Ensign Energy Services Inc. Reports 2009 Second Quarter Results2009-08-10 CALGARY, Aug. 10 /CNW/ - Overview Ensign Energy Services Inc. (the "Company") recorded net income of $13.2 million ($0.09 per share) for the second quarter of 2009, a decline of 59 percent compared with net income of $32.3 million ($0.21 per share) recorded for the second quarter of 2008. Net income for the six months ended June 30, 2009 totaled $85.9 million ($0.56 per share), a decrease of 25 percent from net income of $114.1 million ($0.75 per share) recorded in the first six months of 2008. The decline in the Company's operating and financial results for the second quarter and first half of 2009 compared to the prior year reflect reduced industry activity levels and recessionary global economic conditions that have persisted through the first half of this year. Revenue for the second quarter of 2009 was $226.0 million, a 33 percent decrease from the $337.8 million for the second quarter of the prior year. The Company recorded revenue of $626.4 million for the six months ended June 30, 2009, a 23 percent decrease from revenue of $810.0 million for the six months ended June 30, 2008. Results from the Company's Canadian and United States oilfield services segments continued to deteriorate due to poor fundamentals for natural gas. While the price for crude oil did recover somewhat in the second quarter of 2009, it did not have a meaningful impact on operations in these natural gas driven segments of the Company. Gross margin decreased slightly in the second quarter of 2009 to 31.0 percent compared to 31.1 percent recorded in the second quarter of 2008. While utilization and revenue decreased during the six months ended June 30, 2009 relative to the same period in the prior year, the Company has preserved its gross margin of 33.6 percent (2008 - 35.8 percent). This is attributable to established contractual revenue rates realized on newer equipment working in North America combined with a continued focus on carefully controlling costs. Spot prices for un-contracted oilfield services equipment continued to deteriorate in the quarter due to low demand and an oversupply of equipment in Canada and the United States. The six new drilling rigs delivered by the Company into the international market during the first half of 2009 also contributed favorable margins thereby maintaining the average gross margin for 2009 at a rate higher than would otherwise be expected given current market conditions. Adjusted net income for the second quarter of 2009 was $23.1 million ($0.15 per share), a decrease of 41 percent from adjusted net income of $39.2 million ($0.26 per share) for the second quarter of 2008. During the six months ended June 30, 2009, adjusted net income decreased by 29 percent to $93.2 million ($0.61 per share) from $131.9 million ($0.86 per share) recorded for the corresponding period in 2008. Adjusted net income is defined as net income before the tax-effected stock-based compensation expense. Stock-based compensation expense for the second quarter of 2009 was $15.2 million (2008 - $10.7 million); and for the first six months of 2009 was $11.3 million (2008 - $27.5 million). The impact of the increase in the closing price for the Company's common shares at June 30, 2009 compared to the closing price at March 31, 2009, was significant in the context of the reduction in the net income recorded by the Company for the second quarter of 2009. FINANCIAL AND OPERATING HIGHLIGHTS ($ thousands, except per share data and operating information) ------------------------------------------------------------------------- Three months ended Six months ended June 30 June 30 ------------------------------------------------------------------------- 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Revenue 226,010 337,774 (33) 626,430 809,958 (23) ------------------------------------------------------------------------- EBITDA(1) 60,151 90,935 (34) 188,566 261,990 (28) EBITDA per share(1) Basic $ 0.39 $ 0.59 (34) $ 1.23 $ 1.71 (28) Diluted $ 0.39 $ 0.59 (34) $ 1.23 $ 1.69 (27) ------------------------------------------------------------------------- Adjusted net income(2) 23,083 39,238 (41) 93,233 131,901 (29) Adjusted net income per share(2) Basic $ 0.15 $ 0.26 (42) $ 0.61 $ 0.86 (29) Diluted $ 0.15 $ 0.25 (40) $ 0.61 $ 0.85 (28) ------------------------------------------------------------------------- Net income 13,212 32,262 (59) 85,898 114,058 (25) Net income per share Basic $ 0.09 $ 0.21 (57) $ 0.56 $ 0.75 (25) Diluted $ 0.09 $ 0.21 (57) $ 0.56 $ 0.74 (24) ------------------------------------------------------------------------- Funds from operations(3) 61,924 82,526 (25) 143,929 206,767 (30) Funds from operations per share (3) Basic $ 0.40 $ 0.54 (26) $ 0.94 $ 1.35 (30) Diluted $ 0.40 $ 0.53 (25) $ 0.94 $ 1.34 (30) ------------------------------------------------------------------------- Weighted average shares - basic (000s) 153,144 153,074 - 153,140 153,064 - Weighted average shares - diluted (000s) 153,707 155,161 (1) 153,383 154,669 (1) ------------------------------------------------------------------------- Drilling Number of marketed rigs Canada Conven- tional 158 157 1 158 157 1 Oil sands coring/ coal-bed methane 28 28 - 28 28 - United States 77 76 1 77 76 1 Inter- national(4) 48 48 - 48 48 - Operating days Canada 1,264 3,399 (63) 6,400 11,931 (46) United States 2,121 5,110 (59) 4,996 10,027 (50) Inter- national 1,856 2,596 (29) 3,824 4,963 (23) ------------------------------------------------------------------------- Well Servicing Number of marketed rigs/units Canada 108 118 (8) 108 118 (8) United States 18 15 20 18 15 20 Operating hours Canada 20,098 28,478 (29) 51,747 73,449 (30) United States 6,843 8,629 (21) 16,379 17,431 (6) ------------------------------------------------------------------------- (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 plan. 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 plan, 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 June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Revenue Canada 52,108 108,378 (52) 233,222 368,828 (37) United States 94,617 152,825 (38) 222,321 292,140 (24) Inter- national 79,285 76,571 4 170,887 148,990 15 ----------------------------------------------------------- 226,010 337,774 (33) 626,430 809,958 (23) Oilfield services expense 155,993 232,715 (33) 415,790 520,179 (20) ----------------------------------------------------------- 70,017 105,059 (33) 210,640 289,779 (27) ----------------------------------------------------------- Gross margin 31.0% 31.1% 33.6% 35.8% ------------------------------------------------------------------------- Canada ------ The Company recorded revenue of $52.1 million in Canada in the second quarter of 2009, a 52 percent decrease from $108.4 million recorded in the second quarter of 2008. Canadian revenue was $233.2 million for the six months ended June 30, 2009, a 37 percent decrease from $368.8 million recorded in the six months ended June 30, 2008. Canada accounted for just 23 percent of the Company's revenue in the second quarter of 2009 (2008 - 32 percent); and for 37 percent of the Company's revenue in the first six months of 2009 (2008 - 46 percent). Notwithstanding the seasonality of the second quarter, when spring break-up and wet weather conditions hinder the Company's ability to move heavy equipment and access Canadian drilling locations, the overall results for Canada reflect a weak quarter. The Company experienced a decline in oilfield services activity compared with the same period of the prior year when the prospects for the oilfield services industry appeared much brighter. Customers have significantly reduced demand for oilfield services as crude oil and natural gas commodity prices dropped and credit markets tightened. Without a meaningful increase in natural gas commodity prices leading to increased demand for oilfield services, it will take some time to rebalance the oilfield services market in Canada due to the over-supply of equipment. Drilling days recorded by the Canadian division in the second quarter of 2009 decreased by 63 percent from the comparable period of the prior year. During the six months ended June 30, 2009, Canadian drilling days decreased 46 percent from the same period of the prior year. Similarly, Canadian well servicing hours decreased by 29 percent in the second quarter of 2009 and by 30 percent in the six months ended June 30, 2009 with respect to the corresponding periods in the prior year. In light of the current operating environment and the reduced short term prospects for the Canadian industry, the Company has pared back its Canadian operations to more effectively manage the reduction in activity in Canada. United States ------------- The Company's United States operations recorded revenue of $94.6 million in the second quarter of 2009, a 38 percent decrease from the $152.8 million recorded in the corresponding period of the prior year. United States revenue was $222.3 million for the six months ended June 30, 2009, down 24 percent from revenue of $292.1 million for the first six months of 2008. The United States accounted for 42 percent of the Company's revenue in the second quarter of 2009 (2008 - 45 percent); and for 36 percent of the Company's revenue in the first six months of 2009, unchanged from the prior year. In relative terms, the Company's United States results have fared better than Canada, largely due to a greater contractual coverage of the United States oilfield services equipment fleet compared to the Canadian fleet. Much of the Company's construction program over the last couple of years has been directed at adding new equipment to the United States market, and these high performing ADRTM drilling rigs built for the United States market have been subject to multi-year take-or-pay contracts. At June 30, 2009, a total of five contracted ADRs were still under construction for delivery before year-end. The decline in activity levels in the Company's United States operations compared to the prior year mirror the overall reduction in the United States active rig count in 2009. The number of drilling days recorded by the United States division in the second quarter of 2009 decreased 59 percent from the same period of the prior year. United States drilling days for the first six months of 2009 decreased 50 percent from the prior year. United States well servicing hours in the second quarter of 2009 were down 21 percent compared to the prior year and well servicing hours for the first half of 2009 were down 6 percent compared to the first half of 2008. Further reducing the 2009 contributions from the Company's United States operations is the translation impact of the weakening in the United States dollar relative to the Canadian dollar, the Company's reporting currency. The average Canadian/United States dollar exchange rate at which the Company's United States dollar results were translated to Canadian dollars for presentation purposes was 1.1671 for the second quarter of 2009 compared to 1.2453 for the first quarter of 2009. International ------------- The Company's international operations recorded revenue of $79.3 million in the second quarter of 2009, a 4 percent increase from the $76.6 million recorded in the second quarter of 2008. International revenue totaled $170.9 million for the six months ended June 30, 2009, an increase of 15 percent from revenue of $149.0 million for the first six months of 2008. The international division contributed 35 percent of the Company's revenue in the second quarter of 2009 (2008 - 23 percent); and 27 percent of the Company's revenue in the first six months of 2009 (2008 - 18 percent). The Company's established geographical diversification strategy has offset some of the weakness from the Company's North American operations. The international oilfield services market is not immune to the negative pressures of the global economic recession. Drilling days recorded by the Company's international operations in the quarter ended June 30, 2009 decreased 29 percent from the second quarter of 2008, while drilling days recorded in the six months ended June 30, 2009 decreased 23 percent from the same period in 2008. The Company's operations in Latin America and Africa have experienced reductions in demand for oilfield services in the first half of 2009. Mitigating this regional weakness has been the successful deployment of six new ADRTM drilling rigs in the first six months of the year. The contributions from these new rigs should offset the expected weakness in certain international regions serviced by the Company. Depreciation Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Depreciation 22,854 27,465 (17) 51,794 55,718 (7) ------------------------------------------------------------------------- Depreciation expense totaled $22.9 million for the second quarter of 2009 compared with $27.5 million for the second quarter of 2008. Depreciation expense decreased to $51.8 million for the six months ended June 30, 2009 compared with $55.7 million for the six months ended June 30, 2008. The change in depreciation reflects decreased consolidated operating activity levels, partially offset by increased depreciation on higher valued equipment added to the Company's drilling rig fleet over the course of 2009. In addition, effective July 1, 2008, the Company began applying a depreciation charge for drilling and well servicing rigs that have not operated within the last 12 months based on the estimated useful life of such equipment, resulting in additional depreciation expense in the three and six months ended June 30, 2009. General and Administrative Expense Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- General and administrative 13,375 13,936 (4) 27,317 29,143 (6) % of revenue 5.9% 4.1% 4.4% 3.6% ------------------------------------------------------------------------- General and administrative expense totaled $13.4 million (5.9 percent of revenue) for the second quarter of 2009 compared with $13.9 million (4.1 percent of revenue) for the second quarter of 2008, a decline of 4 percent. General and administrative expense totaled $27.3 million (4.4 percent of revenue) for the six months ended June 30, 2009 compared with $29.1 million (3.6 percent of revenue) for the six months ended June 30, 2008, a decline of 6 percent. As a percentage of revenue, general and administrative expense was comparable to the corresponding periods of 2008. The decline in general and administrative expense reflects the Company's efforts to control costs during periods of declining activity levels. Stock-Based Compensation Expense Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Stock-based compensation 15,186 10,734 41 11,284 27,450 (59) ------------------------------------------------------------------------- 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 for the effect of granting and vesting of employee stock options and changes in the underlying price of the Company's common shares. For the quarter-ended June 30, 2009, the majority of the stock-based compensation expense consists of $14.5 million due to an increase in the Company's common share price during the quarter. For the six months ended June 30, 2009, stock-based compensation expense consists of $0.7 million for the vesting of additional stock options and $10.6 million associated with an increase in the price of the Company's common shares. The price of the Company's common shares was $17.00 at June 30, 2009 compared with $10.92 at March 31, 2009 and $13.22 at December 31, 2008. Interest Expense Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Interest 197 2,007 (90) 926 3,944 (77) ------------------------------------------------------------------------- Interest expense is incurred on the Company's operating lines of credit and promissory note payable, and is shown net of interest income earned on the Company's cash balances. The decrease in interest expense for the three and six months ended June 30, 2009 compared to the prior year is due to the decline in interest rates in the first 6 months of 2009 compared to the same period in 2008. Further, the 2008 second quarter interest expense includes upfront fees related to the new operating lines of credit that were negotiated during that quarter. The Company's effective interest rate for the 6 months ended June 30, 2009 was approximately 1.2% compared to approximately 8.2% for the corresponding period of the prior year. Income Taxes Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Current income tax (7,425) 2,175 (441) 38,253 45,521 (16) Future income tax 16,127 16,292 (1) 411 15,299 (97) ------------------------------------------------------------------------- 8,702 18,467 (53) 38,664 60,820 (36) ------------------------------------------------------------------------- Effective income tax rate (%) 39.7% 36.4% 31.0% 34.8% ------------------------------------------------------------------------- The effective income tax rate for the second quarter of 2009 was 39.7 percent compared with 36.4 percent in the second quarter of 2008. For the six months ended June 30, 2009, the effective income tax rate was 31.0 percent compared with 34.8 percent for the six months ended June 30, 2008. The Company's effective income tax rate on a quarter-over-quarter basis increased due to an increase in the proportion of taxable income being earned in the United States, a higher tax rate jurisdiction. Current income tax decreased due to a reduction in taxable income for the Canadian operations in the second quarter of 2009. The decrease in the effective income tax rate for the six months ended June 30, 2009 compared with the six months ended June 30, 2008 is due to future income tax recoveries in the Canadian partnerships and increased levels of income being generated in international jurisdictions that have lower income tax rates. Financial Position The following chart outlines significant changes in the consolidated balance sheet from December 31, 2008 to June 30, 2009: ($ thousands) Change Explanation ------------------------------------------------------------------------- Cash and cash equivalents 69,081 See consolidated statement of cash flows. Accounts receivable (169,504) Decrease due to a decrease in operating activity levels in the second quarter of 2009 compared with the fourth quarter of 2008. Inventory and other (838) Decrease due to normal course consumption of operating supplies and spare parts. Property and equipment (18,814) Decrease due to increased depreciation on higher-value equipment. Accounts payable and accrued (101,895) Decrease due to a decrease in liabilities operating activity levels in the second quarter of 2009 compared with the fourth quarter of 2008. Operating lines of credit (39,263) Decrease due to net repayments of the operating lines of credit. Promissory note payable (20,000) Decrease due to payment of the promissory note in June 2009. Stock-based compensation 5,746 Increase due to an increase in the price of the Company's common shares as at June 30, 2009 compared with December 31, 2008. Income taxes payable 14,630 Increase due to the current income tax provision for the period, net of tax instalments. Dividends payable 2 Increase due to a slight increase in the number of outstanding common shares compared with the fourth quarter of 2008. Future income taxes (2,458) Decrease due to the current period future income tax recovery arising from a decrease in partnership timing differences. Shareholders' equity 23,163 Increase due to the impact of net income for the period and the impact of foreign exchange rate fluctuations on net assets of foreign self-sustaining subsidiaries, net of dividends declared in the period. ------------------------------------------------------------------------- Working Capital and Funds from Operations Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Funds from operations 61,924 82,526 (25) 143,929 206,767 (30) Funds from operations per share $0.40 $0.54 (26) $0.94 $1.35 (30) Working capital(1) 128,041 107,024 20 128,041 107,024 20 ------------------------------------------------------------------------- (1) Comparative figure as at December 31, 2008. During the three months ended June 30, 2009, the Company generated funds from operations of $61.9 million ($0.40 per common share) compared with funds from operations of $82.5 million ($0.54 per common share) for the three months ended June 30, 2008, a decrease of 25 percent. Funds from operations totaled $143.9 million ($0.94 per common share) in the first six months of 2009, a decrease of 30 percent compared to $206.8 million of funds from operations ($1.35 per common share) generated in the six months ended June 30, 2008. The decrease in funds from operations in both the second quarter of 2009 and the six months ended June 30, 2009 compared to the same periods in 2008 is due to the deterioration of oilfield services market conditions, primarily in the Company's Canadian and United States divisions, resulting in lower activity levels. The decline in operating activity is slightly offset by contributions from the newly constructed ADRs placed in operation in the United States and international markets under term contracts during the first six months of 2009. The significant factors that may impact the Company's ability to generate funds from operations in future periods are outlined in the "Risks and Uncertainties" section of the Management's Discussion and Analysis contained in the Company's 2008 Annual Report. During the second quarter of 2009, the Company increased its working capital to $128.0 million, up $21.0 million from December 31, 2008, an enviable achievement given the difficult economic environment and market conditions present in the second quarter of 2009. As of June 30, 2009, the Company continues to operate with no long-term debt and operates with sufficient liquidity to meet its obligations as they come due. Investing Activities Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Net purchase of property and equipment (26,688) (44,979) (41) (72,782) (78,523) (7) Net change in non-cash working capital (38,695) (2,006) 1,829 (18,865) (5,255) 259 ------------------------------------------------------------- Cash used in investing activities (65,383) (46,985) 39 (91,647) (83,778) 9 ------------------------------------------------------------------------- Net purchases of property and equipment during the second quarter of 2009 totaled $26.7 million compared with $45.0 million for the second quarter of 2008. Net purchases of property and equipment for the six months ended June 30, 2009 totaled $72.8 million compared with $78.5 million for the six months ended June 30, 2008. The net purchase of property and equipment relates predominantly to the Company's new-build program as all other non-critical capital expenditures were tightly controlled or suspended during the second quarter of 2009. Additional details regarding the new-build program are provided in the "New Builds" section below. Financing Activities Three months ended June 30 Six months ended June 30 ----------------------------------------------------------- ($ thousands) 2009 2008 % change 2009 2008 % change ------------------------------------------------------------------------- Net decrease in operating lines of credit (2,761) (50,449) (95) (39,263) (42,773) (8) Net decrease in promissory note payable (20,000) - (100) (20,000) - (100) Issue of capital stock 152 111 37 152 411 (63) Dividends (13,018) (12,629) 3 (26,034) (25,257) 3 Net change in non-cash working capital 2 1 100 2 6 (67) ------------------------------------------------------------- Cash used in financing activities (35,625) (62,966) (43) (85,143) (67,613) 26 ------------------------------------------------------------------------- Net repayments of the operating lines of credit were the result of operating cash flows generated by the Company's Canadian and United States oilfield services divisions in excess of capital expenditure requirements. As of June 30, 2009, the operating lines of credit are primarily being used to fund the new-build program and to support international operations. The $20 million promissory note due July 2011 was paid in full during the second quarter of 2009. Currently, the Company has no long-term debt. Other financing activities during the second quarter of 2009 include the receipt of $0.2 million on the exercise of employee stock options and the payment of dividends in the amount of $13.0 million ($0.085 per share). For the six months ended June 30, 2009, cash received on employee stock option exercises totaled $0.2 million and dividends paid totaled $26.0 million. During the first six months of 2009, the Company declared year-to-date dividends totaling $0.170 per common share compared with $0.165 per common share during the first six months of 2008. 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 ("ITA"). The Board of Directors of the Company has declared a third quarter dividend of $0.085 per common share to be payable October 1, 2009 to all Common Shareholders of record as of September 21, 2009. The dividend is pursuant to the quarterly dividend policy adopted by the Company. Pursuant to subsection 89(1) of the ITA, the dividend being paid is designated as an eligible dividend, as defined in subsection 89(1) of the ITA. New Builds During the quarter ended June 30, 2009, two additional ADR(TM)-1500 models were added to the Company's world-wide rig construction program. As of August 10, 2009, nine ADRs have been completed and five remain under construction. Of the 14 ADRs included in the construction program, two are ADR(TM)-250 models, two are ADR(TM)-300 models, four are ADR(TM)-350 models, four are ADR(TM)-1000 models, and two are ADR(TM)-1500 models. Upon completion of this new-build program, the Company will have a total of 62 ADRs in its fleet. The well servicing rig new-build program consists of seven well servicing rigs: four for the Canadian market, of which three have been delivered during the first half of 2009, and three well servicing rigs for the United States market, all of which have been completed. The new-build delivery schedule, by geographic area, is as follows: ------------------------------------------------------------------------- Actual Forecast ---------------------------------------------------------- Q4 2008 Q1 2009 Q2 2009 Q3 2009 Q4 2009 Total ------------------------------------------------------------------------- ADRs United States 1 1 1 2 3 8 International - 2 4 - - 6 ---------------------------------------------------------- Total 1 3 5 2 3 14 ------------------------------------------------------------------------- Well Servicing Rigs Canada - 1 2 1 - 4 United States 1 2 - - - 3 ---------------------------------------------------------- Total 1 3 2 1 - 7 ------------------------------------------------------------------------- Outlook The outlook for the Company, and the oilfield services industry in general, continues to be very weak as the global economy struggles to overcome the recent recessionary trends. Weak economic conditions have led to reduced levels of demand for energy commodities, thereby resulting in weak equipment utilization levels and deteriorating margins for the Company. Additionally, many of the Company's customers continue to struggle to address balance sheet issues in this environment, adding further downward pressure on the Company's operations. These are indeed difficult times that have placed the oilfield services industry at a crossroads. Survival is dependent on financial strength and the decisions made to adapt to a new operating environment. Our Canadian operations have now exited the "spring break-up" quarter, but third quarter activity levels remain down in historical terms as operators have reduced the demand for oilfield services, particularly in response to natural gas price levels that have challenged the economics associated with many projects. A recent improvement in crude oil commodity prices to the USD$60 to $70 per barrel range has helped activity levels in certain oil-producing regions somewhat, but not enough to overcome the overall weakness owing to unfavorable natural gas commodity prices. Activity levels in Canada are primarily driven by supply and demand fundamentals for natural gas. Until there is a significant improvement in the commodity price for natural gas, we do not expect demand for oilfield services in Canada to improve. Additionally, there remains an oversupply of oilfield services equipment that must be addressed before margins can improve. Clearly, the Canadian industry has many challenges ahead of it. While there have been some encouraging signs in the second quarter, such as the ability of exploration and production companies to raise equity in the capital markets (much of which was utilized to fix balance sheet issues) and interim measures from the Alberta government to provide short-term royalty incentives, there has not been a meaningful increase in demand for oilfield services. The United States oilfield services market has started to show signs that it may have found a bottom. Recent rig count data has stabilized and even shown a modest increase from the floor in 2009 due to additional activity associated with the increase in crude oil prices. However, it is still too early to turn optimistic with respect to the prospects for the United States market. Fundamentals driving oilfield services activity will not improve until economic conditions strengthen to levels that improve the demand for energy commodities. It remains anybody's guess as to when this might occur. In the meantime, the Company continues to enjoy good contract coverage in this market segment and has the advantage of having a newer high tech drilling rig fleet that meets the efficiency demands of today's resource plays. As expected, the international oilfield services market had begun to show signs of weakness amid energy demand reductions resulting from recessionary global economic conditions. Although mild by North American standards, the Company's international operations have been negatively impacted by deteriorating commodity prices. The recent improvement in crude oil prices should help stabilize activities in key areas of the international market. That said, there remain regional issues that must be managed to ensure the continued profitability of certain areas for the Company. On a positive note, the Company has completed the international portion of its new build program. All six drilling rigs for the international market have been successfully completed and mobilized in the first half of 2009. These new drilling rigs are operating at or above design performance levels and will have a meaningful impact on the Company's international results in succeeding quarters through the completion of the multi-year contracts associated with such rigs. The Company continues to search for new contracts and new opportunities to expand its global footprint through the delivery of our industry-leading drilling technology. While much of what is going on in the world falls outside of our control, we continue to adapt the Company to the new realities challenging the oilfield services industry. As we have said before, the strength of the Company's balance sheet has never been more important than it is now. We believe that our diversified operations, well-trained personnel, financial strength, focus on cost control and opportunistic approach towards growth will help us to emerge from this down cycle in a stronger position. 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. MDT (4:00 p.m. EDT) on Monday, August 10, 2009. The conference call number is 1-800-732-9303. A taped recording will be available until August 17, 2009 by dialing 1-877-289-8525 and entering reservation number 21310936 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 As at June 30, 2009 and December 31, 2008 (Unaudited, in thousands of Canadian dollars) June 30 December 31 2009 2008 ------------ ------------- Assets Current assets Cash and cash equivalents $ 164,986 $ 95,905 Accounts receivable 190,982 360,486 Inventory and other 59,986 60,824 Future income taxes 2,546 1,040 -------------------------- 418,500 518,255 Property and equipment 1,691,767 1,710,581 -------------------------- $ 2,110,267 $ 2,228,836 -------------------------- -------------------------- Liabilities Current liabilities Accounts payable and accrued liabilities $ 134,189 $ 236,084 Operating lines of credit 130,180 169,443 Current portion of stock-based compensation 9,292 3,538 Income taxes payable 3,780 (10,850) Dividends payable 13,018 13,016 -------------------------- 290,459 411,231 Promissory note payable - 20,000 Stock-based compensation 1,095 1,103 Future income taxes 244,399 245,351 -------------------------- 535,953 677,685 -------------------------- Shareholders' Equity Capital stock (note 3) 169,717 169,485 Accumulated other comprehensive loss (38,516) (1,583) Retained earnings 1,443,113 1,383,249 -------------------------- 1,574,314 1,551,151 -------------------------- $ 2,110,267 $ 2,228,836 -------------------------- -------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF INCOME AND RETAINED EARNINGS For the three and six months ended June 30, 2009 and 2008 (Unaudited, in thousands of Canadian dollars, except per share data) Three months ended Six months ended June 30 June 30 2009 2008 2009 2008 --------------------------------------------------- Revenue Oilfield services $ 226,010 $ 337,774 $ 626,430 $ 809,958 Expenses Oilfield services 155,993 232,715 415,790 520,179 Depreciation 22,854 27,465 51,794 55,718 General and administrative 13,375 13,936 27,317 29,143 Stock-based compensation 15,186 10,734 11,284 27,450 Interest 197 2,007 926 3,944 Other (3,509) 188 (5,243) (1,354) --------------------------------------------------- 204,096 287,045 501,868 635,080 --------------------------------------------------- Income before income taxes 21,914 50,729 124,562 174,878 Income taxes Current (7,425) 2,175 38,253 45,521 Future 16,127 16,292 411 15,299 --------------------------------------------------- 8,702 18,467 38,664 60,820 --------------------------------------------------- Net income for the period 13,212 32,262 85,898 114,058 Retained earnings - beginning of period 1,442,919 1,243,363 1,383,249 1,174,195 Dividends (note 3) (13,018) (12,629) (26,034) (25,257) --------------------------------------------------- Retained earnings - end of period $ 1,443,113 $ 1,262,996 $ 1,443,113 $ 1,262,996 --------------------------------------------------- --------------------------------------------------- Net income per share (note 3) Basic $ 0.09 $ 0.21 $ 0.56 $ 0.75 Diluted $ 0.09 $ 0.21 $ 0.56 $ 0.74 --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF CASH FLOWS For the three and six months ended June 30, 2009 and 2008 (Unaudited, in thousands of Canadian dollars) Three months ended Six months ended June 30 June 30 2009 2008 2009 2008 --------------------------------------------------- Cash provided by (used in) Operating activities Net income for the period $ 13,212 $ 32,262 $ 85,898 $ 114,058 Items not affecting cash: Depreciation 22,854 27,465 51,794 55,718 Stock-based compensation, net of cash paid 9,731 6,507 5,826 21,692 Future income taxes 16,127 16,292 411 15,299 --------------------------------------------------- Cash provided by operating activities before the change in non-cash working capital 61,924 82,526 143,929 206,767 Net change in non-cash working capital (note 5) 104,008 47,295 101,942 (23,586) --------------------------------------------------- 165,932 129,821 245,871 183,181 --------------------------------------------------- Investing activities Net purchase of property and equipment (26,688) (44,979) (72,782) (78,523) Net change in non-cash working capital (note 5) (38,695) (2,006) (18,865) (5,255) --------------------------------------------------- (65,383) (46,985) (91,647) (83,778) --------------------------------------------------- Financing activities Net decrease in operating lines of credit (2,761) (50,449) (39,263) (42,773) Net decrease in promissory note payable (20,000) - (20,000) - Issue of capital stock 152 111 152 411 Dividends (note 3) (13,018) (12,629) (26,034) (25,257) Net change in non-cash working capital (note 5) 2 1 2 6 --------------------------------------------------- (35,625) (62,966) (85,143) (67,613) --------------------------------------------------- Increase in cash and cash equivalents during the period 64,924 19,870 69,081 31,790 Cash and cash equivalents - beginning of period 100,062 13,860 95,905 1,940 --------------------------------------------------- Cash and cash equivalents - end of period $ 164,986 $ 33,730 $ 164,986 $ 33,730 --------------------------------------------------- --------------------------------------------------- Supplemental information Interest paid $ 988 $ 2,081 $ 1,449 $ 4,064 Income taxes paid $ 15,517 $ 37,364 $ 23,623 $ 75,233 --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) For the three and six months ended June 30, 2009 and 2008 (Unaudited, in thousands of Canadian dollars) Three months ended Six months ended June 30 June 30 2009 2008 2009 2008 --------------------------------------------------- Net income for the period $ 13,212 $ 32,262 $ 85,898 $ 114,058 Other comprehensive income (loss) Foreign currency translation adjustment (62,471) 6,380 (36,933) 41,092 --------------------------------------------------- Comprehensive income (loss) for the period $ (49,259) $ 38,642 $ 48,965 $ 155,150 --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF ACCUMULATED OTHER COMPREHENSIVE LOSS For the three and six months ended June 30, 2009 and 2008 (Unaudited, in thousands of Canadian dollars) Three months ended Six months ended June 30 June 30 2009 2008 2009 2008 --------------------------------------------------- Accumulated other comprehensive loss - beginning of period $ 23,955 $ (62,876) $ (1,583) $ (97,588) Foreign currency translation adjustment (62,471) 6,380 (36,933) 41,092 --------------------------------------------------- Accumulated other comprehensive loss - end of period $ (38,516) $ (56,496) $ (38,516) $ (56,496) --------------------------------------------------- --------------------------------------------------- See accompanying notes to the consolidated financial statements. NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS For the three and six months ended June 30, 2009 and 2008 (Unaudited, in thousands of Canadian 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, 2008. 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, 2008. 1. Recent accounting pronouncements The Canadian Institute of Chartered Accountants ("CICA") Accounting Standards Board ("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. As of January 1, 2011, the Company will be required to adopt the following CICA Handbook sections: (a) CICA Handbook Section 1582 "Business Combinations" will replace the existing business combinations standard. The new standard requires assets and liabilities acquired in a business combination and contingent consideration to be measured at fair value as at the date of the acquisition. Acquisition costs that are currently capitalized as part of the purchase price will be recognized in the consolidated statement of income. The adoption of this standard will impact the accounting treatment of future business combinations. (b) CICA Handbook Section 1601 "Consolidated Financial Statements" and Section 1602 "Non-controlling Interests" will replace the former consolidated financial statements standard. These standards establish the requirements for the preparation of consolidated financial statements and the accounting for a non-controlling interest (previously referred to as minority interest) in a subsidiary. The new standard requires non-controlling interest to be presented as a separate component of equity and requires net income and other comprehensive income to be attributed to both the parent and non-controlling interest. The adoption of this standard is not expected to have a material impact on the Company's consolidated financial statements. 2. 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. 3. Capital Stock Authorized Unlimited common shares Unlimited preferred shares, issuable in series Outstanding Number of Common Shares Amount --------------------------------------------------------------------- Balance at January 1, 2009 153,135,006 $ 169,485 Issued under employee stock option plan 14,500 232 --------------------------------------------------------------------- Balance at June 30, 2009 153,149,506 $ 169,717 --------------------------------------------------------------------- Options A summary of the status of the Company's stock option plan as of June 30, 2009, and the changes during the six-month period then ended, is presented below: Weighted Average Number of Exercise Options Price --------------------------------------------------------------------- Outstanding at January 1, 2009 10,445,962 $ 18.09 Granted 11,000 11.33 Exercised for shares (14,500) (10.50) Exercised for cash (939,600) (10.68) Forfeited (117,600) (21.45) --------------------------------------------------------------------- Outstanding at June 30, 2009 9,385,262 $ 18.79 --------------------------------------------------------------------- Exercisable at June 30, 2009 3,884,162 $ 16.46 --------------------------------------------------------------------- Options Outstanding Options Exercisable --------------------------------------------------------------------- Average Weighted Weighted Vesting Average Options Average Options Remaining Exercise Exercis- Exercise Exercise Price Outstanding (in years) Price able Price --------------------------------------------------------------------- $9.45 to $11.33 1,125,762 0.09 $ 10.51 1,052,362 $ 10.50 $13.50 to $18.85 1,822,900 0.86 14.16 1,179,000 13.81 $19.88 to $23.33 6,436,600 2.04 21.56 1,652,800 22.15 --------------------------------------------------------------------- 9,385,262 1.58 $ 18.79 3,884,162 $ 16.46 --------------------------------------------------------------------- Common share dividends During the six months ended June 30, 2009, the Company declared dividends of $26,034 (2008 - $25,257), being $0.170 per common share (2008 - $0.165 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 six months ended June 30, 2009 and 2008 are as follows: 2009 2008 ------------- ------------- Weighted average number of common shares outstanding - basic 153,139,715 153,063,904 Weighted average number of common shares outstanding - diluted 153,383,401 154,669,014 ------------- ------------- Stock options of 8,259,500 (2008 - 6,876,500) 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. 4. 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 June 30, 2009 --------------------------------------------------------------------- United Inter- Canada States national Total --------------------------------------------------------------------- Revenue $ 52,108 $ 94,617 $ 79,285 $ 226,010 Property and equipment, net $ 811,296 $ 518,001 $ 362,470 $ 1,691,767 Capital expenditures, net $ 164 $ 24,126 $ 2,398 $ 26,688 Depreciation $ 9,426 $ 7,607 $ 5,821 $ 22,854 --------------------------------------------------------------------- Three months ended June 30, 2008 --------------------------------------------------------------------- United Inter- Canada States national Total --------------------------------------------------------------------- Revenue $ 108,378 $ 152,825 $ 76,571 $ 337,774 Property and equipment, net $ 780,034 $ 365,890 $ 351,201 $ 1,497,125 Capital expenditures, net $ 3,752 $ 18,202 $ 23,025 $ 44,979 Depreciation $ 12,854 $ 7,270 $ 7,341 $ 27,465 --------------------------------------------------------------------- Six months ended June 30, 2009 --------------------------------------------------------------------- United Inter- Canada States national Total --------------------------------------------------------------------- Revenue $ 233,222 $ 222,321 $ 170,887 $ 626,430 Property and equipment, net $ 811,296 $ 518,001 $ 362,470 $ 1,691,767 Capital expenditures, net $ 1,211 $ 46,029 $ 25,542 $ 72,782 Depreciation $ 23,836 $ 16,607 $ 11,351 $ 51,794 --------------------------------------------------------------------- Six months ended June 30, 2008 --------------------------------------------------------------------- United Inter- Canada States national Total --------------------------------------------------------------------- Revenue $ 368,828 $ 292,140 $ 148,990 $ 809,958 Property and equipment, net $ 780,034 $ 365,890 $ 351,201 $ 1,497,125 Capital expenditures, net $ 5,509 $ 29,180 $ 43,834 $ 78,523 Depreciation $ 27,828 $ 13,926 $ 13,964 $ 55,718 --------------------------------------------------------------------- 5. Supplemental disclosure of cash flow information The net change in non-cash working capital for the three and six months ended June 30, 2009 and 2008 is determined as follows: Three months ended Six months ended June 30 June 30 --------------------------------------------------- 2009 2008 2009 2008 --------------------------------------------------- Net change in non-cash working capital Accounts receivable $ 145,533 $ 98,435 $ 169,504 $ 18,224 Inventory and other 176 (1,451) 838 (2,225) Accounts payable and accrued liabilities (57,454) (16,505) (101,895) (15,127) Income taxes payable (22,942) (35,190) 14,630 (29,713) Dividends payable 2 1 2 6 --------------------------------------------------- $ 65,315 $ 45,290 $ 83,079 $ (28,835) --------------------------------------------------- Relating to Operating activities $ 104,008 $ 47,295 $ 101,942 $ (23,586) Investing activities (38,695) (2,006) (18,865) (5,255) Financing activities 2 1 2 6 --------------------------------------------------- $ 65,315 $ 45,290 $ 83,079 $ (28,835) --------------------------------------------------- 6. 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 |