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TransGlobe Energy Corporation Third Interim Report for the Three and Nine Months Ended September 30, 2006 TransGlobe Energy Corporation ("TransGlobe" or the "Company") (TSX: TGL) (AMEX: TGA) is pleased to announce its financial and operating results for the three and nine month periods ended September 30, 2006. All dollar values are expressed in United States dollars unless otherwise stated. Conversion of natural gas to oil is made on the basis of 6,000 cubic feet of natural gas being equivalent to one barrel of crude oil. HIGHLIGHTS - $7.4 million net income in Q3-2006 ($0.12 per diluted share). - $12.7 million cash flow from operations in Q3-2006 ($0.21 per diluted share). - Tasour 22ST on production at 8,000+ Bopd (1,100+ Bopd to TransGlobe). - Godah #3 tested 1,511 Bopd (209 Bopd to TransGlobe). - Godah field on production, October 27. - Wadi Bayhan #2 tested 3.5 MMcfd and 35 Bpd of condensate. - 3-D seismic programs underway on Block S-1 and Block 32. - Egypt, first 3 year extension approved effective July 18. Corporate Summary The Company's total production during the third quarter of 2006 averaged 4,952 Boepd, a 1% increase from the second quarter of 2006. The increase in production over Q2-2006 is a result of a 25% increase in production at Block 32 from Tasour #22ST drilled in Q3-2006. The increase was offset by a 5% decline at Block S-1 due to water production in the western portion of the field, and a 10% reduction in Canada due to unscheduled third party pipeline and facility maintenance. The Company is forecasting significantly higher production in the fourth quarter from increases at Block 32 (full quarter of production from Tasour #22ST and commencement of Godah production) and from Canada (pipeline connections from new wells and the commissioning of a new compressor). These production increases are expected to result in a December exit production rate over 6,000 Boed.
FINANCIAL AND OPERATING UPDATE
($000's, except per share,
price and volume amounts)
Three Months Ended Nine Months Ended
Sept. 30 Sept. 30
Financial 2006 2005 Change 2006 2005 Change
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Oil and gas revenue 28,190 28,796 (2)% 82,159 65,570 25%
Oil and gas revenue, net of
royalties 18,542 19,147 (3)% 52,450 44,469 18%
Operating expense 2,761 2,786 (1)% 7,388 7,608 (3)%
General and administrative
expense 665 653 2% 2,372 1,911 24%
Stock-based compensation 324 128 153% 912 578 58%
Depletion, depreciation and
accretion expense 4,903 5,190 (6)% 13,571 12,893 5%
Income taxes 2,769 2,606 6% 6,819 5,730 19%
Cash flow from operations(2) 12,662 13,142 (4)% 36,315 29,474 23%
Basic per share 0.22 0.23 0.62 0.51
Diluted per share 0.21 0.22 0.60 0.49
Net income 7,366 7,539 (2)% 21,469 15,519 38%
Basic per share 0.13 0.13 0.37 0.27
Diluted per share 0.12 0.13 0.35 0.26
Capital expenditures 13,654 10,855 26% 35,838 23,100 55%
Working capital 9,293 9,943 (7)% 9,293 9,943 (7)%
Common shares outstanding
Basic (weighted average) 58,682 58,168 1% 58,627 57,723 2%
Diluted (weighted average) 60,552 60,212 1% 60,588 60,102 1%
Production and Sales Volumes
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Total production (Boepd)
(6:1) (1) 4,952 5,285 (6)% 4,964 4,944 0%
Total sales (Boepd) (6:1) (1) 4,952 5,533 (11)% 4,998 4,966 1%
Oil and liquids (Bopd) 4,290 4,742 (10)% 4,296 4,313 0%
Average price
($ per barrel) 66.40 58.60 13% 64.17 49.70 29%
Gas (Mcfpd) 3,975 4,749 (16)% 4,213 3,917 8%
Average price ($ per Mcf) 5.38 7.35 (27)% 5.95 6.55 (9)%
Operating expense ($ per Boe) 6.06 5.47 11% 5.41 5.61 (4)%
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(1) The differences in production and sales volumes result from inventory
changes at Block S-1, Yemen
(2) Cash flow from operations is a non-GAAP measure that represents cash
generated from operating activities before changes in non-cash working
capital
OPERATIONS UPDATE Block S-1, Republic of Yemen (25% working interest) Operations and Exploration During the third quarter the first exploration well of 2006 was drilled targeting Alif, Lam and fractured Basement prospects at Wadi Bayhan. The Wadi Bayhan #2 exploration well, which commenced drilling July 11, was drilled to a total depth of 2,726 meters. The well was vertically drilled through the Alif and Lam formations and then directionally drilled at an angle of 70 degrees to target a fractured Basement prospect. The Alif and Basement targets had no hydrocarbon indications and were not tested. Tests were conducted on both the upper and lower Lam formations. Wadi Bayhan #2 tested a 29.0 meter portion of the upper Lam sandstone section at a flowing rate of 3.5 million cubic feet per day of natural gas and 35 barrels of condensate per day on a 28/64 inch choke at a flowing pressure of 850 psi. The test has confirmed natural gas in the upper Lam formation of Wadi Bayhan #2. Additional drilling will be required to determine if a commercial upper Lam oil pool exists in the down dip position from Wadi Bayhan #2, similar to that found at An Nagyah. In the lower Lam, a 28.0 meter interval was perforated to evaluate a potential oil column which was identified on wireline logs, pressure surveys and drilling shows. The poorer quality lower Lam formation did not flow after perforation and was not stimulated. Better quality lower Lam sandstones were encountered below the oil/water contact. There is potential to drill in an updip position which would bring better quality, lower Lam sandstones into the oil column. Following Wadi Bayhan #2, the drilling rig was moved to an exploration prospect at Osaylan West. Drilling commenced on October 15 and is expected to take 40 to 60 days to complete. The Osaylan West well is targeting an Alif and Lam prospect located approximately 3.0 km south of Wadi Bayhan and 20 km west northwest of An Nagyah. A large 610 square kilometer 3-D seismic acquisition program commenced in mid-July on the southeast part of Block S-1 with a planned completion date of mid-2007. It is anticipated that the new 3-D seismic program will provide a number of new exploration prospects for drilling in late 2007 and 2008. Production Production from Block S-1 averaged 10,048 Bopd (2,512 Bopd to TransGlobe) during the third quarter of 2006. Production from Block S-1 is expected to average 9,600 to 10,000 Bopd for the remainder of the year. Production has been choked back to the 10,000 Bopd level in response to an increase in water production in several horizontal wells located in the western portion of the field. This increase in water production has been attributed in part to localized pressure drawdowns in the western portion of the field. The choked back wells have responded favorably, with water cut stabilizing. The Joint Venture Group budgeted a project to utilize natural gas from the An Naeem pool to maintain reservoir pressure in the An Nagyah pool and to enhance oil recovery. The proposed project (subject to Ministry approval), includes the extraction of stabilized condensate (natural gas liquids or NGL's) from both the An Naeem gas and the An Nagyah solution gas currently being injected. It is expected that condensate extracted from the injection gas will contribute 600 to 1,000 Bpd to production in late 2007/early 2008. In addition, the operator is currently evaluating a cycling scheme to produce additional gas liquids from the An Naeem pool in conjunction with the neighboring Block 20. If the cycling project is recommended and approved this fall, it is expected that production could commence in late 2008.
Quarterly 2006 An Nagyah Production (Bopd)
Q-1 Q-2 Q-3
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Gross field production rate 11,000 10,636 10,048
TransGlobe working interest 2,750 2,659 2,512
TransGlobe net (after royalties) 1,631 1,467 1,735
TransGlobe net (after royalties
and tax)(1) 1,423 1,266 1,546
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(1) Under the terms of the Block S-1 PSA royalties and taxes are paid out
of the government's share of production sharing oil
Block 32, Republic of Yemen (13.81087% working interest) Operations and Exploration Two oil wells were drilled during the third quarter at Tasour #22ST and Godah #3. The Tasour #22ST well encountered oil bearing upper Qishn S-1A, S-1B and S-1C sands in a crestal position on the eastern edge of the Tasour field. The well was completed and placed on production as a Qishn S-1A oil producer with an initial production rate of 6,440 Bpd of oil and 2,766 Bpd of water (889 barrels of oil to TransGlobe). The production rate was later increased to 8,000 Bopd. The Tasour #22ST was side tracked to its current position following a Sarr/Qishn test offsetting Tasour #21 on the southeastern portion of the field. A test of the Qishn formation confirmed that the southeastern area of Tasour is in communication with the existing producers in the field and is being effectively drained. The Sarr prospect was not successful. The Godah #3 appraisal well is located approximately 1,100 meters to the west/southwest of Godah #1. Godah #3 was production tested from a five meter interval at a stabilized rate of 1,511 barrels of oil per day and 122 thousand cubic feet per day of gas (maximum test pump capacity). The well was suspended as an oil producer and will be placed on production during the fourth quarter of 2006. The Godah #4 well, located approximately 3 kms east/northeast of Godah #1 (1 km north/northeast of Godah #2) was drilled to a total depth of 1,771 m. The well encountered the S-1A reservoir 19 meters structurally lower than Godah #2, below the oil/water contact for the Godah field. The well was cased and suspended as a potential water injector. The drilling rig will be moved to Tasour #24, a development well on the western area of the Tasour field. A second, larger, drilling rig commenced drilling an exploration well at Tasour #23 on September 5. Tasour #23 is targeting a fractured basement prospect south of the Tasour field. Drilling and evaluation of Tasour #23 is expected to be completed in November. A 275 square kilometer 3-D seismic acquisition program commenced in September 2006. The 3-D seismic program consists of two parts. The first part of the program will cover the Godah field and extend to the eastern boundary of Block 32 (210 square kilometers). A second part will cover an area northwest of Tasour (65 square kilometers). The new 3-D seismic should assist in the development of the Godah field and in the exploration drilling planned for the eastern portion of Block 32 and northwest of Tasour. Production The Tasour field averaged 10,673 Bopd (1,474 Bopd to TransGlobe) during the third quarter of 2006, an increase of 25% over the previous quarter. The increase is attributed to the Tasour 22ST Qishn oil well, which commenced production on August 29. The Tasour field averaged 15,500 Bopd (2,142 Bopd to TransGlobe) in September. It is expected that production from the Tasour field will average approximately 12,000 Bopd for the balance of 2006. During the third quarter, production equipment was installed to produce Godah #2 and #3. Godah #2 commenced production on October 27 and is producing at an initial pumping rate of 998 Bpd of oil (138 Bpd of oil to TransGlobe). Production from Godah #3 is expected to commence during the next week. The Godah production facility is pipeline connected to the existing oil sales export line which passes through the Godah Field. Produced water will be trucked to the Tasour Central Production Facility ("CPF") for treatment and disposal until the first quarter of 2007 when a 23 km pipeline to the Tasour CPF should be operational. It is expected that the Godah field will be fully developed over the next two years.
Quarterly 2006 Tasour Production (Bopd)
Q-1 Q-2 Q-3
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Gross field production rate 9,427 8,522 10,673
TransGlobe working interest 1,302 1,177 1,474
TransGlobe net (after royalties) 982 675 766
TransGlobe net (after royalties
and tax)(1) 874 508 532
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(1) Under the terms of the Block 32 PSA royalties and taxes are paid out of
the government's share of production sharing oil
Block 72, Republic of Yemen (33% working interest) The 255 km of new 2-D seismic data acquired at the end of 2005 has been processed, along with 500 km of existing 2-D seismic data. Interpretation and mapping is completed. The first of two exploration wells is scheduled to commence drilling in December of 2006. Nuqra Block 1, Arab Republic of Egypt (50% working interest, Operator) Processing and interpretation of the 800 km of 2-D seismic data acquired during the first quarter of 2006 is now completed. Two firm wells (Narmer #1 and Set #1) and one optional well (West Narmer #1) have been approved by the Joint Venture Partners and the government. All three proposed wells are in the Nuqra sub basin in the central part of the Nuqra Block. The Company has located a suitable drilling rig and is currently in the process of preparing the necessary contracts and receiving government approvals. It is expected that the rig will be available to commence drilling in the first quarter of 2007. The Company elected to proceed with the first three year extension to the exploration period, effective July 18, 2006. This extension requires a mandatory relinquishment of 25% of the Block and completion of a two well drilling program, with a minimum expenditure of $4.0 million over a period of three years. The Company has received approval of the first exploration extension and the proposed area for relinquishment. The area relinquished was considered non-prospective by the Company. The total area of the Nuqra Block 1 concession is approximately 5.5 million acres following the relinquishment. In addition, TransGlobe has fulfilled the original $6 million farm-in commitment (100%) and will pay 60% of future program expenditures until first production. Upon expiry of the first three year extension (July 17, 2009), there is an option to proceed with a second three year extension and work program. The second exploration extension requires a mandatory relinquishment of 25% of the original Block and completion of a two well drilling program, with a minimum expenditure of $5.0 million over a final three year term. Exploitation of discovered commercial fields will continue under a Development Lease for a further 20 years. Canada Operations and Exploration The primary focus for the third quarter was the completion, testing and tie-in of wells drilled in the first half of the year and preparations for the Nevis coal bed methane ("CBM") drilling program. Work was hampered by unseasonably wet conditions in the Nevis and Morningside areas. During the third quarter, no new wells were drilled in Canada. Subsequent to the quarter, the Company drilled 10 (9.1 net) Horseshoe Canyon CBM wells in the Nevis area. Completion, equipping and pipeline work is underway on the Nevis CBM program, with production expected to commence during November. The Company has participated in 16 (11.7 net) wells to the end of September 2006, resulting in 5 oil wells, 10 gas wells and 1 dry hole. The 10 Horseshoe Canyon CBM wells drilled during October brings the Canadian well count to 26 (20.8 net) wells. The Company acquired an additional 9,600 net acres of Crown mineral rights in central Alberta during the quarter. Production Production averaged 966 Boepd during the third quarter of 2006. Production during the quarter was curtailed due to continued restrictions on the TransCanada pipeline system associated with system maintenance and an unscheduled two week shut-in of a third party operated gas facility in the Nevis area. Approximately 450 Boepd of natural gas production in the Nevis area was shut-in from September 21 to late October in response to low natural gas prices. This short term reduction resulted in higher net returns when prices returned to the anticipated C$5 to C$6/Mcf level. In mid-September a new compressor at Nevis was commissioned which added an incremental 200-300 Boepd of production from existing producers and provides additional capacity for the CBM production. One gas well at Morningside and the solution gas from four oil wells at Nevis were pipeline connected during late September. The wells were placed on production throughout October, although wet conditions have limited the ability to truck oil in the Nevis area. The Company is targeting to exit the year at 2,000+ Boepd in Canada.
Quarterly 2006 Canadian Production (Boepd)
Q-1 Q-2 Q-3
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TransGlobe working interest 975 1,079 966
TransGlobe net (after royalties) 798 910 808
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MANAGEMENT'S DISCUSSION AND ANALYSIS October 27, 2006 Management's discussion and analysis ("MD&A") should be read in conjunction with the unaudited interim financial statements for the three and nine months ended September 30, 2006 and 2005, the audited financial statements and MD&A for the year ended December 31, 2005 included in the Company's annual report. The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in Canada in the currency of the United States (except where indicated as being another currency). Additional information relating to the Company, including the Company's Annual Information Form, is on SEDAR at www.sedar.com. Forward Looking Statements This MD&A may include certain statements that may be deemed to be "forward-looking statements" within the meaning of the U.S. Private Securities Litigation Reform Act of 1995. All statements in this interim report, other than statements of historical facts, that address future production, reserve potential, exploration drilling, exploitation activities and events or developments that the Company expects, are forward-looking statements. Although TransGlobe believes the expectations expressed in such forward-looking statements are based on reasonable assumptions, such statements are not guarantees of future performance and actual results or developments may differ materially from those in the forward-looking statements. Factors that could cause actual results to differ materially from those in forward-looking statements include, but are not limited to, oil and gas prices, well production performance, exploitation and exploration successes, continued availability of capital and financing, and general economic, market or business conditions. Non-GAAP Measures This document contains the term "cash flow from operations", which should not be considered an alternative to, or more meaningful than "cash flow from operation activities" as determined in accordance with Generally Accepted Accounting Principles (GAAP). Cash flow from operations is a non-GAAP measure that represents cash generated from operating activities before changes in non-cash working capital. We consider this a key measure as it demonstrates our ability to generate the cash flow necessary to fund future growth through capital investment. Cash flow from operations may not be comparable to similar measures used by other companies. Net operating income is a non-GAAP measure that represents revenue net of royalties and operating expenses. Management believes that net operating income is a useful supplemental measure to analyse operating performance and provide an indication of the results generated by the Company's principal business activities prior to the consideration of other income and expenses. Net operating income may not be comparable to similar measures used by other companies. Use of Boe Equivalents The calculations of barrels of oil equivalent ("Boe") are based on a conversion rate of six thousand cubic feet of natural gas to one barrel of crude oil. Boe may be misleading, particularly if used in isolation. A Boe conversion ratio of 6 Mcf:1 Bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. OUTLOOK TransGlobe has projected a 2006 capital budget of $54 million, which increased from the original budget of $45.3 million due to additional seismic and facility work planned for Block S-1 and the Godah development on Block 32. - In the first nine months of 2006, the Company spent $35.8 million of the capital budget. Production increases in the fourth quarter are expected from the start-up of the Godah field on Block 32, Yemen and from Canada when pipeline connections for new wells are completed. The anticipated production increases should result in a 2006 average production rate of approximately 5,200 to 5,300 boepd. This is down slightly from the estimate at the start of 2006 (5,300 to 5,600 Boepd) due to delays in pipeline connections for Canadian wells and due to the shut-in of some Canadian production because of low gas prices. The December average production rate ("exit rate") is expected to be over 6,000 Boepd with the additions from Godah wells, the restart of production from the shut-in Canadian wells and the tie-in of new Canadian CBM wells. - Production volumes averaged 4,964 Boepd in the first nine months of 2006. At the start of 2006 TransGlobe projected cash flow from operations for 2006 to be between $43 and $45 million based on an average dated Brent oil price of $55.00/Bbl and an average AECO gas price of C$7.50/Mcf. The Company expects to exceed this target (projected at $47 to $49 million) due to high oil prices experienced in the first ten months of 2006. The gas price realized in the first ten months of 2006 was lower than TransGlobe's budgeted number of C$7.50. However, natural gas production represents only 14% of the Company's total production. - Cash flow from operations in the first nine months of 2006 was $36.3 million.
SELECTED QUARTERLY FINANCIAL INFORMATION
2006 2005
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($000's, except per share,
price and volume amounts) Q-3 Q-2 Q-1 Q-4 Q-3
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Average production volumes (Boepd)(1) 4,952 4,915 5,026 5,132 5,285
Average sales volumes (Boepd)(1) 4,952 5,522 4,515 4,935 5,533
Average price ($/Boe) 61.88 62.17 55.93 54.58 56.57
Oil and gas sales 28,190 31,238 22,730 24,781 28,796
Oil and gas sales, net of royalties 18,542 18,600 15,308 14,442 19,147
Cash flow from operations(2) 12,662 12,356 11,297 8,603 13,142
Cash flow from operations per share
- Basic 0.22 0.21 0.19 0.15 0.23
- Diluted 0.21 0.20 0.19 0.14 0.22
Net income 7,366 7,246 6,857 4,331 7,539
Net income per share
- Basic 0.13 0.12 0.12 0.07 0.13
- Diluted 0.12 0.12 0.11 0.07 0.13
Total assets 110,883 105,816 92,596 86,286 77,576
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(1) The differences in production and sales volumes result from inventory
changes at Block S-1, Yemen
(2) Cash flow from operations is a non-GAAP measure that represents cash
generated from operating activities before changes in non-cash working
capital
In Q2-2006 the Company entered into a new marketing contract with Occidental Petroleum Corporation. All of the Company's Block S-1 oil inventory was sold during May 2006, resulting in higher sales volumes for Q2-2006. As expected and consistent with prior years, royalties at Block 32, Yemen decreased to 25% in Q1-2006 resulting in an increased cash flow from operations for Block 32. The Block 32 Production Sharing Agreement ("PSA") allows for the recovery of capital costs over a two year period with 50% recovered in the quarter expended and the remaining 50% recovered in the first quarter of the following calendar year through reduced royalties and taxes paid to the government. Cash flow from operations and net income increased 2% to $12,662,000 and 2% to $7,366,000, respectively, in Q3-2006 compared to Q2-2006 mainly as a result of: - a reduction in royalties on Block S-1, Yemen, offset by a 10% decrease in sales volumes due to all the inventory at Block S-1 being sold in Q2-2006. RESULTS OF OPERATIONS Cash flow from operations decreased by 4% in Q3-2006 compared to Q3-2005 mainly as a result of a 10% decrease in sales volumes.
Cash Flow From Operations Analysis
$ Per Share %
$ 000's Diluted Variance
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Q3-2005 Cash flow from operations (1) 13,142 0.22 -
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Volume variance (3,166) (0.05) (24)
Price variance 2,561 0.04 19
Royalties - - -
Expenses:
Operating 25 - -
Cash general and administrative (56) - -
Current income taxes 9 - -
Realized foreign exchange gain (loss) 67 - -
Settlement of asset retirement
obligations (1) - -
Other 81 - 1
Change in weighted average number of
diluted shares outstanding - - -
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Q3-2006 Cash flow from operations(1) 12,662 0.21 (4)
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(1) Cash flow from operations is a non-GAAP measure that represents cash
generated from operating activities before changes in non-cash working
capital
Net income decreased 2% in Q3-2006 compared to Q3-2005 mainly as a result of
the above decreases in cash flow from operations.
OPERATING RESULTS
Daily Volumes, Working Interest
Before Royalties
Three Months Ended Nine Months Ended
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September 30 September 30
2006 2005 2006 2005
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Yemen - Oil production Bopd 3,986 4,210 3,958 4,076
- Inventory change Bopd - 248 33 22
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Yemen - Oil sales Bopd 3,986 4,458 3,991 4,098
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Canada - Oil and liquids Bopd 304 284 305 215
- Gas sales Mcfpd 3,975 4,749 4,213 3,917
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Canada Boepd 966 1,076 1,007 868
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Total sales Boepd 4,952 5,533 4,998 4,966
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Consolidated Net Operating Results
Consolidated
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Nine Months Ended Nine Months Ended
September 30, 2006 September 30, 2005
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($000's, except per Boe amounts) $ $/Boe $ $/Boe
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Oil and gas sales 82,159 60.21 65,570 48.36
Royalties 29,709 21.77 21,101 15.56
Operating expenses 7,388 5.41 7,608 5.61
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Net operating income(1) 45,062 33.03 36,861 27.19
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Consolidated
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Three Months Ended Three Months Ended
September 30, 2006 September 30, 2005
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($000's, except per Boe amounts) $ $/Boe $ $/Boe
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Oil and gas sales 28,190 61.88 28,796 56.57
Royalties 9,648 21.17 9,649 18.96
Operating expenses 2,761 6.06 2,786 5.47
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Net operating income(1) 15,781 34.65 16,361 32.14
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(1) Net operating income amounts do not reflect Yemen income tax expense
which is paid through oil allocations with the Ministry of Oil and
Minerals ("MOM") in the Republic of Yemen (Q3-2006 - $2,598,000,
$5.70/Boe, Q3-2005 - $2,607,000, $5.12/Boe), (Q1, Q2 and Q3-2006 -
$6,618,000, $4.85/Boe, Q1, Q2 and Q3-2005 - $5,673,000, $4.18/Boe).
Segmented Net Operating Results In 2006 the Company operated in two geographic areas, segmented as the Republic of Yemen and Canada. Also, the Company has start-up operations in a third geographic segment, Arab Republic of Egypt. MD&A will follow under each of these segments.
Republic of Yemen
Nine Months Ended Nine Months Ended
September 30, 2006 September 30, 2005
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($000's, except per Boe amounts) $ $/Boe $ $/Boe
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Oil sales 70,639 64.83 55,938 50.00
Royalties 27,788 25.50 19,464 17.40
Operating expenses 5,252 4.82 6,067 5.42
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Net operating income(1) 37,599 34.51 30,407 27.18
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Three Months Ended Three Months Ended
September 30, 2006 September 30, 2005
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($000's, except per Boe amounts) $ $/Boe $ $/Boe
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Oil sales 24,525 66.88 24,329 59.32
Royalties 9,052 24.68 8,866 21.62
Operating expenses 2,078 5.67 2,115 5.15
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Net operating income(1) 13,395 36.53 13,348 32.55
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(1) Net operating income amounts do not reflect Yemen income tax expense
which is paid through oil allocations with MOM in the Republic of Yemen
(Q3-2006 - $2,598,000, $7.09/Boe; Q3-2005 - 2,607,000, $6.36/Boe),
(Q1, Q2 and Q3-2006 - $6,618,000, $6.07/Boe; Q1, Q2 and Q3-2005 -
$5,673,000, $5.07/Boe).
Net operating income in Yemen increased 24% in the first nine months of
2006 compared to the same period of 2005 primarily as a result of the
following:
- Oil sales increased 26% mainly as a result of the following:
1. Oil prices increased by 30%.
2. Sales volumes decreased 3% in the first nine months of 2006 primarily
as a result of production decreases on Block 32 due to natural
declines and CPF fluid handling and facility constraints offset by
increases at Block S-1.
Nine Months Nine Months
Ended Ended
Daily Volumes, Working Interest September 30, September 30,
Before Royalties 2006 2005 %
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Bopd Bopd Change
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Block S-1 - production 2,640 2,037 30
- inventory change 33 22 50
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Block S-1 - sales 2,673 2,059 30
Block 32 - sales 1,318 2,039 (35)
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Total sales 3,991 4,098 3
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Three Months Three Months
Ended Ended
Daily Volumes, Working Interest September 30, September 30,
Before Royalties 2006 2005 %
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Bopd Bopd Change
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Block S-1 - production 2,512 2,235 12
- inventory change - 248 -
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Block S-1 - sales 2,512 2,483 1
Block 32 - sales 1,474 1,975 (25)
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Total sales 3,986 4,458 (11)
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- Royalty costs increased 43% in the first nine months of 2006 compared to the same period of 2005. Royalties as a percentage of revenue (royalty rate) increased to 39% in the first nine months of 2006 compared to 35% in the first nine months of 2005. This was a result of an increase in Block S-1 royalty rate due to recovery of the Company's historical exploration cost pools at the end of Q3-2005. Royalty rates fluctuate in Yemen due to changes in the amount of cost sharing oil, whereby the Block 32 and Block S-1 PSA's allow for the recovery of operating and capital costs through a reduction in the MOM share of oil production. - Operating expenses on a Boe basis decreased 11% in the first nine months of 2006 compared to the same period of 2005 mainly as a result of the following: 1. Block 32 operating expenses averaged $4.48 per barrel in the first nine months of 2006 compared to $5.32 per barrel in the first nine months of 2005 primarily due to decreased diesel costs. A diesel topping plant was constructed in 2005 to manufacture diesel from produced crude oil which reduced diesel costs significantly on a go forward basis. The plant became operational in December 2005. 2. Block S-1 operating costs averaged $4.99 per barrel in the first nine months of 2006 compared to $5.58 per barrel in the first nine months of 2005. This reduction is a reflection of increased production volumes and commissioning of the pipeline in June 2005.
Canada
Nine Months Ended Nine Months Ended
September 30, 2006 September 30, 2005
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($000's, except per Boe amounts) $ $/Boe $ $/Boe
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Oil sales 2,174 61.47 1,411 51.16
Gas sales ($ per Mcf) 6,847 5.95 7,001 6.55
NGL sales 2,439 51.14 1,170 37.60
Other sales 60 - 50 -
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11,520 41.92 9,632 40.65
Royalties 1,921 6.99 1,637 6.91
Operating expense 2,136 7.77 1,541 6.50
---------------------------------------------------------------------------
Net operating income 7,463 27.16 6,454 27.24
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Three Months Ended Three Months Ended
September 30, 2006 September 30, 2005
---------------------------------------------------------------------------
($000's, except per Boe amounts) $ $/Boe $ $/Boe
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Oil sales 821 65.66 588 59.38
Gas sales ($ per Mcf) 1,966 5.38 3,213 7.35
NGL sales 859 55.66 643 39.78
Other sales 19 - 23 -
---------------------------------------------------------------------------
3,665 41.23 4,467 45.17
Royalties 596 6.70 783 7.92
Operating expense 683 7.69 672 6.79
---------------------------------------------------------------------------
Net operating income 2,386 26.84 3,012 30.46
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Net operating income in Canada increased 16% in the nine months ended September 30, 2006 compared to the same period of 2005 primarily as a result of the following: - Sales increased 20% mainly as a result of the following: 1. Sales volumes increased 16% as a direct result of successful drilling in 2005. 2. Commodity prices increased 3% on a Boe basis. - Royalty costs increased 1% on a Boe basis. Royalties as a percent of revenue were consistent at 17% in the nine months ended September 30, 2006 compared to the same period of 2005. During the third quarter, the Alberta Government announced it is discontinuing the Alberta Royalty Tax Credit program effective January 1, 2007. As a result, the Company's royalties will be increased by C$500,000 in 2007. - Operating costs increased 20% on a Boe basis mainly as a result of three well workovers at Nevis and overall general increases to all services due to a very competitive oil and gas environment in Canada. COMMODITY CONTRACTS TransGlobe uses hedge arrangements as part of its risk management approach to manage commodity price fluctuations and stabilize cash flows for future exploration and development programs. During the third quarter 2005 the Company entered into a crude oil costless collar for 15,000 barrels per month from January 1, 2006 to December 31, 2006. The transaction consisted of the purchase of a $50.00 per barrel dated Brent put (floor) and a $77.93 per barrel dated Brent call (ceiling). Pursuant to Canadian generally accepted accounting principles, the Company has fair valued these hedge transactions. As at September 30, 2006, the estimated fair value of the unrealized hedge transactions is a liability of $2,000, which results in an unrealized $85,000 loss being recorded to the income statement for the first nine months of 2006. The Company will only incur realized gains or losses on these hedge transactions when the dated Brent monthly average oil price is below $50 per barrel or above $77.93 per barrel during the calendar year of 2006, or if the Company sells the contract.
GENERAL AND ADMINISTRATIVE EXPENSES ("G&A")
Nine Months Ended Nine Months Ended
September 30, 2006 September 30, 2005
---------------------------------------------------------------------------
($000's, except Boe amounts) $ $/Boe $ $/Boe
---------------------------------------------------------------------------
---------------------------------------------------------------------------
G&A (gross) 4,218 3.09 3,303 2.44
Capitalized G&A (1,569) (1.15) (1,272) (0.94)
Overhead recoveries (277) (0.20) (120) (0.09)
---------------------------------------------------------------------------
G&A (net) 2,372 1.74 1,911 1.41
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Three Months Ended Three Months Ended
September 30, 2006 September 30, 2005
---------------------------------------------------------------------------
($000's, except Boe amounts) $ $/Boe $ $/Boe
---------------------------------------------------------------------------
---------------------------------------------------------------------------
G&A (gross) 1,291 2.83 1,093 2.14
Capitalized G&A (507) (1.11) (398) (0.78)
Overhead recoveries (119) (0.26) (42) (0.08)
---------------------------------------------------------------------------
G&A (net) 665 1.46 653 1.28
---------------------------------------------------------------------------
---------------------------------------------------------------------------
General and administrative expenses increased 24% (23% increase on a sales Boe basis) in the first nine months of 2006 compared to the same period of 2005 as a result of the following: - Personnel and office overhead costs increased due to additional staff. - Public company costs increased mainly due to the Company preparing for the new Sarbanes Oxley compliance requirements. - Capitalized general and administrative expenses increased mainly as a result of expansion in the Egypt operations and overhead recoveries increased due to the increased capital activity in Canada. - The strengthening of the Canadian dollar against the United States dollar increased net G&A costs by $0.09 per Boe through currency conversion. STOCK-BASED COMPENSATION The Company records a compensation expense over the vesting period based on the fair value of options granted to employees and directors. Non-cash stock-based compensation expense amounted to $912,000 in the first nine months of 2006 compared to $578,000 in the same period of 2005.
DEPLETION, DEPRECIATION AND ACCRETION EXPENSE ("DD&A")
Nine Months Ended Nine Months Ended
September 30, 2006 September 30, 2005
---------------------------------------------------------------------------
($000's, except per Boe amounts) $ $/Boe $ $/Boe
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Republic of Yemen 8,338 7.65 10,326 9.34
Canada 5,208 18.95 2,564 10.82
Arab Republic of Egypt 25 - 3 -
---------------------------------------------------------------------------
13,571 9.95 12,893 9.51
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Three Months Ended Three Months Ended
September 30, 2006 September 30, 2005
---------------------------------------------------------------------------
($000's, except per Boe amounts) $ $/Boe $ $/Boe
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Republic of Yemen 3,060 8.34 3,998 9.92
Canada 1,831 20.60 1,190 12.03
Arab Republic of Egypt 12 - 2 -
---------------------------------------------------------------------------
4,903 10.76 5,190 10.20
---------------------------------------------------------------------------
---------------------------------------------------------------------------
In Yemen, DD&A on a Boe basis decreased 18% in the first nine months of 2006 compared to the same period of 2005 primarily as a result of decreased finding and development costs in Yemen. In Yemen (Block 72) and Egypt (Nuqra Block 1) unproven property costs of $2,218,000 and $6,732,000 respectively, were excluded from costs subject to depletion and depreciation in Q3-2006. In Canada, DD&A on a Boe basis increased 75% in the first nine months of 2006 compared to the same period of 2005 primarily as a result of increased finding and development costs in Canada.
INCOME TAXES
Nine Months Ended Nine Months Ended
($000's) September 30, 2006 September 30, 2005
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Current income tax 6,618 5,673
Future income tax 201 57
---------------------------------------------------------------------------
6,819 5,730
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Current income tax expense in the first nine months of 2006 of $6,618,000 and $5,673,000 in the comparable period of 2005 represents income tax incurred and paid under the laws of Yemen pursuant to the PSA on Block 32 and Block S-1. The increase in current tax is primarily the result of increased sales revenue in Yemen. The income tax expense in Yemen as a percent of revenue was 9% in the first nine months of 2006 compared to 10% in the same period of 2005. No income tax was paid in Canada during 2005 or 2006. The future income tax expense was $201,000 in the first nine months of 2006 and $57,000 in the comparable period of 2005. These relate to a non-cash expense for tax to be incurred in the future as Canadian tax pools reverse.
CAPTITAL EXPENDITURES/DISPOSITIONS
Capital Expenditures
Nine Months Ended
---------------------------------------------------------------------------
Sept. 30,
Sept. 30, 2006 2005
---------------------------------------------------------------------------
Geological Drilling Facilities
Land and and Geo- and and
($000's) Acquisition physical Completions Pipelines Other Total Total
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Republic
of Yemen
Block S-1 - 19 6,320 4,808 165 11,312 9,772
Block 32 - - 3,842 244 30 4,116 3,740
Block 72 - 418 251 - 70 739 572
---------------------------------------------------------------------------
- 437 10,413 5,052 265 16,167 14,084
Canada 1,505 176 8,497 4,905 343 15,426 7,854
Arab Republic
of Egypt - 3,108 191 - 946 4,245 1,162
---------------------------------------------------------------------------
1,505 3,721 19,101 9,957 1,554 35,838 23,100
---------------------------------------------------------------------------
---------------------------------------------------------------------------
On Block S-1 in Yemen, the Company drilled 5 wells (An Nagyah #19, #20, #21 and #22, Wadi Bayhan #2) and continued working on CPF construction and expansion. On Block 32, the Company drilled 5 wells (Godah #1, #2, #3, Tasour #21 and #22). On Block 72, the Company continued to define drilling leads through seismic acquisition and processing. In Canada, the Company drilled 16 wells (11.7 net) mainly in the Nevis, Morningside and Thorsby areas. Also, the Company carried out completion and testing work on 10 wells, tied-in 6 wells and added compression equipment, mainly in the Nevis area. In Egypt, the Company completed the field seismic acquisition on Nuqra Block 1 on April 5, 2006. The processing of seismic was completed in July. Interpretation and mapping of the seismic were completed and drilling locations were selected. OUTSTANDING SHARE DATA Common shares issued and outstanding as at September 30, 2006 are 58,682,439. LIQUIDITY AND CAPITAL RESOURCES Liquidity describes a company's ability to access cash. Companies operating in the upstream oil and gas industry require sufficient cash in order to fund capital programs necessary to maintain and increase production and proved reserves, to acquire strategic oil and gas assets and repay debt. TransGlobe's capital programs are funded principally by cash provided from operating activities. The following table illustrates TransGlobe's sources and uses of cash during the periods ended September 30, 2006 and 2005:
Sources and Uses of Cash
Nine Months Ended September 30
--------------------------------
($000's) 2006 2005
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Cash sourced
Cash flow from operations(1) 36,315 29,474
Issue of common shares 209 1,015
---------------------------------------------------------------------------
36,524 30,489
Cash used
Exploration and development expenditures 35,838 23,100
Other 506 48
---------------------------------------------------------------------------
36,344 23,148
---------------------------------------------------------------------------
Net cash 180 7,341
Decrease in non-cash working capital (2,717) (1,873)
---------------------------------------------------------------------------
Increase (decrease) in cash and cash equivalents (2,537) 5,468
Cash and cash equivalents - beginning of period 12,221 4,988
---------------------------------------------------------------------------
Cash and cash equivalents - end of period 9,684 10,456
---------------------------------------------------------------------------
---------------------------------------------------------------------------
(1) Cash flow from operations is a non-GAAP measure that represents cash
generated from operating activities before changes in non-cash
working capital
Funding for the Company's capital expenditures in the third quarter of 2006 was provided by cash flow from operations and working capital. Working capital is the amount by which current assets exceed current liabilities. At September 30, 2006 the Company had working capital of $9,293,000, zero debt and an unutilized loan facility of $25,000,000. Accounts receivable increased primarily due to two months of revenue receivable for Block S-1 at September 2006 compared to one month's revenue receivable at December 2005. There was no inventory at September 30, 2006 since all Block S-1 production had been sold. Accounts payable were consistent with 2005. The Company expects to fund its approved 2006 exploration and development program of $54 million ($36 million incurred to September 30, 2006) through the use of working capital and cash flow. The use of credit facilities or equity financing during 2006 are expected to be utilized only to accelerate existing projects or to finance new opportunities. Fluctuations in commodity prices, product demand, foreign exchange rates, interest rates and various other risks may impact capital resources. COMMITMENTS AND CONTINGENCIES As part of its normal business, the Company entered into arrangements and incurred obligations that will impact the Company's future operations and liquidity. The principal commitments of the Company are as follows:
Three Twelve Months
Months -------------------------------------
($000's) 2006 2007 2008 2009 2010
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Office and equipment leases 81 288 397 420 414
---------------------------------------------------------------------------
---------------------------------------------------------------------------
In September 2005, the Company entered into a crude oil costless collar for 15,000 barrels per month from January 1, 2006 to December 31, 2006. The transaction consisted of the purchase of a $50.00 per barrel dated Brent put (floor) and a $77.93 per barrel dated Brent call (ceiling). Upon the determination that proved recoverable reserves are 40 million barrels or greater for Block S-1, Yemen, the Company will be required to pay a finders' fee to third parties in the amount of $281,000. Pursuant to the Company's farm-in agreement on the Nuqra Concession in Egypt, the Company is committed to spend $6 million before July 1, 2009 to earn its 50% working interest. As at September 30, 2006, the Company has met this commitment. During the quarter the Company entered into the first three year extension period which requires the completion of a two well drilling program with a minimum expenditure of $4.0 million over a period of three years. As part of this extension, the Company issued a $4.0 million letter of credit (expiring March 4, 2010) to guarantee the Company's performance under the extension period. This letter of credit is secured by a guarantee granted by Export Development Canada in the amount of $2.4 million representing the Company's share of the $4 million. Pursuant to the PSA for Block 72, Yemen, the Contractor (Joint Venture Partners) has a minimum financial commitment of $4 million ($1.32 million to TransGlobe) during the first exploration period of 30 months (expiring January 12, 2008) for exploration work consisting of seismic acquisition (completed) and two exploration wells (planned for Q4-2006 and Q1-2007).
Consolidated Statements of Income and Retained Earnings (Deficit)
(Unaudited - Expressed in thousands of U.S. Dollars)
Three Months Ended Nine Months Ended
September 30 September 30
2006 2005 2006 2005
---------------------------------------------------------------------------
---------------------------------------------------------------------------
REVENUE
Oil and gas sales,
net of royalties $ 18,542 $ 19,147 $ 52,450 $ 44,469
Unrealized gain (loss)
on commodity contracts
(Note 6) 132 (211) (85) (211)
Other income 84 3 208 12
---------------------------------------------------------------------------
18,758 18,939 52,573 44,270
---------------------------------------------------------------------------
EXPENSES
Operating 2,761 2,786 7,388 7,608
General and administrative 665 653 2,372 1,911
Stock-based compensation 324 128 912 578
Foreign exchange (gain) loss (30) 37 42 31
Depletion, depreciation and
accretion 4,903 5,190 13,571 12,893
---------------------------------------------------------------------------
8,623 8,794 24,285 23,021
---------------------------------------------------------------------------
Income before income taxes 10,135 10,145 28,288 21,249
---------------------------------------------------------------------------
Income taxes - current 2,598 2,607 6,618 5,673
- future 171 (1) 201 57
---------------------------------------------------------------------------
2,769 2,606 6,819 5,730
---------------------------------------------------------------------------
NET INCOME 7,366 7,539 21,469 15,519
Retained earnings
(deficit), beginning
of period 33,268 7,295 19,165 (685)
---------------------------------------------------------------------------
RETAINED EARNINGS,
END OF PERIOD $ 40,634 $ 14,834 $ 40,634 $ 14,834
---------------------------------------------------------------------------
Net income per share (Note 5)
- Basic $ 0.13 $ 0.13 $ 0.37 $ 0.27
- Diluted $ 0.12 $ 0.13 $ 0.35 $ 0.26
---------------------------------------------------------------------------
---------------------------------------------------------------------------
See accompanying notes to these consolidated financial statements
Consolidated Balance Sheets
(Unaudited - Expressed in thousands of U.S. Dollars)
September 30, 2006 December 31, 2005
---------------------------------------------------------------------------
---------------------------------------------------------------------------
ASSETS
Current
Cash and cash equivalents $ 9,684 $ 12,221
Accounts receivable 10,256 7,414
Oil inventory - 436
Prepaid expenses 550 463
Unrealized commodity contracts (Note 6) - 83
---------------------------------------------------------------------------
20,490 20,617
---------------------------------------------------------------------------
Property and equipment
Republic of Yemen 39,175 30,898
Canada 42,320 30,261
Arab Republic of Egypt 6,732 2,512
---------------------------------------------------------------------------
88,227 63,671
Future income tax assets 1,759 1,886
Deferred financing costs (Note 7) 407 112
---------------------------------------------------------------------------
$ 110,883 $ 86,286
---------------------------------------------------------------------------
---------------------------------------------------------------------------
LIABILITIES
Current
Accounts payable and accrued
liabilities $ 11,195 $ 11,146
Unrealized commodity contracts
(Note 6) 2 -
---------------------------------------------------------------------------
11,197 11,146
Asset retirement obligations (Note 3) 1,974 1,503
---------------------------------------------------------------------------
13,171 12,649
---------------------------------------------------------------------------
Commitments and Contingencies (Note 8)
SHAREHOLDERS' EQUITY
Share capital (Note 4) 49,234 48,922
Contributed surplus 2,660 1,908
Cumulative translation adjustment 5,184 3,642
Retained earnings 40,634 19,165
---------------------------------------------------------------------------
97,712 73,637
---------------------------------------------------------------------------
$ 110,883 $ 86,286
---------------------------------------------------------------------------
---------------------------------------------------------------------------
See accompanying notes to these consolidated financial statements
Consolidated Statements of Cash Flows
(Unaudited - Expressed in thousands of U.S. Dollars)
Three Months Ended Nine Months Ended
September 30 September 30
2006 2005 2006 2005
---------------------------------------------------------------------------
---------------------------------------------------------------------------
CASH FLOWS RELATED TO THE
FOLLOWING ACTIVITIES:
OPERATING
Net income $ 7,366 $ 7,539 $ 21,469 $ 15,519
Adjustments for:
Depletion, depreciation
and accretion 4,903 5,190 13,571 12,893
Stock-based compensation 324 128 912 578
Future income taxes 171 (1) 201 57
Amortization of deferred
financing costs 31 75 143 216
Unrealized hedging (gain)
loss (Note 6) (132) 211 85 211
Settlement of asset retirement
obligations (1) - (66) -
Changes in non-cash working
capital (3,654) (568) (1,655) 1,226
---------------------------------------------------------------------------
9,008 12,574 34,660 30,700
---------------------------------------------------------------------------
FINANCING
Issue of common shares for cash - 301 209 1,015
Deferred financing costs (438) (15) (438) (17)
Changes in non-cash working
capital 169 - 169 (24)
---------------------------------------------------------------------------
(269) 286 (60) 974
---------------------------------------------------------------------------
INVESTING
Exploration and development
expenditures:
Republic of Yemen (7,498) (7,410) (16,167) (14,084)
Canada (5,855) (3,047) (15,426) (7,854)
Arab Republic of Egypt (301) (398) (4,245) (1,162)
Changes in non-cash working
capital (2,041) 1,223 (1,231) (3,075)
---------------------------------------------------------------------------
(15,695) (9,632) (37,069) (26,175)
---------------------------------------------------------------------------
Effect of exchange rate changes
on cash and cash equivalents (38) (2) (68) (31)
---------------------------------------------------------------------------
NET (DECREASE) INCREASE IN CASH
AND CASH EQUIVALENTS (6,994) 3,226 (2,537) 5,468
CASH AND CASH EQUIVALENTS,
BEGINNING OF PERIOD 16,678 7,230 12,221 4,988
---------------------------------------------------------------------------
CASH AND CASH EQUIVALENTS,
END OF PERIOD $ 9,684 $10,456 $ 9,684 $ 10,456
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Supplemental Disclosure of
Cash Flow Information:
Cash interest paid $ - $ - $ - $ -
Cash taxes paid -
Republic of Yemen $ 2,598 $ 2,607 $ 6,618 $ 5,673
---------------------------------------------------------------------------
---------------------------------------------------------------------------
See accompanying notes to these consolidated financial statements
Notes to the Consolidated Financial Statements (Unaudited - Expressed in U.S. Dollars) 1. Basis of presentation The interim consolidated financial statements include the accounts of TransGlobe Energy Corporation and subsidiaries ("TransGlobe" or the "Company") for the three month and the nine month periods ended September 30, 2006 and 2005 and are presented in accordance with Canadian generally accepted accounting principles on the same basis as the audited consolidated financial statements as at and for the year ended December 31, 2005, except as outlined in Note 2. These interim consolidated financial statements should be read in conjunction with the consolidated financial statements and the notes thereto in TransGlobe's annual report for the year ended December 31, 2005. Interim results are not necessarily indicative of the results expected for the fiscal year. In these interim consolidated financial statements, unless otherwise indicated, all dollars are expressed in United States (U.S.) dollars. All references to US$ or to $ are U.S. dollars and references to C$ are to Canadian dollars. 2. Changes in accounting policies Non-monetary transactions Effective January 1, 2006, the Canadian Institute of Chartered Accountants (CICA) Section 3831 "Non-Monetary Transactions" was adopted by the Company which replaced Section 3830 of the same name. The standard, which harmonizes Canadian generally accepted accounting principles with the United States Financial Accounting Standards Board (FASB) Statement 153 Exchanges of Non-Monetary Assets, requires that all non-monetary transactions are measured based on fair value unless the transaction lacks commercial substance or is an exchange of product or property held for sale in the ordinary course of business. A transaction is determined to have commercial substance if it causes an identifiable and measurable change in the economic circumstances, or expected cash flows, of the entity. The guidance was effective for all non-monetary transactions initiated in periods beginning on or after January 1, 2006. Implicit variable interests Effective January 1, 2006, Emerging Issues Committee (EIC) Abstract 157 "Implicit Variable Interests" was adopted by the Company. The Abstract harmonizes Canadian generally accepted accounting principles with the United States FASB Staff Position (FSP) FIN 46®-5 Implicit Variable Interests. Implicit variable interests are implied financial interests in an entity and act the same as an explicit variable interest except they involve the absorbing and or receiving of variability indirectly from the entity rather than directly. The adoption of EIC Abstract 157 had no effect on the Company's consolidated financial statements. Conditional asset retirement obligations Effective April 1, 2006, EIC Abstract 159 "Accounting for Conditional Asset Retirement Obligations" was adopted by the Company. The Abstract, which is harmonized with the equivalent United States FASB Interpretation 47 (Accounting for Conditional Asset Retirement Obligations), clarifies the accounting for conditional asset retirement obligations where the timing or method of settlement are conditional on a future event that may or may not be within the control of the entity. Although these uncertainties affect the fair value of the liability, they do not relieve an entity from the requirement to record a liability, if it can be reasonably determined. The adoption of EIC Abstract 159 had no effect on the Company's consolidated financial statements. 3. Asset retirement obligations The following table presents the reconciliation of the beginning and ending obligations associated with the retirement of oil and gas properties:
(000's)
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Asset retirement obligations, December 31, 2005 $ 1,503
Liabilities incurred during period 383
Liabilities settled during period (66)
Accretion 88
Foreign exchange loss 66
---------------------------------------------------------------------------
Asset retirement obligations, September 30, 2006 1,974
---------------------------------------------------------------------------
---------------------------------------------------------------------------
At September 30, 2006, the estimated total undiscounted amount required to
settle the asset retirement obligations was $2,746,000. These obligations
will be settled at the end of the useful lives of the underlying assets,
which currently extend up to nine years into the future. This amount has
been discounted using a credit-adjusted risk-free interest rate of 6.5% .
4. Share capital
The Company is authorized to issue an unlimited number of common shares
with no par value.
Continuity of common shares (000's) Shares Amount
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Balance, December 31, 2005 58,473 $ 48,922
Stock options exercised 210 209
Transfer from contributed surplus related to stock
options exercised 103
---------------------------------------------------------------------------
Balance, September 30, 2006 58,683 $ 49,234
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Weighted
Average
Number of Exercise
Continuity of stock options (000's) Options Price
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Balance, December 31, 2005 3,361 $ 2.76
Granted 177 4.60
Exercised (210) .92
Cancelled (33) (6.10)
---------------------------------------------------------------------------
Balance, September 30, 2006 3,295 2.94
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Stock-based compensation Compensation expense of $912,000 has been recorded in the consolidated statements of income and retained earnings (deficit) in the nine months ended 2006 (2005 - $578,000). The fair values of all common stock options granted are estimated on the date of grant using the lattice-based binomial option pricing model in 2006, and the Black-Scholes option-pricing model prior to 2006. The weighted average fair value of options granted during 2006 and the assumptions used in their determination are noted below:
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Weighted average fair market value per option (C$) 2.27
Risk-free interest rate (percent) 4.3
Expected life (years) 5
Expected volatility (percent) 50
Expected dividend yield (percent) 0
Early exercise factor (percent) 25
Early exercise (Year 1/Year 2/Year 3/Year 4/Year 5) (0%/10%/20%/30%/40%)
---------------------------------------------------------------------------
---------------------------------------------------------------------------
5. Per share amounts
In calculating the net income per share basic and diluted, the following
weighted average shares were used:
Three months Nine months
ended ended
September 30 September 30
(000's) 2006 2005 2006 2005
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Weighted average number of shares
outstanding 58,682 58,168 58,627 57,723
Shares issuable pursuant to stock
options 2,657 2,811 2,680 3,144
Shares to be purchased from
proceeds of stock options
under treasury stock method (787) (767) (719) (765)
---------------------------------------------------------------------------
Weighted average number of diluted
shares outstanding 60,552 60,212 60,588 60,102
---------------------------------------------------------------------------
---------------------------------------------------------------------------
The treasury stock method assumes that the proceeds received from the exercise of "in-the-money" stock options are used to repurchase common shares at the average market price. In calculating the weighted average number of diluted common shares outstanding for the three and nine month periods ended September 30, 2006, we excluded 1,211,000 and 1,109,000 options respectively (2005 - 64,000 and 64,000, respectively) because their exercise price was greater than the period average common share market price in this period. 6. Financial instruments The Company has entered into various financial derivative contracts and physical contracts to manage fluctuations in commodity prices in the normal course of operations. In September 2005, the Company entered into a crude oil costless collar for 15,000 barrels per month from January 1, 2006 to December 31, 2006. The transaction consisted of the purchase of a $50.00 per barrel dated Brent put (floor) and a $77.93 per barrel dated Brent call (ceiling). The estimated fair value of unrealized commodity contracts is reported on the consolidated balance sheet with any change in the unrealized positions recorded to income. The fair values of these transactions are based on an approximation of the amounts that would have been paid to or received from counterparties to settle the transactions outstanding as at September 30, 2006 with reference to forward prices and market values provided by independent sources. The actual amounts realized may differ from these estimates. 7. Bank debt The Company entered into an Amended and Restated Credit Agreement on July 18, 2006 in the amount of $55,000,000, with the initial borrowing base established at $25 million, expiring July 18, 2009. The credit agreement bears interest at the Eurodollar Rate plus three percent and is secured by a first floating charge debenture over all assets of the Company, a general assignment of book debts and certain covenants, among other things. At September 30, 2006 $Nil (2005 - $Nil) was drawn on these loan facilities. During the quarter ended September 30, 2006, the Company spent $438,000 to secure the loan facility, of which $31,000 was amortized to the income statement and the remaining $407,000 was deferred and will be amortized to income over the term of the loan facility. 8. Commitments and contingencies Pursuant to the Nuqra Concession Agreement in the Arab Republic of Egypt, the Company and its partners have entered into the first three year extension period which requires the completion of a two well drilling program with a minimum expenditure of $4.0 million over a period of three years. As part of this extension, the Company made the mandatory relinquishment of 25% of the Block and issued a $4.0 million letter of credit (expiring March 4, 2010) to guarantee the Company's performance under the extension period. This letter of credit is secured by a guarantee granted by Export Development Canada in the amount of $2.4 million representing the Company's share of the $4 million.
9. Segmented information
Three months Nine months
ended ended
September 30 September 30
(000's) 2006 2005 2006 2005
---------------------------------------------------------------------------
---------------------------------------------------------------------------
Oil and gas sales, net of
royalties
Republic of Yemen $ 15,473 $ 15,463 $ 42,851 $ 36,474
Canada 3,069 3,684 9,599 7,995
---------------------------------------------------------------------------
18,542 19,147 52,450 44,469
---------------------------------------------------------------------------
Operating expenses
Republic of Yemen 2,078 2,115 5,252 6,067
Canada 683 671 2,136 1,541
---------------------------------------------------------------------------
2,761 2,786 7,388 7,608
---------------------------------------------------------------------------
Depletion, depreciation and
accretion
Republic of Yemen 3,060 4,000 8,338 10,329
Canada 1,831 1,190 5,208 2,564
Arab Republic of Egypt 12 - 25 -
---------------------------------------------------------------------------
4,903 5,190 13,571 12,893
---------------------------------------------------------------------------
Segmented income
Republic of Yemen 10,335 9,348 29,261 20,078
Canada 555 1,823 2,255 3,890
Arab Republic of Egypt (12) - (25) -
---------------------------------------------------------------------------
10,878 11,171 31,491 23,968
Other income 84 3 208 12
Unrealized gain (loss) on
commodity contracts 132 (211) (85) (211)
---------------------------------------------------------------------------
11,094 10,963 31,614 23,769
---------------------------------------------------------------------------
General and administrative 665 653 2,372 1,911
Stock-based compensation 324 128 912 578
Foreign exchange (gain) loss (30) 37 42 31
Income taxes 2,769 2,606 6,819 5,730
---------------------------------------------------------------------------
Net income $ 7,366 $ 7,539 $ 21,469 $ 15,519
---------------------------------------------------------------------------
---------------------------------------------------------------------------
The above includes certain statements that may be deemed to be "forward-looking statements" within the meaning of the U.S. Private Securities Litigation Reform Act of 1995. All statements in this release, other than statements of historical facts, that address future production, reserve potential, exploration drilling, exploitation activities and events or developments that the Company expects are forward-looking statements. Although TransGlobe believes the expectations expressed in such forward-looking statements are based on reasonable assumptions, such statements are not guarantees of future performance and actual results or developments may differ materially from those in the forward-looking statements. Factors that could cause actual results to differ materially from those in forward-looking statements include oil and gas prices, well production performance, exploitation and exploration successes, continued availability of capital and financing, and general economic, market or business conditions. Lloyd Herrick, Vice President & C.O.O. |
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