Ensign Energy Services Inc. Reports 2007 Financial Results2008-03-17 CALGARY, March 17 /CNW/ - Overview Ensign Energy Services Inc. (the "Company") reports net income of $249.8 million ($1.64 per common share) for the year ended December 31, 2007, a decrease of $91.5 million or 27 percent from net income of $341.3 million ($2.25 per common share) recorded in the year ended December 31, 2006. The Canadian industry malaise that started in the second half of 2006 continued into 2007 as the Company's customers reacted to the issues undermining the economics of their opportunities in the Western Canada Sedimentary Basin ("WCSB"), such as moderate natural gas prices, a strong Canadian dollar and proposed changes to the structure of oil and natural gas royalties in the Province of Alberta, and adjusted their drilling programs accordingly. Despite the decline in operating activity levels associated with the exploration and development of natural gas in Canada, the Company is pleased with the performance of its operating divisions focused on the oil sands and crude oil sectors, which were supported by strong crude oil commodity prices throughout 2007. Expansion of the Company's fleet of proprietary Automated Drill Rigs ("ADR(TM)") led the growth achieved in the United States oilfield services division in 2007, and mitigated some of the negative influences impacting the Canadian market. The Company's international operations also showed signs of growth as bidding activity increased in select markets. The Company responded in 2007 with the construction of three drilling rigs under long-term contracts for the international market. Net income of $72.6 million ($0.48 per common share) for the fourth quarter of 2007 compares with net income of $63.9 million ($0.42 per common share) recorded in the fourth quarter of 2006, an increase of 13 percent. Net income for the fourth quarter of 2007 was positively impacted by a stock-based compensation recovery of $15.1 million, compared with an expense of $3.4 million recorded in the fourth quarter of 2006. The recovery arose due to a decline in the price of the Company's common shares over this period. The fourth quarter of 2007 also reflects the recognition of substantively enacted income tax rate reductions in Canada. During the fourth quarter of 2007, the application of the income tax rate reductions resulted in a $14.2 million decline in future income tax liability balances. ------------------------------------------------------------------------- FINANCIAL AND OPERATING HIGHLIGHTS ($ thousands, except per share data and operating information) ------------------------------------------------------------------------- Three months ended Year ended December 31 December 31 ------------------------------------------------------------------------- % % 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Revenue 388,261 421,908 (8) 1,577,601 1,807,230 (13) ------------------------------------------------------------------------- EBITDA(1) 108,554 122,194 (11) 468,178 593,334 (21) EBITDA per share(1) Basic $0.71 $0.80 (11) $3.07 $3.91 (21) Diluted $0.70 $0.78 (10) $3.03 $3.80 (20) ------------------------------------------------------------------------- Adjusted net income(2) 62,739 66,155 (5) 244,966 337,352 (27) Adjusted net income per share(2) Basic $0.41 $0.44 (7) $1.61 $2.22 (27) Diluted $0.41 $0.42 (2) $1.59 $2.16 (26) ------------------------------------------------------------------------- Net income 72,561 63,938 13 249,765 341,284 (27) Net income per share Basic $0.48 $0.42 14 $1.64 $2.25 (27) Diluted $0.47 $0.41 15 $1.62 $2.18 (26) ------------------------------------------------------------------------- Funds from operations(3) $85,305 109,579 (22) 296,048 420,173 (30) Funds from operations per share(3) Basic $0.56 $0.72 (22) $1.94 $2.77 (30) Diluted $0.55 $0.70 (21) $1.92 $2.69 (29) ------------------------------------------------------------------------- Weighted average shares - basic (000s) 152,703 151,975 - 152,517 151,775 - Weighted average shares - diluted (000s) 154,018 155,779 (1) 154,306 156,229 (1) ------------------------------------------------------------------------- Drilling Number of marketed rigs Canada Conventional 160 164 (2) 160 164 (2) Oil sands coring/ coal-bed methane 31 22 41 31 22 41 United States 76 64 19 76 64 19 International(4) 49 47 4 49 47 4 Operating days Canada 5,938 6,793 (13) 24,046 32,689 (26) United States 4,839 4,538 7 19,110 18,252 5 International 2,362 2,453 (4) 9,291 9,151 2 ------------------------------------------------------------------------- Well Servicing Number of marketed rigs/units Canada 116 114 2 116 114 2 United States 14 11 27 14 11 27 Operating hours Canada 38,414 48,009 (20) 168,313 206,951 (19) United States 7,073 5,169 37 26,494 21,383 24 ------------------------------------------------------------------------- (1) EBITDA is defined as "Income before interest expense, income taxes, depreciation and stock-based compensation expense". 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 stock-based compensation plans. EBITDA and EBITDA per share as defined above are not recognized measures under Canadian generally accepted accounting principles and accordingly may not be comparable to measures used by other companies. (2) Adjusted net income is defined as "Net income before stock-based compensation expense, tax-effected using an income tax rate of 35%". 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 stock-based compensation plans, net of income taxes. Adjusted net income and adjusted net income per share as defined above are not recognized measures under Canadian generally accepted accounting principles 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 shareholders and potential investors with 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 Canadian generally accepted accounting principles and accordingly may not be comparable to similar measures used by other companies. (4) Includes workover rigs. Revenue and Oilfield Services Expense Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Revenue Canada 184,344 231,430 (20) 777,228 1,074,491 (28) United States 138,333 128,185 8 555,072 505,748 10 International 65,584 62,293 5 245,301 226,991 8 ---------------------------------------------------------- 388,261 421,908 (8) 1,577,601 1,807,230 (13) Oilfield services expense 263,183 283,982 (7) 1,054,334 1,161,213 (9) ---------------------------------------------------------- 125,078 137,926 (9) 523,267 646,017 (19) ---------------------------------------------------------- Gross margin 32.2% 32.7% 33.2% 35.7% ------------------------------------------------------------------------- Revenue totaled $388.3 million for the fourth quarter of 2007 compared with $421.9 million for the fourth quarter of 2006. Revenue for the year ended December 31, 2007 totaled $1,577.6 million, a decline of 13 percent from the prior year. The decline in revenue originating from the Company's Canadian oilfield services division for both the quarter and year ended December 31, 2007 was partially offset by increases achieved by both the United States and international oilfield services divisions over these same periods. For the three months ended December 31, 2007, gross margin was 32.2 percent compared with 32.7 percent for the three months ended December 31, 2006. Gross margin was 33.2 percent in 2007, compared with 35.7 percent in 2006. The compression in operating margins on a period-over-period basis is predominantly a reflection of the Canadian market, which faced pricing pressure in light of increased competition and declining demand in 2007. The cost control initiatives implemented by the Company have, to the extent possible, ensured its cost structure is commensurate with activity levels. However, in all geographic areas the Company continues to experience some cost inflation as it must compete with other oilfield services providers and other industries for skilled labour, as well as source materials in a tight supply market. Canadian Oilfield Services -------------------------- The Canadian oilfield services division recorded revenue of $184.3 million in the fourth quarter of 2007 and $777.2 million for the year ended December 31, 2007, declines of 20 percent and 28 percent, respectively, compared with the corresponding periods of 2006. Fiscal 2007 proved to be a challenging year for the Company's Canadian oilfield services division as demand for oilfield services in Western Canada tempered in 2007 compared with the record levels of demand experienced in 2006. The Company's customers rationalized drilling programs in 2007 in light of several issues negatively impacting their operations, including a strong Canadian dollar, unfavourable proposed royalty regime changes in Alberta and a negative outlook for natural gas commodity prices. The number of wells drilled in the WCSB totaled 19,144 (per the Canadian Association of Oilwell Drilling Contractors) in 2007, the lowest level of drilling activity in the region since 2002. Record industry equipment capacity further compounded the impact to the Company's Canadian equipment utilization rates and pricing. Gross margins realized by the Canadian oilfield services division eroded in 2007 compared with 2006 as the Company endeavored to maintain its market share in a difficult environment. The Company's diverse product offering and established presence in key oil regions of the WCSB have somewhat mitigated the natural gas-driven market softness, and the Company further bolstered its equipment fleet directed towards serving customers in the crude oil sector in 2007. During the year ended December 31, 2007, the Canadian oilfield services division added to its equipment fleet nine oil sands coring rigs, three well servicing rigs deployed in the heavy oil servicing sector, and one triple drilling rig for operation in south-eastern Saskatchewan. In response to customer demand, the Company also completed the construction of one conventional double drilling rig and one ADR(TM) for operations in northern British Columbia and Alberta, respectively, both of which are operating under long-term contracts. The Company demonstrated the value of its global reach in 2007 and transferred two idle drilling rigs from its Canadian fleet of equipment to Australia. These redeployments further expand the application of its ADR(TM) technology to international markets, and the Company is encouraged by the growing demand for its proprietary technology. In light of current market conditions in Canada, the Company also removed five conventional drilling rigs from its Canadian marketed fleet of equipment in 2007, and will retain the rig packages and critical components for servicing the remainder of its drilling rig fleet. United States Oilfield Services ------------------------------- The Company's strategic geographic diversification and United States focused growth initiatives proved successful in 2007, and served to mitigate the challenging operating environment experienced in Canada. The Company's United States oilfield services division achieved an eight percent increase in revenue in the fourth quarter of 2007 compared with the fourth quarter of 2006. For the year ended December 31, 2007, revenue generated by the United States oilfield services division totaled $555.1 million, an increase of ten percent over 2006. Although lower natural gas prices resulted in a softening of demand in certain areas of the United States market in 2007, the impact was far less than that experienced in Canada, owing to the more favorable economics associated with unconventional natural gas development plays that drove demand for oilfield services in the Rocky Mountain region. The Company's California operation is primarily focused on crude oil and, as such, experienced stable levels of demand throughout the year, supported by strong market prices for crude oil. Revenue generated by the Company's United States oilfield services division now accounts for 35 percent of the Company's annual consolidated revenue, compared with 28 percent in 2006. The Company underwent its most significant United States expansion program in recent years, adding 13 fit-for-purpose ADRs to the Rocky Mountain equipment fleet in 2007. The Company's proprietary ADR(TM) technology has been well received by customers in the Rocky Mountain and California regions and has served to diversify its service offerings to customers in those markets. The Company worked closely with its customers in constructing the latest generation of ADRs to ensure the technologically advanced and mobile equipment met the special needs of their often complex drilling programs. The inherent efficiency of the newly constructed equipment supported higher revenue rates during the year, and the long-term contracts under which these rigs operate have partially shielded the Company from the effects of short-term fluctuations in spot prices for drilling services. International Oilfield Services ------------------------------- The Company's international oilfield services division delivered promising results in 2007, including a five percent increase in revenue in the fourth quarter of 2007 compared with the fourth quarter of 2006, and an eight percent increase in revenue on a year-over-year basis. Demand for oilfield services in the international market remained steady throughout 2007, driven primarily by crude oil pricing levels that remained near historical highs. Although bidding activity was heightened throughout the year, more rapid growth was not achieved given the significant lead times associated with contract negotiations and equipment mobilizations inherent in international operations. The Company embarked on several rig relocation and construction programs in 2007 that will begin to have a meaningful impact on financial results in 2008. During the year ended December 31, 2007, the Company relocated two drilling rigs from Canada to Australia where they commenced operations under long-term contracts, one in the third quarter and one in the fourth quarter of 2007. In December 2007, upon completion of its construction, an additional deep capacity drilling rig commenced operations in the Middle East. The construction of two additional drilling rigs was nearing completion at the end of 2007, and the deployment of these rigs, one to the Middle East and one to north Africa, was complete in the first quarter of 2008. Depreciation Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Depreciation 27,698 18,604 49 92,636 80,921 14 ------------------------------------------------------------------------- Depreciation expense increased 49 percent to $27.7 million for the fourth quarter of 2007, compared with depreciation expense of $18.6 million recorded in the fourth quarter of 2006. Depreciation expense totaled $92.6 million for the year ended December 31, 2007, an increase of $11.7 million or 14 percent compared with the year ended December 31, 2006. The Company depreciates the majority of its equipment on a unit-of-production basis. Although consolidated operating activity levels declined in 2007 compared with 2006, depreciation expense increased due to the significant capital additions made during the last two years. Depreciation expense on a per day basis increased in 2007 as the Company introduced newly constructed and higher valued assets to its equipment fleet. General and Administrative Expense Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- General and administrative 16,524 15,732 5 55,089 52,683 5 % of revenue 4.3% 3.7% 3.5% 2.9% ------------------------------------------------------------------------- For the three months ended December 31, 2007, general and administrative expense totaled $16.5 million (4.3 percent of revenue), compared with $15.7 million (3.7 percent of revenue) for the three months ended December 31, 2006. General and administrative expense totaled $55.1 million for the year ended December 31, 2007, an increase of five percent over the prior year. As a percentage of revenue, general and administrative expense was 3.5 percent in 2007 compared with 2.9 percent in 2006. The increase in general and administrative expense in 2007 relates primarily to the Company's growth initiatives in the United States. Stock-Based Compensation Expense Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Stock-based compensation (15,111) 3,410 (543) (7,383) (6,050) 22 ------------------------------------------------------------------------- Stock-based compensation expense arises from the intrinsic value accounting associated with the Company's stock option plan, whereby the liability associated with stock-based compensation is adjusted on a quarterly basis for the effect of granting and vesting of employee stock options, and changes in the underlying price of the Company's common shares. Stock-based compensation was a recovery of $15.1 million in the fourth quarter of 2007 compared with an expense of $3.4 million recorded in the fourth quarter of 2006. For the year ended December 31, 2007, stock-based compensation is a recovery of $7.4 million, compared with a recovery of $6.1 million for the year ended December 31, 2006. The recovery in both the three months and year ended December 31, 2007 is due to a decline in the price of the Company's common shares over these periods, net of the impact of additional granting and vesting of stock options. The closing price of the Company's common shares was $15.25 at December 31, 2007, compared with $18.78 at September 30, 2007 and $18.39 at December 31, 2006. Interest Expense Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Interest 1,154 1,177 (2) 5,249 5,127 2 ------------------------------------------------------------------------- Interest expense is incurred on the Company's operating lines of credit. Interest expense totaled $1.2 million for the fourth quarter of 2007 and $5.2 million for the year ended December 31, 2007, both of which are comparable to the corresponding periods of 2006. Income Taxes Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Current income tax 12,070 6,236 94 142,846 131,436 9 Future income tax 10,182 28,829 (65) (14,935) 40,616 (137) ---------------------------------------------------------- 22,252 35,065 (37) 127,911 172,052 (26) ---------------------------------------------------------- Effective income tax rate(%) 23.5% 35.4% 33.9% 33.5% ------------------------------------------------------------------------- The effective income tax rate for the fourth quarter of 2007 was 23.5 percent compared with 35.4 percent in the fourth quarter of 2006. The decline in the effective income tax rate on a quarter-over-quarter basis is due to income tax rate reductions in Canada. The application of these income tax rate reductions on opening income tax balances has been reflected as a reduction in future income tax expense. The effective income tax rate for the year ended December 31, 2007 was 33.9 percent compared with 33.5 percent for the year ended December 31, 2006. The future income tax recovery in 2007 is partially due to partnership timing differences and income tax rate reductions in Canada. Taxable income generated in Canadian partnerships was a significant component of the future income tax liability as at December 31, 2006. This balance has declined as of December 31, 2007 due to the decline in income generated by Canadian partnerships. The impact of the income tax rate reductions noted above has also reduced future income taxes in the year ended December 31, 2007. Current income tax expense for the year ended December 31, 2007 includes $3.8 million related to Omani tax assessments. As previously disclosed, the Company's Oman operating entity was appealing income tax assessments received for the 1994, 1995 and 1996 financial years. The Company was appealing these assessments on the basis that they were without merit under Omani law; however, the Company's appeal was dismissed during the year ended December 31, 2007. Excluding the impact of the Omani tax assessments, the effective income tax rate would have been 32.9 percent for the year ended December 31, 2007. Financial Position The following table outlines significant changes in the consolidated balance sheets from December 31, 2006 to December 31, 2007: ($ thousands) Change Explanation ------------------------------------------------------------------------- Cash and cash (12,630) See consolidated statements of cash equivalents flows. Accounts receivable (63,354) Decrease due to a decline in operating activity in the fourth quarter of 2007 compared with the fourth quarter of 2006 within the Canadian oilfield services division. Inventory and other 12,524 Increase due to additions to drill pipe inventory. Property and equipment 96,514 Increase due to the new drilling rig build programs and ongoing capital expenditures, offset by depreciation and changes in foreign exchange rates in the year. Accounts payable and (64,381) Decrease due to a decline in operating accrued liabilities activity in the fourth quarter of 2007 compared with the fourth quarter of 2006 within the Canadian oilfield services division. Operating lines of 47,980 Increase in utilization of the United credit States and Australian-based operating lines of credit during the year in support of rig construction activities. Stock-based (39,038) Decrease due to a decline in the price compensation of the Company's common shares and the exercise of employee stock options in the year. Income taxes payable (27,518) Decrease due to income tax payments made during the year, offset by the current income tax provision for the year. Dividends payable 468 Increase due to a three-percent increase in the fourth quarter dividend rate and a slight increase in the number of outstanding common shares compared with the fourth quarter of 2006. Future income taxes (21,058) Decrease due to the future income tax recovery in the year, primarily resulting from the effect of income tax rate reductions in Canada. Shareholders' equity 136,601 Increase due to the aggregate impact of net income for the year, increase in common shares due to exercises of employee stock options, impact of foreign exchange rate fluctuations on the net assets of foreign self-sustaining subsidiaries, net of dividends declared in the year. ------------------------------------------------------------------------- Working Capital and Funds from Operations Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Funds from operations 85,305 109,579 (22) 296,048 420,173 (30) Funds from operations per share $0.56 $0.72 (22) $1.94 $2.77 (30) Working capital 60,272 63,162 (5) 60,272 63,162 (5) ------------------------------------------------------------------------- Funds from operations totaled $85.3 million ($0.56 per common share) in the fourth quarter of 2007 compared with funds from operations of $109.6 million ($0.72 per common share) recorded in the fourth quarter of 2006, a decline of 22 percent. During the year ended December 31, 2007, the Company generated funds from operations of $296.0 million ($1.94 per common share), a decrease of 30 percent from the prior year. The decline from the record levels of funds from operations generated in 2006 is predominantly due to a reduction in operating activity levels and compressed margins in the Company's Canadian oilfield services division, partially offset by increased financial contributions delivered by the Company's United States operations. Despite the challenges experienced in the Canadian market in 2007, the Company has maintained a strong balance sheet, with working capital of $60.3 million at December 31, 2007. With a positive working capital position at December 31, 2007, available credit facilities and anticipated internally generated funds, the Company has sufficient liquidity to meet its obligations as they come due. Investing Activities Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Net purchase of property and equipment (48,017) (85,662) (44) (271,984) (325,483) (16) Net change in non-cash working capital (39,950) 12,000 (433) (54,168) 40,053 (235) ---------------------------------------------------------- Cash used in investing activities (87,967) (73,662) 19 (326,152) (285,430) 14 ------------------------------------------------------------------------- During the fourth quarter of 2007, cash used in investing activities totalled $88.0 million, an increase of 19 percent over cash used in investing activities of $73.7 million in the fourth quarter of 2006. Cash used in investing activities totalled $326.2 million for the year ended December 31, 2007, an increase of 14 percent over cash used in investing activities of $285.4 million in 2006. Over half of the Company's 2007 capital expenditure initiatives were directed towards expansion of the Company's United States-based equipment fleet, which included the addition of 13 ADRs and the purchase of two well servicing rigs. Although the overall Canadian market was characterized by weak demand and over supply in 2007, the Company bolstered its Canadian-based equipment fleet in strategic areas to further position itself to benefit from crude oil driven demand. The Company also capitalized on opportunities to provide its customers with fit-for-purpose equipment under long-term contracts. Additions to the Canadian oilfield services division's equipment fleet in 2007 include: - nine oil sands coring rigs; - three newly constructed well servicing rigs, all of which were deployed in the heavy oil sector; - one triple drilling rig for the Company's operations in south-eastern Saskatchewan, a predominantly crude oil based market; - one conventional double drilling rig for operations in north-eastern British Columbia; and - one ADR(TM) that will operate under a long-term contract in northern Alberta. Two additional well servicing rigs were under construction in Canada at December 31, 2007 and were placed into operation in January 2008. Capital expenditure activities within the Company's international oilfield services division include the construction of three drilling rigs for operations in the Middle East and Africa. One of the three drilling rigs commenced operations in the Middle East in the fourth quarter of 2007 and the remaining two became operational in the first quarter of 2008. The Company's Australian-based equipment fleet also benefited from the transfer of two ADRs from Canada in the second half of 2007. Financing Activities Three months ended Year ended December 31 December 31 ---------------------------------------------------------- % % ($ thousands) 2007 2006 change 2007 2006 change ------------------------------------------------------------------------- Net increase (decrease) in operating lines of credit 5,605 (24,670) (123) 47,980 (95,790) (150) Issue of capital stock 3,199 3,623 (12) 5,141 6,556 (22) Dividends (12,623) (12,155) 4 (49,214) (42,505) 16 Net change in non-cash working capital 421 769 (45) 468 4,589 (90) ---------------------------------------------------------- Cash (used in) provided by financing activities (3,398) (32,433) (90) 4,375 (127,150) (103) ------------------------------------------------------------------------- The Company maintains operating lines of credit in Canada, the United States and Australia. The total utilized balance outstanding as at December 31, 2007 totaled $118.0 million, an increase of $5.6 million over the outstanding balance as at the end of the third quarter of 2007 and an increase of $48.0 million over the prior year. During the year ended December 31, 2007, the Company increased the amount available under its United States-based operating line of credit to USD$50.0 million to fund the Company's new build projects and to support expanded operations in that country, and the Company also increased the amount available under its Australia-based operating line of credit to AUD$66.5 million to support international drilling rig construction projects. During the fourth quarter of 2007, the Company announced a three percent increase in its quarterly dividend rate to $0.0825 per common share. Dividends declared for the year ended December 31, 2007 totaled $49.2 million ($0.3225 per common share), an increase of 16 percent over dividends of $42.5 million ($0.28 per common share) declared in 2006. Subsequent to December 31, 2007, the Company declared a dividend for the first quarter of 2008 of approximately $12.7 million, being $0.0825 per common share. All dividends paid by the Company subsequent to January 1, 2006 qualify as an eligible dividend, as defined by subsection 89(1) of the Canadian Income Tax Act. Other financing activities include the issue of capital stock on the exercise of employee stock options, which totaled $3.2 million in the fourth quarter of 2007 and $5.1 million in the year ended December 31, 2007. Outlook There continues to be much uncertainty surrounding the outlook for Canadian oilfield services in 2008. The combined effect of weaker natural gas prices, a stronger Canadian dollar, the uncertainty associated with proposed changes to the Alberta royalty regime and an expanded fleet of equipment in the industry has negatively impacted the overall short term prospects for the Canadian oilfield services industry. While natural gas prices have recovered somewhat in recent weeks, it remains to be seen if such a recovery is sustainable over the longer term given the currently negative outlook for the United States economy. Despite all of the negative factors, the Company started 2008 with Canadian utilization that has, so far, exceeded earlier expectations. In fact, the Canadian division could have been more active in the first quarter of 2008 had the Company not been crew constrained. The relatively good start to the year in Canada has not added much clarity to the remainder of 2008. The Company still feels that there will be reduced levels of activity within the industry over the next several quarters before the overall business climate in the Canadian oilfield services industry begins to recover. The Company has taken steps to keep its share of the work and optimize margins through stringent control over costs. The United States oilfield services market is also governed by the overall supply and demand of natural gas. The current market appears to be adequately supplied with equipment and there remain select opportunities to introduce new, fit-for-purpose equipment with expanded technical capabilities into the United States. The Company recently added 13 new ADRs to its United States fleet and 2008 will be the first full year of contributions from the expanded drilling rig fleet. The Company expects that 2008 will be a relatively stable year for its United States operations with select opportunities to introduce new equipment into the market, a market the Company has been involved in for over 13 years. The Company's established position in the international oilfield services market qualifies it for many bidding opportunities that are under consideration. The three larger capacity drilling rigs recently constructed and put into service will have a meaningful impact on the Company's international operations in 2008. Additionally, the Company began construction in early 2008 of six ADRs that are slated for operations in the Middle East and Africa, representing the largest expansion of the Company's international-based ADR(TM) fleet to date. It is anticipated that the new ADRs will be delivered over the November 2008 to May 2009 time frame, at which point these new builds will begin contributing to the financial results of the Company's international oilfield services division. Further growth prospects for the Company's international division remain solid in the coming year. The Company's geographic diversification began in 1994 with its entrance into the United States oilfield services market and continued in 2002 with the Company's first international acquisition outside of North America. The strategic importance of the Company's diversification outside of Canada is underscored by the overall reduction in the Canadian oilfield services activity that began in late 2006 and continued into 2007. An over supply of equipment in the Canadian market has now resulted in many of the Company's competitors looking for new markets to redeploy idle Canadian equipment. In this regard, the Company enjoys the competitive advantage of having an infrastructure in place to understand and accommodate the needs of markets outside of Canada. The Company will continue to exploit this advantage in the future and lessen its exposure to the cyclicality of any one particular market segment. 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. A conference call will be held to discuss the Company's fourth quarter results at 2:00 p.m. MT (4:00 p.m. ET) on Monday, March 17, 2008. The conference call number is 1-416-644-3419 or toll free 1-800-732-9303. A taped recording will be available until March 24, 2008 by dialing 1-416-640-1917 or toll free 1-877-289-8525 and entering reservation number 21266036 followed by the number sign. 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. CONSOLIDATED BALANCE SHEETS (in thousands of dollars) December 31 December 31 2007 2006 ---- ---- Assets Current assets Cash and cash equivalents 1,940 14,570 Accounts receivable 301,721 365,075 Inventory and other 89,752 77,228 Future income taxes 2,367 11,010 ------------------------- 395,780 467,883 Property and equipment 1,390,780 1,294,266 ------------------------- 1,786,560 1,762,149 ------------------------- ------------------------- Liabilities Current liabilities Accounts payable and accrued liabilities 177,595 241,976 Operating lines of credit 117,969 69,989 Current portion of stock-based compensation 8,056 33,818 Income taxes payable 19,265 46,783 Dividends payable 12,623 12,155 ------------------------- 335,508 404,721 Stock-based compensation 4,723 17,999 Future income taxes 202,123 231,824 ------------------------- 542,354 654,544 ------------------------- Shareholders' Equity Capital stock 167,599 154,838 Cumulative translation adjustment (97,588) (20,163) Retained earnings 1,174,195 972,930 ------------------------- 1,244,206 1,107,605 ------------------------- 1,786,560 1,762,149 ------------------------- ------------------------- CONSOLIDATED STATEMENTS OF INCOME AND RETAINED EARNINGS (in thousands of dollars, except per share data) Three months ended Year ended December 31 December 31 2007 2006 2007 2006 ---- ---- ---- ---- Revenue Oilfield services 388,261 421,908 1,577,601 1,807,230 Expenses Oilfield services 263,183 283,982 1,054,334 1,161,213 Depreciation 27,698 18,604 92,636 80,921 General and administrative 16,524 15,732 55,089 52,683 Stock-based compensation (15,111) 3,410 (7,383) (6,050) Interest 1,154 1,177 5,249 5,127 -------------------------------------------------- 293,448 322,905 1,199,925 1,293,894 -------------------------------------------------- Income before income taxes 94,813 99,003 377,676 513,336 Income taxes Current 12,070 6,236 142,846 131,436 Future 10,182 28,829 (14,935) 40,616 -------------------------------------------------- 22,252 35,065 127,911 172,052 -------------------------------------------------- Net income for the year 72,561 63,938 249,765 341,284 Retained earnings - beginning of period, as originally reported 1,114,257 921,147 972,930 674,151 Transition adjustment on adoption of financial instruments standard - - 714 - -------------------------------------------------- Retained earnings - beginning of period, as restated 1,114,257 921,147 973,644 674,151 Dividends (12,623) (12,155) (49,214) (42,505) -------------------------------------------------- Retained earnings - end of period 1,174,195 972,930 1,174,195 972,930 -------------------------------------------------- -------------------------------------------------- Net income per share Basic $0.48 $0.42 $1.64 $2.25 Diluted $0.47 $0.41 $1.62 $2.18 ------------------------------------------------- ------------------------------------------------- CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands of dollars) Three months ended Year ended December 31 December 31 2007 2006 2007 2006 ---- ---- ---- ---- Cash provided by (used in) Operating activities Net income for the period 72,561 63,938 249,765 341,284 Items not affecting cash: Depreciation 27,698 18,604 92,636 80,921 Stock-based compensation, net of cash paid (25,136) (1,792) (31,418) (42,648) Future income taxes 10,182 28,829 (14,935) 40,616 ------------------------------------------------- Cash provided by operating activities before the change in non-cash working capital 85,305 109,579 296,048 420,173 Net change in non-cash working capital (7,301) (9,854) 13,099 (25,016) ------------------------------------------------- 78,004 99,725 309,147 395,157 ------------------------------------------------- Investing activities Net purchase of property and equipment (48,017) (85,662) (271,984) (325,483) Net change in non-cash working capital (39,950) 12,000 (54,168) 40,053 ------------------------------------------------- (87,967) (73,662) (326,152) (285,430) ------------------------------------------------- Financing activities Net (decrease) increase in operating lines of credit 5,605 (24,670) 47,980 (95,790) Issue of capital stock 3,199 3,623 5,141 6,556 Dividends (12,623) (12,155) (49,214) (42,505) Net change in non-cash working capital 421 769 468 4,589 ------------------------------------------------- (3,398) (32,433) 4,375 (127,150) ------------------------------------------------- (Decrease) increase in cash and cash equivalents during the period (13,361) (6,370) (12,630) (17,423) Cash and cash equivalents - beginning of period 15,301 20,940 14,570 31,993 ------------------------------------------------- Cash and cash equivalents - end of period 1,940 14,570 1,940 14,570 ------------------------------------------------- ------------------------------------------------- Supplemental information Interest paid 1,871 1,069 5,683 5,358 Income taxes paid 29,296 22,078 170,364 108,958 ------------------------------------------------- ------------------------------------------------- %SEDAR: 00001999E For further information: Glenn Dagenais, Executive Vice President Finance and Chief Financial Officer, (403) 262-1361 |