Ensign Energy Services Reports 2008 Third Quarter Results2008-11-10 CALGARY, Nov. 10 /CNW/ - Overview Ensign Energy Services Inc. (the "Company") reports net income of $72.1 million ($0.47 per common share) for the third quarter of 2008 compared with net income of $49.7 million ($0.33 per common share) for the third quarter of 2007, an increase of 45 percent. For the nine months ended September 30, 2008, net income totaled $186.1 million ($1.22 per common share), an increase of five percent over net income of $177.2 million ($1.16 per common share) recorded in the first nine months of 2007. Funds from operations for the three months ended September 30, 2008 totaled $90.5 million ($0.59 per common share) and represents a 70 percent increase over funds from operations of $53.3 million ($0.35 per common share) recorded in the third quarter of 2007. For the nine months ended September 30, 2008, funds from operations totaled $297.2 million ($1.94 per common share), an increase of 41 percent over the comparable period of 2007. The comparability of net income on a period-over-period basis is impacted by stock-based compensation expense, which fluctuates based on changes in the price of the Company's common shares. The Company reports adjusted net income, which eliminates the tax-effected impact of stock-based compensation expense, of $61.0 million ($0.40 per common share) for the third quarter of 2008 compared with adjusted net income of $50.2 million ($0.33 per common share) for the third quarter of 2007, an increase of 22 percent. Adjusted net income for the nine-month period ended September 30, 2008 was $192.9 million ($1.26 per common share), an increase of six percent over adjusted net income of $182.2 million ($1.20 per common share) recorded in the nine months ended September 30, 2007. Entering 2008, the outlook for the Company's fiscal 2008 results was diminished by the uncertain short-term prospects of the Canadian oilfield services market. At the time, the 2008 outlook for the Canadian market was negatively impacted by an over-supply of equipment in Canada, concern over weak natural gas prices and the negative impact a strong Canadian dollar may have on the cash flows of the Company's customers. While these factors contributed to a weak first quarter for the Company, gradual market improvements resulted in stronger than anticipated second quarter results (at which point the Company was the most active driller in the Western Canada Sedimentary Basin ("WCSB") on a metres drilled basis), and culminated in third quarter funds from operations that exceeded the same period of 2007 by 70 percent. Favorable natural gas and crude oil commodity prices supported a recovery in Canadian oilfield services activity in the third quarter of 2008, while the United States oilfield services division, with its expanded Automated Drill Rig (ADR(TM)) fleet, captured growing demand for technologically-advanced equipment in the service-intensive resource plays of the Rocky Mountain region of the United States. Internationally, the Company achieved an increase in operating activity levels in the third quarter of 2008 compared with the third quarter of 2007 as repositioned equipment capitalized on strong crude oil commodity prices and the resultant increase in demand for the oilfield services provided by the Company. The positive results generated by the Company in the first nine months of 2008, a period of significant market uncertainty and volatile commodity prices, are owed to the strategic decisions and investments made by the Company in recent years to diversify its geographic footprint and leverage its existing operational bases in the United States and internationally; to maintain strict cost discipline across all of its business lines; and, to remain committed to developing technologies that improve the efficiency and safety of its equipment. The Company's proven track record during uncertain times, and its strong balance sheet, will serve the Company well as it faces the unprecedented events shocking the global economy in the fourth quarter of 2008. ------------------------------------------------------------------------- FINANCIAL AND OPERATING HIGHLIGHTS ($ thousands, except per share data and operating information) ------------------------------------------------------------------------- Three months ended Nine months ended September 30, 2008 September 30, 2008 ------------------------------------------------------------------------- % % 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Revenue 435,186 383,316 14 1,245,144 1,189,340 5 ------------------------------------------------------------------------- EBITDA(1) 121,785 103,519 18 383,775 359,624 7 EBITDA per share(1) Basic $ 0.80 $ 0.68 18 $ 2.51 $ 2.36 6 Diluted $ 0.79 $ 0.67 18 $ 2.48 $ 2.31 7 ------------------------------------------------------------------------- Adjusted net income(2) 61,025 50,157 22 192,926 182,227 6 Adjusted net income per share(2) Basic $ 0.40 $ 0.33 21 $ 1.26 $ 1.20 5 Diluted $ 0.39 $ 0.32 22 $ 1.25 $ 1.17 7 ------------------------------------------------------------------------- Net income 72,071 49,748 45 186,129 177,204 5 Net income per share Basic $ 0.47 $ 0.33 42 $ 1.22 $ 1.16 5 Diluted $ 0.47 $ 0.32 47 $ 1.20 $ 1.14 5 ------------------------------------------------------------------------- Funds from opera- tions(3) 90,450 53,257 70 297,217 210,743 41 Funds from operations per share(3) Basic $ 0.59 $ 0.35 69 $ 1.94 $ 1.38 41 Diluted $ 0.58 $ 0.34 71 $ 1.92 $ 1.35 42 ------------------------------------------------------------------------- Weighted average shares - basic (000s) 153,122 152,516 - 153,083 152,456 - Weighted average shares - diluted (000s) 154,881 155,513 - 154,647 155,534 (1) ------------------------------------------------------------------------- Drilling Number of marketed rigs Canada Conven- tional 169 162 4 169 162 4 Oil sands coring/ coal-bed methane 28 31 (10) 28 31 (10) United States 75 74 1 75 74 1 Interna- tional(4) 44 49 (10) 44 49 (10) Operating days Canada 7,578 5,760 32 19,509 18,108 8 United States 5,289 5,118 3 15,316 14,271 7 Interna- tional 2,458 2,274 8 7,421 6,929 7 ------------------------------------------------------------------------- Well Servicing Number of marketed rigs/units Canada 118 115 3 118 115 3 United States 16 12 33 16 12 33 Operating hours Canada 37,907 39,674 (4) 111,356 129,899 (14) United States 10,481 7,035 49 27,912 19,421 44 ------------------------------------------------------------------------- (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 Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Revenue Canada 193,939 169,726 14 562,767 592,884 (5) United States 161,621 149,108 8 453,761 416,739 9 International 79,626 64,482 23 228,616 179,717 27 ---------------------------------------------------------- 435,186 383,316 14 1,245,144 1,189,340 5 Oilfield services expense 301,233 268,270 12 821,412 791,151 4 ---------------------------------------------------------- 133,953 115,046 16 423,732 398,189 6 ---------------------------------------------------------- Gross margin 30.8% 30.0% 34.0% 33.5% ------------------------------------------------------------------------- Canada ------ The fundamentals of the Canadian oilfield services market strengthened and continued its upward trend during the third quarter of 2008. Following a weak first half of 2008, favorable natural gas and crude oil commodity prices supported an increase in operating activity levels in the third quarter of 2008 compared with earlier expectations and the third quarter of 2007. Improved operating cash flows realized by the Company's customers during the third quarter of 2008 translated to increased demand for oilfield services in the WCSB and a 32 percent increase in operating days for the Canadian oilfield services segment compared with the third quarter of 2007. As the Company's customers redirected capital outside of the Province of Alberta in anticipation of unfavorable royalty regime changes, the most noted growth in operating activity levels were realized by the Company's operations based in southeast Saskatchewan. The Company has strategically expanded its operations in Saskatchewan since the acquisition of Big Sky Drilling Ltd. in 2003, and was well-positioned to capture the recent increase in exploration and development activity in that province as operators shifted their focus to popular crude oil plays in that region. Similarly, the Company experienced steady demand for its services in northeast British Columbia, where activity levels in shale gas resource plays, such as the Montney and Horn River basins, are not as susceptible to short-term fluctuations in natural gas prices given the longer life spans of these reservoirs compared with conventional plays. For the nine months ended September 30, 2008, revenue generated by the Canadian oilfield services segment totaled $562.8 million, a decline of five percent from the same period of 2007. Operating days for the nine months ended September 30, 2008 totaled 19,509 compared with 18,108 operating days recorded in the first three quarters of 2007. While the Company delivered strong financial and operating results in the third quarter of 2008, year-to-date results for 2008 continue to reflect a weak first quarter which experienced period-over-period declines in operating activity and pricing levels. While momentum began to shift in Canada in the second quarter of 2008, continued soft pricing, spring break up and wet weather conditions negated any substantial improvements in financial results in that quarter compared with the same period of 2007. During the third quarter of 2008, the Company expanded its Canadian-based equipment fleet with the acquisition of 12 specialty drilling rigs and related equipment from Terracore Specialty Drilling Ltd. ("Terracore"). The specialty drilling rigs have the capability of drilling coal bed methane and conventional wells in addition to oil sands coring applications. Financial contributions from this additional equipment will be most noted in the first quarter of 2009, as the seasonal demand for coring equipment peaks during the winter months. United States ------------- Partially offsetting challenges faced by the Company's Canadian operations, the United States oilfield services division delivered record financial results in both the third quarter of 2008 and the nine months ended September 30, 2008, highlighting the importance of the Company's initiatives to lessen its exposure to the cyclicality of any one particular market segment. Revenue from the United States oilfield services segment totaled $161.6 million for the third quarter of 2008, an increase of eight percent over the third quarter of 2007. Revenue growth was also achieved in the nine months ended September 30, 2008, with revenue surpassing the prior period by nine percent. The revenue growth achieved by the United States oilfield services division in the first nine months of 2008 compared with the first nine months of 2007, as presented in Canadian dollars, is somewhat diminished by the impact of foreign exchange rates. The average United States dollar exchange rate at which results are translated to Canadian dollars for presentation purposes declined eight percent in the first nine months of 2008 compared with the first nine months of 2007. The addition of 13 ADRs to the United States drilling rig fleet is the main contributor to the improved financial and operational results delivered by the United States oilfield services segment in 2008. As of September 30, 2008, all 13 ADRs from the 2007 build program were operating compared with 11 operating and two under construction as of September 30, 2007. The Company's proprietary ADR(TM) enabled it to capture increased demand for the specialty, technologically-advanced equipment required to explore and develop the unconventional natural gas resource plays in the Rocky Mountain region. The newly constructed ADRs were introduced to the fleet under term contracts, which have partially mitigated the Company's exposure to the impact of short-term fluctuations in natural gas prices on drilling day rates. The Company also expanded its United States well servicing operation in 2008, adding two well servicing units to that market in the first nine months of 2008 and realizing a 49 percent increase in operating hours in the third quarter of 2008 and a 44 percent increase in operating hours in the nine months ended September 30, 2008 compared with the same periods of 2007. The Company previously announced intentions to further expand its drilling rig fleet in the United States by a total of 20 ADRs and four well servicing rigs. Subsequent to that announcement, the Company's customers have been forced to react to a sharp decline in commodity prices, substantial uncertainty caused by the current global credit crisis and the threat of a global recession. As a result, in working with the needs of its customers, the Company has scaled back its expansion plans accordingly. As of November 10, 2008, the Company's construction program consists of eight ADRs destined for the United States under term contracts. The well servicing fleet expansion is continuing as planned. The construction of one well servicing rig was completed during the third quarter of 2008 and the remaining three well servicing rigs are expected to be complete in the fourth quarter of 2008. International ------------- Revenue for the Company's international oilfield services segment totaled $79.6 million for the third quarter of 2008, an increase of 23 percent over the third quarter of 2007. For the nine months ended September 30, 2008, revenue generated by the international oilfield services segment totaled $228.6 million, an increase of 27 percent over the prior period. International operating days increased eight percent and seven percent for the third quarter of 2008 and for the nine months ended September 30, 2008, respectively, compared with the corresponding periods of 2007. Demand for oilfield services in the international arena is more heavily influenced by crude oil prices compared with the predominantly natural gas focus of the WCSB and the Rocky Mountain region of the United States. Crude oil prices improved significantly in 2008 compared with 2007, driving strong demand for oilfield services in all of the Company's international locations. West Texas Intermediate crude oil averaged US$118.22 per barrel during the third quarter of 2008, an increase of 57 percent over an average price of US$75.15 per barrel during the third quarter of 2007. For the nine months ended September 30, 2008, West Texas Intermediate crude oil averaged US$113.52 per barrel, an increase of 71 percent over the average price of $66.22 per barrel for the nine months ended September 30, 2007. The Company repositioned several drilling rigs late in 2007 and early 2008 to better position itself to capture an increase in global demand for oilfield services. These equipment transfers resulted in meaningful period-over-period financial improvements for the international segment. The equipment transfers include the relocation of two ADRs from Canada to Australia in the latter half of 2007, the deployment of one drilling rig to the Middle East in the fourth quarter of 2007, as well as the completion of two drilling rig construction projects in the Middle East and Africa in the first quarter of 2008. Partially offsetting improved financial contributions from this relocated equipment, two drilling rigs previously operating in Asia completed their contracts in 2008 and are being marketed to other international jurisdictions. The drilling rig deployed to the Middle East in the fourth quarter of 2007 completed its contract subsequent to September 30, 2008 and will remain at a Middle East port until a new contract can be secured. The construction of six new ADRs for deployment to the Middle East and Africa markets under term contracts is continuing as planned, with delivery expected to occur in the first and second quarters of 2009. Gross Margin ------------ The Company recorded a gross operating margin of 30.8 percent in the third quarter of 2008 and 34.0 percent for the nine months ended September 30, 2008, slight improvements over gross operating margins realized in the comparable periods of 2007. Stable pricing in the United States and improved operating margins in the international oilfield services division, driven by robust crude oil prices, offset declining operating margins in Canada throughout 2008. Depreciation Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Depreciation 33,987 22,028 54 89,705 64,938 38 ------------------------------------------------------------------------- Depreciation expense totaled $34.0 million for the third quarter of 2008 compared with $22.0 million for the third quarter of 2007. Depreciation expense increased to $89.7 million for the nine months ended September 30, 2008 compared with $64.9 million for the nine months ended September 30, 2007. These increases are due to the introduction of higher valued equipment to the drilling rig fleet following the completion of the 2007 rig building programs, primarily in the United States, as well as an increase in consolidated operating activity levels on a period-over-period basis. Several changes in accounting estimates in 2008 impact the comparability of depreciation on a period-over-period basis. Effective January 1, 2008 the Company reduced the estimated useful life of oil sands coring rigs and coiled tubing units, thereby accelerating the depreciation of this equipment. Effective July 1, 2008, the Company began applying a depreciation charge for drilling and well servicing rigs that are not currently operating based on the revised estimated useful life of such equipment. General and Administrative Expense Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- General and administrative 12,168 11,527 6 39,957 38,565 4 % of revenue 2.8% 3.0% 3.2% 3.2% ------------------------------------------------------------------------- General and administrative expense totaled $12.2 million (2.8 percent of revenue) for the third quarter of 2008 compared with general and administrative expense of $11.5 million (3.0 percent of revenue) for the third quarter of 2007. For the nine-month period ended September 30, 2008, general and administrative expense totaled $40.0 million (3.2 percent of revenue), an increase of four percent over general and administrative expense of $38.6 million (3.2 percent of revenue) recorded in the first three quarters of 2007. Stock-Based Compensation Expense Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Stock-based compensation (16,993) 630 (2,797) 10,457 7,728 35 ------------------------------------------------------------------------- Stock-based compensation expense arises from the fair value accounting for the Company's stock option plan. For the quarter-ended September 30, 2008, stock-based compensation is a recovery of $17.0 million, arising from a decline in the price of the Company's common shares over this period. For the nine months ended September 30, 2008, stock-based compensation expense totaled $10.5 million and comprises $1.8 million for additional vesting of stock options and $8.7 million due to an increase in the price of the Company's common shares. The price of the Company's common shares was $16.68 at September 30, 2008 compared with $22.22 at June 30, 2008 and $15.25 at December 31, 2007. Interest Expense Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Interest 1,458 1,190 23 5,402 4,095 32 ------------------------------------------------------------------------- Interest expense is incurred on the Company's operating lines of credit and the promissory note payable. The variance in interest expense on a period-over-period basis is due to an increase in the average balance outstanding on the Company's operating lines of credit, and the issuance of a promissory note payable in the third quarter of 2008. Income Taxes Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Current income tax 27,364 48,944 (44) 72,885 130,776 (44) Future income tax 3,898 (19,021) (120) 19,197 (25,117) (176) ---------------------------------------------------------- 31,262 29,923 4 92,082 105,659 (13) ---------------------------------------------------------- Effective income tax rate (%) 30.3% 37.6% 33.1% 37.4% ------------------------------------------------------------------------- The effective income tax rate for the third quarter of 2008 was 30.3 percent compared with 37.6 percent for the third quarter of 2007. For the nine months ended September 30, 2008, the effective income tax rate was 33.1 percent compared with 37.4 percent for the nine months ended September 30, 2007. The decrease in the effective income tax rate for the nine months ended September 30, 2008 compared with the corresponding period of 2007 is partially the result of $4.0 million of Omani tax assessments included in current income tax expense for the nine months ended September 30, 2007 with no comparable amount in 2008. Excluding the impact of the Omani tax assessments, the effective income tax rate would have been 35.9 percent for the nine months ended September 30, 2007. The decrease in the Company's effective income tax rate on a quarter-over-quarter and year-to-date basis is also due to ongoing income tax rate reductions in Canada. Income tax rate reductions previously announced by the federal government will phase in income tax rate reductions each year until 2012, at which point the federal corporate income tax rate in Canada will reduce to 15.0 percent from its current level of 19.5 percent. Financial Position The following chart outlines significant changes in the consolidated balance sheets from December 31, 2007 to September 30, 2008: ($ thousands) Change Explanation ------------------------------------------------------------------------- Cash and cash 22,745 See consolidated statement of cash flows. equivalents Accounts receivable 45,216 Increase due to an increase in operating activity in the third quarter of 2008 compared with the fourth quarter of 2007. Inventory and other (38,351) Decrease due to the reclassification of drill pipe inventory to property and equipment as a result of a revision in the estimated useful life. Property and 185,127 Increase due to the acquisition of 12 equipment specialty drilling rigs, the new build construction program, ongoing capital expenditures and the reclassification of drill pipe inventory, offset by depreciation in the period. Accounts payable 18,342 Increase due to an increase in operating and accrued activity in the third quarter of 2008 liabilities compared with the fourth quarter of 2007. Operating lines (3,155) Decrease due to net repayments of the of credit operating lines of credit. Promissory note 20,000 Increase due to the issuance of a payable promissory note payable in conjunction with the acquisition of 12 specialty drilling rigs during the third quarter of 2008. Stock-based 1,364 Increase due to additional vesting of stock compensation options and common share price increases, net of stock option exercises. Income taxes (20,142) Decrease due to income tax instalments, net payable of the current income tax provision for the period. Dividends payable 10 Increase due to a slight increase in the number of outstanding common shares compared with the fourth quarter of 2007. Future income 19,065 Increase due to the current period future taxes income tax provision and changes in foreign exchange rates in the period. Shareholders' 179,253 Increase due to the aggregate impact of net equity income for the period, increase in capital stock due to exercises of employee stock options, impact of foreign exchange rate fluctuations on net assets of foreign self- sustaining subsidiaries, less dividends declared in the period. ------------------------------------------------------------------------- Working Capital and Funds from Operations Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Funds from operations 90,450 53,257 70 297,217 210,743 41 Funds from operations per share $ 0.59 $ 0.35 69 $ 1.94 $ 1.38 41 Working capital(1) 93,001 60,272 54 93,001 60,272 54 ------------------------------------------------------------------------- (1) Comparative figures as of December 31, 2007. During the three months ended September 30, 2008, the Company generated funds from operations of $90.5 million ($0.59 per common share) compared with funds from operations of $53.3 million ($0.35 per common share) for the three months ended September 30, 2007, an increase of 70 percent. Funds from operations totaled $297.2 million ($1.94 per common share) in the first nine months of 2008, an increase of 41 percent over funds from operations of $210.7 million ($1.38 per common share) generated in the nine months ended September 30, 2007. The substantial increase in funds from operations in the third quarter of 2008 compared with the third quarter of 2007 reflects record funds from operations generated in the United States, as well as a rebound in period-over-period operating activity levels in Canada as stable natural gas and high crude oil commodity prices revived demand in parts of the WCSB. The growth in funds from operations achieved in the nine months ended September 30, 2008 over the comparable period of 2007 is predominantly due to improved operating margins and increased operating activity levels in the Company's United States and international oilfield services divisions, offsetting weakness experienced in the Canadian market in the first half of 2008. At September 30, 2008, the Company had a positive working capital position of $93.0 million compared with working capital of $60.3 million at December 31, 2007. The improvement in working capital in the first nine months of 2008 is attributable to positive cash flows generated by all of the Company's operating segments. Offsetting the improvement in working capital arising from strong operating results, working capital was reduced by the reclassification of drill pipe inventory to property and equipment as a result of a revision in the estimated useful lives of these assets. As of September 30, 2008, the Company continues to operate with sufficient liquidity to meet its obligations as they come due. Investing Activities Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Net purchase of property and equipment (128,149) (62,850) 104 (206,672) (223,967) (8) Net change in non-cash working capital 48,845 12,183 301 43,589 (14,218) (407) ---------------------------------------------------------- Cash used in investing activities (79,304) (50,667) 57 (163,083) (238,185) (32) ------------------------------------------------------------------------- Net purchases of property and equipment during the third quarter of 2008 totaled $128.1 million compared with $62.9 million for the third quarter of 2007. Net purchases of property and equipment for the nine months ended September 30, 2008 totaled $206.7 million compared with $224.0 million for the nine months ended September 30, 2007. In addition to ongoing drilling rig upgrade initiatives, capital expenditures in Canada during the third quarter of 2008 include the acquisition of 12 specialty drilling rigs and related equipment from Terracore. The acquisition of this equipment was funded from existing working capital and the issuance of a $20 million promissory note payable. Other capital additions include the construction of two well servicing rigs in Canada in the first quarter of 2008 and the construction of one well servicing rig in the United States in the third quarter of 2008. Major capital additions in the international oilfield services division during the first nine months of 2008 include the deployment of one drilling rig to the Middle East and one drilling rig to North Africa in the first quarter of 2008. Net purchases of property and equipment for the third quarter of 2008 and for the nine months ended September 30, 2008 also include purchases associated with the 2008 new build program. Additional details regarding construction programs in progress at September 30, 2008 are provided below. Financing Activities Three months Nine months ended September 30 ended September 30 ---------------------------------------------------------- % % ($ thousands) 2008 2007 change 2008 2007 change ------------------------------------------------------------------------- Net increase (decrease) in operating lines of credit 39,618 48,243 (18) (3,155) 42,375 (107) Net increase in promissory note payable 20,000 - - 20,000 - - Issue of capital stock 488 276 77 899 1,942 (54) Dividends (12,632) (12,202) 4 (37,889) (36,591) 4 Net change in non-cash working capital 4 1 300 10 47 (79) ---------------------------------------------------------- Cash provided by (used in) financing activities 47,478 36,318 31 (20,135) 7,773 (359) ------------------------------------------------------------------------- During the nine months ended September 30, 2008, the Company restructured its operating credit facilities to better support its global operations and international growth initiatives. Effective June 26, 2008, the Company's available operating lines of credit consist of a $200 million global revolving credit facility (the "global facility") and a $50 million Canadian based revolving credit facility (the "Canadian facility"). The global facility is available to the Company and any of its wholly owned subsidiaries, and may be drawn in Canadian, United States or Australian dollars, up to the equivalent value of $200 million Canadian dollars. The amount available under the Canadian facility is $50 million or the equivalent United States dollars. The utilized balance of the operating lines of credit was increased during the three months ended September 30, 2008 primarily to finance the Company's new build program. During the third quarter, the Company issued a promissory note payable in the amount of $20 million in connection with the purchase of specialty drilling rigs and related equipment from Terracore. The promissory note is unsecured, bears interest at five percent and is payable in full on July 16, 2011. Other financing activities during the third quarter of 2008 include the receipt of $0.5 million on the exercise of employee stock options and the payment of dividends in the amount of $12.6 million. Dividends were declared at a quarterly dividend rate of $0.0825 per common share for the third quarter of 2008, an increase of four percent over dividends of $0.08 per common share declared in the third quarter of 2007. For the nine months ended September 30, 2008, cash received on employee stock option exercises totaled $0.9 million and dividends declared totaled $37.9 million. During the first nine months of 2008, the Company declared year-to-date dividends totaling $0.2475 per common share compared with $0.24 per common share during the first nine months of 2007. 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. The Company also announces an increase of three percent in its regular quarterly dividend to $0.085 per common share. The Company has increased the cumulative amount of dividends declared in each fiscal year since the Company began paying a dividend in September 1995. The Board of Directors of the Company has declared the dividend of $0.085 to be payable on January 2, 2009 to all Common Shareholders of record as of December 22, 2008. The dividend payment is pursuant to the quarterly dividend policy adopted by the Company. Pursuant to subsection 89(14) of the ITA, the dividend being paid is being designated as an eligible dividend, as defined in subsection 89(1) of the ITA. New Builds As previously disclosed, the Company is expanding its global fleet of state-of-the-art ADR(TM) drilling rigs. As of November 10, 2008, the world-wide drilling rig construction program consists of 14 ADRs and eight well servicing rigs, a decline of 13 drilling rigs from previous disclosure. Following the unprecedented events impacting the global economy in recent months and the sharp decline in crude oil prices, the Company has prudently reviewed and amended its drilling rig construction program. Accordingly, 13 of the previously announced drilling rig construction projects have been suspended or delayed. All remaining drilling rig construction projects are supported by term contracts and are proceeding as planned. The Company is carefully monitoring market conditions and continues to look for additional expansion opportunities. Of the 14 ADRs to be constructed, two are ADR(TM)-250 models, two are ADR(TM)-300 models, four are ADR(TM)-350 models and six are ADR(TM)-500 models. Upon completion of this new build program the Company will have a total of 62 ADRs in its fleet. The Company is continuing the expansion of its well servicing fleet in Canada and the United States. During the third quarter of 2008, one new well servicing rig was placed in service in the United States. An additional eight newly built well servicing rigs will be added to the Canadian and United States markets over the remainder of 2008 and early 2009. The revised new build delivery schedule, by geographic area, is as follows: Q4 2008 Q1 2009 Q2 2009 Q3 2009 Q4 2009 Q1 2010 Total ------------------------------------------------------------------------- ADRs United States 1 1 - 2 2 2 8 Interna- tional - 5 1 - - - 6 ------------------------------------------------------------ Total 1 6 1 2 2 2 14 ------------------------------------------------------------------------- Well Servicing Rigs Canada 2 1 2 - - - 5 United States 3 - - - - - 3 ------------------------------------------------------------ Total 5 1 2 - - - 8 ------------------------------------------------------------------------- Outlook As previously disclosed, the operating and financial results for the third quarter of 2008, after adjusting for the impact of stock based compensation expense, exceeded the Company's results from one year ago and our expectations set earlier in the year. That said, there is much uncertainty with respect to the immediate future given the expected impact of the global credit crisis and a general reduction in the demand for crude oil and natural gas owing to recessionary conditions in key North American, European and other world markets. The recent sharp decline in commodity prices, particularly for crude oil, and the tightening of credit availability dictates that our customers will not have the same level of cash flows directed to oilfield services expenditures as we have seen in the past. Reduced demand for oilfield services will, obviously, negatively impact the operating and financial results for the Company and the industry in general. The Company has already taken steps to reduce capital expenditure levels and strategically updated its credit facilities in the second quarter of this year, ensuring that it has the operating facilities required to support current and future levels of operations. The strength of the Company's balance sheet has never been more important than it is now. Currently, the Canadian operations are expected to experience a winter drilling season that is improved over the previous year, more a testament to the weakness of the winter of 2007/08 than the anticipated strength of 2008/09. Exploration and production companies have generally cash flowed very well through the first nine months of 2008, leading to an increase in drilling plans in some areas for this winter compared to last year. Accordingly, bookings for the Canadian drilling fleet are improved for this winter and the Company has been developing crews to ensure that operations can be effectively and safely staffed for the winter. What happens beyond the first quarter of 2009 is still very much in doubt and will be dependent on commodity prices at the end of the winter heating season in North America. In addition to the ongoing risks from global credit, recessionary and environmental issues, oil and natural gas projects in the Province of Alberta also have to contend with the negative economic impacts of royalty changes effective January 1, 2009. Although representatives of the Province of Alberta have stated that they will continue to look at the "unintended consequences" of the royalty changes, it seems that they are making a mistake by not reviewing their stance on this important matter given the way the world has changed. Record crude oil prices and favorable natural gas commodity prices through the first half of 2008 merely masked the problems and issues with the revised Alberta royalty regime. Despite high crude oil prices and favorable natural gas prices, demand for drilling services in Alberta in the third quarter of this year did not react as positively to such prices as did demand in the neighbouring provinces of Saskatchewan and British Columbia. The Company believes that, without meaningful royalty changes, the impact in Alberta will be even worse in 2009. The negative outlook for natural gas prices of one year ago did not materially impact the demand for United States drilling services in 2008 as the exploration and production companies appeared to focus on future strip prices and the need to prove-up reserves. Consequently, many companies drilled through the lower initial outlook for spot prices for natural gas. The Company is not as confident this time around and expects that the demand for drilling rigs in the United States, particularly for conventional natural gas projects, will react to lower expectations for natural gas prices and reduced levels of cash flows and credit availability. The Company expects that its fleet modernization program undertaken over the last several years will allow it to maintain or increase market share in an environment of reduced activity levels in the United States. However, reduced demand for oilfield services will negatively impact margins and cash flow levels. It is therefore prudent that the Company has reduced its previously announced drilling rig building program in the United States from 20 drilling rigs to eight drilling rigs. All eight of the drilling rigs to be constructed over the next 12 to 15 months are supported by "take-or-pay" contracts with major customers. The Company's United States operations are further supported by a significant number of existing term contracts. The international oilfield services market is not immune to the impacts of the global credit crisis and recessionary pressures; however, the nature of the drilling projects is such that they take a longer term view. The projects themselves are generally of a longer term and will carry on through completion. There may be a reduction or delay in new projects resulting from current global conditions and outlook, but existing programs should continue unabated. Accordingly, the Company anticipates its existing international operations will remain steady in the immediate future and that operating and financial results will improve with the completion of the six new drilling rigs currently under construction. These rigs will be deployed to Africa and the Middle East early in the new year adding scale to the international operations. The previously announced refurbishment of an idle international drilling rig has been postponed until general economic conditions improve. This is not the first cyclical low period faced by the Company, nor will it likely be the last. While it is difficult, if not impossible, to ascertain how bad things could really get before the inevitable recovery commences, it is clear that the Company has the advantages of a proven cost-conscious culture and one of the strongest balance sheets in the industry. These strengths will enable the Company to weather the storm and take advantage of the inevitable opportunities that will arise. The key, as always, is not "growth for growth's sake", but acquiring the right type of equipment at the right cost. Our value conscious strategy will ensure that the interests of all our stakeholders, including shareholders, customers and employees, will continue to be well served. 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 second quarter results at 2:00 p.m. MST (4:00 p.m. EST) on Monday, November 10, 2008. The conference call number is 1-800-732-1073. A taped recording will be available until November 17, 2008 by dialing 1-877-289-8525 and entering reservation number 21288240No.. 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 As at September 30, 2008 and December 31, 2007 (Unaudited, in thousands of dollars) September 30 December 31 2008 2007 ------------- ------------ Assets Current assets Cash and cash equivalents $ 24,685 $ 1,940 Accounts receivable 346,937 301,721 Inventory and other 51,401 89,752 Future income taxes 3,129 2,367 -------------------------- 426,152 395,780 Property and equipment 1,575,907 1,390,780 -------------------------- $ 2,002,059 $ 1,786,560 -------------------------- -------------------------- Liabilities Current liabilities Accounts payable and accrued liabilities $ 195,937 $ 177,595 Operating lines of credit (note 4) 114,814 117,969 Current portion of stock-based compensation 10,644 8,056 Income taxes payable (877) 19,265 Dividends payable 12,633 12,623 -------------------------- 333,151 335,508 Promissory note payable (note 5) 20,000 - Stock-based compensation 3,499 4,723 Future income taxes 221,950 202,123 -------------------------- 578,600 542,354 -------------------------- Shareholders' Equity Capital stock (note 6) 169,320 167,599 Accumulated other comprehensive income (68,296) (97,588) Retained earnings 1,322,435 1,174,195 -------------------------- 1,423,459 1,244,206 -------------------------- $ 2,002,059 $ 1,786,560 -------------------------- -------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF INCOME AND RETAINED EARNINGS For the three and nine months ended September 30, 2008 and 2007 (Unaudited - in thousands of dollars, except per share data) Three months ended Nine months ended September 30 September 30 2008 2007 2008 2007 --------------------------------------------------- Revenue Oilfield services $ 435,186 $ 383,316 $ 1,245,144 $ 1,189,340 Expenses Oilfield services 301,233 268,270 821,412 791,151 Depreciation 33,987 22,028 89,705 64,938 General and administrative 12,168 11,527 39,957 38,565 Stock-based compensation (16,993) 630 10,457 7,728 Interest 1,458 1,190 5,402 4,095 --------------------------------------------------- 331,853 303,645 966,933 906,477 --------------------------------------------------- Income before income taxes 103,333 79,671 278,211 282,863 Income taxes Current 27,364 48,944 72,885 130,776 Future 3,898 (19,021) 19,197 (25,117) --------------------------------------------------- 31,262 29,923 92,082 105,659 Net income for the period 72,071 49,748 186,129 177,204 Retained earnings - beginning of period 1,262,996 1,076,711 1,174,195 973,644 Dividends (note 6) (12,632) (12,202) (37,889) (36,591) --------------------------------------------------- Retained earnings - end of period $ 1,322,435 $ 1,114,257 $ 1,322,435 $ 1,114,257 --------------------------------------------------- --------------------------------------------------- Net income per share (note 6) Basic $ 0.47 $ 0.33 $ 1.22 $ 1.16 Diluted $ 0.47 $ 0.32 $ 1.20 $ 1.14 --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF CASH FLOWS For the three and nine months ended September 30, 2008 and 2007 (Unaudited - in thousands of dollars) Three months ended Nine months ended September 30 September 30 2008 2007 2008 2007 --------------------------------------------------- Cash provided by (used in) Operating activities Net income for the period $ 72,071 $ 49,748 $ 186,129 $ 177,204 Items not affecting cash: Depreciation 33,987 22,028 89,705 64,938 Stock-based compensation, net of cash paid (19,506) 502 2,186 (6,282) Future income taxes 3,898 (19,021) 19,197 (25,117) --------------------------------------------------- Cash provided by operating activities before the change in non-cash working capital 90,450 53,257 297,217 210,743 Net change in non-cash working capital (note 8) (67,669) (33,538) (91,254) 20,400 --------------------------------------------------- 22,781 19,719 205,963 231,143 --------------------------------------------------- Investing activities Net purchase of property and equipment (128,149) (62,850) (206,672) (223,967) Net change in non-cash working capital (note 8) 48,845 12,183 43,589 (14,218) --------------------------------------------------- (79,304) (50,667) (163,083) (238,185) --------------------------------------------------- Financing activities Net increase (decrease) in operating lines of credit 39,618 48,243 (3,155) 42,375 Net increase in promissory note payable (note 5) 20,000 - 20,000 - Issue of capital stock 488 276 899 1,942 Dividends (note 6) (12,632) (12,202) (37,889) (36,591) Net change in non-cash working capital (note 8) 4 1 10 47 --------------------------------------------------- 47,478 36,318 (20,135) 7,773 --------------------------------------------------- Net (decrease) increase in cash and cash equivalents during the period (9,045) 5,370 22,745 731 Cash and cash equivalents - beginning of period 33,730 9,931 1,940 14,570 Cash and cash equivalents - end of period $ 24,685 $ 15,301 $ 24,685 $ 15,301 --------------------------------------------------- --------------------------------------------------- Supplemental information Interest paid $ 1,521 $ 1,485 $ 5,585 $ 3,812 Income taxes paid $ 17,794 $ 37,145 $ 93,027 $ 141,068 --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME For the three and nine months ended September 30, 2008 and 2007 (Unaudited - in thousands of dollars) Three months ended Nine months ended September 30 September 30 2008 2007 2008 2007 --------------------------------------------------- Net income for the period $ 72,071 $ 49,748 $ 186,129 $ 177,204 Other comprehensive income Foreign currency translation adjustment (11,800) (31,357) 29,292 (69,708) --------------------------------------------------- Comprehensive income for the period $ 60,271 $ 18,391 $ 215,421 $ 107,496 --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF ACCUMULATED OTHER COMPREHENSIVE INCOME For the three and nine months ended September 30, 2008 and 2007 (Unaudited - in thousands of dollars) Three months ended Nine months ended September 30 September 30 2008 2007 2008 2007 --------------------------------------------------- Accumulated other comprehensive income - beginning of period $ (56,496) $ (58,514) $ (97,588) $ (20,163) Foreign currency translation adjustment (11,800) (31,357) 29,292 (69,708) --------------------------------------------------- Accumulated other comprehensive income - end of period $ (68,296) $ (89,871) $ (68,296) $ (89,871) --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS For the three and nine months ended September 30, 2008 and 2007 (Unaudited, in thousands of dollars, except share and per share data) The interim consolidated financial statements have been prepared in accordance with Canadian generally accepted accounting principles ("Canadian GAAP"), and include the accounts of Ensign Energy Services Inc. and its subsidiaries and partnerships (the "Company"), substantially all of which are wholly-owned. The interim consolidated financial statements have been prepared following the same accounting policies and methods of computation as the consolidated financial statements for the year ended December 31, 2007, except as noted below. The disclosures provided below are incremental to those included with the annual consolidated financial statements. These interim consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto in the Company's annual report for the year ended December 31, 2007. 1. Adoption of new accounting standards Capital disclosures Effective January 1, 2008, the Company adopted the Canadian Institute of Chartered Accountants ("CICA") Handbook Section 1535 "Capital Disclosures". The new section requires an entity to disclose information about its capital and how it is managed. The Company's capital management strategy is outlined in note 9. Financial Instruments Effective January 1, 2008, the Company adopted CICA Handbook Section 3862 "Financial Instruments - Disclosures" and Section 3863 "Financial Instruments - Presentation", which replaced Section 3861 "Financial Instruments - Disclosure and Presentation". The new sections revise and enhance financial instruments disclosure requirements and place increased emphasis on disclosures about the nature and extent of risks arising from financial instruments and how the Company manages those risks. The Company has designated its financial instruments as follows: - Cash and cash equivalents are classified as "held for trading" and any period change in fair value is recorded through net income; - Accounts receivable are classified as "loans and receivables". After their initial fair value measurement, they are measured at amortized cost using the effective interest rate method. For the Company, the measured amount generally corresponds to historical cost; and - Accounts payable and accrued liabilities, operating lines of credit, dividends payable and promissory note payable are classified as "other financial liabilities". After their initial fair value measurement, they are measured at amortized cost using the effective interest rate method. For the Company, the measured amount generally corresponds to historical cost. Inventories Effective January 1, 2008, the Company adopted CICA Handbook Section 3031 "Inventories", which requires inventory to be valued on a 'first-in, first out' or weighted average basis. The new standard also requires fixed and variable production overheads that are incurred in converting materials into finished goods to be allocated to the cost of inventory on a systematic basis. The adoption of this standard did not have a material impact on the Company's consolidated financial statements. Recent accounting pronouncements In January 2006, the CICA Accounting Standards Board ("AcSB") adopted a strategic plan for the direction of accounting standards in Canada. As part of that plan, the AcSB confirmed in February 2008 that International Financial Reporting Standards ("IFRS") will replace Canadian GAAP in 2011 for profit-oriented Canadian publicly accountable enterprises. As the Company will be required to report its results in accordance with IFRS starting in 2011, the Company is assessing the potential impacts of this changeover and developing its plan accordingly. When finalized, it will include project structure and governance, resourcing and training, and an analysis of key differences between IFRS and Canadian GAAP. 2. Change in accounting estimates Effective January 1, 2008 the Company revised the estimated useful life of drill pipe to 1,500 operating days, to be depreciated on a unit-of-production basis. The change in estimated useful life reflects the Company's recent experience with respect to the period over which future benefits are derived from drill pipe and the impact improved technologies have had on extending the useful lives of these assets. As a result of this change in accounting estimate, drill pipe of $39,000 previously classified as inventory and other on the consolidated balance sheet has been reclassified to property and equipment on the basis that its estimated useful life of 1,500 operating days extends beyond the current period. Effective January 1, 2008 the Company revised the estimated useful life of oil sands coring rigs from 3,650 operating days to 1,000 operating days. The oil sands coring rigs will continue to be depreciated on a unit-of-production basis with a 20% residual value. Further, the Company revised the estimated useful life of coiled tubing units from 24,000 operating hours to five years, to be depreciated on a straight-line basis. Effective July 1, 2008, the Company began applying a deprecation charge for crude oil and natural gas drilling and well servicing rigs that are not currently operating based on the revised estimated useful life of such equipment. These changes in accounting estimates have been applied on a prospective basis and did not have a significant effect on consolidated net income for the nine months ended September 30, 2008. It is impracticable to estimate the effect of these changes in accounting estimates on future periods as such an estimate would depend on a forecast of future operating activity levels. 3. Seasonality of operations The Company's Canadian oilfield services operations are seasonal in nature and are impacted by weather conditions that may hinder the Company's ability to access locations or move heavy equipment. The lowest activity levels are experienced during the second quarter of the year when road weight restrictions are in place and access to wellsites in Canada is reduced. 4. Operating lines of credit During the nine months ended September 30, 2008, the Company restructured its operating credit facilities to better support its global operations. Effective June 26, 2008, the Company's available operating lines of credit consist of a $200,000 global revolving credit facility (the "global facility") and a $50,000 Canadian based revolving credit facility (the "Canadian facility"). The global facility is available to the Company and any of its wholly owned subsidiaries and may be drawn in Canadian, United States or Australian dollars, up to the equivalent value of $200,000 Canadian dollars. Interest is incurred on the utilized balance of the global facility at prime interest rates or bankers' acceptance rates/LIBOR plus 0.75%. The global facility is unsecured. The amount available under the Canadian facility is $50,000 or the equivalent United States dollars. Interest is incurred on the utilized balance of the Canadian facility at prime interest rates or bankers' acceptance rates/LIBOR plus 0.85%. The Canadian facility is unsecured. 5. Promissory note payable In connection with the purchase of specialty drilling rigs and related equipment from Terracore Specialty Drilling Ltd. ("Terracore") on July 17, 2008, the Company issued a promissory note to Terracore in the amount of $20,000. The promissory note has a term of three years and shall be payable in full on July 16, 2011. Interest on the promissory note is equal to five percent (5.0%) per annum and will be paid in 12 consecutive quarterly instalments. The Company may prepay the principal sum and interest in whole, or in part, without penalty. The promissory note is unsecured. 6. Capital stock Authorized Unlimited common shares Unlimited preferred shares, issuable in series Outstanding Number of Common Shares Amount --------------------------------------------------------------------- Balance at January 1, 2008 153,041,378 $ 167,599 Issued under employee stock option plan 81,628 1,721 -------------------------- Balance at September 30, 2008 153,123,006 $ 169,320 --------------------------------------------------------------------- Options A summary of the status of the Company's stock option plan as of September 30, 2008, and the changes during the nine-month period then ended, is presented below: Weighted Average Number of Exercise Options Price --------------------------------------------------------------------- Outstanding at January 1, 2008 9,655,450 $ 16.55 Granted 2,369,000 21.68 Exercised for common shares (81,628) (11.01) Exercised for cash (937,860) (11.45) Forfeited (469,700) (19.34) --------------------------------------------------------------------- Outstanding at September 30, 2008 10,535,262 $ 18.07 --------------------------------------------------------------------- Exercisable at September 30, 2008 3,627,062 $ 15.32 --------------------------------------------------------------------- Options Outstanding Options Exercisable --------------------------------------------------------------------- Average Weighted Weighted Vesting Average Options Average Options Remaining Exercise Exer- Exercise Exercise Price Outstanding (in years) Price cisable Price --------------------------------------------------------------------- $8.75 to $11.05 2,085,962 0.56 $ 10.44 1,501,562 $ 10.42 $13.50 to $18.85 1,832,200 1.52 14.10 822,400 13.79 $19.88 to $23.33 6,617,100 2.88 21.58 1,303,100 21.93 ----------------------------------------------------- 10,535,262 2.19 $ 18.07 3,627,062 $ 15.32 --------------------------------------------------------------------- Common share dividends During the nine months ended September 30, 2008, the Company declared dividends of $37,889 (2007 - $36,591), being $0.2475 per common share (2007 - $0.24 per common share). Net income per share Net income per share is calculated by dividing net income by the weighted average number of common shares outstanding during the period. Diluted net income per share is calculated using the treasury stock method, which assumes that all outstanding stock options are exercised, if dilutive, and the assumed proceeds are used to purchase the Company's common shares at the average market price during the period. The weighted average number of common shares outstanding for the nine-month period ended September 30, 2008 and 2007 are as follows: 2008 2007 ------------------------- Weighted average number of common shares outstanding - basic 153,083,329 152,455,715 Weighted average number of common shares outstanding - diluted 154,646,906 155,533,693 ------------------------- Stock options of 4,390,000 (2007 - 4,806,000) were excluded from the calculation of diluted weighted average number of common shares outstanding, as the options' exercise price was greater than the average market price of the common shares for the period. 7. Segmented information The Company operates in three geographic areas within one industry segment. Oilfield services are provided in Canada, the United States and internationally. The amounts related to each geographic area are as follows: Three months ended September 30, 2008 --------------------------------------------------------------------- Canada United States International Total --------------------------------------------------------------------- Revenue $193,939 $161,621 $79,626 $435,186 Property and equipment, net $765,665 $453,479 $356,763 $1,575,907 Capital expenditures, net $3,980 $56,526 $67,643 $128,149 Depreciation $18,348 $8,109 $7,530 $33,987 --------------------------------------------------------------------- Three months ended September 30, 2007 --------------------------------------------------------------------- Canada United States International Total --------------------------------------------------------------------- Revenue $169,726 $149,108 $64,482 $383,316 Property and equipment, net $771,916 $325,535 $284,194 $1,381,645 Capital expenditures, net $12,214 $29,741 $20,895 $62,850 Depreciation $11,400 $5,509 $5,119 $22,028 --------------------------------------------------------------------- Nine months ended September 30, 2008 --------------------------------------------------------------------- Canada United States International Total --------------------------------------------------------------------- Revenue $562,767 $453,761 $228,616 $1,245,144 Property and equipment, net $765,665 $453,479 $356,763 $1,575,907 Capital expenditures, net $9,489 $85,706 $111,477 $206,672 Depreciation $46,176 $22,035 $21,494 $89,705 --------------------------------------------------------------------- Nine months ended September 30, 2007 --------------------------------------------------------------------- Canada United States International Total --------------------------------------------------------------------- Revenue $592,884 $416,739 $179,717 $1,189,340 Property and equipment, net $771,916 $325,535 $284,194 $1,381,645 Capital expenditures, net $28,390 $141,955 $53,622 $223,967 Depreciation $34,255 $15,201 $15,482 $64,938 --------------------------------------------------------------------- 8. Supplemental disclosure of cash flow information The net change in non-cash working capital for the three and nine months ended September 30, 2008 and 2007 is determined as follows: Three months ended Nine months ended September 30 September 30 2008 2007 2008 2007 --------------------------------------------------- Net change in non-cash working capital Accounts receivable $(63,440) $(39,649) $(45,216) $82,681 Inventory and other 1,576 (1,026) (649) (7,726) Accounts payable and accrued liabilities 33,469 7,521 18,342 (58,481) Income taxes payable 9,571 11,799 (20,142) (10,292) Dividends payable 4 1 10 47 --------------------------------------------------- $(18,820) $(21,354) $(47,655) $6,229 --------------------------------------------------- Relating to Operating activities $(67,669) $(33,538) $(91,254) $20,400 Investing activities 48,845 12,183 43,589 (14,218) Financing activities 4 1 10 47 --------------------------------------------------- $(18,820) $(21,354) $(47,655) $6,229 --------------------------------------------------- --------------------------------------------------- 9. Capital management strategy The Company's objectives when managing capital are to exercise financial discipline, and to deliver positive returns and stable dividend streams to its shareholders. The Company's capital management strategy remained unchanged during the nine months ended September 30, 2008; however, the Company continues to be cognizant of the challenges associated with operating in a cyclical, commodity- based industry and may make future adjustments to its capital management strategy in light of changing economic conditions. The Company considers its capital structure to include shareholders' equity and operating lines of credit. In order to maintain or adjust its capital structure, the Company may from time to time adjust its capital spending or dividend policy to manage the level of its short- term borrowings, or may revise the terms of its operating lines of credit to support future growth initiatives. During the nine months ended September 30, 2008, the Company revised the terms of its operating lines of credit as described in note 4. As at September 30, 2008, operating lines of credit totalled $114,814 and shareholders' equity totalled $1,423,459. The Company is subject to externally imposed capital requirements associated with its operating lines of credit, including financial covenants that incorporate shareholders' equity and level of indebtedness. As at September 30, 2008, the Company is in compliance with these requirements. 10. Financial instruments Fair value The carrying value of cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities, operating lines of credit and dividends payable approximate fair value due to the short-term nature of these instruments. The carrying value of the promissory note payable approximates fair value as its interest terms approximate a market rate of interest. Credit risk Credit risk is the risk of financial loss to the Company if a customer or counterparty to a financial instrument fails to meet its contractual obligations. Credit risk arises principally from the Company's accounts receivable balances owing from customers operating primarily in the oil and natural gas industry in Canada, the United States and internationally. The carrying amount of accounts receivable represents the maximum credit exposure as at September 30, 2008. The Company assesses the credit worthiness of its customers on an ongoing basis and considers the credit risk on these amounts normal for the industry. The Company establishes credit limits for each customer based on external credit reports, internal analysis and historical experience with the customer. Credit limits are approved by senior management and are reviewed on a regular basis or when changing economic circumstances dictate. The Company also monitors the amount and age of accounts receivable balances on an ongoing basis. At September 30, 2008 the Company's allowance for doubtful accounts was $629, an increase of $221 from the balance as at December 31, 2007. Liquidity risk Liquidity risk is the risk that the Company will not be able to meets its financial obligations as they are due. The Company manages liquidity by forecasting cash flows on an annual basis and secures sufficient credit facilities to meet financing requirements that exceed anticipated internally generated funds. As at September 30, 2008, the remaining contractual maturities of accounts payable and accrued liabilities, operating lines of credit and dividends payable are less than one year. As at September 30, 2008, the remaining contractual maturity of the promissory note payable is less than three years. Market risk Market risk is the risk that changes in market prices, such as foreign exchange rates and interest rates, will affect the Company's net income or the value of the financial statements. Interest rate risk ------------------ The Company is exposed to interest rate risk with respect to its operating lines of credit that bear interest at floating market rates. For the nine months ended September 30, 2008, if interest rates applicable to the operating lines of credit had been 1% higher or lower, with all other variables held constant, net income would have been $779 higher or lower. Foreign currency exchange rate risk ----------------------------------- The Company operates internationally and is exposed to foreign exchange risk arising from various currency exposures, primarily with respect to the United States dollar and the Australian dollar. The principal foreign exchange risk relates to the conversion of the Company's self-sustaining subsidiaries from their functional currencies to Canadian dollars. At September 30, 2008, had the Canadian dollar weakened or strengthened by $0.01 against the United States dollar, with all other variables held constant, the Company's other comprehensive income would have been approximately $5,500 higher or lower. At September 30, 2008, had the Canadian dollar weakened or strengthened by $0.01 against the Australian dollar, with all other variables held constant, the Company's other comprehensive income would have been approximately $2,500 higher or lower. The Company is also exposed to foreign currency exchange rate risk related to its net United States dollar denominated debt held within its Australian subsidiary. A $0.01 change in the United States to Australian dollar exchange rate would have resulted in a change in net income of approximately $155 at September 30, 2008. The above sensitivities are limited to the impact of changes in the specified variable applied to the items noted above and do not represent the impact of a change in the variable on the operating results of the Company taken as a whole. 11. Prior period amounts Certain prior period amounts have been reclassified to conform to the current period's presentation. %SEDAR: 00001999E For further information: Glenn Dagenais, Executive Vice President Finance and Chief Financial Officer, (403) 262-1361 |