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Share Name | Share Symbol | Market | Type |
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TSXV:LEA | TSX Venture | Common Stock |
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Leader Energy Services Ltd. ("Leader" or the "Company") (TSX VENTURE:LEA) has released its financial and operating results for the three and nine month periods ended September 30, 2012. Performance Summary ---------------------------------------------------------------------------- (000's) (Unaudited) Sept. 30, Sept. 30, Quarter ended 2012 2011 $ Change % Change ----------- ----------------------------------- Revenue - continuing operations $7,436 $10,020 $(2,584) (26)% Operating Expenses - continuing operations 5,113 5,056 57 1% ----------- ----------------------------------- 2,323 4,964 (2,641) (53)% General and Administrative - continuing operations 983 1,196 (213) (18)% Amortization - continuing operations 805 643 162 25% Finance cost 416 871 (455) (52)% Loss on settlement of loans and borrowings - - - n/a Other (gains) losses 11 32 (21) (66)% ----------- ----------------------------------- Income (loss) - continuing operations 108 2,222 (2,114) (95)% ----------- ----------------------------------- Income - discontinued operations - - - n/a ----------- ----------------------------------- Net income (loss) $108 $2,222 $(2,114) (95)% ----------- ----------------------------------- ----------- ----------------------------------- Income (Loss) per share - Basic $0.00 $0.11 $(0.11) n/a Income (Loss) per share - Diluted $0.00 $0.11 $(0.11) n/a EBITDA(i) $1,381 $3,803 $(2,422) (64)% ----------- ----------------------------------- ----------- ----------------------------------- ----------- ----------------------------------- Sept. 30, Sept. 30, 9 months ended 2012 2011 $ Change % Change ----------- ----------------------------------- Revenue - continuing operations $20,838 $23,078 $(2,240) (10)% Operating Expenses - continuing operations 16,006 14,043 1,963 14% ----------- ----------------------------------- 4,832 9,035 (4,203) (47)% General and Administrative - continuing operations 3,376 3,437 (61) (2)% Amortization - continuing operations 2,343 1,867 476 25% Finance cost 1,905 2,505 (600) (24)% Loss on settlement of loans and borrowings 1,338 1,401 (63) (4)% Other gains (66) (22) (44) n/a ----------- ----------------------------------- Loss - continuing operations (4,064) (153) (3,911) n/a ----------- ----------------------------------- Income - discontinued operations - 31 (31) n/a ----------- ----------------------------------- Net loss $(4,064) $(122) $(3,942) n/a ----------- ----------------------------------- ----------- ----------------------------------- Loss per share - Basic $(0.15) $(0.01) $(0.14) n/a Loss per share - Diluted $(0.15) $(0.01) $(0.14) n/a EBITDA(i) $1,549 $5,744 $(4,195) (73)% ----------- ----------------------------------- ----------- ----------------------------------- (i) EBITDA means income (loss) from continuing operations before finance costs, loss on settlement of loans and borrowings, taxes, amortization, other (gains) losses, and share based compensation. Readers are cautioned that EBITDA is generally regarded as an indirect measure of operating cash flow, and, as such, the Company believes it is a significant indicator of success of public companies, and is particularly relevant to readers within the investment community. EBITDA is not a measure that has a standardized meaning and accordingly may not be comparable to similar measures used by other companies. Results of Continuing Operations -------------------------------------------------------------------------- Well Stimulation Services (000's) (Unaudited) Sept. 30, Sept. 30, Quarter ended 2012 2011 $ Change % Change ---------- ----------------------------------- Revenue $7,436 $10,020 $(2,584) (26)% Operating Expenses 5,113 5,056 57 1% ---------- ----------------------------------- Gross profit(i) $2,323 $4,964 $(2,641) 53% ---------- ----------------------------------- Sept. 30, Sept. 30, Nine months ended 2012 2011 $ Change % Change ---------- ----------------------------------- Revenue $20,838 $23,078 $(2,240) (10)% Operating Expenses 16,006 14,043 1,963 14% ---------- ----------------------------------- Gross profit(i) $4,832 $9,035 $(4,203) (47)% (i) Management believes that gross profit provides investors with an indication of income before administrative costs, amortization, finance costs, taxes and other. Readers are cautioned that gross profit should not be considered as an alternative to income determined in accordance with International Financial Reporting Standards ("IFRS") as an indicator of the Company's performance. Revenues from well stimulation services decreased 26% in the third quarter of 2012 as compared to the third quarter of 2011. On a year-to-date basis, revenue decreased 10% to $20.8 million. Revenue in the third quarter was $7.4 million as compared to $10.0 million in the third quarter of the prior year. Activity levels in the third quarter were slower to recover from spring break-up as industry activity was hampered by wet weather at various times during the summer. In addition, preceding the start of the third quarter oil prices declined over 25% in a two-month period causing customers to re-evaluate their exploration and development budgets for the remainder of 2012. This reduction in activity resulted in lower than expected equipment utilization across the industry which had the effect of increased competition for available work. In addition, the Company continued to experience a reduction in the number of nitrogen jobs performed in the quarter as compared to 2011. This decrease is attributed to the reduction in stand-alone nitrogen work caused by customers reducing activity on gas wells. For the nine month period ended September 30, 2012, the Company reported revenue of $20.8 million as compared to $23.1 million reported in the nine month period of the prior year. Revenue recorded in 2012 continued to reflect demand for deeper, larger diameter coil equipment applicable to the horizontal drilling market in north-central Alberta and northeast British Columbia, particularly in the first quarter of 2012. This concentration on larger diameter deep coil work focuses on oil and liquids-rich resource plays, and has traditionally resulted in higher day rates being charged by the Company. These higher revenues reported in the first quarter were partially offset by an increase in equipment standby at lower day rates as a result of an industry-wide shortage of class three 2" and 2 3/8" coiled tubing units. As a result of this shortage in the first quarter, customers requested equipment stay on location at lower standby rates in anticipation of further work at these locations, forcing the Company to delay upcoming jobs and in some circumstances turn down potential projects while this equipment was deployed. Increases in revenue reported in the first quarter of 2012 as compared to the same period in 2011 were substantially reversed in the second quarter due to a prolonged spring break-up and wet weather in the WCSB resulting in lower than expected equipment utilization across the industry which had the effect of increasing competition for available work. Activity was also affected as customers evaluated their capital expenditure spending in light of current commodity price fluctuations. In addition, the Company experienced a reduction in the number of stand-alone nitrogen jobs. Further reductions in revenue as compared to 2011 were reported in the third quarter of 2012 as discussed previously. The Company exited the quarter with six coil units plus one reel trailer with 2 3/8" coil, seven nitrogen pumpers and three fluid pumpers. At the end of the third quarter, the Company's new 2 3/8" reel trailer was nearing completion. At the end of October, the reel trailer was complete and ready for service. Based on initial interest, the Company expects significant demand for this equipment on a go forward basis. The Company's current reel trailer will be used to support operations and provide redundancy during periods of increased activity levels. Operating costs totaled $5.1 million during the third quarter of 2012 compared to $5.1 million reported in the comparable period in 2011. During the current quarter, the Company retained its qualified mechanics and field personnel and continued to focus on training and cross-training initiatives. Over the past few years, the biggest challenge facing the Company has been the ability to hire enough qualified personnel to operate the equipment in the field. In response to this challenge, the Company has been able to hire personnel from both within and outside western Canada. In addition to the above, the Company continued to concentrate on routine repair and maintenance initiatives and incurred additional expense for larger diameter coiled tubing charges resulting from harsh down hole conditions decreasing the life of certain larger diameter coiled tubing strings. Lower activity levels in the quarter, resulted in the Company reporting higher costs as a percentage of revenue as a result of the fixed cost structure required to ensure personnel are available to operate the equipment and additional costs incurred for rotational personnel from outside western Canada. These increases were partially offset by savings realized in third party transportation as a result of new equipment received in the second quarter of 2012. As a result of increased operating costs as a percentage of revenue and lower than anticipated activity levels, the Company is reviewing its cost structures and has implemented cost reduction initiatives during the fourth quarter of 2012. For the nine month period ended September 30, 2012, the Company reported operating costs of $16.0 million as compared to $14.0 million in the nine month period ended September 30, 2011. Operating costs for the first nine months increased 14% over the same period in 2011 reflecting the increased costs incurred to hire and retain additional qualified field staff to operate equipment added to the fleet, the repair and maintenance of equipment in anticipation of increased activity on a go-forward basis, the inefficiencies caused by weight re-distribution during spring break-up, and the reliance on third party transportation services in the first quarter of 2012. Liquidity and Capital Resources On June 14, 2012, the Company entered into new credit facilities with a Canadian chartered bank. The credit facilities include a demand revolving facility of up to $5 million, a three year committed non-revolving term loan of up to $9.0 million amortized over 60 months with provision to extend for two additional one year terms subject to lender approval, and a demand revolving reducing capital expenditure loan of up to $2.0 million. The interest rates on these facilities were at prime plus 1.25% and the facilities are subject to normal and customary terms and covenant ratios including working capital, tangible net worth, debt to EBITDA and fixed charge coverage ratios. During the third quarter of 2012, the Company negotiated an amendment to its credit facilities which resulted in changes to the benchmarks on certain covenant ratios as described above. Included in this amendment is an increase in the interest rate from prime plus 1.25% to prime plus 1.50%. In addition, the Company has drawn $1.0 million on the capital expenditure demand loan to assist in the funding of capital expenditures. This loan is repayable on a quarterly basis with the first payment of $50,000 due in December 2012. Based on projected activity levels, the Company anticipates paying this capital expenditure demand loan off prior to March 2013. At September 30, 2012, all covenants have been met under these facilities. Management reassesses compliance with these covenants on a quarterly basis. Outlook U.S. West Texas Intermediate (WTI) crude oil started 2012 above $100 per barrel and reached a peak in early March of almost $110 per barrel. Crude oil prices fell during the second quarter due in part, to concerns about lower oil demand with a slowdown of the global economy. By the end of June, WTI oil prices were down over 25% from their peak to just under $78 per barrel. The volatility in oil prices resulted in our customers adjusting their budgets downward for the remainder of 2012, which had the effect of increasing competition in the coiled tubing space. In spite of a recovery in oil prices at the end of the third quarter, we have experienced a reduction in demand at the start of the fourth quarter. Heading into 2013, Leader has moderated its plans for capital expenditures and has recently implemented cost savings strategies. Leader has recently expanded its geographic footprint in the WCSB where activity levels are robust. Demand for deep coiled tubing services is expected to remain healthy in 2013, with PSAC estimating that 70% of new wells will be drilled horizontally. Other Additional information can be found on SEDAR at www.sedar.com or the Company web site at www.leaderenergy.com. The number of common shares issued and outstanding at the date hereof was 29,388,021 which does not include 1,948,000 unexercised stock options and 4,250,000 share purchase warrants. Forward-looking information This press release contains certain statements or disclosures relating to the Company that are based on the expectations of the Company as well as assumptions made by and information currently available to the Company which may constitute forward-looking information under applicable securities laws. All such statements and disclosures, other than those of historical fact, which address activities, events, outcomes, results or developments that the Company anticipates or expects may, or will occur in the future (in whole or in part) should be considered forward-looking information. FOR FURTHER INFORMATION PLEASE CONTACT: Leader Energy Services Ltd. Rod Hauser President & CEO (403) 265-5400 r.hauser@leaderenergy.com Leader Energy Services Ltd. Jason Krueger, CFA Executive VP & Director (403) 265-5400 j.krueger@leaderenergy.com Leader Energy Services Ltd. Graham Reid, CA VP Finance & CFO (403) 265-5400 g.reid@leaderenergy.com www.leaderenergy.com
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