8-K

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 8-K

CURRENT REPORT

PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934

Date of Report (Date of earliest event reported) April 23, 2013

NABORS INDUSTRIES LTD.

(Exact name of registrant as specified in its charter)

Bermuda	001-32657	98-0363970
(State or Other Jurisdiction of Incorporation or Organization)	(Commission File Number)	(I.R.S. Employer Identification No.)

Crown House 4 Par-la-Ville Road Second Floor Hamilton, HM08 Bermuda	N/A
(Address of principal executive offices)	(Zip Code)

(441) 292-1510

(Registrant’s telephone number, including area code)

N/A

(Former name or former address, if changed since last report.)

Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:

oWritten communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

oSoliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

oPre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

oPre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))

Item 2.02Results of Operations and Financial Condition.

On April 23, 2013, we issued a press release announcing our results of operations for the three-month period ending March 31, 2013.  A copy of that release is furnished herewith as Exhibit 99.1 and is incorporated herein by reference.

The press release includes forward-looking statements within the meaning of the Securities Act of 1933 and the Securities Exchange Act of 1934.  Such forward-looking statements are subject to risks and uncertainties, as disclosed from time to time in our filings with the Securities and Exchange Commission.  As a result of these factors, our actual results may differ materially from those indicated or implied by such forward-looking statements.

We also presented in the press release “non-GAAP” financial measures under Regulation G.  We presented our adjusted EBITDA from continuing operations and adjusted income (loss) derived from operating activities for all periods presented in the release.  The components of these non-GAAP measures are computed by using amounts that are determined in accordance with accounting principles generally accepted in the United States of America (“GAAP”).  Adjusted EBITDA from continuing operations is computed by subtracting the sum of direct costs, general and administrative expenses, and earnings (losses) from our former U.S. oil and gas joint venture from the sum of Operating revenues and Earnings (losses) from unconsolidated affiliates.  Adjusted income (loss) derived from operating activities is computed similarly, but also subtracts depreciation and amortization expenses from the sum of Operating revenues and Earnings (losses) from unconsolidated affiliates. As part of the press release information, we have provided a reconciliation of adjusted EBITDA and adjusted income (loss) derived from operating activities to income (loss) from continuing operations before income taxes, which is its nearest comparable GAAP financial measure.

We included our adjusted EBITDA and adjusted income (loss) derived from operating activities in the release because management evaluates the performance of our business units and the consolidated company based on several criteria, including these non-GAAP measures, and because we believe these financial measures are an accurate reflection of our ongoing profitability.

Item 8.01.Other Events.

On April 24, 2013, we will present certain information in connection with our call with shareholders, analysts and others relating to our results of operations discussed above.  Attached hereto as Exhibit 99.2 are slides that will be presented at that time.

Item 9.01Financial Statements and Exhibits.

(d)  Exhibits

Exhibit No.	Description
99.1	Press Release
99.2	Investor Information

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	NABORS INDUSTRIES LTD.
Date: April 24, 2013	By:	/s/ Mark D. Andrews
		Mark D. Andrews
		Corporate Secretary

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EXHIBIT INDEX

Exhibit No.	Description
99.1	Press Release
99.2	Investor Information

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EX-99.1

Exhibit 99.1

NEWS RELEASE

Nabors Announces First Quarter Results

Nabors’ 1Q 2013 EPS Equals $0.33 per Share, Inclusive of Gains and a Lower Tax Rate

HAMILTON, Bermuda, April 23, 2013 — Nabors Industries Ltd. (NYSE:NBR) today reported its financial results for the first quarter of 2013.  Adjusted income derived from operating activities was $149.6 million, compared to $315.5 million in the first quarter of 2012 and $149.8 million in the fourth quarter of 2012.  Operating cash flow (EBITDA) was $423.0 million for the first quarter compared to $563.2 million and $427.0 million, respectively, in the first and fourth quarters of last year.  Net income from continuing operations was $97.2 million ($0.33 per diluted share), compared to $142.6 million ($0.49 per diluted share) in the first quarter of 2012 and $129.3 million ($0.44 per diluted share) in the fourth quarter of 2012.  Operating revenues and earnings from unconsolidated affiliates for this quarter totaled $1.58 billion, compared to $1.82 billion in the comparable quarter of the prior year and $1.60 billion in the fourth quarter of 2012.  First quarter results included a gain on the sale of a large portion of marketable securities net of charges related to the previously disclosed CEO employment contract restructuring.  The quarter’s results also benefited from a lower effective tax rate, principally attributable to the settlement of a long outstanding tax dispute.

Tony Petrello, Nabors’ Chairman, President & CEO, commented, “Operating income and cash flow were essentially flat compared to the fourth quarter, as improved results in Production Services coupled with the seasonal peak in Canada were offset by a sharp decline in Completion Services and more moderate declines in our U.S. and International drilling operations.  The anticipated seasonal trough in Completion Services was exacerbated by the slow restart of activity following the holidays and the series of late winter storms across the areas where a majority of our operations are located.  Despite the slow start, we expect our performance to improve later this year as we begin to restore operating leverage across our Production Services and drilling operations.”

“Our initiatives to streamline and consolidate our operations are reflected in an enhanced reporting format beginning this quarter.  This format reflects the way in which we now analyze our businesses and provides better visibility into the cash contribution of each of our segments.”

To facilitate historical comparisons, the Company will post a downloadable Excel worksheet with three years of reformatted results to its website at www.nabors.com.

DRILLING & RIG SERVICES

In the Company’s Drilling & Rig Services business line, revenues were essentially flat with the fourth quarter at $1.1 billion, as were operating cash flow and income at $356.7 and $137.3 million, respectively.  Aggregate rig activity increased sequentially from 346 to 352 rigs, while daily per rig margins declined approximately $153 to average $11,987.

U.S. Drilling

Improved results in the Gulf of Mexico coupled with seasonally higher results in Alaska mostly offset the anticipated sharp decline in the U.S. Lower 48 portion of this segment.  Revenues for the quarter were $484.8 million, generating $184.9 million in operating cash flow and $77.6 million in operating income.  The U.S. Lower 48 rig count bottomed in mid-February at 165 rigs and has since increased by 16 to 177 rigs, three of which are recently deployed PACE®-X rigs.  An additional two PACE®-X rig commitments were secured during the quarter, bringing the total number of PACE®-X contract awards to 19 since the beginning of 2012 and the total number of contract awards for new rigs to 23 during the same period.  This segment expects to see even lower results in the second quarter as the Alaska winter season winds down and spot market pricing impacts on revenue become fully realized in the U.S. Lower 48 operations.  Activity in the Gulf of Mexico is gradually improving, although seasonally weak activity is expected from June through October due to hurricane season.  The new 4,600 horsepower deepwater platform rig we are building is in the final stages of commissioning after which it will be used for training until its planned mobilization later in the year.  The recent

1

passage of favorable tax legislation in Alaska is expected to spur plans for new activity, with Nabors in line to be a major beneficiary.  Activity should begin later this year and increase for at least two or three years.  Regaining lost market share in the U.S. Lower 48 is a priority and should result in increasing operating leverage as rig count is restored, especially since a large portion of the fleet has already been renewed at spot market rates.

Canada Drilling

The first quarter represented the customary seasonal peak in Canada, although results were short of expectations and historical highs as customers curtailed plans and concluded projects earlier than usual, despite favorable weather.  Cash flow constraints continue to limit this market, with little upside expected until natural gas prices improve or LNG export timing becomes more visible.  Despite the challenging market, a new rig was recently deployed under a term contract, and two deep capacity rigs have been readied for a recent award.  Inquiries for rigs to drill in support of anticipated LNG exports have increased and Nabors is well positioned to capitalize on these opportunities.

International Drilling

Sequential results were down slightly in our International operations, as startup and unfavorable rig move costs offset the initial contribution of the increase in rig activity which was comprised of one land and 2.4 offshore rigs.  Extraordinary and unanticipated cost issues offset a number of recent positive developments.  Among the more significant issues are excessive costs in Iraq and Yemen, higher labor costs in the Middle East and North Africa, delays in restarting rigs in Algeria and lower activity in certain Latin American countries.  These issues are beginning to dissipate and should be gradually extinguished over the intermediate term.

A number of positive developments are emerging.  Availability of high specification rigs is becoming limited in the Middle East region, and rates are improving significantly as contracts renew.  The Company has received incremental inquiries for a large number of high-specification rigs, with more anticipated in the near future.  The number of available rigs in this class is insufficient to meet this prospective demand, causing the Company to anticipate significant demand for new or upgraded rigs.  Nabors is well suited to meet new build requirements, and also owns the majority of the rigs eligible for upgrading.  The Company recently received awards for the startup of two existing offshore platform rigs in Latin America, resumed operations with one of its idle jackups in the Arabian Gulf, is restarting rigs in Algeria and is achieving improvements in Iraq and Yemen.  The impact of these developments should begin to be reflected in second-half results.

Rig Services

Sequential results in Rig Services improved with seasonally strong activity in Alaska oilfield hauling and construction more than offsetting lower results in Canrig.  Fewer capital equipment shipments and reduced rental and field services activity in Canrig were in line with the lower levels of land rig activity and reduced new build construction in the U.S. and Canada.  The second quarter is expected to show lower results with the end of winter activity in Alaska, despite some improvement in Canrig.

COMPLETION & PRODUCTION SERVICES

In the Company’s Completion & Production Services business line, revenues decreased to $513.7 million compared to $544.2 million in the fourth quarter.  This decrease resulted in a significant decrease in both segment EBITDA and operating income, which were $97.8 million and $43.8 million, respectively.  The lower results were attributable to lower seasonal utilization in Completion Services, resulting in suppressed margins due to higher unrecovered costs.  This more than offset the increase in Production Services as it recovered from its seasonally weak fourth quarter.

Completion Services

First quarter results in the completion services segment were even weaker than expected with the slow restart of activity exacerbated by the recent series of late winter storms.  While industry activity is improving modestly, the competition for each incremental project is still intense.  Modest improvement is expected in the second quarter as utilization and margins recover, although the potential for continued pricing pressure exists.

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Production Services

This operation saw a modest improvement sequentially, with improving activity in the U.S. and seasonally high activity in Canada, despite a slow start to the year in the U.S. following the late fourth quarter stall in activity and difficult weather in its northern districts.  Modest improvement is anticipated in the second quarter on higher expected activity in the U.S., even though the recent release of a large number of rigs by a major operator in multiple areas has disrupted the market and seasonality will weaken Canada results.  Longer term, the outlook for this segment remains promising as the population of oil and liquids wells continues to grow.

Summary

Mr. Petrello summarized the results and outlook, “We remain focused on our goal of improving our performance, both financially and operationally.  Our financial position remains solid despite lower operating cash flow and over $200 million in cash outflows during the quarter for semi-annual interest payments, a technology acquisition and other less significant one-time expenditures.  Operationally, we continue to set records across numerous areas, and develop and adopt numerous performance enhancing technologies.

“We believe technology differentiation will be increasingly relevant in the future and will consist of both increased automation of the surface-based rig functions, and ultimately the downhole drilling processes.  Nabors has all of the relevant resources under one roof to be a leader in this effort.  To date we deployed three of our new PACE®-X series of rigs and are approaching completion of our sophisticated deepwater platform rig.  All of these rigs incorporate the latest performance-enhancing technology, most of which is produced by Canrig.  Our U.S. Lower 48 customers are increasingly incorporating pad drilling capability into their requirements and we continue to invest in not only new pad capable rigs but also in the retrofitting of our existing fleet.  Pad drilling is expanding rapidly and is a differentiator over the near term.  Nabors pioneered pad drilling in the 1970s and has the largest complement of the industry’s pad-capable rigs, particularly walking style rigs.

“The near term remains challenging across all of our markets.  Although cost issues are beginning to abate internationally, North American contract renewal and spot rates remain under pressure across all classes of rigs and all regions, as we have articulated since last summer.  Despite these challenging conditions, we are encouraged by the increasing visibility of a meaningful improvement in our results later this year.”

About Nabors

The Nabors companies own and operate approximately 473 land drilling rigs throughout the world and approximately 546 land workover and well servicing rigs in North America.  Nabors’ actively marketed offshore fleet consists of 37 platform rigs, 7 jackup units and 4 barge rigs in the United States and multiple international markets. In addition, Nabors is one of the largest providers of hydraulic fracturing, cementing, nitrogen and acid pressure pumping services with approximately 805,000 hydraulic horsepower currently in service.  Nabors also manufactures top drives and drilling instrumentation systems and provides comprehensive oilfield hauling, engineering, civil construction, logistics, and facilities maintenance and project management services.  Nabors participates in most of the significant oil and gas markets in the world.

For further information, please contact Dennis A. Smith, Director of Corporate Development & Investor Relations, at 281-775-8038.  To request investor materials, contact Nabors’ corporate headquarters in Hamilton, Bermuda at 441-292-1510 or via email at mark.andrews@nabors.com.

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NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (LOSS)

(Unaudited)

	Three Months Ended
	March 31,						December 31,
(In thousands, except per share amounts)	2013			2012			2012
Revenues and other income:
Operating revenues	$	1,578,645		$	1,890,426		$	1,595,614
Earnings (losses) from unconsolidated affiliates	2,895			(68,669		)	1,193
Investment income (loss)	79,421			20,252			30,293
Total revenues and other income	1,660,961			1,842,009			1,627,100
Costs and other deductions:
Direct costs	1,026,042			1,184,816			1,039,050
General and administrative expenses	132,545			136,346			130,723
Depreciation and amortization	273,365			247,621			277,283
Interest expense	60,008			62,654			61,835
Losses (gains) on sales and disposals of long-lived assets and other expense (income), net	59,807			(1,840		)	(15,590		)
Total costs and other deductions	1,551,767			1,629,597			1,493,301
Income (loss) from continuing operations before income taxes	109,194			212,412			133,799
Income tax expense (benefit)	11,272			69,044			3,777
Subsidiary preferred stock dividend	750			750			750
Income (loss) from continuing operations, net of tax	97,172			142,618			129,272
Income (loss) from discontinued operations, net of tax	2,046			(8,795		)	(101,121		)
Net income (loss)	99,218			133,823			28,151
Less: Net (income) loss attributable to noncontrolling interest	(97		)	267			(1,074		)
Net income (loss) attributable to Nabors	$	99,121		$	134,090		$	27,077
Earnings (losses) per share: (1)
Basic from continuing operations	$	.33		$	.50		$	.44
Basic from discontinued operations	.01			(.04		)	(.35		)
Basic	$	.34		$	.46		$	.09
Diluted from continuing operations	$	.33		$	.49		$	.44
Diluted from discontinued operations	—			(.03		)	(.35		)
Diluted	$	.33		$	.46		$	.09
Weighted-average number of common shares outstanding: (1)
Basic	291,687			288,538			290,394
Diluted	294,170			291,709			292,421
Adjusted EBITDA from continuing operations (2)	$	422,953		$	563,157		$	427,034
Adjusted income (loss) derived from operating activities from continuing operations (3)	$	149,588		$	315,536		$	149,751

(1)See “Computation of Earnings (Losses) Per Share” included herein as a separate schedule.

(2)Adjusted EBITDA is computed by subtracting the sum of direct costs, general and administrative expenses, earnings (losses) from the U.S. oil and gas joint venture from the sum of Operating revenues and Earnings (losses) from unconsolidated affiliates. There are limitations inherent in using adjusted EBITDA as a measure of overall profitability because it excludes significant expense items. However, management evaluates the performance of our business units and the consolidated company based on several criteria, including adjusted EBITDA and adjusted income (loss) derived from operating activities, because we believe that these financial measures accurately reflect our ongoing profitability. These amounts should not be used as a substitute for the amounts reported in accordance with GAAP. To compensate for the limitations in utilizing adjusted EBITDA as an operating measure, management also uses GAAP measures of performance, including income from continuing operations and net income, to evaluate performance, but only with respect to the Company as a whole and not on a segment basis.

(3)Adjusted income (loss) derived from operating activities is computed by subtracting the sum of direct costs, general and administrative expenses, depreciation and amortization and earnings (losses) from the U.S. oil and gas joint venture from the sum of Operating revenues and Earnings (losses) from unconsolidated affiliates. 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 table set forth immediately following the heading “Reconciliation of non-GAAP Financial Measures to Income (loss) from continuing operations before income taxes”.

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NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

	(Unaudited)
	March 31,		December 31,
(In thousands, except ratios)	2013		2012
ASSETS
Current assets:
Cash and short-term investments	$	690,480	$	778,204
Accounts receivable, net	1,434,530		1,382,623
Assets held for sale	385,133		383,857
Other current assets	608,555		588,173
Total current assets	3,118,698		3,132,857
Long-term investments and other receivables	3,910		4,269
Property, plant and equipment, net	8,641,947		8,712,088
Goodwill	487,760		472,326
Investment in unconsolidated affiliates	64,598		61,690
Other long-term assets	268,544		272,792
Total assets	$	12,585,457	$	12,656,022
LIABILITIES AND EQUITY
Current liabilities:
Current portion of long-term debt	$	435	$	364
Other current liabilities	1,090,711		1,132,018
Total current liabilities	1,091,146		1,132,382
Long-term debt	4,379,758		4,379,336
Other long-term liabilities	1,060,680		1,117,999
Total liabilities	6,531,584		6,629,717
Subsidiary preferred stock (1)	69,188		69,188
Equity:
Shareholders’ equity	5,973,814		5,944,929
Noncontrolling interest	10,871		12,188
Total equity	5,984,685		5,957,117
Total liabilities and equity	$	12,585,457	$	12,656,022

(1)Represents subsidiary preferred stock from acquisition in September 2010. 75,000 shares of such stock are outstanding and pay quarterly dividends at an annual rate of 4%.

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NABORS INDUSTRIES LTD. AND SUBSIDIARIES

SEGMENT REPORTING

(Unaudited)

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

	Three Months Ended
	March 31,						December 31,
(In thousands, except rig activity)	2013			2012			2012
Reportable segments:
Operating revenues and Earnings (losses) from unconsolidated affiliates from continuing operations: (1)
Drilling and Rig Services:
U.S.	$	484,773		$	627,105		$	495,154
Canada	126,867			144,735			115,668
International	321,516			306,465			324,728
Rig Services (2)	179,310			241,758			180,467
Subtotal Drilling and Rig Services (3)	1,112,466			1,320,063			1,116,017
Completion and Production Services:
Production Services	251,571			257,259			248,407
Completion Services	262,138			398,036			295,827
Subtotal Completion and Production Services (4)	513,709			655,295			544,234
Other reconciling items (5)	(44,635		)	(153,601		)	(63,444		)
Total operating revenues and earnings (losses) from unconsolidated affiliates	$	1,581,540		$	1,821,757		$	1,596,807
Adjusted EBITDA from continuing operations: (1) (6)
Drilling and Rig Services:
U.S.	$	184,859		$	257,964		$	190,877
Canada	45,531			58,184			42,360
International	106,514			97,250			110,661
Rig Services (2)	19,784			41,827			15,991
Subtotal Drilling and Rig Services (3)	356,688			455,225			359,889
Completion and Production Services:
Production Services	51,118			53,374			47,369
Completion Services	46,724			93,186			60,363
Subtotal Completion and Production Services (4)	97,842			146,560			107,732
Other reconciling items (7)	(31,577		)	(38,628		)	(40,587		)
Total adjusted EBITDA	$	422,953		$	563,157		$	427,034
Adjusted income (loss) derived from operating activities from continuing operations: (1) (8)
Drilling and Rig Services:
U.S.	$	77,595		$	166,733		$	82,603
Canada	30,518			43,146			27,064
International	21,469			21,138			23,388
Rig Services (2)	7,737			29,846			4,829
Subtotal Drilling and Rig Services (3)	137,319			260,863			137,884
Completion and Production Services:
Production Services	26,014			28,029			21,374
Completion Services	17,756			64,860			30,296
Subtotal Completion and Production Services (4)	43,770			92,889			51,670
Other reconciling items (7)	(31,501		)	(38,216		)	(39,803		)
Total adjusted income (loss) derived from operating activities	$	149,588		$	315,536		$	149,751
Rig activity:
Rig years: (9)
U.S.	189.6			239.1			190.3
Canada	40.0			48.7			36.3
International (10)	122.7			117.7			119.3
Total rig years	352.3			405.5			345.9
Rig hours: (11)
U.S. Production Services	212,298			213,026			202,368
Canada Production Services	48,027			57,044			44,582
Total rig hours	260,325			270,070			246,950

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(1)All periods present the operating activities of our wholly owned oil and gas businesses in the United States, Canada and Colombia, our equity interests in joint ventures in Canada and Colombia, and 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 $2.8 million, $(6.1) million and $.7 million for the three months ended March 31, 2013 and 2012 and December 31, 2012, respectively.

(4)Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $.1 million and $.5 million for the three months ended March 31, 2013 and December 31, 2012, respectively.

(5)Represents the elimination of inter-segment transactions and earnings (losses), net from the U.S. unconsolidated oil and gas joint venture, accounted for using the equity method of $(62.6) million for the three months ended March 31, 2012. In December 2012, we sold our equity interest in the oil and gas joint venture.

(6)Adjusted EBITDA is computed by subtracting the sum of direct costs, general and administrative expenses, earnings (losses) from the U.S. oil and gas joint venture from the sum of Operating revenues and Earnings (losses) from unconsolidated affiliates. There are limitations inherent in using adjusted EBITDA as a measure of overall profitability because it excludes significant expense items. However, management evaluates the performance of our business units and the consolidated company based on several criteria, including adjusted EBITDA and adjusted income (loss) derived from operating activities, because we believe that these financial measures accurately reflect our ongoing profitability. These amounts should not be used as a substitute for the amounts reported in accordance with GAAP. To compensate for the limitations in utilizing adjusted EBITDA as an operating measure, management also uses GAAP measures of performance, including income from continuing operations and net income, to evaluate performance, but only with respect to the Company as a whole and not on a segment basis.  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 table set forth immediately following the heading “Reconciliation of non-GAAP Financial Measures to Income (loss) from continuing operations before income taxes.”

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

(8)Adjusted income (loss) derived from operating activities is computed by subtracting the sum of direct costs, general and administrative expenses, depreciation and amortization and earnings (losses) from the U.S. oil and gas joint venture from the sum of Operating revenues and Earnings (losses) from unconsolidated affiliates. These amounts should not be used as a substitute for the 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 table set forth immediately following the heading “Reconciliation of non-GAAP Financial Measures to Income (loss) from continuing operations before income taxes.”

(9)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.

(10)International rig years includes our equivalent percentage ownership of rigs owned by unconsolidated affiliates, which totaled 2.5 years during each of the three months ended March 31, 2013 and 2012 and December 31, 2012.

(11)Rig hours represents the number of hours that our well-servicing rig fleet operated during the period.

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NABORS INDUSTRIES LTD. AND SUBSIDIARIES

RECONCILIATION OF NON-GAAP FINANCIAL MEASURES TO INCOME FROM CONTINUING OPERATIONS BEFORE INCOME TAXES

(Unaudited)

	Three Months Ended
	March 31,						December 31,
(In thousands)	2013			2012			2012
Adjusted EBITDA from continuing operations	$	422,953		$	563,157		$	427,034
Less: Depreciation and amortization	273,365			247,621			277,283
Adjusted income (loss) derived from operating activities from continuing operations	149,588			315,536			149,751
U.S. oil and gas joint venture earnings (losses)	—			(62,562		)	—
Interest expense	(60,008		)	(62,654		)	(61,835		)
Investment income (loss)	79,421			20,252			30,293
Gains (losses) on sales and disposals of long-lived assets and other income (expense), net	(59,807		)	1,840			15,590
Income from continuing operations before income taxes	$	109,194		$	212,412		$	133,799

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NABORS INDUSTRIES LTD. AND SUBSIDIARIES

COMPUTATION OF EARNINGS (LOSSES) PER SHARE

(Unaudited)

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

	Three Months Ended
	March 31,						December 31,
(In thousands, except per share amounts)	2013			2012			2012
Net income (loss) attributable to Nabors (numerator):
Income (loss) from continuing operations, net of tax	$	97,172		$	142,618		$	129,272
Less: net (income) loss attributable to noncontrolling interest	(97		)	267			(1,074		)
Less: earnings allocated to unvested shareholders	(814		)	—			—
Adjusted income (loss) from continuing operations - basic and diluted	$	96,261		$	142,885		$	128,198
Income (loss) from discontinued operations, net of tax	2,046			(8,795		)	(101,121		)
	$	98,307		$	134,090		$	27,077
Earnings (losses) per share:
Basic from continuing operations	$	.33		$	.50		$	.44
Basic from discontinued operations	.01			(.04		)	(.35		)
Total Basic	$	.34		$	.46		$	.09
Diluted from continuing operations	$	.33		$	.49		$	.44
Diluted from discontinued operations	—			(.03		)	(.35		)
Total Diluted	$	.33		$	.46		$	.09
Shares (denominator):
Weighted-average number of shares outstanding-basic	291,687			288,538			290,394
Net effect of dilutive stock options, warrants and restricted stock awards based on the if-converted method	2,483			3,171			2,027
Weighted-average number of shares outstanding - diluted	294,170			291,709			292,421

For all periods presented, the computation of diluted earnings (losses) per share excluded outstanding stock options and warrants with exercise prices greater than the average market price of Nabors’ common shares because their inclusion would have been anti-dilutive and because they were not considered participating securities. The average number of options and warrants that were excluded from diluted earnings (losses) per share that would have potentially diluted earnings (losses) per share were 12,452,263 and 11,763,048 shares during the three months ended March 31, 2013 and 2012, respectively; and 15,000,882 shares during the three months ended December 31, 2012. 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 are included in our diluted earnings (losses) per share computation using the if-converted method of accounting.  Restricted stock is 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.

1-6

EX-99.2

Exhibit 99.2

1Q13 Earnings Presentation April 24, 2013 Presenter: Anthony G. Petrello Chairman, President & Chief Executive Officer

Forward-Looking Statements 2 We often discuss expectations regarding our markets, demand for our products and services, and our future performance in our annual and quarterly reports, press releases, and other written and oral statements. Such statements, including statements in this document incorporated by reference that relate 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 of 1933 and Section 21E of the Securities Exchange Act of 1934. These “forward-looking statements” are based on our analysis of currently available competitive, financial and economic data and our operating plans. They are inherently uncertain, and investors must recognize that events and actual results could turn out to be significantly different from our expectations. You should consider the following key factors when evaluating these forward-looking statements: • fluctuations in worldwide prices and demand for natural gas, natural gas liquids and crude oil; • fluctuations in levels of natural gas, natural gas liquids and crude 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 existence of regulatory and legislative uncertainties; • the possibility of changes in tax laws; • the possibility of political instability, war or acts of terrorism in any of the countries in which we do business; 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, natural gas liquids or crude oil, which could have a material impact on exploration and 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.

3 Recent Highlights

Completion Services 20% Production Services 14% U.S. Drilling 31% Canada 6% International 17% Other Rig Services 12% Two Primary Business Lines 4 (1) Includes announced new build commitments (2) Revenue excludes other reconciling items > Drilling & Rig Services – U.S. Lower 48 – 279 rigs(1) – U.S. Offshore – 22 rigs – Alaska – 20 rigs – Canada – 66 rigs – International – 150 rigs – Other Rig Services • Canrig (top drives, rig automation software) • Peak (Alaska logistics) • Ryan (directional drilling) > Completion & Production Services – Completion Services - 805k HHP – Production Services • 546 rigs • 1,036 trucks • 3,568 frac tanks 2012 Revenue(2)

New Board Member Howard Wolf 5 > Experience – Former senior partner at Fulbright & Jaworski L.L.P. (1959-2003) – Chaired State Bar of Texas Committee on Securities and Investment Banking and Section on Corporation, Banking, and Business Law – Served on, or chaired, numerous boards of directors including, Stewart & Stevenson and Offshore Logistics – Currently serves as a director of Simmons & Company

6 Balance Sheet Management Targeted Net Debt Reduction (1) Coverage defined as LTM EBITDA / LTM Interest Expense (3) Based on consensus EBITDA as of 4/19/13 (2) Leverage defined as Total Debt / LTM EBITDA Actual Targeted(3) ($MM's) 4Q11 4Q12 1Q13 4Q13 Total Debt $4,624 $4,380 $4,380 $3,913 Cash and Investments 539 778 690 540 Net Debt 4,084 3,601 3,690 3,372 Shareholders’ Equity 5,588 5,945 5,974 6,241 Gross Debt to Capitalization 45% 42% 42% 39% Net Debt to Capitalization 42% 38% 38% 35% Coverage(1) 7.0x 7.9x 7.4x 7.7x Leverage(2) 2.6x 2.2x 2.4x 2.1x

PACE®-X Rig Designed for Current and Future Market Demands 7 > Smaller modular footprint and walking system – Reduces pad construction and remediation costs – Faster and lower cost well-to-well and pad-to-pad moves – Fewer permit loads for anytime moving and reduced truck traffic – Minimizes environmental impact – Increases drilling efficiency – Reduces HSE exposure > Scalable size and capacity – High downhole torque – Oversized setback – Expandable bi-fuel power and pump capacity > Designed specifically for pad drilling – Expanded substructure height and width – Reduces need for deep cellars > Higher hydraulic horsepower and closed loop mud system – Consistent ROP in long laterals – Reduces equipment rental and rig move time – Increases productivity Awarded 2 New Contracts = 19 Contracted 18 rigs delivered in 2013 & 1 rig in 2014

Alaska Legislature Repeals Progressive Tax 8 > Senate Bill 21 passed April 14, 2013 – Gov. Sean Parnell: “We are signaling to the world that Alaska is back, ready to compete, and ready to supply more energy once again.” > Goal to increase Alaska oil production – North Slope production • 1988 peaked at over 2 mmbpd with Prudhoe Bay comprising 1.6 mmbpd • 2012 production averaged 579 mbpd with Prudhoe comprising 265 mbpd > Prior progressive tax – Oil profits taxed at 25% per barrel at $30 per barrel – Tax increases 0.4% for every $1 per barrel above $30 > New tax – Flat 35% net profits tax, with $5 per barrel exempted for all produced oil Other Oil States’ Tax Structures . North Dakota: 11.5% of gross value of oil production . Texas: 4.6% per barrel (plus other small fees)

9 Financial Summary ($M’s except EPS) 1Q12 2Q12 3Q12 4Q12 1Q13 Revenue $1,821,757 $1,602,797 $1,666,892 $1,596,807 $1,581,540 EBITDA 563,157 486,363 497,612 427,034 422,953 Operating Income 315,536 225,347 228,015 149,751 149,588 Diluted EPS(1) $0.49 $(0.34) $0.22 $0.44 $0.33 (1) Diluted EPS for continuing operations

10 Drilling & Rig Services

11 Drilling & Rig Services Adjusted Income (Loss) Derived from Operating Activities ($M’s) 1Q12 2Q12 3Q12 4Q12 1Q13 Drilling & Rig Services: U.S. Drilling $166,733 $145,351 $115,207 $82,603 $77,595 Canada 43,146 (529) 21,679 27,064 30,518 International 21,138 16,401 30,299 23,388 21,469 Rig Services 29,846 28,179 16,207 4,829 7,737 Total $260,863 $189,402 $183,392 $137,884 $137,319

Global Rig Fleet Details 12 AC SCR Mech Total Moving Systems Alaska Land 5 12 3 20 13 Lower 48 157 96 26 279 141 Canada 16 21 29 66 20 International Land 31 64 31 126 49 Offshore 6 40 2 48 n/a Total 215 233 91 539 223 As of 3/31/13, including contracted rigs scheduled to be delivered and moving systems scheduled to be installed 40% 43% 17% Rigs by Power Type AC SCR Mech 45% 55% Global Rigs with Moving Systems Moving Systems Non-Moving

1Q Rig Utilization & Availability 13 Rig Fleet 1Q13 Rig Years Utilization U.S. Lower 48 AC 140 119 85% Legacy 122 51 42% U.S. Lower 48 Total 262 170 65% U.S. Offshore 22 14 64% Alaska 21 6 29% Canada 65 40 62% International 148 123 83% Subtotal 518 353 68% PACE®-X Construction(1) 16 Total Fleet 534 (1) Includes announced new build commitments

> Contract mix – 115 rigs (65%) term – 62 rigs (35%) spot > Commodity focus – 136 rigs (77%) oil and liquids – 26 rigs (15%) gas term – 15 rigs (8%) gas spot > Customer base – Super majors and majors 20% – Large independents 43% – Small and private 37% > 95% pad-capable rig utilization Leading Lower 48 Player 14 PACE®-F Rig PACE®-M Rig PACE®-B Rig PACE®-X Rig As of 4/24/13

Lower 48 Working Rigs by Region and Play 5 Total Lower 48 Rigs on Revenue: 177 As of 3/31/13 15 Basin Rigs Marcellus/Utica 9 Haynesville 12 Bakken 49 Eagle Ford 30 Permian 25 Barnett 3 Granite Wash 11 Other 38 Total 177 62 25 20 16 30 10 9

0 2 4 6 8 10 12 14 16 2Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2Q 3Q 4Q 1Q 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 Lower 48 Newbuild Deployments 0% 45% 55% 2005 AC SCR Mech 28% 41% 31% 2009 AC SCR Mech 16 rigs left to be delivered in 2013 & 1 rig in 2014 As of 3/31/13 including rigs scheduled to be delivered 16 56% 35% 9% 2014 AC SCR Mech

NBR Skid, 27 NBR Walking, 114 Non Pad-Capable 83% Pad-Capable (NBR) 6% Pad-Capable (Industry) 11% Industry Skid, 65 NBR Skid, 27 NBR Walking, 78 Industry Walking, 112 Lower 48 Pad-Capable Rigs 17 Source: Baker Hughes Land Rig Count, NBR Estimates Nabors currently has over 1/3 of industry’s padcapable rigs and 40% of its walking rigs After ’13 &’14 newbuilds and upgrades, Nabors will have 27 skidding rigs and 114 walking rigs

> Skidding System • Limited by guide track, problems with existing wells • Requires perfectly level guide track to prevent high-center of rig • Guide track is last to leave, first to be rigged up • Unforgiving if conductor is off-center • Requires additional loads > Stomper System • Reduced rig up • Ability to walk around existing wells • Onboard rig leveling system Walking System Advantages 18

Three Limitations of Skid Rigs 1. Accommodating misaligned wells 19

Three Limitations of Skid Rigs 2. Accommodating typical wellhead installation 20

Three Limitations of Skid Rigs 3. Accommodating uneven ground 21

PACE®-X Pad Drilling Capabilities 22

U.S. Offshore Two of the Largest Platform Drilling Rigs in the Gulf of Mexico 23 U.S. Offshore Rig Fleet Workover Platform 10 Drilling Platform 7 Workover Jackup 1 Barge 4 Total 22 Nabors designed, built and owned Nabors designed and built, customer-owned Two New 4,600 HP Rigs

24 Nabors Arctic Coiled Tubing Drilling Rig CDR-2

0 10 20 30 40 50 60 2Q12 3Q12 4Q12 1Q13 Recent Seasonal Ramps 2010/2011 2011/2012 2012/2013 0 10 20 30 40 50 60 2Q07 3Q07 4Q07 1Q08 2Q08 3Q08 4Q08 1Q09 2Q09 3Q09 4Q09 1Q10 2Q10 3Q10 4Q10 1Q11 2Q11 3Q11 4Q11 1Q12 2Q12 3Q12 4Q12 1Q13 Canada Rig Year Seasonality Canada Rig Years Canada Drilling 25 1Q rig count lower than traditional seasonal high

Canada Working Rigs by Play 26 Play Target AC SCR Mechanical Walking Rigs Workover Rigs Montney Oil / Gas 3 8 5 1 Duvernay (NW Alberta) Oil 1 1 18 Cardium (Central Alberta) Oil 8 18 Saskatchewan Oil 4 Oil Sands Oil 2 2 4 10 Horn River Gas 1 2 1 Total 6 13 8 11 51 As of 3/31/13

International Working Rigs 27 Algeria 10 Ecuador 6 Kuwait 2 Romania 1 Angola 1 India 5 Malaysia 2 Russia 4 Argentina 15 Iraq 5 Mexico 14 Saudi Arabia 32 Colombia 8 Italy 1 Oman 4 Venezuela 5 Congo 2 Jordan 1 PNG 2 Yemen 3 Kazakhstan 1 Qatar 1 Total 125 10 2 15 8 1 6 5 5 1 1 1 2 2 14 4 2 1 1 4 32 5 3

International Land Fleet Details 28 AC SCR Mech Total Moving Systems International 32 64 30 126 49 25% 51% 24% Rigs by Power Type AC SCR Mech 39% 61% Rigs with Moving Systems Moving Systems Non-Moving 90% 10% Rigs with Top Drives Top Drive No Top Drive 31% 35% 34% Since 2005 Newbuild Refurbished Original

Manufacturing Automated Drilling Equipment Drilling Software & Automation Technology Directional Drilling Expertise Operational Excellence Advanced Rig Designs Closing the Loop on Drilling Automation 29

30 Completion & Production Services

Completion & Production Services Adjusted Income Derived from Operating Activities 31 ($M’s) 1Q12 2Q12 3Q12 4Q12 1Q13 Completion & Production Services: Completion Services $64,860 $46,144 $47,218 $30,296 $17,756 Production Services 28,029 25,397 34,035 21,374 26,014 Total $92,889 $71,541 $81,253 $51,670 $43,770

Completion & Production Services Fleet Region Rigs Frac Crews Trucks Frac Tanks CTU Cementing Wireline Additional Equipment Western 181 108 99 15 12 P&A Rigs, Foam Units Rockies 69 10 56 322 2 9 10 P&A Rigs, Pumps, Swivels Mid-Con 36 1 111 438 2 8 8 Reverse Units, Foam Units Northeast 11 4 105 602 5 40 12 Rig Moving, Excavation West Texas 104 3 334 1,241 2 4 2 Reverse Units, Foam Units South Texas 25 3 196 570 4 7 2 Condensate Trucks Ark-La-Tex 16 2 126 296 P&A Rigs Gulf Coast 1 4 Canada 104 2 P&A Rigs Total 546 26 1,036 3,568 30 84 34 32

Stimulation Fleet Contract Detail Region # of Crews Term Spot Idle Oil/Liquids Dry Gas 24 Hr. Rockies 10 6 4 10 6 Mid-Con 1 1 Northeast 4 1 3 2 2 3 West Texas 3 1 1 1 2 South Texas 3 2 1 3 3 Ark-La-Tex 2 2 Gulf Coast 1 1 Canada 2 2 2 Total 26 10 11 5 19 2 12 33 21working

U.S. Production Services Rates & Hours 34 500,000 600,000 700,000 800,000 900,000 $380 $420 $460 $500 $540 $580 2009 2010 2011 2012 Well Servicing Rigs Annual Rates and Hours Rig Hours Rig Rate 0 500,000 1,000,000 1,500,000 2,000,000 2,500,000 $80 $90 $100 $110 $120 $130 2009 2010 2011 2012 Fluid Hauling Trucks Annual Rates and Hours Truck Hours Truck Rate 180,000 190,000 200,000 210,000 220,000 230,000 $100 $200 $300 $400 $500 $600 $700 2Q11 3Q11 4Q11 1Q12 2Q12 3Q12 4Q12 1Q13 Quarterly Rates and Hours Rig Hours Rig Rate 0 100,000 200,000 300,000 400,000 500,000 600,000 $100 $105 $110 $115 $120 $125 $130 2Q11 3Q11 4Q11 1Q12 2Q12 3Q12 4Q12 1Q13 Quarterly Rates and Hours Truck Hours Truck Rate

35 Summary

Key Takeaways > Near term remains challenging with limited visibility > Outsized operating leverage over longer term > Global optionality relative to North America-centric peers > Continued focus on EBITDA generation > Multiple opportunities for high-impact investments > Focused on matters within our control > Potential for trading multiple expansion 36

EBITDA 37 ($M’s) 1Q12 2Q12 3Q12 4Q12 1Q13 Drilling & Rig Services $455,225 $399,217 $398,741 $359,889 $356,688 Completion & Production Services 146,560 123,176 136,488 107,732 97,842 Other reconciling items (38,628) (36,030) (37,617) (40,587) (31,577) Total $563,157 $486,363 $497,612 $427,034 $422,953

38 Ancillary Information

39 Nabors Global Infrastructure Margins and Activities 1Q12 4Q12 1Q13 Drilling Margin (1) Rig Yrs Margin (1) Rig Yrs Margin (1) Rig Yrs U.S. Lower 48 $10,942 219.0 $12,363 172.7 $9,955 169.5 U.S. Offshore 19,630 11.9 (428) 12.4 19,163 14.1 Alaska 48,124 8.2 22,344 5.2 48,491 6.0 Canada 14,282 48.7 14,389 36.3 14,278 40.0 International 11,023 117.7 12,004 119.3 11,452 122.7 Production Services Rev/Hr Rig Hrs Rev/Hr Rig Hrs Rev/Hr Rig Hrs U.S. Lower 48 $529 213,026 $590 202,368 $586 212,298 Canada 834 57,044 818 44,582 806 48,027 (1) Margin = gross margin per rig per day for the period. Gross margin is computed by subtracting direct costs from operating revenues for the period.

Quarter-end Number Of Rigs Subject To Term Contracts(1) 1Q13 2Q13 3Q13 4Q13 1Q14 4Q 2012 95 81 69 63 55 1Q 2013 111 92 79 76 64 U.S. Lower 48 Term Contracts in Force at March 31, 2013 (1) Represents the quarterend number of contracts in force with no incremental contract awards in the future 40 ($MM’s) Actual Estimates Non-Working Rig Revenue 1Q13 2Q13 Out Years Lump Sum 1.4 1.0 -- Lump Sum: Amortized Monthly 1.6 2.3 2.3 Standby: Monthly 4.7 3.3 -- Total 7.7 6.6 2.3 Added 16 contracts in 1Q net of expirations Expect term contracts to decrease by 19 net of newbuilds