Ensign Energy Services Inc. Reports 2012 Third Quarter Results

CALGARY, Nov. 12, 2012 /CNW/ -

Overview

Ensign Energy Services Inc. ("Ensign" or the "Company") recorded revenue for the third quarter of 2012 of $525.7 million, 10 percent higher than revenue of $475.7 million recorded in the third quarter of 2011.  Revenue for the nine months ended September 30, 2012 was $1,667.2 million, 27 percent higher than revenue of $1,312.4 million for the nine months ended September 30, 2011.  Net income for the third quarter of 2012 decreased 30 percent to $44.8 million ($0.29 per common share) compared to net income of $64.0 million ($0.42 per common share) for the third quarter of 2011.  Removing the large quarterly year-over-year swing in share-based compensation, adjusted net income for the third quarter was $47.2 million, a decrease of nine percent from adjusted net income of $52.1 million recorded in the third quarter of 2011.  Net income for the nine months ended September 30, 2012 increased six percent to $169.0 million ($1.11 per common share) compared to net income of $159.8 million ($1.05 per common share) for the first nine months of 2011.    EBITDA, defined as "income before interest, income taxes, depreciation, and share-based compensation expense (recovery)", totaled $135.6 million ($0.89 per common share) in the third quarter of 2012, 22 percent higher than EBITDA of $111.5 million ($0.73 per common share) in the third quarter of 2011.  For the first nine months of 2012, EBITDA was $431.3 million ($2.82 per common share), 24 percent higher than EBITDA of $346.9 million ($2.27 per common share) for the first nine months of 2011.  Funds from operations increased nine percent to $123.9 million ($0.81 per common share) in the third quarter of 2012 from $114.2 million ($0.75 per common share) in the third quarter of the prior year.  For the nine months ended September 30, 2012, funds from operations increased 14 percent to $383.4 million compared to $335.1 million for the nine months ended September 30, 2011.

Increases to the Company's credit facilities in 2012 resulted in an increase in available borrowings to $137.3 million as of September 30, 2012 compared with $10.1 million at December 31, 2011.  Long-term debt at September 30, 2012 was reduced to $293.2 million compared to $406.0 million at December 31, 2011 and consists of USD $300.0 million of senior unsecured notes, issued in February 2012.  The senior unsecured notes consist of: USD $100.0 million in five year notes with an interest rate of 3.43 percent; USD $100.0 million in seven year notes with an interest rate of 3.97 percent; and USD $100.0 million in ten year notes with an interest rate of 4.54 percent.  Proceeds from the issuance of the senior unsecured notes, along with the Company's credit facilities and funds generated from operations, were used to fully repay the USD $400.0 million term loan, incurred to finance the September 2011 acquisition of the land drilling division of Rowan Companies, Inc. ("Rowan Land Drilling", subsequently referred to as "Ensign US Southern"), in the first half of 2012.

FINANCIAL AND OPERATING HIGHLIGHTS

($ thousands, except per share data and operating information)

    Three months ended September 30          Nine months ended September 30
    2012   2011   % Change   2012   2011   % Change
Revenue   525,666   475,749   10   1,667,215   1,312,405   27
EBITDA 1   135,595   111,458   22   431,267   346,864   24
EBITDA per share 1                        
  Basic   $0.89   $0.73   22   $2.82   $2.27   24
  Diluted   $0.89   $0.73   22   $2.82   $2.26   25
Adjusted net income 2   47,210   52,087   (9)   167,371   158,728   5
Adjusted net income per share 2                        
  Basic   $0.31   $0.34   (9)   $1.10   $1.04   6
  Diluted   $0.31   $0.34   (9)   $1.09   $1.04   5
Net income   44,832   63,989   (30)   169,033   159,753   6
Net income per share                        
  Basic   $0.29   $0.42   (31)   $1.11   $1.05   6
  Diluted   $0.29   $0.42   (31)   $1.11   $1.04   7
Funds from operations 3   123,934   114,186   9   383,429   335,122   14
Funds from operations per share 3                        
  Basic   $0.81   $0.75   8   $2.51   $2.19   15
  Diluted   $0.81   $0.74   9   $2.51   $2.19   15
Weighted average shares - basic (000s)   152,480   152,778   -   152,680   152,872   -
Weighted average shares - diluted (000s)   152,838   153,603   -   152,923   153,322   -
Drilling                        
  Number of marketed rigs                        
    Canada 4   133   130   2   133   130   2
    United States   116   116   -   116   116   -
    International 5   58   59   (2)   58   59   (2)
  Operating days                        
    Canada 4   4,551   6,443   (29)   14,263   16,750   (15)
    United States   6,170   5,478   13   18,671   14,156   32
    International 5   2,960   2,781   6   8,602   8,050   7
Well Servicing                        
  Number of marketed rigs                        
    Canada   99   103   (4)   99   103   (4)
    United States   46   34   35   46   34   35
  Operating hours                        
    Canada   35,098   38,076   (8)   105,924   106,557   (1)
    United States   33,029   20,537   61   93,669   56,894   65

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

Revenue and Oilfield Services Expense

    Three months ended September 30   Nine months ended September 30
 ($ thousands)   2012   2011   % Change   2012   2011   % Change
Revenue                        
  Canada   164,081   192,699   -15   597,751   561,005   7
  United States   237,114   189,204   25   730,913   490,857   49
  International   124,471   93,846   33   338,551   260,543   30
                         
    525,666   475,749   10   1,667,215   1,312,405   27
Oilfield services expense   373,982   327,006   14   1,170,956   911,886   28
                         
    151,684   148,743   2   496,259   400,519   24
Gross margin (%)   28.9   31.3       29.8   30.5    

 

Revenue for the three months ended September 30, 2012 increased 10 percent to $525.7 million compared to $475.7 million for the comparable period in 2011.  Revenue for the nine months ended September 30, 2012 increased 27 percent to $1,667.2 million over revenue of $1,312.4 million recorded for the nine months ended September 30, 2011.  As a percentage of revenue, gross margin for the three and nine months ended September 30, 2012 decreased to 28.9 percent (2011 - 31.3 percent) and 29.8 percent (2011 - 30.5 percent) respectively.  Pricing pressures inherent in reduced demand for oilfield services negatively impacted gross margins for the current quarter for the Company's North American operations.

Despite downward pressure on the demand for North American oilfield services, revenue continued to grow in the three and nine months ended September 30, 2012 over the comparable periods of the prior year as a result of the Company expanding and upgrading its rig fleet.  The acquisition of Rowan Land Drilling in the third quarter of 2011 added 30 drilling rigs to the Company's United States fleet, with an additional 10 ADR® drilling rigs and 16 well servicing rigs added to the Company's consolidated fleet in 2011, all through the new build program.  As at September 30, 2012, the new build program delivered an additional 12 ADR® drilling rigs and 11 well servicing rigs to the Company's consolidated fleet in the current year.

Canadian Oilfield Services

Revenue decreased 15 percent to $164.1 million for the three months ended September 30, 2012, from $192.7 million for the three months ended September 30, 2011. For the nine months ended September 30, 2012, revenue increased seven percent to $597.8 million compared to $561.0 million for the same period in 2011. Canadian revenues accounted for 31 percent of the Company's total revenue in the third quarter of 2012, compared with 40 percent in the third quarter of 2011, and during the nine months ended September 30, 2012, Canadian revenues were 36 percent of total revenue (2011 - 43 percent).  Demand for Canadian oilfield services decreased in the current quarter when compared to the prior year which weakened operating and financial results.  Stronger pricing in the earlier months of 2012 compared to 2011 generally offset this decrease for the nine months ended September 30, 2012.

The Company recorded 4,551 drilling days in the third quarter of 2012, compared to 6,443 drilling days for the third quarter of 2011, a 29 percent decrease.  For the nine months ended September 30, 2012 drilling days were 14,263 compared to 16,750 for the nine months ended September 30, 2011, a 15 percent decrease.  The reduced operating activity in 2012 was due to reduced demand for oilfield service equipment when compared to the stronger levels seen in 2011.  Canadian well servicing hours decreased by eight percent to 35,098 operating hours in the third quarter of 2012 compared with 38,076 operating hours in the corresponding period of 2011.  For the nine months ended September 30, 2012 well servicing hours were similar to those of the prior year, decreasing one percent to 105,924 operating hours compared with 106,557 operating hours for the nine months ended September 30, 2011.

During the nine months ended September 30, 2012, the Company added five newly constructed ADR® drilling rigs to its Canadian fleet, including one added in the third quarter of 2012.  An additional three new ADRs and six new well servicing rigs are scheduled to be added to the Company's Canadian equipment fleet over the next three quarters.

United States Oilfield Services

The Company's United States operations recorded revenue of $237.1 million in the third quarter of 2012, a 25 percent increase from the $189.2 million recorded in the corresponding period of the prior year. During the nine months ended September 30, 2012, revenue of $730.9 million was recorded, an increase of 49 percent from the $490.9 million recorded for the nine months ended September 30, 2011. The Company's United States operations accounted for 45 percent of the Company's revenue in the third quarter of 2012 (2011 - 40 percent) and 44 percent of total revenue in the nine months ended September 30, 2012 (2011 - 37 percent).  Drilling rig operating days increased by 13 percent to 6,170 drilling days in the third quarter of 2012 from 5,478 drilling days in the third quarter of 2011.  For the nine months ended September 30, 2012 drilling days increased by 32 percent to 18,671 drilling days from 14,156 drilling days in the nine months ended September 30, 2011.  Well servicing activity increased by 61 percent in the third quarter of 2012 to 33,029 operating hours from 20,537 operating hours in the third quarter of 2011.  For the nine months ended September 30, 2012 well servicing activity increased 65 percent to 93,669 operating hours from 56,894 operating hours in the first nine months of 2011.

The upgrading of the Company's United States drilling and well servicing rig fleets resulted in improved operating results for the three and nine months ended September 30, 2012 compared to similar periods in the prior year despite a softening in the demand for United States oilfield services in the current quarter.  The 2011 third quarter acquisition of Rowan Land Drilling added 30 drilling rigs to the fleet while the Company's new build program added a further eight ADR® drilling rigs and 12 well servicing rigs throughout 2011; and five ADR® drilling rigs and 11 well servicing rigs during the first nine months of 2012.  An additional four new ADRs are scheduled to be delivered over the next 12 months pursuant to the Company's new build program.

Despite the United States dollar weakening against the Canadian dollar at the end of the current quarter it strengthened during the three and nine month periods ended September 30, 2012 compared to the same periods in 2011, positively impacting the operating results of the Company's United States operations on translation to Canadian dollars.  In the first nine months of 2012 the average United States dollar exchange rate increased by two percent to 1.002, when compared to the same period of the prior year.

International Oilfield Services

The Company's international operations recorded revenue of $124.5 million in the third quarter of 2012, a 33 percent increase from $93.8 million recorded in the corresponding period of the prior year. International revenues for the nine months ended September 30, 2012 increased by 30 percent to $338.6 million from $260.5 million recorded for the nine months ended September 30, 2011. International operations contributed 24 percent of the Company's revenue in the third quarter of 2012 (2011 - 20 percent) and 20 percent of the Company's revenue in the first nine months of 2012 (2011 - 20 percent). International operating days for the three months ended September 30, 2012 totaled 2,960 drilling days compared with 2,781 drilling days in 2011, an increase of six percent.  For the nine months ended September 30, 2012 international operating days totaled 8,602 drilling days compared with 8,050 drilling days for the nine months ended September 30, 2011, an increase of seven percent.

Higher revenue rates across the Company's Latin America and Eastern Hemisphere operations, combined with higher activity levels in both regions, led to improved operating results for the three and nine months ended September 30, 2012 compared to the three and nine months ended September 30, 2011.  Prior year results from the Company's Australian operations were also weakened due to flooding in certain regions during the first half of 2011.  The Company delivered two new ADR® drilling rigs into the international market during the nine months ended September 30, 2012.  Similar to the Company's United States operations, international operations benefited from the strengthening of the United States dollar over the Canadian dollar on translation into Canadian dollars for reporting purposes in 2012 compared to the prior year.

Depreciation

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011 % Change 2012 2011 % Change
Depreciation   57,599 44,528 29 166,198 120,387 38

The Company uses the unit of production method of calculating depreciation for the majority of its property and equipment.  Depreciation expense totalled $57.6 million for the third quarter of 2012 compared with $44.5 million for the third quarter of 2011, an increase of 29 percent.  Depreciation expense for the first nine months of 2012 was $166.2 million, an increase of 38 percent over the $120.4 million recorded for the first nine months of 2011.  Increased depreciation reflects the impact from the growth of the Company's fleet through the addition of Ensign US Southern in the third quarter of 2011 and recent additions from the Company's new build program.

General and Administrative Expense

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011 % Change 2012  2011 % Change
General and administrative  19,107 21,174 (10) 59,199 49,380 20
% of revenue   3.6 4.5   3.6 3.8

General and administrative expense decreased 10 percent to $19.1 million (3.6 percent of revenue) for the third quarter of 2012 compared with $21.2 million (4.5 percent of revenue) for the third quarter of 2011. For the nine months ended September 30, 2012, general and administrative expense totaled $59.2 million (3.6 percent of revenue) compared with $49.4 million (3.8 percent of revenue) recorded for the nine months ended September 30, 2011, an increase of 20 percent.  The overall increase in general and administrative expense for the nine months ended September 30, 2012 compared to the prior year was to support the increased operating activity during the first nine months of 2012, including the impact from the addition of Ensign US Southern in September 2011, and also includes the negative translational impact of a stronger United States dollar on United States and international administrative expenses in the current periods.

Share-Based Compensation Expense (Recovery)

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011 % Change 2012 2011 % Change
Share-based compensation   3,659 (18,311) (120) (2,557) (1,577) 62

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

For the three months ended September 30, 2012, share-based compensation expense (recovery) was an expense of $3.7 million compared with a recovery of $18.3 million recorded in the third quarter of 2011. For the nine months ended September 30, 2012, share-based compensation was a recovery of $2.6 million compared with a recovery of $1.6 million for the nine months ended September 30, 2011.  The change in share-based compensation expense (recovery) in the three and nine months ended September 30, 2012 compared to the same periods of the prior year reflects the change in the fair value of the share-based compensation liability primarily resulting from fluctuations in the Company's share price.  The closing price of the Company's common shares was $15.10 at September 30, 2012 ($13.75 at September 30, 2011), compared with $14.00 at June 30, 2012 ($19.12 at June 30, 2011), $14.91 at March 31, 2012 ($18.26 at March 31, 2011) and $16.25 at December 31, 2011 ($15.03 at December 31, 2010).

Interest Expense

  Three months ended September 30   Nine months ended September 30
($ thousands)   2012 2011 % Change 2012 2011 % Change
Interest expense   4,926 1,755 181 14,804 2,515 489
Interest income   (145) (216) (33)  (365) (511) (29)
  4,781 1,539 211 14,439 2,004 621

The Company increased its global revolving credit facility (the "Global Facility") by $150.0 million to $400.0 million in the second quarter of 2012 and repaid the USD $100.0 million remaining balance of the term loan during the first half of 2012.  Interest is incurred on the Company's $10.0 million Canadian-based revolving credit facility (the "Canadian Facility"), the $400.0 million Global Facility, the USD $300.0 million senior unsecured notes issued in February 2012 and the USD $100.0 million term loan outstanding during the first half of 2012.  The amortization of deferred financing costs associated with the issuance of the Company's long-term debt are included in interest expense in the three and nine months ended September 30, 2012.

The increase in interest expense in the first nine months of 2012 reflects the additional debt incurred by the Company in connection with the Rowan Land Drilling acquisition, completed in September 2011.

Foreign Exchange and Other ((Gain)/Loss)

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011 % Change 2012 2011 % Change
Foreign exchange and other  (3,018) 16,111 (119) 5,793 4,275 36

Included in this amount is the impact of the conversion of the Australian operations from Australian dollars to United States dollars.  The Australian currency strengthened in the current quarter but weakened in the three and nine months ended September 30, 2011 with the movement much greater in 2011 compared to 2012.

Income Taxes

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011  % Change 2012 2011 % Change
Current income tax   9,795 (2,258) (534) 41,017 13,897 195
Deferred income tax   14,929 21,971 (32) 43,137 52,400 (18)
  24,724 19,713 25 84,154 66,297 27
Effective income tax rate (%)   35.5 23.6   33.2 29.3

The effective income tax rate for the three months ended September 30, 2012 was 35.5 percent compared with 23.6 percent for the three months ended September 30, 2011. The effective income tax rate for the nine months ended September 30, 2012 was 33.2 percent compared with 29.3 percent for the nine months ended September 30, 2011. The effective income tax rate was higher in the current quarter and for the nine months ended September 30, 2012 due to a smaller proportion of income earned in Canada, in combination with higher proportions of income earned in higher tax rate jurisdictions.

Financial Position

The following chart outlines significant changes in the consolidated statement of financial position from December 31, 2011 to September 30, 2012:

($ thousands) Change Explanation
Cash and cash equivalents 46,526 See consolidated statements of cash flows.
Accounts receivable  (50,335) Decrease was mainly due to reduced operating activity in Canada in the third quarter of 2012 compared to the fourth quarter of 2011 as a result of reduced demand for oilfield services.
Inventories and other (9,390) Decrease due to normal course use of consumables and amortization of prepaid expenses offset by additional inventory.
Property and equipment 8,713 Increase was due to additions from the current new build construction program offset by depreciation and a decrease in the quarter end foreign exchange rate on the consolidation of the Company's foreign subsidiaries.
Note receivable (930) Decrease was due to the reclassification of the current portion of the note receivable to accounts receivable offset by accretion of interest income during the first nine months of 2012.
Accounts payable and accruals (42,723) Decrease was due to reduced operating activity in Canada in the third quarter of 2012 compared to the fourth quarter of 2011 as a result of reduced demand for oilfield services.
Operating lines of credit 20,961 Increase was due to additional draws during the period on the expanded Global Facility offset by repayments during the period and the impact of foreign exchange fluctuations on the consolidation of the Company's foreign subsidiaries.
Income taxes payable 4,103 Increase was due to the current income tax provision for the period, net of tax instalments and refunds.
Share-based compensation (2,526) Decrease was due to the decrease in the price of the Company's common shares as at September 30, 2012 compared with December 31, 2011.
Long-term debt (112,781) Decrease reflects the repayment of the term loan and accounting for financing costs associated with long-term debt and the impact of foreign exchange fluctuations on the United States dollar denominated debt offset by the issuance of senior unsecured notes in February 2012.
Deferred income taxes 42,567 Increase primarily due to accelerated tax depreciation of assets added during the first nine months of 2012.
Shareholders' equity 84,983 Increase was due to net income for the period offset by the amount of dividends declared in the period and the impact of foreign exchange rate fluctuations on net assets of foreign subsidiaries.

Funds from Operations and Working Capital

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011 % Change 2012 2011 % Change
Funds from operations   123,934 114,186 9  383,429 335,122 14
Funds from operations per share  $ 0.81 $ 0.75 8  $ 2.51 $ 2.19 15
Working capital 1   (3,751)  (10,233) (63) (3,751) (10,233) (63)

1 Comparative figure as of December 31, 2011.

During the three months ended September 30, 2012, the Company generated funds from operations of $123.9 million ($0.81 per common share) compared with funds from operations of $114.2 million ($0.75 per common share) for the three months ended September 30, 2011, an increase of nine percent. For the nine months ended September 30, 2012, the Company generated funds from operations of $383.4 million ($2.51 per common share), an increase of 14 percent over funds from operations of $335.1 million ($2.19 per common share) generated in the first nine months of 2011.  Increased funds from operations in 2012 compared to 2011 is mainly due to growth of the Company's operations across all regions through the addition of Ensign US Southern in the United States in September 2011 and additions from the new build program to the Company's North American and Australian equipment fleet throughout 2011 and 2012.

At September 30, 2012, the Company's working capital totaled negative $3.8 million, compared to negative $10.2 million at December 31, 2011.  The improvement in the Company's working capital position in the current year reflects the expanded operations of the Company, offset by use of internally generated cash flows and the recently expanded credit facilities to repay the remaining balance of the USD $100.0 million term loan; paid off in full in the first half of 2012.  The Company expects funds generated by operations, combined with current and future credit facilities, to fully support current operating and capital requirements.  Existing revolving credit facilities provide for total borrowing of $410.0 million, of which $137.3 million was available at September 30, 2012.

Investing Activities

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011 % Change 2012 2011 % Change
Purchase of property and equipment  (69,751) (71,615) (3) (226,360) (252,624) (10)
Acquisition   - (497,352) (100) - (497,352) (100)
Net change in non-cash working capital   21,801 42,704 (49) 8,352 46,402 (82)
Cash used in investing activities   (47,950) (526,263) (91) (218,008) (703,574) (69)

Purchases of property and equipment during the third quarter of 2012 totaled $69.8 million (2011 - $71.6 million).  Purchases of property and equipment during the first three quarters of 2012 totaled $226.4 million (2011 - $252.6 million).  The purchase of property and equipment for the three and nine months ended September 30, 2012 relate predominantly to expenditures made pursuant to the Company's ongoing new build program.

In September 2011, the Company completed the acquisition of Rowan Land Drilling, comprised of 30 drilling rigs in the southern United States, for USD $510.0 million.  The purchase was funded with existing cash balances and expanded credit facilities.

Financing Activities

  Three months ended September 30 Nine months ended September 30
($ thousands)   2012 2011 % Change 2012 2011 % Change
Net (decrease) increase in operating lines of credit   (40,493) 70,877 (157) 29,188 66,997 (56)
Issue of unsecured term loan   - 390,080 (100) - 390,080 (100)
Issue of senior unsecured notes   - - - 300,000 - -
Repayment of term loan   - - - (403,279) - -
Issue of capital stock   - - - 43 - -
Purchase of shares held in trust   (524) (617) (15) (8,044) (5,528) 46
Deferred financing costs   - (2,078) (100) (2,156) (2,078) 4
Dividends   (16,087)  (14,555) 11 (48,262) (43,665) 11
Net change in non-cash working capital   (65) (65) - 930 (97) (1,059)
Cash (used in) provided by financing activities   (57,169) 443,642 (113) (131,580) 405,709 (132)

The Company's Global Facility was increased by $150.0 million during the second quarter of 2012 to a new limit of $400.0 million.  Additionally, the Company has available a $10.0 million Canadian Facility.  The Global Facility is available to the Company and certain of its wholly-owned subsidiaries, and may be drawn in Canadian, United States or Australian dollars, up to the equivalent value of $400.0 million Canadian dollars.  The amount available under the Canadian Facility is $10.0 million or the equivalent in United States dollars.

The change in the operating lines of credit for the three and nine months ended September 30, 2012 reflects operating cash flows generated by the Company's operations in excess of capital expenditure requirements in the current quarter and the repayment of the USD $100.0 million remaining balance of the term loan during the first half of 2012.  As of September 30, 2012, the operating lines of credit are primarily being used to fund the completion of the most recent new build program and to support international operations.

In February 2012, the Company completed the private placement of USD $300.0 million of senior unsecured notes (the "Notes"), with the proceeds from the issuance being used to repay a portion of the term loan.  The Notes consist of: USD $100.0 million in five year notes with an interest rate of 3.43 percent and a maturity date of February 22, 2017; USD $100.0 million in seven year notes with an interest rate of 3.97 percent and a maturity date of February 22, 2019; and USD $100.0 million in ten year notes with an interest rate of 4.54 percent and a maturity date of February 22, 2022.  The Notes rank equally with the Company's Global Facility. 

On June 14, 2012 the Company received approval from the Toronto Stock Exchange to acquire for cancellation up to three percent of the Company's issued and outstanding common shares under a Normal Course Issuer Bid (the "Bid").  The Company may purchase up to 4,596,397 common shares for cancellation.  The Bid commenced on June 18, 2012 and will terminate on June 17, 2013 or such earlier time as the Bid is completed or terminated at the option of the Company.  As at September 30, 2012, no common shares have been purchased and cancelled pursuant to the Bid.

The Company previously had a Bid that commenced on June 7, 2011 and terminated on June 6, 2012, under which no common shares were purchased and cancelled.

The Board of Directors of the Company has declared a fourth quarter dividend of $0.110 per common share, a 4.8 percent increase over the previous quarterly dividend rate of $0.105 per common share.  The Company has increased its dividend by a compound annual growth rate of 17 percent since it first started to pay a dividend in 1995, with the dividend rate increasing every year.  The fourth quarter dividend is payable January 4, 2013 to all Common Shareholders of record as of December 21, 2012.  The dividend is pursuant to the quarterly dividend policy adopted by the Company.  Pursuant to subsection 89(1) of the Canadian Income Tax Act ("ITA"), the dividend being paid is designated as an eligible dividend, as defined in subsection 89(1) of the ITA.

New Builds

During the nine months ended September 30, 2012, the Company commissioned five new ADR® drilling rigs and 11 new well servicing rigs in the United States; five new ADR® drilling rigs in Canada; and two new ADR® drilling rigs in Australia.

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

  Estimated Delivery Date
  Q4-2012 Q1-2013 Q2-2013 Q3-2013 Q4-2013 Total
ADRs            
  Canada 1 1 1 - - 3
  United States   - 1 1 1 1 4
  International   - - - - - -
Total   1 2 2 1 1 7
Well Servicing            
  Canada   2 3 1 - - 6
  United States   - - - - - -
  International   - - - - - -
Total   2 3 1 - - 6

Outlook

As expected, third quarter activity levels in Canada fell below the activity levels of the comparable quarter of the prior year.  Operators delayed or reduced programs due to decreased levels of cash flows and continuing uncertainty with respect to global economic conditions and the resulting impact on the supply and demand fundamentals for crude oil and natural gas.  The fourth quarter has continued this softening trend but the Company expects that fourth quarter oilfield service activity levels will improve, subject to weather conditions, over activity levels in the recently completed third quarter.  The general weakness in the Canadian market has resulted in a softening of rates for certain equipment classes resulting in reduced margins compared to the prior year.  Current expectations for strong, seasonal levels of demand for the upcoming winter drilling season should enable the Company to improve pricing from current levels and approach margins similar to those experienced in last year's winter drilling season.  Future Canadian operations will be further bolstered by the delivery of three new ADRs and six new well servicing rigs over the next several quarters.

The United States market continued to soften in the third quarter as various regions saw a slight decrease in the level of oilfield services activity as measured by the operating drilling rig fleet.  While there are still just under 1,800 drilling rigs operating in the United States land-drilling market, oil and natural gas fundamentals continue to put downward pressure on the demand and revenue rates for oilfield services.  The Company has experienced a reduction in activity levels and pricing, particularly for conventional drilling rigs.  That said, the four new ADR® drilling rigs that are being delivered under term contracts into the United States market pursuant to the Company's current new build program will have a positive impact on activity levels and margins going forward.

The Company's international operations continue to improve as two new ADRs were delivered into Australia in the third quarter and operations resumed in Libya with the start-up of one drilling rig in September.  The Company anticipates that operating activity and financial contributions from the international segment will continue to moderately improve in future quarters.

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 2012 results at 2:00 p.m. MST (4:00 p.m. EST) on Monday, November 12, 2012.  The conference call number is (647) 427-7450 (in Toronto) or 1-888-231-8191 (outside Toronto).  A taped recording will be available until November 19, 2012 by dialing 1-416-849-0833 (in Toronto) or 1-855-859-2056 (outside Toronto) and entering the reservation number 43355202.  A live broadcast may be accessed through the Company's web site at www.ensignenergy.com.

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

Ensign Energy Services Inc.              
Consolidated Statements of Financial Position           
As at           September 30     December 31
            2012     2011
(Unaudited, in thousands of Canadian dollars)            
                   
Assets                  
Current Assets                
  Cash and cash equivalents         $ 49,139   $ 2,613
  Accounts receivable           426,808     477,143
  Inventories and other           72,588     81,978
                   
            548,535     561,734
                   
Property and equipment       2,488,331     2,479,618
Note receivable         5,831     6,761
                   
          $ 3,042,697   $ 3,048,113
                   
                   
                   
Liabilities                
Current Liabilities                
  Accounts payable and accruals         $ 246,818   $ 289,541
  Operating lines of credit           259,401     238,440
  Income taxes payable           15,597     11,494
  Dividends payable            16,087     16,087
  Share-based compensation           14,383     16,405
                   
            552,286     571,967
                   
Long-term debt         293,172     405,953
Share-based compensation       4,800     5,304
Deferred income taxes       384,034     341,467
                   
            1,234,292     1,324,691
                   
Shareholders' Equity              
                   
  Share capital           165,205     166,864
  Contributed surplus           3,137     3,448
  Foreign currency translation reserve           (32,786)     1,032
  Retained earnings           1,672,849     1,552,078
                   
            1,808,405     1,723,422 
                   
          $ 3,042,697   $ 3,048,113
                   
                   

 

Ensign Energy Services Inc.                        
Consolidated Statements of Income                       
For the three and nine months ended September 30                    
                             
(Unaudited, in thousands of Canadian dollars, except per share data)                  
                             
            Three months ended   Nine months ended
            September 30     September 30   September 30     September 30
            2012     2011   2012     2011
                             
Revenue         $ 525,666   $ 475,749 $ 1,667,215   $ 1,312,405
                             
Expenses                            
  Oilfield services           373,982     327,006   1,170,956     911,886
  Depreciation           57,599     44,528   166,198     120,387
  General and administrative           19,107     21,174   59,199     49,380
  Share-based compensation           3,659     (18,311)   (2,557)     (1,577)
  Foreign exchange and other           (3,018)     16,111   5,793     4,275
                             
            451,329     390,508   1,399,589     1,084,351
                             
Income before interest and income taxes           74,337     85,241   267,626     228,054
                             
Interest income           145     216   365     511
Interest expense           (4,926)     (1,755)   (14,804)     (2,515)
                             
Income before income taxes           69,556     83,702   253,187     226,050 
                             
Income taxes                            
  Current tax           9,795     (2,258)   41,017     13,897
  Deferred tax           14,929     21,971   43,137     52,400
                             
            24,724     19,713   84,154     66,297
                             
Net income         $ 44,832   $ 63,989 $ 169,033   $ 159,753
                             
Net income per share                             
  Basic         $ 0.29   $ 0.42 $ 1.11   $ 1.05
  Diluted         $ 0.29   $ 0.42 $ 1.11   $ 1.04
                             
                             

 

Ensign Energy Services Inc.                    
Consolidated Statements of Cash Flows                  
For the three and nine months ended September 30                
                         
(Unaudited, in thousands of Canadian dollars)                        
            Three months ended       Nine months ended
            September 30   September 30   September 30   September 30
            2012   2011   2012   2011
Cash provided by (used in)                        
Operating activities                        
Net income         $ 44,832 $ 63,989 $ 169,033 $ 159,753
Items not affecting cash                        
  Depreciation           57,599   44,528   166,198   120,387
  Share-based compensation, net of cash paid           6,499   (16,605)   3,558   2,279
  Accretion on long-term debt           75   303   1,503   303
  Deferred income tax           14,929   21,971   43,137   52,400
Net change in non-cash working capital           (26,307)   (112,758)   6,874   (97,460)
            97,627   1,428   390,303   237,662 
                         
Investing activities                        
Purchase of property and equipment           (69,751)   (71,615)   (226,360)   (252,624)
Acquisition            -   (497,352)   -   (497,352)
Net change in non-cash working capital           21,801   42,704   8,352   46,402
            (47,950)   (526,263)   (218,008)   (703,574)
                         
Financing activities                        
Net (decrease) increase in operating lines of credit           (40,493)   70,877   29,188   66,997
Issue of unsecured term loan           -   390,080   -   390,080
Issue of senior unsecured notes           -   -   300,000   -
Repayment of term loan           -   -   (403,279)   -
Issue of capital stock           -   -   43   -
Purchase of shares held in trust           (524)   (617)   (8,044)   (5,528)
Deferred financing costs           -   (2,078)   (2,156)   (2,078)
Dividends           (16,087)   (14,555)   (48,262)   (43,665)
Net change in non-cash working capital           (65)   (65)   930   (97)
            (57,169)   443,642   (131,580)   405,709
                         
Net (decrease) increase in cash and cash equivalents           (7,492)   (81,193)   40,715   (60,203)
  Effects of foreign exchange on cash and                         
    cash equivalents           3,054   (22,560)   5,811   (22,863)
Cash and cash equivalents                        
  Beginning of period           53,577   110,207   2,613   89,520
                         
  End of period         $ 49,139 $ 6,454 $ 49,139 $ 6,454
                         
Supplemental information                        
  Interest paid         $ 1,827 $ 1,337 $ 9,322 $ 2,130
  Income taxes paid         $ 9,949 $ 8,279 $ 36,914 $ 23,504
                         
                         

 

 

 

 

 

SOURCE: Ensign Energy Services Inc.

For further information:

Glenn Dagenais, Executive Vice President Finance and Chief Financial Officer, (403) 262-1361


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