TransGlobe Energy Corporation Announces Third Quarter 2012

TransGlobe Energy Corporation Announces Third Quarter 2012 Financial
and Operating Results 
CALGARY, ALBERTA -- (Marketwire) -- 11/08/12 -- TransGlobe Energy
Corporation (TSX:TGL) (NASDAQ:TGA) ("TransGlobe" or the "Company") is
pleased to announce its financial and operating results for the three
and nine months ended September 30, 2012. All dollar values are
expressed in United States dollars unless otherwise stated.  
HIGHLIGHTS 


 
--  Increased production to an average of 18,143 Bopd (17,124 Bopd sales)
    for the quarter; 
--  Third quarter funds flow of $35.4 million; 
--  Third quarter earnings of $11.8 million (includes a $4.4 million
    unrealized loss on convertible debentures); 
--  Spent $17.5 million on exploration, development and acquisitions during
    the quarter; 
--  Drilled 9 wells in the quarter resulting in 6 oil wells and 3 dry holes;
--  Ended the quarter with $45.7 million in cash and cash equivalents;
    positive working capital of $252.2 million or $117.4 million net of debt
    (including convertible debentures); 
--  Closed corporate acquisition of Cepsa on July 26, 2012, providing the
    remaining operated 50% working interest in the South Alamein concession;
--  The Company's first oil production in the Western Desert of Egypt; 
--  The Company was the successful bidder on four concessions offered in the
    EGPC 2011 bid round (NW Gharib, SW Gharib, SE Gharib and S Ghazalat). 

 
A conference call to discuss TransGlobe's 2012 third quarter results
presented in this news release will be held Thursday, November 8,
2012 at 9:00 AM Mountain Time (11:00 AM Eastern Time) and is
accessible to all interested parties by dialing 1-416-981-9005 or
toll-free 1-800-736-4610 (see also TransGlobe's news release dated
November 1, 2012). The webcast may be accessed at
http://events.digitalmedia.telus.com/transglobe/110812/index.php 
FINANCIAL AND OPERATING RESULTS  
(US$000s, except per share, price, volume amounts and % change) 


 
                             Three months ended           Nine months ended 
                                   September 30                September 30 
                    --------------------------------------------------------
Financial                                     %                           % 
                          2012     2011  Change      2012      2011  Change 
----------------------------------------------------------------------------
Oil revenue            152,624  128,265      19   460,128   339,875      35 
Oil revenue, net of                                                         
 royalties              74,540   71,769       4   225,385   187,145      20 
Derivative gain                                                             
 (loss) on commodity                                                        
 contracts                   -      (13)      -      (125)     (599)     79 
Production and                                                              
 operating expense      11,622    9,762      19    35,024    26,404      33 
General and                                                                 
 administrative                                                             
 expense                 7,350    4,357      69    20,829    13,591      53 
Depletion,                                                                  
 depreciation and                                                           
 amortization                                                               
 expense                11,005   10,300       7    34,516    26,263      31 
Income taxes            22,742   19,442      17    65,660    53,146      24 
Funds flow from                                                             
 operations(i)          35,397   37,980      (7)  106,659    93,507      14 
 Basic per share          0.49     0.52              1.46      1.29         
 Diluted per share        0.47     0.51              1.41      1.25         
Net earnings            11,774   26,110     (55)   52,898    50,873       4 
Net earnings -                                                              
 diluted                11,774   26,110     (55)   52,898    50,873       4 
 Basic per share          0.16     0.36              0.72      0.70         
 Diluted per share        0.16     0.35              0.70      0.68         
Capital expenditures    12,579   20,160     (38)   31,501    59,544     (47)
Corporate                                                                   
 acquisition             4,881        -       -    27,978         -       - 
Working capital        252,242  164,132      54   252,242   164,132      54 
Long-term debt,                                                             
 including current                                                          
 portion                31,878   57,303     (44)   31,878    57,303     (44)
Convertible                                                                 
 debentures            102,920        -       -   102,920         -       - 
Common shares                                                               
 outstanding                                                                
 Basic (weighted-                                                           
  average)              73,450   72,993       1    73,249    72,358       1 
 Diluted (weighted-                                                         
  average)              75,621   75,371       -    75,501    74,906       1 
Total assets           635,529  465,262      37   635,529   465,262      37 
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
(i) Funds flow from operations is a measure that represents cash
generated from operating activities before changes in non-cash
working capital and may not be comparable to measures used by other
companies.     


 
Operating                                                                   
----------------------------------------------------------------------------
Average production                                                          
 volumes (Bopd)         18,143    13,406     35     17,284    12,158     42 
Average sales                                                               
 volumes (Bopd)         17,124    13,406     28     16,942    12,158     39 
Average price ($ per                                                        
 Bbl)                    96.88    104.00     (7)     99.12    102.40     (3)
Operating expense ($                                                        
 per Bbl)                 7.38      7.92     (7)      7.54      7.96     (5)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
Corporate Summary  
TransGlobe Energy Corporation's ("TransGlobe" or the "Company") total
production increased to a record 18,143 barrels of oil per day
("Bopd") during the quarter. The increase in production over Q-2 was
due to Block S-1 in Yemen coming back on production July 27th,
production increases at West Bakr and new production at East
Ghazalat. Total oil sales for the Company averaged 17,124 Bopd during
the quarter, 1,019 Bopd less than production as Block S-1 production
in Yemen was held in inventory and sold subsequent to quarter end.  
The Safwa field in East Ghazalat was placed on production in
mid-September and represents the Company's first oil production in
the Western Desert. The Safwa field is producing approximately 1,000
Bopd (500 Bopd to TransGlobe) from the four existing wells. 
In the Eastern desert the Company continued drilling at West Gharib
and West Bakr with a drilling rig on each concession. Concurrent with
the drilling activities, the Company advanced a number of facility
projects focused on the integration of the West Bakr and West Gharib
assets to improve delivery of production to the Government-controlled
("GPC") processing and handling facilities. In early November the
Company expects to move a portion of the Hana/Hana West production in
West Gharib through the West Bakr system pipeline, which will
partially alleviate some of the production constraints in West
Gharib. The Company has approximately 300 Bopd of production shut-in
and an additional 2,400 Bopd (12 Nukhul wells at 200 Bopd using the
average 90 day Upper Nukhul production rate after completion and
stimulation) of production behind casing at West Gharib due to
facility constraints at the GPC receiving terminal. The Company
commenced a six-well completion and stimulation program in October to
evaluate new pools/extensions and to provide additional productive
capacity; the remaining wells will be completed in 2013 as required.
The Company expects to be able to bring on the shut-in production
through the winter and bring on the additional behind casing
production to off-set natural declines during 2013. 
During the quarter TransGlobe acquired Cepsa Egypt SA B.V. which
holds and is operator of the remaining 50% interest in South Alamein.
TransGlobe now holds a 100% interest in the South Alamein concession.
The Company is advancing an initial five-well drilling program at
South Alamein which could commence prior to year end, depending upon
the approval of the necessary well permits. In addition, the Company
finalized the drilling plans for the Al Azayem #1 exploration well on
South Mariut (60% operated interest). In October drilling commenced
on the 14,500 foot Al Azayem #1 exploration well which represents the
Company's first operated well in the Western desert and the start of
a significant exploration drilling program in the Western desert.  
Dated Brent oil prices were strong in the third quarter, averaging
$109.61 per barrel. The West Gharib and West Bakr crude is sold at a
quality discount to Dated Brent and received a blended price of
$96.72 during the quarter. The Company had funds flow of $35.4
million and ended the quarter with positive working capital of $252.2
million or $117.4 million net of debt (including the convertible
debentures). The Company's accounts receivable balance, (net of
excess cost oil due to Egyptian General Petroleum Company ("EGPC")),
increased to $222.8 million. Subsequent to the quarter a tanker
lifting of approximately 512,000 barrels allocated to the Company by
EGPC, was completed October 24th to 26th. The proceeds of that
lifting, estimated at $52.5 million, are due to be received in
November directly from the purchaser. This payment is expected to
bring the accounts receivable balance in-line with the historical
average of five to eight months aging. 
The Company had net earnings in the quarter of $11.7 million
($0.16/share), which included a $4.4 million ($0.06/share) non-cash
unrealized loss on convertible debentures. The $4.4 million loss
represents a fair value adjustment in accordance with IFRS, but does
not represent a cash outflow or a change in the future cash outlay
required to repay the convertible debentures.  
In the Company's view, the political environment in the Arab Republic
of Egypt ("Egypt") continues to improve and business processes and
operations are proceeding as normal. The Company has a strong
financial position and continues to pursue business development
opportunities both within and outside of Egypt. 
ARAB REPUBLIC OF EGYPT  
West Gharib, Arab Republic of Egypt (100% working interest, operated) 
Operations and Exploration  
The Company drilled five wells during the third quarter in the
Arta/East Arta area resulting in three Nukhul oil wells (two new
pools), one potential Thebes oil well (new pool) and one dry hole. A
step-out well was drilled near the Fadl field subsequent to the
quarter which encountered the target zone on the down-thrown side of
a fault. The well has been plugged back to surface casing and
suspended as a potential future sidetrack location. The drilling rig
is currently drilling a step-out location at Hoshia. It is expected
that the drilling rig will continue working in West Gharib throughout
2013. 
Production  
Production from West Gharib averaged 12,182 Bopd to TransGlobe during
the third quarter, essentially flat (1% or 174 Bopd lower) with the
previous quarter. The production gains to the 12,700 Bopd to 13,000
Bopd level that were achieved in the third quarter were offset by
several issues.   
In August and early September production was lower due to performance
issues associated with the incumbent trucking contractor during the
tender process for a new trucking contract. A new trucking contract
was awarded in the fourth quarter which has improved trucking
operations.   
At the end of September, production was impacted by an 8-day illegal
labor protest at the West Gharib field entrance which shut down crude
oil trucking from West Gharib from September 30 to October 7. The
labor protest involved subcontractor day-rate workers who were
seeking full time employment. The protest was ruled illegal by the
courts on October 7 and disbanded peacefully by the Ministry of
Interior. It is estimated that approximately 100,000 barrels of
production was deferred dur
ing the eight day protest, which will
impact fourth quarter sales by approximately 950 Bopd.   
Production averaged 9,867 Bopd to TransGlobe during October,
primarily due to the illegal labor protest. Current production in
November is approximately 12,800 Bopd.   
Of the 21 wells drilled in 2012, 13 wells are awaiting completion and
stimulation. The wells will be completed and brought on to production
to offset natural declines and as additional sales capacity becomes
available at the GPC terminal over the next 12 months. The Company
commenced a six-well completion and stimulation program in
mid-October to evaluate new pools and pool extensions.  
Facility Projects  
The Company has completed a number of facility projects and several
more are underway at West Gharib and West Bakr to reduce the amount
of water trucked with the oil from West Gharib and increase sales
capacity at GPC. The larger facility projects completed and underway
are summarized below: 


 
--  South Arta Multi Well Battery ("MWB") completed December 2011; 
--  Hoshi MWB completed May 2012; 
--  Hana West Treater completed July 2012; 
--  West Bakr K station offloading system for West Gharib production
    targeting Q-4 2012; 
    --  Initially trucking the Hana/Hana West production to K station
        completed early November 2012. 
--  Hana Treater facility targeting Q-4 2012; 
--  East Arta MWB in the northern portion of the field targeting Q-1 2013; 
--  Arta Central Processing Facility ("CPF") Q-4 2013. 
--  Expand tie-in facilities to allow West Gharib crude from Northern fields
    production (Hoshia, Arta, East Arta) to tie into the West Bakr pipeline
    facilities. 

 
The Company continues to progress a number of longer term
infrastructure projects in the West Gharib/West Bakr fields to
deliver West Gharib production to GPC by pipeline and thereby
eliminate oil trucking outside the West Gharib field area. 


 
Quarterly West Gharib Production                                            
 (Bopd)                                                                     
                                                 2012                   2011
----------------------------------------------------------------------------
                                           
Q-3       Q-2       Q-1       Q-4
----------------------------------------------------------------------------
Gross production rate                   12,182    12,356    12,065    11,280
TransGlobe working interest             12,182    12,356    12,065    11,280
TransGlobe net (after royalties)         6,757     6,847     6,581     6,255
TransGlobe net (after royalties and                                         
 tax)(i)                                 4,741     4,805     4,536     4,358
----------------------------------------------------------------------------
(i) 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.                                                            

 
West Bakr, Arab Republic of Egypt (100% working interest, operated)  
Operations and Exploration  
The Company drilled two wells during the third quarter resulting in
one oil well in the H field and one directional well in the K field
(K27) which had to be abandoned prior to reaching the target zones
due to drilling problems in a thick shale section. Subsequent to the
quarter, the Company has drilled an oil well in the K field (K28)
which will be completed and placed on production from one of the
three oil zones encountered.  
The rig is currently drilling on the M field targeting a new pool.
The initial three-well drilling program for 2012 has been increased
to eight wells (two wells in H, two wells in M and four wells in K).
In addition to the planned eight-well drilling program, the West Bakr
team has identified an additional 14 drilling targets. It is expected
that the drilling rig will continue working in West Bakr throughout
2013. 
Production  
Production from West Bakr averaged 4,590 Bopd to TransGlobe during
the third quarter, a 9% (360 Bopd) increase from the previous
quarter. Production increases from new wells and recompletions were
offset during the quarter by a number of unscheduled pump changes and
some initial sand clean-outs on new producers.  
Production has averaged 4,863 Bopd in October primarily due to better
pump performance. The Company expects to achieve improved pump
performance similar to the West Gharib operations as equipment is
repaired or replaced with better quality components over the balance
of 2012. 


 
Quarterly West Bakr Production                                              
 (Bopd)                                                                     
                                                 2012                   2011
----------------------------------------------------------------------------
                                           Q-3       Q-2       Q-1    Q-4(i)
----------------------------------------------------------------------------
Gross production rate                    4,590     4,230     4,358       138
TransGlobe working interest              4,590     4,230     4,358       138
TransGlobe net (after royalties)         1,268     1,244     1,239        45
TransGlobe net (after royalties and                                         
 tax)(ii)                                  939       941       926        35
----------------------------------------------------------------------------

 
(i)  Purchased December 29, 2011, includes three days of production. 
(ii)  Under the terms of the West Bakr Production Sharing concession,
royalties and taxes are paid out of the Government's share of
production sharing oil. 
East Ghazalat, Arab Republic of Egypt (50% working interest)  
Operations and Exploration  
During the third quarter the Company finished drilling the East
Ghazalat 2x exploration well (Eradah prospect), which was abandoned.  
Production 
During the quarter the operator completed and
 equipped the four
existing Safwa wells for production and installed production
facilities at Safwa. First oil production started September 9th at
200 Bopd (100 Bopd to TransGlobe) from one of the four wells with the
other three wells placed on production over the following 30 days.
Production from East Ghazalat averaged 82 Bopd to TransGlobe during
the third quarter. Production during October averaged 549 Bopd to
TransGlobe, with the four Safwa wells on production. 
Production is trucked to a receiving terminal at the Dapetco operated
South Dabaa facility approximately 35 kilometers southwest of Safwa.  


 
Quarterly East Ghazalat Production                                          
 (Bopd)                                                                     
                                                 2012                   2011
----------------------------------------------------------------------------
                                           Q-3       Q-2       Q-1       Q-4
----------------------------------------------------------------------------
Gross production rate                      163         -         -         -
TransGlobe working interest                 82         -         -         -
TransGlobe net (after royalties)            41         -         -         -
TransGlobe net (after royalties and                                         
 tax)(i)                                    33         -         -         -
----------------------------------------------------------------------------

 
(i) Under the terms of the East Ghazalat Production Sharing
concession, royalties and taxes are paid out of the Government's
share of production sharing oil. 
South Alamein, Arab Republic of Egypt (100% working interest,
operated)  
TransGlobe now holds a 100% working interest in the South Alamein
Production Sharing Concession ("PSC") through two, wholly-owned
subsidiary companies. On June 7, 2012 the Company acquired a company
from EP Energy LLC which holds a 50% interest in the South Alamein
PSC. On July 26, 2012 the Company acquired a company from COMPANIA
ESPANOLA DE PETROLEOS, S.A.U. which holds the remaining 50% working
interest in the South Alamein PSC.  
The South Alamein concession is located onshore in the Western Desert
of Egypt and includes portions of the prolific Alamein and Tiba
basins. The current size of this exploration concession is 1,423
square kilometers (355,832 acres), and is in the final two-year
exploration phase. The concession includes an oil discovery well,
Boraq-2X. The primary Cretaceous zone tested at a rate of 800 to
1,323 Bopd of 34 API oil with no water and a 13% pressure drawdown
during a 28 hour drill stem test ("DST"). A secondary Cretaceous zone
tested at a rate of 274 Bopd of 32-35 API oil and 4% water during a
23 hour DST. Test rates are not necessarily indicative of long-term
performance but it is anticipated that the well should be capable of
producing approximately 1,700 Bopd. 
Operations and Exploration  
No wells were drilled during the third quarter. The Company has
scheduled a drilling rig to commence an initial five-well drilling
program starting in December 2012 or early 2013 which is dependent on
receiving the necessary well permits. The program will include two
appraisal wells at Boraq and three exploration wells. It is expected
that a drilling rig will remain in the South Alamein concession
throughout 2013. The Company is targeting first production from the
Boraq discovery in mid-2013.  
South Mariut, Arab Republic of Egypt (60% working interest, operated) 
The South Mariut concession is located in the Western Desert of Egypt
and is onshore along the Mediterranean coastline, adjacent to
prolific offshore hydrocarbon fields and southwest of the city of
Alexandria. The current gross size of this exploration concession is
approximately 3,350 square kilometers (828,000 acres). The South
Mariut concession is in the first, three-year extension period which
expires on April 5, 2013. A further two-year extension is available
under the PSC. 
Operations and Exploration  
No wells were drilled during the third quarter. Subsequent to the
quarter, drilling commenced on October 10th at Al Azayem #1. The well
is targeting several stacked horizons with four-way closures
identified on 3-D seismic, and drilling is expected to take
approximately 90 days. The total depth is expected at approximately
14,500 feet in Jurassic reservoirs. In addition to the Al Azayem #1
well, the Company is in the process of finalizing the selection of
two additional exploration prospects for drilling in early 2013. It
is expected that the joint venture partners will finalize the second
and third exploration locations prior to year-end. 
Nuqra Block 1, Arab Republic of Egypt (71.43% working interest,
operated)  
Operations and Exploration  
The Nuqra Block exploration concession expired on July 17, 2012 and
was relinquished. All exploration commitments were met. 
YEMEN WEST- Marib Basin  
Block S-1, Republic of Yemen (25% working interest)  
Operations and Exploration  
No wells were drilled during the quarter.  
Production  
Production from Block S-1 re-commenced on July 27, 2012 following
repairs to the Marib export pipeline to the Ras Eisa port on the Red
Sea, which was damaged in October 2011. During the quarter
TransGlobe's sales production averaged 63 Bopd which represents the
Company's share of production for the last five days of July at 1,140
Bopd. The gross field production for the third quarter averaged 3,860
Bopd (965 Bopd to TransGlobe). In October gross field production
averaged appr
oximately 6,852 Bopd (1,713 Bopd to TransGlobe).  
The Company agreed to amend the Block S-1 marketing contract
effective July 2012 from a monthly purchase contract to a tanker
lifting sales contract. The unsold third quarter inventory was lifted
and sold with October production in early November. Based on current
production volumes it is anticipated that tanker liftings could occur
approximately once per quarter from Block S-1. It is expected that
sales production rates and the field production rates will vary
quarter to quarter depending on the timing of tanker liftings during
the respective quarter. 


 
Quarterly Block S-1 Production and                                          
 Sales (Bopd)                                                               
                                                 2012                   2011
----------------------------------------------------------------------------
                                           Q-3       Q-2       Q-1       Q-4
----------------------------------------------------------------------------
Gross field production rate              3,860         -         -       736
Gross sales production rate                252         -         -       736
TransGlobe working interest                 63         -         -       184
TransGlobe net (after royalties)            41         -         -        93
TransGlobe net (after royalties and                                         
 tax)(ii)                                   36         -         -        69
----------------------------------------------------------------------------

 
(i) Partial quarter, production started July 27, 2012.  
(ii) 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 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
2011 Block S-1/75 drilling program however the drilling program was
cancelled in the first quarter of 2011 due to logistics and security
concerns. 
YEMEN EAST- Masila Basin  
Block 32, Republic of Yemen (13.81% working interest)  
Operations and Exploration  
One oil well was drilled in the Tasour field during the third
quarter. The well was placed on production in early August and is
producing approximately 380 Bopd.  
Production  
Production sales from Block 32 averaged 1,501 Bopd (207 Bopd to
TransGlobe) during the quarter. The reported gross sales production
rate represents the amount of oil that was lifted and sold during the
quarter. It is expected that sales production rates and the field
production rates will vary quarter to quarter depending on the timing
of tanker lifting's during the respective quarter.  
The actual field production during the third quarter averaged 2,532
Bopd (350 Bopd to TransGlobe) which is approximately 2% lower than
the previous quarter due to natural declines and a leak in the export
pipeline that had curtailed sales for five days during September.  
Field production averaged approximately 2,509 Bopd (346 Bopd to
TransGlobe) during October. 


 
Quarterly Block 32 Production and                                           
 Sales (Bopd)                                                               
                                                 2012                   2011
----------------------------------------------------------------------------
                                           Q-3       Q-2       Q-1       Q-4
----------------------------------------------------------------------------
Gross field production rate              2,532     2,575     2,704     3,276
Gross sales production rate              1,501     2,839     2,151     3,276
TransGlobe working interest                207       392       297       452
TransGlobe net (after royalties)           123       232       166       254
TransGlobe net (after royalties and                                         
 tax)(i)                                    96       179       120       188
----------------------------------------------------------------------------

 
(i) 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 (20% working interest)  
Operations and Exploration  
No new wells were drilled during the quarter. In July the joint
venture partners met and approved the Gabdain #3 well, subject to the
resolution of logistic/security issues in the area. The current
exploration phase of the PSA has been extended to October 12, 2013.  
Gabdain #3 is targeting a large fractured basement prospect
originally drilled at Gabdain #1 in 2010. Gabdain #1 tested
approximately 170 Bopd light oil from the Kholan formation with 85%
drawdown (which overlies the basement) during a two-day production
test. Test rates are not necessarily indicative of long-term
performance. The basement fractures at Gabdain #1 were tight and
non-productive. The Gabdain #3 well is located approximately five
kilometers from Gabdain #1 and is targeting fractures in the
basement. It is expected that the 3,500 meter (11,500 feet)
exploration well will cost approximately $11.5 million ($2.3 million
to TransGlobe).  
November 6, 2012  
Management's discussion and analysis ("MD&A") should be read in
conjunction with the unaudited Condensed Consolidated Interim
Financial Statements for the three and nine months ended September
30, 2012 and 2011 and the audited financial statements and MD&A for
the year ended December 31, 2011 included in the Company's annual
report. Additional information relating to the Company, including the
Company's Annual Information Form, is on SEDAR at www.sedar.com. The
Company's Form 40-F may be found on EDG
AR at www.sec.gov. 
READER ADVISORIES  
Forward Looking Statements  
Certain statements or information contained herein may constitute
forward-looking statements, or information under applicable
securities laws, including management's assessment of future plans
and operations, drilling plans and the timing thereof, commodity
price risk management strategies, adapting to the current political
situations in Egypt and Yemen, reserve estimates, the resolution of
potential litigation and claims and impact on the Company of the
costs and resolutions, management's expectation for results of
operations for 2012, including expected 2012 average production,
funds flow from operations, the 2012 capital program for exploration
and development, the timing and method of financing thereof, method
of funding drilling commitments, commodity prices and expected
volatility thereof and the use of proceeds from recent financings.  
Forward-looking statements or information relate to the Company's
future events or performance. All statements other than statements of
historical fact may be forward-looking statements or information.
Such statements or information 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.  
Forward-looking statements or information necessarily involve risks
including, without limitation, risks associated with oil and gas
exploration, development, exploitation, production, marketing and
transportation, loss of markets, economic and political instability,
volatility of commodity prices, currency fluctuations, imprecision of
reserve estimates, environmental risks, competition from other
producers, inability to retain drilling rigs and other services,
incorrect assessment of the value of acquisitions, failure to realize
the anticipated benefits of acquisitions, delays resulting from or
inability to obtain required regulatory approvals and ability to
access sufficient capital from internal and external sources. The
recovery and reserve estimates of the Company's reserves are
estimates only and there is no guarantee that the estimated reserves
will be recovered. Events or circumstances may cause actual results
to differ materially from those predicted, as a result of the risk
factors set out and other known and unknown risks, uncertainties, and
other factors, many of which are beyond the control of the Company.  
In addition, forward-looking statements or information are based on a
number of factors and assumptions which have been used to develop
such statements and information in order to provide shareholders with
a more complete perspective on the Company's future operations. Such
statements and information may prove to be incorrect and readers are
cautioned that such statements and information may not be appropriate
for other purposes. Although the Company believes that the
expectations reflected in such forward-looking statements or
information are reasonable, undue reliance should not be placed on
forward-looking statements or information because the Company can
give no assurance that such expectations will prove to be correct. In
addition to other factors and assumptions which may be identified
herein, assumptions have been made regarding, among other things: the
impact of increasing competition; the general stability of the
economic and political environment in which the Company operates; the
timely receipt of any required regulatory approvals; the ability of
the Company to obtain qualified staff, equipment and services in a
timely and cost efficient manner; drilling results; the ability of
the operator of the projects which the Company has an interest in to
operate the field in a safe, efficient and effective manner; the
ability of the Company to obtain financing on acceptable terms; field
production rates and decline rates; the ability to replace and expand
oil and natural gas reserves through acquisition, development and
exploration; the timing and costs of pipeline, storage and facility
construction and expansion and the ability of the Company to secure
adequate product transportation; future commodity prices; currency,
exchange and interest rates; the regulatory framework regarding
royalties, taxes and environmental matters in the jurisdictions in
which the Company operates; and the ability of the Company to
successfully market and receive payment for its oil and natural gas
products.  
Readers are cautioned that the foregoing list is not exhaustive of
all factors and assumptions which have been used. As a consequence,
actual results may differ materially from those anticipated in the
forward-looking statements. Additional information on these and other
factors that could affect the Company's operations and financial
results are included in reports on file with Canadian securities
regulatory authorities and may be accessed through the SEDAR website
(www.sedar.com), EDGAR website (www.sec.gov) and at the Company's
website (www.trans-globe.com). Furthermore, the forward-looking
statements or information contained herein are made as at the date
hereof and the Company does not undertake any obligation to update
publicly or to revise any of the included forward-looking statements,
whether as a result of new information, future events or otherwise,
except as may be required by applicable securities laws.  
The reader is further cautioned that the preparation of financial
statements in accordance with IFRS requires management to make
certain judgments and estimates that affect the reported amounts of
assets, liabilities, revenues and expenses. Estimating reserves is
also critical to several accounting estimates and requires judgments
and decisions based upon available geological, geophysical,
engineering and economic data. These estimates may change, having
either a negative or positive effect on net earnings as further
information becomes available, and as the economic environment
changes. 
Additional 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 IFRS. Funds flow from operations is a 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. 


 
Reconciliation of Funds Flow from Operations                                
                                      Three Months Ended   Nine Months Ended
                                            September 30        September 30
----------------------------------------------------------------------------
($000s)                                   2012      2011      2012      2011
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Cash flow from operating activities      2,368     3,456    28,742    61,300
Changes in non-cash working capital     33,029    34,524    77,917    32,207
----------------------------------------------------------------------------
Funds flow from operations(i)           35,397    37,980   106,659    93,507
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
(i) Funds flow from operations does not include interest or financing
costs. Interest expense is included in financing costs on the
Condensed Consolidated Interim Statements of Earnings and
Comprehensive Income. Cash interest paid is reported as a financing
a
ctivity on the Condensed Consolidated Interim Statements of Cash
Flows. 
Debt-to-funds flow ratio  
Debt-to-funds flow is a 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, plus
convertible debentures 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 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. 
BUSINESS ACQUISITIONS  
On July 26, 2012, the Company completed a Share Purchase Agreement to
acquire 100% of the common shares of Cepsa Egypt SA B.V. ("Cepsa
Egypt"), a wholly-owned subsidiary of Compania Espanola De Petroleos,
S.A.U. ("Cepsa"), a company registered in Spain. Cepsa Egypt holds an
operated 50% working interest in the South Alamein Production Sharing
concession ("PSC") in Egypt. As a result, the Company now holds a
100% working interest in the South Alamein concession through two
wholly-owned subsidiaries. The Cepsa transaction was structured as an
all-cash deal, effective July 1, 2012, funded through working
capital. Total consideration for the transaction was $4.9 million,
which represents the initial $3.0 million base purchase price plus
$1.9 million in consumable drilling equipment inventory (which is
classified as exploration and evaluation assets), working capital and
other closing adjustments.  
On June 7, 2012, the Company completed a Share Purchase Agreement to
acquire 100% of the common shares of a wholly-owned subsidiary of EP
Energy LLC which holds, though wholly-owned subsidiaries, a
non-operated 50% interest in the South Alamein PSC in Egypt and an
operated 60% working interest in the South Mariut PSC in Egypt. The
South Alamein concession covers an area of 355,832 acres, and an
extensive 3-D seismic covers the entire area. There is currently one
oil discovery well in South Alamein. The South Mariut concession
covers an area of approximately 828,000 acres and includes the
approval of a 14,500 foot exploration well which began drilling on
October 10, 2012. The transaction was structured as an all-cash deal,
effective April 1, 2012, funded through working capital and the
proceeds of the issuance of convertible debentures. Total
consideration for the transaction was $23.3 million, which represents
the initial $15.0 million base purchase price plus $8.3 million in
consumable drilling equipment inventory (which is classified as
exploration and evaluation assets), working capital and other closing
adjustments. 
SELECTED QUARTERLY FINANCIAL INFORMATION 


 
                       2012                        2011                 2010
----------------------------------------------------------------------------
($000s,                                                                     
 except per                                                                 
 share,                                                                     
 price and                                                                  
 volume                                                                     
 amounts)        Q-3     Q-2     Q-1     Q-4     Q-3     Q-2     Q-1     Q-4
----------------------------------------------------------------------------
                                                                            
Average                                                                     
 production                                                                 
 volumes                                                                    
(Bopd)        18,143  16,978  16,720  12,054  13,406  11,826  11,218  10,789
                                                                            
Average                                                                     
 sales                                                                      
 volumes                                                                    
 (Bopd)       17,124  16,978  16,720  12,054  13,406  11,826  11,218  10,789
Average                                                                     
 price                                                                      
 ($/Bbl)       96.88   95.84  104.78   99.12  104.00  105.57   97.06   79.83
Oil sales    152,624 148,078 159,426 109,919 128,265 113,615  97,995  79,240
Oil sales,                                                                  
 net of                                                                     
 royalties    74,540  73,633  77,212  60,609  71,769  62,513  52,863  45,198
Cash flow                                                                   
 from                                                                       
 operating                                                                  
 activities    2,368  24,603   1,771   2,330   3,456  54,354   3,490  17,010
Funds flow                                                                  
 from                                                                       
 operations                                                                 
 (i)          35,397  35,174  36,088  26,469  37,980  30,597  24,930  19,355
Funds flow                                                                  
 from                                                                       
 operations                                                                 
 per share                                                                  
  - Basic       0.49    0.48    0.49    0.36    0.52    0.42    0.35    0.29
  - Diluted     0.47    0.43    0.48    0.35    0.51    0.40    0.34    0.28
Net earnings  11,774  30,149  10,975  30,519  26,110  21,874   2,889   8,932
Net earnings                                                                
 - diluted    11,774  20,821  10,975  30,519  26,110  21,874   2,889   8,932
Net earnings                                                                
 per share                                                                  
  - Basic       0.16    0.41    0.15    0.42    0.36    0.30    0.04    0.13
  - Diluted     0.16    0.25    0.15    0.41    0.35    0.29    0.04    0.13
----------------------------------------------------------------------------
                                                                            
Total assets 635,529 620,937 648,012 525,806 465,262 420,956 404,184 345,625
Cash and                                                                    
 cash                                                                       
 equivalents  45,732  72,230 127,313  43,884 105,007 122,659  86,353  57,782
Convertible                                                                 
 debentures  102,920  95,043 105,835       -       -       -       -       -
Total long-                                                                 
 term debt,                                                                 
 including                                                                  
 current                                                                    
 portion      31,878  37,855  57,910  57,609  57,303  56,998  56,731  86,420
Debt-to-                                                                    
 funds flow                                                                 
 ratio (ii)      1.0     1.0     1.2     0.5     0.5     0.6     0.7     1.1
----------------------------------------------------------------------------

 
(i) Funds flow from operations is a measure that represents cash
generated from operating activities before changes in non-cash
working capital, and may not be comparable to measures used by other
companies.  
(ii) Debt-to-funds flow ratio is a measure that represents total
long-term debt (including current portion) and convertible debentures
over funds flow from operations for the trailing 12 months, and may
not be comparable to measures used by other companies.  
During the third quarter of 2012, TransGlobe has:  


 
--  Maintained a strong financial position, reporting a debt-to-funds flow
    ratio of 1.0 at September 30, 2012; 
--  Reported net earnings of $11.8 million; 
--  Reported net earnings of $16.1 million prior to the unrealized fair
    value adjustment on convertible debentures; 
--  Achieved funds flow from operations of $35.4 million; and 
--  Spent $17.5 million on capital programs and acquisitions, which were
    funded entirely with cash on hand. 

 
The accounting for the convertible debentures continued to have a
significant impact on important components of the Company's financial
statements: 


 
--  Reported a decrease in net earnings of $18.4 million from the second
    quarter of 2012. This decrease was due in large part to the unrealized
    gain on convertible debentures of $8.8 million recognized in the second
    quarter of 2012, combined with an unrealized loss of $4.4 million
    recognized on the convertible debentures in the third quarter of 2012;
    and 
--  Reported a decrease in net earnings of $14.3 million or 55% in the third
    quarter of 2012 compared to the third quarter of 2011, which was also
    due partly to an unrealized loss on convertible debentures of $4.4
    million in the second quarter of 2012. 
 
2012 VARIANCES                                                              
                                                  $ Per Share               
                                         $000s        Diluted     % Variance
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Q3-2011 net earnings                   26,110           0.35                
----------------------------------------------------------------------------
Cash items                                                                  
Volume variance                        32,780           0.44            126 
Price variance                         (8,421)         (0.11)           (32)
Royalties                             (21,588)         (0.29)           (82)
Expenses:                                                                   
 Production and operating              (1,860)         (0.02)            (7)
 Cash general and                                                           
  administrative                       (2,237)         (0.03)            (9)
 Exploration                              202              -              1 
 Current income taxes                  (1,298)         (0.02)            (5)
 Realized foreign exchange gain          (113)             -              - 
 Interest on long-term debt            (1,614)         (0.02)            (6)
Other income                              (48)             -              - 
----------------------------------------------------------------------------
Total cash items variance              (4,197)         (0.05)           (14)
----------------------------------------------------------------------------
Non-cash items                                                              
Unrealized derivative gain                 13              -             (1)
Unrealized foreign exchange                                                 
 gain                                  (2,812)         (0.04)           (11)
Depletion, depreciation and                                                 
 amortization                            (705)         (0.01)            (3)
Unrealized gain (loss) on                                                   
 financial instruments                 (4,361)         (0.06)           (17)
Impairment loss                            68              -              - 
Stock-based compensation                 (762)         (0.01)            (3)
Deferred income taxes                  (2,002)         (0.03)            (8)
Deferred lease inducement                   6              -              - 
Amortization of deferred                                                    
 financing costs                          416           0.01              2 
----------------------------------------------------------------------------
Total non-cash items variance         (10,139)         (0.14)           (41)
----------------------------------------------------------------------------
Q3-2012 net earnings                   11,774           0.16            (55)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
Net earnings decreased to $11.8 million in Q3-2012 compared to $26.1
million in Q3-2011, which was mainly due to an unrealized loss on
financial instruments (convertible debentures) combined with
increases in deferred tax expense and cash general and administrative
expenses in Q3-2012. The earnings impact of increased volumes were
mostly offset by price reductions and increases in royalties, income
taxes, operating costs and foreign exchange fluctuations. Increased
expenses were a result of the increased volumes.  
The non-cash unrealized loss on financial instruments (convertible
debentures) has arisen because the Company has elected to carry the
convertible debenture liability at fair value on its Condensed
Consolidated Interim Balance Sheets. Fair value is determined based
on the quoted market price of the convertible debentures as at the
period end date. Based on quoted market prices, a $4.4 million
increase to the convertible debenture liability was recorded as at
September 30, 2012, with a corresponding loss recorded on the
Condensed Consolidated Interim Statement of Earnings and
Comprehensive Income. As the market price of the convertible
debentures fluctuates from period to period, so will the fair value
of the convertible debenture liability, and therefore so will the
unrealized gain or loss on financial instruments (convertible
debentures). This fair value adjustment has had a significant impact
on net earnings in the first three quarters of 2012, and, depending
on the magnitude of fluctuations in the trading price of the
convertible debentures in future periods, could have a material
impact on the Company's net earnings in future periods. While this
fair value adjustment is made in accordance with IFRS, it does not
represent a cash gain or loss or a change in the future cash outlay
required to redeem the convertible debentures. 
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:  


 
                                              2012                2011      
----------------------------------------------------------------------------
                                         Q-3     Q-2     Q-1     Q-4     Q-3
----------------------------------------------------------------------------
Dated Brent average oil price                                               
 ($/Bbl)                              109.61  108.19  118.49  109.31  113.44
U.S./Canadian Dollar average                                             
   
 exchange rate                         0.995   1.006   1.001   1.023   0.980
----------------------------------------------------------------------------

 
The price of Dated Brent oil averaged 3% lower in Q3-2012 compared
with Q3-2011. All of the Company's production is priced based on
Dated Brent and shared with the respective governments through
Production Sharing Agreements. When the price of oil goes up, it
takes fewer barrels to recover costs (cost recovery barrels) which
are assigned 100% to the Company. The contracts provide for cost
recovery per quarter up to a maximum percentage of total revenue.
Typically maximum cost recovery or cost oil ranges from 25% to 30% in
Egypt and 50% to 60% in Yemen. Generally the balance of the
production is shared with the respective governments (production
sharing oil). Depending on the contract, the government receives 70%
to 86% of the production sharing oil or profit oil. Production
sharing splits are set in each contract for the life of the contract.
Typically the government's share of production sharing oil increases
when production exceeds pre-set production levels in the respective
contracts. During times of increased oil prices, the Company receives
less cost oil and may receive more production sharing oil. For
reporting purposes, the Company records the respective government's
share of production as royalties and taxes (all taxes are paid out of
the Government's share of production).  
During the political change in Egypt, business processes and
operations have generally proceeded as normal. The Company continues
to expand its footprint in Egypt as evidenced by the closing of
recent business acquisitions. While exploration and development
activities have been uninterrupted for the most part, the Company has
experienced delays in the collection of accounts receivable from the
Egyptian Government due to the economic impact caused by instability
in the country. The Company is in continual discussions with the
Egyptian Government to determine solutions to the delayed cash
collections, and still expects to recover the accounts receivable
balance in full. Yemen is still unsettled, however, the Company's
production from Block S-1, which was shut-in on October 8, 2011, was
back on production as of July 27, 2012. Production from Block S-1
averaged 965 Bopd to TransGlobe during Q3-2012. The Company's
historic crude marketing agreements for Block S-1 production have
changed. Post re-start of Block S-1 the Company will now be paid on
crude vessel liftings rather than on a monthly basis. As a result,
sales production will no longer equate to physical production. Sales
volumes versus production volumes will vary during the quarters
depending on the timing of tanker liftings in the respective
quarters. 
OPERATING RESULTS AND NETBACK  
Daily Volumes, Working Interest before Royalties (Bopd) 
Production Volumes 


 
                                      Three Months Ended   Nine Months Ended
                                            September 30        September 30
----------------------------------------------------------------------------
                                          2012      2011      2012      2011
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Egypt                                   16,853    11,138    16,622    10,419
Yemen                                    1,290     2,268       662     1,739
----------------------------------------------------------------------------
Total Company                           18,143    13,406    17,284    12,158
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
Sales Volumes 


 
                                      Three Months Ended   Nine Months Ended
                                            September 30        September 30
----------------------------------------------------------------------------
                                          2012      2011      2012      2011
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Egypt                                   16,853    11,138    16,622    10,419
Yemen                                      271     2,268       320     1,739
----------------------------------------------------------------------------
Total Company                           17,124    13,406    16,942    12,158
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
Netback  
Consolidated 


 
                                          Nine Months Ended September 30    
                                             2012                2011       
----------------------------------------------------------------------------
(000s, except per Bbl amounts)               $     $/Bbl         $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil sales                              460,128     99.12   339,875    102.40
Royalties                              234,743     50.57   152,730     46.02
Current taxes                           66,216     14.26    55,827     16.82
Production and operating expenses       35,024      7.54    26,404      7.96
----------------------------------------------------------------------------
Netback                                124,145     26.75   104,914     31.60
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                          Three Months Ended September 30   
----------------------------------------------------------------------------
                                             2012                2011       
----------------------------------------------------------------------------
(000s, except per Bbl amounts)               $     $/Bbl         $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil sales                              152,623     96.88   128,265    104.00
Royalties                               78,083     49.56    56,496     45.81
Current taxes                           21,634     13.73    20,336     16.49
Production and operating expenses       11,622      7.38     9,762      7.92
----------------------------------------------------------------------------
Netback                                 41,284     26.21    41,671     33.78
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
Egypt 


 
                                          Nine Months Ended September 30    
----------------------------------------------------------------------------
                                             2012                2011       
----------------------------------------------------------------------------
(000s, except per Bbl amounts)               $     $/Bbl         $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil sales                              450,374     98.89   288,426    101.40
Royalties                              230,649     50.64   129,665     45.59
Current taxes                           64,890     14.25    49,350     17.35
Production and operating expenses       29,552      6.49    19,930      7.01
----------------------------------------------------------------------------
Netback                                125,283     27.51    
89,481     31.45
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                       Three Months Ended September 30      
                                             2012                2011       
----------------------------------------------------------------------------
(000s, except per Bbl amounts)               $     $/Bbl         $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil sales                              149,961     96.72   104,780    102.25
Royalties                               77,032     49.68    47,044     45.91
Current taxes                           21,318     13.75    17,783     17.35
Production and operating expenses       10,510      6.78     7,065      6.89
----------------------------------------------------------------------------
Netback                                 41,101     26.51    32,888     32.10
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
The netback per Bbl in Egypt decreased 17% and 13% respectively, in
the three and nine months ended September 30, 2012 compared with the
same periods of 2011, mainly as a result of a 5% and 2% decrease in
the selling price on a per Bbl basis. The average selling price
during the three months ended September 30, 2012 was $96.72/Bbl,
which represents a gravity/quality adjustment of approximately
$12.89/Bbl to the average Dated Brent oil price for the period of
$109.61/Bbl.  
Royalties and taxes as a percentage of revenue increased to 66% in
the three and nine months ended September 30, 2012, compared with 62%
in the same periods of 2011. This increase is due to the fact that
the three and nine month periods ended September 30, 2011 included
only West Gharib production, whereas 2012 includes West Gharib and
West Bakr production. West Bakr production is subject to higher
Government takes according to the West Bakr Production Sharing
concession.   
Operating expenses decreased slightly on a per Bbl basis for the
three and nine month periods ended September 30, 2012 compared with
the same period of 2011. This is due to the inclusion of West Bakr in
the 2012 figures. West Bakr has slightly lower operating costs on a
per Bbl basis than West Gharib, which is due mostly to lower oil
handling fees per Bbl along with the absence of trucking costs in
West Bakr. 
Yemen 


 
                                              Nine Months Ended September 30
----------------------------------------------------------------------------
                                                   2012                 2011
----------------------------------------------------------------------------
(000s, except per Bbl amounts)              $     $/Bbl          $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil sales                               9,754    111.25     51,449    108.37
Royalties                               4,094     46.69     23,065     48.58
Current taxes                           1,326     15.12      6,477     13.64
Production and operating expenses       5,472     62.41      6,474     13.64
----------------------------------------------------------------------------
Netback                                (1,138)   (12.97)    15,433     32.51
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
                                         Three Months Ended September 30    
----------------------------------------------------------------------------
                                             2012                2011       
----------------------------------------------------------------------------
(000s, except per Bbl amounts)               $     $/Bbl         $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Oil sales                                2,662    106.77    23,485    112.55
Royalties                                1,051     42.15     9,452     45.30
Current taxes                              316     12.67     2,553     12.24
Production and operating expenses        1,112     44.60     2,697     12.93
----------------------------------------------------------------------------
Netback                                    183      7.35     8,783     42.08
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
In Yemen, the Company experienced an 83% netback reduction on a per
Bbl basis in the three months ended September 30, 2012 compared with
the same period of 2011, and a negative netback of $12.97 per Bbl in
the nine months ended September 30, 2012. Operating expenses on a per
Bbl basis increased substantially (245% and 358%, respectively) in
the three and nine months ended September 30, 2012 compared to the
same periods in 2011 as a result of production being shut-in on Block
S-1 from the beginning of the year until July 27, 2012. While
production volumes were down, the Company continued to incur the
majority of the operating costs on Block S-1 which significantly
increased operating expenses per Bbl.  
Royalties and taxes as a percentage of revenue were 51% and 56%,
respectively, in the three and nine months ended September 30, 2012,
which is consistent with the comparative percentages of 51% and 57%,
respectively, from the same periods of 2011.  
Production and operating expenses associated with the production of
unsold crude oil held in storage have been recorded as product
inventory and are therefore not included in the netback calculations.
The per Bbl figures in the netback calculations are based on sales
volumes.  
Production from Block S-1 recommenced on July 27, 2012 after having
been shut-in following an attack on the oil export pipeline on
October 8, 2011. The Block S-1 operating expenses incurred during the
shut-in period are recoverable through cost oil on future production. 
DERIVATIVE COMMODITY CONTRACTS  
TransGlobe uses hedging arrangements from time to time as part of its
risk management strategy to manage commodity price fluctuations and
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.  
As there are no outstanding derivative commodity contracts at
September 30, 2012, no assets or liabilities have been recognized on
the Condensed Consolidated Interim Balance Sheet for the current
period. As at September 30, 2012, no production is hedged in future
periods.  
GENERAL AND ADMINISTRATIVE EXPENSES ("G&A") 


 
                                         Nine Months Ended September 30     
----------------------------------------------------------------------------
                                            2012                2011        
----------------------------------------------------------------------------
(000s, except per Bbl amounts)              $     $/Bbl         $     $/Bbl 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
G&A (gross)                            18,993      4.09    13,138      3.94 
Stock-based compensation                3,477      0.75     2,139      0.64 
Capitalized G&A and overhead           (1,641)    (0.35)   (1,686)    (0.51)
 recoveries                 
                                                
----------------------------------------------------------------------------
G&A (net)                              20,829      4.49    13,591      4.07 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
                                         Three Months Ended September 30    
----------------------------------------------------------------------------
                                            2012                2011        
----------------------------------------------------------------------------
(000s, except per Bbl amounts)              $     $/Bbl         $     $/Bbl 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
G&A (gross)                             6,112      3.88     4,588      3.72 
Stock-based compensation                1,500      0.95       797      0.65 
Capitalized G&A and overhead                                                
 recoveries                              (262)    (0.17)   (1,028)    (0.83)
----------------------------------------------------------------------------
G&A (net)                               7,350      4.66     4,357      3.54 
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
G&A expenses (net) increased 69% (32% on a per Bbl basis) and 53%
(10% on a per Bbl basis) in the three and nine months ended September
30, 2012, compared with the same period in 2011. The increase is
principally due to increased staffing, administration and insurance
costs associated with West Bakr, along with increased costs
associated with recent acquisitions (South Alamein and South Mariut). 
The increase in stock-based compensation is due partly to an increase
in the total value of new options awarded during 2012 as compared to
those issued during 2011, combined with an increase in the expense
recorded on share appreciation rights in the nine months of 2012 as a
result of share price increases. 
FINANCE COSTS  
Finance costs for the three and nine months ended September 30, 2012
increased to $2.5 million and $11.5 million, respectively (2011 -
$1.3 million and $3.8 million, respectively). Finance costs include
interest on long-term debt and convertible debentures, issue costs on
convertible debentures and amortization of transaction costs
associated with long-term debt. The overall increase in finance costs
is due to higher debt levels combined with the costs of issuing the
convertible debentures. 


 
                                    Three Months Ended     Nine Months Ended
                                          September 30          September 30
----------------------------------------------------------------------------
(000s)                                 2012       2011       2012       2011
----------------------------------------------------------------------------
Interest expense                 $    2,144 $      963 $    5,905 $    2,886
Issue costs for convertible                                                 
 debentures                               -          -      4,630          -
Amortization of deferred                                                    
 financing costs                        323        306        953        884
----------------------------------------------------------------------------
Finance costs                    $    2,467 $    1,269 $   11,488 $    3,770
----------------------------------------------------------------------------

 
The Company had $33.7 million of long-term debt outstanding at
September 30, 2012 (September 30, 2011 - $60.0 million). The
long-term debt that was outstanding at September 30, 2012 bore
interest at LIBOR plus an applicable margin that varies from 3.75% to
4.75% depending on the amount drawn under the facility.  
In February 2012, the Company sold, on a bought-deal basis, C$97.8
million ($97.9 million) aggregate principal amount of convertible
unsecured subordinated debentures with a maturity date of March 31,
2017. Transaction costs of $4.6 million relating to the issuance of
the convertible debentures were expensed in the nine months ended
September 30, 2012. The debentures are convertible at any time and
from time to time into common shares of the Company at a price of
C$15.10 per common share. The debentures are not redeemable by the
Company on or before March 31, 2015 other than in limited
circumstances in connection with a change of control of TransGlobe.
After March 31, 2015 and prior to March 31, 2017, the debentures may
be redeemed by the Company at a redemption price equal to the
principal amount plus accrued and unpaid interest, provided that the
weighted-average trading price of the common shares for the 20
consecutive trading days ending five trading days prior to the date
on which notice of redemption is provided is not less than 125
percent of the conversion price (or C$18.88). Interest of 6% is
payable semi-annually in arrears on March 31 and September 30. The
first semi-annual interest payment was made on September 30, 2012
which included 39 days prior to March 31, 2012. At maturity or
redemption, the Company has the option to settle all or any portion
of principal obligations by delivering to the debenture holders
sufficient common shares to satisfy these obligations. 
DEPLETION AND DEPRECIATION ("DD&A") 


 
                                         Nine Months Ended September 30     
----------------------------------------------------------------------------
                                            2012                2011        
----------------------------------------------------------------------------
(000s, except per Bbl amounts)               $     $/Bbl         $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Egypt                                   33,570      7.37    22,746      8.00
Yemen                                      645      7.36     3,166      6.67
Corporate                                  301         -       351         -
----------------------------------------------------------------------------
                                        34,516      7.44    26,263      7.91
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                         Three Months Ended September 30    
----------------------------------------------------------------------------
                                            2012                2011        
----------------------------------------------------------------------------
(000s, except per Bbl amounts)               $     $/Bbl         $     $/Bbl
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Egypt                                   10,706      6.90     8,781      8.57
Yemen                                      196      7.86     1,408      6.75
Corporate                                  103         -       111         -
----------------------------------------------------------------------------
                                        11,005      6.99    10,300      8.35
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
In Egypt, DD&A decreased 19% and 8%, respectively, on a per Bbl basis
for the three and nine month periods ended September 30, 2012. These
decreases are mostly due to proved plus probable reserve additions
during the third quarter of 2012.  
In Yemen, DD&A increased 16% and 10%, respectively, on a per Bbl
basis for the three and nine month periods ended September 30, 2012.
These increases are mostly due to a smaller reserve base over which
capital costs are being depleted compared to 2011. 
CAPITAL EXPENDITURES 


 
                                                           Nine Months Ended
                                                                September 30
----------------------------------------------------------------------------
($000s)                                                       2012      2011
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Egypt                                                       30,368    52,570
Yemen                                                        1,003     5,557
Acquisitions                                                27,978         -
Corporate                                                      130     1,417
----------------------------------------------------------------------------
Total                                                       59,479    59,544
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
In Egypt, total capital expenditures in the first nine months of 2012
were $30.4 million (2011 - $52.6 million). The Company drilled 20
wells at West Gharib (thirteen at Arta and seven at East Arta) during
the first nine months of the year. During the second and third
quarters of 2012 the Company drilled five wells at West Bakr and two
wells at East Ghazalat. Production is currently restricted at West
Gharib due to volume constraints at the processing facility. As a
result, the capital cost per well drilled in West Gharib has
decreased as the Company has chosen not to proceed with the
completion and equipping of those new wells, which will require
fracture stimulations, until the fourth quarter of 2012 or during
2013. Furthermore, movable equipment is being redeployed from shut-in
wells to producing wells.  
On July 26, 2012, the Company completed a Share Purchase Agreement to
acquire 100% of the common shares of Cepsa Egypt SA B.V. ("Cepsa
Egypt"), a wholly-owned subsidiary of Compania Espanola De Petroleos,
S.A.U. ("Cepsa"), a company registered in Spain. Cepsa Egypt holds an
operated 50% working interest in the South Alamein PSC in Egypt. As a
result, the Company now holds a 100% working interest in the South
Alamein concession through two wholly-owned subsidiaries. The Cepsa
transaction was structured as an all-cash deal, effective July 1,
2012, funded through working capital. Total consideration for the
transaction was $4.9 million, which represents a $3.0 million base
purchase price plus $1.9 million in consumable drilling inventory
(which is classified as exploration and evaluation assets), working
capital and other closing adjustments.  
On June 7, 2012, the Company completed a Share Purchase Agreement to
acquire 100% of the common shares of a wholly-owned subsidiary of EP
Energy LLC which holds, through wholly-owned subsidiaries, a
non-operated 50% interest in the South Alamein PSC in Egypt and an
operated 60% working interest in the South Mariut PSC in Egypt. The
transaction was structured as an all-cash deal, effective April 1,
2012, funded through working capital and the proceeds of the issuance
of convertible debentures. Total consideration for the transaction
was $23.3 million, which represents a $15.0 million base purchase
price plus $8.3 million in working capital and other closing
adjustments.  
OUTSTANDING SHARE DATA  
As at September 30, 2012, the Company had 73,758,638 common shares
issued and outstanding. 
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 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 evaluate the Company's overall financial
strength is debt-to-funds flow from operations (calculated on a
12-month trailing basis). TransGlobe's debt-to-funds flow from
operations ratio, a key short-term leverage measure, remained strong
at 1.0 times at September 30, 2012. This is 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 periods ended September 30, 2012 and 2011: 


 
Sources and Uses of Cash                                                    
                                                          Nine Months Ended 
                                                               September 30 
----------------------------------------------------------------------------
($000s)                                                   2012         2011 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Cash sourced                                                                
  Funds flow from operations(i)                        106,659       93,507 
  Transfer from restricted cash                            806        1,161 
  Issue of convertible debentures                       97,851            - 
  Exercise of stock options                              3,196        1,828 
  Issuance of common shares, net of share issuance                          
   costs                                                     -       71,583 
  Other                                                    814          772 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                       209,326      168,851 
Cash used                                                                   
  Capital expenditures                                  31,501       59,544 
  Deferred financing costs                                 383            - 
  Acquisitions                                          27,978            - 
  Repayment of long-term debt                           26,300       30,000 
  Finance costs                                         10,203        2,453 
  Other                                                    435          463 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                        96,800       92,460 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                       112,526       76,391 
Changes in non-cash working capital                   (110,678)     (29,166)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Increase in cash and cash equivalents                    1,848       47,225 
Cash and cash equivalents - beginning of period         43,884       57,782 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Cash and cash equivalents - end of period               45,732      105,007 
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
(i) Funds flow from operations is a measure that represents cash
generated from operating act
ivities before changes in non-cash
working capital.  
Funding for the Company's capital expenditures was provided by funds
flow from operations. The Company expects to fund its 2012
exploration and development program of $52.0 million ($20.5 million
remaining) and contractual commitments through the use of working
capital and cash generated by operating activities. Fluctuations in
commodity prices, product demand, 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 September 30, 2012, the Company had working capital
of $252.2 million (December 31, 2011 - $140.0 million). The increase
to working capital in 2012 is principally a result of an increase in
accounts receivable between December 31, 2011 and September 30, 2012,
combined with a decrease in accounts payable during the same period.
The majority of the Company's accounts receivable are due from
Egyptian General Petroleum Company ("EGPC"), and the recent political
changes in the country have increased the Company's credit risk. The
Company is in continual discussions with EGPC and the Egyptian
Government to determine solutions to the delayed cash collections,
and still expects to recover the entire accounts receivable balance
in full. Subsequent to the end of the third quarter, the Company
received notification that it will collect $52.5 million in late
November via an exported shipment of crude oil designated for
TransGlobe.  
In February 2012, the Company sold, on a bought-deal basis, C$97.8
million ($97.9 million) aggregate principal amount of convertible
unsecured subordinated debentures with a maturity date of March 31,
2017. Transaction costs of $4.6 million relating to the issuance of
the convertible debentures were expensed in the nine months ended
September 30, 2012. The debentures are convertible at any time and
from time to time into common shares of the Company at a price of
C$15.10 per common share. The debentures are not redeemable by the
Company on or before March 31, 2015 other than in limited
circumstances in connection with a change of control of TransGlobe.
After March 31, 2015 and prior to March 31, 2017, the debentures may
be redeemed by the Company at a redemption price equal to the
principal amount plus accrued and unpaid interest, provided that the
weighted-average trading price of the common shares for the 20
consecutive trading days ending five trading days prior to the date
on which notice of redemption is provided is not less than 125
percent of the conversion price (or C$18.88). Interest of 6% is
payable semi-annually in arrears on March 31 and September 30. The
first semi-annual interest payment was made on September 30, 2012
which includes 39 days prior to March 31, 2012. At maturity or
redemption, the Company has the option to settle all or any portion
of principal obligations by delivering to the debenture holders
sufficient common shares to satisfy these obligations.  
At September 30, 2012, TransGlobe had $85.5 million available under a
Borrowing Base Facility of which $33.7 million was drawn. As
repayments on the Borrowing Base Facility are not expected to
commence until 2014, the entire balance is presented as a long-term
liability on the Condensed Consolidated Interim Balance Sheets.
Repayments will be made as required according to the scheduled
reduction of the facility. 


 
                                               September 30,   December 31, 
($000s)                                                 2012           2011 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Bank debt                                             33,700         60,000 
Deferred financing costs                              (1,822)        (2,391)
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Long-term debt (net of deferred financing                                   
 costs)                                               31,878         57,609 
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
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:  


 
($000s)                              Payment Due by Period(1,2)             
----------------------------------------------------------------------------
                     Recognized                                             
                     in                       Less                          
                     Financial Contractual  than 1     1-3     4-5 More than
                     Statements Cash Flows    year   years   years   5 years
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Accounts payable and Yes-                                                   
 accrued liabilities Liability      47,603  47,603       -       -         -
                                                                            
Long-term debt       Yes-                                                   
                     Liability      33,700       -  33,700       -         -
                                                                            
Convertible          Yes-                                                   
 debentures          Liability     102,920       -       - 102,920         -
                                                                            
Office and equipment                                                        
 leases              No             13,019   4,936   2,438   2,094     3,551
                                                                            
Minimum work                                                                
 commitments(3)      No                750     750       -       -         -
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Total                              197,992  53,289  36,138 105,014     3,551
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Payments exclude ongoing operating costs, finance costs and payments made to
settle derivatives.                                                         
Payments denominated in foreign currencies have been translated at September
30, 2012 exchange rates.                                                    
Minimum work commitments include contracts awarded for capital projects and 
those commitments related to exploration and drilling obligations.          

 
Pursuant to the PSA for Block 75 in Yemen, the Contractor (Joint
Interest Partners) has a remaining minimum financial commitment of
$3.0 million ($0.8 million to TransGlobe) for one exploration well in
the first exploration period, which has been extended to March 9,
2013.  
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. Based on the Company's annual Reserve Report
effective December 31, 2011, no additional fees are due in 2012.  
Pursuant to the June 7, 2012 share purchase agreement for a 60%
operated interest in the South Mariut concession in Egypt, the
Contractor (Joint Interest Partners) has a minimum financial
commitment of $9.0 million ($5.4 million to TransGlobe) for three
exploration wells ($3.0 million each) which were commitments from the
original exploration period and were carried into the first
three-year extension period, which expires on April 5, 2013. The
Company issued three $3.0 million letters of credit to guarantee
performance under this extension period and has commenced drilling
the first of three planned wells. To date all financial commitments
have been met. There is a further two-year extension available under
the terms of the PSC.  
Pursuant to the June 7, 2012 and July 26, 2012 share purchase
agreements for a combined 100% operated interest in the South Alamein
concession in Egypt, the Company has a commitment to drill one well
(all financial commitments have been met) prior to the termination of
the final two-year extension period, which expires on April 5, 2014.  
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.  
The Company is not aware of any material provisions or other
contingent liabilities as at September 30, 2012.  
EVENTS AFTER THE REPORTING PERIOD  
On November 6, 2012, the Company received notification that it was
the successful bidder on four concessions in the 2011/2012 EGPC bid
round in Egypt. The new concessions will be awarded following the
ratification process which culminates when each concession is passed
into law by the Egyptian People's Assembly (Parliament). All four
concessions have a seven year exploration term which will commence
when the respective concessions are passed into law. The seven year
term is comprised of three phases starting with an initial three year
exploration period and two additional two year extension periods. The
Company committed to spending $101 million in the first exploration
period (3 years) including signature bonuses, the acquisition of new
2D and 3D seismic, and an extensive drilling program approaching 40
wells. 
MANAGEMENT STRATEGY AND OUTLOOK FOR 2012  
The 2012 outlook provides information as to management's expectation
for results of operations for 2012. Readers are cautioned that the
2012 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", outlined
on the first page of this MD&A.  
2012 Outlook Highlights 


 
--  Production is expected to average 17,500 Bopd, a 44% increase over the
    2011 average production; 
--  Exploration and development spending is expected to be $52.0 million
    excluding acquisitions; and 
--  Funds flow from operations is estimated at $147 million, an increase of
    23% over 2011, using an oil price assumption of $100.00 per barrel Dated
    Brent oil price for the remaining quarter of 2012. 

 
2012 Production Outlook 


 
Production Forecast                                                         
                                          2012                              
                                   Guidance(i)    2011 Actual       % Change
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Barrels of oil per day                  17,500         12,132             44
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
(i) Production is estimated to average approximately 17,500 for 2012,
assuming no additional production disruptions in Yemen and Egypt 
2012 Updated Funds Flow From Operations Outlook  
Funds flow from operations is estimated at $147.0 million
($1.96/share) based on an average Dated Brent oil price of $100/Bbl
for the remainder of the year. Variations in production and commodity
prices during the remainder of 2012 could significantly change this
outlook. An increase or decrease in the average Dated Brent oil price
of $10/Bbl for the remainder of the year would result in a
corresponding change in anticipated 2012 funds flow by approximately
$3.8 million or $0.05/share. 


 
Funds Flow Forecast                                                         
($ millions)                                                                
                                  2012 Updated                              
                                      Guidance    2011 Actual       % Change
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Funds flow from operations               147.0          120.0            23 
Dated Brent oil price ($ per                                                
 Bbl) (i)                               109.05         111.27            (2)
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
(i) Dated Brent oil price for 2012 Updated Guidance includes an
estimated price of $100/Bbl for Q4-2012. 


 
Revised 2012 Capital Budget                                                 
($ millions)                                                                
                                   Nine Months                              
                                         Ended                              
                                 September 30,           2012   Amended 2012
                                          2012       Guidance  Annual Budget
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Egypt                                     30.4           50.3           72.7
Yemen                                      1.0            1.5            5.4
Corporate                                  0.1            0.2            0.3
----------------------------------------------------------------------------
----------------------------------------------------------------------------
Total                                     31.5           52.0           78.4
----------------------------------------------------------------------------
----------------------------------------------------------------------------

 
The 2012 capital spending, excluding acquisitions, is now expected to
be approximately $52.0 million, a decrease of approximately $26
million from the amended budget. The capital spending will be lower,
primarily due to delays in the acquisition approvals and subsequent
operations.  
The Company plans to participate in 35 wells in 2012. It is
anticipated that the Company will fund its 2012 capital budget from
funds flow from operations and working capital. 
2013 Guidance  
The Company is planning to provide 2013 guidance for production,
funds flow and capital by mid-December 2012. 
CHANGES IN ACCOUNTING POLICIES  
New accounting policies 
IFRS 7 (revised) "Financial Instruments: Disclosures"  
In October 2010, the International Accounting Standards Board
("IASB") issued amendments to IFRS 7 to provide additional disclosure
on the transfer of financial assets including the possible effects of
any residual risks that the transferring entity retains. These
amendments are effective for annual periods beginning after July 1,
2011. In December 2011, the IASB issued further amendments to IFRS 7
to provide additional disclosures about offsetting financial assets
and financial liabilities on the entity's balance sheet when
permitted. These amendments are effective for annual periods
beginning on or after January 1, 2013. The Company has adopted these
amendments for the year ending December 31, 2012. These amendments
had no material impact to the Condensed Consolidated Interim
Financial Statements. 
IAS 12 (revised) "Income Taxes"  
In December 2010, the IASB issued amendments to IAS 12 to remove
subjectivity in determining on which basis an entity measures the
deferred tax relating to an asset. The amendments introduce a
presumption that entities will assess whether the carrying value of
an asset will be recovered through the sale of the asset. These
amendments are effective for annual periods beginning on or after
January 1, 2012; therefore, the Company has adopted them for the year
ending December 31, 2012. These amendments had no material impact to
the Condensed Consolidated Interim Financial Statements. 
Future changes to accounting policies  
The following standards and interpretations have not been adopted as
they apply to future periods. They may result in changes to the
Company's existing accounting policies and other note disclosures: 
IFRS 9 (revised) "Financial Instruments: Classification and
Measurement"  
In November 2009, the IASB issued IFRS 9 as part of its project to
replace IAS 39, "Financial Instruments: Recognition and Measurement".
In October 2010, the IASB updated IFRS 9 to include the requirements
for financial liabilities. IFRS 9 replaces the multiple rules in IAS
39 with a single approach to determine whether a financial asset is
measured at amortized cost or fair value. The approach in IFRS 9 is
based on how an entity manages its financial instruments in the
context of its business model and the contractual cash flow
characteristics of the financial assets. IFRS 9 is effective for
annual periods beginning on or after January 1, 2015. The Company is
currently evaluating the impact of this standard on its Consolidated
Financial Statements. 
IFRS 10 (new) "Consolidated Financial Statements"  
In May 2011, the IASB issued IFRS 10 to replace SIC-12,
"Consolidation - Special Purpose Entities", and parts of IAS 27,
"Consolidated and Separate Financial Statements". IFRS 10 establishes
principles for the presentation and preparation of consolidated
financial statements when an entity controls one or more other
entities. IFRS 10 is effective for annual periods beginning on or
after January 1, 2013. The Company does not expect the impact of this
standard on its Consolidated Financial Statements to be material. 
IFRS 11 (new) "Joint Arrangements"  
In May 2011, the IASB issued IFRS 11 to replace IAS 31, "Interests in
Joint Ventures", and SIC-13, "Jointly Controlled Entities -
Non-monetary Contributions by Venturers". IFRS 11 requires entities
to follow the substance rather than legal form of a joint arrangement
and removes the choice of accounting method. IFRS 11 is effective for
annual periods beginning on or after January 1, 2013. The Company
does not expect the impact of this standard on its Consolidated
Financial Statements to be material. 
IFRS 12 (new) "Disclosure of Interests in Other Entities"  
In May 2011, the IASB issued IFRS 12, which aggregates and amends
disclosure requirements included within other standards. IFRS 12
requires entities to provide disclosures about subsidiaries, joint
arrangements, associates and unconsolidated structured entities. IFRS
12 is effective for annual periods beginning on or after January 1,
2013. The Company does not expect the impact of this standard on its
Consolidated Financial Statements to be material. 
IFRS 13 (new) "Fair Value Measurement"  
In May 2011, the IASB issued IFRS 13 to clarify the definition of
fair value and provide guidance on determining fair value. IFRS 13
amends disclosure requirements included within other standards and
establishes a single framework for fair value measurement and
disclosure. IFRS 13 is effective for annual periods beginning on or
after January 1, 2013. The Company does not expect the impact of this
standard on its Consolidated Financial Statements to be material. 
IAS 1 (revised) "Presentation of Financial Statements"  
In June 2011, the IASB issued amendments to IAS 1 to require separate
presentation for items of other comprehensive income that would be
reclassified to profit or loss in the future from those that would
not. These amendments are effective for annual periods beginning on
or after July 1, 2012. The Company does not expect the impact of this
standard on its Consolidated Financial Statements to be material. 
IAS 19 (revised) "Employee Benefits"  
In June 2011, the IASB issued amendments to IAS 19 to revise certain
aspects of the accounting for pension plans and other benefits. The
amendments eliminate the corridor method of accounting for defined
benefit plans, change the recognition pattern of gains and losses,
and require additional disclosures. These amendments are effective
for annual periods beginning on or after January 1, 2013. The Company
does not expect the impact of this standard on its Consolidated
Financial Statements to be material. 
IAS 28 (revised) "Investments in Associates and Joint Ventures"  
In May 2011, the IASB issued amendments to IAS 28 to prescribe the
accounting for investments in associates and set out the requirements
for applying the equity method when accounting for investments in
associates and joint ventures. These amendments are effective for
annual periods beginning on or after January 1, 2013. The Company
does not expect the impact of this standard on its Consolidated
Financial Statements to be material. 
IAS 32 (revised) "Financial Instruments: Presentation"  
In December 2011, the IASB issued amendments to IAS 32 to address
inconsistencies when applying the offsetting criteria. These
amendments clarify some of the criteria required to be met in order
to permit the offsetting of financial assets and financial
liabilities. These amendments are effective for annual periods
beginning on or after January 1, 2014. The Company is currently
evaluating the impact of these amendments to its Consolidated
Financial Statements.  
INTERNAL CONTROLS OVER FINANCIAL REPORTING  
TransGlobe's management designed and implemented internal controls
over financial reporting, as defined under National Instrument 52-109
Certification of Disclosure in Issuers' Annual and Interim Filings,
of the Canadian Securities Administrators. Internal controls over
financial reporting is a process designed under the supervision of
the Chief Executive Officer and the Chief Financial Officer and
effected by the Board of Directors, management and other personnel to
provide reasonable assurance regarding the reliability of financial
reporting and the preparation of financial statements for external
purposes in accordance with IFRS, focusing in particular on controls
over information contained in the annual and interim financial
statements. Due to its inherent limitations, internal controls over
financial reporting may not prevent or detect misstatements on a
timely basis. A system of internal controls over financial reporting,
no matter how well conceived or operated, can provide only
reasonable, not absolute, assurance that the objectives of the
internal controls over financial reporting are met. Also, projections
of any evaluation of the effectiveness of internal control over
financial reporting to future periods are subject to the risk that
the controls may become inadequate because of changes in conditions,
or that the degree of compliance with policies or procedures may
deteriorate.  
No changes were made to the Company's internal control over financial
reporting during the period ended September 30, 2012 that have
materially affected, or are reasonably likely to materially affect,
the internal controls over financial reporting. 


 
Condensed Consolidated Interim Statements of Earnings and Comprehensive     
Income                                                 
                     
                                                                            
(Unaudited - Expressed in thousands of U.S. Dollars, except per share       
amounts)                                                                    
                                                                            
                                    Three Months Ended     Nine Months Ended
                                          September 30          September 30
                                        2012      2011       2012       2011
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
REVENUE                                                                     
  Oil sales, net of royalties     $   74,540 $ 71,769  $ 225,385  $ 187,145 
  Derivative gain (loss) on                                                 
   commodity contracts                     -      (13)      (125)      (599)
  Finance revenue                        100      148        351        343 
----------------------------------------------------------------------------
                                      74,640   71,904    225,611    186,889 
----------------------------------------------------------------------------
                                                                            
EXPENSES                                                                    
  Production and operating            11,622    9,762     35,024     26,404 
  General and administrative           7,350    4,357     20,829     13,591 
  Foreign exchange (gain) loss         3,190      265      1,016        345 
  Finance costs                        2,467    1,269     11,488      3,770 
  Exploration                            129      331        800        353 
  Depletion, depreciation and                                               
   amortization                       11,005   10,300     34,516     26,263 
  Unrealized (gain) loss on                                                 
   financial instruments               4,361        -      3,363          - 
  Impairment of exploration and                                             
   evaluation assets                       -       68         17     12,144 
----------------------------------------------------------------------------
                                      40,124   26,352    107,053     82,870 
----------------------------------------------------------------------------
                                                                            
Earnings before income taxes          34,516   45,552    118,558    104,019 
Income tax expense (recovery) -                                             
 current                              21,634   20,336     66,216     55,827 
- deferred                             1,108     (894)      (556)    (2,681)
----------------------------------------------------------------------------
                                      22,742   19,442     65,660     53,146 
----------------------------------------------------------------------------
NET EARNINGS AND COMPREHENSIVE                                              
INCOME FORTHE PERIOD              $   11,774 $ 26,110  $  52,898  $  50,873 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
                                                                            
Earnings per share                                                          
  Basic                           $     0.16 $   0.36  $    0.72  $    0.70 
  Diluted                         $     0.16 $   0.35  $    0.70  $    0.68 
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
                                                                            
Condensed Consolidated Interim Balance Sheets                               
(Unaudited - Expressed in thousands of U.S. Dollars)                        
                                                                            
                                                       As at           As at
                                                September 30     December 31
                                                        2012            2011
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
ASSETS                                                                      
Current                                                                     
  Cash and cash equivalents                  $        45,732 $        43,884
  Accounts receivable                                243,483         162,225
  Derivative commodity contracts                           -             125
  Prepaids and other                                   8,347           7,441
  Product inventory                                    2,283               -
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                     299,845         213,675
Non-Current                                                                 
Restricted cash                                        1,420           2,226
  Intangible exploration and evaluation                                     
   assets                                             46,084          17,453
  Property and equipment                                                    
    Petroleum properties                             274,955         280,524
    Other assets                                       5,045           3,748
  Goodwill                                             8,180           8,180
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                             $       635,529 $       525,806
----------------------------------------------------------------------------
----------------------------------------------------------------------------
                                                                            
LIABILITIES                                                                 
Current                                                                     
  Accounts payable and accrued liabilities   $        47,603 $        73,692
----------------------------------------------------------------------------
                                                      47,603          73,692
Non-Current                                                                 
  Long-term debt                                      31,878          57,609
  Convertible debentures                             102,920               -
  Deferred taxes                                      52,335          52,891
  Other long-term liabilities                          1,029           1,122
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                                                     235,765         185,314
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SHAREHOLDERS' EQUITY                                     
                   
  Share capital                                      158,539         154,263
  Contributed surplus                                 10,636           8,538
  Retained earnings                                  230,589         177,691
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                                                     399,764         340,492
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                                             $       635,529 $       525,806
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Condensed Consolidated Interim Statements of Changes in Shareholders' Equity
(Unaudited - Expressed in thousands of U.S. Dollars)                        
                                                                            
                                  Three Months Ended       Nine Months Ended
                                        September 30            September 30
                                    2012        2011        2012        2011
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Share Capital                                                               
  Balance, beginning of                                                     
   period                   $   156,320 $   153,815 $   154,263 $    80,106 
  Stock options exercised         1,674         215       3,196       1,828 
  Share issuance                      -           -           -      75,594 
  Share issue costs                   -           -           -      (4,011)
  Transfer to share capital                                                 
   on exercise of options           545          74       1,080         587 
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  Balance, end of period    $   158,539 $   154,104 $   158,539 $   154,104 
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Contributed Surplus                                                         
  Balance, beginning of                                                     
   period                   $     9,844 $     6,673 $     8,538 $     5,785 
  Stock-based compensation                                                  
   expense                        1,337         982       3,178       2,383 
  Transfer to share capital                                                 
   on exercise of options          (545)        (74)     (1,080)       (587)
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  Balance, end of period    $    10,636 $     7,581 $    10,636 $     7,581 
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Retained Earnings                                                           
  Balance, beginning of                                                     
   period                   $   218,815 $   121,062 $   177,691 $    96,299 
  Net earnings                   11,774      26,110      52,898      50,873 
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  Balance, end of period    $   230,589 $   147,172 $   230,589 $   147,172 
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Condensed Consolidated Interim Statements of Cash Flows                     
(Unaudited - Expressed in thousands of U.S. Dollars)                        
                                                                            
                                  Three Months Ended       Nine Months Ended
                                        September 30            September 30
                                    2012        2011        2012        2011
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CASH FLOWS RELATED TO THE                                                   
 FOLLOWING                                                                  
ACTIVITIES:                                                                 
                                                                            
OPERATING                                                                   
  Net earnings for the                                                      
   period                   $    11,774 $    26,110 $    52,898 $    50,873 
  Adjustments for:                                                          
    Depletion, depreciation                                                 
     and amortization            11,005      10,300      34,516      26,263 
    Deferred lease                                                          
     inducement                     113         119         342         238 
    Impairment of                                                           
     exploration and                                                        
     evaluation costs                 -          68          17      12,144 
    Stock-based compensation      1,500         738       3,477       2,139 
    Finance costs                 2,467       1,269      11,488       3,770 
    Income tax expense           22,742      19,442      65,660      53,146 
    Unrealized (gain) loss                                                  
     on commodity contracts           -          13         125         235 
    Unrealized (gain) loss                                                  
     on financial                                                           
     instruments                  4,361           -       3,363           - 
    Unrealized (gain) loss                                                  
     on foreign currency                                                    
     translation                  3,069         257         989         526 
  Income taxes paid             (21,634)    (20,336)    (66,216)    (55,827)
  Changes in non-cash                                                       
   working capital              (33,029)    (34,524)    (77,917)    (32,207)
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Net cash generated by (used                                                 
 in) operating activities         2,368       3,456      28,742      61,300 
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INVESTING                                                                   
  Additions to intangible                                  
                 
   exploration and                                                          
   evaluation assets               (189)       (862)     (1,710)     (6,699)
  Additions to petroleum                                                    
   properties                   (11,854)    (19,296)    (28,626)    (50,981)
  Additions to other assets        (536)         (2)     (1,165)     (1,864)
  Business acquisitions          (4,881)          -     (27,978)          - 
  Changes in restricted cash         (1)         (3)        806       1,161 
  Changes in non-cash                                                       
   working capital                 (765)       (651)    (32,850)      2,713 
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Net cash generated by (used                                                 
 in) investing activities       (18,226)    (20,814)    (91,523)    (55,670)
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FINANCING                                                                   
  Issue of common shares for                                                
   cash                           1,674         215       3,196      77,422 
  Issue costs for common                                                    
   shares                             -           -           -      (4,011)
  Financing costs                     -           -        (383)          - 
  Interest paid                  (4,180)       (530)     (5,573)     (2,453)
  Issue of convertible                                                      
   debentures                         -           -      97,851           - 
  Issue costs for                                                           
   convertible debentures             -           -      (4,630)          - 
  Repayments of long-term                                                   
   debt                          (6,300)          -     (26,300)    (30,000)
  Decrease in other long-                                                   
   term liabilities                (106)          -        (435)        772 
  Changes in non-cash                                                       
   working capital               (2,374)        432          89         328 
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Net cash generated by (used                                                 
 in) financing activities       (11,286)        117      63,815      42,058 
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Currency translation                                                        
 differences relating to                                                    
 cash and cash equivalents          646        (411)        814        (463)
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NET INCREASE (DECREASE) IN                                                  
 CASH AND CASH EQUIVALENTS      (26,498)    (17,652)      1,848      47,225 
CASH AND CASH EQUIVALENTS,                                                  
 BEGINNING OF PERIOD             72,230     122,659      43,884      57,782 
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CASH AND CASH EQUIVALENTS,                                                  
 END OF PERIOD              $    45,732 $   105,007 $    45,732 $   105,007 
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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. 
Contacts:
TransGlobe Energy Corporation
Scott Koyich
Investor Relations
403.264.9888
investor.relations@trans-globe.com
www.trans-globe.com
 
 
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