TransGlobe Energy Corporation Announces Fourth Quarter and

CALGARY, ALBERTA--(Marketwire - March 10, 2011) - TransGlobe Energy Corporation (TSX:TGL) (NASDAQ:TGA) ("TransGlobe" or the "Company") is pleased to announce its financial and operating results for the three months and year ended December 31, 2010. All dollar values are expressed in United States dollars unless otherwise stated. The conversion to barrels of oil equivalent ("Boe") of natural gas to oil is made on the basis of six thousand cubic feet of natural gas being equivalent to one barrel ("Bbl") of crude oil. With the sale of TransGlobe's Canadian assets on April 30, 2008 the results from the Canadian segment of operations are presented as "discontinued operations" in this document. HIGHLIGHTS 2010 - Production increased to 9,960 barrels of oil per day ("Bopd") from an average 8,980 Bopd in 2009, a growth rate of 11%; - Funds flow from operations of $74.6 million ($1.08/share diluted) representing an increase of 65% over 2009; - Net income of $37.9 million ($0.55/share diluted) representing a $46.3 million increase over 2009; - Year-end 2010 Proved ("1P") reserves increased 6% to 20.5 million barrels ("MMBbl"), representing a production replacement for the year of 133%; - Year-end 2010 Proved plus Probable ("2P") reserves increased 26% to 30.4 MMBbl, representing a production replacement for the year of 272%; - Year-end 2010 Proved plus Probable plus Possible ("3P") reserves increased 37% to 41.9 MMBbl, representing a production replacement for the year of 412%; - Finding and development costs in 2010 of $11.06/Bbl (2P) with a recycle ratio of 1.85; and - TransGlobe joined the S&P/TSX Composite Index in December 2010. 2011 - 2011 Guidance: -- Capital program of $90.0 million, a 34% increase over 2010; -- Production of 13,000 to 13,500 Bopd, a 33% increase over 2010 using the mid-point of 13,250 Bopd; -- Funds Flow of $101 million, based on an average Dated Brent oil price of $75.00/Bbl and using the mid-point production of 13,250 Bopd; - January production 10,897 Bopd; February production 11,049 Bopd; - Raised gross proceeds of Cdn$75 million through an equity offering in February; - Albert Gress promoted to Vice President of Business Development effective March 13, 2011; and - Brian Twaddle joins TransGlobe as our new Country Manager in Egypt effective March 13, 2011. Announcements Effective March 13, 2011, Mr. Albert (Al) Gress, Country Manager for TransGlobe Egypt will be promoted to Vice President, Business Development for TransGlobe Energy Corporation. As TransGlobe's Country Manager for the past three years, Al has been very instrumental in the Company's tremendous growth and success in Egypt. In total, Al has over 15 years of direct experience in Egypt in addition to 10 years' experience as a US Certified Public Accountant with PwC (serving energy clients in the United States and Egypt). Al will join the executive team in Calgary and be responsible for developing new business opportunities for the Company in addition to providing transitional support for the new Egypt Country Manager. Concurrently the Company is very pleased to announce that Mr. Brian Twaddle is joining TransGlobe as Country Manager for TransGlobe Egypt effective March 13, 2011. Brian joins TransGlobe with 27 years of oil and gas experience. Holding a Master of Science in Mechanical Engineering from the University of Glasgow, Brian brings a wealth of knowledge to TransGlobe. Most recently, Brian was Country Manager in Egypt for Dana Petroleum plc for the past three years where he was responsible for their exploration, production, development and new ventures. Prior thereto, he served in various roles at Shell from 1991 to 2008 finishing his final four years as an Asset Coordinator. A conference call to discuss TransGlobe's 2010 fourth quarter and year-end results presented in this news release will be held Friday, March 11, 2011 at 9:00 AM Mountain Time (11:00 AM Eastern Time) and is accessible to all interested parties by dialing 1-416-340-8527 or toll-free 1-877-440-9795 (see also TransGlobe's news release dated March 3, 2011). The webcast may be accessed at http://events.digitalmedia.telus.com/transglobe/031111/index.php. TransGlobe Energy Corporation's Annual General and Special Meeting of Shareholders Tuesday, May 11, 2010 at 3:00 PM Mountain Time Centennial Place West, 3rd Floor,250 - 5th Street S.W., Calgary, Alberta, Canada /T/ FINANCIAL AND OPERATING RESULTS Three Months Ended Year Ended December 31 December 31 ---------------------------------------------------- % % Financial 2010 2009 Change 2010 2009 Change ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Oil and gas sales 79,240 50,044 58 268,901 167,798 60 Oil and gas sales, net of royalties and other 45,198 28,788 57 157,220 102,805 53 Derivative loss on commodity contracts (738) (684) (8) (670) (4,213) 84 Operating expense 8,108 7,387 10 26,850 24,765 8 General and administrative expense 5,170 3,922 32 14,588 11,427 28 Depletion, depreciation and accretion expense 9,812 6,955 41 33,933 47,579 (29) Income taxes 12,188 6,887 77 39,807 21,853 82 Cash flow from operating activities 19,326 12,594 53 51,504 36,799 40 Funds flow from operations(1) 18,934 9,703 95 74,569 45,064 65 Basic per share 0.28 0.15 1.12 0.70 Diluted per share 0.26 0.15 1.08 0.70 Net income (loss) 8,026 2,516 219 37,867 (8,417) - Basic per share 0.12 0.04 0.57 (0.13) Diluted per share 0.11 0.04 0.55 (0.13) Capital expenditures 19,546 7,541 159 66,932 35,546 88 Long-term debt (including current portion) 86,420 49,799 74 86,420 49,799 74 Common shares outstanding Basic (weighted average) 67,052 65,357 3 66,328 64,443 3 Diluted (weighted average) 70,426 66,908 5 69,103 64,443 7 Total assets 341,901 228,882 49 341,901 228,882 49 ---------------------------------------------------------------------------- (1) Funds flow from operations is a non-GAAP measure that represents cash generated from operating activities before changes in non-cash working capital. Operating ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Average production volumes (Bopd) 10,789 8,656 25 9,960 8,980 11 Average price ($ per Bbl) 79.83 62.84 27 73.97 51.19 44 Operating expense ($ per Bbl) 8.17 9.28 (12) 7.39 7.56 (2) ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ OPERATIONS UPDATE ARAB REPUBLIC OF EGYPT West Gharib, Arab Republic of Egypt (100% working interest, TransGlobe operated) Operations and Exploration Drilling in the fourth quarter was focused on defining the lateral and structural extent of the Nukhul formation in the Arta, East Arta and South Rahmi development leases. During the fourth quarter, the Company drilled six oil wells (Arta #19, Arta #22, Arta #23, East Arta #5, East Arta #7 and South Rahmi #8) and three dry holes (East Arta #6, East Arta #8 and East Arta #10). Arta #19, Arta #22, Arta #23 and East Arta #5 were drilled and completed as Upper Nukhul oil wells and placed on production. The most significant well drilled in the quarter was East Arta #7 which encountered a thicker Lower Nukhul section structurally down dip of the main Arta pool was placed on production at an initial rate of 1,400 Bopd in November and increased to 2,000 Bopd in December. The well has stabilized in the 1,000 to 1,200 Bopd range in 2011. The reservoir found at East Arta #7 has high porosity and permeability and did not require fracture stimulation. The Upper Nukhul formation has not been completed in East Arta #7. South Rahmi #8 was fracture stimulated in late February and placed on production in early March as an oil well. Subsequent to year-end, six additional oil wells were drilled (two Upper Nukhul wells and four dual Nukhul (Upper and Lower) wells). One well was completed as a Lower Nukhul oil well in January and is producing approximately 1,000 Bopd. Five of the six wells drilled (three dual zone and two upper) were cased awaiting access to perforating services which were unavailable during the month of February. The five oil wells are being perforated and placed on production in early March. Fracture stimulations are scheduled next week for the two Upper Nukhul oil wells. Two drilling rigs are currently drilling at West Gharib, primarily focused on the Nukhul formation. It is expected that up to 44 wells will be drilled in West Gharib during 2011, primarily focused on the Nukhul formation. The Company and the Egyptian General Petroleum Corporation ("EGPC") reviewed development lease continuations for the Arta, East Arta, East Hoshia, North Hoshia, West Hoshia and South Rahmi development leases in the fourth quarter of 2010. All of the Arta, East Arta and South Rahmi leases were continued. Approximately 50% of the West Hoshia development lease and 40% of the North Hoshia development lease were continued. The remainder of the West Hoshia and North Hoshia leases along with the East Hoshia development lease were relinquished. The relinquished lands were not considered prospective by the Company. Production Production from West Gharib averaged 7,941 Bopd to TransGlobe during the fourth quarter, a four per cent (340 Bopd) increase from the previous quarter. Production increases were attributable to increased Nukhul production from Arta and East Arta during the quarter. Production averaged 7,990 Bopd to TransGlobe during January and 8,133 Bopd during February. February production was impacted by access to perforating services which were restored in early March. /T/ Quarterly West Gharib Production (Bopd) 2010 ---------------------------------------------------------------------------- Q-4 Q-3 Q-2 Q-1 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Gross production rate 7,941 7,601 6,631 6,848 TransGlobe working interest 7,941 7,601 6,631 6,848 TransGlobe net (after royalties) 4,634 4,626 4,040 4,250 TransGlobe net (after royalties and tax) (1) 3,338 3,460 3,009 3,222 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Under the terms of the West Gharib Production Sharing Concession, royalties and taxes are paid out of the Government's share of production sharing oil. /T/ East Ghazalat Block, Arab Republic of Egypt (50% working interest) Operations and Exploration During the fourth quarter, the Company drilled three wells resulting in two oil wells (Sabbar #1, Safwa #2) and one exploration well (Nakhil#1) which was abandoned in early January. The Sabbar #1 well was drilled to a total depth of 4,600 feet, cased and completed as a Bahariya oil well. Sabbar #1 was perforated and flowed naturally at a rate of 500 Bopd on a short test. Sabbar #1 is located approximately 1.7 kilometres northeast of Safwa NW-1 which tested 250 Bopd and Safwa #1 which tested 300 Bopd from the Upper Bahariya (un-stimulated). The Safwa #2 was drilled to a total depth of 7,987 feet and cased as a Bahariya oil well. Safwa #2 is the fourth Bahariya oil well drilled on the Safwa structure. Safwa #2 is a step-out appraisal well located approximately 350 metres east of Safwa #1. The Safwa #2 well will be completed and tested as part of the early production test program planned for early 2011, subject to Egyptian Government approval. The operator filed a declaration of Commercial Discovery for the Safwa field and is finalizing the initial Safwa development lease and development plan. In addition, the operator has requested approval to start early production. The commencement of first production will also be contingent on the availability of supplies and services in Egypt. The drilling rig was moved to TransGlobe's Nuqra Block in January. Nuqra Block 1, Arab Republic of Egypt (71.43% working interest, TransGlobe operated) Operations and Exploration TransGlobe has contracted for one year, the 1,200 HP drilling rig previously used at East Ghazalat. The rig was moved to Upper Egypt and commenced drilling the Selsella #1 exploration well on January 26. Drilling operations were suspended January 31 due to disruptions in the delivery of services and drilling supplies by third party contractors. Drilling recommenced February 20 and the well is expected to reach total depth in March. The rig is scheduled to drill two exploration wells (Selsella and Diwan) in Nuqra. The rig will be available for Nukhul development drilling at West Gharib following the Nuqra program. YEMEN EAST-Masila Basin Block 32, Republic of Yemen (13.81% working interest) Operations and Exploration During the fourth quarter, the Godah #12 development well was drilled and completed as a Qishn oil well. Production Production from Block 32 averaged 4,206 Bopd (581 Bopd to TransGlobe) during the quarter, essentially flat with the previous quarter with the addition of Godah #12. Production averaged approximately 3,979 Bopd (550 Bopd to TransGlobe) during January and 3,805 Bopd (526 Bopd to TransGlobe) during February. /T/ Quarterly Block 32 Production (Bopd) 2010 ---------------------------------------------------------------------------- Q-4 Q-3 Q-2 Q-1 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Gross production rate 4,206 4,232 4,464 4,948 TransGlobe working interest 581 585 616 683 TransGlobe net (after royalties) 344 332 315 472 TransGlobe net (after royalties and tax) (1) 265 248 215 400 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Under the terms of the Block 32 Production Sharing Agreement ("PSA"), royalties and taxes are paid out of the government's share of production sharing oil. /T/ Block 72, Republic of Yemen (20% working interest) Operations and Exploration The Gabdain #1 Basement exploration well commenced drilling on November 19, 2010. The well was drilled to total depth of 3,485 meters measured depth (approximately 636 meters measured depth into the Basement). Hydrocarbons were observed while drilling through the Kohlan sandstone overlaying the Basement interval and an oil sample (37 degrees API) was recovered from the Kohlan using a wire line MDT tool prior to running intermediate casing. Hydrocarbon charged fractures were observed while drilling the upper basement interval. An open hole test was conducted on the Basement interval, but no flow to surface was achieved due to the limited fractures encountered in the wellbore. Following the Basement test, a 15 meter interval was perforated in the Kohlan. The Kohlan was placed on test on January 27 using a small electric submersible pump. The well continued to clean up and was producing at an unstablized rate of approximately 130-180 barrels per day of 39 degrees API oil at the end of the five-day test. The presence of oil shows in the Basement and oil in the Kohlan demonstrates a working hydrocarbon generation and migration system. The Kohlan/Basement discovery in Gabdain-1 will be further analyzed prior to any further appraisal plan. Gabdain #1 was suspended and the drilling rig was moved to Gabdain #2 to test a shallow Qishn prospect. The Gabdain #2 exploration well was drilled to total depth and abandoned. The Qishn reservoir was wet. YEMEN WEST- Marib Basin Block S-1, Republic of Yemen (25% working interest) Operations and Exploration During the quarter, two wells were drilled resulting in two oil wells (An Nagyah #2 and An Nagyah #31). Subsequent to the quarter, two additional wells were drilled resulting in two oil wells (An Nagyah # 5 and An Nagyah #28). An Nagyah #2 was re-entered and drilled as a horizontal Lam A oil well and placed on production at an initial gross rate 700+ Bopd. An Nagyah #31 fractured Basement exploration well was drilled and tested oil from the Lam B formation. The Basement section encountered minor oil shows and limited fractures. The Basement section was not tested. Although the Shuqra and the Kohlan had good oil shows during drilling, they did not recover any oil during testing. The Lam B discovery in An Nagyah #31 will require a horizontal side track prior to being commercially productive. An Nagyah #5 was re-entered and drilled as a horizontal Lam A oil well and placed on production at an initial gross rate of 700+ Bopd in late January. The An Nagyah #28 well encountered water in the horizontal section of the Lam B, and was plugged back to the intermediate casing for a future side track horizontal well targeting Lam B oil encountered in the build section of the well. Following An Nagyah #28, the operator suspended the drilling program due to security and logistic concerns associated with maintaining a drilling program as planned on Block S-1 and Block 75. Production operations at An Nagyah have not been affected and are continuing as normal. Production Production from Block S-1 averaged 9,068 Bopd (2,267 Bopd to TransGlobe) during the fourth quarter, a 16% (315 Bopd to TransGlobe) increase from the previous quarter. Production increases were attributable to the development drilling program and additional compression to increase gas injection capacity in December. Production averaged approximately 9,428 Bopd (2,357 Bopd to TransGlobe) during January and approximately 9,560 Bopd (2,390 Bopd to TransGlobe) during February. /T/ Quarterly Block S-1 Production (Bopd) 2010 ---------------------------------------------------------------------------- Q-4 Q-3 Q-2 Q-1 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Gross field production rate 9,068 7,812 7,836 8,652 TransGlobe working interest 2,267 1,952 1,959 2,163 TransGlobe net (after royalties) 1,188 1,003 995 1,169 TransGlobe net (after royalties and tax) (1) 895 756 744 906 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (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. /T/ Block 75, Republic of Yemen (25% working interest) Operations and Exploration The PSA for Block 75 was ratified and signed into law effective March 8, 2008. The first, three-year exploration phase has a work commitment of 3-D seismic and one exploration well. The 3-D seismic was acquired in 2009. One exploration well was planned as part of the Block S-1/75 drilling program. The first exploration phase was extended six months to September 8, 2011. With the suspension of the Block S-1/Block 75 drilling program, the Block 75 exploration well (Osaylan SW)which was scheduled for the second quarter of 2011 will be delayed. The Osaylan SW exploration well is targeting a Lam formation exploration prospect which has an internally estimated gross Petroleum-Initially-In-Place("PIIP") of 184 million barrels of oil per day ("MMBbl") using the probabilistic P-mean case. The following discussion and analysis is management's opinion of TransGlobe's historical financial and operating results and should be read in conjunction with the audited consolidated financial statements of the Company for the years ended December 31, 2010 and 2009, together with the notes related thereto. 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 otherwise noted). This communication is not a suitable source of information for readers who are unfamiliar with the Company, and is not in any way a substitute for reading the annual audited financial statements and annual Management's Discussion and Analysis ("MD&A") related thereto. Additional information relating to the Company, including the Company's Annual Information Form, is on SEDAR at www.sedar.com. The Company's annual report on Form 40-F may be found on EDGAR at www.sec.gov. READER ADVISORIES Forward-Looking Statements The following 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. Such statements relate to possible future events. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "expect", "may", "will", "project", "predict", "potential", "targeting", "intend", "could", "might", "should", "believe" and similar expressions. These statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements. Although TransGlobe's forward-looking statements are based on the beliefs, expectations, opinions and assumptions of the Company's management on the date the statements are made, such statements are inherently uncertain and provide no guarantee of future performance. Actual results may differ materially from TransGlobe's expectations as reflected in such forward-looking statements as a result of various factors, many of which are beyond the control of the Company. These factors include, but are not limited to, unforeseen changes in the rate of production from TransGlobe's oil and gas properties, changes in price of crude oil and natural gas, adverse technical factors associated with exploration, development, production or transportation of TransGlobe's crude oil and natural gas reserves, changes or disruptions in the political or fiscal regimes in TransGlobe's areas of activity, changes in tax, energy or other laws or regulations, changes in significant capital expenditures, delays or disruptions in production due to shortages of skilled manpower, equipment or materials, economic fluctuations, and other factors beyond the Company's control. TransGlobe does not assume any obligation to update forward-looking statements, other than as required by law, if circumstances or management's beliefs, expectations or opinions should change and investors should not attribute undue certainty to, or place undue reliance on, any forward-looking statements. Please consult TransGlobe's public filings at www.sedar.com and www.sec.gov for further, more detailed information concerning these matters. Use of Barrel of Oil Equivalents The calculation of barrels of oil equivalent ("Boe") is based on a conversion rate of six thousand cubic feet of natural gas ("Mcf") to one barrel ("Bbl") of crude oil. Boe's may be misleading, particularly if used in isolation. A Boe conversion ratio of 6 Mcf:1Bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Non-GAAP Measures Funds Flow from Operations This document contains the term "funds flow from operations", which should not be considered an alternative to or more meaningful than "cash flow from operating activities" as determined in accordance with Generally Accepted Accounting Principles ("GAAP"). Funds flow from operations is a non-GAAP measure that represents cash generated from operating activities before changes in non-cash working capital. Management considers this a key measure as it demonstrates TransGlobe's ability to generate the cash flow necessary to fund future growth through capital investment. Funds flow from operations may not be comparable to similar measures used by other companies. /T/ Reconciliation of Funds Flow from Operations Year Ended December 31 ---------------------------------------------------------------------------- ($000s) 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Cash flow from operating activities 51,504 36,799 Changes in non-cash working capital 23,065 8,265 ---------------------------------------------------------------------------- Funds flow from operations 74,569 45,064 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ Debt-to-funds flow ratio Debt-to-funds flow is a non-GAAP measure that is used to set the amount of capital in proportion to risk. The Company's debt-to-funds flow ratio is computed as long-term debt, including the current portion, over funds flow from operations for the trailing twelve months. Debt-to-funds flow may not be comparable to similar measures used by other companies. Netback Netback is a non-GAAP measure that represents sales net of royalties (all government interests, net of income taxes), operating expenses and current taxes. Management believes that netback is a useful supplemental measure to analyze 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. Netback may not be comparable to similar measures used by other companies. TRANSGLOBE'S BUSINESS TransGlobe is a Canadian-based, publicly traded, oil exploration and production company whose activities are concentrated in two main geographic areas, the Arab Republic of Egypt ("Egypt") and the Republic of Yemen ("Yemen"). Egypt and Yemen include the Company's exploration, development and production of crude oil. TransGlobe disposed of its Canadian oil and gas operations in 2008 to reposition itself as 100% oil, Middle East/North Africa growth company. /T/ SELECTED ANNUAL INFORMATION ($000s, except per share, price and volume amounts) 2010 % Change 2009 % Change 2008 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Total Operations Average production volumes (Boepd) 9,960 11 8,980 22 7,342 Average sales volumes (Boepd) 9,960 11 8,980 22 7,342 Average price ($/Boe) 73.97 45 51.19 (41) 86.96 Oil and gas sales 268,901 60 167,798 (28) 233,695 Oil and gas sales, net of royalties and other 157,220 53 102,805 (22) 132,393 Cash flow from operating activities 51,504 40 36,799 (36) 57,793 Funds flow from operations(1) 74,569 65 45,064 (24) 59,267 Funds flow from operations per share - Basic 1.12 0.70 0.99 - Diluted 1.08 0.70 0.98 Net income (loss) 37,867 (8,417) 31,523 Net income (loss) per share - Basic 0.57 (0.13) 0.53 - Diluted 0.55 (0.13) 0.52 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Continuing Operations Average production volumes (Bopd) 9,960 11 8,980 31 6,858 Average sales volumes (Bopd) 9,960 11 8,980 31 6,858 Average price from continuing operations ($/Bbl) 73.97 45 51.19 (42) 88.66 Oil sales 268,901 60 167,798 (25) 222,538 Oil sales, net of royalties and other 157,220 53 102,805 (17) 123,231 Cash flow from operating activities 51,504 40 36,799 (28) 51,090 Funds flow from continuing operations(1) 74,569 65 45,064 (14) 52,359 Funds flow from continuing operations per share - Basic 1.12 0.70 0.88 - Diluted 1.08 0.70 0.86 Net (loss) income 37,867 (8,417) 23,173 Net (loss) income per share - Basic 0.57 (0.13) 0.39 - Diluted 0.55 (0.13) 0.38 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Total assets 341,901 49 228,882 - 228,238 Cash and cash equivalents 57,782 257 16,177 112 7,634 Total long-term debt, including current portion 86,420 74 49,799 (13) 57,230 Debt-to-funds flow ratio(2) 1.2 1.1 1.0 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Reserves Total Proved (MMboe) 20.5 6 19.2 53 12.6 Total Proved plus Probable (MMBoe) 30.4 26 24.2 22 19.8 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Funds flow from operations is a non-GAAP measure that represents cash generated from operating activities before changes in non-cash working capital. (2) Debt-to-funds flow ratio is a non-GAAP measure that represents long-term debt, including the current portion, over funds flow from operations for the trailing 12 months. /T/ In 2010 compared with 2009, TransGlobe, - Increased Proved reserves by 1.3 MMBbl, representing a production replacement of 133%, primarily from the development of its operated West Gharib concession in Egypt; - Increased total production by 11%, as a result of a 25% increase in production from Egypt offset by a 14% decline in production in Yemen; - Funds flow increased by 65% primarily due to a 45% increase in realized oil prices combined with increased production; - Realized a net income of $37.9 million due to increased revenues combined with an 84% decrease in derivative loss and a 29% decrease in depreciation and depletion due to increased Proved reserves; and - Increased debt by $36.6 million while maintaining a debt-to-funds flow ratio of 1.2 at December 31, 2010 (December 31, 2009 - 1.1). /T/ 2010 TO 2009 NET INCOME (LOSS) VARIANCES $000s $ Per Share Diluted Variance% ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- 2009 net loss (8,417) (0.13) ---------------------------------------------------------------------------- Cash items Volume variance 26,439 0.40 314 Price variance 74,664 1.08 887 Royalties (46,688) (0.68) (555) Expenses: Operating (2,085) (0.03) (25) Realized derivative loss (595) (0.01) (7) Cash general and administrative (2,423) (0.04) (29) Current income taxes (17,954) (0.26) (213) Realized foreign exchange loss (1,248) (0.02) (15) Interest on long-term debt (589) (0.01) (7) Other income (16) - - ---------------------------------------------------------------------------- Total cash items variance 29,505 0.43 350 ---------------------------------------------------------------------------- Non-cash items Unrealized derivative gain 4,138 0.06 50 Depletion and depreciation 13,646 0.20 162 Stock-based compensation (738) (0.01) (9) Amortization of deferred financing costs (267) - (3) ---------------------------------------------------------------------------- Total non-cash items variance 16,779 0.25 200 ---------------------------------------------------------------------------- 2010 net income 37,867 0.55 550 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ Net income increased to $37.9 million in 2010 compared to a loss of $8.4 million in 2009, which was mostly due to significant increases in commodity prices and production volumes along with a decrease in depletion and depreciation, which was partially offset by higher royalties and income taxes. BUSINESS ENVIRONMENT The Company's financial results are significantly influenced by fluctuations in commodity prices, including price differentials. The following table shows select market benchmark prices and foreign exchange rates: /T/ ---------------------------------------------------------------------------- 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Dated Brent average oil price ($/Bbl) 79.42 61.51 U.S./Canadian Dollar average exchange rate 1.0301 1.1415 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ The price of Dated Brent oil averaged 29% higher in 2010 compared with 2009. Global markets are currently in a period of economic recovery with improved liquidity and access to capital, in addition to strengthening oil prices. Conversely, the recent political instability in Egypt and Yemen could present challenges to the Company if the issues persist over an extended period of time. TransGlobe's management believes the Company is well positioned to adapt to the current political situations in Egypt and Yemen; due to its increasing production, manageable debt levels, positive cash generation from operations and the availability of cash and cash equivalents. The Company designed its 2011 budget to be flexible, allowing spending to be adjusted up or down depending upon the business environment in Egypt and Yemen. /T/ SELECTED QUARTERLY FINANCIAL INFORMATION 2010 2009 ---------------------------------------------------------------------------- ($000s, except per share, price and volume amounts) Q-4 Q-3 Q-2 Q-1 Q-4 Q-3 Q-2 Q-1 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Total Operations Average sales volumes (Bopd) 10,789 10,138 9,206 9,694 8,656 8,864 9,619 8,788 Average price ($/Bopd) 79.83 71.27 73.46 70.66 62.84 57.41 48.62 35.88 Oil and gas sales 79,240 66,470 61,540 61,651 50,044 46,818 42,557 28,379 Oil and gas sales, net of royalties and other 45,198 38,980 35,638 37,404 28,788 28,495 26,462 19,060 Cash flow from operating activities 19,326 12,297 15,627 4,254 12,594 1,264 15,052 7,889 Funds flow from operations (1) 18,934 19,535 17,027 19,073 9,703 12,603 14,117 8,641 Funds flow from operations per share - Basic 0.28 0.29 0.26 0.29 0.15 0.19 0.22 0.14 - Diluted 0.26 0.28 0.25 0.29 0.15 0.19 0.22 0.14 Net income (loss) 8,026 8,805 9,438 11,598 2,516 (1,618) (4,361) (4,954) Net income (loss) per share - Basic 0.12 0.13 0.14 0.18 0.04 (0.02) (0.07) (0.08) - Diluted 0.11 0.13 0.14 0.17 0.04 (0.02) (0.07) (0.08) ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Total assets 341,901 275,885 263,345 248,446 228,882 228,964 229,658 238,145 Cash and cash equivalents 57,782 15,412 21,437 18,845 16,177 14,804 23,952 22,041 Total long-term debt, including current portion 86,420 46,045 49,977 49,888 49,799 52,686 52,551 57,347 Debt-to-funds flow ratio(2) 1.2 0.7 0.9 0.9 1.1 1.3 1.2 1.1 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Funds flow from operations is non-GAAP measure that represents cash generated from operating activities before changes in non-cash working capital. (2) Debt-to-funds flow ratio is a non-GAAP measure that represents long-term debt, including the current portion, over funds flow from operations for the trailing 12 months. /T/ During the fourth quarter of 2010, TransGlobe: - Maintained a strong financial position, reporting a debt-to-funds flow ratio of 1.2 at December 31, 2010 (December 31, 2009 - 1.1), with available cash of $57.8 million; - Funded capital programs with funds flow from operations and working capital; - Reported a 95% increase in funds flow from operations due to a 27% increase in commodity prices along with a 25% increase in sales volumes compared to Q4-2009; and - Reported net income in Q4-2010 of $8.0 million (Q4-2009 - $2.5 million) mainly due to higher commodity prices and production volumes in the quarter compared with the same period in 2009. /T/ OPERATING RESULTS AND NETBACK Daily Volumes, Working Interest, Before Royalties and Other Year Ended December 31 ---------------------------------------------------------------------------- 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Egypt - Oil sales Bopd 7,259 5,828 Yemen - Oil sales Bopd 2,701 3,152 ---------------------------------------------------------------------------- Total Company - daily sales volumes Bopd 9,960 8,980 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Three Months Ended December 31 ---------------------------------------------------------------------------- 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Egypt - Oil sales Bopd 7,941 5,815 Yemen - Oil sales Bopd 2,848 2,841 ---------------------------------------------------------------------------- Total Company - daily sales volumes Bopd 10,789 8,656 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Netback from Continuing Operations 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- Oil sales 268,901 73.97 167,798 51.19 Royalties and other 111,681 30.72 64,993 19.83 Current taxes 39,807 10.95 21,853 6.67 Operating expenses 26,850 7.39 24,765 7.56 ---------------------------------------------------------------------------- Netback 90,563 24.91 56,187 17.13 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Three Months Ended December 31 ---------------------------------------------------------------------------- Consolidated 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Oil sales 79,240 79.83 50,044 62.84 Royalties and other 34,042 34.30 21,256 26.69 Current taxes 12,188 12.28 6,887 8.65 Operating expenses 8,108 8.17 7,387 9.28 ---------------------------------------------------------------------------- Netback 24,902 25.08 14,514 18.22 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Egypt 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Oil sales 190,234 71.80 98,801 46.45 Royalties and other 75,339 28.43 34,684 16.30 Current taxes 29,686 11.20 13,980 6.57 Operating expenses 16,464 6.21 14,703 6.91 ---------------------------------------------------------------------------- Netback 68,745 25.96 35,434 16.67 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Three Months Ended December 31 ---------------------------------------------------------------------------- 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Oil sales 56,558 77.42 30,536 57.08 Royalties and other 23,557 32.24 10,715 20.03 Current taxes 9,225 12.63 4,322 8.08 Operating expenses 4,664 6.38 5,008 9.36 ---------------------------------------------------------------------------- Netback 19,112 26.17 10,491 19.61 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ The netback per Bbl in Egypt increased 56% in 2010 compared with 2009, mainly as a result of oil prices increasing by 55%, which was partially offset by higher royalty and tax rates. In 2010, the average realized oil price for the West Gharib crude had a gravity/quality adjustment of approximately $7.62/Bbl (10%) to the average Dated Brent oil price versus a $15.06/Bbl (24%) differential in 2009. Royalties and taxes as a percentage of revenue increased to 55% in 2010, compared with 49% in 2009. Royalty and tax rates fluctuate in Egypt due to changes in the cost oil whereby the Production Sharing Contract ("PSC") allows for recovery of operating and capital costs through a reduction in government take. Operating expenses for 2010 decreased 10% on a per Bbl basis, which is mainly due to a significant increase in production in Egypt combined with fewer workovers in 2010 as compared to 2009. /T/ Yemen 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Oil sales 78,667 79.79 68,997 59.97 Royalties and other 36,342 36.86 30,309 26.34 Current taxes 10,121 10.27 7,873 6.84 Operating expenses 10,386 10.53 10,062 8.75 ---------------------------------------------------------------------------- Netback 21,818 22.13 20,753 18.04 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Three Months Ended December 31 ---------------------------------------------------------------------------- 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Oil sales 22,682 86.57 19,508 74.64 Royalties and other 10,485 40.02 10,541 40.33 Current taxes 2,963 11.31 2,565 9.81 Operating expenses 3,444 13.14 2,379 9.10 ---------------------------------------------------------------------------- Netback 5,790 22.10 4,023 15.40 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ In Yemen, the netback per Bbl increased 23% in 2010 compared with 2009, primarily as a result of the 33% increase in oil prices, which was partially offset by higher royalty and tax rates along with increased operating expenses. Royalties and taxes as a percentage of revenue increased to 59% in 2010 compared with 55% in 2009. Royalty and tax rates fluctuate in Yemen due to changes in the amount of cost oil, whereby the Block 32 and Block S-1 Production Sharing Agreements ("PSAs") allow for the recovery of operating and capital costs through a reduction in the Ministry of Oil and Minerals' take of oil production. Operating expenses on a per Bbl basis increased 20% in 2010, which is mainly due to lower production volumes and increased selling costs in 2010. DERIVATIVE COMMODITY CONTRACTS TransGlobe uses hedging arrangements as part of its risk management strategy to manage commodity price fluctuations and to stabilize cash flows for future exploration and development programs. The hedging program is actively monitored and adjusted as deemed necessary to protect the cash flows from the risk of commodity price exposure. The estimated fair value of unrealized commodity contracts is reported on the Consolidated Balance Sheets 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, counter-parties to settle the transactions outstanding as at the Consolidated Balance Sheet date with reference to forward prices and market values provided by independent sources. The actual amounts realized may differ from these estimates. The realized loss on commodity contracts in 2010 relates mostly to the purchase of new financial floor derivative commodity contracts, whereas the loss in 2009 was lower due to depressed oil prices. The mark-to-market valuation of TransGlobe's future derivative commodity contracts increased from a $0.5 million liability at December 31, 2009 to a $0.3 million asset at December 31, 2010, thus resulting in a $0.8 million unrealized gain on future derivative commodity contracts being recorded in the year. /T/ Year Ended December 31 ---------------------------------------------------------------------------- ($000s) 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Realized cash loss on commodity contracts(i) (1,486) (891) Unrealized (loss) gain on commodity contracts(ii) 816 (3,322) ---------------------------------------------------------------------------- Total derivative (loss) gain on commodity contracts (670) (4,213) ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (i) Realized cash loss represents actual cash settlements or receipts under the respective contracts. (ii) The unrealized (loss) gain on derivative commodity contracts represents the change in fair value of the contracts during the year. /T/ If the Dated Brent oil prices in 2011 are consistent with the estimated Dated Brent forward curve prices at the end of 2010, the derivative asset will be realized over the year. However, a 10% decrease in Dated Brent oil prices would result in a $0.3 million increase in the derivative commodity contract asset, thus increasing the unrealized gain by the same amount. Conversely, a 10% increase in Dated Brent oil prices would decrease the unrealized gain on commodity contracts by $0.1 million. The following commodity contracts are outstanding immediately following December 31, 2010: /T/ Dated Brent Pricing Period Volume Type Put ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Crude Oil ---------- Financial January 1, 2011-December 31, 2011 40,000 Bbls/month Floor $65.00 Financial April 1, 2011-December 31, 2011(i) 20,000 Bbls/month Floor $75.00 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (i) Contract entered into on January 19, 2011. The total volumes hedged for 2011 are: 2011 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Bbls 660,000 Bopd 1,808 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- At December 31, 2010, all of the derivative commodity contracts were classified as current liabilities. GENERAL AND ADMINISTRATIVE EXPENSES ("G&A") 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- G&A (gross) 14,513 4.00 12,550 3.83 Stock-based compensation 2,749 0.76 2,011 0.61 Capitalized G&A and overhead recoveries (2,674) (0.74) (3,134) (0.96) ---------------------------------------------------------------------------- G&A (net) 14,588 4.02 11,427 3.48 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Three Months Ended December 31 ---------------------------------------------------------------------------- 2010 2009 ---------------------------------------------------------------------------- (000s, except per Boe amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- G&A (gross) 4,774 4.81 4,291 5.39 Stock-based compensation 1,079 1.09 518 0.65 Capitalized G&A and overhead recoveries (683) (0.69) (887) (1.11) ---------------------------------------------------------------------------- G&A (net) 5,170 5.21 3,922 4.93 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ G&A expenses (net) increased 16% on a per Bbl basis in 2010 compared with 2009 partly due to a strengthening Canadian dollar which accounted for approximately 46% of the increase as the majority of TransGlobe's G&A costs are incurred in Canadian dollars. The remainder of the increase was due to increased insurance, staffing and office costs in Egypt. INTEREST ON LONG-TERM DEBT Interest expense includes interest on long-term debt and amortization of transaction costs associated with long-term debt. Interest expense for 2010 increased to $3.3 million (2009 - $2.5 million), as a result of higher interest rates in 2010 combined with higher amortization of transaction costs. In 2010, the Company expensed $0.8 million of transaction costs (2009 - $0.6 million). The Company had $90.0 million of debt outstanding at December 31, 2010 (December 31, 2009 - $50.0 million). The long-term debt that was outstanding at December 31, 2010 bore interest at LIBOR plus an applicable margin that varies from 3.75% to 4.75% depending on the amount drawn under the facility. The long-term debt that was outstanding at December 31, 2009 bore interest at the Eurodollar Rate plus three per cent under the terms of the previous credit facility that was terminated in July 2010 and replaced with a new Borrowing Base Facility. /T/ DEPLETION AND DEPRECIATION ("DD&A") 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Egypt 26,010 9.82 37,942 17.84 Yemen 7,683 7.79 9,436 8.20 Corporate 240 - 201 - ---------------------------------------------------------------------------- 33,933 9.33 47,579 14.52 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Three Months Ended December 31 ---------------------------------------------------------------------------- 2010 2009 ---------------------------------------------------------------------------- (000s, except per Bbl amounts) $ $/Bbl $ $/Bbl ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Egypt 7,824 10.71 4,792 8.96 Yemen 1,931 7.37 2,105 8.05 Corporate 57 - 58 - ---------------------------------------------------------------------------- 9,812 9.89 6,955 8.73 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ In Egypt, DD&A decreased 31% in 2010 (45% on a per Bbl basis) due to significant increases to Proven reserves at year-end 2009 along with further increases at year end 2010 (181% production replacement). In Yemen, DD&A decreased 19% in 2010 (5% on a per Bbl basis) due to a reduction in estimated future capital costs which decreased the capital base, combined with Proved reserve additions on Block S-1 and Block 32 at year-end 2009 along with further increases at year end 2010 (6% production replacement). In Egypt, unproven properties of $9.8 million in 2010 (2009 - $9.8 million) relating to Nuqra ($8.2 million), West Gharib ($0.5 million) and East Ghazalat ($1.1 million) were excluded from the costs subject to depletion and depreciation. In Yemen, unproven property costs of $11.6 million in 2010 (2009 - $10.8 million) relating to Block 72 ($7.8 million) and Block 75 ($3.8 million) were excluded from the costs subject to depletion and depreciation. Capital costs in the amount of $0.5 million were excluded from the corporate costs subject to the depreciation for the year ended December 31, 2010. /T/ CAPITAL EXPENDITURES ($000s) 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Egypt 58,435 28,349 Yemen 7,684 7,013 Corporate 813 184 ---------------------------------------------------------------------------- Total 66,932 35,546 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ In Egypt, total capital expenditures for the year ended December 31, 2010 were up 106% from 2009 due to an increased capital program in response to higher oil prices in 2010 and the East Ghazalat farm-in. Further fuelling the increase to the capital program were new discoveries in West Gharib and East Ghazalat, along with certain drilling activities undertaken to retain key blocks of land in West Gharib. The Company drilled 31 wells, resulting in 24 oil wells (four at Hana, six at Arta, five at East Arta, two at North Hoshia, one at each of Hana West, Hoshia and South Rahmi, and four at East Ghazalat), in addition to three dry holes at East Arta, one at Hoshia, one at West Hoshia, and two at East Ghazalat. In Yemen, total capital expenditures in the year ended December 31, 2010 increased by 10% from 2009 due mostly to restarting the drilling program at Block S-1. Five oil development wells were drilled in 2010 at Block S-1, along with two oil development wells and one dry hole at Block 32. Corporate capital expenditures relate mainly to leasehold improvements and furnishings for new office space in Canada. FINDING AND DEVELOPMENT COSTS/FINDING, DEVELOPMENT AND NET ACQUISITION COSTS Canadian National Instrument 51-101, Standards of Disclosure for Oil and Gas Activities ("NI 51-101"), specifies how finding and development ("F&D") costs should be calculated. NI 51-101 requires that exploration and development costs incurred in the year along with the change in estimated future development costs be aggregated and then divided by the applicable reserve additions. The calculation specifically excludes the effects of acquisitions and dispositions on both reserves and costs. TransGlobe believes that the provisions of NI 51-101 do not fully reflect TransGlobe's ongoing reserve replacement costs. Since acquisitions can have a significant impact on TransGlobe's annual reserves replacement cost, to not include these amounts could result in an inaccurate portrayal of TransGlobe's cost structure. Accordingly, TransGlobe has also reported finding, development and acquisition ("FD&A") costs that will incorporate all acquisitions net of any dispositions during the year. /T/ Proved ($000s, except volumes and $/Boe amounts) 2010 2009 2008 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Total capital expenditure 66,932 35,546 43,292 Acquisitions - - 58,946 Dispositions - - (57,295) Net change from previous year's future capital 4,776 1,816 (6,479) ---------------------------------------------------------------------------- 71,708 37,362 38,464 ---------------------------------------------------------------------------- Reserve additions and revisions (MBoe) Exploration and development 4,845 9,921 3,129 Acquisitions, net of dispositions - - 118 ---------------------------------------------------------------------------- Total reserve additions (Mboe) 4,845 9,921 3,247 ---------------------------------------------------------------------------- Average cost per Boe F&D 14.80 3.77 11.77 FD&A 14.80 3.77 11.85 Three-year weighted average cost per Boe F&D 8.15 7.40 14.97 FD&A 8.19 9.75 16.62 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Proved Plus Probable ($000s, except volumes and $/Boe amounts) 2010 2009 2008 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Total capital expenditure 66,932 35,546 43,292 Acquisitions - - 58,946 Dispositions - - (57,295) Net change from previous year's future capital 42,546 4,112 (8,602) ---------------------------------------------------------------------------- 109,478 39,658 36,341 ---------------------------------------------------------------------------- Reserve additions and revisions (MBoe) Exploration and development 9,895 7,670 5,200 Acquisitions, net of dispositions - - 709 ---------------------------------------------------------------------------- Total reserve additions (Mboe) 9,895 7,670 5,909 ---------------------------------------------------------------------------- Average cost per Boe F&D 11.06 5.17 6.67 FD&A 11.06 5.17 6.15 Three-year weighted average cost per Boe F&D 8.07 7.27 12.35 FD&A 7.90 8.59 12.14 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Note: The aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserves additions for that year. RECYCLE RATIO Three-Year Proved Weighted Average 2010 2009 2008 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Netback ($/Boe) (1) 18.63 20.51 13.75 22.05 Proved F&D costs ($/Boe) 8.15 14.80 3.77 11.77 Proved FD&A costs ($/Boe) 8.19 14.80 3.77 11.85 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- F&D Recycle ratio 2.29 1.39 3.65 1.87 FD&A Recycle ratio 2.27 1.39 3.65 1.86 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Netback, for the purposes of calculating the recycle ratio, is defined as net sales less operating, G&A (excluding non-cash items), foreign exchange (gain) loss, interest and current income tax expense per Boe of production. Three-Year Proved Plus Probable Weighted Average 2010 2009 2008 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Netback ($/Boe) (1) 18.63 20.51 13.75 22.05 Proved plus Probable F&D costs ($/Boe) 8.07 11.06 5.17 6.67 Proved plus Probable FD&A costs ($/Boe) 7.90 11.06 5.17 6.15 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- F&D Recycle ratio 2.31 1.85 2.66 3.31 FD&A Recycle ratio 2.36 1.85 2.66 3.59 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Netback, for the purposes of calculating the recycle ratio, is defined as net sales less operating, G&A (excluding non-cash items), foreign exchange (gain) loss, interest and current income tax expense per Boe of production. /T/ The 2010 proved recycle ratios decreased from 2009 by 62%, which is mainly a result of fewer Proved reserve additions in 2010. The proved plus probable ratios decreased from 2009 mainly due to the low cost of the 2009 reserve additions, which were the result of waterflood simulation and field response at Hoshia and Hana and the development of the Hana West pool. The decreased ratios were also impacted by increased future capital associated with undrilled Proved plus Probable reserve additions in 2010. Due to the nature of international projects, the Company considers the three-year weighted average recycle ratios to provide the most useful information. The three-year weighted average ratios are consistent with Company expectations and with prior periods. The recycle ratio measures the efficiency of TransGlobe's capital program by comparing the cost of finding and developing both proved reserves and proved plus probable reserves with the netback from production. The ratio is calculated by dividing the netback by the proved and proved plus probable finding and development cost on a per Boe basis. /T/ ($000s, except volumes and per Boe amounts) 2010 2009 2008 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Net income 37,867 (8,417) 31,523 Adjustments for non-cash items: Depletion, depreciation and accretion 33,933 47,579 38,056 Stock-based compensation 2,749 2,011 1,830 Future income taxes - - (82) Amortization of deferred financing costs 836 569 1,884 Unrealized (gain) loss on commodity contracts (816) 3,322 (9,906) Gain on sale - - (4,012) Settlement of asset retirement obligations - - (25) ---------------------------------------------------------------------------- Netback (1) 74,569 45,064 59,268 Sales volumes (MBoe) 3,635 3,278 2,687 ---------------------------------------------------------------------------- Netback per Boe (1) 20.51 13.75 22.05 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Netback, for the purposes of calculating the recycle ratio, is defined as net sales less operating, G&A (excluding non-cash items), foreign exchange (gain) loss, interest and current income tax expense per Boe of production. /T/ OUTSTANDING SHARE DATA As at December 31, 2010, the Company had 67,575,321 common shares issued and outstanding. The Company received regulatory approval to purchase, from time to time, as it considers advisable, up to 6,116,905 common shares under a Normal Course Issuer Bid, which commenced September 7, 2009 and expired September 6, 2010. During the year ended December 31, 2010 and during the year ended December 31, 2009, the Company did not repurchase any common shares. Subsequent to December 31, 2010, the Company issued an additional 5,000,000 common shares in a public offering that closed on February 1, 2011. 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 to repay debt. TransGlobe's capital programs are funded principally by cash provided from operating activities. A key measure that TransGlobe uses to measure the Company's overall financial strength is debt-to-funds flow from operating activities (calculated on a 12-month trailing basis). TransGlobe's debt-to-funds flow from operating activities ratio, a key short-term leverage measure, remained strong at 1.2 times at December 31, 2010. This was within the Company's target range of no more than 2.0 times. The following table illustrates TransGlobe's sources and uses of cash during the years ended December 31, 2010 and 2009: /T/ Sources and Uses of Cash ($000s) 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Cash sourced Funds flow from operations(1) 74,569 45,064 Increase in long-term debt 95,916 - Issuance of common shares, net of share issuance costs 9,959 15,374 ---------------------------------------------------------------------------- 180,444 60,438 Cash used Capital expenditures 66,932 35,546 Bank financing costs 4,216 - Repayment of long-term debt 55,916 8,000 Increase in restricted cash 3,387 - Options surrendered for cash payments - 13 ---------------------------------------------------------------------------- 130,451 43,559 ---------------------------------------------------------------------------- Net cash from operations 49,993 16,879 Changes in non-cash working capital (8,388) (8,336) ---------------------------------------------------------------------------- Increase in cash and cash equivalents 41,605 8,543 Cash and cash equivalents - beginning of year 16,177 7,634 ---------------------------------------------------------------------------- Cash and cash equivalents - end of year 57,782 16,177 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Funds flow from continuing operations is a non-GAAP measure that represents cash generated from continuing operating activities before changes in non-cash working capital. /T/ Funding for the Company's capital expenditures was provided by funds flow from operations for the year ended December 31, 2010. The Company expects to fund its 2011 exploration and development program of $90.0 million and contractual commitments through the use of working capital and cash generated by operating activities. Furthermore, the Company raised C$75.0 million (US$75.6 million), before fees and expenses, in a public offering that closed on February 1, 2011. The net proceeds of the offering will primarily be used by the Company to repay existing credit facilities and to evaluate, and if determined to be in the best interests of the Company, pursue business development opportunities in Egypt during fiscal 2011, including adding new acreage through farm-in arrangements, bid rounds or acquisitions from third parties. Fluctuations in commodity prices, foreign exchange rates, interest rates and various other risks may impact capital resources. Working capital is the amount by which current assets exceed current liabilities. At December 31, 2010, the Company had working capital of $88.3 million (December 31, 2009 - deficiency of $11.8 million). The working capital deficiency as at December 31, 2009 was primarily the result of the reclassification of all long-term debt as a current liability. On July 22, 2010, the Company entered into a new Borrowing Base Facility. Therefore, as at December 31, 2010 the Borrowing Base Facility was classified as long-term which eliminated the working capital deficiency. While the reclassification of bank debt accounts for the majority of the increase in working capital, other increases to working capital in 2010 are the result of increased accounts receivable due to higher oil prices and higher sales volumes. These receivables are not considered to be impaired; however, to mitigate this risk, the Company insured a portion of the receivable balance. At December 31, 2009 TransGlobe had a $60.0 million Revolving Credit Agreement of which $50.0 million was drawn. Amounts drawn under the Revolving Credit Agreement were set to become due on September 25, 2010. On July 22, 2010, the Company entered into a new five-year $100.0 million Borrowing Base Facility and paid out the original Revolving Credit Agreement. The new Borrowing Base Facility is secured by a pledge over certain bank accounts, a pledge over the Company's subsidiaries, and a fixed and floating charge over certain assets. As repayments on the new Borrowing Base Facility are not expected to commence until 2012, the entire balance has been presented as a long-term liability on the Consolidated Balance Sheet at December 31, 2010. Repayments will be made on a semi-annual basis according to the scheduled reduction of the facility. As of December 31, 2010, the Company has incurred financing costs related to the new Borrowing Base Facility in the amount of $4.2 million. /T/ December 31 ($000s) 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Revolving Credit Agreement 90,000 50,000 Unamortized transaction costs (3,580) (201) ---------------------------------------------------------------------------- 86,420 49,799 ---------------------------------------------------------------------------- Current portion of long-term debt - 49,799 ---------------------------------------------------------------------------- Long-term debt 86,420 - ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ 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: /T/ (000s) Payment Due by Period(1)(2) ---------------------------------------------------------------------------- Recognized More in Financial Contractual Less than 1-3 4-5 than Statements Cash Flows 1 year years years 5 years ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Accounts payable and accrued liabilities Yes-Liability $ 41,772 $41,772 $ - $ - $ - Long-term debt: Borrowing Base Facility Yes-Liability 90,000 - 56,803 33,197 - Office and equipment leases No 11,255 1,474 3,422 1,970 4,389 Minimum work commitments(3) No 5,433 1,890 3,543 - - ---------------------------------------------------------------------------- Total $148,460 $45,136 $63,768 $35,167 $4,389 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) Payments exclude ongoing operating costs related to certain leases, interest on long-term debt and payments made to settle derivatives. (2) Payments denominated in foreign currencies have been translated at December 31, 2010 exchange rates. (3) Minimum work commitments include contracts awarded for capital projects and those commitments related to exploration and drilling obligations. /T/ Pursuant to the Concession agreement for Nuqra Block 1 in Egypt, the Contractor (Joint Venture Partners) has a minimum financial commitment of $5.0 million ($4.4 million to TransGlobe) and a work commitment for two exploration wells in the second exploration extension. The second, 36-month extension period commenced on July 18, 2009. The Contractor has met the second extension financial commitment of $5.0 million in the prior periods. At the request of the Government, the Company provided a $4.0 million production guarantee from the West Gharib Concession prior to entering the second extension period. Pursuant to the PSA for Block 72 in Yemen, the Contractor (Joint Venture Partners) has a minimum financial commitment of $2.0 million ($0.1 million to TransGlobe) to drill one exploration well during the second exploration period. The second, 30-month exploration period commenced on January 12, 2009. The Contractor has entered into a farm-in agreement with TOTAL E&P Yemen which has reduced TransGlobe's interest in the concession to 20%.This commitment was fully satisfied subsequent to December 31, 2010. Pursuant to the PSA for Block 75 in Yemen, the Contractor (Joint Venture Partners) has a remaining minimum financial commitment of $3.0 million ($0.8 million to TransGlobe) for one exploration well. The first, 36-month exploration period commenced March 8, 2008. Subsequent to December 31, 2010, the Company received an extension on the first exploration period to September 9, 2011. The Company issued a $1.5 million letter of credit (expiring November 15, 2011) to guarantee the Company's performance under the first exploration period. The letter is secured by a guarantee granted by Export Development Canada. Pursuant to the August 18, 2008 asset purchase agreement for a 25% financial interest in eight development leases on the West Gharib Concession in Egypt, the Company has committed to paying the vendor a success fee to a maximum of $2.0 million if incremental reserve thresholds are reached in the South Rahmi development lease, to be evaluated annually. As at December 31, 2010, no additional fees are due in 2011. Pursuant to a one-year extension to the West Hoshia development lease, which is part of the Concession agreement for West Gharib in Egypt, the Company provided a $1.0 million production guarantee to drill one exploration well prior to October 14, 2011. In the normal course of its operations, the Company may be subject to litigations and claims. Although it is not possible to estimate the extent of potential costs, if any, management believes that the ultimate resolution of such contingencies would not have a material adverse impact on the results of operations, financial position or liquidity of the Company. OFF BALANCE SHEET ARRANGEMENTS The Company has certain lease agreements, all of which are reflected in the Commitments and Contingencies table, which were entered into in the normal course of operations. All leases have been treated as operating leases whereby the lease payments are included in operating expenses or G&A expenses depending on the nature of the lease. No asset or liability value has been assigned to these leases in the balance sheet as of December 31, 2010. MANAGEMENT STRATEGY AND OUTLOOK FOR 2011 The 2011 outlook provides information as to management's expectation for results of operations for 2011. Readers are cautioned that the 2011 outlook may not be appropriate for other purposes. The Company's expected results are sensitive to fluctuations in the business environment and may vary accordingly. This outlook contains forward-looking statements that should be read in conjunction with the Company's disclosure under "Forward-Looking Statements" included on the first page of the MD&A. 2011 Outlook Highlights - Production is expected to average between 13,000 Bopd and 13,500 Bopd, a 33% increase over the 2010 average production; - Exploration and development spending is budgeted to be $90 million, a 34% increase from 2010 (allocated 85% to Egypt, 13% to Yemen and 2% Corporate) and will be funded by funds flow from operations and cash on hand; and - Using the mid-point of production expectations and an average oil price assumption for the year of $75.00/Bbl for Dated Brent oil, funds flow from operations is expected to be $101.0 million. 2011 Production Outlook Production for 2011 is expected to average between 13,000 Bopd and 13,500 Bopd, representing a 33% increase over the 2010 average production of 9,960 Bopd. Production from Egypt is expected to average approximately 10,350 Bopd during 2011, up 43% from an average of 7,259 Bopd in 2010, with the balance of approximately 2,900 Bopd coming from the Yemen properties, which represents a 7% increase from an average of 2,701 Bopd in 2010. This forecast excludes any production contributions from the East Ghazalat project. /T/ Production Forecast 2011 Guidance 2010 Actual % Change(1) ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Barrels of oil per day 13,000 -13,500 9,960 33 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) % growth based on mid-point of outlook. 2011 Funds Flow From Operations Outlook This outlook was developed using the above production forecast and a Dated Brent oil price of $75.00/Bbl. 2010 Funds Flow From Operations Outlook ($ million) 2011 Guidance 2010 Actual % Change(1) ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Funds flow from operations(2) 101.0 74.6 35 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- (1) % growth based on mid-point of outlook. (2) Funds flow from operations is a non-GAAP measure that represents cash generated from operating activities before changes in non-cash working capital. /T/ Due in part to higher expected prices and higher production, funds flow from operations is expected to increase by 35% in 2011. Variations in production and commodity prices during 2011 could significantly change this outlook. An increase in the Dated Brent oil price of $10.00/Bbl would increase anticipated funds flow by approximately $14.0 million to $115.0 million for the year, while a $10.00/Bbl decrease in the Dated Brent oil price would result in anticipated funds flow decreasing by approximately $14.0 million to $87.0 million for the year. /T/ 2011 Capital Budget ($ million) 2011 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Egypt 76.6 Yemen 11.7 Corporate 1.7 ---------------------------------------------------------------------------- Total 90.0 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ The 2011 capital program is split 80:20 between development and exploration, respectively. The Company plans to participate in 61 wells in 2011. The Company will fund its entire 2011 capital budget from funds flow and working capital. The Company designed its 2011 budget to be flexible, allowing spending to be adjusted up or down depending upon the business environment in Egypt and Yemen. /T/ Consolidated Statements of Income (Loss) and Retained Earnings (Unaudited - Expressed in thousands of U.S. Dollars, except per share amounts) Three Months Ended Year Ended December 31 December 31 2010 2009 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- REVENUE Oil sales, net of royalties and other $ 45,198 $ 28,788 $157,220 $102,805 Derivative (loss) on commodity contracts (738) (684) (670) (4,213) Other income 10 28 28 44 ---------------------------------------------------------------------------- 44,470 28,132 156,578 98,636 ---------------------------------------------------------------------------- EXPENSES Operating 8,108 7,387 26,850 24,765 General and administrative 5,170 3,922 14,588 11,427 Foreign exchange loss (gain) (37) (92) 216 (1,032) Interest on long-term debt 1,203 557 3,317 2,461 Depletion and depreciation 9,812 6,955 33,933 47,579 ---------------------------------------------------------------------------- 24,256 18,729 78,904 85,200 ---------------------------------------------------------------------------- Income before income taxes 20,214 9,403 77,674 13,436 Income taxes - current 12,188 6,887 39,807 21,853 ---------------------------------------------------------------------------- NET INCOME (LOSS) 8,026 2,516 37,867 (8,417) Retained earnings, beginning of period 109,854 77,497 80,013 88,430 ---------------------------------------------------------------------------- RETAINED EARNINGS, END OF PERIOD $117,880 $ 80,013 $117,880 $ 80,013 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Net income (loss) per share Basic 0.12 0.04 0.57 (0.13) Diluted 0.11 0.04 0.55 (0.13) ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Consolidated Statements of Comprehensive Income (Loss) (Expressed in thousands of U.S. Dollars) Three Months Ended Year Ended December 31 December 31 2010 2009 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Net income (loss) $ 8,026 $ 2,516 $ 37,867 $ (8,417) Other comprehensive loss: Foreign currency translation adjustment - - - - ---------------------------------------------------------------------------- COMPREHENSIVE INCOME (LOSS) $ 8,026 $ 2,516 $ 37,867 $ (8,417) ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Consolidated Balance Sheets (Unaudited - Expressed in thousands of U.S. Dollars) As at December 31 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- ASSETS Current Cash and cash equivalents $ 57,782 $ 16,177 Accounts receivable 69,085 35,319 Derivative commodity contracts 303 - Prepaids and other 2,867 1,909 ---------------------------------------------------------------------------- 130,037 53,405 ---------------------------------------------------------------------------- Restricted cash 3,387 - Goodwill 8,180 8,180 Property and equipment 200,297 167,297 ---------------------------------------------------------------------------- $ 341,901 $ 228,882 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- LIABILITIES Current Accounts payable and accrued liabilities $ 41,772 $ 14,879 Derivative commodity contracts - 514 Current portion of long-term debt - 49,799 ---------------------------------------------------------------------------- 41,772 65,192 Long-term debt 86,420 - ---------------------------------------------------------------------------- 128,192 65,192 ---------------------------------------------------------------------------- Commitments and contingencies Subsequent event SHAREHOLDERS' EQUITY Share capital 80,193 66,106 Contributed surplus 4,756 6,691 Accumulated other comprehensive income 10,880 10,880 Retained earnings 117,880 80,013 ---------------------------------------------------------------------------- 213,709 163,690 ---------------------------------------------------------------------------- $ 341,901 $ 228,882 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Consolidated Statement of Cash Flows (Unaudited - Expressed in thousands of U.S. Dollars) Three months ended Year-ended December 31 December 31 2010 2009 2010 2009 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- CASH FLOWS RELATED TO THE FOLLOWING ACTIVITIES: OPERATING Net Income (loss) $ 8,026 $ 2,516 $ 37,867 $ (8,417) Adjustments for: Depletion and depreciation 9,812 6,955 33,933 47,579 Amortization of deferred financing costs 313 112 836 569 Stock-based compensation 1,079 518 2,749 2,011 Unrealized (gain) loss on commodity contracts (296) (398) (816) 3,322 Changes in non-cash working capital 392 2,891 (23,065) (8,265) ---------------------------------------------------------------------------- 19,326 12,594 51,504 36,799 ---------------------------------------------------------------------------- FINANCING Increase in long-term debt 40,000 - 95,916 - Repayments of long-term debt - (3,000) (55,916) (8,000) Deferred financing costs 61 - (4,216) - Options surrendered for cash payments - - - (13) Issue of common shares for cash 2,553 186 9,959 16,578 Issue costs for common shares - (1) - (1,204) Changes in non-cash working capital - (640) - (1,515) ---------------------------------------------------------------------------- 42,614 (3,455) 45,743 5,846 ---------------------------------------------------------------------------- INVESTING Exploration and development expenditures (19,546) (7,541) (66,932) (35,546) Changes in restricted cash (1,497) - (3,387) - Changes in non-cash working capital 1,473 (225) 14,677 1,444 ---------------------------------------------------------------------------- (19,570) (7,766) (55,642) (34,102) ---------------------------------------------------------------------------- NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 42,370 1,373 41,605 8,543 CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD 15,412 14,804 16,177 7,634 ---------------------------------------------------------------------------- CASH AND CASH EQUIVALENTS, END OF PERIOD $ 57,782 $ 16,177 $ 57,782 $ 16,177 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- Supplemental Disclosure of Cash Flow Information Cash interest paid $ 890 $ 445 $ 2,481 $ 1,892 Cash tax paid 12,188 6,887 39,807 21,853 Cash is comprised of cash on hand and balances with banks 27,782 14,274 27,782 14,274 Cash equivalents 30,000 1,903 30,000 1,903 ---------------------------------------------------------------------------- ---------------------------------------------------------------------------- /T/ Cautionary Statement to Investors: This news release 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. Such statements relate to possible future events. All statements other than statements of historical fact may be forward-looking statements. Forward-looking statements are often, but not always, identified by the use of words such as "seek", "anticipate", "plan", "continue", "estimate", "expect", "may", "will", "project", "predict", "potential", "targeting", "intend", "could", "might", "should", "believe" and similar expressions. These statements involve known and unknown risks, uncertainties and other factors that may cause actual results or events to differ materially from those anticipated in such forward-looking statements. Although TransGlobe's forward-looking statements are based on the beliefs, expectations, opinions and assumptions of the Company's management on the date the statements are made, such statements are inherently uncertain and provide no guarantee of future performance. Actual results may differ materially from TransGlobe's expectations as reflected in such forward-looking statements as a result of various factors, many of which are beyond the control of the Company. These factors include, but are not limited to, unforeseen changes in the rate of production from TransGlobe's oil and gas properties, changes in price of crude oil and natural gas, adverse technical factors associated with exploration, development, production or transportation of TransGlobe's crude oil and natural gas reserves, changes or disruptions in the political or fiscal regimes in TransGlobe's areas of activity, changes in tax, energy or other laws or regulations, changes in significant capital expenditures, delays or disruptions in production due to shortages of skilled manpower, equipment or materials, economic fluctuations, and other factors beyond the Company's control. TransGlobe does not assume any obligation to update forward-looking statements if circumstances or management's beliefs, expectations or opinions should change, other than as required by law, and investors should not attribute undue certainty to, or place undue reliance on, any forward-looking statements. Please consult TransGlobe's public filings at www.sedar.com and www.sec.gov/edgar.shtml for further, more detailed information concerning these matters.

Contact Information: TransGlobe Energy Corporation Investor Relations Scott Koyich 403.264.9888 investor.relations@trans-globe.com www.trans-globe.com

TransGlobe Energy Corporation Announces Fourth Quarter and Year-End 2010 Financial and Operating Results