Ensign Energy Services Inc. - 2007 Third Quarter Earnings2007-11-05 CALGARY, Nov. 5 /CNW/ - Overview Ensign Energy Services Inc. (the "Company") reports net income of $49.7 million ($0.33 per common share) for the third quarter of 2007, a decrease of $53.1 million or 52 percent from net income of $102.9 million ($0.68 per common share) recorded in the third quarter of 2006. EBITDA (as defined below) for the three months ended September 30, 2007 totaled $103.5 million ($0.68 per common share) compared with EBITDA of $159.5 million ($1.05 per common share) in the three months ended September 30, 2006, a decline of 35 percent. Net income of $177.2 million ($1.16 per common share) for the nine months ended September 30, 2007 compares with net income of $277.3 million ($1.83 per common share) recorded in the nine months ended September 30, 2006, a decrease of 36 percent. EBITDA for the nine months ended September 30, 2007 totaled $359.6 million ($2.36 per common share), a decrease of 24 percent from EBITDA of $471.1 million ($3.11 per common share) in the first three quarters of 2006. The decline in financial results in the third quarter of 2007 and the nine months ended September 30, 2007 is primarily the result of declining contributions from the Company's Canadian oilfield services division. Weaker demand for oilfield services throughout the Western Canada Sedimentary Basin ("WCSB"), combined with an over-supply of equipment, negatively impacted equipment utilization and operating margins in 2007 compared to the record levels of 2006. The Company's expansion of its United States operations and the stable returns generated by its international oilfield services division partially mitigated the challenging operating environment experienced in Canada in the first nine months of 2007. ------------------------------------------------------------------------- FINANCIAL AND OPERATING HIGHLIGHTS ($ thousands, except per share data and operating information) ------------------------------------------------------------------------- Three months ended Nine months ended September 30 September 30 ------------------------------------------------------------------------- 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Revenue 383,316 459,778 (17) 1,189,340 1,385,322 (14) ------------------------------------------------------------------------- EBITDA(1) 103,519 159,464 (35) 359,624 471,140 (24) EBITDA per share(1) Basic $0.68 $1.05 (35) $2.36 $3.11 (24) Diluted $0.67 $1.02 (34) $2.31 $3.00 (23) ------------------------------------------------------------------------- Adjusted net income(2) 50,157 88,279 (43) 182,227 271,197 (33) Adjusted net income per share(2) Basic $0.33 $0.58 (43) $1.20 $1.79 (33) Diluted $0.32 $0.56 (43) $1.17 $1.73 (32) ------------------------------------------------------------------------- Net income 49,748 102,850 (52) 177,204 277,346 (36) Net income per share Basic $0.33 $0.68 (51) $1.16 $1.83 (37) Diluted $0.32 $0.66 (52) $1.14 $1.77 (36) ------------------------------------------------------------------------- Funds from operations(3) 53,257 99,653 (47) 210,743 310,594 (32) Funds from operations per share(3) Basic $0.35 $0.66 (47) $1.38 $2.05 (33) Diluted $0.34 $0.64 (47) $1.35 $1.98 (32) ------------------------------------------------------------------------- Weighted average shares - basic (000s) 152,516 151,786 - 152,456 151,708 - Weighted average shares - diluted (000s) 155,513 156,800 (1) 155,534 156,913 (1) ------------------------------------------------------------------------- Drilling Number of marketed rigs Canada Conven- tional 162 162 - 162 162 - Oil sands coring/ coal-bed methane 31 21 48 31 21 48 United States 74 65 14 74 65 14 Interna- tional(4) 49 47 4 49 47 4 Operating days Canada 5,760 8,861 (35) 18,108 25,896 (30) United States 5,118 4,735 8 14,271 13,714 4 Interna- tional 2,274 2,138 6 6,929 6,698 3 ------------------------------------------------------------------------- Well Servicing Number of marketed rigs/units Canada 115 116 (1) 115 116 (1) United States 12 8 50 12 8 50 Operating hours Canada 39,674 49,378 (20) 129,899 158,942 (18) United States 7,035 5,505 28 19,421 16,214 20 ------------------------------------------------------------------------- (1) EBITDA is defined as "income before interest expense, income taxes, depreciation and stock-based compensation expense". Management believes that in addition to net income, EBITDA and EBITDA per share are useful supplemental measures as they provide an indication of the results generated by the Company's principal business activities prior to consideration of how these activities are financed, how the results are taxed in various jurisdictions or how the results are impacted by the accounting standards associated with the Company's stock-based compensation plans. EBITDA and EBITDA per share as defined above are not recognized measures under Canadian generally accepted accounting principles and accordingly may not be comparable to measures used by other companies. (2) Adjusted net income is defined as "net income before stock-based compensation expense, tax-effected using an income tax rate of 35%". Adjusted net income and adjusted net income per share are useful supplemental measures as they provide an indication of the results generated by the Company's principal business activities prior to consideration of how the results are impacted by the accounting standards associated with the Company's stock-based compensation plans, net of income taxes. Adjusted net income and adjusted net income per share as defined above are not recognized measures under Canadian generally accepted accounting principles and accordingly may not be comparable to measures used by other companies. (3) Funds from operations is defined as "cash provided by operating activities before the change in non-cash working capital". Funds from operations and funds from operations per share are measures that provide shareholders and potential investors with additional information regarding the Company's liquidity and its ability to generate funds to finance its operations. Management utilizes these measures to assess the Company's ability to finance operating activities and capital expenditures. Funds from operations and funds from operations per share are not measures that have any standardized meaning prescribed by Canadian generally accepted accounting principles and accordingly may not be comparable to similar measures used by other companies. (4) Includes workover rigs. Revenue and Oilfield Services Expense Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Revenue Canada 169,726 271,124 (37) 592,884 843,061 (30) United States 149,108 132,988 12 416,739 377,563 10 Interna- tional 64,482 55,666 16 179,717 164,698 9 ---------------------------------------------------------- 383,316 459,778 (17) 1,189,340 1,385,322 (14) Oilfield services expense 268,270 288,678 (7) 791,151 877,231 (10) ---------------------------------------------------------- 115,046 171,100 (33) 398,189 508,091 (22) ---------------------------------------------------------- Gross margin 30.0% 37.2% 33.5% 36.7% ------------------------------------------------------------------------- The Company's Canadian oilfield services division faced an increasingly competitive market in the first nine months of 2007. Although the Company maintains a strong presence in key crude oil regions of the WCSB and offers a diverse range of services, the majority of exploration and development activity in western Canada remains focused on natural gas. Lower natural gas commodity prices persisted throughout the first three quarters of 2007, resulting in a decrease in drilling and well servicing demand. The reduction in the number of natural gas wells being drilled in Western Canada comes at a time of a significant increase in industry-wide capacity, compounding the impact to utilization and pricing. These factors contributed to the decline in revenue generated by the Company's Canadian oilfield services division, which decreased 37 percent and 30 percent in the third quarter of 2007 and nine- month period ended September 30, 2007, respectively, compared with the corresponding periods of 2006. The Company's gradual expansion of its United States operations has successfully diversified its operations geographically, providing growth in revenue and operating activity levels during periods of declining demand in Canada. On a year-to-date basis, revenue generated by the Company's United States oilfield services division now accounts for 35 percent of consolidated revenue compared with 27 percent one year ago. Revenue generated by the United States oilfield services division in the third quarter of 2007 totaled $149.1 million compared with $133.0 million in the third quarter of 2006, an increase of 12 percent. For the nine months ended September 30, 2007, revenue of $416.7 million compares with revenue of $377.6 million for the nine months ended September 30, 2006, an increase of 10 percent. The improved financial contributions are largely the result of the successful deployment of the Company's proprietary Automated Drill Rig ("ADR(TM)") technology to that market. During the first three quarters of 2007, a total of 11 ADRs were added to the equipment fleet in the United States, with an additional two ADRs scheduled to commence operations in the fourth quarter of 2007. Revenue generated by the Company's international oilfield services division totaled $64.5 million for the three months ended September 30, 2007 compared with $55.7 million for the three months ended September 30, 2006, an increase of 16 percent. For the nine months ended September 30, 2007, revenue increased nine percent to $179.7 million compared with revenue of $164.7 million recorded in the nine months ended September 30, 2006. The Company continuously assesses growth opportunities around the globe and relocates equipment accordingly. During 2007, the Company relocated two drilling rigs from Canada to Australia where they will operate under long-term contracts. During the third quarter of 2007, one of these drilling rigs commenced operations while the second will be introduced into service in the fourth quarter of 2007. The Company is nearing completion of the construction of two drilling rigs for operations in the Middle East, with delivery anticipated in the fourth quarter of 2007. The upgrade and reactivation of one drilling rig in Africa is in progress and is expected to be complete in the first quarter of 2008. Oilfield services expense totaled $268.3 million in the three months ended September 30, 2007, a decline of seven percent compared with the third quarter of 2006. For the nine months ended September 30, 2007, oilfield services expense declined 10 percent to $791.2 million compared with the nine months ended September 30, 2006. The decline in oilfield services expense is due to a decline in consolidated operating activity levels on a period-over- period basis, partially offset by an increase in labour and material costs. Gross margin was 30.0 percent for third quarter of 2007 compared with 37.2 percent for the third quarter of 2006. On a year-to-date basis, gross margin was 33.5 percent in 2007 compared with 36.7 percent in 2006. The weakening Canadian market and the resultant lower pricing is the largest factor contributing to the decline in gross margin on a period-over-period basis. Depreciation Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Depreciation 22,028 22,309 (1) 64,938 62,317 4 ------------------------------------------------------------------------- Depreciation expense totaled $22.0 million for the third quarter of 2007 compared with $22.3 million for the third quarter of 2006. For the nine months ended September 30, 2007, depreciation expense totaled $64.9 million compared with $62.3 million for the nine months ended September 30, 2006. Depreciation expense is calculated on a unit-of-production basis for rigs and related equipment. Throughout the first nine months of 2007, a higher cost base of equipment in operation offset the impact of lower equipment utilization rates on depreciation expense. Depreciation expense per operating day increased in 2007 as the Company introduced newly constructed and higher valued assets to its equipment fleet. General and Administrative Expense Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- General and administrative 11,527 11,636 (1) 38,565 36,951 4 % of revenue 3.0% 2.5% 3.2% 2.7% ------------------------------------------------------------------------- As a percentage of revenue, general and administrative expense for the third quarter of 2007 was 3.0 percent compared with 2.5 percent for the third quarter of 2006. On a year-to-date basis, general and administrative expense as a percentage of revenue is 3.2 percent in 2007 compared with 2.7 percent in 2006. Costs contributing to general and administrative expense are relatively fixed and, as a result, general and administrative expense as a percentage of revenue will increase during periods of declining revenue levels. On a gross dollar basis, general and administrative expense for both the quarter and nine months ended September 30, 2007 is comparable to the prior periods. Stock-Based Compensation Expense Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Stock-based compensation 630 (22,417) (103) 7,728 (9,460) (182) ------------------------------------------------------------------------- Stock-based compensation expense arises from the intrinsic value accounting of the Company's stock option plan, whereby the liability associated with stock-based compensation is adjusted on a quarterly basis for the effect of vesting of stock options and changes in the underlying price of the Company's common shares. Stock-based compensation expense for the third quarter of 2007 is comprised of $1.7 million for additional vesting of stock options (net of forfeitures), net of a $1.1 million decrease associated with a decline in the price of the Company's common shares. For the nine-month period ended September 30, 2007, stock-based compensation expense is comprised of $5.3 million for additional granting and vesting of stock options, $4.3 million related to the increase in the price of the Company's common shares, and a recovery of $1.9 million due to forfeitures during the period. The price of the Company's common shares was $18.78 at September 30, 2007 compared with $19.00 at June 30, 2007 and $18.39 at December 31, 2006. The significant recovery of stock-based compensation expense in the three months and nine months ended September 30, 2006 is primarily the result of decreases in the price of the Company's common shares during these periods. Share price declines of $4.39 and $4.91 were experienced in the third quarter of 2006 and in the nine months ended September 30, 2006, respectively. Interest Expense Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Interest 1,190 1,213 (2) 4,095 3,950 4 ------------------------------------------------------------------------- Interest expense is incurred on the Company's operating lines of credit. Interest expense totaled $1.2 million for the third quarter of 2007 and $4.1 million for the nine months ended September 30, 2007, both of which are comparable to the corresponding periods of 2006. Income Taxes Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Current income tax 48,944 53,635 (9) 130,776 125,200 4 Future income tax (19,021) 1,874 (1,115) (25,117) 11,787 (313) --------------------------------------------------------- 29,923 55,509 (46) 105,659 136,987 (23) --------------------------------------------------------- Effective income tax rate (%) 37.6% 35.1% 37.4% 33.1% ------------------------------------------------------------------------- The effective income tax rate for the third quarter of 2007 was 37.6 percent compared with 35.1 percent in the third quarter of 2006. For the nine months ended September 30, 2007, the effective income tax rate was 37.4 percent compared with 33.1 percent in the nine months ended September 30, 2006. The increase in the Company's effective income tax rate on a year-over- year basis is partially due to the recognition of substantively enacted income tax rate reductions in Canada in the second quarter of 2006. During the second quarter of 2006, a one-time reduction in the Company's opening future income tax liability of $11.5 million was recognized. Current income tax expense for the nine months ended September 30, 2007 includes $4.0 million related to Omani tax assessments. As previously disclosed, the Company's Oman operating entity was appealing income tax assessments received for the 1994, 1995 and 1996 financial years. The Company was appealing these assessments; however, the Company's appeal was dismissed during the second quarter of 2007. 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 future income tax recovery in 2007 is due to partnership timing differences and an income tax rate reduction in Canada. Taxable income generated by Canadian partnerships was a significant component of the future income tax liability as at December 31, 2006. This balance declined as of September 30, 2007 due to the decline in income generated by Canadian partnerships. Also, a further income tax rate reduction in Canada of 0.5 percent was enacted in the second quarter of 2007. The application of this rate reduction on opening future income tax balances resulted in a one-time reduction in the Company's opening future income tax liability of $2.2 million. Financial Position The following chart outlines significant changes in the consolidated balance sheets from December 31, 2006 to September 30, 2007: ($ thousands) Change Explanation ------------------------------------------------------------------------- Cash and cash 731 See consolidated statement of cash flows. equivalents Accounts receivable (82,681) Decrease due to the reduction in operating activity within the Canadian oilfield services division. Inventory and other 7,726 Increase due to additions to drill pipe inventory. Property and 87,379 Increase due to ongoing capital equipment expenditures and equipment under construction, offset by depreciation for the period. Accounts payable (58,481) Decrease due to the reduction in operating and accrued activity within the Canadian oilfield liabilities services division. Operating lines 42,375 Increase in utilization of the available of credit United States and Australian-based operating lines of credit, net of repayments in Canada during the period Stock-based (9,412) Decrease due to stock option exercises, compensation net of the increase associated with additional vesting and share price increases. Income taxes (10,292) Decrease due to income tax payments, net payable of the current income tax provision for the period. Dividends payable 47 Increase due to a slight increase in the number of outstanding common shares compared with the fourth quarter of 2006. Future income (27,773) Decrease due to the future income tax taxes recovery in the period and an income tax rate reduction in Canada. Shareholders' 76,691 Increase due to the aggregate impact of equity net 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, net of dividends declared in the period. ------------------------------------------------------------------------- Working Capital and Funds from Operations Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Funds from operations 53,257 99,653 (47) 210,743 310,594 (32) Funds from operations per share $0.35 $0.66 (47) $1.38 $2.05 (33) Working capital(1) 16,558 63,162 (74) 16,558 63,162 (74) ------------------------------------------------------------------------- (1) Comparative figures as of December 31, 2006. During the three months ended September 30, 2007, the Company generated funds from operations of $53.3 million ($0.35 per common share) compared with funds from operations of $99.7 million ($0.66 per common share) for the three months ended September 30, 2006, a decline of 47 percent. Funds from operations totaled $210.7 million ($1.38 per common share) in the first nine months of 2007, a decline of 32 percent from funds from operations of $310.6 million ($2.05 per common share) generated in the nine months ended September 30, 2006. The decline from the record levels of funds from operations generated in 2006 is predominantly due to a reduction in operating activity and compressed margins in the Company's Canadian oilfield services division on a period-over-period basis. Compared to the corresponding periods of 2006, reduced oilfield services activity in Canada in both the third quarter of 2007 and the nine months ended September 30, 2007 was partially offset by increased contributions from the Company's United States oilfield services division. The Company had a positive working capital position of $16.6 million at September 30, 2007 compared with working capital of $63.2 million at December 31, 2006. The decline in working capital is largely due to an increase in the utilized balance of the Company's United States and international operating lines of credit, which are supporting capital expenditure initiatives in those segments. As of September 30, 2007, the Company continues to operate with no long- term debt. The Company's strong balance sheet positions the Company to weather the downturn in the Canadian market, as well as provides the financial strength to pursue potential growth opportunities as they may arise. Investing Activities Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Net purchase of property and equipment (62,850) (74,716) (16) (223,967) (239,821) (7) Net change in non-cash working capital 12,183 (13,296) (192) (14,218) (14,342) (1) --------------------------------------------------------- Cash used in investing activities (50,667) (88,012) (42) (238,185) (254,163) (6) ------------------------------------------------------------------------- A substantial portion of the Company's 2007 capital expenditure program was directed toward expansion of its equipment fleet in the United States. During the nine months ended September 30, 2007, construction of 11 ADRs was completed within the United States, including three within the third quarter of 2007. An additional two ADRs were completed subsequent to September 30, 2007, with one being introduced into service in October 2007 and the second in early November 2007. The delivery of these additional ADRs in the fourth quarter of 2007 completes the Company's 2007 13-ADR(TM)-build program. Capital expenditure activity within Canada in the third quarter of 2007 included the addition of two newly constructed slant well servicing rigs. Other capital expenditures completed by the Company in the first nine months of 2007 include the addition of one triple drilling rig to its fleet of equipment in southeastern Saskatchewan in the second quarter of 2007, a double drilling rig slated for operations in northeastern British Columbia and nine oilsands coring rigs in the first quarter of 2007. The Canadian oilfield services division also recently completed the construction of a new ADR(TM), which will commence operations in the fourth quarter of 2007 under a long-term contract in northern Alberta. Within the international arena, the Company is currently refurbishing two drilling rigs for operations in the Middle East and reactivating one previously idle drilling rig for operations in Libya. Other equipment movements during 2007 include the transfer of two drilling rigs from the Canadian fleet of equipment to Australia, where they will both operate under long-term contracts. One well servicing rig was also transferred from Canada to the Rocky Mountain region of the United States. These movements demonstrate the Company's ability to leverage its established operational bases around the globe and to relocate idle equipment to areas of higher demand. Financing Activities Three months ended Nine months ended September 30 September 30 --------------------------------------------------------- ($ thousands) 2007 2006 % change 2007 2006 % change ------------------------------------------------------------------------- Net increase (decrease) in operating lines of credit 48,243 10,826 346 42,375 (71,120) (160) Issue of capital stock 276 422 (35) 1,942 2,933 (34) Dividends (12,202) (11,386) 7 (36,591) (30,350) 21 Net change in non-cash working capital 1 5 (80) 47 3,820 (99) --------------------------------------------------------- Cash provided by (used in) financing activities 36,318 (133) (27,407) 7,773 (94,717) (108) ------------------------------------------------------------------------- The Company increased the utilized balance of its operating lines of credit during both the three months and nine months ended September 30, 2007. Net repayments made by the Company's Canadian oilfield services division were offset by increases in the United States and Australian-based operating lines of credit. During the first quarter of 2007, the Company amended the terms of its United States-based operating line of credit and increased the amount available to US$50.0 million. The increased credit facility is being used to finance the Company's new build projects and support its expanded operations in the United States. The Company also temporarily increased its available Australia-based facility by AUD$22.2 million in the third quarter of 2007 to finance the three additional drilling rigs being prepared for long-term contracts in the international market. Other financing activities during the third quarter of 2007 include the receipt of $0.3 million on the exercise of employee stock options and the payment of dividends in the amount of $12.2 million. Dividends were declared at a quarterly dividend rate of $0.08 per common share for the three months ended September 30, 2007, an increase of seven percent over the third quarter of 2006. For the nine months ended September 30, 2007, cash received on employee stock option exercises totaled $1.9 million and dividends totaled $36.6 million. During the first nine months of 2007, the Company declared year- to-date dividends totaling $0.24 per common share compared with $0.20 during the first nine months of 2006. 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 Company also announces an increase of three percent in its regular quarterly dividend to $0.0825 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 $0.0825 to be payable on January 2, 2008 to all Common Shareholders of record as of December 20, 2007. 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. Outlook The third quarter financial results reflect the deteriorating market conditions in Canada, the growing positive impact of the Company's United States operations and continued steady improvement of the Company's international operations. The fundamentals around natural gas remain weak as North American storage levels are at peak levels heading into the winter heating season. The Canadian market has been especially hard hit as operators have experienced reduced economic returns due to relatively low commodity price levels for natural gas and a stronger Canadian dollar. Such reduced economics have resulted in reduced levels of demand for oilfield services at a time when the oilfield services industry's fleet of equipment has reached record levels. There is currently too much equipment chasing a reduced number of jobs. Accordingly, the deterioration of day rates experienced in the latter part of the third quarter has continued into the fourth quarter. As if basic supply and demand fundamentals were not enough, the government of the Province of Alberta chose to conduct a royalty review thereby adding another layer of uncertainty onto an already uncertain market. The government of Alberta announced proposed changes to the royalty rate structure on October 25, 2007. These proposed changes have been deemed by some to be a reasonable compromise between the status quo and the proposals of a royalty review panel commissioned by the government of Alberta. Only time will tell the ultimate impact of the royalty changes on each sub-sector of the oil and natural gas industry within Alberta. Unfortunately for the Company, the damage in the near-term has been done as many customers have reduced planned expenditures in Alberta for the upcoming winter drilling season due to reduced economics and uncertainty around the impact of the new royalty regime. Accordingly, utilization and margins will be negatively impacted until such time as natural gas commodity prices improve to a level that is attractive for more investment by the Company's customers in western Canada, particularly those affected by Alberta's new royalty environment. The challenges facing the Company and the Canadian industry are summarized in the Canadian Association of Oilwell Drilling Contractors forecast for 13,735 wells to be drilled in western Canada in 2008, for an average drilling rig utilization of 35 percent for the year, numbers not seen since 2002 when the drilling rig fleet was substantially smaller. Partially offsetting the expected weakness in the Canadian market is the Company's growing presence in the United States and international markets. The United States operations are subject to similar natural gas fundamentals that are challenging the Canadian market, but to this point operators appear to be committed to continuing with the unconventional plays that underscore the increased level of activity in the Rocky Mountain region. However, another mild winter and high season-ending natural gas storage levels could result in reduced levels of demand in the United States in the second half of 2008 if operators choose to adjust their programs following the winter season. The California market, which is largely crude oil based, is expected to continue at a steady level of activity. The international market segment is also primarily driven by crude oil pricing levels, which are currently at historical highs. Further, the international market is experiencing increased demand for oilfield services in support of increased development of the liquid natural gas (LNG) sector. Accordingly, the Company continues to experience continued improvements in its international operations. The Company continues to face many challenges in its operations, mainly within Canada at this time. The Company has the people, the experience, the quality equipment fleet (including the advanced technology of our growing ADR(TM) drilling fleet), the geographic diversification and the financial strength and discipline that give it an advantage over many of its competitors. The next year will be full of challenges and opportunities, which the Company is well positioned to meet head on. 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 third quarter results at 2:00 p.m. MST (4:00 p.m. EST) on Monday, November 5, 2007. The conference call number is 1-800-733-7571. A taped recording will be available until November 12, 2007 by dialing 1-877-289-8525 and entering reservation number 21252523 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 September 30, 2007 and December 31, 2006 (Unaudited, in thousands of dollars) September 30 December 31 2007 2006 ---- ---- Assets Current assets Cash and cash equivalents 15,301 14,570 Accounts receivable 282,394 365,075 Inventory and other 84,954 77,228 Future income taxes 10,418 11,010 ------------------------------ 393,067 467,883 Property and equipment 1,381,645 1,294,266 ------------------------------ 1,774,712 1,762,149 ------------------------------ ------------------------------ Liabilities Current liabilities Accounts payable and accrued liabilities 183,495 241,976 Operating lines of credit 112,364 69,989 Current portion of stock-based compensation 31,957 33,818 Income taxes payable 36,491 46,783 Dividends payable 12,202 12,155 ------------------------------ 376,509 404,721 Stock-based compensation 10,448 17,999 Future income taxes 203,459 231,824 ------------------------------ 590,416 654,544 ------------------------------ Shareholders' Equity Capital stock (note 2) 159,910 154,838 Accumulated other comprehensive income (note 1) (89,871) (20,163) Retained earnings 1,114,257 972,930 ------------------------------ Contingencies and commitments (note 5) 1,184,296 1,107,605 ------------------------------ 1,774,712 1,762,149 ------------------------------ ------------------------------ See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF INCOME AND RETAINED EARNINGS (Unaudited - in thousands of dollars, except per share data) Three months ended Nine months ended September 30 September 30 2007 2006 2007 2006 ---- ---- ---- ---- Revenue Oilfield services 383,316 459,778 1,189,340 1,385,322 Expenses Oilfield services 268,270 288,678 791,151 877,231 Depreciation 22,028 22,309 64,938 62,317 General and administrative 11,527 11,636 38,565 36,951 Stock-based compensation 630 (22,417) 7,728 (9,460) Interest 1,190 1,213 4,095 3,950 ------------------------------------------------- 303,645 301,419 906,477 970,989 ------------------------------------------------- Income before income taxes 79,671 158,359 282,863 414,333 Income taxes Current (note 5) 48,944 53,635 130,776 125,200 Future (19,021) 1,874 (25,117) 11,787 ------------------------------------------------- 29,923 55,509 105,659 136,987 ------------------------------------------------- Net income for the period 49,748 102,850 177,204 277,346 Retained earnings - beginning of period, as originally reported 1,076,711 829,683 972,930 674,151 Transition adjustment on adoption of financial instruments standard (note 1) - - 714 - ------------------------------------------------- Retained earnings - beginning of period, as restated 1,076,711 829,683 973,644 674,151 Dividends (note 2) (12,202) (11,386) (36,591) (30,350) ------------------------------------------------- Retained earnings - end of period 1,114,257 921,147 1,114,257 921,147 ------------------------------------------------- ------------------------------------------------- Net income per share (note 2) Basic $ 0.33 $ 0.68 $ 1.16 $1.83 Diluted $ 0.32 $ 0.66 $ 1.14 $1.77 ------------------------------------------------- ------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited - in thousands of dollars) Three months ended Nine months ended September 30 September 30 2007 2006 2007 2006 ---- ---- ---- ---- Cash provided by (used in) Operating activities Net income for the period 49,748 102,850 177,204 277,346 Items not affecting cash: Depreciation 22,028 22,309 64,938 62,317 Stock-based compensation, net of cash paid 502 (27,380) (6,282) (40,856) Future income taxes (19,021) 1,874 (25,117) 11,787 ------------------------------------------------- Cash provided by operating activities before the change in non-cash working capital 53,257 99,653 210,743 310,594 Net change in non-cash working capital (note 4) (33,538) (13,593) 20,400 27,233 ------------------------------------------------- 19,719 86,060 231,143 337,827 ------------------------------------------------- Investing activities Net purchase of property and equipment (62,850) (74,716) (223,967) (239,821) Net change in non-cash working capital (note 4) 12,183 (13,296) (14,218) (14,342) ------------------------------------------------- (50,667) (88,012) (238,185) (254,163) ------------------------------------------------- Financing activities Net increase (decrease) in operating lines of credit 48,243 10,826 42,375 (71,120) Issue of capital stock 276 422 1,942 2,933 Dividends (note 2) (12,202) (11,386) (36,591) (30,350) Net change in non-cash working capital (note 4) 1 5 47 3,820 ------------------------------------------------- 36,318 (133) 7,773 (94,717) ------------------------------------------------- Increase (decrease) in cash and cash equivalents during the period 5,370 (2,085) 731 (11,053) Cash and cash equivalents - beginning of period 9,931 23,025 14,570 31,993 ------------------------------------------------- Cash and cash equivalents - end of period 15,301 20,940 15,301 20,940 ------------------------------------------------- ------------------------------------------------- Supplemental information Interest paid 1,485 1,191 3,812 4,289 Income taxes paid 37,145 26,595 141,068 86,880 ------------------------------------------------- ------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited - in thousands of dollars) Three months ended Nine months ended September 30 September 30 2007 2006 2007 2006 ---- ---- ---- ---- Net income for the period 49,748 102,850 177,204 277,346 Other comprehensive income Foreign currency translation adjustment (31,357) 1,816 (69,708) (16,749) ------------------------------------------------- Comprehensive income 18,391 104,666 107,496 260,597 ------------------------------------------------- ------------------------------------------------- See accompanying notes to the consolidated financial statements. CONSOLIDATED STATEMENTS OF ACCUMULATED OTHER COMPREHENSIVE INCOME (Unaudited - in thousands of dollars) Three months ended Nine months ended September 30 September 30 2007 2006 2007 2006 ---- ---- ---- ---- Accumulated other comprehensive income - beginning of period (58,514) (57,786) (20,163) (39,221) Foreign currency translation adjustment (31,357) 1,816 (69,708) (16,749) ------------------------------------------------- Accumulated other comprehensive income - end of period (89,871) (55,970) (89,871) (55,970) ------------------------------------------------- ------------------------------------------------- See accompanying notes to the consolidated financial statements. NOTES TO THE CONSOLIDATED FINANCIAL STATEMENTS For the nine months ended September 30, 2007 and 2006 (Unaudited - in thousands of dollars, except per share data) The interim consolidated financial statements have been prepared in accordance with Canadian generally accepted accounting principles, and include the accounts of Ensign Energy Services Inc. and all of 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, 2006, 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, 2006. 1. Change in accounting policies Effective January 1, 2007, the Company adopted the Canadian Institute of Chartered Accountants Handbook Section 1530 "Comprehensive Income", Section 3251 "Equity" and Section 3855 "Financial Instruments - Recognition and Measurement". As required by the new standards, prior periods have not been restated except to reclassify the cumulative translation adjustment balance. Comprehensive income The new standards introduce comprehensive income, which consists of net income and other comprehensive income ("OCI"). For the Company, OCI is comprised entirely of the movement in the cumulative translation adjustment balance. The Company's consolidated financial statements now include Consolidated Statements of Comprehensive Income, which outline the components of comprehensive income. The cumulative changes in OCI are included in accumulated other comprehensive income ("AOCI"), which is presented as a new category within shareholders' equity in the Consolidated Balance Sheets. The cumulative translation adjustment, formerly presented as a separate category within shareholders' equity, is now included in AOCI. The Company's consolidated financial statements now include Consolidated Statements of Accumulated Other Comprehensive Income, which provide the continuity of the AOCI balance. Financial instruments The financial instruments standard establishes the recognition and measurement criteria for financial assets and financial liabilities. All financial instruments are required to be measured at fair value on initial recognition of the instrument. Measurement in subsequent periods depends on how the financial instruments have been classified in accordance with the standard. The adjustment to recognize financial instruments at fair value on the balance sheet was recorded as an adjustment to the opening balance of retained earnings. 2. Capital stock Authorized Unlimited common shares Unlimited preferred shares, issuable in series Outstanding Number of Common Shares Amount --------------------------------------------------------------------- Balance at January 1, 2007 152,267,928 $ 154,838 Issued under employee stock option plan 262,550 5,072 ------------------------------ Balance at September 30, 2007 152,530,478 $ 159,910 --------------------------------------------------------------------- Options A summary of the status of the Company's stock option plan as of September 30, 2007, and the changes during the nine-month period then ended, is presented below: Weighted Average Number of Exercise Options Price --------------------------------------------------------------------- Outstanding at January 1, 2007 11,112,100 $ 13.16 Granted 2,515,000 19.83 Exercised for common shares (262,550) (7.40) Exercised for cash (1,271,000) (7.97) Forfeited (642,800) (16.44) --------------------------------------------------------------------- Outstanding at September 30, 2007 11,450,750 $ 15.08 --------------------------------------------------------------------- Exercisable at September 30, 2007 4,260,450 $ 10.86 --------------------------------------------------------------------- Options Outstanding Options Exercisable --------------------------------------------------------------------- Average Weighted Weighted Options Vesting Average Options Average Exercise Outstan- Remaining Exercise Exercis- Exercise Price ding (in years) Price able Price --------------------------------------------------------------------- $6.25 to $8.75 1,893,750 0.11 $ 6.74 1,687,750 $ 6.49 $9.45 to $13.50 4,608,500 1.51 11.77 2,062,900 11.48 $16.55 to $23.33 4,948,500 3.37 21.36 509,800 22.83 ----------------------------------------------------- 11,450,750 2.08 $ 15.08 4,260,450 $ 10.86 --------------------------------------------------------------------- Common share dividends During the nine months ended September 30, 2007, the Company declared dividends of $36,591 (2006 - $30,350), being $0.24 per common share (2006 - $0.20 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 months ended September 30, 2007 and 2006 are as follows: 2007 2006 ------------------------------ Weighted average number of common shares outstanding - basic 152,455,715 151,707,915 Weighted average number of common shares outstanding - diluted 155,533,693 156,913,449 ------------------------------ Stock options of 4,806,000 (2006 - 2,769,500) 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. 3. 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: Nine months ended September 30, 2007 --------------------------------------------------------------------- United Inter- Canada States national Total --------------------------------------------------------------------- Revenue $592,884 $416,739 $179,717 $1,189,340 Property and equipment, net $815,320 $289,265 $277,060 $1,381,645 Capital expenditures, net $71,794 $105,685 $46,488 $223,967 Depreciation $34,255 $15,201 $15,482 $64,938 --------------------------------------------------------------------- Nine months ended September 30, 2006 --------------------------------------------------------------------- United Inter- Canada States national Total --------------------------------------------------------------------- Revenue $843,061 $377,563 $164,698 $1,385,322 Property and equipment, net $730,529 $220,797 $239,252 $1,190,578 Capital expenditures, net $131,096 $95,924 $12,801 $239,821 Depreciation $37,536 $10,572 $14,209 $62,317 --------------------------------------------------------------------- 4. Supplemental disclosure of cash flow information Three months Six months September 30 September 30 2007 2006 2007 2006 ---------------------------------------------- Net change in non-cash working capital Accounts receivable $(39,649) $(46,767) $82,681 $18,543 Inventory and other (1,026) (4,939) (7,726) (9,263) Accounts payable and accrued liabilities 7,521 (2,223) (58,481) (34,709) Income taxes payable 11,799 27,040 (10,292) 38,320 Dividends payable 1 5 47 3,820 ---------------------------------------------- $(21,354) $(26,884) $6,229 $16,711 ---------------------------------------------- ---------------------------------------------- Relating to Operating activities $(33,538) $(13,593) $20,400 $27,233 Investing activities 12,183 (13,296) (14,218) (14,342) Financing activities 1 5 47 3,820 ---------------------------------------------- $(21,354) $(26,884) $6,229 $16,711 ---------------------------------------------- ---------------------------------------------- 5. Contingencies and commitments The Company's Oman operating entity had previously received income tax assessments for the 1994, 1995 and 1996 financial years. The Company was appealing these assessments on the basis that they were without merit under Omani law; however, the Company's appeal was dismissed during the nine-month period ended September 30, 2007. Current income tax expense for the nine months ended September 30, 2007 includes $4,000 (2006: $nil) related to this matter. 6. Prior period amounts Certain prior year amounts have been reclassified to conform to the current year's presentation. For further information: Glenn Dagenais, Executive Vice President Finance and Chief Financial Officer, (403) 262-1361 |