. This was partially offset by ~~decreased revenues related to~~ our semisubmersibles and jackups, which generated ~~$13~~$150 million and $37 million less revenue, ~~in the Current Quarter.~~

The increase in drillship revenues was driven by a 16 percent increase in operating days and a 3 percent increase in average dayrates, resulting in a $56 million and a $13 million increase in revenues, respectively, ~~from~~than in the Comparable Quarter. ~~The increase in both average dayrates and operating days was~~

During the ~~result of the newbuilds~~ ~~Noble Sam Croft~~ ~~and the~~ ~~Noble Tom Madden, which commenced their contracts in July 2014 and November 2014, respectively.~~

~~The increase in semisubmersible revenues was attributable to the recognition of $137~~Current Quarter, we recognized $393 million of dayrate revenues related to the ~~Noble Homer Ferrington~~ ~~arbitration award during~~FCX Settlement, of which $14 million related to the ~~Current Quarter.~~termination date valuation of certain contingent payments. Excluding ~~the arbitration award, semisubmersible~~these items, drillship revenues decreased by ~~$129~~$101 million driven by a 3624 percent decrease in operating days and a 1 percent decrease in average dayrates, resulting in decreases in revenues of $99 million and $2 million, respectively, from the Comparable Quarter. The decrease in both operating days and average dayrates was the result of the retirement and subsequent sale of the Noble Discoverer, which operated in the Comparable Quarter, as well as the contract cancellations of the Noble Sam Croft and the Noble Tom Madden in the Current Quarter. Additionally, unfavorable dayrate changes on contracts across the drillship fleet contributed to the decrease in average dayrates. This was partially offset by a $4 million change in valuation of the contingent payments from the FCX Settlement between the termination date (May 10, 2016) and June 30, 2016.

The $150 million decrease in semisubmersible revenue was driven by a 75 percent decline in operating days and a 1228 percent decline in average dayrates, resulting in a ~~$106~~$137 million and ~~$23~~a $13 million decline in revenues, respectively, from the Comparable Quarter. The decrease in both operating days and average dayrates was ~~primarily~~ attributable to the ~~retirement of~~contract completions for the Noble Clyde Boudreaux, the Noble Jim ~~Thompson~~Day, the Noble Amos Runner, the Noble Danny Adkins and the Noble ~~Driller~~Dave Beard ~~as a result~~, each of ~~our decision~~which has not returned to ~~discontinue marketing these rigs based on current market conditions. Additionally, the~~ ~~Noble Max Smith~~ ~~and~~ ~~Noble Paul Romano~~ ~~were operational during the Comparable Quarter but were off contract during the Current Quarter. This~~work since those completions. The decrease in revenues was partially offset by the Noble ~~Amos Runner~~Paul Romano, which operated ~~during the Current Quarter but was in the shipyard undergoing regulatory inspections and maintenance during the Comparable Quarter.~~

The 12 percent decrease in average dayrates on our jackups resulted in a $23 million decrease in revenues from the Comparable Quarter. The decrease in average dayrates was driven by unfavorable dayrate changes on contracts across the jackup fleet. This was partially offset by the 6 percent increase in operating days, which increased revenues by $10 million. The increase in operating days was the result of the commencement of the newbuild, ~~Noble Sam Turner,~~ ~~in August 2014 and the~~ ~~Noble David Tinsley, which was fully operational~~ during the Current Quarter but was off contract during the Comparable Quarter. ~~This~~

The $37 million decrease in jackup revenues was ~~partially offset~~driven by a 21 percent decline in average dayrates and a 1 percent decline in operating days, resulting in a $35 million and a $2 million decline in revenues, respectively, from the Comparable Quarter. The decrease in both average dayrates and operating days was primarily driven by the Noble ~~Mick O’Brien~~Regina Allen,, which was off contract during the Current Quarter but ~~experienced full utilization~~operated during the Comparable Quarter, and the retirement and subsequent sale of the Noble Charles Copeland, which operated in the Comparable Quarter. Additionally, unfavorable dayrate changes on contracts across the jackup fleet

contributed to the decrease in average dayrates. This was partially offset by the commencement of the newbuilds, the Noble Tom Prosser and the Noble Sam Hartley, which commenced their contracts in October 2015 and January 2016, respectively.

Operating Costs and Expenses. Contract drilling services operating costs and expenses decreased ~~$93~~$75 million for the Current Quarter as compared to the Comparable Quarter. This was due to decreased costs of ~~$33~~$57 million related to idle or stacked rigs and $22 million related to the retirement of the Noble Discoverer, the Noble Jim Thompson, the Noble Driller, the Noble Charles Copeland and the Noble Paul Wolff~~and $26 million related to idle or stacked rigs.~~. This was partially offset by crew-up and operating expenses for our newbuild rigs as they commenced ~~or prepared to commence,~~ operating under contracts, which added approximately ~~$27~~$11 million in expense in the Current Quarter. ~~Additionally, we received $10 million for the reimbursement of costs and fees related to the~~ ~~Noble Homer Ferrington~~ ~~arbitration award during the Current Quarter that were previously recognized through contract drilling services operating costs and expenses.~~ The remaining ~~$51~~$7 million decrease in costs was driven by ~~a $12~~decreases of $5 million ~~decrease in mobilization and transportation expenses related to certain rig moves during the Comparable Quarter, an $11 million decrease~~ in repair and maintenance costs, ~~an $11~~$5 million ~~decrease~~ in labor related costs ~~a $9~~and $8 million ~~decrease~~ in other rig-related expenses. This was partially offset by a cost increase of $11 million in the Current Quarter from the accelerated recognition of deferred mobilization and other expenses ~~a $6 million decrease in operations support costs and a $2 million decrease in insurance costs related to our policy renewal in March 2015.~~resulting from the FCX Settlement.

The $8 million decrease in depreciation and amortization in the Current Quarter from the Comparable Quarter was primarily attributable to the retirement of the ~~three semisubmersible~~five rigs discussed ~~above.~~above, partially offset by the newbuild rigs placed in service.

Loss on impairment of $17 million in the Current Quarter was a result of our decision to dispose of certain capital spare equipment.

General and administrative expenses. Overall, general and administrative expenses decreased $9$3 million in the Current Quarter as compared to the Comparable Quarter primarily as a result of decreased ~~legal and other~~employee related costs of $5 million, partially offset by increased professional ~~fees.~~fees of $2 million.

Interest Expense, net of amount capitalized. Interest expense, net of amount capitalized, ~~increased $17~~was $57 million in both the Current Quarter and the Comparable Quarter. Interest increases related to an increase in applicable interest rates on the senior notes issued in March 2015 due to the downgrading of our credit rating below investment grade during the Current Quarter, as ~~compared to the Comparable Quarter. The increase is a result of the issuance of $1.1 billion of senior notes in March 2015, coupled with a reduction in~~well as lower capitalized interest in the Current Quarter as compared to the Comparable Quarter ~~as a result of~~due to the completion of construction onof two ~~of our newbuild drillships and one of our~~ newbuild jackups. During the Current Quarter, we capitalized approximately 116 percent of total interest charges versus approximately 2310 percent during the Comparable Quarter.

~~Interest Income~~ These expense increases were fully offset by the repayment of our maturing $350 million 3.45% Senior Notes and ~~Other, Net.~~ ~~Interest income~~our $300 million 3.05% Senior Notes in August 2015 and ~~other, net increased $28 million in~~March 2016, respectively, and the Current Quarter retirement of a portion of our 2020 and 2021 Senior Notes as ~~compared to the Comparable Quarter. The increase is primarily the~~a result of ~~$30~~a tender offer.

Gain on extinguishment of debt, net. In March 2016, we commenced cash tender offers for our 4.90% Senior Notes due 2020, of which $500 million principal amount was outstanding, and our 4.625% Senior Notes due 2021, of which $400 million principal amount was outstanding. On April 1, 2016, we purchased $36 million of these Senior Notes for $24 million, plus accrued interest, ~~income~~using cash on hand. As a result of this transaction, we recognized ~~in connection with the~~ ~~Noble Homer Ferrington~~ ~~arbitration award~~a gain of approximately $11 million during the Current Quarter.

Income Tax Provision. Our income tax provision increased $1$17 million in the Current Quarter, of which ~~$29~~$55 million related to the ~~Noble Homer Ferrington~~ ~~arbitration award.~~FCX Settlement, the impairment of certain capital spare equipment, the retirement of a portion of our 2020 and 2021 Senior Notes as a result of a tender offer and a discrete tax item in the Current Quarter. Excluding the ~~arbitration award,~~impact of these items, taxes decreased by $38 million as a ~~$28 million decrease in our~~result of lower pre-tax income ~~tax provision was driven by~~and a lower effective tax rate than in the Comparable Quarter. The decreases in pre-tax earnings and the worldwide effective tax rate generated a $35 million and a $3 million decrease in income tax expense, respectively, in the Current ~~Quarter due to~~Quarter. The decrease in the worldwide effective tax rate is primarily a result of the geographic mix of ~~pre-tax~~ income ~~the effect~~and sources of ~~lower downtime coupled with cost reduction measures, as well as various discrete items.~~

~~Discontinued Operations.~~ Net loss from discontinued operations for the Comparable Quarter was $20 million. Revenues reported within discontinued operations were $142 million during the Comparable Quarter. Operating income included within discontinued operations was $1 million during the Comparable Quarter. There was no activity related to discontinued operationsrevenue during the Current Quarter.

For the ~~Nine~~Six Months Ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015

Net income ~~from continuing operations~~ attributable to Noble-UK for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 (the “Current Period”) was ~~$663~~$428 million, or ~~$2.68~~$1.70 per diluted share, on operating revenues of ~~$2.5~~$1.5 billion, compared to net income ~~from continuing operations~~ for the ~~nine~~six months ended ~~September~~June 30, ~~2014~~2015 (the “Comparable Period”) of ~~$443~~$337 million, or ~~$1.71~~$1.36 per diluted share, on operating revenues of ~~$2.4~~$1.6 billion. ~~The Current Period results include amounts from the~~ ~~Noble Homer Ferrington~~ arbitration award. The arbitration award totaled approximately $177 million, of which $137 million was recognized as contract drilling services revenues, $30 million as interest income, and $10 million for the reimbursement of costs and fees as a reduction of contract drilling services costs.

As a result of Noble-UK conducting all of its business through Noble-Cayman and its subsidiaries, 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 the Current Period and the Comparable Period, would be the same as the information presented below regarding Noble-UK in all material respects, except operating income for Noble-Cayman for the ~~nine~~six months ended ~~September~~June 30, 2016 and 2015 ~~and 2014~~ was ~~$29~~$19 million and ~~$55~~$24 million higher, respectively, than operating income for Noble-UK for the same periods. The operating income difference is primarily a result of executive costs directly attributable to Noble-UK for operations support and stewardship related services. ~~In addition, we had non-recurring costs of $49 million during the Comparable Period related to the Spin-off, which we recognized as part of discontinued operations at the Noble-UK level.~~

Operating results ~~from continuing operations~~ 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 ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014:~~2015:

	Average Rig						Operating							Average							Average Rig						Operating							Average
	Utilization (1)						Days (2)							Dayrates							Utilization (1)						Days (2)							Dayrates
	Nine Months Ended						Nine Months Ended							Nine Months Ended							Six Months Ended						Six Months Ended							Six Months Ended
	September 30,						September 30,							September 30,							June 30,						June 30,							June 30,
	2015			2014			2015		2014		% Change			2015		2014		% Change			2016			2015			2016		2015		% Change			2016			2015		% Change
Jackups		86	%		92	%		2,989		2,691		11	%	$	167,937	$	174,718		-4	%		84	%		88	%		1,962		1,983		-1	%	$	135,455		$	172,090		-21	%
Semisubmersibles ~~(3)~~		62	%		74	%		1,379		2,230		-38	%		491,951		425,645		16	%		32	%		64	%		465		948		-51	%		266,535			397,839		-33	%
Drillships		100	%		100	%		2,457		1,979		24	%		506,341		475,459		6	%		93	%		100	%		1,354		1,629		-17	%		796,427	⁽³⁾		511,014		56	%
Other	N/A				0	%	N/A			—	**			N/A			—	**
Total		84	%		87	%		6,825		6,900		-1	%	$	355,246	$	342,059		4	%		72	%		85	%		3,781		4,560		-17	%	$	388,253	⁽³⁾	$	340,089		14	%

The following table sets forth the operating results ~~from continuing operations~~ for our contract drilling services segment for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015 (dollars in thousands):

	Nine Months Ended										Six Months Ended
	September 30,				Change						June 30,				Change
	2015		2014		$			%			2016		2015		$			%
Operating revenues:
Contract drilling services	$	2,424,481	$	2,360,205	$	64,276			3	%	$	1,468,064	$	1,550,668	$	(82,604	)		-5	%
Reimbursables (1)		70,087		65,307		4,780			7	%		38,539		47,229		(8,690	)		-18	%
Other		—		1		(1	)	**				153		—		153		**
	$	2,494,568	$	2,425,513	$	69,055			3	%	$	1,506,756	$	1,597,897	$	(91,141	)		-6	%
Operating costs and expenses:
Contract drilling services	$	934,024	$	1,109,456	$	(175,432	)		-16	%	$	495,424	$	640,957	$	(145,533	)		-23	%
Reimbursables (1)		55,592		51,579		4,013			8	%		30,304		37,809		(7,505	)		-20	%
Depreciation and amortization		456,967		446,425		10,542			2	%		289,266		301,787		(12,521	)		-4	%
General and administrative		61,558		76,826		(15,268	)		-20	%		38,573		46,362		(7,789	)		-17	%
Loss on impairment												16,616		—		16,616		**
		1,508,141		1,684,286		(176,145	)		-10	%		870,183		1,026,915		(156,732	)		-15	%
Operating income	$	986,427	$	741,227	$	245,200			33	%	$	636,573	$	570,982	$	65,591			11	%

Operating ~~Revenues~~Revenues.. Changes in contract drilling services revenues for the Current Period as compared to the Comparable Period were driven by a 417 percent decrease in operating days, which reduced revenues by $265 million. The decrease in revenues during the Current Period was partially offset by a 14 percent increase in average dayrates, ~~partially offset by a 1 percent decrease in operating days. The 4 percent increase in average dayrates~~which increased revenues by ~~approximately $90 million, while~~$182 million. As indicated above, excluding the ~~1 percent decrease~~impact of the FCX Settlement, our average dayrates actually decreased in ~~operating days decreased revenues by $26 million.~~the Current Period as compared to the Comparable Period.

The ~~increase~~decrease in contract drilling services revenues ~~relates~~were related to our ~~drillships~~semisubmersibles and jackups, which generated ~~approximately $303~~$253 million and ~~$32~~$75 million ~~more~~less revenue, respectively, than in the ~~Current~~Comparable Period. This reduction in contract drilling services revenues was partially offset by ~~decreased revenues related to~~ our ~~semisubmersibles,~~drillships, which ~~declined $271~~generated $245 million ~~from~~more revenue than in the Comparable Period.

The ~~increase~~$253 million decrease in ~~drillship revenues~~semisubmersible revenue was driven by a 24 percent increase in operating days and a 6 percent increase in average dayrates, resulting in a $227 million and a $76 million increase in revenues, respectively, from the Comparable Period. The increase in both average dayrates and operating days was the result of the newbuilds ~~Noble Sam Croft~~ ~~and the~~ ~~Noble Tom Madden, which commenced their contracts in July 2014 and November 2014, respectively.~~

The increase in jackup revenues was driven by an 11 percent increase in operating days, resulting in a $52 million increase in revenues from the Comparable Period. The increase in operating days was the result of the commencements of the following newbuilds: ~~Noble Regina Allen, Noble Houston Colbert~~ ~~and~~ ~~Noble Sam Turner~~ ~~in January 2014, March 2014 and August 2014, respectively. Additionally, the~~ ~~Noble David Tinsley~~ ~~experienced full utilization in the Current Period but was off contract for a majority of the Comparable Period. This was partially offset by the~~ ~~Noble Mick O’Brien~~, which was off contract during the Current Period but experienced full utilization during the Comparable Period. The 4 percent decline in average dayrates resulted in a $20 million decrease in revenues driven by unfavorable dayrate changes on contracts across the jackup fleet.

~~During the Current Period, we recognized $137 million of dayrate revenues related to the~~ ~~Noble Homer Ferrington~~ ~~arbitration award. Excluding the arbitration award, semisubmersible revenues decreased by $408 million driven by a 38~~51 percent decline in operating days and ~~an 8~~a 33 percent decline in average dayrates, resulting in a ~~$363~~$192 million and ~~a $45~~$61 million decline in revenues, respectively, from the Comparable Period. The decrease in both operating days and average dayrates was primarily attributable to the ~~retirement of~~Current Period contract completions for the Noble Clyde Boudreaux, the Noble Jim ~~Thompson,~~Day, the Noble ~~Driller~~Amos Runner, the Noble Danny Adkins and the Noble ~~Paul Wolff~~Dave Beard ~~as a result of our decision to retire and scrap these rigs based on current market conditions. Additionally, the~~ ~~Noble Max Smith~~ ~~and the~~ ~~Noble Paul Romano~~ ~~were operational during the Comparable Period but were off contract during the Current Period. This~~. The decrease in revenue was partially offset by the Noble ~~Amos Runner~~Paul Romano, which operated during the Current Period but was ~~in the shipyard undergoing regulatory inspections and maintenance~~off contract during ~~a portion of~~ the Comparable Period.

The $75 million decrease in jackup revenues was driven by a 21 percent decrease in average dayrates and a 1 percent decrease in operating days, resulting in a $72 million and a $3 million decrease in revenues, respectively, from the Comparable Period. The decrease in both average dayrates and operating days was primarily driven by the Noble Regina Allen, which was off contract during the Current Period but operated during the Comparable Period, and the retirement and subsequent sale of the Noble Charles Copeland, which operated in the Comparable Period. Additionally, unfavorable dayrate changes on contracts across the jackup fleet contributed to the decrease in average dayrates. This was partially offset by the commencement of the newbuilds, the Noble Tom Prosser and the Noble Sam Hartley, which commenced their contracts in October 2015 and January 2016, respectively.

During the Current Period, we recognized $393 million of dayrate revenues related to the FCX Settlement, of which $14 million related to the termination date valuation of the contingent payments. Excluding these items, drillship revenues decreased by $148 million driven by a 17 percent decrease in operating days and a 1 percent decrease in average dayrates, resulting in a $141 million and a $7 million decrease in revenues, respectively, from the Comparable Period. The decrease in both operating days and average dayrates was the result of the retirement and subsequent sale of the Noble Discoverer, which operated in the Comparable Period, as well as the contract cancellations of the Noble Sam Croft and the Noble Tom Madden in the Current Period. Additionally, unfavorable dayrate changes on contracts across the drillship fleet contributed to the decrease in average dayrates. This was partially offset by a $4 million change in valuation of the contingent payments from the FCX Settlement between the termination date (May 10, 2016) and June 30, 2016.

Operating Costs and Expenses. Contract drilling services operating costs and expenses decreased ~~$175~~$146 million for the Current Period as compared to the Comparable Period. This was due to decreased costs of ~~$92~~$105 million related to idle or stacked rigs and $56 million related to the retirement of the Noble Discoverer, the Noble Jim Thompson, the Noble Driller, the Noble Charles Copeland and the Noble Paul Wolff ~~and $83 million related to idle or stacked rigs.~~. This was partially offset by crew-up and operating expenses for our newbuild rigs as they commenced ~~or prepared to commence,~~ operating under contracts, which added approximately ~~$119~~$19 million in expense in the Current Period. ~~Additionally, we received $10 million for the reimbursement of costs and fees related to the~~ ~~Noble Homer Ferrington~~ ~~arbitration award during the Current Period that were previously recognized through contract drilling services operating costs and expenses.~~ The remaining ~~$109~~$4 million decrease in costs was driven by ~~a $38~~decreases of $8 million decrease in mobilization and transportation expenses related to certain rig moves during the Comparable Period, a $28 million decrease in labor costs, a $17 million decrease in other rig-related expenses, a $12 million decrease in operations support costs, a $9 million decrease in repair and maintenance costs and $7 million in other rig-related expenses. This was partially offset by a $5cost increase of $11 million ~~decrease~~ in ~~insurance costs related to our policy renewal in March 2015.~~the Current Period from the accelerated recognition of deferred mobilization and other expenses resulting from the FCX Settlement.

The ~~increase~~$13 million decrease in depreciation and amortization in the Current Period from the Comparable Period was primarily attributable to ~~assets placed in service, including~~ the ~~newbuilds noted~~retirement of the five rigs discussed above, partially offset by the ~~retirement~~newbuild rigs placed in service.

Loss on impairment of $17 million in the ~~three semisubmersible rigs discussed above.~~Current Period was a result of our decision to dispose of certain capital spare equipment.

General and administrative expenses. Overall, general and administrative expenses decreased ~~$16~~$8 million in the Current Period as compared to the Comparable Period primarily as a result of decreased ~~legal and other professional fees.~~employee related costs.

Interest Expense, net of amount capitalized. Interest expense, net of amount capitalized, increased ~~$47~~$8 million in the Current Period as compared to the Comparable Period. The increase is a result of ~~the issuance~~a full period of ~~$1.1 billion~~interest in respect of the senior notes issued in March 2015, ~~coupled with a reduction~~an increase in applicable interest rates on those senior notes due to the downgrading of our credit rating below investment grade during the Current Period, as well as lower capitalized interest in the Current Period as compared to the Comparable Period due ~~primarily~~ to the completion of construction ~~on four~~ of ~~our~~two newbuild ~~jackups and two of our newbuild drillships.~~jackups. During the Current Period, we capitalized approximately 106 percent of total interest charges versus approximately 2510 percent during the Comparable Period.

~~Interest Income~~ These expense increases were partially offset by the repayment of our maturing $350 million 3.45% Senior Notes and ~~Other, Net.~~ ~~Interest income~~our $300 million 3.05% Senior Notes in August 2015 and ~~other, net increased $37 million~~March 2016, respectively, decreased activity on the credit facility and commercial paper program in the Current Period as compared to the Comparable ~~Period. The increase is primarily~~Period and the Current Period retirement of a portion of our 2020 and 2021 Senior Notes as a result of ~~$30~~a tender offer.

Gain on extinguishment of debt, net. In March 2016, we commenced cash tender offers for our 4.90% Senior Notes due 2020, of which $500 million principal amount was outstanding, and our 4.625% Senior Notes due 2021, of which $400 million principal amount was outstanding. On April 1, 2016, we purchased $36 million of these Senior Notes for $24 million, plus accrued interest, ~~income~~using cash on hand. As a result of this transaction, we recognized ~~in connection with the~~ ~~Noble Homer Ferrington~~ ~~arbitration award, coupled with $5~~a gain of approximately $11 million ~~of interest received on an IRS tax refund for the years 2006 and 2007~~ during the Current Period.

Income Tax Provision. Our income tax provision ~~increased $14~~decreased $33 million in the Current Period, of which ~~$29~~$27 million related to the ~~Noble Homer Ferrington~~ ~~arbitration award.~~FCX Settlement, the impairment of certain capital spare equipment, the retirement of a portion of our 2020 and 2021 Senior Notes as a result of a tender offer and discrete tax items in the Current Period. Excluding the ~~arbitration award, our income tax provision~~impact of these items, taxes decreased by ~~$15 million. A 21 percent decrease~~$60 million as a result of lower pre-tax income and a lower effective tax rate than in the Comparable Period. The decreases in pre-tax earnings and the worldwide effective tax rate generated a ~~$25~~$57 million and a $3 million decrease in income tax ~~expense.~~expense, respectively, in the Current Period. The decrease in the worldwide effective tax rate ~~was~~is primarily a result of the geographic mix of ~~pre-tax~~ income ~~the effect~~and sources of lower downtime coupled with cost reduction measures, as well as various discrete items. This was partially offset by a 9 percent increase in pre-tax earnings during the Current Period, which increased income tax expense by $10 million.

~~Discontinued Operations.~~ Net income from discontinued operations for the Comparable Period was $176 million. Revenues reported within discontinued operations were $1.0 billion during the Comparable Period. Operating income included within discontinued operations was $233 million during the Comparable Period. There was no activity related to discontinued operationsrevenue during the Current Period.

Cash flows from discontinued operations are combined with cash flows from continuing operations within each cash flow statement category on our Consolidated Statements of Cash Flows for the nine months ended September 30, 2014 included in this Quarterly Report on Form 10-Q. Net cash from operating activities was ~~$1.3 billion~~$862 million for the six months ended June 30, 2016 (“Current Period”) and $768 million for the six months ended June 30, 2015 (“Comparable Period”). The increase in net cash from operating activities in the Current Period ~~and $1.4 billion~~was primarily attributable to decreases in accounts receivable mainly from the ~~Comparable Period.~~FCX Settlement. We had working capital of ~~$32~~$535 million and ~~$260~~$377 million at ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014,~~2015, respectively.

Net cash used in investing activities in the Current Period was ~~$321~~$138 million as compared to ~~$1.8 billion~~$209 million in the Comparable Period. The variance primarily relates to lower capital expenditures related to our major projects and newbuild expenditures ~~coupled with expenditures for Paragon Offshore~~and proceeds from the disposal of assets in the ~~Comparable~~Current Period.

Net cash used in financing activities in the Current Period was ~~$835~~$413 million as compared to ~~net cash provided from financing activities of $366~~$380 million in the Comparable Period. During the Current Period, our primary uses of cash included the repayment of our ~~$350~~maturing $300 million ~~3.45%~~3.05% Senior Notes, ~~in August 2015,~~ coupled with shareholder dividend payments of approximately ~~$278 million, the repurchase of 6.2 million shares during the period for $101~~$43 million, and dividends paid to noncontrolling interests of approximately ~~$57~~$41 million. Our total debt as a percentage of total debt plus equity was ~~37.2~~35 percent at ~~September~~June 30, ~~2015 as compared to 40.1~~2016, down from 38 percent at December 31, ~~2014. Although we issued $1.1 billion of Senior Notes in March~~ 2015 ~~this amount was substantially offset by a net reduction in indebtedness outstanding on our Credit Facilities and commercial paper program during the Current Period~~ as a result of the ~~application~~repayment of ~~proceeds from the senior note offering.~~certain maturing notes in 2016.

Our principal source of capital in the Current Period was cash generated from operating ~~activities coupled with the $1.1 billion Senior Notes offering in March 2015.~~activities. Cash generated during the Current Period was primarily used for the following:

Our currently anticipated cash flow needs, both in the short-term and long-term, may include the following:

We currently expect to fund these cash flow needs with cash generated by our operations, cash on hand, borrowings under our existing ~~or future~~ credit ~~facilities and commercial paper program,~~facility, potential issuances of long-term debt, or asset sales. However, to

adequately cover our expected cash flow needs, we may require capital in excess of the amount available from these sources, and we may seek additional sources of liquidity and/or delay or cancel certain discretionary capital expenditures or other payments as necessary.

At ~~September~~June 30, ~~2015,~~2016, we had a total contract drilling services backlog of approximately ~~$8.1~~$5.1 billion. Our backlog as of ~~September~~June 30, ~~2015~~2016 includes a commitment of 7860 percent of available days for the remainder of ~~2015~~2016 and 6746 percent of available days for ~~2016.~~2017. For additional information regarding our backlog, see “Contract Drilling Services Backlog.”

Our total capital expenditure estimate for ~~2015~~2016 is approximately ~~$450 million, which includes capitalized interest that may fluctuate as a result of the timing of completion of ongoing projects.~~$675 million.

In connection with our capital expenditure program, as of ~~September~~June 30, ~~2015,~~2016, we had outstanding commitments, including shipyard and purchase commitments, for approximately ~~$676~~$559 million, including the final payment on the Noble Lloyd Noble, all of which we expect to spend within the next twelve months. On July 15, 2016, we took delivery of the Noble Lloyd Noble and made the final payment of $409 million.

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

On ~~October 23, 2015,~~July 22, 2016, our Board of Directors approved the payment of a quarterly dividend to shareholders of ~~$0.15~~$0.02 per share. The payment is expected to total approximately ~~$37~~$5 million, based on the number of shares currently outstanding.

The declaration and payment of dividends require authorization of the Board of Directors of Noble-UK, ~~and~~provided that such dividends on issued share capital may be paid only out of Noble-UK’s “distributable reserves” on its statutory balance sheet. Noble-UK is not permitted to pay dividends out of share capital, which includes share premiums. The ~~amount, or continuance,~~payment of future dividends will depend on our results of operations, financial condition, cash requirements, future business prospects, contractual restrictions ~~anticipated capital needs~~ and other factors deemed relevant by our Board of ~~Directors and we may decide to change our dividend at any time.~~Directors.

In December 2014, we received shareholder approval to repurchase up to ~~37,000,000~~37 million additional ordinary shares, or approximately 15 percent of our outstanding ordinary shares at the time of the shareholder approval. ~~Any repurchases are expected to be funded using cash on hand, cash from operations or short-term borrowings under our credit facilities.~~ The authority to make such repurchases ~~will expire on the later of April 2016 or~~expired at the end of the Company’s 2016 annual general meeting of shareholders, at which ~~time we could seek shareholder approval for further repurchases.~~

In January 2015, we repurchased 6.2 million of our ordinary shares at an average price of $16.10 per share, excluding commissions and stamp tax. Including these items, the average price paid per share during January 2015 was ~~$16.21. There can be no~~

assurance as to the timing or amount of any such further repurchases. However, we intend to take a cautious approach to future share repurchases at least until market conditions in the offshore drilling business stabilize.held on April 22, 2016.

We currently have ~~two credit facilities with an aggregate maximum capacity of $2.7 billion, which are comprised of~~ a ~~five year~~five-year $2.4 billion senior unsecured credit facility that matures in January ~~2020 and a $225 million 364-day senior unsecured~~2020. The credit ~~facility that matures in January 2016 (together, the “Credit Facilities”).~~

We have a commercial paper program, which allows us to issue up to $2.4 billion in unsecured commercial paper notes. Amounts issued under the commercial paper program are supported by the unused capacity under our Credit Facilities and, therefore, are classified as long-term on our Consolidated Balance Sheet. The outstanding amounts of commercial paper reduce availability under our Credit Facilities.

Our total debt related to the Credit Facilities and commercial paper program was $1.1 billion at December 31, 2014. At September 30, 2015, we had no amounts outstanding under the Credit Facilities and commercial paper program, therefore, we had $2.7 billion of available capacity under the Credit Facilities.

~~The $2.4 billion~~ facility provides us with the ability to issue up to $500 million in letters of credit. The issuance of letters of credit under the facility reduces the amount available for borrowing. At ~~September~~June 30, ~~2015,~~2016, we had no letters of credit issued under the facility.

We also have a commercial paper program that allows us to issue up to $2.4 billion in unsecured commercial paper notes. Amounts issued under the commercial paper program are supported by the unused capacity under our credit facility and, therefore, are classified as long-term on our Consolidated Balance Sheet. The outstanding amounts of commercial paper reduce availability under our credit facility. Access to our commercial paper program is dependent upon our credit ratings. As our credit ratings are below investment grade, we are currently prohibited from accessing the commercial paper market.

Our credit facility and certain of our senior notes, as discussed below, have provisions which vary the applicable interest rates based upon our credit ratings.

Our total debt related to senior unsecured notes was ~~$4.5~~$4.2 billion at ~~September~~June 30, ~~2015~~2016 as compared to ~~$3.7~~$4.5 billion at December 31, ~~2014.~~2015. The ~~increase~~decrease in senior unsecured notes outstanding is a result of the ~~issuance~~March 2016 repayment of ~~$1.1 billion aggregate principal amount of senior notes in March 2015, which we issued through~~ our ~~indirect wholly-owned subsidiary, Noble Holding International Limited (“NHIL”). These senior notes were issued in three separate tranches, consisting of $250~~maturing $300 million of 4.00% Senior Notes due 2018, $450 million of 5.95% Senior Notes due 2025, and $400 million of 6.95% Senior Notes due 2045. The weighted average coupon of all three tranches is 5.87%. The interest rate on these senior notes may be increased if the credit rating applicable to the notes is downgraded below certain specified levels. The net proceeds of approximately $1.08 billion, after expenses, were used to repay indebtedness outstanding under our Credit Facilities and commercial paper program.

~~In August 2015, we repaid our $350 million 3.45%~~3.05% Senior Notes using cash on hand.

In February 2016, as a result of a reduction in our debt rating below investment grade by Moody’s Investors Service, the interest rates on the Senior Notes due 2018, Senior Notes due 2025 and Senior Notes due 2045 were increased 1.00% each to 5.00%, 6.95% and 7.95%, respectively, effective the first day of each interest period after which the downgrade occurred. As a result of an additional downgrade by S&P Global Ratings in July 2016, the interest rates on these Senior Notes were further increased by 0.25% each to 5.25%, 7.20% and 8.20%, respectively, effective the first day of each interest period after which the downgrade occurred. The interest rates on these Senior Notes may be further increased if our debt rating were to be downgraded further (up to a maximum of an additional 75 basis points). Our other outstanding senior notes do not contain provisions varying applicable interest rates based upon our credit rating.

The ~~Credit Facilities are~~credit facility is guaranteed by ~~NHIL~~Noble Holding International Limited and Noble Holding ~~Corporation (“NHC”).~~Corporation. The ~~covenants and events of default under the two Credit Facilities are substantially similar, and each~~credit facility contains a covenant that limits our ratio of debt to total tangible capitalization, as defined in the ~~Credit Facilities,~~credit facility, to 0.60. At ~~September~~June 30, ~~2015,~~2016, our ratio of debt to total tangible capitalization was approximately ~~0.37.~~0.35. We were in compliance with all covenants under the ~~Credit Facilities~~credit facility as of ~~September~~June 30, ~~2015.~~2016.

In addition to the covenants from the ~~Credit Facilities~~credit facility noted above, 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 entering into sale and lease-back transactions. At ~~September~~June 30, ~~2015,~~2016, we were in compliance with all of our debt covenants. We continually monitor compliance with the covenants under our notes and expect to remain in compliance during the remainder of ~~2015.~~2016.

In ~~April~~May 2014, the ~~FASB issued~~Financial Accounting Standards ~~Update~~Board (“~~ASU”~~FASB”) issued ASU No. ~~2014-08,~~2014-09, which ~~amends FASB~~creates Accounting Standards Codification (“ASC”) Topic 205, “Presentation of Financial Statements” and ASC Topic 360, “Property, Plant, and Equipment.” This ASU alters the definition of a discontinued operation to cover only asset disposals that are a strategic shift with a major effect on an entity’s operations and finances, and calls for more extensive disclosures about a discontinued operation’s assets, liabilities, income and expenses. The guidance is effective for all disposals, or classifications as held-for-sale, of components of an entity that occur within annual periods beginning on or after December 15, 2014. This standard was not early adopted in connection with the Spin-off. The adoption of this guidance did not have a material impact on our financial condition, results of operations, cash flows or financial disclosures.

~~In May 2014, the FASB issued ASU No. 2014-09, which amends ASC Topic~~ 606, “Revenue from Contracts with ~~Customers.~~Customers,” ~~The amendments in this ASU are intended to provide a more robust framework for addressing revenue issues, improve comparability of~~and supersedes the revenue recognition ~~practices and improve disclosure requirements.~~requirements in Topic 605, “Revenue Recognition,” including most industry-specific revenue recognition guidance throughout the Industry Topics of the Codification. In ~~August 2015, the FASB issued~~addition, ASU No. ~~2015-14, which defers~~2014-09 supersedes the ~~effective date~~cost guidance in Subtopic 605-35, “Revenue Recognition—Construction-Type and Production-Type Contracts,” and creates new Subtopic 340-40, “Other Assets and Deferred Costs—Contracts with Customers.” In summary, the core principle of Topic 606 is to recognize revenue when promised goods or services are transferred to customers in an amount that reflects the consideration that is expected to be received for those goods or services. Companies are allowed to select between two transition methods: (1) a full retrospective transition method with the

application of the new guidance ~~by one year~~ to ~~interim and~~each prior reporting period presented, or (2) a retrospective transition method that recognizes the cumulative effect on prior periods at the date of adoption together with additional footnote disclosures. The amendments in ASU No. 2014-09 are effective for annual reporting periods beginning after December 15, ~~2017.~~2017, including interim periods within that reporting period, and early application is not permitted. A number of amendments have been issued in connection with ASU No. 2014-09, all of which are effective upon adoption of Topic 606. In March 2016 and April 2016, the FASB issued clarification amendments ASU No. 2016-08 and ASU No. 2016-10 which clarify the implementation guidance on principle versus agent considerations and identify performance obligations and the licensing implementation guidance, respectively. In May 2016, the FASB issued ASU No. 2016-11 and ASU No. 2016-12 which rescind certain SEC Staff Observer comments that are codified in Topic 605, “Revenue Recognition,” and Topic 932, “Extractive Activities—Oil and Gas” and provide improvements to narrow aspects of ASU No. 2014-09, respectively. We are currently evaluating ~~what~~the impact ~~if any,~~ the adoption of this guidance will have on our consolidated financial ~~condition, results~~statements and have not made any decision on the method of ~~operations, cash flows or financial disclosures.~~adoption.

In February 2015, the FASB issued ASU No. 2015-02, which amends ASC Subtopic 810, “Consolidations.” This amendment affects reporting entities that are required to evaluate whether they should consolidate certain legal entities. Specifically, the amendments modify the evaluation of whether limited partnerships and similar legal entities are VIEs or voting interest entities; eliminate the presumption that a general partner should consolidate a limited partnership; affect the consolidation analysis of reporting entities that are involved with VIEs, particularly those that have fee arrangements and related party relationships. The standard is effective for interim and annual reporting periods beginning after December 15, 2015. The standard may be applied retrospectively or through a cumulative effect adjustment to retained earnings as of the beginning of the year of adoption. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

In April 2015, the FASB issued ASU No. 2015-03, which amends ASC Subtopic 835-30, “Interest – Imputation of Interest.” The guidance requires debt issuance costs to be presented in the balance sheet as a direct reduction from the associated debt liability. The standard is effective for interim and annual reporting periods beginning after December 15, 2015. ~~Early adoption is permitted for financial statements that have not been previously issued. The new guidance will be applied on a retrospective basis.~~ In August 2015, the FASB issued ASU No. 2015-15 which amends ASC Subtopic 835-30, “Interest – Imputation of Interest.” The guidance allows a debt issuance cost related to a line-of-credit to be presented in the balance sheet as an asset and subsequently amortized ratably over the term of the line-of credit arrangement, regardless of whether there are any outstanding borrowings on the line-of-credit arrangement. ~~We are evaluating what impact the~~The new guidance is applied on a retrospective basis. In accordance with our adoption of ~~this guidance will have on~~ASU No. 2015-03, unamortized debt issuance costs related to our ~~financial condition, results~~senior notes of ~~operations, cash flows~~approximately $26 million as of December 31, 2015, which were previously included in “Other assets,” are included in either “Current maturities of long-term debt” or ~~financial disclosures.~~“Long-term debt” in the accompanying Consolidated Balance Sheets, based upon the maturity date of the respective senior notes.

In July 2015, the FASB issued ASU No. 2015-12, which amends ASC Topic 960, “Plan Accounting-Defined Benefit Pension ~~Plans”,~~Plans,” ASC Topic 962, “Defined Contribution Pension Plans”, and ASC Topic 965, “Health and Welfare Benefit ~~Plans”.~~Plans.” There are three parts to the ASU that aim to simplify the accounting and presentation of plan accounting. Part I of this ASU requires fully benefit-responsive investment contracts to be measured at contract value instead of the current fair value measurement. Part II of this ASU requires investments (both participant-directed and nonparticipant-directed investments) of employee benefit plans be grouped only by general type, eliminating the need to disaggregate the investments in multiple ways. Part III of this ASU provides a similar measurement date practical expedient for employee benefit plans as available in ASU No. 2015-04, which allows employers to measure defined benefit plan assets on a month-end date that is nearest to the year’s fiscal year-end when the fiscal period does not coincide with a month-end. Parts I and II of the new guidance should be applied on a retrospective basis. Part III of the new guidance should be applied on a prospective basis. This guidance is effective for interim and annual reporting periods beginning after December 15, 2015. ~~We are evaluating what impact, if any, the~~The adoption of this guidance ~~will~~did not have an impact on our financial condition, results of operations, cash flows or financial disclosures.

In February 2016, the FASB issued ASU No. 2016-02, which creates ASC Topic 842, “Leases.” This update increases transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. This guidance is effective for interim and annual reporting periods beginning after December 15, 2018. We are evaluating what impact, if any, the adoption of this guidance will have on our financial condition, results of operations, cash flows or financial disclosures.

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

Market risk is the potential for loss due to 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~~credit facility and commercial paper program. Interest on borrowings under the ~~Credit Facilities~~credit facility is at an agreed upon percentage point spread over LIBOR, or a base rate stated in the ~~agreements.~~agreement. At ~~September~~June 30, ~~2015,~~2016, we had no borrowings outstanding under our ~~Credit Facilities~~credit facility and commercial paper program, which is supported by the ~~Credit Facilities.~~credit facility.

Access to our commercial paper program is dependent upon our credit ratings. ~~A decline in~~As a result of our credit ratings being below investment grade, ~~would prohibit us~~we are currently prohibited from accessing the commercial paper market. ~~If we were unable to access~~

In February 2016, as a result of a reduction in our debt rating below investment grade by Moody’s Investors Service, the ~~commercial paper market, we would likely transfer any outstanding borrowings to our Credit Facilities. Our Credit Facilities have~~ interest rates ~~that are generally higher than those found~~on the Senior Notes due 2018, Senior Notes due 2025 and Senior Notes due 2045 were increased 1.00% each to 5.00%, 6.95% and 7.95%, respectively, effective the first day of each interest period after which the downgrade occurred. As a result of an additional downgrade by S&P Global Ratings in July 2016, the ~~commercial paper market,~~interest rates on these Senior Notes were further increased by 0.25% each to 5.25%, 7.20% and 8.20%, respectively, effective the first day of each interest period after which ~~would result in~~the downgrade occurred. The interest rates on these Senior Notes may be further increased ~~interest expense in the future.~~

~~In addition,~~if our ~~Credit Facilities and certain~~debt rating were to be downgraded further (up to a maximum of ~~our~~an additional 75 basis points). Our other outstanding senior ~~unsecured~~ notes ~~have~~do not contain provisions ~~which vary the~~varying applicable interest rates based upon our credit ~~ratings. If our credit ratings were to decline to certain specified levels, the interest expense under our Credit Facilities and certain of our senior unsecured notes would increase.~~rating.

We maintain certain debt instruments at a fixed rate whose fair value will fluctuate based on changes in interest rates and market perceptions of our credit risk. The fair value of our total debt was ~~$3.5~~$3.1 billion and ~~$4.5~~$3.3 billion at ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014,~~2015, respectively. The decrease in the fair value of debt primarily relates to ~~the overall decline of our sector in the marketplace coupled with~~ the repayment of our ~~$350~~maturing $300 million ~~3.45%~~3.05% Senior Notes, which matured in ~~August 2015.~~March 2016.

Although we are a ~~U.K.~~UK company, we define foreign currency as any non-U.S. denominated currency. 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 other 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~~Several of our regions, including our operations in the North Sea ~~Australian~~ and ~~Brazilian operations~~Australia, have a significant amount of their cash operating expenses payable in local currencies. To limit the potential risk of currency fluctuations, we periodically enter into forward contracts, which settle monthly in the operations’ respective local currencies. All of these contracts have a maturity of less than 12 months. The forward contract settlements in the remainder of ~~2015~~2016 represent approximately 60 percent of these forecasted local currency requirements. The notional amount of the forward contracts outstanding, expressed in U.S. dollars, was approximately ~~$23~~$25 million at ~~September~~June 30, ~~2015.~~2016. Total unrealized losses related to these forward contracts were approximately $1 million as of ~~September~~June 30, ~~2015~~2016 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 $2$3 million.

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~~

(collectively referred to as our “qualified U.S. plans”). These plans are governed by the Noble Drilling Employees’ 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,~~contributions, or utilize credits available to us, for the qualified U.S. plans when required. The benefit amount that can be covered by the qualified U.S. plans is limited under ERISA and the Internal Revenue Code (“IRC”) of 1986. Therefore, we maintain an unfunded, nonqualified excess benefit plan designed to maintain benefits for specified employees at the formula level in the qualified salary U.S. plan. We refer to the qualified U.S. plans and the excess benefit plan collectively as the “U.S. ~~plans”.~~plans.”

In addition to the U.S. plans, each of Noble Drilling (Land Support) Limited and Noble Resources Limited, both indirect, wholly-owned subsidiaries of Noble-UK, maintains a pension plan that covers all of its salaried, non-union employees, whose most recent date of employment is prior to April 1, 2014 (collectively referred to as our “non-U.S. plans”). Benefits are based on credited service and employees’ compensation, 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-UK, and ~~James A. MacLennan, Senior~~Dennis J. Lubojacky, Chief Financial Officer, Vice President, Controller and ~~Chief Financial Officer~~Treasurer of Noble-UK, have evaluated the disclosure controls and procedures of Noble-UK as of the end of the period covered by this report. On the basis of this evaluation, Mr. Williams and Mr. ~~MacLennan~~Lubojacky have concluded that Noble-UK’s disclosure controls and procedures were effective as of ~~September~~June 30, ~~2015.~~2016. Noble-UK’s disclosure controls and procedures are designed to ensure that information required to be disclosed by Noble-UK 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 ~~September~~June 30, ~~2015.~~2016. 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-UK’s or Noble-Cayman’s internal control over financial reporting that occurred during the quarter ended ~~September~~June 30, ~~2015~~2016 that has materially affected, or is reasonably likely to materially affect, the internal control over financial reporting of each of Noble-UK or Noble-Cayman, respectively.

Information regarding legal proceedings is set forth in Notes 6 and 14 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.

Under UK law, the Company is only permitted to purchase its own shares by way of an “off-market purchase” in a plan approved by shareholders. ~~In December 2014, we received shareholder approval to repurchase up to 37,000,000 ordinary shares, or approximately 15 percent of our outstanding ordinary shares at the time~~As of the ~~shareholder approval. Any repurchases are expected to be funded using cash on hand, cash from operations or short-term borrowings under our Credit Facilities. The authority to make~~date of this report, no such repurchases will expire on the later of April 2016 or the end of the Company’s 2016 annual general meeting of shareholders, at which time we could seek shareholder approval for further repurchases. The Company may only fund the purchase of its own shares out of distributable reserves or the proceeds of a new issue of shares made expressly for that purpose. The Company currentlyplan has ~~adequate distributable reserves to fund its currently~~been approved repurchase plan. If any premium above the nominal value of the purchased shares is paid, it must be paid out of distributable reserves. Any shares purchased by the Company out of distributable reserves may be held as treasury shares or cancelled at the Company’s election. Duringand during the three months ended ~~September~~June 30, ~~2015,~~2016, there were no repurchases by Noble-UK of its shares.

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.

Noble Corporation plc, a public limited company incorporated under the laws of England and Wales

Noble Corporation plc:	Large accelerated filer R	Accelerated filer £	Non-accelerated filer £	Smaller reporting company £

Noble Corporation:	Large accelerated filer £	Accelerated filer £	Non-accelerated filer R	Smaller reporting company £

		Page
PART I	FINANCIAL INFORMATION
Item 1	Financial Statements
	Noble Corporation plc (Noble-UK) Financial Statements:
	Consolidated Balance Sheets as of ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014~~2015	3
	Consolidated Statements of Income for the three and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	4
	Consolidated Statements of Comprehensive Income for the three and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	5
	Consolidated Statements of Cash Flows for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	6
	Consolidated Statements of Equity for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	7

	Noble Corporation (Noble-Cayman) Financial Statements:
	Consolidated Balance Sheets as of ~~September~~June 30, ~~2015~~2016 and December 31, ~~2014~~2015	8
	Consolidated Statements of Income for the three and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	9
	Consolidated Statements of Comprehensive Income for the three and ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	10
	Consolidated Statements of Cash Flows for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	11
	Consolidated Statements of Equity for the ~~nine~~six months ended ~~September~~June 30, ~~2015~~2016 and ~~2014~~2015	12

	Notes to Combined Consolidated Financial Statements	13

Item 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	3738
Item 3	Quantitative and Qualitative Disclosures About Market Risk	4951
Item 4	Controls and Procedures	5052
PART II	OTHER INFORMATION
Item 1	Legal Proceedings	5153
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds	5153
Item 6	Exhibits	5153
	SIGNATURES	5254
	Index to Exhibits	5355

	Three months ended			Nine months ended
	September 30,			September 30,
	2014			2014
Operating revenues
Contract drilling services	$	136,548		$	993,253
Reimbursables		2,398			21,899
Labor contract drilling services		2,946			19,304
Other		1			2
Operating revenues from discontinued operations	$	141,893		$	1,034,458
(Loss) income from discontinued operations
(Loss) income from discontinued operations before income taxes	$	(3,292	)	$	229,482
Income tax provision		(16,922	)		(53,950	)
Net (loss) income from discontinued operations	$	(20,214	)	$	175,532

	June 30,			December 31,
	2016			2015
Current
Current maturities of long-term debt	$	299,974		$	299,997
Less: Unamortized debt issuance costs		(332	)		(73	)
Current maturities of long-term debt, net of debt issuance costs	$	299,642		$	299,924

Long-term
3.05% Senior Notes due March 2016	$	—		$	299,997
2.50% Senior Notes due March 2017		299,974			299,956
5.00% Senior Notes due March 2018		249,688			249,602
7.50% Senior Notes due March 2019		201,695			201,695
4.90% Senior Notes due August 2020		467,162			499,287
4.625% Senior Notes due March 2021		396,323			399,680
3.95% Senior Notes due March 2022		399,401			399,354
6.95% Senior Notes due April 2025		448,862			448,814
6.20% Senior Notes due August 2040		399,897			399,896
6.05% Senior Notes due March 2041		397,738			397,719
5.25% Senior Notes due March 2042		498,353			498,338
7.95% Senior Notes due April 2045		394,589			394,563
Total senior unsecured notes		4,153,682			4,488,901
Credit facility & commercial paper program		—			—
Total debt		4,153,682			4,488,901
Less: Unamortized debt issuance costs		(24,292	)		(26,266	)
Less: Current maturities of long-term debt		(299,974	)		(299,997	)
Long-term debt, net of debt issuance costs	$	3,829,416		$	4,162,638

	September 30,			December 31,
	2015			2014
Senior unsecured notes:
3.45% Senior Notes due August 2015	$	—		$	350,000
3.05% Senior Notes due March 2016		299,993			299,982
2.50% Senior Notes due March 2017		299,947			299,920
4.00% Senior Notes due March 2018		249,559			—
7.50% Senior Notes due March 2019		201,695			201,695
4.90% Senior Notes due August 2020		499,252			499,151
4.625% Senior Notes due March 2021		399,667			399,627
3.95% Senior Notes due March 2022		399,332			399,264
5.95% Senior Notes due April 2025		448,790			—
6.20% Senior Notes due August 2040		399,896			399,895
6.05% Senior Notes due March 2041		397,709			397,681
5.25% Senior Notes due March 2042		498,331			498,310
6.95% Senior Notes due April 2045		394,549			—
Total senior unsecured notes		4,488,720			3,745,525
Credit facilities & commercial paper program		—			1,123,495
Total debt		4,488,720			4,869,020
Less: Current maturities of long-term debt		(299,993	)		—
Long-term debt	$	4,188,727		$	4,869,020

										Accumulated
					Capital in					Other
	Shares				Excess of		Retained			Comprehensive			Noncontrolling			Total
	Balance		Par Value		Par Value		Earnings			Loss			Interests			Equity
Balance at December 31, 2014		261,246	$	26,125	$	530,657	$	6,009,114		$	(69,418	)	$	722,304		$	7,218,782
Distributions to parent company, net		—		—		—		(273,626	)		—			—			(273,626	)
Capital contribution by parent - share- based compensation		—		—		14,695		—			—			—			14,695
Net income		—		—		—		359,342			—			38,864			398,206
Dividends paid to noncontrolling interests		—		—		—		—			—			(44,484	)		(44,484	)
Other comprehensive income, net		—		—		—		—			245			—			245
Balance at June 30, 2015		261,246	$	26,125	$	545,352	$	6,094,830		$	(69,173	)	$	716,684		$	7,313,818
Balance at December 31, 2015		261,246	$	26,125	$	561,309	$	6,167,211		$	(63,175	)	$	723,001		$	7,414,471
Distributions to parent company, net		—		—		—		(65,316	)		—			—			(65,316	)
Capital contribution by parent - share- based compensation		—		—		17,653		—			—			—			17,653
Net income		—		—		—		447,869			—			41,181			489,050
Dividends paid to noncontrolling interests		—		—		—		—			—			(41,088	)		(41,088	)
Other comprehensive income, net		—		—		—		—			1,305			—			1,305
Balance at June 30, 2016		261,246	$	26,125	$	578,962	$	6,549,764		$	(61,870	)	$	723,094		$	7,816,075


Valuation assumptions:
Expected volatility		43.11	%
Mean-reversion rate		0.03
Discount rate ⁽¹⁾		4.0	%
Underlying spot price ⁽²⁾	$	48.33

	Issuer
Notes	(Co-Issuer(s))	Guarantor
$300 million ~~3.05% Senior Notes due 2016~~	~~NHIL~~	~~Noble-Cayman~~
~~$300 million~~ 2.50% Senior Notes due 2017	NHIL	Noble-Cayman
$250 million ~~4.00%~~5.00% Senior Notes due 2018	NHIL	Noble-Cayman
$202 million 7.50% Senior Notes due 2019	NHC	Noble-Cayman
	Noble Drilling Holding, LLC ("NDH")
	Noble Drilling Services 6 LLC ("NDS6")
$~~500~~468 million 4.90% Senior Notes due 2020	NHIL	Noble-Cayman
$~~400~~397 million 4.625% Senior Notes due 2021	NHIL	Noble-Cayman
$400 million 3.95% Senior Notes due 2022	NHIL	Noble-Cayman
$450 million ~~5.95%~~6.95% Senior Notes due 2025	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
$400 million ~~6.95%~~7.95% Senior Notes due 2045	NHIL	Noble-Cayman

				Year Ending December 31,
		Total		2016 ⁽¹⁾			2017			2018			2019			2020-2023
		(In millions)
Contract Drilling Services Backlog	~~We maintain a backlog (as defined below)~~
Semisubmersibles/Drillships ⁽⁴⁾⁽⁶⁾		$	3,811	$	552		$	723		$	658		$	508		$	1,370
Jackups ⁽³⁾			1,310		281			469			285			159			116
Total ⁽²⁾		$	5,121	$	833		$	1,192		$	943		$	667		$	1,486
Percent of ~~commitments for contract drilling services. The following table sets forth, as of September~~ Available Days Committed ⁽⁵⁾
Semisubmersibles/Drillships					40	%		27	%		25	%		20	%		13	%
Jackups					85	%		68	%		36	%		7	%		1	%
Total					60	%		46	%		30 ~~2015, the amount of our contract drilling services backlog and the percent of available operating days committed for the periods indicated:~~	%		14	%		8	%

			Year Ending December 31,
	Total		2015 ⁽¹⁾			2016			2017			2018			2019-2023
	(In millions)
Contract Drilling Services Backlog
Semisubmersibles/Drillships ^{(2) (5)}	$	6,205	$	584		$	1,813		$	1,107		$	702		$	1,999
Jackups		1,878		147			712			465			293			261
Total ⁽³⁾	$	8,083	$	731		$	2,525		$	1,572		$	995		$	2,260
Percent of Available Days Committed ⁽⁴⁾
Semisubmersibles/Drillships				80	%		58	%		35	%		24	%		14	%
Jackups				74	%		76	%		48	%		25	%		2	%
Total				78	%		67	%		41	%		24	%		8	%

/s/ David W. Williams		~~November 4, 2015~~August 8, 2016
David W. Williams Chairman, President and Chief Executive Officer (Principal Executive Officer)		Date

/s/ ~~James A. MacLennan~~Dennis J. Lubojacky
~~James A. MacLennan~~Dennis J. Lubojacky ~~Senior~~Chief Financial Officer, Vice President, Controller and ~~Chief Financial Officer~~Treasurer (Principal Financial Officer)

Noble Corporation, a Cayman Islands company

/s/ David W. Williams		~~November 4, 2015~~August 8, 2016
David W. Williams President and Chief Executive Officer (Principal Executive Officer)		Date

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

Exhibit
Number		Exhibit

2.1		Merger Agreement, dated as of June 30, 2013, between Noble Corporation, a Swiss corporation (“Noble-Swiss”) and Noble Corporation Limited (“Noble-UK”) (filed as Exhibit 2.1 to Noble-Swiss’ Current Report on Form 8-K filed on July 1, 2013 and incorporated herein by reference).

2.2		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).

2.3		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).

2.4		Master Separation Agreement, dated as of July 31, 2014, between Noble-Cayman and Paragon Offshore plc. (filed as Exhibit 2.1 to Noble-UK’s Current Report on Form 8-K filed on August 5, 2014 and incorporated herein by reference).

3.1		Composite Copy of Articles of Association of Noble-UK, as of June 10, 2014 (filed as Exhibit 3.1 to Noble-UK’s Quarterly Report on Form 10-Q for the quarter ended ~~September~~March 30, 2014 and incorporated herein by reference).

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

4.1		Revolving Credit Agreement dated as of January 26, 2015, among Noble-Cayman and Noble International Finance Company, a Cayman Islands company, as borrowers; JPMorgan Chase Bank, N.A., as administrative agent and a swingline lender; Wells Fargo Bank, National Association, as a swingline lender; the lenders party thereto; Barclays Bank PLC, Citibank, N.A., DNB Bank ASA New York Branch, HSBC Bank USA, N.A., SunTrust Bank and Wells Fargo, as co-syndication agents; BNP Paribas, Credit Suisse AG, Cayman Islands Branch and Mizuho Bank, Ltd, as co-documentation agents; and J.P. Morgan Securities LLC, Barclays Bank PLC, Citigroup Global Markets Inc., DNB Markets, Inc., HSBC Securities (USA) Inc., SunTrust Robinson Humphrey, Inc. and Wells Fargo Securities, LLC, as joint lead arrangers and joint lead bookrunners (filed as Exhibit 4.1 to Noble-UK’s Current Report on Form 8-K filed on January 29, 2015 and incorporated herein by reference).

4.2		364-Day Revolving Credit Agreement dated as of January 29, 2015, among Noble-Cayman and Noble International Finance Company, a Cayman Islands company, as borrowers; JPMorgan, as administrative agent; the lenders party thereto; Barclays Bank PLC, Citibank, N.A. and HSBC Bank USA, N.A., as co-syndication agents; BNP Paribas, as documentation agent; and J.P. Morgan Securities LLC, Barclays Bank PLC, Citigroup Global Markets Inc., and HSBC Securities (USA) Inc., as joint lead arrangers and joint lead bookrunners (filed as Exhibit 4.2 to Noble-UK’s Current Report on Form 8-K filed on January 29, 2015 and incorporated herein by reference).

~~4.3~~		Indenture, dated as of March 16, 2015, among Noble Holding International Limited, as Issuer, and Wells Fargo N.A., as Trustee, relating to 4.000% senior notes due 2018, 5.950% senior notes due 2025 and 6.95% senior notes due 2045 of Noble Holding International Limited (filed as Exhibit 4.1 to Noble-UK’s Current Report on Form 8-K filed on March 16, 2015 and incorporated herein by reference).

~~4.4~~ 4.3		First Supplemental Indenture, dated as of March 16, 2015, among Noble Holding International Limited, as Issuer, Noble Corporation, as Guarantor, and Wells Fargo N.A., as Trustee, relating to 4.000% senior notes due 2018, 5.950% senior notes due 2025 and 6.95% senior notes due 2045 of Noble Holding International Limited (filed as Exhibit 4.2 to Noble-UK’s Current Report on Form 8-K filed on March 16, 2015 and incorporated herein by reference).

10.1		Tax Sharing Agreement, dated as of July 31, 2014, between Noble-UK and Paragon Offshore plc. (filed as Exhibit 10.1 to Noble-UK’s Current Report on Form 8-K filed on August 5, 2014 and incorporated herein by reference).

10.2		Employee Matters Agreement, dated as of July 31, 2014, between Noble-Cayman and Paragon Offshore plc. (filed as Exhibit 10.2 to Noble-UK’s Current Report on Form 8-K filed on August 5, 2014 and incorporated herein by reference).

10.3		Transition Services Agreement, dated as of July 31, 2014, between Noble-Cayman and Paragon Offshore plc. (filed as Exhibit 10.3 to Noble-UK’s Current Report on Form 8-K filed on August 5, 2014 and incorporated herein by reference).

10.4		Transition Services Agreement (Brazil), dated as of July 31, 2014, among Paragon Offshore do Brasil Limitada, Paragon Offshore (Nederland) B.V., Paragon Offshore plc, Noble-Cayman, Noble Dave Beard Limited and Noble Drilling (Nederland) II B.V. (filed as Exhibit 10.4 to Noble-UK’s Current Report on Form 8-K filed on August 5, 2014 and incorporated herein by reference).

10.5*		Noble Corporation plc 2015 ~~Short Term~~Omnibus Incentive Plan, restated as of May 1, 2016 (filed as Exhibit ~~10.5~~10.1 to Noble-UK’s Current Report on Form 8-K filed on April 26, 2016 and incorporated herein by reference).