Ensign Energy Serv. : Ensign Energy Services Inc. - Record Revenue Drives Strong 2011 Financial Results

Ensign Energy Services Inc. - Record Revenue Drives Strong 2011 Financial Results

CALGARY, March 19, 2012 /CNW/ -

Overview

Ensign Energy Services Inc. ("Ensign" or the "Company") generated record revenue for the year ended December 31, 2011, increasing 39 percent over the prior year to $1,890.4 million.  Net income for the year ended December 31, 2011 was $212.4 million ($1.39 per common share), a 78 percent increase from $119.3 million ($0.78 per common share) recorded in 2010.  Operating earnings, expressed as EBITDA (defined as earnings before interest, income taxes, depreciation, and share-based compensation expense (recovery)), for 2011 were $502.0 million ($3.28 per common share), a 54 percent increase from EBITDA of $325.6 million ($2.13 per common share) for the year ended December 31, 2010.  Funds from operations increased 59 percent to $475.6 million ($3.11 per common share) in 2011, a record high for the Company, from $299.9 million ($1.96 per common share) in the prior year.

During the fourth quarter of 2011, the Company generated the highest fourth quarter revenue in its history, increasing 43 percent over 2010 to $578.0 million.  Net income increased 64 percent to $52.6 million ($0.34 per common share) compared to $32.1 million ($0.21 per common share) recorded in 2010.  EBITDA was $155.2 million ($1.02 per common share) for the fourth quarter of 2011, an increase of 49 percent over EBITDA of $104.0 million ($0.68 per common share) recorded in the fourth quarter of 2010.  Funds from operations were $140.5 million ($0.92 per common share) for the fourth quarter of 2011, a 55 percent increase from $90.5 million ($0.59 per common share) recorded in the fourth quarter of 2010.

The improved financial results in the fourth quarter and year ended December 31, 2011 reflect the continued recovery in demand for oilfield services and generally higher revenue rates for oilfield services as pricing, particularly in Canada, improved in line with the increased level of operating activity.  Improvements to operating results in the Company's United States and international operations were somewhat reduced by the translational impact of a weakening United States dollar against the Canadian dollar.  Although the United States dollar strengthened towards the end of the 2011 fiscal year compared to 2010, overall the United States dollar weakened approximately four percent during 2011 compared to 2010.  Improved operating results were also dampened in the Company's international operations by challenges in the Middle East and North Africa as a result of regional geopolitical issues and weather setbacks in Australia during the first half of 2011.

In the third quarter of 2011, the Company completed the acquisition of the land drilling division of Rowan Companies, Inc. ("Rowan Land Drilling"), the largest acquisition in the Company's history, adding 30 deeper capacity electric land drilling rigs to the Company's existing United States fleet.  Subsequent to the acquisition, Rowan Land Drilling was renamed Ensign US Southern Drilling LLC ("Ensign US Southern").  In addition to this acquisition, the Company added 10 new Automated Drill Rigs ("ADR®") and 16 new well servicing rigs to its equipment fleet in 2011 as part of its most recent new build program, which had been expanded throughout the year in response to customer demand for additional oilfield services equipment.  The Company's total assets grew 37 percent in 2011 to $3,048.1 million from $2,225.5 million as at December 31, 2010.

The Company increased its dividend in 2011 with the dividend declared in the fourth quarter of 2011 increasing 10.5 percent to $0.1050 per common share from the previous dividend rate of $0.0950 per common share.  During the year ended December 31, 2011, the Company declared dividends of $0.3900 per common share, an increase of nine percent over dividends of $0.3575 per common share declared in 2010.  The dividend increase represents an 18 percent compound annual growth rate since the Company first paid a dividend in 1995.

The Company added long-term debt to its capital structure in the 2011 fiscal year as it entered into USD $400.0 million of term financing to partially fund the acquisition of Rowan Land Drilling.  As a result, long-term debt as at December 31, 2011 totaled $406.0 million.  In February of 2012, the Company issued USD $300.0 million of senior unsecured notes and applied the proceeds to partially repay the USD $400.0 million term loan.  The senior unsecured notes consist of: USD $100.0 million in five year notes with an interest rate of 3.43 percent; USD $100.0 million in seven year notes with an interest rate of 3.97 percent; and USD $100.0 million in ten year notes with an interest rate of 4.54 percent.  The remaining USD $100.0 million balance of the term loan is due in February 2013.

FINANCIAL AND OPERATING HIGHLIGHTS
($ thousands, except per share data and operating information)

														Three months ended December 31										Year ended December 31
														2011			2010			% change				2011			2010			% change
Revenue														577,967			403,992			43				1,890,372			1,355,683			39
EBITDA 1														155,167			104,045			49				502,031			325,617			54
EBITDA per share 1
	Basic													$1.02			$0.68			50				$3.28			$2.13			54
	Diluted													$1.01			$0.68			49				$3.28			$2.13			54
Adjusted net income 2														57,926			36,330			59				216,654			117,406			85
Adjusted net income per share 2
	Basic													$0.38			$0.24			58				$1.42			$0.77			84
	Diluted													$0.38			$0.24			58				$1.42			$0.77			84
Net income														52,640			32,118			64				212,393			119,308			78
Net income per share
	Basic													$0.34			$0.21			62				$1.39			$0.78			78
	Diluted													$0.34			$0.21			62				$1.39			$0.78			78
Funds from operations 3														140,465			90,505			55				475,587			299,922			59
Funds from operations per share 3
	Basic													$0.92			$0.59			56				$3.11			$1.96			59
	Diluted													$0.92			$0.59			56				$3.11			$1.96			59
Weighted average shares - basic (000s)														152,844			152,733			-				152,865			152,835			-
Weighted average shares - diluted (000s)														152,994			153,076			-				153,062			153,179			-
Drilling
	Number of marketed rigs
		Canada
			Conventional											131			136			(4)				131			136			(4)
			Oil sands coring/coal bed methane											37			38			(3)				37			38			(3)
		United States												117			80			46				117			80			46
		International 4												59			59			-				59			59			-
Operating days
	Canada 5													6,000			5,789			4				22,750			18,787			21
	United States													6,671			4,229			58				20,827			15,254			37
	International													2,698			2,716			(1)				10,748			10,014			7
Well Servicing
	Number of marketed rigs
		Canada												103			99			4				103			99			4
		United States												36			24			50				36			24			50
	Operating hours
		Canada												38,663			36,082			7				145,220			129,564			12
		United States												25,559			16,045			59				82,453			53,618			54

1			EBITDA is defined as "income before interest, income taxes, depreciation and share-based compensation expense (recovery)".  Management believes that in addition to net income, EBITDA and EBITDA per share are useful supplemental measures as they provide an indication of the results generated by the Company's principal business activities prior to consideration of how these activities are financed, how the results are taxed in various jurisdictions or how the results are impacted by the accounting standards associated with the Company's share-based compensation plans.  EBITDA and EBITDA per share as defined above are not recognized measures under International Financial Reporting Standards and accordingly may not be comparable to measures used by other companies.
2			Adjusted net income is defined as "net income before share-based compensation expense (recovery), tax-effected using an income tax rate of 35 percent".  Adjusted net income and Adjusted net income per share are useful supplemental measures as they provide an indication of the results generated by the Company's principal business activities prior to consideration of how the results are impacted by the accounting standards associated with the Company's share-based compensation plans, net of income taxes.  Adjusted net income and Adjusted net income per share as defined above are not recognized measures under International Financial Reporting Standards and accordingly may not be comparable to measures used by other companies.
3			Funds from operations is defined as "cash provided by operating activities before the change in non-cash working capital".  Funds from operations and funds from operations per share are measures that provide additional information regarding the Company's liquidity and its ability to generate funds to finance its operations.  Management utilizes these measures to assess the Company's ability to finance operating activities and capital expenditures.  Funds from operations and funds from operations per share are not measures that have any standardized meaning prescribed by International Financial Reporting Standards and accordingly may not be comparable to similar measures used by other companies.
4			Includes workover rigs.
5			Excludes coring rig operating days.

Revenue and Oilfield Services Expense

												Three months ended December 31										Year ended December 31
($ thousands)												2011			2010			% change				2011			2010			% change
Revenue
	Canada											225,153			173,815			30				786,158			546,249			44
	United States											236,821			142,460			66				727,678			492,991			48
	International											115,993			87,717			32				376,536			316,443			19
												577,967			403,992			43				1,890,372			1,355,683			39
Oilfield services expense												411,040			290,874			41				1,322,926			984,823			34
Gross margin												166,927			113,118			48				567,446			370,860			53
Gross margin %												28.9			28.0							30.0			27.4

Revenue recorded in the year ended December 31, 2011 totaled $1,890.4 million, an increase of 39 percent over the prior year.  Revenue recorded in the fourth quarter of 2011 totaled $578.0 million, an increase of 43 percent over $404.0 million recorded in the fourth quarter of 2010.  Higher activity levels and improved revenue rates led to the revenue growth in 2011 over 2010.  In addition, the third quarter acquisition of Rowan Land Drilling, adding 30 drillings rigs to the Company's fleet, as well as an active new build program which added 10 new drilling rigs and 16 new well servicing rigs throughout the year, contributed to the year-over-year increase in revenue generated by the Company.  Partially offsetting these improvements from the Company's North American operations were certain challenges that developed in the international segment during the 2011 fiscal year. The Company's international results were negatively impacted by the disruption of operations in Libya resulting from civil unrest that commenced in the first quarter of 2011 and the temporary halting of operations in parts of Australia due to regional flooding conditions in the first half of the year.

Gross margin increased to $567.4 million (30.0 percent of revenue) in the year ended December 31, 2011 compared to $370.9 million (27.4 percent of revenue) for the corresponding period in 2010.  Similarly, gross margin increased to $166.9 million (28.9 percent of revenue) for the fourth quarter of 2011 compared with $113.1 million (28.0 percent of revenue) for the fourth quarter of 2010.  The improvement in gross margin was a result of higher revenue rates in 2011 over 2010 as prices for oilfield services generally improved in line with the higher levels of demand.  Higher major maintenance costs in 2011 compared to 2010 partially offset the increases to margins from better pricing as the Company continued to maintain and upgrade its equipment fleet during the year.  These major maintenance costs were incurred as a result of the Company preparing portions of its fleet for higher anticipated activity levels in the second half of 2011 and a busy Canadian winter drilling season in the first quarter of 2012; and are generally expensed as incurred.

Canadian Oilfield Services

													Three months ended										Year ended
													December 31										December 31
													2011			2010			% change				2011			2010			% change
Conventional drilling and coring rigs
	Opening balance												168			174							174			182
		Additions											1			-							2			-
		Transfers											-			-							1			-
		Decommissions / Disposals											(1)			-							(9)			(8)
	Ending balance												168			174			(3)				168			174			(3)
Drilling operating days1													6,000			5,789			4				22,750			18,787			21
Drilling rig utilization %													50.0			46.3			8				48.3			37.9			27
Well servicing rigs
	Opening balance												103			112							99			112
		Additions											-			1							4			1
		Decommissions / Disposals											-			(14)							-			(14)
		Ending balance											103			99			4				103			99			4
Well servicing operating hours													38,663			36,082			7				145,220			129,564			12
Well servicing utilization %													40.8			40.9			-				39.5			37.0			7

1

Excludes coring rig operating days.

Revenue generated in Canada increased 30 percent to $225.2 million for the three months ended December 31, 2011, from $173.8 million for the three months ended December 31, 2010.  The Company recorded revenue of $786.2 million in Canada for the year ended December 31, 2011, a 44 percent increase from $546.3 million recorded in the year ended December 31, 2010.  In the fourth quarter of 2011, Canadian revenues accounted for 39 percent of total revenue (2010 - 43 percent), and during the year ended December 31, 2011, Canadian revenues were 42 percent of total revenue (2010 - 40 percent).

The Company's Canadian operations benefited in 2011 from improved levels of demand and pricing for Canadian oilfield services, as crude oil prices remained at attractive levels.  Despite weakness in the price for natural gas, crude oil prices for 2011 averaged USD $100 per barrel and continued to drive development in crude oil and liquids-rich natural gas resource plays, such as the Montney, Bakken, Cardium and heavy oil resource plays.

Drilling days recorded by the Company's Canadian operations in the fourth quarter of 2011 increased four percent from the comparable quarter in the prior year.  During the year ended December 31, 2011, drilling days increased 21 percent from the same period of the prior year.  Similarly, Canadian well servicing hours increased by seven percent in the fourth quarter of 2011 and by 12 percent in the year ended December 31, 2011 compared to the corresponding periods in the prior year.

The Company decommissioned or disposed of nine inactive drilling rigs during 2011 and added three drilling rigs, two of which are new build ADRs, and four new well servicing rigs to its Canadian equipment fleet in 2011.  As previously indicated, the Canadian operations incurred higher major maintenance costs in 2011 compared to 2010, negatively impacting margins as these costs are expensed as incurred.  The equipment additions and additional major maintenance costs were incurred to take advantage of rising customer demand for oilfield services in 2011 and into 2012.

United States Oilfield Services

													Three months ended										Year ended
													December 31										December 31
													2011			2010			% change				2011			2010			% change
Conventional drilling rigs
	Opening balance												116			80							80			82
		Additions											1			-							38			2
		Transfers											-			-							(1)			(1)
		Decommissions / Disposals											-			-							-			(3)
	Ending balance												117			80			46				117			80			46
Drilling operating days													6,671			4,229			58				20,827			15,254			37
Drilling rig utilization %													62.5			57.5			9				60.7			52.5			16
Well servicing rigs
	Opening balance												34			23							24			18
		Additions											2			1							12			6
	Ending balance												36			24			50				36			24			50
Well servicing operating hours													25,559			16,045			59				82,453			53,618			54
Well servicing utilization %													78.6			74.7			5				73.4			71.9			2

The Company's United States operations recorded revenue of $236.8 million in the fourth quarter of 2011, a 66 percent increase from the $142.5 million recorded in the corresponding period of the prior year.  During the year ended December 31, 2011, revenue of $727.7 million was recorded, an increase of 48 percent from the $493.0 million recorded in the year ended December 31, 2010.  The United States segment accounted for 41 percent of the Company's revenue in the fourth quarter of 2011 (2010 - 35 percent); and 38 percent of the Company's revenue in the current year (2010 - 37 percent).

The number of drilling days recorded by the Company's United States operations in the fourth quarter of 2011 was 6,671, an increase of 58 percent over 4,229 drilling days recorded for the same period of the prior year.  Drilling days for the year ended December 31, 2011 increased 37 percent from the comparable period in the prior year to 20,827 from 15,254 drilling days in 2010.  United States well servicing hours in the fourth quarter of 2011 were up 59 percent compared to the prior year and well servicing hours for 2011 were up 54 percent compared to 2010.

The Company's United States operations experienced substantial growth in 2011, primarily a result of the third quarter acquisition of Rowan Land Drilling and its fleet of 30 ADR® style drilling rigs.  This acquisition significantly expanded the Company's operations into many of the resource plays of the southern United States.  In addition, eight new ADR® drilling rigs and 12 new well servicing rigs were added to the United States equipment fleet in 2011 as part of the Company's ongoing new build program, combining to produce strong revenue growth in this segment.

Although operating results for the United States segment were improved overall, the weakening United States dollar in 2011 compared to the prior year negatively impacted the translation to Canadian dollars of the United States division earnings.  Despite the United States dollar strengthening against the Canadian dollar towards the end of the year, the average exchange rate weakened during the twelve months ended December 31, 2011, compared to the same period in the prior year.  The average Canadian/United States dollar exchange rate at which the Company's United States results were translated to Canadian dollars for presentation purposes was 0.99 for 2011 compared to 1.03 for 2010, a four percent decline.

International Oilfield Services

													Three months ended										Year ended
													December 31										December 31
													2011			2010			% change				2011			2010			% change
Conventional drilling and workover rigs
	Opening balance												59			59							59			58
		Transfers											-			-							-			1
	Ending balance												59			59			-				59			59			-
Drilling operating days													2,698			2,716			(1)				10,748			10,014			7
Drilling rig utilization %													49.7			50.9			(2)				49.9			47.3			6

The Company's international operations recorded revenue of $116.0 million in the fourth quarter of 2011, a 32 percent increase from $87.7 million recorded in the corresponding period of the prior year.  International revenue for the year ended December 31, 2011 increased by 19 percent to $376.5 million from $316.4 million recorded for the year ended December 31, 2010.  International operations contributed 20 percent of the Company's revenue in the fourth quarter of 2011 (2010 - 22 percent) and 20 percent in the year ended December 31, 2011 (2010 - 23 percent).

International drilling days for the three months ended December 31, 2011 decreased one percent over the comparable prior year period to 2,698 drilling days compared to 2,716 drilling days in the fourth quarter of 2010.  The Company's international operations recorded 10,748 drilling days in 2011, a seven percent increase from 10,014 drilling days recorded in 2010.

Increased operating activity in the Company's Latin America operations drove the improvement in revenue and activity in 2011 compared with 2010.  Other regions experienced challenges outside of the Company's control, including disruptions of operations resulting from severe flooding in Australia and political unrest in parts of the Middle East and North Africa.  Australian operations recovered in the second half of 2011; however, the Company continues to focus on addressing challenges with respect to its Libyan operations that remain suspended since the civil unrest that started in the first quarter of 2011.

Consistent with the translation of results from the Company's United States operations, the operating results from the Company's international operations were negatively impacted on translation into Canadian dollars by the weakening of the United States dollar relative to the Canadian dollar in 2011 when compared to the prior year.

Depreciation

											Three months ended December 31										Year ended December 31
($ thousands)											2011			2010			% change				2011			2010			% change
Depreciation											57,540			35,112			64				177,927			132,980			34

The Company uses the unit of production method of calculating depreciation for the majority of its property and equipment.  Depreciation expense totaled $57.5 million for the fourth quarter of 2011 compared with $35.1 million for the fourth quarter of 2010.  Depreciation expense increased 34 percent to $177.9 million for the year ended December 31, 2011 compared with $133.0 million for the year ended December 31, 2010.  Higher depreciation expense in 2011 over 2010 is attributable to additional operating days, including the expansion of the Company's fleet through the acquisition of Rowan Land Drilling and equipment additions during the year from the Company's new build program, adding several higher-valued drilling and well servicing rigs to the equipment fleet throughout the year.  Depreciation charges for 2011 also include additional amounts of $9.2 million (2010 - $12.1 million) in respect of equipment that has been inactive for a period of 12 consecutive months or more with a limited near term outlook for future work.

General and Administrative Expense

											Three months ended December 31										Year ended December 31
($ thousands)											2011			2010			% change				2011			2010			% change
General and administrative											20,878			18,383			14				70,258			60,849			15
% of revenue											3.6			4.6							3.7			4.5

General and administrative expense increased 14 percent to $20.9 million (3.6 percent of revenue) for the fourth quarter of 2011 compared with $18.4 million (4.6 percent of revenue) for the fourth quarter of 2010.  General and administrative expense totaled $70.3 million (3.7 percent of revenue) for the year ended December 31, 2011 compared with $60.8 million (4.5 percent of revenue) for the year ended December 31, 2010, an increase of 15 percent.   The overall increase in general and administrative expense was to support the increased operating activity, the addition of Ensign US Southern in the third quarter of 2011 and higher incentive compensation costs compared to 2010.  The decrease in general and administrative expense as a percentage of revenue reflects the revenue growth in 2011 compared to 2010 as well as the Company's ongoing efforts to control fixed costs and the translational impact of a weaker United states dollar on United States and international administrative expenses.

Share-Based Compensation Expense (Recovery)

											Three months ended December 31										Year ended December 31
($ thousands)											2011			2010			% change				2011			2010			% change
Share-based compensation											8,132			6,479			26				6,555			(2,926)			(324)

Share-based compensation expense (recovery) arises from the Black-Scholes valuation accounting associated with the Company's share-based compensation plans, whereby the liability associated with share-based compensation is adjusted for the effect of granting and vesting of employee stock options and changes in the underlying price of the Company's common shares.

For the three months ended December 31, 2011, share-based compensation expense was $8.1 million compared with an expense of $6.5 million recorded in the fourth quarter of 2010.  For 2011, share-based compensation was an expense of $6.6 million compared with a recovery of $2.9 million for the year ended December 31, 2010.  The increase in share-based compensation expense for the year ended December 31, 2011 arises from the change in the fair value of share-based compensation liability primarily due to an increase in the price of the Company's common shares during the year.  The closing price of the Company's common shares was $16.25 at December 31, 2011, compared with $15.03 at December 31, 2010.

Interest Expense

											Three months ended December 31										Year ended December 31
($ thousands)											2011			2010			% change				2011			2010			% change
Interest expense											4,071			352			1,057				6,586			2,073			218
Interest income											(136)			(402)			(66)				(647)			(794)			(19)
											3,935			(50)			(7,970)				5,939			1,279			364

Interest is incurred on the Company's $10.0 million Canadian-based revolving credit facility, the global revolving credit facility, which was increased by $50.0 million in the third quarter of 2011 to a total of $250.0 million, and the Company's new USD $400.0 million 18-month term loan, incurred to partially fund the acquisition of Rowan Land Drilling.  Transaction costs related to the Company's term loan financing and revolving credit facility renewal are included in interest expense in 2011.

Foreign Exchange and Other

										Three months ended December 31										Year ended December 31
($ thousands)										2011			2010			% change				2011			2010			% change
Foreign exchange and other										(9,118)			(9,310)			(2)				(4,843)			(15,606)			(69)

The reduction in foreign exchange gain in 2011, when compared to 2010, is primarily attributable to the impact of converting the Australian operations from Australian dollars to United States dollars.  The Australian currency weakened slightly against the United States dollar during the year ended December 31, 2011, but had strengthened during the year ended December 31, 2010.

Income Taxes

											Three months ended December 31										Year ended December 31
($ thousands)											2011			2010			% change				2011			2010			% change
Current income tax											12,985			11,885			9				26,882			25,435			6
Deferred income tax											19,935			18,501			8				72,335			49,541			46
											32,920			30,386			8				99,217			74,976			32
Effective income tax rate %											38.5			48.6							31.8			38.6

The effective income tax rate for the three months ended December 31, 2011 was 38.5 percent compared with 48.6 percent for the three months ended December 31, 2010.  The effective income tax rate for the year ended December 31, 2011 was 31.8 percent compared with 38.6 percent for the year ended December 31, 2010.  The decrease in the effective income tax rate in the three and twelve months ended December 31, 2011 is due to a greater proportion of taxable income being generated in Canada and a reduced proportion of income generated in certain international jurisdictions with higher income tax rates, including jurisdictions where income taxes are based on "deemed profits" or withholding taxes on gross revenue. Consistent with 2010, the lower than expected proportion of current income tax in 2011 arises primarily from an extension of the bonus depreciation regime in the United States which results in accelerated tax deductions in relation to new qualified capital assets placed into service during the current year.

Financial Position

The following chart outlines significant changes in the consolidated statement of financial position from December 31, 2010 to December 31, 2011:

($ thousands)				Change				Explanation
Cash and cash equivalents				(86,907)				See consolidated statements of cash flows.
Accounts receivable				146,006				Increase is consistent with increased operating activity in the fourth quarter of 2011 compared to the fourth quarter of 2010.
Inventories and other				14,127				Increase is due to additional inventory and other, offset by normal course use of consumables.
Property and equipment				749,229				Increase due to the addition of 30 drilling rigs to the Company's United States fleet through the acquisition of Rowan Land Drilling as well as the current new build construction program and the impact of foreign exchange fluctuations on the consolidation of the Company's foreign subsidiaries, offset by depreciation.
Note receivable				170				Increase is due to accretion of interest income during the year.
Accounts payable and accruals				76,457				Increase is consistent with increased operating activity in the fourth quarter of 2011 compared to the fourth quarter of 2010.
Operating lines of credit				79,105				Increase is due to additional draws of the expanded operating lines of credit to partially finance the acquisition of Rowan Land Drilling, completed in the third quarter of 2011, the ongoing new build construction program, and increased operating activity offset by repayments during the year.
Share-based compensation				6,246				Increase is due to increase in the price of the Company's common shares as at December 31, 2011 compared with December 31, 2010.
Income taxes payable				5,696				Increase due to the current income tax provision for the period, net of tax instalments.
Dividends payable				1,540				Increase is due to a 10.5 percent increase in the quarterly dividend rate for the fourth quarter of 2011 compared to the fourth quarter dividend of 2010.
Long-term debt				405,953				Increase is due to the term loan obtained as partial financing of the acquisition of Rowan Land Drilling in the third quarter of 2011.
Deferred income taxes				72,361				Increase primarily due to accelerated tax depreciation of assets added in the United States during the current year and partnership timing differences in Canada.
Shareholders' equity				175,267				Increase due to net income for the year and the impact of foreign exchange rate fluctuations on net assets of foreign subsidiaries, offset by the amount of dividends declared in the year.

Funds from Operations and Working Capital

											Three months ended December 31										Year ended December 31
($ thousands)											2011			2010			% change				2011			2010			% change
Funds from operations											140,465			90,505			55				475,587			299,922			59
Funds from operations per share											$0.92			$0.59			56				$3.11			$1.96			59
Working capital											(10,233)			84,516			(112)				(10,233)			84,516			(112)

During the three months ended December 31, 2011, the Company generated funds from operations of $140.5 million ($0.92 per common share) compared with $90.5 million ($0.59 per common share) for the three months ended December 31, 2010, an increase of 55 percent.  For the year ended December 31, 2011, the Company generated funds from operations of $475.6 million ($3.11 per common share), an increase of 59 percent over $299.9 million ($1.96 per common share) generated in the year of 2010.  The increase in funds from operations in 2011 compared to 2010 is due to higher activity levels, particularly in North America, as a result of increased demand for oilfield services equipment and the expansion of the Company's fleet through the acquisition of Rowan Land Drilling and the ongoing new build program.

At December 31, 2011, the Company's working capital totaled negative $10.2 million compared to positive working capital of $84.5 million at December 31, 2010, a decrease of 112 percent.  The Company utilized its cash resources in 2011 to partially fund the acquisition of Rowan Land Drilling, which was completed in the third quarter.  This resulted in a temporary negative working capital balance on the Company's statement of financial position as at December 31, 2011; however, the Company expects the growth in operating results combined with current and future credit facilities to fully support current operating and capital requirements.  Existing revolving credit facilities provide for total borrowings of $260.0 million, of which $10.1 million was available as at December 31, 2011.

Investing Activities

											Three months ended December 31										Year ended December 31
($ thousands)											2011			2010			% change				2011			2010			% change
Purchase of property and equipment											(134,209)			(103,095)			30				(386,833)			(255,463)			51
Acquisition											-			-			-				(497,352)			-			-
Net change in non-cash working capital											(14,892)			29,248			(151)				31,510			3,593			777
Cash used in investing activities											(149,101)			(73,847)			102				(852,675)			(251,870)			239

Effective September 1, 2011 the Company acquired Rowan Land Drilling for USD $510.0 million plus working capital of USD $5.5 million.  Rowan Land Drilling was comprised of 30 deeper capacity electric land drilling rigs in the southern United States. The purchase was funded with existing cash balances and expanded credit facilities, including a new 18-month term loan of USD $400.0 million.  The Company did not complete any significant acquisitions in 2010.

Purchases of property and equipment during the fourth quarter of 2011 totaled $134.2 million (2010 - $103.1 million).  For the year ended December 31, 2011, purchases of property and equipment totaled $386.8 million (2010 - $255.5 million).  The purchases of property and equipment relate primarily to expenditures made pursuant to the Company's ongoing new build program.  Significant additions as a result of the new build program included:

• Completion of eight new ADR® drilling rigs in the United States (two in the first quarter, three in the second quarter, two in the third quarter and one in the fourth quarter);
• Construction of 12 new well servicing rigs in the United States (two in the first quarter, five in the second quarter, three in the third quarter and two in the fourth quarter);
• Completion of two new ADR® drilling rigs in Canada (one in the third quarter and one in the fourth quarter); and
• Construction of four new well servicing rigs in Canada (two in the second quarter and two in the third quarter).

Financing Activities

												Three months ended December 31										Year ended December 31
($ thousands)												2011			2010			% change				2011			2010			% change
Net increase (decrease) in operating lines of credit												6,604			27,560			(76)				73,601			(621)			(11,952)
Increase in long-term debt												-			-			-				390,080			-			-
Issue of capital stock												-			2,458			(100)				-			2,458			(100)
Purchase of shares held in trust												(674)			(642)			5				(6,202)			(2,310)			168
Purchase of common shares under Normal
	Course Issuer Bid											-			-			-				-			(2,330)			(100)
Deferred financing costs												-			-			-				(2,078)			-			-
Dividends												(16,087)			(14,546)			11				(59,752)			(54,751)			9
Net change in non-cash working capital												1,468			1,881			(22)				1,371			2,160			(37)
Cash (used in) from financing activities												(8,689)			16,711			(152)				397,020			(55,394)			(817)

The Company's global revolving credit facility (the "Global Facility") was increased by $50.0 million during 2011 to a new limit of $250.0 million.  Additionally, the Company has available a $10.0 million Canadian-based revolving credit facility (the "Canadian Facility"). The Global Facility is available to the Company and certain of its wholly-owned subsidiaries, and may be drawn in Canadian, United States or Australian dollars, up to the equivalent value of $250.0 million Canadian dollars. The amount available under the Canadian Facility is $10.0 million or the equivalent United States dollars.

Net draws of the operating lines of credit for the fourth quarter of 2011 were due to capital expenditures made pursuant to the Company's ongoing new build program.  New draws of the operating lines of credit for the year ended December 31, 2011 were the result of the acquisition of Rowan Land Drilling which was completed on September 1, 2011, as well as funding for the continuing new build program which is anticipated to deliver an additional 16 new ADR® drilling rigs and 12 new well servicing rigs throughout 2012.  As of December 31, 2011, the operating lines of credit are primarily being used to fund the completion of the new build rigs and to support international operations.

In connection with the purchase of Rowan Land Drilling, the Company entered into an unsecured term loan of USD $400.0 million. There are no mandatory principal repayments and the debt matures on February 28, 2013.  The Company incurred financing fees associated with the term loan that are being deferred and amortized using the effective interest method.  Subsequent to December 31, 2011, the Company completed the placement of USD $300.0 million of senior unsecured notes with the proceeds from the issuance being used to repay a portion of the term loan.  The senior unsecured notes consist of: USD $100.0 million in five year notes with an interest rate of 3.43 percent and a maturity date of February 22, 2017; USD $100.0 million in seven year notes with an interest rate of 3.97 percent and a maturity date of February 22, 2019; and USD $100.0 million in ten year notes with an interest rate of 4.54 percent and a maturity date of February 22, 2022.  The notes rank equally with the Company's Global Facility.

On June 3, 2011, the Company received approval from the Toronto Stock Exchange to acquire for cancellation up to five percent of the Company's issued and outstanding common shares under a Normal Course Issuer Bid (the "Bid").  The Company may purchase up to 7,660,512 common shares for cancellation.  The Bid commenced on June 7, 2011 and will terminate on June 6, 2012 or such earlier time as the Bid is completed or terminated at the option of the Company.  As at December 31, 2011, no common shares have been purchased and cancelled pursuant to the Bid.  In 2010, 200,000 common shares were purchased and cancelled under a previous bid the Company held that was terminated on May 31, 2011.

In the fourth quarter of 2011, the Company increased its quarterly dividend rate to $0.1050 per common share, a 10.5 percent increase over the dividend of $0.0950 per common share declared in the fourth quarter of 2010.  During the year ended December 31, 2011, the Company declared dividends of $0.3900 per common share, an increase of nine percent over dividends of $0.3575 per common share declared in 2010.  The Company did not issue any common shares in connection with the employee stock option program in 2011 compared to the receipt of $2.5 million in the fourth quarter of 2010 on the exercise of employee stock options for common shares in the Company.

Subsequent to December 31, 2011, the Company declared a dividend for the first quarter of 2012. A quarterly dividend of $0.1050 per common share is payable April 5, 2012 to all Common Shareholders of record as of March 27, 2012.  The dividend is pursuant to the quarterly dividend policy adopted by the Company.  Pursuant to subsection 89(1) of the Canadian Income Tax Act ("ITA"), the dividend being paid is designated as an eligible dividend, as defined in subsection 89(1) of the ITA.

New Builds

During the year ended December 31, 2011, the Company commissioned eight new ADR® drilling rigs and 12 new well servicing rigs in the United States; and two new ADR ® drilling rigs and four new well servicing rigs in Canada.

The remaining new build estimated delivery schedule, by geographic area, is as follows:

												Estimated Delivery Date
												Q1-2012			Q2-2012			Q3-2012			Q4-2012			Total
ADRs
	Canada											4			2			-			-			6
	United States											5			1			-			2			8
	International											1			1			-			-			2
Total												10			4			-			2			16
Well Servicing
	Canada											-			-			-			4			4
	United States											4			4			-			-			8
	International											-			-			-			-			-
Total												4			4			-			4			12

Outlook

General global economic conditions seem to be improving at a moderate rate as programs of quantitative easing appear to be attaining the goal of containing downside risk to the global economy.  A slightly stronger than expected North American economy has improved demand for crude oil; and continuing tensions in the Middle East have resulted in escalating concerns with respect to potential supply disruptions, particularly in the event of a disruption in crude oil supplies flowing through the Strait of Hormuz.  Improved levels of demand and concern over supply have combined to elevate crude oil prices for West Texas Intermediate (Cushing) above USD $100 per barrel.   Conversely, North American natural gas has not fared well, as supply continues to outstrip demand for this continental commodity.  Natural gas prices have declined over 40 percent in the last seven months and have recently hovered around the USD $2.50 per mmbtu level owing to an oversupply of natural gas resulting from increased production associated with many developing resource plays, particularly in the southern United States.   It is no surprise that operators have finally started to reduce the amount of drilling for natural gas and have refocused on crude oil and liquids-rich natural gas projects.  Against this backdrop, the Company currently estimates that approximately 80 percent of its drilling rigs are being utilized in crude oil and liquids-rich natural gas exploration and development programs.

The Canadian operations experienced a very good start to the 2011 fiscal year with the favorable weather conditions enjoyed in the first quarter of 2011.  The second quarter softened due to a prolonged break-up period and activity levels and operating margins recovered nicely in the last half of the year. The first quarter of 2012 also started quite strong, but it would be difficult to expect Canadian field conditions to be as good as the prior year as the weather to date has generally been warmer than the first quarter of the prior year.  Accordingly, an earlier spring break-up is expected.  While first quarter Canadian operating days will likely be down on a year-over-year basis, improved operating margins should compensate for the reduction in drilling days compared to the prior year.  It remains to be seen what the impact of the current level of natural gas prices will be on the cash flows of the operators and their projects for the remainder of 2012; however, the outlook for oilfield services generally appears positive in the Canadian market due to the expected favorable crude oil prices driving demand for crude oil and liquids-rich natural gas drilling projects.  The Company added three new ADRs and four new well servicing rigs in Canada during 2011 in order to meet customer demand for specific types of equipment.  Earnings capabilities will continue to expand in Canada with six new ADRs to be delivered under term contracts in the 2012 fiscal year.

United States activity levels continued to increase through 2011 as the Company experienced strong levels of demand for oilfield services with respect to the development of crude oil and liquids-rich resource plays.  Natural gas related drilling activity started to decline towards the end of the year as operators reacted to poor supply and demand fundamentals for the commodity.  The Company expects that dry gas drilling will reduce even further in 2012 as favorable hedges continue to run out and supply levels exceed the prior year owing to a relatively mild winter in North America.  So far the Company has successfully redeployed drilling rigs from natural gas projects to crude oil and liquids-rich natural gas projects as demand remains strong for commodities tied to the current price of crude oil.  The Company added eight new ADRs and 12 new well servicing rigs to its United States equipment fleet in 2011.  An additional eight ADRs and eight well servicing rigs will be added to the fleet in 2012.  All of the new build ADRs are backed by term contracts and are being delivered into key resource plays.  The Company expanded its capabilities in many of the key resource plays in the southern United States with the September 2011 acquisition of Rowan Land Drilling and its quality fleet of 30 ADR® style drilling rigs.  This acquisition was the largest in the history of the Company and filled in a crucial gap in the Company's coverage of the United States market.  The Company is now the fourth largest land-based drilling contractor in the United States.  As with Canada, the prospects for the Company's United States operations look good in 2012 for crude oil and liquids-rich natural gas projects, tempered by the direct and indirect consequences of the continuing decline in the demand and supply fundamentals for natural gas.

There were two main events that negatively impacted the Company's international operations in the 2011 fiscal year.  The first was the disruption of operations in Libya in February 2011 due to civil unrest owing to the so-called "Arab Spring" and the second was the disruption in activity levels in Australia resulting from extreme flooding conditions that occurred in parts of the country during the first half of 2011.  Neither of these events could have been predicted.  Operations resumed in Australia in the second half of 2011; and Libyan operations could possibly resume before the end of 2012, provided that the country remains stable and security concerns can be addressed.  All other international areas serviced by the Company are expected to remain steady in 2012 compared to 2011 owing to the high level of long-term contracts associated with international operations.  The Company's international operations will be expanded with the delivery of two new ADRs under term contracts into the Australian market in 2012.

As previously stated, the Company completed its largest acquisition to date with the successful acquisition of Rowan Land Drilling in September 2011.  In connection with this acquisition, the Company entered into an unsecured term loan of USD $400.0 million.  In February 2012, the Company repaid USD $300.0 million of this term facility using funds received from a private placement of USD $300.0 million in senior unsecured notes.  This private placement was a first for the Company and changes the capital structure in such a way as to add some leverage in the form of long-term debt, while still affording the Company the flexibility to look at additional growth opportunities in the future.

Risks and Uncertainties

This document contains forward-looking statements based upon current expectations that involve a number of business risks and uncertainties.  The factors that could cause results to differ materially include, but are not limited to, political and economic conditions, crude oil and natural gas prices, foreign currency fluctuations, weather conditions and the ability of oil and natural gas companies to raise capital or other unforeseen conditions which could impact on the use of the services supplied by the Company.

Conference Call

A conference call will be held to discuss the Company's year-end 2011 results at 2:00 p.m. MDT (4:00 p.m. EDT) on Monday, March 19, 2012.  The conference call number is [phone] (in Toronto) or 1-888-231-8191 (outside Toronto).  A taped recording will be available until March 26, 2012 by dialing 1-416-849-0833 (in Toronto) or 1-855-859-2056 (outside Toronto) and entering the reservation number 43360133.  A live broadcast may be accessed through the Company's web site at www.ensignenergy.com.

Ensign Energy Services Inc. is an international oilfield services contractor and is listed on the Toronto Stock Exchange under the trading symbol ESI.

Ensign Energy Services Inc.
Consolidated Statements of Financial Position
As at December 31			2011		2010
(Unaudited, in thousands of Canadian dollars)
Assets
Current Assets
	Cash and cash equivalents	$	2,613	$	89,520
	Accounts receivable		477,143		331,137
	Inventories and other		81,978		67,851
			561,734		488,508
Property and equipment			2,479,618		1,730,389
Note receivable			6,761		6,591
		$	3,048,113	$	2,225,488
Liabilities
Current Liabilities
	Accounts payable and accruals	$	289,541	$	213,084
	Operating lines of credit		238,440		159,335
	Income taxes payable		11,494		5,798
	Dividends payable		16,087		14,547
	Share-based compensation		16,405		11,228
			571,967		403,992
Long-term debt			405,953		-
Share-based compensation			5,304		4,235
Deferred income taxes			341,467		269,106
			1,324,691		677,333
Shareholders' Equity
	Share capital		166,864		168,206
	Contributed surplus		3,448		2,929
	Foreign currency translation reserve		1,032		(22,417)
	Retained earnings		1,552,078		1,399,437
			1,723,422		1,548,155
		$	3,048,113	$	2,225,488

Ensign Energy Services Inc.
Consolidated Statements of Income
For the three months and Year ended December 31
(Unaudited, in thousands of Canadian dollars - except per share data)
			Three months ended				Year ended
			December31		December 31		December 31		December 31
			2011		2010		2011		2010
Revenue		$	577,967	$	403,992	$	1,890,372	$	1,355,683
Expenses
	Oilfield services		411,040		290,874		1,322,926		984,823
	Depreciation		57,540		35,112		177,927		132,980
	General and administrative		20,878		18,383		70,258		60,849
	Share-based compensation		8,132		6,479		6,555		(2,926)
	Foreign exchange and other		(9,118)		(9,310)		(4,843)		(15,606)
			488,472		341,538		1,572,823		1,160,120
Income before interest and income taxes			89,495		62,454		317,549		195,563
Interest income			136		402		647		794
Interest expense			(4,071)		(352)		(6,586)		(2,073)
Income before income taxes			85,560		62,504		311,610		194,284
Income taxes
	Current tax		12,985		11,885		26,882		25,435
	Deferred tax		19,935		18,501		72,335		49,541
			32,920		30,386		99,217		74,976
Net income		$	52,640	$	32,118	$	212,393	$	119,308
Net income per share
	Basic	$	0.34	$	0.21	$	1.39	$	0.78
	Diluted	$	0.34	$	0.21	$	1.39	$	0.78

Ensign Energy Services Inc.
Consolidated Statements of Cash Flows
For the three months and Year ended December 31
(Unaudited, in thousands of Canadian dollars)
			Three months ended				Year ended
			December 31		December 31		December 31		December 31
			2011		2010		2011		2010
Cash provided by (used in)
Operating activities
Net income		$	52,640	$	32,118	$	212,393	$	119,308
Items not affecting cash
	Depreciation		57,540		35,112		177,927		132,980
	Share-based compensation, net of cash paid		9,499		4,774		11,778		(1,907)
	Accretion on long-term debt		851		-		1,154		-
	Deferred income tax		19,935		18,501		72,335		49,541
Net change in non-cash working capital			(7,641)		(22,552)		(105,101)		(33,772)
			132,824		67,953		370,486		266,150
Investing activities
Purchase of property and equipment			(134,209)		(103,095)		(386,833)		(255,463)
Acquisition			-		-		(497,352)		-
Net change in non-cash working capital			(14,892)		29,248		31,510		3,593
			(149,101)		(73,847)		(852,675)		(251,870)
Financing activities
Net increase (decrease) in operating lines of credit			6,604		27,560		73,601		(621)
Increase in long-term debt			-		-		390,080		-
Issue of capital stock			-		2,458		-		2,458
Purchase of shares held in trust			(674)		(642)		(6,202)		(2,310)
Purchase of common shares under Normal Course Issuer Bid			-		-		-		(2,330)
Deferred financing costs			-		-		(2,078)		-
Dividends			(16,087)		(14,546)		(59,752)		(54,751)
Net change in non-cash working capital			1,468		1,881		1,371		2,160
			(8,689)		16,711		397,020		(55,394)
Net (decrease)			(24,966)		10,817		(85,169)		(41,114)
	Effects of foreign exchange on cash and cash equivalents		21,125		(3,230)		(1,738)		(4,519)
Cash and cash equivalents
	Beginning of period		6,454		81,933		89,520		135,153
	End of period	$	2,613	$	89,520	$	2,613	$	89,520
Supplemental information
	Interest paid	$	3,295	$	489	$	5,425	$	2,205
	Income taxes (received) paid	$	(2,318)	$	2,742	$	21,186	$	13,211

For further information:

Glenn Dagenais, Executive Vice President Finance and Chief Financial Officer, [phone].