UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

THE SECURITIES EXCHANGE ACT OF 1934

For the Quarterly Period Ended June 30, 2012

Commission File Number: 001-32657

NABORS INDUSTRIES LTD.

Bermuda	98-0363970
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

Crown House

Second Floor

4 Par-la-Ville Road

Hamilton, HM08

Bermuda

(441) 292-1510

(Address of principal executive offices)

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

Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (Section 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    YES  x    NO  ¨

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

Large Accelerated Filer	x	Accelerated Filer	¨
Non-accelerated Filer	¨	Smaller Reporting Company	¨

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

The number of common shares, par value $.001 per share, outstanding as of July 31, 2012 was 290,386,130.

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

Index

	PART I FINANCIAL INFORMATION
Item 1.	Financial Statements
	Consolidated Balance Sheets as of June 30, 2012 and December 31, 2011	3
	Consolidated Statements of Income (Loss) for the Three and Six Months Ended June 30, 2012 and 2011	4
	Consolidated Statements of Other Comprehensive Income (Loss) for the Three and Six Months Ended June 30, 2012 and 2011	5
	Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2012 and 2011	6
	Consolidated Statements of Changes in Equity for the Six Months Ended June 30, 2012 and 2011	7
	Notes to Consolidated Financial Statements	9
	Report of Independent Registered Public Accounting Firm	40
Item 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	41
Item 3.	Quantitative and Qualitative Disclosures About Market Risk	56
Item 4.	Controls and Procedures	56
	PART II OTHER INFORMATION
Item 1.	Legal Proceedings	57
Item 1A.	Risk Factors	57
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	58
Item 3.	Defaults Upon Senior Securities	58
Item 4.	Mine Safety Disclosures	58
Item 5.	Other Information	58
Item 6.	Exhibits	59
Signatures		60

2

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

	June  30, 2012			December 31, 2011
(In thousands, except per share amounts)	(Unaudited)
ASSETS
Current assets:
Cash and cash equivalents	$	320,398		$	398,575
Short-term investments		134,784			140,914
Assets held for sale		396,413			401,500
Accounts receivable, net		1,607,422			1,576,555
Inventory		259,943			272,852
Deferred income taxes		70,288			127,874
Other current assets		185,922			170,044
Total current assets		2,975,170			3,088,314
Long-term investments and other receivables		5,452			11,124
Property, plant and equipment, net		8,904,324			8,629,946
Goodwill		471,913			501,258
Investment in unconsolidated affiliates		165,003			371,021
Other long-term assets		321,610			310,477
Total assets	$	12,843,472		$	12,912,140
LIABILITIES AND EQUITY
Current liabilities:
Current portion of long-term debt	$	275,323		$	275,326
Trade accounts payable		606,571			782,753
Accrued liabilities		604,627			744,483
Total current liabilities		1,486,521			1,802,562
Long-term debt		4,398,452			4,348,490
Other long-term liabilities		326,202			292,758
Deferred income taxes		834,207			797,925
Total liabilities		7,045,382			7,241,735
Commitments and contingencies (Note 12)
Subsidiary preferred stock		69,188			69,188
Equity:
Shareholders’ equity:
Common shares, par value $.001 per share:
Authorized common shares 800,000; issued 318,719 and 317,042, respectively		319			317
Capital in excess of par value		2,326,590			2,287,743
Accumulated other comprehensive income		318,088			321,264
Retained earnings		4,017,665			3,956,364
Less: treasury shares, at cost, 28,414 and 29,414 common shares, respectively		(944,627	)		(977,873	)
Total shareholders’ equity		5,718,035			5,587,815
Noncontrolling interest		10,867			13,402
Total equity		5,728,902			5,601,217
Total liabilities and equity	$	12,843,472		$	12,912,140

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

3

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (LOSS)

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
(In thousands, except per share amounts)	2012			2011			2012			2011
Revenues and other income:
Operating revenues	$	1,737,114		$	1,343,642		$	3,627,540		$	2,717,210
Earnings (losses) from unconsolidated affiliates		(134,317	)		9,308			(202,986	)		25,582
Investment income (loss)		5,368			(975	)		25,620			11,305
Total revenues and other income		1,608,165			1,351,975			3,450,174			2,754,097
Costs and other deductions:
Direct costs		1,123,256			827,450			2,308,072			1,668,558
General and administrative expenses		133,612			122,970			269,958			238,921
Depreciation and amortization		261,016			225,042			508,637			450,252
Interest expense		63,459			63,755			126,113			137,721
Losses (gains) on sales and retirements of long-lived assets and other expense (income), net		13,414			4,348			11,574			10,507
Impairments and other charges		147,503			—			147,503			—
Total costs and other deductions		1,742,260			1,243,565			3,371,857			2,505,959
Income (loss) from continuing operations before income taxes		(134,095	)		108,410			78,317			248,138
Income tax expense (benefit):
Current		34,698			7,849			60,704			27,538
Deferred		(70,890	)		28,924			(27,852	)		53,661
Total income tax expense
(benefit)		(36,192	)		36,773			32,852			81,199
Subsidiary preferred stock dividend		750			750			1,500			1,500
Income (loss) from continuing operations, net of tax		(98,653	)		70,887			43,965			165,439
Income (loss) from discontinued operations, net of tax		24,690			121,167			15,895			108,771
Net income (loss)		(73,963	)		192,054			59,860			274,210
Less: Net (income) loss attributable to noncontrolling interest		1,174			394			1,441			1,063
Net income (loss) attributable to Nabors	$	(72,789	)	$	192,448		$	61,301		$	275,273
Earnings (losses) per share:
Basic from continuing operations	$	(.34	)	$	.25		$	.16		$	.58
Basic from discontinued operations		.09			.42			.05			.38
Total Basic	$	(.25	)	$	.67		$	.21		$	.96
Diluted from continuing operations	$	(.34	)	$	.24		$	.16		$	.57
Diluted from discontinued operations		.09			.41			.05			.37
Total Diluted	$	(.25	)	$	.65		$	.21		$	.94
Weighted-average number of common shares outstanding:
Basic		290,311			287,311			289,550			286,712
Diluted		290,311			294,298			292,185			293,493

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

4

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OTHER COMPREHENSIVE INCOME (LOSS)

(Unaudited)

	Three Months Ended June 30,						Six Months Ended June 30,
(In thousands)	2012			2011			2012			2011
Net income (loss) attributable to Nabors	$	(72,789	)	$	192,448		$	61,301		$	275,273
Other comprehensive income (loss), before tax:
Translation adjustment attributable to Nabors		(19,659	)		7,910			(2,393	)		39,349
Unrealized gains/(losses) on marketable securities:
Unrealized gains/(losses) on marketable securities		(5,008	)		(11,192	)		7,215			(4,884	)
Less: reclassification adjustment for (gains)/losses included in net income (loss)		(19	)		2			(12,484	)		(1	)
Unrealized gains/(losses) on marketable securities		(5,027	)		(11,190	)		(5,269	)		(4,885	)
Defined benefit pension plans:
Pension liability amortization		260			149			520			300
Pension liability adjustment		—			—			—			—
Defined benefit pension plans		260			149			520			300
Unrealized gains/(losses) and amortization of (gains)/losses on cash flow hedges		191			190			382			381
Other comprehensive income (loss), before tax		(24,235	)		(2,941	)		(6,760	)		35,145
Income tax expense (benefit) related to items of other comprehensive income (loss)		140			124			(3,584	)		306
Other comprehensive income (loss), net of tax		(24,375	)		(3,065	)		(3,176	)		34,839
Comprehensive income (loss)		(97,164	)		189,383			58,125			310,112
Net income (loss) attributable to noncontrolling interest		(1,174	)		(394	)		(1,441	)		(1,063	)
Translation adjustment attributable to noncontrolling interest		(216	)		95			27			452
Comprehensive income (loss) attributable to noncontrolling interest		(1,390	)		(299	)		(1,414	)		(611	)
Comprehensive income (loss) attributable to Nabors	$	(98,554	)	$	189,084		$	56,711		$	309,501

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

5

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Six Months Ended June 30,
(In thousands)	2012			2011
Cash flows from operating activities:
Net income (loss) attributable to Nabors	$	61,301		$	275,273
Adjustments to net income (loss):
Depreciation and amortization		508,748			451,986
Depletion and other exploratory expenses		151			19,072
Deferred income tax expense (benefit)		(15,404	)		47,308
Deferred financing costs amortization		2,185			2,922
Pension liability amortization and adjustments		520			300
Discount amortization on long-term debt		993			26,081
Amortization of loss on hedges		463			464
Impairments and other charges		159,950			—
Losses (gains) on long-lived assets, net		8,335			(41,458	)
Losses (gains) on investments, net		(21,400	)		(8,761	)
Losses (gains) on debt retirement, net		—			58
Losses (gains) on derivative instruments		90			338
Share-based compensation		8,784			8,107
Foreign currency transaction losses (gains), net		2,285			615
Gain on sale of oil and gas operations		(48,486	)		—
Equity in (earnings) losses of unconsolidated affiliates, net of dividends		202,985			(102,122	)
Changes in operating assets and liabilities, net of effects from acquisitions:
Accounts receivable		(33,981	)		(82,533	)
Inventory		6,636			(39,807	)
Other current assets		(26,906	)		21,051
Other long-term assets		6,693			61,543
Trade accounts payable and accrued liabilities		(94,423	)		237,743
Income taxes payable		(33,147	)		(13,363	)
Other long-term liabilities		15,565			5,085
Net cash provided by operating activities		711,937			869,902
Cash flows from investing activities:
Purchases of investments		(795	)		(7,945	)
Sales and maturities of investments		25,517			20,622
Investment in unconsolidated affiliates		—			(29,762	)
Distribution of proceeds from asset sales from unconsolidated affiliates		—			119,207
Capital expenditures		(967,861	)		(1,003,245	)
Proceeds from sales of assets and insurance claims		116,923			102,067
Net cash used for investing activities		(826,216	)		(799,056	)
Cash flows from financing activities:
Increase (decrease) in cash overdrafts		(2,060	)		11,203
Proceeds from revolving credit facilities		200,000			1,200,000
Proceeds from issuance of common shares		(5,066	)		11,622
Debt issuance costs		—			(2,188	)
Reduction in long-term debt		(1,235	)		(1,404,247	)
Paydown of revolving credit facilities		(150,000	)		—
Repurchase of equity component of convertible debt		—			(14	)
Purchase of restricted stock		(2,071	)		(2,527	)
Tax benefit related to share-based awards		(36	)		42
Net cash provided by (used for) financing activities		39,532			(186,109	)
Effect of exchange rate changes on cash and cash equivalents		(3,430	)		2,383
Net increase (decrease) in cash and cash equivalents		(78,177	)		(112,880	)
Cash and cash equivalents, beginning of period		398,575			641,702
Cash and cash equivalents, end of period	$	320,398		$	528,822

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

6

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(Unaudited)

	Common Shares
(In thousands)	Shares		Par Value		Capital in Excess of Par Value			Accumulated Other Comprehensive Income			Retained Earnings		Treasury Shares			Non- controlling Interest			Total Equity
Balances, December 31, 2011		317,042	$	317	$	2,287,743		$	321,264		$	3,956,364	$	(977,873	)	$	13,402		$	5,601,217
Net income (loss)												61,301					(1,441	)		59,860
Comprehensive income (loss), net of tax									(3,176	)							27			(3,149	)
Issuance of common shares for stock options exercised, net of surrender of unexercised stock options		999		1		(5,067	)													(5,066	)
Capital contribution from forgiveness of liability, net of tax						62,734														62,734
Issuance of treasury shares, net of tax benefit						(25,496	)							33,246						7,750
Other						(2,107	)										(1,121	)		(3,228	)
Share-based compensation		678		1		8,783														8,784
Balances, June 30, 2012		318,719	$	319	$	2,326,590		$	318,088		$	4,017,665	$	(944,627	)	$	10,867		$	5,728,902

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

7

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY

(Unaudited)

	Common Shares
(In thousands)	Shares		Par Value		Capital in Excess of Par Value			Accumulated Other Comprehensive Income		Retained Earnings		Treasury Shares			Non- controlling Interest			Total Equity
Balances, December 31, 2010		315,034	$	315	$	2,255,787		$	342,052	$	3,707,881	$	(977,873	)	$	14,701		$	5,342,863
Net income (loss)											275,273					(1,063	)		274,210
Comprehensive income, net of tax									34,839							452			35,291
Issuance of common shares for stock options exercised, net of surrender of unexercised stock options		956		1		11,621													11,622
Other		868				(2,499	)									(1,119	)		(3,618	)
Share-based compensation						8,107													8,107
Balances, June 30, 2011		316,858	$	316	$	2,273,016		$	376,891	$	3,983,154	$	(977,873	)	$	12,971		$	5,668,475

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

8

Nabors Industries Ltd. and Subsidiaries

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

Note 1 Nature of Operations

Nabors is the largest land drilling contractor in the world and one of the largest land well-servicing and workover contractors in the United States and Canada:

• We actively market approximately 513 land drilling rigs for oil and gas land drilling operations in the U.S. Lower 48 states, Alaska, Canada, South and Central America, Mexico, the Middle East, the Far East, the South Pacific, Russia and Africa.

• We actively market approximately 424 rigs for land well-servicing and workover work in the United States and approximately 176 rigs for land well-servicing and workover work in Canada.

We are also a leading provider of offshore platform workover and drilling rigs, and actively market 40 platform, 12 jackup and four barge rigs in the United States, including the Gulf of Mexico, and multiple international markets.

In addition to the foregoing services:

• We provide completion and production services, including hydraulic fracturing, cementing, nitrogen and acid pressure pumping services with over 805,000 hydraulic horsepower in key basins throughout the United States and Canada.

• We offer a wide range of ancillary well-site services, including engineering, transportation and disposal, construction, maintenance, well logging, directional drilling, rig instrumentation, data collection and other support services in select U.S. and international markets.

• We manufacture and lease or sell top drives for a broad range of drilling applications, directional drilling systems, rig instrumentation and data collection equipment, pipeline handling equipment and rig reporting software.

• We have a 51% ownership interest in a joint venture in Saudi Arabia, which owns and actively markets nine rigs in addition to the rigs we lease to the joint venture.

• We have invested in oil and gas exploration, development and production activities through both our wholly owned subsidiaries and our oil and gas joint ventures in which we hold 49-50% ownership interests.

The majority of our business is conducted through our Drilling and Rig Services and our Completion and Production business lines. Our Drilling and Rig Services business line includes our drilling operations for oil and natural gas wells, on land and offshore, and companies engaged in drilling technology, top drive manufacturing, directional drilling, construction services, and rig instrumentation and software. Our Completion and Production Services business line includes our well-servicing, fluid logistics, workover operations and our pressure pumping services. In addition to these two primary business lines, we have an Oil and Gas operating segment. Our oil and gas exploration, development and production operations are included in our Oil and Gas operating segment, or in discontinued operations in some cases.

Unless the context requires otherwise, references in this report and in Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations to “we,” “us,” “our,” “Company” or “Nabors” mean Nabors Industries Ltd., together with our subsidiaries where the context requires, including Nabors Industries, Inc., a Delaware corporation (“Nabors Delaware”).

9

Note 2 Summary of Significant Accounting Policies

Interim Financial Information

The unaudited consolidated financial statements of Nabors are prepared in conformity with accounting principles generally accepted in the United States (“GAAP”). Certain reclassifications have been made to the prior period to conform to the current-period presentation, with no effect on our consolidated financial position, results of operations or cash flows. Pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”), certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been omitted. Therefore, these financial statements should be read along with our annual report on Form 10-K for the year ended December 31, 2011 (“2011 Annual Report”). In management’s opinion, the consolidated financial statements contain all adjustments necessary to present fairly our financial position as of June 30, 2012, the results of our operations and other comprehensive income for the three and six months ended June 30, 2012 and 2011, and cash flows and changes in equity for the six months ended June 30, 2012 and 2011, in accordance with GAAP. Interim results for the three and six months ended June 30, 2012 may not be indicative of results that will be realized for the full year ending December 31, 2012.

Our independent registered public accounting firm has reviewed and issued a report on these consolidated interim financial statements in accordance with standards established by the Public Company Accounting Oversight Board. Pursuant to Rule 436(c) under the Securities Act of 1933, as amended (the “Securities Act”) this report should not be considered a part of any registration statement prepared or certified within the meanings of Sections 7 and 11 of such Act.

Principles of Consolidation

Our consolidated financial statements include the accounts of Nabors, as well as all majority-owned and nonmajority-owned subsidiaries required to be consolidated under GAAP. Our consolidated financial statements exclude majority-owned entities for which we do not have either (1) the ability to control the operating and financial decisions and policies of that entity or (2) a controlling financial interest in a variable interest entity. All significant intercompany accounts and transactions are eliminated in consolidation.

Investments in operating entities where we have the ability to exert significant influence, but where we do not control operating and financial policies, are accounted for using the equity method. Our share of the net income (loss) of these entities is recorded as earnings (losses) from unconsolidated affiliates in our consolidated statements of income (loss), and our investment in these entities is included in both investment in unconsolidated affiliates and assets held for sale in our consolidated balance sheets. The portion of such investments included in investments in unconsolidated affiliates totaled $165.0 million and $371.0 million as of June 30, 2012 and December 31, 2011, respectively. At June 30, 2012 and December 31, 2011, the portion of such investments included in assets held for sale totaled $13.7 million. See Note 4 – Discontinued Operations for additional information.

We have investments in offshore funds, which are classified as long-term investments and are accounted for using the equity method of accounting based on our ownership interest in each fund.

Inventory

Inventory is stated at the lower of cost or market. Cost is determined using the first-in, first-out method and includes the cost of materials, labor and manufacturing overhead. Inventory included the following:

	June 30, 2012		December 31, 2011
	(In thousands)
Raw materials	$	136,734	$	133,480
Work-in-progress		43,799		50,951
Finished goods		79,410		88,421
	$	259,943	$	272,852

10

Goodwill

We determined it was necessary to perform our annual goodwill impairment test, a level 3 fair value measurement, during the second quarter of 2012. The impairment test compares the estimated fair value of the reporting unit to its carrying amount. If the carrying amount exceeds the fair value, a second step is required to measure the goodwill impairment loss. This second step compares the implied fair value of the reporting unit’s goodwill to its carrying amount. If the carrying amount exceeds the implied fair value, an impairment loss is recognized in an amount equal to the excess. Our goodwill impairment test results required the second step measurement for two reporting units.

The fair values calculated in these impairment tests were determined using discounted cash flow models involving assumptions based on our utilization of rigs or other oil and gas service equipment, revenues and earnings from affiliates, as well as direct costs, general and administrative costs, depreciation, applicable income taxes, capital expenditures and working capital requirements. Our discounted cash flow projections for each reporting unit were based on financial forecasts. The future cash flows were discounted to present value using discount rates determined to be appropriate for each reporting unit. Terminal values for each reporting unit were calculated using a Gordon Growth methodology with a long-term growth rate of 3%.

Our estimated fair values of our reporting units incorporate judgment and the use of estimates by management. Potential factors requiring assessment include a further or sustained decline in our stock price, declines in natural gas and oil prices, a variance in results of operations from forecasts, and additional transactions in the oil and gas industry. Another factor in determining whether impairment has occurred is the relationship between our market capitalization and our book value. As part of our annual review, we compared the sum of our reporting units’ estimated fair value, which included the estimated fair value of non-operating assets and liabilities, less debt, to our market capitalization and assessed the reasonableness of our estimated fair value. Any of the above-mentioned factors may cause us to re-evaluate goodwill during any quarter throughout the year.

The carrying amounts and change of goodwill for our operating segments as of and for the six months ended June 30, 2012 were as follows:

	Balance as of December 31, 2011		Acquisitions and Purchase Price Adjustments		Disposals and Impairments			Cumulative Translation Adjustment			Balance as of June 30, 2012
	(In thousands)
Drilling and Rig Services:
U.S. Lower 48 Land Drilling	$	30,154	$	—	$	—		$	—		$	30,154
U.S. Offshore		7,296		—		7,296	(1)		—			—
Alaska		19,995		—		—			—			19,995
International		18,983		—		18,983	(1)		—			—
Other Rig Services		34,766		—		3,035	(2)		(31	)		31,700
Subtotal Drilling and Rig Services		111,194		—		29,314			(31	)		81,849
Completion and Production Services:
U.S. Land Well-servicing		55,072		—		—			—			55,072
Pressure Pumping		334,992		—		—			—			334,992
Subtotal Completion and Production Services		390,064		—		—			—			390,064
Total	$	501,258	$	—	$	29,314		$	(31	)	$	471,913

(1) Represents the impairment of goodwill associated with our U.S. Offshore and International reporting units. As of June 30, 2012, these reporting units had no recorded goodwill. The impairments were deemed necessary due to the prolonged uncertainty of utilization of some of our rigs as a result of changes in our

11

customers’ plans for future drilling operations in the Gulf of Mexico as well as our international markets. A significantly prolonged period of lower natural gas prices or changes in laws and regulations could continue to adversely affect the demand for and prices of our services, which could result in future goodwill impairment charges for other reporting units due to the potential impact on our estimate of our future operating results.

(2) Represents the removal of goodwill in connection with our sale of Peak USA to an unrelated third party for $13.5 million cash during the second quarter of 2012. Peak USA, a subsidiary included in our Other Rig Services reporting unit, provided trucking and logistics services to the oilfield service market in the U.S. Lower 48 states.

Note 3 Impairments and Other Charges

Impairments and other charges included the following:

	Three Months Ended June 30,
(In thousands)	2012		2011
Goodwill impairment	$	26,279	$	—
Intangible asset impairment (1)		74,960		—
Provision for retirement of assets: (2)
Canada		15,095		—
U.S. Well-servicing		4,628		—
Pressure Pumping		26,541		—
Total impairments and other charges	$	147,503	$	—

(1) Represents $75.0 million related to the impairment of the Superior trade name. The Superior trade name was initially classified as a ten-year intangible asset at the date of acquisition in September 2010. The impairment is a result of the decision to cease using the Superior trade name to reduce confusion in the marketplace and enhance the Nabors brand.

(2) During the three months ended June 30, 2012, we recorded a provision for retirement of long-lived assets totaling $46.2 million in multiple operating segments, which reduced the carrying value of some assets to their salvage value. The retirements in our Canada operations included functionally inoperable rigs and other drilling equipment. Our U.S. Well-servicing operations related to retirements of rigs and vehicles that would require significant repair to return to work. We recorded retirements of some non-core assets as we have begun the process to streamline our operations and consolidate our Pressure Pumping and U.S. Well-servicing segments into one business line, Nabors Completion and Production Services. As a result, we decided to retire these assets. As we continue to streamline our lines of business, there could be future retirement or impairment charges, which could have a potential impact on our future operating results. In addition, a prolonged period of lower natural gas and oil prices and its potential impact on our utilization and dayrates could result in the recognition of future impairment charges to additional assets if future cash flow estimates, based upon information then available to management, indicate that the carrying value of those assets may not be recoverable.

Note 4 Discontinued Operations

Assets held for sale included the following:

(In thousands)	June 30, 2012		December 31, 2011
Assets Held for Sale
Oil and Gas	$	385,047	$	385,414
Other Rig Services		11,366		16,086
Assets Held for Sale	$	396,413	$	401,500

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Our condensed statements of income (loss) from discontinued operations for the three and six months ended June 30, 2012 and 2011 were as follows:

	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
	(In thousands)
Operating revenues and Earnings (losses) from unconsolidated affiliates
Oil and Gas	$	2,919		$	9,397		$	6,220		$	20,816
Other Rig Services (1)	$	5,554		$	7,245		$	10,416		$	11,839
Income (loss) from Oil and Gas discontinued operations:
Income (loss) from discontinued operations	$	(2,476	)	$	77,356		$	(7,921	)	$	60,140
Gain (loss) on sale of wholly owned assets		41,282			42,717			36,110			42,717
Less: income tax expense (benefit)		7,042			(2,223	)		4,227			(8,563	)
Income (loss) from Oil and Gas discontinued operations, net of tax	$	31,764		$	122,296		$	23,962		$	111,420
Income (loss) from Other Rig Services discontinued operations: (1)
Income (loss) from discontinued operations	$	(4,190	)	$	(1,506	)	$	(5,519	)	$	(3,533	)
Gain (loss) on sale of assets		(5,242	)		—			(5,242	)		—
Less: income tax expense (benefit)		(2,358	)		(377	)		(2,694	)		(884	)
Income (loss) from Other Rig Services discontinued operations, net of tax	$	(7,074	)	$	(1,129	)	$	(8,067	)	$	(2,649	)

(1) Represents our aircraft logistics operations in Canada included in our Other Rig Services operating segment.

In April 2012, we sold our remaining wholly owned oil and gas business in Colombia to an unrelated third party for a cash purchase price of $72.6 million, which resulted in a pre-tax gain of approximately $48.5 million. These assets were included in our assets held for sale as part of our Oil and Gas operating segment.

In May 2012, we sold some of our U.S. wholly owned oil and gas business in the Fayetteville Shale, Floyd Shale, and Barnett Shale areas to unrelated third parties for cumulative cash receipts of $5.7 million, which did not result in any gain or loss. These assets were included in our assets held for sale as part of our Oil and Gas operating segment. Based on current market conditions and our assessment of the sales price, we adjusted the carrying value of our U.S. wholly owned oil and gas business by $7.2 million in the second quarter of 2012 to reflect their estimated sales price or current fair value.

Our contracts with pipeline companies include pipeline transmission commitments in the Horn River Basin. During the year ended December 31, 2011, we evaluated current production levels, natural gas prices and the anticipated sales cycle related to the sale of properties corresponding to these commitments. As a result, we recorded liabilities for excess pipeline capacity. Our consolidated balance sheets included current liabilities related to discontinued operations of $63.9 million and $54.3 million that were included in accrued liabilities and noncurrent liabilities related to discontinued operations of $35.3 million and $71.4 million that were included in other long-term liabilities at June 30, 2012 and December 31, 2011, respectively. These amounts represent our best estimate of the excess capacity of the pipeline, based upon the estimated sales date of the properties, as compared to the contractual commitments. Our commitments beyond December 31, 2013 could approximate $265.4 million if the related properties are not sold or developed. Decreases in actual production, natural gas prices or a change in the estimated sales date could result in future charges related to excess capacity of the pipeline that may materially impact our results of operations.

Based on current market conditions and our assessment of the sales price, we adjusted the carrying value of our aircraft logistics assets by $5.2 million in the second quarter of 2012 to reflect their estimated sales price or current fair value.

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Note 5 Cash and Cash Equivalents and Short-term Investments

Our cash and cash equivalents and short-term investments consisted of the following:

	June 30, 2012		December 31, 2011
	(In thousands)
Cash and cash equivalents	$	320,398	$	398,575
Short-term investments:
Trading equity securities		19,049		11,600
Available-for-sale equity securities		77,993		71,433
Available-for-sale debt securities		37,742		57,881
Total short-term investments	$	134,784	$	140,914

Certain information related to our cash and cash equivalents and short-term investments follows:

	June 30, 2012							December 31, 2011
	Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses			Fair Value		Gross Unrealized Holding Gains		Gross Unrealized Holding Losses
	(In thousands)
Cash and cash equivalents	$	320,398	$	—	$	—		$	398,575	$	—	$	—
Short-term investments:
Trading equity securities		19,049		13,325		—			11,600		5,876		—
Available-for-sale equity securities		77,993		41,014		(1,379	)		71,433		33,075		—
Available-for-sale debt securities:
Commercial paper and CDs		673		—		—			1,230		—		—
Corporate debt securities		32,400		11,819		(3,310	)		51,300		22,494		(2,095	)
Mortgage-backed debt securities		261		15		—			309		10		—
Mortgage-CMO debt securities		2,343		11		(12	)		2,547		13		(15	)
Asset-backed debt securities		2,065		—		(180	)		2,495		—		(238	)
Total available-for-sale debt securities		37,742		11,845		(3,502	)		57,881		22,517		(2,348	)
Total available-for-sale securities		115,735		52,859		(4,881	)		129,314		55,592		(2,348	)
Total short-term investments		134,784		66,184		(4,881	)		140,914		61,468		(2,348	)
Total cash, cash equivalents and short-term investments	$	455,182	$	66,184	$	(4,881	)	$	539,489	$	61,468	$	(2,348	)

Certain information related to the gross unrealized losses of our cash and cash equivalents and short-term investments follows:

	As of June 30, 2012
	Less Than 12 Months				More Than 12 Months
	Fair Value		Gross Unrealized Loss		Fair Value		Gross Unrealized Loss
	(In thousands)
Available-for-sale equity securities	$	17,516	$	1,379	$	—	$	—
Available-for-sale debt securities:
Corporate debt securities (1)		—		—		16,500		3,310
Mortgage-CMO debt securities (2)		2,069		9		62		3
Asset-backed debt securities (2)		2,065		180		—		—
Total available-for-sale debt securities		4,134		189		16,562		3,313
Total	$	21,650	$	1,568	$	16,562	$	3,313

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(1) Our unrealized loss on corporate debt securities relates to our investment in NFR Energy LLC’s 9.75% senior notes. This investment is in addition to our equity interest in NFR Energy LLC. The senior notes mature in 2017 and interest is paid semi-annually on February 15 and August 15. We do not intend to sell this investment, and it is less likely than not that we will be required to sell it to satisfy our own cash flow and working capital requirements. We believe that we will continue to collect all amounts due according to the contractual terms of the investment and, therefore, do not consider the decline in value of the investment to be other-than-temporary at June 30, 2012. See Note 8 Investments in Unconsolidated Affiliates for additional discussion of our equity investment.

(2) Our unrealized losses on available-for-sale debt securities held for more than one year are comprised of various types of securities. Each of these securities has a rating ranging from “A” to “AAA” from Standard & Poor’s and ranging from “A2” to “Aaa” from Moody’s Investors Service and is considered of high credit quality. In each case, we do not intend to sell these investments, and it is less likely than not that we will be required to sell them to satisfy our own cash flow and working capital requirements. We believe that we will be able to collect all amounts due according to the contractual terms of each investment and, therefore, do not consider the decline in value of these investments to be other-than-temporary at June 30, 2012.

The estimated fair values of our corporate, mortgage-backed, mortgage-CMO and asset-backed debt securities at June 30, 2012, classified by time to contractual maturity, are shown below. Expected maturities differ from contractual maturities because the issuers of the securities may have the right to repay obligations without prepayment penalties and we may elect to sell the securities prior to the contractual maturity date.

	Estimated Fair Value June 30, 2012
	(In thousands)
Debt securities:
Due in one year or less	$	673
Due after one year through five years		16,500
Due in more than five years		20,569
Total debt securities	$	37,742

Certain information regarding our debt and equity securities is presented below:

	Six Months Ended June 30,
	2012		2011
	(In thousands)
Available-for-sale:
Proceeds from sales and maturities	$	19,233	$	782
Realized gains (losses), net		12,484		(7	)

Note 6 Fair Value Measurements

The following table sets forth, by level within the fair value hierarchy, our financial assets and liabilities that are accounted for at fair value on a recurring basis as of June 30, 2012. Our debt securities could transfer into or out of a Level 1 or 2 measure depending on the availability of independent and current pricing at the end of each quarter. During the three months ended June 30, 2012, there were no transfers of our financial assets and liabilities between Level 1 and Level 2 measures. Our financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

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Recurring Fair Value Measurements

	Fair Value as of June 30, 2012
	Level 1		Level 2		Level 3		Total
	(In thousands)
Assets:
Short-term investments:
Available-for-sale equity securities – energy industry	$	71,054	$	6,939	$	—	$	77,993
Available-for-sale debt securities
Commercial paper and CDs		673		—		—		673
Corporate debt securities		—		32,400		—		32,400
Mortgage-backed debt securities		—		261		—		261
Mortgage-CMO debt securities		—		2,343		—		2,343
Asset-backed debt securities		2,065		—		—		2,065
Trading securities – energy industry		19,049		—		—		19,049
Total short-term investments	$	92,841	$	41,943	$	—	$	134,784
Liabilities:
Derivative contract	$	—	$	268	$	—	$	268

Nonrecurring Fair Value Measurements

Fair value measurements were applied with respect to our nonfinancial assets and liabilities measured on a nonrecurring basis, which would primarily consist of goodwill, intangible assets and other long-lived assets, assets acquired and liabilities assumed in a business combination, and asset retirement obligations.

Fair Value of Financial Instruments

The fair value of our financial instruments has been estimated in accordance with GAAP. We measure the estimated fair value of our long-term debt, subsidiary preferred stock and revolving credit facilities using significant other observable inputs, which represent Level 2 fair value measurements, including quoted market prices or prices quoted from third-party financial institutions as well as the terms and credit spreads for such instruments. The carrying and fair values of these liabilities were as follows:

	June 30, 2012				December 31, 2011
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In thousands)
5.375% senior notes due August 2012 (1)	$	274,918	$	277,475	$	274,604	$	281,188
6.15% senior notes due February 2018		968,098		1,125,365		967,490		1,113,986
9.25% senior notes due January 2019		1,125,000		1,457,741		1,125,000		1,419,514
5.00% senior notes due September 2020		697,495		750,792		697,343		734,475
4.625% senior notes due September 2021		697,787		706,776		697,667		708,176
Subsidiary preferred stock		69,188		68,625		69,188		68,625
Revolving credit facilities		910,000		910,000		860,000		860,000
Other		477		477		1,712		1,712
	$	4,742,963	$	5,297,251	$	4,693,004	$	5,187,676

(1) Includes $.1 million and $.3 million as of June 30, 2012 and December 31, 2011, respectively, related to the unamortized loss on the interest rate swap that was unwound during the fourth quarter of 2005.

The fair values of our cash equivalents, trade receivables and trade payables approximate their carrying values due to the short-term nature of these instruments.

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As of June 30, 2012, our short-term investments were carried at fair market value and included $115.7 million and $19.0 million in securities classified as available-for-sale and trading, respectively. As of December 31, 2011, our short-term investments were carried at fair market value and included $129.3 million and $11.6 million in securities classified as available-for-sale and trading, respectively.

Note 7 Share-Based Compensation

We have several share-based employee compensation plans, which are more fully described in Note 8 Share-Based Compensation in our 2011 Annual Report. Total share-based compensation expense, which includes both stock options and restricted stock, totaled $4.3 million and $4.1 million for the three months ended June 30, 2012 and 2011, respectively, and $8.8 million and $8.1 million for the six months ended June 30, 2012 and 2011, respectively. Total share-based compensation is included in direct costs and general and administrative expenses in our consolidated statements of income (loss). Share-based compensation expense has been allocated to our various operating segments. See Note 15 – Segment Information.

During the six months ended June 30, 2012 and 2011, we awarded 923,131 and 1,029,157 shares of restricted stock, respectively, vesting over periods up to four years, to our employees and directors. These awards had an aggregate value at their grant date of $19.2 million and $28.8 million, respectively. The fair value of restricted stock that vested during the six months ended June 30, 2012 and 2011 was $9.3 million and $15.9 million, respectively.

The total intrinsic value of stock options exercised during the six months ended June 30, 2012 and 2011 was $5.1 million and $15.1 million, respectively. Additionally, the intrinsic value of stock options surrendered during the six months ended June 30, 2012 was $17.9 million. The total fair value of stock options that vested during the six months ended June 30, 2012 and 2011 was $7.6 million and $5.1 million, respectively.

Note 8 Investments in Unconsolidated Affiliates

We have several unconsolidated affiliates that are integral to our operations. For a full description, refer to Note 10 – Investments in Unconsolidated Affiliates in our 2011 Annual Report.

At June 30, 2012 and December 31, 2011, our consolidated balance sheets reflect our investments in unconsolidated affiliates accounted for using the equity method totaling $165.0 million and $371.0 million, respectively. In addition, assets held for sale include investments in unconsolidated affiliates accounted for using the equity method totaling $13.7 million at June 30, 2012 and December 31, 2011.

Presented below is summarized income statement (loss) information for our unconsolidated U.S. oil and gas joint venture:

	Three Months Ended June 30,					Six Months Ended June 30,
	2012			2011		2012			2011
	(In thousands)
Gross revenues	$	74,140		$	65,840	$	125,469		$	103,752
Gross margin	$	45,421		$	52,418	$	83,057		$	82,817
Net income (loss)	$	(282,403	)	$	39,217	$	(409,512	)	$	38,491
Nabors’ earnings (losses) from our U.S. oil and gas joint venture (1)	$	(140,434	)	$	6,216	$	(202,996	)	$	21,376

(1) During the three and six months ended June 30, 2012, our unconsolidated U.S. oil and gas joint venture recorded full-cost ceiling test writedowns, of which our proportionate share was $145.5 million and $213.7 million, respectively. The writedowns are included in our Oil and Gas operating segment. If the average of the historical unweighted first-day-of-the-month natural gas prices for the prior 12-month periods remain at current levels or decline further through the end of the third and fourth quarters of 2012 due to price declines, there could be further reductions in our joint venture’s asset carrying value for oil and gas properties.

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Note 9 Debt

Long-term debt consisted of the following:

	June 30, 2012		December 31, 2011
	(In thousands)
5.375% senior notes due August 2012	$	274,918	$	274,604
6.15% senior notes due February 2018		968,098		967,490
9.25% senior notes due January 2019		1,125,000		1,125,000
5.00% senior notes due September 2020		697,495		697,343
4.625% senior notes due September 2021		697,787		697,667
Revolving credit facilities		910,000		860,000
Other		477		1,712
		4,673,775		4,623,816
Less: current portion		275,323		275,326
	$	4,398,452	$	4,348,490

5.375% Senior Notes Due August 2012

At June 30, 2012, the current portion of our long-term debt included Nabors Delaware’s 5.375% senior notes of $274.9 million. We intend to utilize cash on hand and capacity under our revolving credit facilities to meet this obligation.

Revolving Credit Facilities

At June 30, 2012, we had $490 million of remaining availability from a combined total of $1.4 billion under our existing revolving credit facilities. The existing revolving credit facilities mature in September 2014, and can be used for general corporate purposes, including capital expenditures and working capital. The weighted average interest rate on borrowings at June 30, 2012 was 1.75%. We fully and unconditionally guarantee the obligations under all of these credit facilities.

The revolving credit facilities contain various covenants and restrictive provisions that limit our ability to incur additional indebtedness, make investments or loans and create liens and require us to maintain a net funded indebtedness to total capitalization ratio, as defined in each agreement. We were in compliance with all covenants under the agreements at June 30, 2012 and December 31, 2011. If we should fail to perform our obligations under the covenants, the revolving credit commitments could be terminated and any outstanding borrowings under the relevant facility could be declared immediately due and payable.

Note 10 Common Shares

During the six months ended June 30, 2012, our employees exercised vested options and surrendered unexercised vested stock options to acquire 1.0 million of our common shares. We received proceeds of $15.9 million from exercised vested options and used approximately $21.0 million, the value of the unexercised vested options that were surrendered, to satisfy some of the option exercise price and related tax withholding obligations pursuant to stock option share settlements and exercises by some of the employees. During the six months ended June 30, 2011, our employees exercised vested options to acquire 1.0 million of our common shares, resulting in proceeds of $11.6 million. For each of the six months ended June 30, 2012 and 2011, we withheld .1 million of our common shares with a fair value of $2.1 million and $2.5 million, respectively, to satisfy tax withholding obligations in connection with the vesting of all stock awards.

At December 31, 2011, accrued liabilities included a provision of $100 million for a contingent liability related to the change of our Chief Executive Officer that occurred in October 2011. In February 2012, our former

18

Chief Executive Officer elected to forego triggering that payment. In connection with that development, we announced plans to make charitable contributions to benefit the needs of our employees and other community-based causes. During the first quarter of 2012, we contributed one million of our treasury shares to the Nabors Charitable Foundation, a 501(c)(3) organization, in support of this objective. We consider the former Chief Executive Officer to be a significant shareholder of the Company and, therefore, have recorded these transactions as equity. We recorded the release of the contingent liability, net of tax, through capital in excess of par as a forgiveness of liability from a beneficial owner. We recorded the donation of the treasury shares at their weighted-average cost, net of tax, through capital in excess of par.

Shareholder Rights Plan

On July 16, 2012, the Board of Directors declared the issuance of one preferred share purchase right (a “Right”) for each Common Share issued and outstanding on July 27, 2012 (the “Record Date”) to the shareholders of record on that date. Each Right entitles the registered holder to purchase from the Company one one-thousandth of a Series A Junior Participating Preferred Share, par value US$0.001 per share (the “Preferred Shares”), of the Company, at a price of $70.00 per one one-thousandth of a Preferred Share (the “Purchase Price”), subject to adjustment.

Until the earlier to occur of (i) 10 days following a public announcement that a person or group of affiliated or associated persons (an “Acquiring Person”) has acquired beneficial ownership (including derivative positions) of 10% or more of the issued and outstanding Common Shares (or, in the event an exchange is effected in accordance with Section 24 of the Rights Agreement and the Board of Directors determines that a later date is advisable, then such later date that is not more than 20 days after such public announcement) or (ii) 10 business days (or such later date as may be determined by action of the Board of Directors prior to such time as any Person becomes an Acquiring Person) following the commencement of, or announcement of an intention to make, a tender offer or exchange offer the consummation of which would result in the beneficial ownership by a person or group of 10% or more of the issued and outstanding Common Shares (the earlier of such dates being called the “Distribution Date”), the Rights will be evidenced, with respect to any of the Common Share certificates issued and outstanding as of the Record Date, by such Common Share certificate with a copy of the Summary of Rights attached as Exhibit C to the Rights Agreement.

The Rights are not exercisable until the Distribution Date. The Rights will expire on July 16, 2013 (the “Final Expiration Date”), unless the Final Expiration Date is extended or unless the Rights are earlier redeemed by the Company, in each case.

Note 11 Subsidiary Preferred Stock

During the three months ended June 30, 2012, dividends of $.75 million on outstanding shares of preferred stock had been declared and paid in full.

Note 12 Commitments and Contingencies

Commitments

Employment Contracts

The employment agreement for Mr. Petrello currently provides for a term through March 30, 2015, with automatic one-year extensions each April 1, unless either party gives notice of nonrenewal. In the event of Mr. Petrello’s termination without cause or constructive termination without cause, he would be entitled to receive three times the average of his base salary and annual bonus during the three fiscal years preceding the termination. If, by way of example, Mr. Petrello were terminated without cause subsequent to June 30, 2012, his payment would be approximately $31.1 million. The formula will be further reduced to two times the average stated above in April 1, 2015. In the event of his death or disability, either he or his estate would be entitled to receive within 30 days thereafter a payment of $50 million.

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We do not have insurance to cover, and we have not recorded an expense or accrued a liability relating to, this potential obligation. See Note 18 Commitments and Contingencies to our 2011 Annual Report for additional discussion and description of Mr. Petrello’s employment agreement.

Contingencies

Income Tax Contingencies

We are subject to income taxes in the United States and numerous other jurisdictions. Significant judgment is required in determining our worldwide provision for income taxes. In the ordinary course of our business, there are many transactions and calculations where the ultimate tax determination is uncertain. We are regularly audited by tax authorities. Although we believe our tax estimates are reasonable, the final determination of tax audits and any related litigation could be materially different than what is reflected in income tax provisions and accruals. An audit or litigation could materially affect our financial position, income tax provision, net income, or cash flows in the period or periods challenged.

It is possible that future changes to tax laws (including tax treaties) could impact our ability to realize the tax savings recorded to date as well as future tax savings, resulting from our 2002 corporate reorganization. See Note 13 – Income Taxes to our 2011 Annual Report for additional discussion.

On September 14, 2006, Nabors Drilling International Limited, one of our wholly owned Bermuda subsidiaries (“NDIL”), received a Notice of Assessment from Mexico’s federal tax authorities in connection with the audit of NDIL’s Mexico branch for 2003. The notice proposes to deny depreciation expense deductions relating to drilling rigs operating in Mexico in 2003. The notice also proposes to deny a deduction for payments made to an affiliated company for the procurement of labor services in Mexico. The amount assessed was approximately $19.8 million (including interest and penalties). Nabors and its tax advisors previously concluded that the deductions were appropriate. NDIL’s Mexico branch took similar deductions for depreciation and labor expenses from 2004 to 2008. On June 30, 2009, the government proposed similar assessments against the Mexico branch of another wholly owned Bermuda subsidiary, Nabors Drilling International II Ltd. (“NDIL II”) for 2006. We anticipate that a similar assessment will eventually be proposed against NDIL for 2005 through 2008 and against NDIL II for 2007 to 2010. We believe that the potential assessments will range from $6 million to $26 million per year for the period from 2005 to 2009, and in the aggregate, would be approximately $90 million to $95 million. Although Nabors and our tax advisors previously concluded that the deductions were appropriate for the 2003 and 2005 to 2010 years, a reserve has been recorded in accordance with GAAP. The statute of limitations for NDIL’s 2004 tax year expired. Accordingly, during the fourth quarter of 2010, we released $7.4 million from our tax reserves, which represented the reserve recorded for that tax year. If these additional assessments were made and we ultimately did not prevail, we would be required to recognize additional tax for the amount in excess of the current reserve.

Self-Insurance

We estimate the level of our liability related to insurance and record reserves for these amounts in our consolidated financial statements. Our estimates are based on the facts and circumstances specific to existing claims and our past experience with similar claims. These loss estimates and accruals recorded in our financial statements for claims have historically been reasonable in light of the actual amount of claims paid. Although we believe our insurance coverage and reserve estimates are reasonable, a significant accident or other event that is not fully covered by insurance or contractual indemnity could occur and could materially affect our financial position and results of operations for a particular period.

Effective April 1, 2012, our workers’ compensation claims are subject to a $2.0 million per-occurrence deductible, and our automobile claims are subject to a $1.0 million per-occurrence deductible.

Litigation

Nabors and its subsidiaries are defendants or otherwise involved in a number of lawsuits in the ordinary course of business. We estimate the range of our liability related to pending litigation when we believe the amount and range of loss can be estimated. We record our best estimate of a loss when the loss is considered probable. When a liability is probable and there is a range of estimated loss with no best estimate in the range, we record the minimum estimated

20

liability related to the lawsuits or claims. As additional information becomes available, we assess the potential liability related to our pending litigation and claims and revise our estimates. Due to uncertainties related to the resolution of lawsuits and claims, the ultimate outcome may differ from our estimates. For matters where an unfavorable outcome is reasonably possible and significant, we disclose the nature of the matter and a range of potential exposure, unless an estimate cannot be made at the time of disclosure. In the opinion of management and based on liability accruals provided, our ultimate exposure with respect to these pending lawsuits and claims is not expected to have a material adverse effect on our consolidated financial position or cash flows, although they could have a material adverse effect on our results of operations for a particular reporting period.

On July 5, 2007, we received an inquiry from the U.S. Department of Justice relating to its investigation of one of our vendors and compliance with the Foreign Corrupt Practices Act. The inquiry relates to transactions with and involving Panalpina, which provided freight forwarding and customs clearance services to some of our affiliates. The inquiry focused on transactions in Kazakhstan, Saudi Arabia, Algeria and Nigeria. The Audit Committee of our Board of Directors engaged outside counsel to review some of our transactions with this vendor, received periodic updates at its regularly scheduled meetings, and the Chairman of the Audit Committee received updates between meetings as circumstances warranted. The investigation included a review of certain amounts paid to and by Panalpina in connection with obtaining permits for the temporary importation of equipment and clearance of goods and materials through customs. Both the SEC and the Department of Justice have been advised of the results of our investigation. The SEC has advised us that it concluded its review of this matter and does not intend to recommend any enforcement action against us. Although the Department of Justice has not concluded its inquiry, we do not anticipate that its final determination will have an adverse effect on the Company.

In 2009, the Court of Ouargla (in Algeria) entered a judgment of approximately $19.7 million against us related to alleged customs infractions in 2009. We believe we did not receive proper notice of the judicial proceedings, and that the amount of the judgment was excessive in any case. We asserted the lack of legally required notice as a basis for challenging the judgment on appeal to the Algeria Supreme Court. On May 31, 2012, that court reversed the lower court and remanded the case to the Ouargla Court of Appeals for treatment consistent with the Supreme Court’s ruling. Based upon our understanding of applicable law and precedent, we continue to believe that we will prevail. We do not believe that a loss is probable and have not accrued any amounts related to this matter. If we are ultimately required to pay a fine or judgment related to this matter, the amount of the loss could range from approximately $140,000 to $19.7 million.

In March 2011, the Court of Ouargla entered a judgment of approximately $39.1 million against us relating to alleged violations of Algeria’s foreign currency exchange controls, which require that goods and services provided locally be invoiced and paid in local currency. The case relates to certain foreign currency payments made to us by CEPSA, a Spanish operator, for wells drilled in 2006. Approximately $7.5 million of the total contract amount was paid offshore in foreign currency, and approximately $3.2 million was paid in local currency. The judgment includes fines and penalties of approximately four times the amount at issue, and is not payable pending appeal. We have appealed the ruling based on our understanding that the law in question applies only to resident entities incorporated under Algerian law. An intermediate court of appeals has upheld the lower court’s ruling, and we have appealed the matter to the Algeria Supreme Court. While our payments were consistent with our historical operations in the country and, we believe, those of other multinational corporations there, and interpretations of the law by the Central Bank of Algeria, the ultimate resolution of this matter could result in a loss of up to $31.1 million in excess of amounts accrued.

On September 21, 2011, we received an informal inquiry from the SEC related to perquisites and personal benefits received by the officers and directors of Nabors, including their use of non-commercial aircraft. Our Audit Committee and Board of Directors have been apprised of this inquiry and we are cooperating with the SEC. The ultimate outcome of this process cannot be determined at this time.

Nabors Industries Ltd. and its Board of Directors were sued in three separate purported shareholder derivative lawsuits filed in federal and state court in Houston, Texas. The cases were filed on November 18, 2011, January 9, 2012, and November 30, 2011, respectively, before Judges Ewing Werlein and Gray Miller in the United States

21

Southern District of Texas, Houston Division, and Judge Mike Miller of the 11th Judicial District Court of Harris County, Texas. As previously disclosed, the case pending before Judge Gray Miller was voluntarily dismissed on January 31, 2012. On July 30, 2012, Judge Werlein entered a final judgment, dismissing the case pending in United States Southern District of Texas finding that plaintiffs lacked standing to sue and failed to state a claim for which relief could be granted. Judge Werlein also denied the plaintiffs’ request for leave to replead their claim. The other case in the 11th Judicial District Court of Harris County, Texas remains pending. The allegations of each lawsuit were substantially similar, alleging that the members of the Board breached their fiduciary duties to the Company, wasted corporate assets, and committed oppressive conduct against the shareholders by agreeing to acquiesce to certain compensation arrangements with two senior officers of the Company, Eugene M. Isenberg and Anthony G. Petrello. The remaining lawsuit seeks relief that includes an award of monetary damages in an unspecified amount, disgorgement by Messrs. Isenberg and Petrello of allegedly excessive compensation in an unspecified amount of at least $90 million, and equitable relief to reform Nabors’ compensations practices. Nabors intends to vigorously defend the remaining lawsuit. The ultimate outcome of these lawsuits cannot be determined at this time.

On March 9, 2012, Nabors Global Holdings II Limited (“NGH2L”) signed a contract with ERG Resources, LLC (“ERG”) relating to the sale of all of the Class A shares of NGH2L’s wholly owned subsidiary, Ramshorn International Limited, an oil and gas exploration company. When ERG failed to meet its closing obligations, NGH2L terminated the transaction on March 19, 2012 and, as contemplated in the agreement, retained ERG’s $3 million escrow deposit. ERG filed suit the following day in the 61^st Judicial District Court of Harris County, Texas, in a case styled ERG Resources, LLC v. Nabors Global Holdings II Limited, Ramshorn International Limited, and Parex Resources, Inc.; Cause No. 2012-16446, seeking injunctive relief to halt any sale of the shares to a third party, specifically naming as defendant Parex Resources, Inc. (“Parex”). The lawsuit also seeks monetary damages of up to $100 million based on an alleged breach of contract by NGH2L and tortious interference with contractual relations by Parex. Nabors successfully defeated ERG’s effort to obtain a temporary restraining order from the Texas court on March 20, 2012. On March 23, 2012, ERG filed and obtained an ex parte stay from the Supreme Court of Bermuda (Commercial Court), in a case styled as ERG Resources LLC v. Nabors Global Holdings II Limited, Case No. 2012: No. 110. Nabors challenged the stay and, following a series of oral hearings on the matter, the Bermuda court discharged the stay by a ruling dated April 5, 2012. Nabors completed the sale of Ramshorn’s Class A shares to a Parex affiliate on April 12, 2012, which mooted ERG’s application for a temporary injunction that was scheduled for hearing by the Texas court on April 13, 2012. ERG retains its causes of action for monetary damages, but Nabors believes the claims are foreclosed by the terms of the agreement and are without factual or legal merit. While Nabors intends to vigorously defend the lawsuit, the ultimate outcome of the lawsuit cannot be determined at this time.

Off-Balance Sheet Arrangements (Including Guarantees)

We are a party to some transactions, agreements or other contractual arrangements defined as “off-balance sheet arrangements” that could have a material future effect on our financial position, results of operations, liquidity and capital resources. The most significant of these off-balance sheet arrangements involve agreements and obligations under which we provide financial or performance assurance to third parties. Certain of these agreements serve as guarantees, including standby letters of credit issued on behalf of insurance carriers in conjunction with our workers’ compensation insurance program and other financial surety instruments such as bonds. In addition, we have provided indemnifications, which serve as guarantees, to some third parties. These guarantees include indemnification provided by Nabors to our share transfer agent and our insurance carriers. We are not able to estimate the potential future maximum payments that might be due under our indemnification guarantees.

Management believes the likelihood that we would be required to perform or otherwise incur any material losses associated with any of these guarantees is remote. The following table summarizes the total maximum amount of financial guarantees issued by Nabors:

	Maximum Amount
	Remainder of 2012		2013		2014		Thereafter		Total
	(In thousands)
Financial standby letters of credit and other financial surety instruments	$	48,158	$	60,580	$	75	$	—	$	108,813

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Note 13 Earnings (Losses) Per Share

A reconciliation of the numerators and denominators of the basic and diluted earnings (losses) per share computations is as follows:

	Three Months Ended June 30,					Six Months Ended June 30,
	2012			2011		2012		2011
	(In thousands, except per share amounts)
Net income (loss) (numerator):
Income (loss) from continuing operations, net of tax	$	(98,653	)	$	70,887	$	43,965	$	165,439
Less: net (income) loss attributable to noncontrolling interest		1,174			394		1,441		1,063
Adjusted income (loss) from continuing operations, net of tax – basic		(97,479	)		71,281		45,406		166,502
Add: interest expense on assumed conversion of our 0.94% senior exchangeable notes, net of tax (1)		—			—		—		—
Adjusted net income (loss) from continuing operations, net of tax – diluted		(97,479	)		71,281		45,406		166,502
Income (loss) from discontinued operations, net of tax		24,690			121,167		15,895		108,771
Adjusted net income (loss) attributable to Nabors		(72,789	)		192,448		61,301		275,273
Earnings (losses) per share:
Basic from continuing operations	$	(.34	)	$	.25	$	.16	$	.58
Basic from discontinued operations		.09			.42		.05		.38
Total Basic	$	(.25	)	$	.67	$	.21	$	.96
Diluted from continuing operations	$	(.34	)	$	.24	$	.16	$	.57
Diluted from discontinued operations		.09			.41		.05		.37
Total Diluted	$	(.25	)	$	.65	$	.21	$	.94
Shares (denominator):
Weighted-average number of shares outstanding — basic		290,311			287,311		289,550		286,712
Net effect of dilutive stock options, warrants and restricted stock awards based on the if-converted method		—			6,987		2,635		6,781
Assumed conversion of our 0.94% senior exchangeable notes due 2011 (1)		—			—		—		—
Weighted-average number of shares outstanding — diluted		290,311			294,298		292,185		293,493

(1) At maturity in May 2011, we redeemed the remaining aggregate principal amount of $1.4 billion of our 0.94% senior exchangeable notes. Prior to maturity, we had purchased $1.4 billion par value of these notes in the open market for cash of $1.2 billion.

For all periods presented, the computation of diluted earnings (losses) per Nabors’ share excludes outstanding stock options and warrants with exercise prices greater than the average market price of Nabors’ common shares because their inclusion would be anti-dilutive and because they are not considered participating securities. The average number of options and warrants that were excluded from diluted earnings (losses) per share that would potentially dilute earnings per share in the future was 17,635,173 and 5,494,895 shares during the three months ended June 30, 2012 and 2011, respectively, and 13,395,935 and 6,381,967 shares during the six months ended June 30, 2012 and 2011, respectively. In any period during which the average market price of Nabors’ common shares exceeds the exercise prices of these stock options and warrants, such stock options and warrants will be included in our diluted earnings (losses) per share computation using the if-converted method of accounting. Restricted stock will be included in our basic and diluted earnings (losses) per share computation using the two-class method of accounting in all periods because such stock is considered a participating security.

23

Note 14 Supplemental Balance Sheet, Income Statement and Cash Flow Information

Accrued liabilities include the following:

	June 30,			December 31,
	2012			2011
	(In thousands)
Accrued compensation	$	145,927		$	173,732
Deferred revenue		194,699			172,578
Other taxes payable		43,546			44,652
Workers’ compensation liabilities		22,645			22,645
Interest payable		97,223			99,869
Due to joint venture partners		—			6,041
Warranty accrual		7,086			5,237
Litigation reserves		26,451			23,687
Provision for termination payment		—			100,000
Current liability to discontinued operations		63,912			54,287
Professional fees		3,452			6,413
Income taxes payable		(8,539	)		27,710
Current deferred tax liability		—			269
Other accrued liabilities		8,225			7,363
	$	604,627		$	744,483

Investment income (loss) includes the following:

	Three Months Ended June 30,					Six Months Ended June 30,
	2012		2011			2012			2011
	(In thousands)
Interest and dividend income	$	3,594	$	1,948		$	4,949		$	3,773
Gains (losses) on investments, net (1)		1,774		(2,923	)		20,671	(2)		7,532	(3)

(1) Includes net unrealized gains/(losses) of $1.4 million and $(3.4) million, during the three months ended June 30, 2012 and 2011, respectively, and $7.4 million and $(6.7) million during the six months ended June 30, 2012 and 2011, respectively, from our trading securities.

(2) Includes $12.5 million realized gain related to debt securities in addition to unrealized gains discussed above.

(3) Includes $12.9 million realized gain related to one of our overseas fund investments classified as long-term investments, partially offset by unrealized losses discussed above.

Losses (gains) on sales and retirements of long-lived assets and other expense (income), net includes the following:

	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
	(In thousands)
Losses (gains) on sales, retirements and involuntary conversions of long-lived assets	$	5,962		$	(959	)	$	4,180		$	134
Litigation expenses		4,996			4,007			5,536			9,926
Foreign currency transaction losses (gains)		2,710			998			2,255			446
Losses (gains) on derivative instruments		(551	)		(350	)		(1,013	)		(861	)
Losses (gains) on debt extinguishment		—			—			—			58
Other losses (gains)		297			652			616			804
	$	13,414		$	4,348		$	11,574		$	10,507

24

Note 15 Segment Information

The following table sets forth financial information with respect to our reportable segments:

	Three Months Ended June 30,						Six Months Ended June 30,
	2012			2011			2012			2011
	(In thousands)
Operating revenues and earnings (losses) from unconsolidated affiliates from continuing operations: (1)
Drilling and Rig Services:
U.S. Lower 48 Land Drilling	$	494,371		$	404,984		$	990,068		$	783,552
U.S. Offshore		71,978			40,284			141,093			70,738
Alaska		32,416			32,336			94,709			73,651
Canada		92,390			87,974			284,683			260,417
International		304,622			265,231			611,087			527,708
Other Rig Services (2)		228,614			155,246			470,372			272,035
Subtotal Drilling and Rig Services (3)		1,224,391			986,055			2,592,012			1,988,101
Completion and Production Services:
U.S. Land Well-servicing		214,005			164,140			423,706			314,396
Pressure Pumping		387,663			265,930			785,699			523,789
Subtotal Completion and Production Services		601,668			430,070			1,209,405			838,185
Oil and Gas (4)		(140,434	)		6,216			(202,996	)		21,376
Other reconciling items (5)		(82,828	)		(69,391	)		(173,867	)		(104,870	)
Total	$	1,602,797		$	1,352,950		$	3,424,554		$	2,742,792
Adjusted income (loss) derived from operating activities from continuing operations: (1)(6)
Drilling and Rig Services:
U.S. Lower 48 Land Drilling	$	126,532		$	99,231		$	258,113		$	179,326
U.S. Offshore		9,924			(1,059	)		17,656			(5,036	)
Alaska		8,895			8,288			36,315			19,307
Canada		(3,718	)		(2,512	)		45,569			36,480
International		16,401			35,851			37,539			71,348
Other Rig Services (2)		28,179			13,946			58,025			22,290
Subtotal Drilling and Rig Services (3)		186,213			153,745			453,217			323,715
Completion and Production Services:
U.S. Land Well-servicing		28,599			16,526			50,487			27,649
Pressure Pumping		46,144			43,888			111,004			87,603
Subtotal Completion and Production Services		74,743			60,414			161,491			115,252
Oil and Gas (7)		5,066			6,216			10,716			21,376
Other reconciling items (8)		(35,609	)		(42,887	)		(73,825	)		(75,282	)
Total adjusted income derived from operating activities		230,413			177,488			551,599			385,061
Full-cost ceiling test writedowns		(145,500	)		—			(213,712	)		—
Interest expense		(63,459	)		(63,755	)		(126,113	)		(137,721	)
Investment income (loss)		5,368			(975	)		25,620			11,305
Gains (losses) on sales and retirements of long-lived assets and other income (expense), net		(13,414	)		(4,348	)		(11,574	)		(10,507	)
Impairments and other charges		(147,503	)		—			(147,503	)		—
Income (loss) from continuing operations before income taxes		(134,095	)		108,410			78,317			248,138
Income tax expense (benefit)		(36,192	)		36,773			32,852			81,199
Subsidiary preferred stock dividend		750			750			1,500			1,500
Income (loss) from continuing operations, net of tax		(98,653	)		70,887			43,965			165,439
Income (loss) from discontinued operations, net of tax		24,690			121,167			15,895			108,771
Net income (loss)		(73,963	)		192,054			59,860			274,210
Less: Net income (loss) attributable to noncontrolling interest		1,174			394			1,441			1,063
Net income (loss) attributable to Nabors	$	(72,789	)	$	192,448		$	61,301		$	275,273

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	June 30, 2012		December 31, 2011
	(In thousands)
Total assets:
Drilling and Rig Services:
U.S. Lower 48 Land Drilling	$	3,487,357	$	3,216,803
U.S. Offshore		445,956		402,506
Alaska		272,956		288,253
Canada		837,694		962,239
International		3,713,632		3,702,611
Other Rig Services (2)		677,803		720,775
Subtotal Drilling and Rig Services (9)		9,435,398		9,293,187
Completion and Production Services:
U.S. Well-servicing		840,616		812,049
Pressure Pumping		1,477,427		1,503,298
Subtotal Completion and Production Services		2,318,043		2,315,347
Oil and Gas (10)		582,981		796,327
Other reconciling items (8)		507,050		507,279
Total assets	$	12,843,472	$	12,912,140

(1) All periods present the operating activities of our wholly owned oil and gas business in the United States, Canada and Colombia, including equity interests in joint ventures in Canada and Colombia, as well as our aircraft logistics operations in Canada as discontinued operations.

(2) Includes our drilling technology and top drive manufacturing, directional drilling, rig instrumentation and software, and construction services. These services represent our other companies that are not aggregated into a reportable operating segment.

(3) Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $6.1 million and $3.1 million for the three months ended June 30, 2012 and 2011, respectively, and $4.2 million for the six months ended June 30, 2011.

(4) Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $(140.4) million and $6.2 million for the three months ended June 30, 2012 and 2011, respectively, and $(203.0) million and $21.4 million for the six months ended June 30, 2012 and 2011, respectively.

(5) Represents the elimination of inter-segment transactions.

(6) Adjusted income (loss) derived from operating activities is computed by subtracting direct costs, general and administrative expenses, and depreciation and amortization from Operating revenues and then adding Earnings (losses) from unconsolidated affiliates (excluding our proportionate share of full-cost ceiling test writedowns recorded by our oil and gas joint venture). These amounts should not be used as a substitute for those amounts reported in accordance with GAAP. However, management evaluates the performance of our business units and the consolidated company based on several criteria, including adjusted income (loss) derived from operating activities, because it believes that these financial measures accurately reflect our ongoing profitability. A reconciliation of this non-GAAP measure to income (loss) from continuing operations before income taxes, which is a GAAP measure, is provided in the above table.

(7) Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $5.1 million (excluding $145.5 million, which represents our proportionate share of full-cost ceiling test writedowns by our oil and gas joint venture) and $6.2 million for the three months ended June 30, 2012 and 2011, respectively, and $10.7 million (excluding $213.7 million, which represents our proportionate share of full-cost ceiling test writedowns by our oil and gas joint venture) and $21.4 million, for the six months ended June 30, 2012 and 2011, respectively.

(8) Represents the elimination of inter-segment transactions and unallocated corporate expenses and assets.

(9) Includes $70.9 million and $76.9 million of investments in unconsolidated affiliates accounted for using the equity method as of June 30, 2012 and December 31, 2011, respectively.

(10) Includes $94.1 million and $294.1 million of investments in unconsolidated affiliates accounted for using the equity method as of June 30, 2012 and December 31, 2011, respectively.

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Note 16 Condensed Consolidating Financial Information

Nabors has fully and unconditionally guaranteed all of the issued public debt securities of Nabors Delaware. The following condensed consolidating financial information is included so that separate financial statements of Nabors Delaware are not required to be filed with the SEC. The condensed consolidating financial statements present investments in both consolidated and unconsolidated affiliates using the equity method of accounting.

The following condensed consolidating financial information presents condensed consolidating balance sheets as of June 30, 2012 and December 31, 2011, statements of income (loss) and statements of other comprehensive income for the three and six months ended June 30, 2012 and 2011, and statements of cash flows for the six months ended June 30, 2012 and 2011, of (a) Nabors, parent/guarantor, (b) Nabors Delaware, issuer of public debt securities guaranteed by Nabors, (c) the non-guarantor subsidiaries, (d) consolidating adjustments necessary to consolidate Nabors and its subsidiaries and (e) Nabors on a consolidated basis.

27

Condensed Consolidating Balance Sheets

	June 30, 2012
(In thousands)	Nabors (Parent/ Guarantor)		Nabors Delaware (Issuer/ Guarantor)		Other Subsidiaries (Non- Guarantors)		Consolidating Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents	$	828	$	6,946	$	312,624	$	—		$	320,398
Short-term investments		—		—		134,784		—			134,784
Assets held for sale		—		—		396,413		—			396,413
Accounts receivable, net		—		—		1,607,422		—			1,607,422
Inventory		—		—		259,943		—			259,943
Deferred income taxes		—		—		70,288		—			70,288
Other current assets		50		671		185,201		—			185,922
Total current assets		878		7,617		2,966,675		—			2,975,170
Long-term investments and other receivables		—		—		5,452		—			5,452
Property, plant and equipment, net		—		39,042		8,865,282		—			8,904,324
Goodwill		—		—		471,913		—			471,913
Intercompany receivables		169,994		—		537,881		(707,875	)		—
Investment in unconsolidated affiliates		5,549,273		6,165,994		1,604,915		(13,155,179	)		165,003
Other long-term assets		—		29,688		291,922		—			321,610
Total assets	$	5,720,145	$	6,242,341	$	14,744,040	$	(13,863,054	)	$	12,843,472
LIABILITIES AND EQUITY
Current liabilities:
Current portion of long-term debt	$	—	$	274,918	$	405	$	—		$	275,323
Trade accounts payable		86		23		606,462		—			606,571
Accrued liabilities		2,024		97,305		505,298		—			604,627
Total current liabilities		2,110		372,246		1,112,165		—			1,486,521
Long-term debt		—		4,398,381		71		—			4,398,452
Other long-term liabilities		—		32,132		294,070		—			326,202
Deferred income taxes		—		11,319		822,888		—			834,207
Intercompany payable		—		336,350		371,525		(707,875	)		—
Total liabilities		2,110		5,150,428		2,600,719		(707,875	)		7,045,382
Subsidiary preferred stock		—		—		69,188		—			69,188
Shareholders’ equity		5,718,035		1,091,913		12,063,266		(13,155,179	)		5,718,035
Noncontrolling interest		—		—		10,867		—			10,867
Total equity		5,718,035		1,091,913		12,074,133		(13,155,179	)		5,728,902
Total liabilities and equity	$	5,720,145	$	6,242,341	$	14,744,040	$	(13,863,054	)	$	12,843,472

28

	December 31, 2011
(In thousands)	Nabors (Parent/ Guarantor)		Nabors Delaware (Issuer/ Guarantor)		Other Subsidiaries (Non- Guarantors)		Consolidating Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents	$	203	$	21	$	398,351	$	—		$	398,575
Short-term investments		—		—		140,914		—			140,914
Assets held for sale		—		—		401,500		—			401,500
Accounts receivable, net		—		—		1,576,555		—			1,576,555
Inventory		—		—		272,852		—			272,852
Deferred income taxes		—		—		127,874		—			127,874
Other current assets		50		671		169,323		—			170,044
Total current assets		253		692		3,087,369		—			3,088,314
Long-term investments and other receivables		—		—		11,124		—			11,124
Property, plant and equipment, net		—		40,792		8,589,154		—			8,629,946
Goodwill		—		—		501,258		—			501,258
Intercompany receivables		164,760		—		537,881		(702,641	)		—
Investment in unconsolidated affiliates		5,429,029		6,084,868		1,843,654		(12,986,530	)		371,021
Other long-term assets		—		32,037		278,440		—			310,477
Total assets	$	5,594,042	$	6,158,389	$	14,848,880	$	(13,689,171	)	$	12,912,140
LIABILITIES AND EQUITY
Current liabilities:
Current portion of long-term debt	$	—	$	274,604	$	722	$	—		$	275,326
Trade accounts payable		42		23		782,688		—			782,753
Accrued liabilities		6,185		100,101		638,197		—			744,483
Total current liabilities		6,227		374,728		1,421,607		—			1,802,562
Long-term debt		—		4,297,500		50,990		—			4,348,490
Other long-term liabilities		—		32,303		260,454		—			292,757
Deferred income taxes		—		11,221		786,705		—			797,926
Intercompany payable		—		379,400		323,241		(702,641	)		—
Total liabilities		6,227		5,095,152		2,842,997		(702,641	)		7,241,735
Subsidiary preferred stock		—		—		69,188		—			69,188
Shareholders’ equity		5,587,815		1,063,237		11,923,293		(12,986,530	)		5,587,815
Noncontrolling interest		—		—		13,402		—			13,402
Total equity		5,587,815		1,063,237		11,936,695		(12,986,530	)		5,601,217
Total liabilities and equity	$	5,594,042	$	6,158,389	$	14,848,880	$	(13,689,171	)	$	12,912,140

29

Condensed Consolidating Statements of Income (Loss)

	Three Months Ended June 30, 2012
(In thousands)	Nabors (Parent/ Guarantor)			Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Revenues and other income:
Operating revenues	$	—		$	—		$	1,737,114		$	—		$	1,737,114
Earnings (losses) from unconsolidated affiliates		—			—			(134,317	)		—			(134,317	)
Earnings (losses) from consolidated affiliates		(70,408	)		(35,150	)		(61,938	)		167,496			—
Investment income (loss)		—			16			5,352			—			5,368
Intercompany interest income		—			17,078			—			(17,078	)		—
Total revenues and other income		(70,408	)		(18,056	)		1,546,211			150,418			1,608,165
Costs and other deductions:
Direct costs		—			—			1,123,256			—			1,123,256
General and administrative expenses		2,022			50			131,899			(359	)		133,612
Depreciation and amortization		—			903			260,113			—			261,016
Interest expense		—			68,268			(4,809	)		—			63,459
Intercompany interest expense		—			—			17,078			(17,078	)		—
Losses (gains) on sales and retirements of long-lived assets and other expense (income), net		359			(546	)		13,242			359			13,414
Impairments and other charges		—			—			147,503			—			147,503
Total costs and other deductions		2,381			68,675			1,688,282			(17,078	)		1,742,260
Income (loss) from continuing operations before income taxes		(72,789	)		(86,731	)		(142,071	)		167,496			(134,095	)
Income tax expense (benefit)		—			(19,085	)		(17,107	)		—			(36,192	)
Subsidiary preferred stock dividend		—			—			750			—			750
Income (loss) from continuing operations, net of tax		(72,789	)		(67,646	)		(125,714	)		167,496			(98,653	)
Income (loss) from discontinued operations, net of tax		—			—			24,690			—			24,690
Net income (loss)		(72,789	)		(67,646	)		(101,024	)		167,496			(73,963	)
Less: Net (income) loss attributable to noncontrolling interest		—			—			1,174			—			1,174
Net income (loss) attributable to Nabors	$	(72,789	)	$	(67,646	)	$	(99,850	)	$	167,496		$	(72,789	)

30

	Three Months Ended June 30, 2011
(In thousands)	Nabors (Parent/ Guarantor)		Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Revenues and other income:
Operating revenues	$	—	$	—		$	1,343,642		$	—		$	1,343,642
Earnings (losses) from unconsolidated affiliates		—		—			9,308			—			9,308
Earnings (losses) from consolidated affiliates		195,770		18,971			(7,481	)		(207,260	)		—
Investment income (loss)		1		68			(1,044	)		—			(975	)
Intercompany interest income		—		17,405			—			(17,405	)		—
Total revenues and other income		195,771		36,444			1,344,425			(224,665	)		1,351,975
Costs and other deductions:
Direct costs		—		—			827,450			—			827,450
General and administrative expenses		3,120		49			120,005			(204	)		122,970
Depreciation and amortization		—		871			224,171			—			225,042
Interest expense		—		69,059			(5,304	)		—			63,755
Intercompany interest expense		—		—			17,405			(17,405	)		—
Losses (gains) on sales and retirements of long-lived assets and other expense (income), net		203		(344	)		4,285			204			4,348
Total costs and other deductions		3,323		69,635			1,188,012			(17,405	)		1,243,565
Income (loss) from continuing operations before income taxes		192,448		(33,191	)		156,413			(207,260	)		108,410
Income tax expense (benefit)		—		(19,300	)		56,073			—			36,773
Subsidiary preferred stock dividend		—		—			750			—			750
Income (loss) from continuing operations, net of tax		192,448		(13,891	)		99,590			(207,260	)		70,887
Income (loss) from discontinued operations, net of tax		—		—			121,167			—			121,167
Net income (loss)		192,448		(13,891	)		220,757			(207,260	)		192,054
Less: Net (income) loss attributable to noncontrolling interest		—		—			394			—			394
Net income (loss) attributable to Nabors	$	192,448	$	(13,891	)	$	221,151		$	(207,260	)	$	192,448

31

	Six Months Ended June 30, 2012
(In thousands)	Nabors (Parent/ Guarantor)		Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Revenues and other income:
Operating revenues	$	—	$	—		$	3,627,540		$	—		$	3,627,540
Earnings (losses) from unconsolidated affiliates		—		—			(202,986	)		—			(202,986	)
Earnings (losses) from consolidated affiliates		65,471		19,377			(33,576	)		(51,272	)		—
Investment income (loss)		—		16			25,604			—			25,620
Intercompany interest income		—		34,010			—			(34,010	)		—
Total revenues and other income		65,471		53,403			3,416,582			(85,282	)		3,450,174
Costs and other deductions:
Direct costs		—		—			2,308,072			—			2,308,072
General and administrative expenses		3,549		190			266,841			(622	)		269,958
Depreciation and amortization		—		1,805			506,832			—			508,637
Interest expense		—		136,436			(10,323	)		—			126,113
Intercompany interest expense		—		—			34,010			(34,010	)		—
Losses (gains) on sales and retirements of long-lived assets and other expense (income), net		621		(979	)		11,310			622			11,574
Impairments and other charges		—		—			147,503			—			147,503
Total costs and other deductions		4,170		137,452			3,264,245			(34,010	)		3,371,857
Income (loss) from continuing operations before income taxes		61,301		(84,049	)		152,337			(51,272	)		78,317
Income tax expense (benefit)		—		(38,268	)		71,120			—			32,852
Subsidiary preferred stock dividend		—		—			1,500			—			1,500
Income (loss) from continuing operations, net of tax		61,301		(45,781	)		79,717			(51,272	)		43,965
Income (loss) from discontinued operations, net of tax		—		—			15,895			—			15,895
Net income (loss)		61,301		(45,781	)		95,612			(51,272	)		59,860
Less: Net (income) loss attributable to noncontrolling interest		—		—			1,441			—			1,441
Net income (loss) attributable to Nabors	$	61,301	$	(45,781	)	$	97,053		$	(51,272	)	$	61,301

32

	Six Months Ended June 30, 2011
(In thousands)	Nabors (Parent/ Guarantor)		Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Revenues and other income:
Operating revenues	$	—	$	—		$	2,717,210		$	—		$	2,717,210
Earnings (losses) from unconsolidated affiliates		—		—			25,582			—			25,582
Earnings (losses) from consolidated affiliates		281,564		78,864			22,177			(382,605	)		—
Investment income (loss)		4		68			11,233			—			11,305
Intercompany interest income		—		36,089			—			(36,089	)		—
Total revenues and other income		281,568		115,021			2,776,202			(418,694	)		2,754,097
Costs and other deductions:
Direct costs		—		—			1,668,558			—			1,668,558
General and administrative expenses		5,993		90			233,140			(302	)		238,921
Depreciation and amortization		—		1,742			448,510			—			450,252
Interest expense		—		146,408			(8,687	)		—			137,721
Intercompany interest expense		—		—			36,089			(36,089	)		—
Losses (gains) on sales and retirements of long-lived assets and other expense (income), net		302		(808	)		10,711			302			10,507
Total costs and other deductions		6,295		147,432			2,388,321			(36,089	)		2,505,959
Income (loss) from continuing operations before income taxes		275,273		(32,411	)		387,881			(382,605	)		248,138
Income tax expense (benefit)		—		(41,172	)		122,371			—			81,199
Subsidiary preferred stock dividend		—		—			1,500			—			1,500
Income (loss) from continuing operations, net of tax		275,273		8,761			264,010			(382,605	)		165,439
Income (loss) from discontinued operations, net of tax		—		—			108,771			—			108,771
Net income (loss)		275,273		8,761			372,781			(382,605	)		274,210
Less: Net (income) loss attributable to noncontrolling interest		—		—			1,063			—			1,063
Net income (loss) attributable to Nabors	$	275,273	$	8,761		$	373,844		$	(382,605	)	$	275,273

33

Condensed Consolidating Statements of Other Comprehensive Income

	Three Months Ended June 30, 2012
(In thousands)	Nabors (Parent/ Guarantor)			Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Net income (loss) attributable to Nabors	$	(72,789	)	$	(67,646	)	$	(99,850	)	$	167,496		$	(72,789	)
Other comprehensive income (loss), before tax
Translation adjustment attributable to Nabors		(19,659	)		52			(19,606	)		19,554			(19,659	)
Unrealized gains/(losses) on marketable securities:
Unrealized gains/(losses) on marketable securities		(5,008	)		(52	)		(5,061	)		5,113			(5,008	)
Less: reclassification adjustment for (gains)/losses included in net income (loss)		(19	)		—			(19	)		19			(19	)
Unrealized gains (losses) on marketable securities		(5,027	)		(52	)		(5,080	)		5,132			(5,027	)
Defined benefit pension plans:
Pension liability amortization		260			260			520			(780	)		260
Pension liability adjustment		—			—			—			—			—
Defined benefit pension plans		260			260			520			(780	)		260
Unrealized gains/(losses) and amortization of (gains)/losses on cash flow hedges		191			191			191			(382	)		191
Other comprehensive income (loss), before tax		(24,235	)		451			(23,975	)		23,524			(24,235	)
Income tax expense related to items of other comprehensive income (loss)		140			140			220			(360	)		140
Other comprehensive income (loss), net of tax		(24,375	)		311			(24,195	)		23,884			(24,375	)
Comprehensive income (loss)		(97,164	)		(67,335	)		(124,045	)		191,380			(97,164	)
Net income (loss) attributable to noncontrolling interest		(1,174	)		—			(1,174	)		1,174			(1,174	)
Translation adjustment to noncontrolling interest		(216	)		—			(216	)		216			(216	)
Comprehensive income (loss) attributable to noncontrolling interest		(1,390	)		—			(1,390	)		1,390			(1,390	)
Comprehensive income (loss) attributable to Nabors	$	(98,554	)	$	(67,335	)	$	(125,435	)	$	192,770		$	(98,554	)

34

	Three Months Ended June 30, 2011
(In thousands)	Nabors (Parent/ Guarantor)			Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Net income (loss) attributable to Nabors	$	192,448		$	(13,891	)	$	221,151		$	(207,260	)	$	192,448
Other comprehensive income (loss), before tax
Translation adjustment attributable to Nabors		7,910			97			8,007			(8,104	)		7,910
Unrealized gains/(losses) on marketable securities:
Unrealized gains/(losses) on marketable securities		(11,192	)		18			(11,174	)		11,156			(11,192	)
Less: reclassification adjustment for (gains)/losses included in net income (loss)		2			—			2			(2	)		2
Unrealized gains (losses) on marketable securities		(11,190	)		18			(11,172	)		11,154			(11,190	)
Defined benefit pension plans:
Pension liability amortization		149			149			296			(445	)		149
Pension liability adjustment		—			—			—			—			—
Defined benefit pension plans		149			149			296			(445	)		149
Unrealized gains/(losses) and amortization of (gains)/losses on cash flow hedges		190			190			190			(380	)		190
Other comprehensive income (loss), before tax		(2,941	)		454			(2,679	)		2,225			(2,941	)
Income tax expense related to items of other comprehensive income (loss)		124			124			189			(313	)		124
Other comprehensive income (loss), net of tax		(3,065	)		330			(2,868	)		2,538			(3,065	)
Comprehensive income (loss)		189,383			(13,561	)		218,283			(204,722	)		189,383
Net income (loss) attributable to noncontrolling interest		(394	)		—			(394	)		394			(394	)
Translation adjustment to noncontrolling interest		95			—			95			(95	)		95
Comprehensive income (loss) attributable to noncontrolling interest		(299	)		—			(299	)		299			(299	)
Comprehensive income (loss) attributable to Nabors	$	189,084		$	(13,561	)	$	217,984		$	(204,423	)	$	189,084

35

	Six Months Ended June 30, 2012
(In thousands)	Nabors (Parent/ Guarantor)			Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Net income (loss) attributable to Nabors	$	61,301		$	(45,781	)	$	97,053		$	(51,272	)	$	61,301
Other comprehensive income (loss), before tax
Translation adjustment attributable to Nabors		(2,392	)		(1	)		(2,392	)		2,392			(2,393	)
Unrealized gains/(losses) on marketable securities:
Unrealized gains/(losses) on marketable securities		7,215			11			7,226			(7,237	)		7,215
Less: reclassification adjustment for (gains)/losses included in net income (loss)		(12,484	)		(10,288	)		(22,772	)		33,060			(12,484	)
Unrealized gains (losses) on marketable securities		(5,269	)		(10,277	)		(15,546	)		25,823			(5,269	)
Defined benefit pension plans:
Pension liability amortization		519			519			1,040			(1,558	)		520
Pension liability adjustment		—			—			—			—			—
Defined benefit pension plans		519			519			1,040			(1,558	)		520
Unrealized gains/(losses) and amortization of (gains)/losses on cash flow hedges		382			382			382			(764	)		382
Other comprehensive income (loss), before tax		(6,760	)		(9,377	)		(16,516	)		25,893			(6,760	)
Income tax expense related to items of other comprehensive income (loss)		(3,584	)		(3,584	)		(7,288	)		10,872			(3,584	)
Other comprehensive income (loss), net of tax		(3,176	)		(5,793	)		(9,228	)		15,021			(3,176	)
Comprehensive income (loss)		58,125			(51,574	)		87,825			(36,251	)		58,125
Net income (loss) attributable to noncontrolling interest		(1,441	)		—			(1,441	)		1,441			(1,441	)
Translation adjustment to noncontrolling interest		27			—			27			(27	)		27
Comprehensive income (loss) attributable to noncontrolling interest		(1,414	)		—			(1,414	)		1,414			(1,414	)
Comprehensive income (loss) attributable to Nabors	$	56,711		$	(51,574	)	$	86,411		$	(34,837	)	$	56,711

36

	Six Months Ended June 30, 2011
(In thousands)	Nabors (Parent/ Guarantor)			Nabors Delaware (Issuer/ Guarantor)		Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Net income (loss) attributable to Nabors	$	275,273		$	8,761	$	373,844		$	(382,605	)	$	275,273
Other comprehensive income (loss), before tax
Translation adjustment attributable to Nabors		39,349			76		39,426			(39,502	)		39,349
Unrealized gains/(losses) on marketable securities:
Unrealized gains/(losses) on marketable securities		(4,884	)		185		(4,697	)		4,512			(4,884	)
Less: reclassification adjustment for (gains)/losses included in net income (loss)		(1	)		—		(1	)		1			(1	)
Unrealized gains (losses) on marketable securities		(4,885	)		185		(4,698	)		4,513			(4,885	)
Defined benefit pension plans:
Pension liability amortization		300			300		598			(898	)		300
Pension liability adjustment		—			—		—			—			—
Defined benefit pension plans		300			300		598			(898	)		300
Unrealized gains/(losses) and amortization of (gains)/losses on cash flow hedges		381			381		381			(762	)		381
Other comprehensive income (loss), before tax		35,145			942		35,707			(36,649	)		35,145
Income tax expense related to items of other comprehensive income (loss)		306			306		493			(799	)		306
Other comprehensive income (loss), net of tax		34,839			636		35,214			(35,850	)		34,839
Comprehensive income (loss)		310,112			9,397		409,058			(418,455	)		310,112
Net income (loss) attributable to noncontrolling interest		(1,063	)		—		(1,063	)		1,063			(1,063	)
Translation adjustment to noncontrolling interest		452			—		452			(452	)		452
Comprehensive income (loss) attributable to noncontrolling interest		(611	)		—		(611	)		611			(611	)
Comprehensive income (loss) attributable to Nabors	$	309,501		$	9,397	$	408,447		$	(417,844	)	$	309,501

37

Condensed Consolidating Statements of Cash Flows

	Six Months Ended June 30, 2012
(In thousands)	Nabors (Parent/ Guarantor)			Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Net cash provided by (used for) operating activities	$	7,762		$	(93,075	)	$	809,750		$	(12,500	)	$	711,937
Cash flows from investing activities:
Purchases of investments		—			—			(795	)		—			(795	)
Sales and maturities of investments		—			—			25,517			—			25,517
Cash paid for acquisition of businesses, net		—			—			—			—			—
Capital expenditures		—			—			(967,861	)		—			(967,861	)
Proceeds from sales of assets and insurance claims		—			—			116,923			—			116,923
Cash paid for investments in consolidated affiliates		—			—			—			—			—
Net cash provided by (used for) investing activities		—			—			(826,216	)		—			(826,216	)
Cash flows from financing activities:
Increase (decrease) in cash overdrafts		—			—			(2,060	)		—			(2,060	)
Proceeds from revolving credit facilities		—			200,000			—			—			200,000
Proceeds from issuance of common shares		(5,066	)		—			—			—			(5,066	)
Debt issuance costs		—			—			(1,235	)		—			(1,235	)
Reduction in long-term debt		—			—			—			—			—
Paydown of revolving credit facilities		—			(100,000	)		(50,000	)		—			(150,000	)
Purchase of restricted stock		(2,071	)		—			—			—			(2,071	)
Tax benefit related to share-based awards		—			—			(36	)		—			(36	)
Proceeds from parent contributions		—			—			(12,500	)		12,500			—
Net cash (used for) provided by financing activities		(7,137	)		100,000			(65,831	)		12,500			39,532
Effect of exchange rate changes on cash and cash equivalents		—			—			(3,430	)		—			(3,430	)
Net (decrease) increase in cash and cash equivalents		625			6,925			(85,727	)		—			(78,177	)
Cash and cash equivalents, beginning of period		203			21			398,351			—			398,575
Cash and cash equivalents, end of period	$	828		$	6,946		$	312,624		$	—		$	320,398

38

	Six Months Ended June 30, 2011
(In thousands)	Nabors (Parent/ Guarantor)			Nabors Delaware (Issuer/ Guarantor)			Other Subsidiaries (Non— Guarantors)			Consolidating Adjustments			Consolidated Total
Net cash provided by (used for) operating activities	$	1,044		$	256,452		$	612,406		$	—		$	869,902
Cash flows from investing activities:
Purchases of investments		—			—			(7,945	)		—			(7,945	)
Sales and maturities of investments		—			—			20,622			—			20,622
Cash paid for acquisition of businesses, net		—			—			—			—			—
Investment in unconsolidated affiliates		—			—			(29,762	)		—			(29,762	)
Distribution of proceeds from asset sales from unconsolidated affiliates		—			—			119,207			—			119,207
Capital expenditures		—			—			(1,003,245	)		—			(1,003,245	)
Proceeds from sales of assets and insurance claims		—			—			102,067			—			102,067
Cash paid for investments in consolidated affiliates		(19,300	)		—			—			19,300			—
Net cash provided by (used for) investing activities		(19,300	)		—			(799,056	)		19,300			(799,056	)
Cash flows from financing activities:
Increase (decrease) in cash overdrafts		—			—			11,203			—			11,203
Proceeds from issuance of common shares		11,623			—			(1	)		—			11,622
Proceeds from revolving credit facilities		—			1,150,000			50,000						1,200,000
Debt issuance costs		—			(2,188	)		—			—			(2,188	)
Reduction in long-term debt		—			(1,404,247	)		—			—			(1,404,247	)
Repurchase of equity component of convertible debt		—			(14	)		—			—			(14	)
Purchase of restricted stock		(2,527	)		—			—			—			(2,527	)
Tax benefit related to share-based awards		—			(1	)		43			—			42
Proceeds from parent contributions		—			—			19,300			(19,300	)		—
Net cash (used for) provided by financing activities		9,096			(256,450	)		80,545			(19,300	)		(186,109	)
Effect of exchange rate changes on cash and cash equivalents		—			—			2,383			—			2,383
Net (decrease) increase in cash and cash equivalents		(9,160	)		2			(103,722	)		—			(112,880	)
Cash and cash equivalents, beginning of period		10,847			20			630,835			—			641,702
Cash and cash equivalents, end of period	$	1,687		$	22		$	527,113		$	—		$	528,822

39

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders

of Nabors Industries Ltd.:

We have reviewed the accompanying consolidated balance sheet of Nabors Industries Ltd. and its subsidiaries (the “Company”) as of June 30, 2012, and the related consolidated statements of income and other comprehensive income for the three-month and six-month periods ended June 30, 2012 and June 30, 2011 and the consolidated statements of cash flows and of changes in equity for the six-month periods ended June 30, 2012 and June 30, 2011. This interim financial information is the responsibility of the Company’s management.

We conducted our review in accordance with the standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

Based on our review, we are not aware of any material modifications that should be made to the accompanying consolidated interim financial information for it to be in conformity with accounting principles generally accepted in the United States of America.

We previously audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet as of December 31, 2011, and the related consolidated statements of income, changes in equity and of cash flows for the year then ended (not presented herein), and in our report dated February 29, 2012, we expressed an unqualified opinion on those consolidated financial statements. In our opinion, the information set forth in the accompanying consolidated balance sheet information as of December 31, 2011, is fairly stated in all material respects in relation to the consolidated balance sheet from which it has been derived.

/s/ PricewaterhouseCoopers LLP

Houston, Texas

August 3, 2012

40

ITEM 2. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FORWARD-LOOKING STATEMENTS

We often discuss expectations regarding our future markets, demand for our products and services, and our performance in our annual and quarterly reports, press releases, and other written and oral statements. Statements relating to matters that are not historical facts are “forward-looking statements” within the meaning of the safe harbor provisions of Section 27A of the Securities Act and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). These “forward-looking statements” are based on an analysis of currently available competitive, financial and economic data and our operating plans. They are inherently uncertain and investors should recognize that events and actual results could turn out to be significantly different from our expectations. By way of illustration, when used in this document, words such as “anticipate,” “believe,” “expect,” “plan,” “intend,” “estimate,” “project,” “will,” “should,” “could,” “may,” “predict” and similar expressions are intended to identify forward-looking statements.

You should consider the following key factors when evaluating these forward-looking statements:

• fluctuations in worldwide prices of and demand for natural gas and oil;

• fluctuations in levels of natural gas and oil exploration and development activities;

• fluctuations in the demand for our services;

• the existence of competitors, technological changes and developments in the oilfield services industry;

• the existence of operating risks inherent in the oilfield services industry;

• the possibility of changes in tax and other laws and regulations;

• the possibility of political instability, war or acts of terrorism; and

• general economic conditions including the capital and credit markets.

Our businesses depend to a large degree on the level of spending by oil and gas companies for exploration, development and production activities. Therefore, a sustained increase or decrease in the price of natural gas or oil that has a material impact on exploration, development or production activities could also materially affect our financial position, results of operations and cash flows.

The above description of risks and uncertainties is by no means all-inclusive, but is designed to highlight what we believe are important factors to consider. For a more detailed description of risk factors, please refer to Part I, Item 1A. — Risk Factors in our 2011 Annual Report.

Management Overview

The following discussion and analysis is intended to help the reader understand the results of our operations and our financial condition. This information is provided as a supplement to, and should be read in conjunction with, our consolidated financial statements and the accompanying notes thereto.

The majority of our business is conducted through our Drilling and Rig Services and our Completion and Production Services business lines. Our Drilling and Rig Services business line includes our drilling operations for oil and natural gas wells, on land and offshore, and companies engaged in drilling technology, top drive manufacturing, directional drilling, construction services, and rig instrumentation and software. Our Completion and Production Services business line includes our well-servicing, fluid logistics, workover operations and our pressure pumping services. In addition to these two primary business lines, we have an Oil and Gas operating segment. Our oil and gas exploration, development and production operations are included in our Oil and Gas operating segment, or in discontinued operations in some cases.

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The magnitude of customer spending on new and existing wells is the primary driver of our business. Our customers’ spending is determined principally by their internally generated cash flow and to a lesser extent by joint venture arrangements and funding from the capital markets. In our Drilling and Rig Services business lines, operations have traditionally been driven by natural gas prices, but the majority of current activity is being driven by the price of oil and natural gas liquids from unconventional reservoirs (shales). In our Completion and Production Services business line, operations are primarily driven by oil prices. The Henry Hub natural gas spot price (per Bloomberg) averaged $3.06 per thousand cubic feet (mcf) during the 12-month period ended June 30, 2012, down from $4.16 per mcf average during the prior 12 months. West Texas intermediate spot crude oil prices (per Bloomberg) averaged $94.91 per barrel for the 12 months ended June 30, 2012, up from $89.41 per barrel average during the preceding 12 months.

Operating revenues and Earnings (losses) from unconsolidated affiliates for the three months ended June 30, 2012 totaled $1.6 billion, representing an increase of $249.8 million, or 18%, as compared to the three months ended June 30, 2011, and $3.4 billion for the six months ended June 30, 2012, representing an increase of $681.8 million, or 25%, as compared to the six months ended June 30, 2011. Adjusted income derived from operating activities for the three and six months ended June 30, 2012 totaled $230.4 million and $551.6 million, respectively, representing increases of 30% and 43%, respectively, compared to the three and six months ended June 30, 2011. Net income (loss) from continuing operations for the three and six months ended June 30, 2012 totaled $(98.7) million ($(.34) per diluted share) and $44.0 million ($.16 per diluted share), respectively, representing decreases of 239% and 73%, respectively, compared to the three and six months ended June 30, 2011.

During the three and six months ended June 30, 2012, our net income (loss) from continuing operations was negatively impacted as a result of charges arising from oil and gas full-cost ceiling test writedowns and other impairments. Earnings (losses) from unconsolidated affiliates includes full-cost ceiling test writedowns of $68.2 million and $145.5 million, respectively, for the first and second quarters of 2012, representing our proportionate share of the writedowns. Net income (loss) from continuing operations was further negatively impacted as a result of impairments and other charges, which included $75.0 million to impair an intangible asset related to the Superior trade name, a provision for the retirement of long-lived assets totaling $46.2 million in multiple operating segments and goodwill impairment totaling $26.3 million.

Excluding these charges, our operating results improved as a result of increased demand for our services and products due to increased drilling activity in oil- and liquids-rich shale plays and increased well-servicing activity in the U.S. and Canada. This has more than offset the drop in demand from gas-related plays.

The lower price environment for natural gas has reduced activity in our gas-driven markets and is adversely impacting our pressure pumping business as the reduced activity has created a sooner than anticipated oversupply of pumping equipment. Directionally, similar forces are at work on land drilling in gas-driven markets but to a lesser degree. We anticipate a protracted weak spot market in pressure pumping operations and flat to slightly lower industry rig activity throughout 2012. While the U.S. Land Drilling and Pressure Pumping operating segments face these headwinds, we expect healthy operations in our remaining segments for the remainder of the year. The key factors supporting our views are:

• The current term contracts in both our Lower 48 Land Drilling and Pressure Pumping operating segments, combined with new and contracted rig deployments in 2012, will mitigate to a degree the continued reduction in gas drilling activity arising from weaker natural gas pricing;

• The increased activity expected in our International operations throughout the year as the result of new contracts for rig deployments in international markets; and

• An expected gradual improvement in our U.S. Offshore results as the pace of permit issuance improves and contribution from a new platform construction project increases throughout 2012.

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The following tables set forth certain information with respect to our reportable segments and rig activity:

	Three Months Ended June 30,											Six Months Ended June 30,
	2012			2011			Increase/ (Decrease)					2012			2011			Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues and Earnings (losses) from unconsolidated affiliates from continuing operations: (1)
Drilling and Rig Services:
U.S. Lower 48 Land Drilling	$	494,371		$	404,984		$	89,387		22	%	$	990,068		$	783,552		$	206,516		26	%
U.S. Offshore		71,978			40,284			31,694		79	%		141,093			70,738			70,355		99	%
Alaska		32,416			32,336			80		0	%		94,709			73,651			21,058		29	%
Canada		92,390			87,974			4,416		5	%		284,683			260,417			24,266		9	%
International		304,622			265,231			39,391		15	%		611,087			527,708			83,379		16	%
Other Rig Services(2)		228,614			155,246			73,368		47	%		470,372			272,035			198,337		73	%
Subtotal Drilling and Rig Services (3)		1,224,391			986,055			238,336		24	%		2,592,012			1,988,101			603,911		30	%
Completion and Production Services:
U.S. Land Well-servicing		214,005			164,140			49,865		30	%		423,706			314,396			109,310		35	%
Pressure Pumping		387,663			265,930			121,733		46	%		785,699			523,789			261,910		50	%
Subtotal Completion and Production Services		601,668			430,070			171,598		40	%		1,209,405			838,185			371,220		44	%
Oil and Gas (4)		(140,434	)		6,216			(146,650	)	n/m	(5)		(202,996	)		21,376			(224,372	)	n/m	(5)
Other reconciling items (6)		(82,828	)		(69,391	)		(13,437	)	(19	%)		(173,867	)		(104,870	)		(68,997	)	(66	%)
Total	$	1,602,797		$	1,352,950		$	249,847		18	%	$	3,424,554		$	2,742,792		$	681,762		25	%

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	Three Months Ended June 30,											Six Months Ended June 30,
	2012			2011			Increase/ (Decrease)					2012			2011			Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Adjusted income (loss) derived from operating activities from continuing operations: (1)(7)
Drilling and Rig Services:
U.S. Lower 48 Land Drilling	$	126,532		$	99,231		$	27,301		28	%	$	258,113		$	179,326		$	78,787		44	%
U.S. Offshore		9,924			(1,059	)		10,983		n/m	(5)		17,656			(5,036	)		22,692		451	%
Alaska		8,895			8,288			607		7	%		36,315			19,307			17,008		88	%
Canada		(3,718	)		(2,512	)		(1,206	)	(48	%)		45,569			36,480			9,089		25	%
International		16,401			35,851			(19,450	)	(54	%)		37,539			71,348			(33,809	)	(47	%)
Other Rig Services(2)		28,179			13,946			14,233		102	%		58,025			22,290			35,735		160	%
Subtotal Drilling and Rig Services (3)		186,213			153,745			32,468		21%			453,217			323,715			129,502		40	%
Completion and Production Services:
U.S. Land Well-servicing		28,599			16,526			12,073		73%			50,487			27,649			22,838		83	%
Pressure Pumping		46,144			43,888			2,256		5%			111,004			87,603			23,401		27	%
Subtotal Completion and Production Services		74,743			60,414			14,329		24%			161,491			115,252			46,239		40	%
Oil and Gas (8)		5,066			6,216			(1,150	)	(19%)			10,716			21,376			(10,660	)	(50	%)
Other reconciling items (9)		(35,609	)		(42,887	)		7,278		17%			(73,825	)		(75,282	)		1,457		2	%
	$	230,413		$	177,488		$	52,925		30%		$	551,599		$	385,061		$	166,538		43	%
Full-cost ceiling test writedowns		(145,500	)		—			(145,500	)	(100%)			(213,712	)		—			(213,712	)	(100	%)
Interest expense		(63,459	)		(63,755	)		296		0%			(126,113	)		(137,721	)		11,608		8	%
Investment income (loss)		5,368			(975	)		6,343		651%			25,620			11,305			14,315		127	%
Gains (losses) on sales and retirements of long-lived assets and other income (expense), net		(13,414	)		(4,348	)		(9,066	)	(209%)			(11,574	)		(10,507	)		(1,067	)	(10	%)
Impairment and other charges		(147,503	)		—			(147,503	)	(100%)			(147,503	)		—			(147,503	)	(100	%)
Income (loss) from continuing operations before income taxes		(134,095	)		108,410			(242,505	)	(224%)			78,317			248,138			(169,821	)	(68	%)

44

	Three Months Ended June 30,										Six Months Ended June 30,
	2012			2011		Increase/ (Decrease)					2012		2011		Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Income tax expense (benefit)		(36,192	)		36,773		(72,965	)	(198%)			32,852		81,199		(48,347	)	(60	%)
Subsidiary preferred stock dividend		750			750		—		0%			1,500		1,500		—		0	%
Income (loss) from continuing operations, net of tax		(98,653	)		70,887		(169,540	)	(239%)			43,965		165,439		(121,474	)	(73	%)
Income (loss) from discontinued operations, net of tax		24,690			121,167		(96,477	)	(80%)			15,895		108,771		(92,876	)	(85	%)
Net income (loss)		(73,963	)		192,054		(266,017	)	(139%)			59,860		274,210		(214,350	)	(78	%)
Less: Net (income) loss attributable to noncontrolling interest		1,174			394		780		198	%		1,441		1,063		378		36	%
Net income (loss) attributable to Nabors	$	(72,789	)	$	192,448	$	(265,237	)	(138%)		$	61,301	$	275,273	$	(213,972	)	(78	%)
Rig Activity:
Rig Years: (10)
U.S. Lower 48 Land Drilling		217.9			194.2		23.7		12	%		218.4		191.0		27.4		14	%
U.S. Offshore		14.0			9.4		4.6		49	%		13.0		8.7		4.3		49	%
Alaska		4.4			4.5		(.1	)	(2	%)		6.3		4.9		1.4		29	%
Canada		20.3			22.5		(2.2	)	(10	%)		34.5		36.1		(1.6	)	(4	%)
International (11)		120.9			102.8		18.1		18	%		119.3		101.2		18.1		18	%
Total rig years (3)		377.5			333.4		44.1		13	%		391.5		341.9		49.6		15	%
Rig Hours: (12)
U.S. Land Well-servicing		220,304			195,949		24,355		12	%		433,330		383,530		49,800		13	%
Canada Well-servicing		35,710			29,254		6,456		22	%		92,754		82,408		10,346		13	%
Total rig hours		256,014			225,203		30,811		14	%		526,084		465,938		60,146		13	%

(1) All periods present the operating activities of our wholly owned oil and gas business in the United States, Canada and Colombia, including equity interests in joint ventures in Canada and Colombia, as well as our aircraft logistics operations in Canada as discontinued operations.

(2) Includes our drilling technology and top drive manufacturing, directional drilling, rig instrumentation and software, and construction services. These services represent our other companies that are not aggregated into a reportable operating segment.

(3) Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $6.1 million and $3.1 million for the three months ended June 30, 2012 and 2011, respectively, and $4.2 million for the six months ended June 30, 2011.

(4) Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $(140.4) million and $6.2 million for the three months ended June 30, 2012 and 2011, respectively, and $(203.0) million and $21.4 million for the six months ended June 30, 2012 and 2011, respectively.

(5) This number is so large that it is meaningless.

(6) Represents the elimination of inter-segment transactions.

(7) Adjusted income (loss) derived from operating activities is computed by subtracting direct costs, general and administrative expenses, and depreciation and amortization from Operating revenues and then adding Earnings

45

(losses) from unconsolidated affiliates (excluding our proportionate share of full-cost ceiling test writedowns recorded by our oil and gas joint venture). These amounts should not be used as a substitute for those amounts reported in accordance with GAAP. However, management evaluates the performance of our business units and the consolidated company based on several criteria, including adjusted income (loss) derived from operating activities, because it believes that these financial measures accurately reflect our ongoing profitability. A reconciliation of this non-GAAP measure to income (loss) from continuing operations before income taxes, which is a GAAP measure, is provided in the above table.

(8) Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $5.1 million (excluding our proportionate share of the full-cost ceiling test writedowns totaling $145.5 million) and $6.2 million for the three months ended June 30, 2012 and 2011, respectively, and $10.7 million (excluding our proportionate share of the full-cost ceiling test writedowns totaling $213.7 million) and $21.4 million for the six months ended June 30, 2012 and 2011, respectively.

(9) Represents the elimination of inter-segment transactions and unallocated corporate expenses.

(10) Excludes well-servicing rigs, which are measured in rig hours. Includes our equivalent percentage ownership of rigs owned by unconsolidated affiliates. Rig years represent a measure of the number of equivalent rigs operating during a given period. For example, one rig operating 182.5 days during a 365-day period represents 0.5 rig years.

(11) International rig years include our equivalent percentage ownership of rigs owned by unconsolidated affiliates, which totaled 2.5 years and 2.0 years during the three months ended June 30, 2012 and 2011, respectively, and 2.5 years and 2.0 years during the six months ended June 30, 2012 and 2011, respectively.

(12) Rig hours represents the number of hours that our well-servicing rig fleet operated during the specified periods.

Segment Results of Operations

Drilling and Rig Services

Our Drilling and Rig Services operations contain one or more of the following operations: drilling on land and offshore, drilling technology, top drive manufacturing, directional drilling, construction services, and rig instrumentation and software.

U.S. Lower 48 Land Drilling. The results of operations for this segment were as follows:

	Three Months Ended June 30,								Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)				2012		2011		Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues	$	494,371	$	404,984	$	89,387	22	%	$	990,068	$	783,552	$	206,516	26	%
Adjusted income derived from operating activities	$	126,532	$	99,231	$	27,301	28	%	$	258,113	$	179,326	$	78,787	44	%
Rig years		217.9		194.2		23.7	12	%		218.4		191.0		27.4	14	%

Operating results increased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods primarily due to higher average day rates and increased drilling activity, driven by deployment of rigs into oil-rich shale areas. The increase was partially offset by an increase in operating costs associated with drilling activity, as well as higher depreciation expense related to new rigs placed into service during the past year.

46

U.S. Offshore. The results of operations for this segment were as follows:

	Three Months Ended June 30,									Six Months Ended June 30,
	2012		2011			Increase/ (Decrease)				2012		2011			Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues	$	71,978	$	40,284		$	31,694	79	%	$	141,093	$	70,738		$	70,355	99	%
Adjusted income derived from operating activities	$	9,924	$	(1,059	)	$	10,983	n/m	(1)	$	17,656	$	(5,036	)	$	22,692	451	%
Rig years		14.0		9.4			4.6	49	%		13.0		8.7			4.3	49	%

(1) The number is so large that it is meaningless.

Operating results increased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods resulting primarily from higher utilization for the MODS^® rigs, SuperSundowner^TM platform rigs, and workover jackup rigs, as well as from profits related to a major construction project. Demand for our rigs has increased substantially as operators have obtained permits for drilling operations in the Gulf of Mexico, the issuance of which had been subject to lengthy delays since the Macondo blowout in the Gulf of Mexico in mid-2010.

Alaska. The results of operations for this segment were as follows:

	Three Months Ended June 30,									Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)					2012		2011		Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues	$	32,416	$	32,336	$	80		0	%	$	94,709	$	73,651	$	21,058	29	%
Adjusted income derived from operating activities	$	8,895	$	8,288	$	607		7	%	$	36,315	$	19,307	$	17,008	88	%
Rig years		4.4		4.5		(.1	)	(2	%)		6.3		4.9		1.4	29	%

The increase in operating results during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods was due to higher average dayrates and increased drilling activity, driven primarily by an overall increase in winter exploration activity in the first and second quarters of 2012.

Canada. The results of operations for this segment were as follows:

	Three Months Ended June 30,											Six Months Ended June 30,
	2012			2011			Increase/ (Decrease)					2012		2011		Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues	$	92,390		$	87,974		$	4,416		5	%	$	284,683	$	260,417	$	24,266		9	%
Adjusted income (loss) derived from operating activities	$	(3,718	)	$	(2,512	)	$	(1,206	)	(48	%)	$	45,569	$	36,480	$	9,089		25	%
Rig years		20.3			22.5			(2.2	)	(10	%)		34.5		36.1		(1.6	)	(4	%)
Rig hours		35,710			29,254			6,456		22	%		92,754		82,408		10,346		13	%

Operating revenues increased during the three and six months ended June 30, 2012 as compared to the corresponding 2011 periods as a result of an overall increase in drilling rates and production services activity. Drilling average dayrates in 2012, particularly in Western Canada, driven by renewed interest in oil exploration, are supported by strong oil commodity prices. The production services hourly rates during the three and six months ended June 30, 2012 are in line with the corresponding 2011 periods. Adjusted income derived from operating activities decreased during the three months ended June 30, 2012 as compared to the 2011 corresponding quarter as a result of lower drilling margins resulting from higher costs.

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International. The results of operations for this segment were as follows:

	Three Months Ended June 30,									Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)					2012		2011		Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues and Earnings from unconsolidated affiliates	$	304,622	$	265,231	$	39,391		15	%	$	611,087	$	527,708	$	83,379		16	%
Adjusted income derived from operating activities	$	16,401	$	35,851	$	(19,450	)	(54	%)	$	37,539	$	71,348	$	(33,809	)	(47	%)
Rig years		120.9		102.8		18.1		18	%		119.3		101.2		18.1		18	%

Operating revenues and Earnings from unconsolidated affiliates increased during the three and six months ended June 30, 2012 as compared to the corresponding 2011 periods as a result of an increase in the utilization of our overall rig fleet, partially offset by lower margins. Adjusted income derived from operating activities decreased during the three and six months ended June 30, 2012 as compared to the corresponding 2011 periods primarily due to decreases in average dayrates and lower utilization of our jackup rigs in Saudi Arabia, lower offshore activity in Congo, and lower margins in Iraq.

Other Rig Services. The results of operations for this segment were as follows:

	Three Months Ended June 30,								Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)				2012		2011		Increase/ (Decrease)
	(In thousands, except percentages)
Operating revenues and Earnings from unconsolidated affiliates	$	228,614	$	155,246	$	73,368	47	%	$	470,372	$	272,035	$	198,337	73	%
Adjusted income derived from operating activities	$	28,179	$	13,946	$	14,233	102	%	$	58,025	$	22,290	$	35,735	160	%

Operating results for our Canrig business increased during the three and six months ended June 30, 2012 as compared to the corresponding 2011 periods primarily due to increased demand in the United States and Canada drilling markets. Our operating results reflect higher third-party rental of capital equipment and higher sales of RIGWATCH^TM software and ROCKIT^TM directional drilling systems, as well as higher top-drive rental sales.

Additionally, operating results increased for our construction and rig-moving business in Alaska during the three and six months ended June 30, 2012 as compared to the corresponding 2011 periods primarily due to an overall increase in the 2012 winter exploration activity. The increases were partially offset by decreased demand for our directional drilling business. Operating costs in the U.S. remained consistent with 2011 levels, while operating costs in Canada decreased during the first half of 2012.

Completion and Production Services

Our Completion and Production Services operations contain one or more of the following operations in the U.S. and Canada: well-servicing, fluid logistics, workover operations and pressure pumping services.

U.S. Land Well-servicing. The results of operations for this segment were as follows:

	Three Months Ended June 30,								Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)				2012		2011		Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues	$	214,005	$	164,140	$	49,865	30	%	$	423,706	$	314,396	$	109,310	35	%
Adjusted income derived from operating activities	$	28,599	$	16,526	$	12,073	73	%	$	50,487	$	27,649	$	22,838	83	%
Rig hours		220,304		195,949		24,355	12	%		433,330		383,530		49,800	13	%

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Operating results increased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods primarily due to an increase in rig and truck utilization facilitated by capital invested over the past few years to increase our rig and truck fleets as well as frac tanks. Higher equipment utilization and price improvements were driven primarily by sustained higher oil prices.

Pressure Pumping. The results of operations for this segment were as follows:

	Three Months Ended June 30,								Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)				2012		2011		Increase/ (Decrease)
	(In thousands, except percentages and rig activity)
Operating revenues	$	387,663	$	265,930	$	121,733	46	%	$	785,699	$	523,789	$	261,910	50	%
Adjusted income derived from operating activities	$	46,144	$	43,888	$	2,256	5	%	$	111,004	$	87,603	$	23,401	27	%

Operating results increased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods primarily due to the increased levels of fracturing activity and associated increase in our assets deployed in the major producing areas in the United States.

Oil and Gas. The results from our U.S. oil and gas unconsolidated affiliate were as follows:

	Three Months Ended June 30,										Six Months Ended June 30,
	2012			2011		Increase/ (Decrease)					2012			2011		Increase/ (Decrease)
	(In thousands, except percentages)
Earnings (losses) from unconsolidated affiliate	$	(140,434	)	$	6,216	$	(146,650	)	n/m	(1)	$	(202,996	)	$	21,376	$	(224,372	)	n/m	(1)
Adjusted income derived from operating activities	$	5,066		$	6,216	$	(1,150	)	(19	%)	$	10,716		$	21,376	$	(10,660	)	(50	%)

(1) The number is so large that it is meaningless.

Earnings (losses) from unconsolidated affiliate decreased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods primarily as a result of full-cost ceiling test writedowns during the first quarter and second quarters of 2012, of which our proportionate share totaled $68.2 million and $145.5 million, respectively. Excluding the writedowns, the operating results for this same joint venture decreased during the first half of 2012 as compared to 2011 due to sustained lower natural gas prices. Adjusted income derived from operating activities excludes the impact of the full-cost ceiling test writedowns for the three and six months ended June 30, 2012. There were no such writedowns during the six months ended June 30, 2011.

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Discontinued Operations

Our condensed statements of income (loss) from discontinued oil and gas operations for the three and six months ended June 30, 2012 and 2011 were as follows:

	Three Months Ended June 30,											Six Months Ended June 30,
	2012			2011			Increase/ (Decrease)					2012			2011			Increase/ (Decrease)
	(In thousands, except percentages)
Operating revenues and Earnings from unconsolidated affiliate
Oil and Gas	$	2,919		$	9,397		$	(6,478	)	(69	%)	$	6,220		$	20,816		$	(14,596	)	(70	%)
Other Rig Services(1)	$	5,554		$	7,245		$	(1,691	)	(23	%)	$	10,416		$	11,839		$	(1,423	)	(12	%)
Income (loss) from discontinued operations, net of tax
Oil and Gas	$	31,764		$	122,296		$	(90,532	)	(74	%)	$	23,962		$	111,420		$	(87,458	)	(78	%)
Other Rig Services(1)	$	(7,074	)	$	(1,129	)	$	(5,945	)	(527	%)	$	(8,067	)	$	(2,649	)	$	(5,418	)	(205	%)

(1) Represents our aircraft logistics operations in Canada included in our Other Rig Services operating segment.

In April 2012, we sold our remaining wholly owned oil and gas business in Colombia to an unrelated third party for a cash purchase price of $72.6 million, which resulted in a pre-tax gain of approximately $48.5 million. These assets were included in our assets held for sale as part of our Oil and Gas operating segment.

In May 2012, we sold some of our U.S. wholly owned oil and gas business in the Fayetteville Shale, Floyd Shale, and Barnett Shale areas to unrelated third parties for cumulative cash receipts of $5.7 million, which did not result in any gain or loss. These assets were included in our assets held for sale as part of our Oil and Gas operating segment. Based on current market conditions and our assessment of the sales price, we adjusted the carrying value of our U.S. wholly owned oil and gas business by $7.2 million in the second quarter of 2012 to reflect their estimated sales price or current fair value.

Based on current market conditions and our assessment of the sales price, we adjusted the carrying value of our aircraft logistics assets by $5.2 million in the second quarter of 2012 to reflect their estimated sales price or current fair value.

OTHER FINANCIAL INFORMATION

General and administrative expenses

	Three Months Ended June 30,											Six Months Ended June 30,
	2012			2011			Increase/ (Decrease)					2012			2011			Increase/ (Decrease)
							(In thousands, except percentages)
General and administrative expenses	$	133,612		$	122,970		$	10,642		9	%	$	269,958		$	238,921		$	31,037		13	%
General and administrative expenses as a percentage of operating revenues		7.7	%		9.2	%		(1.5	%)	(16	%)		7.4	%		8.8	%		(1.4	%)	(16	%)

General and administrative expenses increased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods primarily as a result of increases in wages to support a higher headcount as a result of increased operations for a majority of our operating segments. As a percentage of operating revenues, general and administrative expenses decreased from the 2012 periods to corresponding periods of 2011.

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Depreciation and amortization

	Three Months Ended June 30,								Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)				2012		2011		Increase/ (Decrease)
	(In thousands, except percentages)
Depreciation and amortization expense	$	261,016	$	225,042	$	35,974	16	%	$	508,637	$	450,252	$	58,385	13	%

Depreciation and amortization expense increased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods primarily as a result of the incremental depreciation expense from (i) newly constructed rigs recently placed into service, (ii) additional completion and production services assets and (iii) rig upgrades and other capital expenditures made during 2011 and 2012.

Interest expense

	Three Months Ended June 30,									Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)					2012		2011		Increase/ (Decrease)
	(In thousands, except percentages)
Interest expense	$	63,459	$	63,755	$	(296	)	(.5	%)	$	126,113	$	137,721	$	(11,608	)	(8.4	%)

Interest expense decreased during the three and six months ended June 30, 2012 compared to the corresponding 2011 periods primarily as a result of the redemption in May 2011 of $1.4 billion 0.94% senior exchangeable notes. The decrease was partially offset by additional interest related to our August 2011 issuance of 4.625% senior notes due September 2021 and interest on amounts outstanding on our revolving credit facilities.

Investment income (loss)

	Three Months Ended June 30,									Six Months Ended June 30,
	2012		2011			Increase/ (Decrease)				2012		2011		Increase/ (Decrease)
	(In thousands, except percentages)
Investment income (loss)	$	5,368	$	(975	)	$	6,343	651	%	$	25,620	$	11,305	$	14,315	127	%

Investment income for the three months ended June 30, 2012 included (i) net unrealized gains of $1.4 million from our trading securities, (ii) interest and dividend income of $3.6 million from our cash, other short-term and long-term investments and (iii) realized gains of $.4 million from other long-term investments.

Investment income for the six months ended June 30, 2012 included (i) a $12.5 million realized gain related to the sale of some of our debt securities, (ii) net unrealized gains of $7.4 million from our trading securities, (iii) interest and dividend income of $5.0 million from our cash, other short-term and long-term investments and (iv) realized gains of $.7 million from other long-term investments.

Investment loss for the three months ended June 30, 2011 included unrealized losses of $3.4 million from our trading securities, partially offset by interest and dividend income of $2.0 million from our cash, other short-term and long-term investments and realized gains of $.5 million from other long-term investments.

Investment income for the six months ended June 30, 2011 included (i) a $12.9 million realized gain recorded in the first quarter of 2011 relating to one of our overseas fund investments classified as long-term investments, (ii) $1.3 million realized gains from other long-term investments and (iii) $3.8 million interest and dividend income from our cash, other short-term and long-term investments. Investment income was partially offset by net unrealized losses of $6.7 million from our trading securities.

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Gains (losses) on sales and retirements of long-lived assets and other income (expense), net

	Three Months Ended June 30,											Six Months Ended June 30,
	2012			2011			Increase/ (Decrease)					2012			2011			Increase/ (Decrease)
	(In thousands, except percentages)
Gains (losses) on sales and retirements of long-lived assets and other income (expense), net	$	(13,414	)	$	(4,348	)	$	(9,066	)	(209	%)	$	(11,574	)	$	(10,507	)	$	(1,067	)	(10	%)

The amount of gains (losses) on sales and retirements of long-lived assets and other income (expense), net for the three and six months ended June 30, 2012 was primarily comprised of net losses on sales and retirements of long-lived assets of approximately $6.0 million and $4.2 million, respectively, and net increases to our litigation reserves of $5.0 million and $5.5 million, respectively.

The amount of gains (losses) on sales and retirements of long-lived assets and other income (expense), net for the three and six months ended June 30, 2011 was primarily comprised of net increases to our litigation reserves of $4.0 million and $9.9 million, respectively.

Impairments and other charges

	Three Months Ended June 30,								Six Months Ended June 30,
	2012		2011		Increase/ (Decrease)				2012		2011		Increase/ (Decrease)
	(In thousands, except percentages)
Impairments and other charges	$	147,503	$	—	$	147,503	100	%	$	147,503	$	—	$	147,503	100	%

The amount of impairments and other charges for the three and six months ended June 30, 2012 included: (i) $26.3 million from goodwill impairment associated with our U.S. Offshore and International reporting units, (ii) $75.0 million related to the impairment of the Superior trade name, and (iii) $46.2 million for a provision for retirement of long-lived assets in our Canada, U.S. Well-servicing and Pressure Pumping Operating Segments.

The impairment of goodwill related to our U.S. Offshore and International reporting units. As of June 30, 2012, these reporting units had no recorded goodwill. The impairments were deemed necessary due to the prolonged uncertainty of utilization of some of our rigs as a result of changes in our customers’ plans for future drilling operations in the Gulf of Mexico as well as our international markets.

The Superior trade name was initially classified as a ten-year intangible asset at the date of acquisition in September 2010. The impairment is a result of the decision to cease using the Superior trade name to reduce confusion in the marketplace and enhance the Nabors brand.

Our provision for retirement of long-lived assets included (i) $15.1 million to Canada operations for functionally obsolete or inoperable rigs, (ii) $4.6 million to our U.S. Well-servicing operations for assets that would require significant repair to return to work and (iii) $26.5 million to our Pressure Pumping operations for non-core assets as we streamline our business lines and consolidate our Pressure Pumping and U.S. Well-servicing segments into one business line, Nabors Completion and Production Services. As a result, we decided to retire these assets. As we continue to streamline our lines of business, there could be future retirement or impairment charges, which could have a potential impact on our future operating results. In addition, a prolonged period of lower natural gas and oil prices and its potential impact on our utilization and dayrates could result in the recognition of future impairment charges to additional assets if future cash flow estimates, based upon information then available to management, indicate that the carrying value of those assets may not be recoverable.

For additional information on the foregoing, see Note 2 – Summary of Significant Accounting Policies and Note 3 – Impairments and Other Charges.

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Income tax rate

	Three Months Ended June 30,											Six Months Ended June  30,
	2012			2011			Increase/ (Decrease)					2012			2011			Increase/ (Decrease)
Effective income tax rate from continuing operations		27	%		34	%		(7	%)	(21	%)		42	%		33	%		9	%	27	%

While our effective income tax rate during the three and six months ended June 30, 2012 fluctuates substantially when compared to the corresponding 2011 periods, the fluctuations are primarily a result of the proportion of income generated in the United States during each of these periods. Income generated in the United States is generally taxed at a higher rate than that of other jurisdictions.

We are subject to income taxes in the United States and numerous other jurisdictions. Significant judgment is required in determining our worldwide provision for income taxes. One of the most volatile factors in this determination is the relative proportion of our income or loss being recognized in high- versus low-tax jurisdictions. In the ordinary course of our business, there are many transactions and calculations for which the ultimate tax determination is uncertain. We are regularly audited by tax authorities. Although we believe our tax estimates are reasonable, the final outcome of tax audits and any related litigation could be materially different than what is reflected in our income tax provisions and accruals. The results of an audit or litigation could materially affect our financial position, income tax provision, net income, or cash flows.

Various bills have been introduced in Congress that could reduce or eliminate the tax benefits associated with our reorganization as a Bermuda company. Legislation enacted by Congress in 2004 provides that a corporation that reorganized in a foreign jurisdiction on or after March 4, 2003 be treated as a domestic corporation for U.S. federal income tax purposes. Nabors’ reorganization was completed on June 24, 2002. There has been and we expect that there may continue to be legislation proposed by Congress from time to time which, if enacted, could limit or eliminate the tax benefits associated with our reorganization.

Because we cannot predict whether any legislation will ultimately be adopted, no assurance can be given that the tax benefits associated with our reorganization will ultimately accrue to the benefit of the Company and its shareholders. It is possible that future changes to the tax laws (including tax treaties) could impact our ability to realize the tax savings recorded to date as well as future tax savings resulting from our reorganization.

Liquidity and Capital Resources

Cash Flows

Our cash flows depend, to a large degree, on the level of spending by oil and gas companies for exploration, development and production activities. Sustained increases or decreases in the price of natural gas or oil could have a material impact on these activities, and could also materially affect our cash flows. Certain sources and uses of cash, such as the level of discretionary capital expenditures, purchases and sales of investments, issuances and repurchases of debt and of our common shares are within our control and are adjusted as necessary based on market conditions. The following is a discussion of our cash flows for the six months ended June 30, 2012 and 2011.

Operating Activities. Net cash provided by operating activities totaled $711.9 million during the six months ended June 30, 2012 compared to net cash provided by operating activities of $869.9 million during the corresponding 2011 period. Net cash provided by operating activities is our primary source of capital and liquidity. Factors affecting changes in operating cash flows are largely the same as those that affect net earnings, with the exception of non-cash expenses such as depreciation and amortization, impairments and other charges, share-based compensation, deferred income taxes and our proportionate share of earnings or losses from unconsolidated affiliates. Net income (loss) adjusted for non-cash components was approximately $871.5 million and $680.2 million for the six months ended June 30, 2012 and 2011, respectively. Additionally, changes in working capital items such as increases or decreases in receivables or payables can be a significant factor in the determination of operating cash flows. Changes in working capital items used $159.6 million and provided $189.7 million, respectively, in cash flows for the six months ended June 30, 2012 and 2011.

53

Investing Activities. Net cash used for investing activities totaled $826.2 million during the six months ended June 30, 2012 compared to net cash used for investing activities of $799.1 million during the corresponding 2011 period. The primary use of cash for investing activities is for capital expenditures related to rig-related enhancements, new construction and equipment, as well as sustaining capital expenditures. During the six months ended June 30, 2012 and 2011, we used cash for capital expenditures totaling $967.9 million and $1.0 billion, respectively.

During the six months ended June 30, 2012, cash of $116.9 million was provided in proceeds from sales of assets and recoveries from insurance claims. During the six months ended June 30, 2012, cash of $25.5 million was provided from sales of investments. Additionally during the six months ended June 30, 2011, we received a distribution of $119.2 million from an unconsolidated affiliate related to proceeds they received from the sale of some of their oil and gas assets. During the six months ended June 30, 2011, we provided cash of $29.8 million to our unconsolidated affiliates.

Financing Activities. Net cash provided by financing activities totaled $39.5 million during the six months ended June 30, 2012 and consists primarily of amounts drawn from our revolving credit facilities. Net cash used for financing activities was $186.1 million during the corresponding 2011 period. During the six months ended June 30, 2011, we used $1.2 billion in proceeds from our revolving credit facilities to redeem $1.4 billion of our 0.94% senior exchangeable notes.

Future Cash Requirements

In August 2012, Nabors Delaware’s 5.375% senior notes totaling $275.0 million are due. We intend to utilize cash on hand and capacity under our revolving credit facilities to meet this obligation.

We expect capital expenditures over the next 12 months to approximate $1.2 billion. We had outstanding purchase commitments of approximately $.8 billion at June 30, 2012, primarily for rig-related enhancements, new construction and equipment, as well as sustaining capital expenditures, other operating expenses and purchases of inventory. This amount could change significantly based on market conditions and new business opportunities. The level of our outstanding purchase commitments and our expected level of capital expenditures over the next 12 months represent a number of capital programs that are currently underway or planned. These programs will result in an expansion in the number of land drilling rigs, pressure pumping and well-servicing equipment that we own and operate. We can reduce the planned expenditures if necessary, or increase them if market conditions and new business opportunities warrant it.

We have historically completed a number of acquisitions and will continue to evaluate opportunities to acquire assets or businesses to enhance our operations. Several of our previous acquisitions were funded through issuances of debt or our common shares. Future acquisitions may be paid for using existing cash or by issuing debt or additional shares of our stock. Such capital expenditures and acquisitions will depend on our view of market conditions and other factors.

Our discontinued operations include our contracts with pipeline companies include pipeline transmission commitments in the Horn River Basin. During the year ended December 31, 2011, we evaluated current production levels, natural gas prices and the anticipated sales cycle related to the sale of properties corresponding to these commitments. As a result, we recorded liabilities for excess pipeline capacity. Our consolidated balance sheets included current liabilities related to discontinued operations of $63.9 million and $54.3 million that were included in accrued liabilities and noncurrent liabilities related to discontinued operations of $35.3 million and $71.4 million that were included in other long-term liabilities at June 30, 2012 and December 31, 2011, respectively. These amounts represent our best estimate of the excess capacity of the pipeline, based upon the estimated sales date of the properties, as compared to the contractual commitments. Our commitments beyond December 31, 2013 could approximate $265.4 million if the related properties are not sold or developed. Decreases in actual production, natural gas prices or a change in the estimated sales date could result in future charges related to excess capacity of the pipeline that may materially impact our results of operations.

54

See our discussion of guarantees issued by Nabors that could have a potential impact on our financial position, results of operations or cash flows in future periods included below under Off-Balance Sheet Arrangements (Including Guarantees).

There have been no significant changes to our contractual cash obligations table which was included in our 2011 Annual Report.

We may from time to time seek to retire or purchase our outstanding debt through cash purchases and/or exchanges for equity securities, both in open-market purchases, privately negotiated transactions or otherwise. Such repurchases or exchanges, if any, will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.

See Note 18 – Commitments and Contingencies in our 2011 Annual Report for discussion of commitments and contingencies relating to (i) our employment agreement with Mr. Petrello that could result in a cash payment of $50 million by the Company if his employment were terminated in the event of his death or disability or a cash payment of approximately $31.1 million if his employment were terminated without cause or in the event of a change in control and (ii) off-balance sheet arrangements (including guarantees).

Financial Condition and Sources of Liquidity

Our primary sources of liquidity are operating cash flows, cash and cash equivalents, short-term and long-term investments and availability under our various revolving credit facilities. As of June 30, 2012, we had cash and short-term investments of $455.2 million and working capital of $1.5 billion. We also had $490 million of availability remaining from a combined total of $1.4 billion under revolving credit facilities. As of December 31, 2011, we had cash and short-term investments of $539.5 million and working capital of $1.3 billion.

During the three months ended June 30, 2012, we sold our remaining wholly owned oil and gas business in Colombia and some of our U.S. wholly owned oil and gas business for cumulative cash receipts of $78.3 million.

We had seven letter-of-credit facilities with various banks as of June 30, 2012. Availability under these facilities as of June 30, 2012 was as follows:

	(In thousands)
Credit available	$	290,900
Less: Letters of credit outstanding, inclusive of financial and performance guarantees		73,714
Remaining availability	$	217,186

Our revolving credit facilities contain various covenants and restrictive provisions that limit our ability to incur additional indebtedness, make investments or loans and create liens and require us to maintain the net funded indebtedness to total capitalization ratio, as defined in each agreement, at certain levels. We were in compliance with all covenants under the agreement at June 30, 2012.

Our ability to access capital markets or to otherwise obtain sufficient financing is enhanced by our senior unsecured debt ratings as provided by Fitch Ratings, Moody’s Investors Service and Standard & Poor’s and our historical ability to access those markets as needed. While there can be no assurances that we will be able to access these markets in the future, we believe that we will be able to access capital markets or otherwise obtain financing in order to satisfy any payment obligation that might arise upon purchase of our notes, payment of other debt and that any cash payment due, in addition to our other cash obligations, would not ultimately have a material adverse impact on our liquidity or financial position. A credit downgrade may impact our ability to access credit markets.

Our gross funded debt to capital ratio was 0.42:1 as of June 30, 2012 and 0.43:1 as of December 31, 2011. Our net funded debt to capital ratio was 0.40:1 as of each June 30, 2012 and December 31, 2011.

The gross funded debt to capital ratio is calculated by dividing (x) funded debt by (y) funded debt plus deferred tax liabilities (net of deferred tax assets) plus capital. Funded debt is the sum of (1) short-term borrowings, (2) the current portion of long-term debt and (3) long-term debt. Capital is shareholders’ equity.

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The net funded debt to capital ratio is calculated by dividing (x) net funded debt by (y) net funded debt plus deferred tax liabilities (net of deferred tax assets) plus capital. Net funded debt is funded debt minus the sum of cash and cash equivalents and short-term investments. Both of these ratios are used to calculate a company’s leverage in relation to its capital. Neither ratio measures operating performance or liquidity as defined by GAAP and, therefore, may not be comparable to similarly titled measures presented by other companies.

Our interest coverage ratio was 8.6:1 as of June 30, 2012 and 8.1:1 as of December 31, 2011. The interest coverage ratio is a trailing 12-month quotient of the sum of (x) income (loss) from continuing operations, net of tax, net income (loss) attributable to noncontrolling interest, interest expense, subsidiary preferred stock dividends, depreciation and amortization, income tax expense (benefit) and our proportionate share of writedowns from our unconsolidated oil and gas joint venture less investment income (loss) divided by (y) the sum of cash interest expense and subsidiary preferred stock dividends. This ratio is a method for calculating the amount of operating cash flows available to cover cash interest expense. The interest coverage ratio is not a measure of operating performance or liquidity defined by GAAP and may not be comparable to similarly titled measures presented by other companies.

Our current cash and investments, projected cash flows from operations, possible dispositions of non-core assets and our revolving credit facilities are expected to adequately finance our purchase commitments, scheduled debt service requirements, and all other expected cash requirements for the next 12 months.

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

We may be exposed to market risk through changes in interest rates and foreign-currency risk arising from our operations in international markets as discussed in our 2011 Annual Report.

ITEM 4. CONTROLS AND PROCEDURES

(a) Disclosure Controls and Procedures. We maintain a set of disclosure controls and procedures designed to provide reasonable assurance that information required to be disclosed in our reports filed under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms. We have investments in certain unconsolidated entities that we do not control or manage. Because we do not control or manage these entities, our disclosure controls and procedures with respect to these entities are necessarily more limited than those we maintain with respect to our consolidated subsidiaries.

The Company’s management, with the participation of the Company’s Chairman, President and Chief Executive Officer and its Principal Accounting and Financial Officer (the “reviewing officers”), has evaluated the effectiveness of the Company’s disclosure controls and procedures (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of the end of the period covered by this report. Based on this evaluation, the reviewing officers have concluded that, as of the end of the period, the Company’s disclosure controls and procedures are effective, at the reasonable assurance level, in recording, processing, summarizing and reporting, on a timely basis, information required to be disclosed by the Company in reports that it files or furnishes under the Exchange Act and are effective, at the reasonable assurance level, in ensuring that information required to be disclosed by the Company in the reports that it files or furnishes under the Exchange Act is accumulated and communicated to the Company’s management, including the reviewing officers, as appropriate to allow timely decisions regarding required disclosure.

(b) Changes in Internal Control Over Financial Reporting. There have not been any changes in our internal control over financial reporting (identified in connection with the evaluation required by paragraph (d) in Rules 13a-15 and 15d-15 under the Exchange Act) during the most recently completed quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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PART II OTHER INFORMATION

Item 1. Legal Proceedings

Nabors and its subsidiaries are defendants or otherwise involved in a number of lawsuits in the ordinary course of business. We estimate the range of our liability related to pending litigation when we believe the amount and range of loss can reasonably be estimated. We record our best estimate of a loss when the loss is considered probable. When a liability is probable and there is a range of estimated loss with no best estimate in the range, we record the minimum estimated liability related to the lawsuits or claims. As additional information becomes available, we assess the potential liability related to our pending litigation and claims and revise our estimates. Due to uncertainties related to the resolution of lawsuits and claims, the ultimate outcome may differ from our estimates. In the opinion of management and based on liability accruals provided, our ultimate exposure with respect to these pending lawsuits and claims is not expected to have a material adverse effect on our consolidated financial position or cash flows, although they could have a material adverse effect on our results of operations for a particular reporting period.

Refer to Note 12 Commitments and Contingencies for discussion of previously disclosed litigation contingencies.

Item 1A. Risk Factors

There have been no material changes during the three months ended June 30, 2012 to the “Risk Factors” discussed in our 2011 Annual Report.

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

We withheld the following shares of our common stock to satisfy tax withholding obligations in connection with grants of stock awards during the three months ended June 30, 2012 from the distributions described below. These shares may be deemed to be “issuer purchases” of shares that are required to be disclosed pursuant to this Item, but were not purchased as part of a publicly announced program to purchase common shares:

(In thousands, except average price paid per share)

Period	Total Number  of Shares Purchased  (1)		Average Price Paid per Share		Total Number of Shares Purchased as Part of Publicly Announced Program		Approximate Dollar Value  of Shares that May Yet Be Purchased Under the Program (2)
April 1 – April 30, 2012		18	$	15.91		—		—
May 1 – May 31, 2012		<1	$	14.74		—		—
June 1 – June 30, 2012		1	$	12.93		—		—

(1) Shares were withheld from employees to satisfy certain tax withholding obligations due in connection with grants of stock under our 1996, 1998 and 2003 Employee Stock Plans and our 1999 Stock Option Plan for Non-Employee Directors. Each plan provides for the withholding of shares to satisfy tax obligations, but does not specify a maximum number of shares that can be withheld for this purpose.

(2) We currently do not intend to make further purchases of our common shares under the share repurchase program that was authorized by the Board of Directors in July 2006.

Item 3. Defaults Upon Senior Securities

None

Item 4. Mine Safety Disclosures

Not applicable.

Item 5. Other Information

None.

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Item 6. Exhibits

Exhibit No.	Description
3.1	Memorandum of Association of Nabors Industries Ltd. (incorporated by reference to Annex II to the proxy statement/prospectus included in Nabors Industries Ltd.’s Registration Statement on Form S-4 (Registration No. 333-76198) filed with the Commission on May 10, 2002, as amended).
3.2	Amended and Restated Bye-laws of Nabors Industries Ltd.*
4.1	Rights Agreement, dated July 16, 2012 between Nabors Industries Ltd. and Computershare Trust Company, N.A., as Rights Agent, including the Form of Certificate of Designations of Series A Junior Participating Preferred Shares, the Form of Right Certificate, and the Summary of Rights to Purchase Preferred Shares, respectively attached thereto as Exhibits A, B and C (incorporated by reference to Exhibit 4.1 to Nabors Industries Ltd.’s Form 8-K (File No. 001-32657) filed with the Commission on July 17, 2012).
15	Awareness Letter of Independent Accountants*
31.1	Rule 13a-14(a)/15d-14(a) Certification of Anthony G. Petrello, Chairman, President and Chief Executive Officer*
31.2	Rule 13a-14(a)/15d-14(a) Certification of R. Clark Wood, Principal Accounting and Financial Officer*
32.1	Certifications required by Rule 13a-14(b) or Rule 15d-14(b) and Section 1350 of Chapter 63 of Title 18 of the United States Code (18 U.S.C. 1350), executed by Anthony G. Petrello, Chairman, President and Chief Executive Officer and R. Clark Wood, Principal Accounting and Financial Officer (furnished herewith).
101.INS	XBRL Instance Document*
101.SCH	XBRL Schema Document*
101.CAL	XBRL Calculation Linkbase Document*
101.LAB	XBRL Label Linkbase Document*
101.PRE	XBRL Presentation Linkbase Document*
101.DEF	XBRL Definition Linkbase Document*

* Filed herewith.

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SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) 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.

NABORS INDUSTRIES LTD.
By:	/s/ Anthony G. Petrello
	Anthony G. Petrello
	Chairman, President and
	Chief Executive Officer
By:	/s/ R. Clark Wood
	R. Clark Wood
	Principal Accounting and Financial Officer
Date: August 3, 2012

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