425

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) March 2, 2015

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:

xWritten 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 March 2, 2015, we issued a press release announcing our results of operations for the fourth quarter and full year 2014.  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 certain “non-GAAP” financial measures.  We presented our adjusted EBITDA and adjusted income (loss) derived from operating activities for all periods presented in the release.  We also presented our adjusted income (loss) from continuing operations, net of tax, non-cash charges and other non-operational items and the related earnings (losses) per share impact of such charges for the three months ended December 31, 2014 and September 30, 2014. 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 is computed by subtracting the sum of direct costs and general and administrative expenses 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.  Adjusted income (loss) from continuing operations, net of tax is computed by subtracting the sum of non-cash charges and other non-operational items from income (loss) from continuing operations, net of tax. 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. In addition, we provided a schedule of the non-cash charges and other non-operational items recorded for the three months ended December 31, 2014 and September 30, 2014, and their related earnings (losses) per share impact in calculating adjusted income (loss) from continuing operations, net of tax.

We included these non-GAAP financial measures 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.  There are, however, certain limitations to these measures and therefore they should be considered in addition to and not as an alternative to our results in accordance with GAAP.

Item 8.01.Other Events.

On March 3, 2015, 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

2

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: March 3, 2015	By:	/s/ Mark D. Andrews
		Mark D. Andrews
		Corporate Secretary

3

EXHIBIT INDEX

Exhibit No.	Description
99.1	Press Release
99.2	Investor Information

4

EX-99.1

Exhibit 99.1

NEWS RELEASE

Nabors Announces Fourth-Quarter and Full-Year Financial Results

Notable items include:

·Fourth-quarter diluted EPS of $0.33, adjusted for impairments and other charges

·U.S., Canada and International drilling operations improved sequentially

·Three newbuild contracts awarded in U.S. Drilling segment in the fourth quarter

·Deployed 36 new or substantially upgraded rigs during the year

·Achieved the best annual safety performance in company history

·Impaired asset values by $387 million in goodwill and $612 million in equipment

·Expanded available credit facilities and cash by $525 million in February 2015

HAMILTON, Bermuda, March 2, 2015 — Nabors Industries Ltd. (NYSE:NBR) today reported fourth quarter revenues and earnings from unconsolidated affiliates of $1.78 billion, compared to $1.81 billion in the third quarter of 2014 and $1.61 billion in the same quarter of the prior year.  Excluding a third quarter early termination payment of $30 million, fourth quarter revenue was essentially unchanged sequentially and increased by 11% year-over-year. For the quarter, the combined drilling segments improved by 2%, with U.S., Canada and International drilling operations all growing as compared to the third quarter. These increases were offset by a 2% reduction in the Completion & Production Services business.  Revenues and earnings from unconsolidated affiliates for the full year 2014 was $6.80 billion compared to $6.15 billion in 2013, a 10% increase.

Income from continuing operations, net of taxes reported for the fourth quarter was a loss of $886.4 million or ($3.06) per diluted share, inclusive of $982.7 million in after-tax charges or $3.39 per share for asset impairments and transaction costs.  For the full year 2014, income from continuing operations, net of tax was a loss of $669.3 million or ($2.28) per diluted share.  Corresponding 2013 full-year results were $158.3 million or $0.51 per diluted share.  Adjusting for impairments and other charges, income from continuing operations, net of taxes for the fourth quarter was $96.3 million or $0.33 per fully diluted share.  This compares to adjusted net income from continuing operations, net of taxes of $116.7 million or $0.39 per share in the third quarter and $128.5 million or $0.42 per share in the same quarter of last year. The third quarter of 2014 included the $30.0 million pre-tax impact for an early termination payment.

Fourth quarter adjusted income derived from operating activities (“operating income”) was $152.1 million, bringing the total for 2014 to $598.0 million.  This compares to $159.6 million for the corresponding quarter of 2013 and $558.2 million for all of 2013.  Adjusted EBITDA was $445.7 million for the fourth quarter compared to $437.2 million in the same quarter last year and $490.0 million in the third quarter of 2014.  Full-year adjusted EBITDA for the year was $1.74 billion, which compares favorably to $1.64 billion in 2013.

Anthony Petrello, Nabors’ Chairman and CEO, commented, “Despite the initial effects of the weakening environment, our drilling operations posted a sequential improvement in operating income, primarily attributable to new rig deployments and the seasonal ramp-up in Alaska. Our Canada drilling business also improved due to the usual seasonal ramp-up. Our International drilling segment benefitted from new rig deployments and recent contract renewals. These were more than offset by lower results in our Rig Services and Completion and Production Services operations as a result of lower activity and increased pricing competitiveness.

“Thanks to our experienced executive management team, we are confident in our ability to manage through this downturn.  We are taking the necessary steps to scale the company for the current environment, while we continue investing in advanced drilling technologies.  We intend to emerge from this downturn consolidating our position as the leading global land driller.

“We are taking numerous actions aimed at lowering our costs in ways that do not inhibit our core capabilities and flexibility.  For example, we have significantly scaled back our pace of new U.S. rig construction and will make further adjustments based on the outcome of ongoing discussions regarding additional rig awards.  During the quarter, we continued to demonstrate our ability to secure these rig awards, with three additional U.S new-build contracts: two PACE®-X rigs and another one of our proprietary coiled tubing drilling units under a six-year contract for work on the North Slope of Alaska.

“The most notable achievement of 2014 was continued improvement of our safety record. Both our U.S. Lower 48 and worldwide total recordable incidence rate were the lowest ever at less than one incident per 200,000 man-hours.  As noteworthy as this record is, no incident is acceptable to us and we remain focused on our ultimate goal of zero incidents.”

Drilling and Rig Services

Operating income in the Drilling & Rig Services business line was essentially flat at $189.6 million from $218.3 million in the third quarter, when included a $30 million final payment from a 2013 contract termination.  Adjusted EBITDA in this unit improved by approximately $6 million exclusive of the termination payment.

U.S. Drilling operating income of $90.5 million represents a decrease of $26.7 million sequentially, reflecting the $30 million termination payment received in the third quarter, modest improvement in the U.S. Lower 48 operations and seasonal improvement in Alaska, partially offset by slower activity in the U.S. Gulf of Mexico.  In the Lower 48 operation, exclusive of the effect of the termination payment, the fourth quarter’s results include an increase in daily rig margins of approximately $236, reflecting improved pricing and mix, and four fewer average rigs working as customers began to rationalize their capital spending budgets.  Demand for PACE®-X rigs continues as indicated by the award of two additional rigs.  The total number of contracted PACE®-X rig awards is now 41, with 16 deployments for the year and 36 deployed in aggregate to date.  Utilization for AC rigs was 89%, while SCR rig utilization was 44% overall and 65% for the pad-capable units.  This operation deployed five PACE®-X rigs in the fourth quarter and plans to complete 17 additional rigs during 2015, nine of which have contracts.  Activity in Alaska should improve significantly in the seasonally high first quarter, with lower but meaningful year-over-year improvement in the subsequent quarters of 2015.  The Company expects lower results in the Gulf of Mexico until the fourth quarter, when its new deepwater platform is scheduled to commence operations.

International operating income increased by approximately 11% sequentially to $75.7 million, principally reflecting new rig startups, partially offset by rig moves and rig releases in Mexico, rig downtime, and lower operating results in Venezuela.  For 2015, results should benefit from full-year contributions of the recent rig deployments in Saudi Arabia, plus partial years from the awards announced last quarter.  In Mexico, two recently completed newbuild platform rigs are set to commence in the second quarter.  Partially offsetting these developments is the wind-down in the first half of 2015 of a successful, multi-year, two-rig project in Papua New Guinea. The International customer base has not been immune to the decline in oil prices since mid-year 2014.  Demand for newbuild rigs has softened and several customers have requested price adjustments, a trend that could continue through 2015.

Canada operating income increased sequentially to $14.6 million from $11.5 million in the third quarter.  Demand in this market has weakened and warm weather is leading to lower than expected first quarter results this year.

Rig Services operating income declined sequentially by 58% to $8.8 million, due to declines at both Canrig and Ryan.  Canrig’s capital equipment margins declined for both third-party customers and Nabors. Ryan Directional Services’ business was the first among our operations to experience lower utilization and aggressive competition as a result of the recent reductions in U.S. drilling activity.

Completion & Production Services

The Completion & Production Services business line recorded operating income of $16.7 million, with adjusted EBITDA of $73.7 million.  Seasonal declines, competitive pricing and multiple large customer spending reductions led to sequential declines in both businesses.

In Completion Services, operating income was $4.9 million, despite the second highest quarterly stage count in this operation’s history, with the return of price competition and persistent higher logistics costs.

Production Services saw a sequential decrease of $9.4 million in operating income, primarily attributable to the aforementioned seasonality and continuing budget constraints of key customers.  Average rig pricing improved slightly during the quarter.

Financial Discussion

The financial results for the fourth quarter included a number of exceptional charges, totaling approximately $1.2 billion ($982.7 million tax effected), related to the current industry downturn and to the pending transaction with C&J Energy Services. Market conditions drove pre-tax impairments of both underutilized assets and goodwill amounting to $612 million and $387 million, respectively. Approximately two-thirds of the asset impairments relate to legacy rigs and associated equipment, including the workover jackups in the U.S. Drilling segment. These rigs have experienced a decline in utilization over the last several years. The potential financial return does not justify investment in necessary repair, recertification, or inspection of this legacy rig equipment.  Most of the balance of the impaired assets consists of underutilized rigs and components in International operations and Canrig component inventory, while a majority of the goodwill impairments are associated with Completion Services.

As previously disclosed, the C&J deal required the restructuring of several of our legal entities in preparation for the pending closing of the transaction. This internal reorganization had a tax impact of approximately $180 million, essentially non-cash. The financial results also included various transaction costs related to the C&J transaction totaling $5 million before taxes.

William Restrepo, Nabors CFO, stated, “While our liquidity and financial flexibility remain strong, we are moving swiftly to reduce all aspects of our operating, support and capital costs in the current environment.  In addition to curtailing our newbuild program, we have reduced staffing levels and have begun consolidating our operating footprint.  We have also made progress working with our vendors to reduce costs across our supply chain.   Our target remains to generate positive free cash flow during 2015.”

In February, the Company expanded its revolving line of credit by $225 million. In addition, the Company announced the expansion of its financial capacity with the establishment of an unsecured

three-year $300 million bank loan.  The proceeds are being used to redeem outstanding short-term commercial paper as it matures.  The loan agreement dictates repayment of the outstanding borrowings upon receipt of the $688 million cash proceeds it expects to receive from the pending transaction with C&J Energy Services.

Outlook and Summary

The Company expects further improvement in International and Alaska drilling operations, more than offset by sharp decreases in the U.S. Lower 48 operations and smaller, but significant, decreases in the U.S. Offshore, Canada and Rig Services operations.  Similarly, the Company foresees smaller but still meaningful decreases in its Completion & Production Services businesses.   While the International unit is still expected to progressively improve this year, the improvement will be less significant than previously anticipated and the potential for geopolitical interruptions is higher.

Petrello concluded, “Our transaction with C&J Energy Services is now awaiting the outcome of the C&J shareholder vote, scheduled for March 20. Assuming a favorable outcome, we anticipate closing the transaction the following week.”

About Nabors

The Nabors companies own and operate approximately 466 land drilling rigs throughout the world and approximately 543 land workover and well servicing rigs in North America. Nabors’ actively marketed offshore fleet consists of seven jackups and 36 platform 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 800,000 hydraulic horsepower currently in service. Nabors also manufactures top drives and drilling instrumentation systems.  Nabors participates in most of the significant oil and gas markets in the world.

The information above 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 certain risks and uncertainties, as disclosed by Nabors from time to time in its filings with the Securities and Exchange Commission. As a result of these factors, Nabors’ actual results may differ materially from those indicated or implied by such forward-looking statements.  The projections contained in this release reflect management’s estimates as of the date of the release.  Nabors does not undertake to update these forward-looking statements.

Important Additional Information

In connection with the proposed transactions, Nabors Red Lion Limited (which will be renamed C&J Energy Services Ltd. as of the closing of the proposed transaction) (“Red Lion”) has filed with the SEC a registration statement on Form S-4 that includes a proxy statement of C&J Energy Services, Inc. (“C&J”) that also constitutes a prospectus of Red Lion. On February 13, 2015, the registration statement was declared effective by the SEC, C&J filed a definitive proxy statement with the SEC, and Red Lion filed a definitive prospectus with the SEC.  Each of Red Lion and C&J also plans to file other relevant documents with the SEC regarding the proposed transactions. This material is not a substitute for the final prospectus/proxy statement or any other documents the parties will file with the SEC. Mailing of the definitive proxy statement/prospectus to the stockholders of C&J

commenced on February 13, 2015. INVESTORS ARE URGED TO READ THE DEFINITIVE PROXY STATEMENT/PROSPECTUS (INCLUDING ALL AMENDMENTS AND SUPPLEMENTS THERETO) AND OTHER RELEVANT DOCUMENTS FILED WITH THE SEC IF AND WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION. You may obtain a free copy of the registration statement, the definitive joint proxy statement/prospectus and other relevant documents filed by Red Lion and C&J with the SEC at the SEC’s website at www.sec.gov.  You may also obtain copies of the documents filed by Red Lion with the SEC free of charge on Nabors Industries Ltd.’s (“Nabors”) website at www.nabors.com, and copies of the documents filed by C&J with the SEC are available free of charge on C&J’s website at www.cjenergy.com.

Participants in the Solicitation

Red Lion, C&J and Nabors and their respective directors and executive officers and other members of management and employees may be deemed to be participants in the solicitation of proxies in respect of the proposed transactions.  Information about C&J’s directors and executive officers is available in C&J’s proxy statement dated April 10, 2014, for its 2014 annual meeting of shareholders.  Information about Nabors’ directors and executive officers is available in Nabors’ proxy statement dated April 30, 2014, for its 2014 annual meeting of shareholders.  Other information regarding the participants in the proxy solicitations and a description of their direct and indirect interests, by security holdings or otherwise, will be contained in the proxy statement/prospectus and other relevant materials to be filed with the SEC regarding the proposed transactions when they become available. Investors should read the proxy statement/prospectus carefully before making any voting or investment decisions. You may obtain free copies of these documents from C&J and Nabors using the sources indicated above.

This document shall not constitute an offer to sell or the solicitation of an offer to buy any securities, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the U.S. Securities Act of 1933, as amended.

MEDIA CONTACT:

Dennis A. Smith, Director of Corporate Development & Investor Relations, +1 281-775-8038.  To request investor materials, contact Nabors’ corporate headquarters in Hamilton, Bermuda at +441-292-1510 or via e-mail at mark.andrews@nabors.com

SOURCE: Nabors Industries Ltd.

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (LOSS)

(Unaudited)

	Three Months Ended									Year Ended
	December 31,						September 30,			December 31,
(In thousands, except per share amounts)	2014			2013			2014			2014			2013
Revenues and other income:
Operating revenues	$	1,783,836		$	1,606,978		$	1,813,762		$	6,804,197		$	6,152,015
Earnings (losses) from unconsolidated affiliates	(429		)	(1,588		)	(2,851		)	(6,301		)	39
Investment income (loss)	1,596			1,106			2,189			11,831			96,577
Total revenues and other income	1,785,003			1,606,496			1,813,100			6,809,727			6,248,631
Costs and other deductions:
Direct costs	1,194,844			1,032,841			1,181,986			4,505,064			3,981,828
General and administrative expenses	142,871			135,307			138,967			549,734			525,330
Depreciation and amortization	293,572			277,658			286,581			1,145,100			1,086,677
Interest expense	43,697			47,075			43,138			177,948			223,418
Losses (gains) on sales and disposals of long-lived assets and other expense (income), net	9,606			10,732			(18,513		)	9,073			37,977
Impairments and other charges	1,010,423			—			17,000			1,027,423			287,241
Total costs and other deductions	2,695,013			1,503,613			1,649,159			7,414,342			6,142,471
Income (loss) from continuing operations before income taxes	(910,010		)	102,883			163,941			(604,615		)	106,160
Income tax expense (benefit)	(23,609		)	(26,383		)	61,511			62,666			(55,181		)
Subsidiary preferred stock dividend	—			750			—			1,984			3,000
Income (loss) from continuing operations, net of tax	(886,401		)	128,516			102,430			(669,265		)	158,341
Income (loss) from discontinued operations, net of tax	(4,467		)	23,113			4,005			21			(11,179		)
Net income (loss)	(890,868		)	151,629			106,435			(669,244		)	147,162
Less: Net (income) loss attributable to noncontrolling interest	(202		)	(1,026		)	(387		)	(1,415		)	(7,180		)
Net income (loss) attributable to Nabors	$	(891,070	)	$	150,603		$	106,048		$	(670,659	)	$	139,982
Earnings (losses) per share: (1)
Basic from continuing operations	$	(3.06	)	$	.43		$	.34		$	(2.28	)	$	.51
Basic from discontinued operations	(.02		)	.07			.02			—			(.04		)
Basic	$	(3.08	)	$	.50		$	.36		$	(2.28	)	$	.47
Diluted from continuing operations	$	(3.06	)	$	.42		$	.34		$	(2.28	)	$	.51
Diluted from discontinued operations	(.02		)	.08			.01			—			(.04		)
Diluted	$	(3.08	)	$	.50		$	.35		$	(2.28	)	$	.47
Weighted-average number of common shares outstanding: (1)
Basic	284,938			295,218			292,621			290,694			294,182
Diluted	284,938			297,746			295,005			290,694			296,592
Adjusted EBITDA (2)	$	445,692		$	437,242		$	489,958		$	1,743,098		$	1,644,896
Adjusted income (loss) derived from operating activities (3)	$	152,120		$	159,584		$	203,377		$	597,998		$	558,219

(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 and general and administrative expenses 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”.
(3)	Adjusted income (loss) derived from operating activities is computed by subtracting the sum of direct costs, general and administrative expenses and depreciation and amortization 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”.

1-1

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

			(Unaudited)
	December 31,		September 30,		December 31,
(In thousands, except ratios)	2014		2014		2013
ASSETS
Current assets:
Cash and short-term investments	$	536,169	$	464,818	$	507,133
Accounts receivable, net	1,517,503		1,624,441		1,399,543
Assets held for sale	146,467		158,327		243,264
Other current assets	541,735		544,885		603,890
Total current assets	2,741,874		2,792,471		2,753,830
Long-term investments and other receivables	2,806		2,568		3,236
Property, plant and equipment, net	8,599,125		9,016,508		8,597,813
Goodwill	173,928		512,203		512,964
Investment in unconsolidated affiliates	58,251		60,451		64,260
Other long-term assets	303,958		235,139		227,708
Total assets	$	11,879,942	$	12,619,340	$	12,159,811
LIABILITIES AND EQUITY
Current liabilities:
Current debt	$	6,190	$	196	$	10,185
Other current liabilities	1,561,285		1,415,385		1,301,239
Total current liabilities	1,567,475		1,415,581		1,311,424
Long-term debt	4,348,859		4,255,136		3,904,117
Other long-term liabilities	1,044,819		1,075,389		893,905
Total liabilities	6,961,153		6,746,106		6,109,446
Subsidiary preferred stock (1)	—		—		69,188
Equity:
Shareholders’ equity	4,908,619		5,862,873		5,969,086
Noncontrolling interest	10,170		10,361		12,091
Total equity	4,918,789		5,873,234		5,981,177
Total liabilities and equity	$	11,879,942	$	12,619,340	$	12,159,811

(1)Represents subsidiary preferred stock from acquisition in September 2010.  All 75,000 outstanding shares were redeemed in June 2014.

1-2

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									Year Ended
	December 31,						September 30,			December 31,
(In thousands, except rig activity)	2014			2013			2014			2014			2013
Reportable segments:
Operating revenues and Earnings (losses) from unconsolidated affiliates:
Drilling and Rig Services:
U.S.	$	544,862		$	471,027		$	571,736		$	2,159,968		$	1,914,786
Canada	88,219			88,623			80,491			335,192			361,676
International	432,084			407,615			424,698			1,623,102			1,464,264
Rig Services (1)	190,399			132,502			191,437			687,302			516,004
Subtotal Drilling and Rig Services (2)	1,255,564			1,099,767			1,268,362			4,805,564			4,256,730
Completion and Production Services:
Completion Services	361,796			292,039			352,027			1,218,361			1,074,713
Production Services	239,897			266,235			259,863			1,033,538			1,009,214
Subtotal Completion and Production Services (3)	601,693			558,274			611,890			2,251,899			2,083,927
Other reconciling items (4)	(73,850		)	(52,651		)	(69,341		)	(259,567		)	(188,603		)
Total operating revenues and earnings (losses) from unconsolidated affiliates	$	1,783,407		$	1,605,390		$	1,810,911		$	6,797,896		$	6,152,054
Adjusted EBITDA: (5)
Drilling and Rig Services:
U.S.	$	207,001		$	187,426		$	234,980		$	835,679		$	755,706
Canada	28,315			29,159			25,804			108,454			118,989
International	173,248			157,720			159,588			610,163			524,492
Rig Services (1)	17,507			5,937			30,153			81,327			28,111
Subtotal Drilling and Rig Services (2)	426,071			380,242			450,525			1,635,623			1,427,298
Completion and Production Services:
Completion Services	33,372			40,851			40,507			94,839			160,964
Production Services	40,284			55,574			49,312			207,919			205,632
Subtotal Completion and Production Services (3)	73,656			96,425			89,819			302,758			366,596
Other reconciling items (6)	(54,035		)	(39,425		)	(50,386		)	(195,283		)	(148,998		)
Total adjusted EBITDA	$	445,692		$	437,242		$	489,958		$	1,743,098		$	1,644,896
Adjusted income (loss) derived from operating activities: (7)
Drilling and Rig Services:
U.S.	$	90,490		$	75,378		$	117,212		$	370,173		$	315,496
Canada	14,566			14,536			11,517			52,468			61,193
International	75,664			69,612			68,452			242,818			177,833
Rig Services (1)	8,845			(2,179		)	21,136			47,768			(3,918		)
Subtotal Drilling and Rig Services (2)	189,565			157,347			218,317			713,227			550,604
Completion and Production Services:
Completion Services	4,927			14,072			14,211			(15,078		)	51,722
Production Services	11,752			26,736			21,182			93,414			102,130
Subtotal Completion and Production Services (3)	16,679			40,808			35,393			78,336			153,852
Other reconciling items (6)	(54,124		)	(38,571		)	(50,333		)	(193,565		)	(146,237		)
Total adjusted income (loss) derived from operating activities	$	152,120		$	159,584		$	203,377		$	597,998		$	558,219
Rig activity:
Rig years: (8)
U.S.	212.2			198.4			216.0			212.5			195.0
Canada	36.9			32.5			34.3			34.1			29.9
International (9)	121.2			124.6			130.1			127.1			124.2
Total rig years	370.3			355.5			380.4			373.7			349.1
Rig hours: (10)
U.S. Production Services	183,102			205,456			205,604			809,438			865,939
Canada Production Services	33,218			36,455			36,509			139,938			152,747
Total rig hours	216,320			241,911			242,113			949,376			1,018,686

1-3

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

(2)Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of ($.6) million, $(1.4) million and ($2.9) million for the three months ended December 31, 2014 and 2013 and September 30, 2014, respectively, and ($6.8) million and ($.4) million for the years ended December 31, 2014 and 2013, respectively.

(3)Includes earnings (losses), net from unconsolidated affiliates, accounted for using the equity method, of $.2 million, $(.2) million and $0 million for the three months ended December 31, 2014 and 2013 and September 30, 2014, respectively, and $.5 million and $.4 million for the years ended December 31, 2014 and 2013, respectively.

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

(5)Adjusted EBITDA is computed by subtracting the sum of direct costs and general and administrative expenses 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”.

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

(7)Adjusted income (loss) derived from operating activities is computed by subtracting the sum of direct costs, general and administrative expenses and depreciation and amortization 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”.

(8)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.

(9)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 December 31, 2014 and 2013 and September 30, 2014 and 2.5 years for each of the years ended December 31, 2014 and 2013.

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

1-4

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

RECONCILIATION OF NON-GAAP FINANCIAL MEASURES TO

INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAXES

(Unaudited)

	Three Months Ended									Year Ended
	December 31,						September 30,			December 31,
(In thousands)	2014			2013			2014			2014			2013
Adjusted EBITDA	$	445,692		$	437,242		$	489,958		$	1,743,098		$	1,644,896
Less: Depreciation and amortization	293,572			277,658			286,581			1,145,100			1,086,677
Adjusted income (loss) derived from operating activities	152,120			159,584			203,377			597,998			558,219
Interest expense	(43,697		)	(47,075		)	(43,138		)	(177,948		)	(223,418		)
Investment income (loss)	1,596			1,106			2,189			11,831			96,577
Gains (losses) on sales and disposals of long-lived assets and other income (expense), net	(9,606		)	(10,732		)	18,513			(9,073		)	(37,977		)
Impairments and other charges	(1,010,423		)	—			(17,000		)	(1,027,423		)	(287,241		)
Income (loss) from continuing operations before income taxes	$	(910,010	)	$	102,883		$	163,941		$	(604,615	)	$	106,160

1-5

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									Year Ended
	December 31,						September 30,			December 31,
(In thousands, except per share amounts)	2014			2013			2014			2014			2013
BASIC EPS:
Income (loss) from continuing operations, net of tax	$	(886,401	)	$	128,516		$	102,430		$	(669,265	)	$	158,341
Less: Net (income) loss attributable to noncontrolling interest	(202		)	(1,026		)	(387		)	(1,415		)	(7,180		)
Less: Redemption of preferred shares	—			—			—			(1,688		)	—
Less: Earnings allocated to unvested shareholders	13,881			(1,948		)	(1,579		)	10,595			(1,277		)
Adjusted income (loss) from continuing operations - basic and diluted	$	(872,722	)	$	125,542		$	100,464		$	(661,773	)	$	149,884
Income (loss) from discontinued operations, net of tax	$	(4,467	)	$	23,113		$	4,005		$	21		$	(11,179	)
Weighted-average number of shares outstanding-basic	284,938			295,218			292,621			290,694			294,182
Earnings (losses) per share:
Basic from continuing operations	$	(3.06	)	$	.43		$	.34		$	(2.28	)	$	.51
Basic from discontinued operations	(.02		)	.07			.02			—			(.04		)
Total Basic	$	(3.08	)	$	.50		$	.36		$	(2.28	)	$	.47
DILUTED EPS:
Income (loss) from continuing operations attributed to common shareholders	$	(872,722	)	$	125,542		$	100,464		$	(661,773	)	$	149,884
Add: Effect of reallocating undistributed earnings of unvested shareholders	—			15			11			—			20
Adjusted income (loss) from continuing operations attributed to common shareholders	$	(872,722	)	$	125,557		$	100,475		$	(661,773	)	$	149,904
Income (loss) from discontinued operations	$	(4,467	)	$	23,113		$	4,005		$	21		$	(11,179	)
Weighted-average number of shares outstanding-basic	284,938			295,218			292,621			290,694			294,182
Add: dilutive effect of potential common shares	—			2,528			2,384			—			2,410
Weighted-average number of diluted shares outstanding	284,938			297,746			295,005			290,694			296,592
Diluted from continuing operations	$	(3.06	)	$	.42		$	.34		$	(2.28	)	$	.51
Diluted from discontinued operations	(.02		)	.08			.01			—			(.04		)
Total Diluted	$	(3.08	)	$	.50		$	.35		$	(2.28	)	$	.47

Restricted stock grants that contain non-forfeitable rights to dividends are considered participating securities.  As such, these grants are included in our basic and diluted earnings (losses) per share computation using the two-class method of accounting.  For all periods presented, the computation of diluted earnings (losses) per share excluded outstanding stock options 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 that were excluded from diluted earnings (losses) per share that would have potentially diluted earnings (losses) per share were 11,485,314 and 10,908,160 shares during the three months ended December 31, 2014 and 2013, respectively; 5,389,090 shares during the three months ended September 30, 2014; and 12,950,249 and 11,642,417 shares during the years ended December 31, 2014 and 2013, respectively. In any period during which the average market price of Nabors’ common shares exceeds the exercise prices of these stock options, such stock options are included in our diluted earnings (losses) per share computation using the if-converted method of accounting.

1-6

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF INCOME (LOSS) ITEMS EXCLUDING CERTAIN NON-CASH CHARGES
AND OTHER NON-OPERATIONAL ITEMS (NON-GAAP)

(Unaudited)

				Non-Cash Charges and Non-Operational			As adjusted
	Actuals			Items			(Non-GAAP)
(In thousands, except per share amounts)	Three Months Ended December 31, 2014
Income (loss) from continuing operations, net of tax	$	(886,401	)	$	(982,685	)	$	96,284
Diluted earnings (losses) per share from continuing operations	$	(3.06	)	$	(3.39	)	$	0.33
	Three Months Ended September 30, 2014
Income (loss) from continuing operations, net of tax	$	102,430		$	(14,300	)	$	116,730
Diluted earnings (losses) per share from continuing operations	$	0.34		$	(0.05	)	$	0.39

1-7

NABORS INDUSTRIES LTD. AND SUBSIDIARIES

SCHEDULE OF NON-CASH CHARGES AND OTHER NON-OPERATIONAL ITEMS (NON-GAAP)

(Unaudited)

	Three Months Ended
	December 31, 2014				September 30, 2014
			Per Diluted					Per Diluted
(In thousands, except per share amounts)	2014		Share		2014			Share
Retirements & impairments to underutilized assets (1)	$	431,242	$	1.49	$	—		$	—
Goodwill and intangible asset impairments (2)	359,611		1.24		—			—
Other non-operational items (3)	11,759		.03		13,062			.04
Restructuring tax effect (4)	180,073		.63		18,261			.07
Sale of Alaska E&P business (5)	—		—		(17,023		)	(.06		)
Total Adjustments, net of tax	$	982,685	$	3.39	$	14,300		$	.05

(1) Represents retirements and impairments related to underutilized assets, net of tax of $180.4 million.

(2) Represents impairments to goodwill and intangible assets, net of tax of $26.9 million.

(3) Represents losses related to the impairment of an equity investment, debt buybacks and transaction costs, net of tax of $2.9 million for the three months ended December 31, 2014 and transaction costs, net of tax of $3.9 million for the three months ended September 30, 2014.

(4) Represents the tax effect of internal restructuring.

(5) Represents the gain on the divestiture of our Alaska E&P business, net of tax of $5.1 million.

1-8

EX-99.2

Exhibit 99.2

4Q14 Earnings Presentation March 3, 2015 Presenters: Anthony G. Petrello Chairman, President & Chief Executive Officer William Restrepo Chief Financial Officer

Forward-Looking Statements 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 statement within the meaning of the safe harbor provisions of Section 27A of the U.S. Securities Act of 1933, as amended (the “Securities Act”) and Section 21E of the U.S. Securities Exchange Act of 1934. These forward-looking statement 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. Factors to consider when evaluating these forward-looking statements include, but are not limited to: 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. Statements made in this presentation include non-GAAP financial measures. The required reconciliation to GAAP financial measures are included on our website. 2

Important Additional Information 3 In connection with the proposed transactions, Nabors Red Lion Limited (which will be renamed C&J Energy Services Ltd. as of the closing of the proposed transaction) (“Red Lion”) has filed with the SEC a registration statement on Form S-4 that includes a proxy statement of C&J Energy Services, Inc. (“C&J”) that also constitutes a prospectus of Red Lion. On February 13, 2015, the registration statement was declared effective by the SEC, C&J filed a definitive proxy statement with the SEC, and Red Lion filed a definitive prospectus with the SEC. Each of Red Lion and C&J also plans to file other relevant documents with the SEC regarding the proposed transactions. This material is not a substitute for the final prospectus/proxy statement or any other documents the parties will file with the SEC. Mailing of the definitive proxy statement/prospectus to the stockholders of C&J commenced on February 13, 2015. INVESTORS ARE URGED TO READ THE DEFINITIVE PROXY STATEMENT/PROSPECTUS (INCLUDING ALL AMENDMENTS AND SUPPLEMENTS THERETO) AND OTHER RELEVANT DOCUMENTS FILED WITH THE SEC IF AND WHEN THEY BECOME AVAILABLE BECAUSE THEY WILL CONTAIN IMPORTANT INFORMATION. You may obtain a free copy of the registration statement, the definitive joint proxy statement/prospectus and other relevant documents filed by Red Lion and C&J with the SEC at the SEC’s website at www.sec.gov. You may also obtain copies of the documents filed by Red Lion with the SEC free of charge on C&J’s website at www.cjenergy.com C Participants in the Solicitation Red Lion, C&J and Nabors and their respective directors and executive officers and other members of management and employees may be deemed to be participants in the solicitation of proxies in respect of the proposed transactions. Information about Cs 30, 2014, for its 2014 annual meeting of shareholders. Other information regarding the participants in the proxy solicitations and a description of their direct and indirect interests, by security holdings or otherwise, will be contained in the proxy statement/prospectus and other relevant materials to be filed with the SEC regarding the proposed transactions when they become available. Investors should read the proxy statement/prospectus carefully before making any voting or investment decisions. You may obtain free copies of these documents from C&J and Nabors using the sources indicated above. This document shall not constitute an offer to sell or the solicitation of an offer to buy any securities, nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the U.S. Securities Act of 1933, as amended.

4 Recent Highlights

5 Financial Summary ($000’s except EPS) 4Q13 1Q14 2Q14 3Q14 4Q14 Revenue $1,605,390 $1,587,173 $1,616,405 $1,810,911 $1,783,407 Adjusted EBITDA 437,242 391,168 416,280 489,958 445,692 Operating Income 159,584 109,041 133,460 203,377 152,120 Diluted EPS(1) $0.42 $0.16 $0.21(2) $0.34(3) ($3.06)(4) (1) Diluted EPS from continuing operations (2) Includes several charges related to businesses in the process of being disposed and the redemption of SWSI preferred stock, which net to a loss of approximately 3¢ per share (3) Includes charges of 5¢ per share for income tax and merger-related fees, net of early termination payment, gain on sale of Alaska E&P and other items (4) Includes charges and impairments of $3.39 per share related to asset impairments and transaction costs Financials reflect reclassification of Peak to discontinued operations

Combination of Nabors Completion & Production Services with C&J Energy Services 6 > Update S-4 Filed, became effective Febuary 13, 2015 C&J shareholder special meeting to approve transaction set for March 20, 2015 Expected to close the week of March 23, 2015 > Combination creates: 5th largest stimulation fleet in North America Largest fluids management fleet in North America 2nd largest workover/well-servicing fleet in North America Enhanced prospects for international expansion through a global alliance agreement > Nearly 1.2 MM HHP of pressure pumping capacity across the US 543 workover rigs in the US and Canada ~1,500 fluid management trucks

High 3/31/12 3Q14 9/30/14 Liquidity 12/31/14 Change 4Q14 from High Change 3Q14 to 4Q14 ($MM's) Total Debt $4,773 $4,255 $4,355 ($418) $100 Cash and ST Investments 494 465 536 42 71 Net Debt $4,279 $3,791 $3,819 ($460) $28 Net Debt to Capitalization(1) 42.4% 39.3% 43.8% 1.4% 4.5% Coverage(2) 7.8x 9.6x 9.8x 2.0x 0.2x Leverage(3) 2.5x 2.5x 2.5x 0.0 0.0 Improving Financial Flexibility 7 (1) Capitalization defined as Net Debt plus Shareholders’ Equity (2) Coverage defined as LTM Adjusted EBITDA / LTM Interest Expense (3) Leverage defined as Total Debt / LTM Adjusted EBITDA (4) Post C&J transaction and assumes additional revolver capacity (5) C&J stock price as of 12/31/14 subject to six month lockup Note: Subtotals may not foot due to rounding Liquidity (as of December 31, 2014) Cash & Available Capacity: $1,053 Liquidity Pro Forma C&J Transaction (at December 31, 2014) Cash & Available Capacity(4): $1,966 C&J stock(5): $825

8 Drilling & Rig Services

4Q14 Rig Utilization & Availability 9 Rig Fleet(1) 4Q14 Rig Years Average Utilization U.S. Lower 48 AC 165 154 93% Legacy(2) 88 45 51% U.S. Lower 48 Total 253 198 78% U.S. Offshore 16 8 50% Alaska 19 6 32% Canada 57 37 65% International 153 121 79% Subtotal 498 370 74% PACE®-X Construction(3) 17 Intl. Newbuilds & Upgrades(3) 8 U.S. & Intl. Offshore Newbuilds(3) 3 Total Fleet 526 (1) As of 12/31/14 (2) After impairment (3) Includes announced newbuild commitments and rigs to be completed in 2015

4Q14 U.S. Rig Utilization Power Type and Pad Capability 10 As of 12/31/14 Walking Skidding Pad Capable Not Pad Capable Total Working Total Util. Working Total Util. Total Working Total Util. AC 99 109 91% 17 18 94% 91% 30 38 79% 88% SCR 4 6 67% 7 11 64% 65% 27 71 38% 43% Mech 1 26 4% 4% Grand Total 103 115 90% 24 29 83% 88% 58 135 43% 66%

0 5 10 15 20 25 30 35 1Q13 2Q13 3Q13 4Q13 1Q14 2Q14 3Q14 4Q14 Deployments Cumulative Deployments Cumulative Rig Years PACE-X Rig Deployments & Rig Years 11 > 30 PACE®-X Rig Years through 4Q14

4Q14 International Working Rigs 12 Algeria 10 Ecuador 5 Kurdistan 2 Romania 1 Angola 1 India 3 Kuwait 2 Russia 6 Argentina 22 Iraq 1 Malaysia 1 Saudi Arabia 40 Bahrain 1 Italy 1 Mexico 7 Venezuela 5 Colombia 8 Kazakhstan 2 Oman 5 Yemen 2 Congo 1 PNG 2 Australia 1 Total 128 As of 12/31/14

13 Completion & Production Services

U.S. Completion & Production Services Fleet Region Rigs Frac Crews Trucks Frac Tanks CTU Cementing Wireline SWD Western 181 538 1,924 15 12 2 Rockies 76 7 61 322 2 9 10 2 Mid-Con 35 1 96 447 8 11 5 Northeast 7 4 100 597 38 13 West Texas 106 5 328 1,271 3 4 6 12 South Texas 25 2 218 492 7 3 Ark-La-Tex 15 119 274 7 Gulf Coast 4 San Angelo 10 Total 445 19 1,460 5,327 30 82 42 29 14 As of 12/31/14

15 Outlook and Summary

Key Takeaways 16 > Focus efforts to balance current market pricing and utilization, while adjusting our cost structure and capital spending as necessary. > Pursue opportunities to add rigs in high-spec drilling markets around the globe at attractive risk-adjusted rates of return > Invest in technology that advances our position as a high performance driller > Pending merger restores pure-play drilling focus, enhances financial flexibility while preserving upside from improving stimulation market

17 Appendix

18 4Q14 Margins & Rig Activities 1Q14 2Q14 3Q14 4Q14 Drilling Margin (1) Rig Yrs Margin (1) Rig Yrs Margin (1) Rig Yrs Margin (1) Rig Yrs U.S. Drilling $11,073 206.6 $11,380 215.3 $12,756(2) 216.0 $11,525 212.2 Canada 11,452 43.8 10,034 21.6 9,663 34.3 9,889 36.9 International 13,811 129.8 14,124 127.3 15,490 130.1 17,803 121.2 Production Services Rev/Hr Rig Hrs Rev/Hr Rig Hrs Rev/Hr Rig Hrs Rev/Hr Rig Hrs U.S. $576 209,982 $582 210,750 $584 205,604 $593 183,102 Canada 860 41,540 660 28,671 749 36,509 770 33,218 (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. (2) Includes early termination payment of $30 million