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TransGlobe Energy Corporation Announces Third Quarter 2021 Financial and Operating Results for the Three and Nine Months Ended September 30, 2021

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This Announcement contains inside information as defined in Article 7 of the Market Abuse Regulation No. 596/2014 ("MAR"). Upon the publication of this Announcement, this inside information is now considered to be in the public domain.

Calgary, Alberta--(Newsfile Corp. - November 3, 2021) - TransGlobe Energy Corporation (AIM: TGL) (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, 2021. All dollar values are expressed in United States dollars unless otherwise stated. TransGlobe's Condensed Consolidated Interim Financial Statements together with the notes related thereto, as well as TransGlobe's Management's Discussion and Analysis for the three and nine months ended September 30, 2021 and 2020, are available on TransGlobe's website at www.trans-globe.com.

FINANCIAL HIGHLIGHTS:

  • Third quarter sales averaged 14,868 boe/d including 307.5 Mbbls sold to EGPC for net proceeds of $20.9 million and one cargo lifting of 499.6 Mbbls of entitlement crude oil for net proceeds of $33.3 million (collected in August 2021). The overlift portion of the cargo (~221.7 Mbbls) will be settled through future entitlement crude oil production at West Gharib;

  • Average realized price for Q3-2021 sales of $60.85/boe; Q3-2021 average realized price on Egyptian sales of $64.73/bbl and Canadian sales of $36.82/boe;

  • Funds flow from operations of $12.4 million ($0.17 per share) in the quarter;

  • Third quarter net earnings of $37.1 million ($0.51 per share), inclusive of a $31.5 million non-cash impairment reversal and a $1.3 million unrealized gain on derivative commodity contracts;

  • Ended the third quarter with positive working capital of $17.7 million, including cash of $54.0 million;

OPERATIONAL HIGHLIGHTS:

  • Third quarter production averaged 13,342 boe/d (Egypt 11,276 bbls/d, Canada 2,066 boe/d), an increase of 265 boe/d (2%) from the previous quarter, primarily due to well optimization activities and new drilling in Egypt, partially offset by natural declines while awaiting the production start from new drilling in Canada;

  • Production in October averaged ~13,882 boe/d (Egypt ~10,964 bbls/d, Canada ~2,918 boe/d), an increase of 4% from Q3-2021;

  • Ended the quarter with nil entitlement crude oil inventory, a decrease of 140.3 Mbbls from Q2-2021. This decrease is due to an increase in sales volumes as a result of the Q3-2021 cargo lifting, partially offset by a slight increase in production;

  • Drilled two development oil wells at West Bakr in the Eastern Desert, Egypt, both successfully encountering oil-bearing sands and placed on production. A third development oil well was spud at West Bakr subsequent to the quarter;

  • Drilled one well at North West Gharib in the Eastern Desert, Egypt;

  • Drilled an oil exploration well on the SGZ-7B prospect at South Ghazalat in the Western Desert, Egypt subsequent to the quarter;

  • Drilled, completed, and equipped the one 2-mile and two 1-mile horizontal wells in the northern area of the Company's Cardium reservoir extension in South Harmattan;

  • Brought the 2-mile well in South Harmattan on production;

CORPORATE HIGHLIGHTS:

  • Amounts outstanding under the Mercuria prepayment agreement were repaid in full during the quarter. On September 27, 2021 the prepayment agreement was amended to $10 million (undrawn) and extended to December 31, 2021 to coincide with the expiry of the Company's remaining Brent crude oil hedges of 150 Mbbls; and

  • The Company announced a merged concession agreement with a 15-year primary term and improved Company economics on December 3, 2020. The agreement is currently awaiting ratification by the Egyptian Parliament but will have a February 2020 effective date upon ratification. As such, the results achieved in Q3-2021 and year to-date are exclusive of any effective date adjustments that will be made upon ratification.

FINANCIAL AND OPERATING RESULTS

(US$000s, except per share, price, volume amounts and % change)



Three Months Ended September 30



Nine Months Ended September 30


Financial


2021



2020



% Change



2021



2020



% Change


Petroleum and natural gas sales2


83,234



33,046



152



210,528



137,782



53


Petroleum and natural gas sales, net of royalties2


42,316



16,740



153



110,963



81,366



36


Realized derivative (loss) gain on commodity contracts


(2,188

)


662



(431

)


(7,379

)


6,807



(208

)

Unrealized derivative gain (loss) on commodity contracts


1,327



(267

)


(597

)


(2,891

)


761



(480

)

Production and operating expense


16,741



11,473



46



45,912



45,136



2


Overlift


15,551



-



100



15,551



-



100


Selling costs


2,161



54



3,902



3,866



1,103



250


General and administrative expense


4,230



2,542



66



12,937



8,397



54


Depletion, depreciation and amortization expense


6,592



5,493



20



18,366



23,402



(22

)

Income tax expense


6,096



3,092



97



16,361



10,122



62


Cash flow generated by (used in) operating activities


27,026



(3,349

)


(907

)


46,918



17,529



168


Funds flow from operations1


12,381



323



3,733



29,562



23,241



27


Basic per share


0.17



0.00





0.41



0.32




Diluted per share


0.17



0.00





0.41



0.32




Net earnings (loss)


37,080



(5,957

)


(722

)


33,778



(74,542

)


(145

)

Basic per share


0.51



(0.08

)




0.47



(1.03

)



Diluted per share


0.51



(0.08

)




0.46



(1.03

)



Capital expenditures


11,624



437



2,560



18,128



7,243



150


Working capital


17,667



12,708



39



17,667



12,708



39


Long-term debt, including current portion


6,882



25,946



(73

)


6,882



25,946



(73

)

Common shares outstanding













Basic (weighted average)


72,542



72,542



-



72,542



72,542



-


Diluted (weighted average)


72,980



72,542



1



72,983



72,542



1


Total assets


267,263



205,583



30



267,263



205,583



30















Operating













Average production volumes (boe/d)


13,342



12,044



11



12,884



13,774



(6

)

Average sales volumes (boe/d)2


14,868



10,680



39



13,719



15,344



(11

)

Inventory (Mbbls)


-



534.2



(100

)


-



534.2



(100

)

Average realized sales price ($/boe)2


60.85



33.63



81



56.21



32.77



72


Production and operating expenses ($/boe)2


12.24



11.68



5



12.26



10.74



14


1 Funds flow from operations (before finance costs) 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. See "Non-GAAP Financial Measures".
2 Excludes the impact of the Q3-2021 overlift of $15.6 million (221.7 Mbbls).



2021



2020

Average reference prices and exchange rates


Q-3



Q-2



Q-1



Q-4



Q-3

Crude oil
















Dated Brent average oil price ($/bbl)


73.47



68.83



60.82



44.29



42.96


Edmonton Sweet index ($/bbl)


66.61



63.01



52.54



38.50



37.35


Natural gas











AECO ($/MMBtu)


2.97



2.48



2.30



2.18



1.69


US/Canadian Dollar average exchange rate


1.26



1.23



1.27



1.30



1.33

CORPORATE SUMMARY

TransGlobe Energy Corporation ("TransGlobe" or the "Company") produced an average of 13,342 barrels of oil equivalent per day ("boe/d") during the third quarter of 2021. Egypt production was 11,276 barrels of oil per day ("bbls/d") and Canada production was 2,066 boe/d. Production for the quarter was slightly above full year 2021 guidance of 12,000 to 13,000 boe/d and 2% higher than the previous quarter. The increase was primarily due to well optimization activities and new drilling in Egypt, partially offset by natural declines while awaiting the production start from new drilling in Canada.

TransGlobe's Egyptian crude oil is sold at a quality discount to Dated Brent. The Company received an average price of $64.73 per barrel in Egypt during the quarter. In Canada, the Company received an average of $65.43 per barrel of oil, $35.40 per barrel of NGLs and $2.71 per thousand cubic feet ("Mcf") of natural gas during the quarter.

During Q3-2021, the Company had funds flow from operations of $12.4 million and ended the quarter with positive working capital of $17.7 million, including cash of $54.0 million. The Company had net earnings in the quarter of $37.1 million, inclusive of a $1.3 million unrealized derivative gain on commodity contracts which represents a fair value adjustment on the Company's hedging contracts at September 30, 2021. Net income was also inclusive of a non-cash impairment reversal of $31.5 million on the Company's petroleum and natural gas ("PNG") assets that was recognized due to the sustained increase and stabilization in forecasted commodity prices in 2021.

The Mercuria prepayment agreement was fully repaid during the quarter with the final $10.0 million being paid in August 2021. On September 27, 2021 the prepayment agreement was amended to $10.0 million (undrawn) and extended to December 31, 2021 to coincide with the expiry of the Company's remaining Brent crude oil hedges of 150 thousand barrels ("Mbbls").

In Egypt, the Company sold 307.5 Mbbls of entitlement crude oil to the Egyptian General Petroleum Company ("EGPC") and sold one cargo lifting of 499.6 Mbbls of entitlement crude oil to third-party buyers during the quarter. The cargo resulted in an overlift of 221.7 Mbbls by TransGlobe. The overlift will be settled as the Company delivers the equivalent future entitlement production from West Gharib to EGPC. All Canadian production was sold during the quarter.

As announced on December 3, 2020, the Company has reached an agreement with EGPC to merge its three existing Eastern Desert concessions with a 15-year primary term and improved Company economics. As previously announced, the Company is now expecting ratification to occur in Q4-2021. The February 1, 2020 effective date for the improved concession terms is supportive of increased investment in advance of ratification.

In Egypt, the Company drilled two development oil wells in the Eastern Desert at West Bakr. The K-62 development well was drilled to a total depth of 1,473 meters, and encountered oil-bearing sands in the Asl-A formation. The second well in West Bakr, K-65, was drilled to a total depth of 1,730 meters, and encountered oil-bearing sands in the Asl-A, Asl-B, Asl-C, Asl-D and Asl-E formations. The Company drilled one additional well in the Eastern Desert at North West Gharib, NWG-3B-2, to a total depth of 1,627 meters to assess Red Bed potential in the northern area of TransGlobe's development leases. The well encountered Red Bed sands which were wet. The results are under evaluation to identify any up-dip sidetrack potential.

In Canada, the Company successfully drilled, completed, and equipped one 2-mile and two 1-mile horizontal wells in the northern area of the Cardium reservoir extension at South Harmattan, first identified by the 2-20 well in 2019. The 2-mile well was brought on production at the end of Q3-2021, while the other two wells were brought on production in October. All three wells initially flowed without the assistance of pumps. As of month end, two of the wells ceased flowing naturally, as anticipated, and are now equipped with pumps. The third well continues to flow naturally and will be equipped with a pump when the unassisted flow ceases. Initial production rates (IP30 and IP60) will be made available once sufficient data has been acquired.

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 that maintain and increase production and reserves, to acquire strategic oil and gas assets, to repay current liabilities and debt and ultimately to provide a return to shareholders. TransGlobe's capital programs are funded by existing working capital and cash provided from operating activities. The Company's cash flow from operations varies significantly from quarter to quarter, depending on the timing of oil sales from cargoes lifted in Egypt, and these fluctuations in cash flow impact the Company's liquidity. TransGlobe's management will continue to steward capital and focus on cost reductions in order to maintain balance sheet strength.

Funding for the Company's capital expenditures is provided by cash flows from operations and cash on hand. The Company expects to fund its 2021 exploration and development program through the use of working capital and cash flow from operations. Fluctuations in commodity prices, product demand, foreign exchange rates, interest rates and various other risks may impact capital resources and capital expenditures.

Working capital is the amount by which current assets exceed current liabilities. As at September 30, 2021, the Company had a working capital surplus of $17.7 million (December 31, 2020 - $15.3 million). The increase in working capital is primarily due to an increase in cash resulting from collections on accounts receivable in the period and an increase in accounts receivable due to increased sales in Q3-2021. These increases were partially offset by a decrease in crude oil inventory and increase in overlift liability as a result of the Q3-2021 cargo lifting, an increase in the derivative commodity contracts liability from increased commodity pricing and an increase in accounts payable driven by the 2021 capital program.

All of the Company's cash and cash equivalents are on deposit with high credit-quality financial institutions.

Over the past 10 years, the Company has experienced delays in the collection of accounts receivable from EGPC. The length of delay peaked in 2013, returned to historical delays of up to nine months in 2017, and has since fluctuated within an acceptable range. As at September 30, 2021, amounts owing from EGPC were $24.5 million. The Company considers there to be minimal credit risk associated with amounts receivable from EGPC.

In Egypt, the Company sold 307.5 Mbbls of entitlement crude oil to EGPC in Q3-2021 for net proceeds of $20.9 million and sold one cargo lifting of 499.6 Mbbls of entitlement crude oil for net proceeds of $33.3 million (collected in August 2021). The overlift portion of the cargo (221.7 Mbbls) will be settled through future entitlement crude oil production at West Gharib. During the third quarter of 2021, the Company collected a total of $4.5 million of accounts receivable from EGPC, an additional $3.7 million has been collected subsequent to the quarter. The Company incurs a 30-day collection cycle on sales to third-party international buyers. Depending on the Company's assessment of the credit of crude oil purchasers, they may be required to post irrevocable letters of credit to support the sales prior to the cargo lifting. As at September 30, 2021, the Company held no crude oil inventory.

As at September 30, 2021, the Company had $27.7 million of revolving credit facilities with $6.9 million drawn and $20.8 million available. The Company has a prepayment agreement with Mercuria that was amended to $10.0 million (undrawn) and extended to December 31, 2021 to coincide with the expiry of TransGlobe's remaining Brent crude oil hedges. During the quarter, the prepayment agreement was fully repaid in the amount of $10.0 million. The Company also has a revolving Canadian reserves-based lending facility with ATB totaling C$22.5 million ($17.7 million), of which C$8.7 million ($6.9 million) was drawn and outstanding. During the nine months ended September 30, 2021, the Company had drawings of C$0.4 million ($0.3 million) on this facility.

The Company actively monitors its liquidity to ensure that cash flows, credit facilities and working capital are adequate to support these financial liabilities, as well as the Company's capital programs.

OPERATIONS UPDATE

ARAB REPUBLIC OF EGYPT

EASTERN DESERT

West Gharib, West Bakr, and North West Gharib (100% working interest, operated)

Operations and Exploration

The Company continues to utilize the EDC-64 rig drilling development oil wells.

In West Bakr, the Company successfully drilled two development oil wells during Q3-2021 and moved on to a third well (K-66) at quarter end.

The K-62 development well was drilled to a total depth of 1,473 meters, and encountered oil-bearing sands in the Asl-A formation. The reservoir section has been fully logged and evaluated, with an internally estimated 24.2 meters of net oil pay in the Asl-A reservoirs. The Asl-A2 was completed for oil production and came on production at a field estimated 120 bbls/d of oil.

The second well in West Bakr (K-65) was drilled to a total depth of 1,730 meters, and encountered oil-bearing sands in the Asl-A, Asl-B, Asl-C, Asl-D and Asl-E formations. The reservoir section has been fully logged and evaluated, with an internally estimated 10.6 meters of net oil pay in the Asl-A sand, 12.5 meters of net oil pay across the Asl-B sand, 6.1 meters of net oil pay across the Asl-C sand, 5.5 meters of net oil pay across the Asl-D sand and 11.4 meters of net oil pay in the Asl-E sand (total net oil pay 46.1 meters). The Asl-E was completed for production in this well and came on production at a field estimated 520 bbls/d oil. The Asl-A, Asl-B, Asl-C, and Asl-D are expected to be recovered through future recompletions of this well.

The Company drilled one well in North West Gharib (NWG-3B-2) to a total depth of 1,627 meters to assess Red Bed potential in the northern area of TransGlobe's development leases. The well encountered Red Bed sands which were wet. The results are under evaluation to identify any up-dip sidetrack potential.

Production

Production averaged 10,653 bbls/d during the quarter, an increase of 7% (736 bbls/d) from the previous quarter. The increase was primarily due to well optimization activities and new drilling, partially offset by natural declines.

Production in October 2021 averaged ~10,445 bbls/d.

Sales

The Company sold 285.9 Mbbls of entitlement crude oil to EGPC and sold one cargo lifting of 499.6 Mbbls of entitlement crude oil to third-party buyers during the quarter. The remaining overlift position (221.7 Mbbls) will be settled as the Company delivers equivalent future entitlement production from West Gharib.

Quarterly Eastern Desert Production (bbls/d)


2021



2020



Q-3



Q-2



Q-1



Q-4

Gross production rate1


10,653



9,917



10,050



10,129


TransGlobe production sold (inventoried)


1,525



3,465



(2,531

)


3,328

Total sales3


12,178



13,382



7,519



13,457










Government share (royalties and tax)


6,050



5,229



5,680



5,715


TransGlobe sales (after royalties and tax)2


6,128



8,153



1,839



7,742

Total sales3


12,178



13,382



7,519



13,457

1 Quarterly production by concession (bbls/d):
West Gharib - 2,932 (Q3- 2021), 3,024 (Q2-2021), 3,076 (Q1-2021), and 3,113 (Q4-2020)
West Bakr - 7,257 (Q3-2021), 6,327 (Q2-2021), 6,415 (Q1-2021), and 6,656 (Q4-2020)
North West Gharib - 464 (Q3-2021), 566 (Q2-2021), 559 (Q1-2021), and 360 (Q4-2020)
2 Under the terms of the Production Sharing Concession Agreements, royalties and taxes are paid out of the government's share of production sharing oil.
3 Excludes the impact of the Q3-2021 overlift of 221.7 Mbbls.

WESTERN DESERT

South Ghazalat (100% working interest, operated)

Operations and Exploration

The Lower Bahariya reservoir at SGZ-6X continues to produce on Gas Oil Ratio ("GOR") control at a field estimated ~490 bbls/d of light oil with a 54% watercut.

With improved oil prices and spare capacity available in the South Ghazalat early production facility, the Company has accelerated drilling of an oil exploration well on the SGZ-7B prospect to the east of SGZ-6X. The SGZ-7B well was drilled to a total depth of 5,240 feet MD and encountered gas-bearing sands in the Upper Bahariya formation and oil-bearing sands in the Lower Bahariya formation. It has been cased for further testing and evaluation. This well fulfills the Company's commitment to EGPC as part of the South Ghazalat development lease approval in 2019.

Production

Production averaged 623 bbls/d during the quarter, a decrease of 23% (187 bbls/d) from the previous quarter. The decrease was primarily due to natural declines.

Production in October 2021 averaged ~519 bbls/d.

Sales

The Company sold 21.6 Mbbls of inventoried entitlement crude oil to EGPC during the quarter.

Quarterly Western Desert Production (bbls/d)


2021



2020



Q-3



Q-2



Q-1



Q-4

Gross production rate


623



810



188



139

Total sales


623



810



188



139









Government share (royalties and tax)


388



504



117



86

TransGlobe sales (after royalties and tax)1


235



306



71



53

Total sales


623



810



188



139

1 Under the terms of the Production Sharing Concession Agreements, royalties and taxes are paid out of the government's share of production sharing oil.

CANADA

Operations and Exploration

The Company successfully drilled, completed, and equipped one 2-mile and two 1-mile horizontal wells in the northern area of TransGlobe's Cardium reservoir extension at South Harmattan, first identified by the 2-20 well in 2019. The 2-mile well was brought on production at the end of September 2021, while the other two wells commenced production in October. All three wells initially flowed without artificial lift. Two of the wells ceased natural flow, as anticipated, and are now equipped with pumps, while the third well continues to flow unassisted.

Additional information on individual well performance will be provided when sufficient stabilized production history has been obtained late 2021 / early 2022.

In Canada, ethane extraction from gas stream at the 3rd party processing facility resumed in October, resulting in increased production on a boe basis.

Production

In Canada, production averaged 2,066 boe/d during the quarter, a decrease of 284 boe/d (12%) from the previous quarter and below full year 2021 guidance of 2,300 to 2,500 boe/d. The decrease in production from the previous quarter is primarily due to natural declines while awaiting the production start from new drilling.

Production in October 2021 averaged ~2,918 boe/d with ~1,310 bbls/d of oil. The increase from Q3-2021 is due to the new wells being brought on stream and the resumption of ethane extraction at the 3rd party processing facility.

Quarterly Canada Production


2021



2020



Q-3



Q-2



Q-1



Q-4

Canada crude oil (bbls/d)


601



687



564



618

Canada NGLs (bbls/d)


677



857



710



755

Canada natural gas (Mcf/d)


4,734



4,834



4,259



4,454


Total production (boe/d)


2,066



2,350



1,983



2,116

Condensed Consolidated Interim Statements of Earnings (Loss) and Comprehensive Income (Loss)

(Unaudited - Expressed in thousands of U.S. Dollars, except per share amounts)



Three Months Ended
September 30



Nine Months Ended
September 30




2021



2020



2021



2020















REVENUE













Petroleum and natural gas sales, net of royalties


57,868



16,740



126,515



81,366


Finance revenue


2



9



8



101


Other revenue


-



106



33



328




57,870



16,855



126,556



81,795











EXPENSES









Production and operating


16,741



11,473



45,912



45,136


Overlift


15,551



-



15,551



-


Selling costs


2,161



54



3,866



1,103


General and administrative


4,230



2,542



12,937



8,397


Foreign exchange (gain) loss


(75

)


(65

)


(32

)


100


Finance costs


227



552



1,030



1,956


Depletion, depreciation and amortization


6,592



5,493



18,366



23,402


Asset retirement obligation accretion


47



66



158



194


Loss (gain) on financial instruments


861



(395

)


10,270



(7,568

)

Gain on overlift liability


(120

)


-



(120

)


-


Impairment (reversal) loss


(31,521

)


-



(31,521

)


73,495




14,694



19,720



76,417



146,215











Earnings (loss) before income taxes


43,176



(2,865

)


50,139



(64,420

)










Income tax expense - current


6,096



3,092



16,361



10,122


NET EARNINGS (LOSS)


37,080



(5,957

)


33,778



(74,542

)










OTHER COMPREHENSIVE INCOME (LOSS)









Currency translation adjustments


(1,296

)


1,188



(130

)


(1,371

)

COMPREHENSIVE INCOME (LOSS)


35,784



(4,769

)


33,648



(75,913

)










Net earnings (loss) per share









Basic


0.51



(0.08

)


0.47



(1.03

)

Diluted


0.51



(0.08

)


0.46



(1.03

)

Condensed Consolidated Interim Balance Sheets

(Unaudited - Expressed in thousands of U.S. Dollars)



As at



As at




September 30, 2021



December 31, 2020








ASSETS


Current


Cash and cash equivalents


53,952



34,510


Accounts receivable


29,030



9,996


Prepaids and other


3,642



3,530


Product inventory


-



5,828



86,624



53,864


Non-Current


Intangible exploration and evaluation assets


1,245



584


Property and equipment





Petroleum and natural gas assets


172,652



140,059


Other


2,334



2,917


Deferred taxes


4,408



3,723



267,263



201,147






LIABILITIES


Current


Accounts payable and accrued liabilities


49,319



21,667


Derivative commodity contracts


3,285



398


Current portion of lease obligations


922



1,553


Current portion of long-term debt


-



14,897


Overlift liability


15,431



-



68,957



38,515

Non-Current


Long-term debt


6,882



6,567


Asset retirement obligations


13,519



13,042


Other long-term liabilities


1,235



544


Lease obligations


51



461


Deferred taxes


4,408



3,723



95,052



62,852






SHAREHOLDERS' EQUITY


Share capital


152,805



152,805


Accumulated other comprehensive income


1,770



1,900


Contributed surplus


25,377



25,109


Deficit


(7,741

)


(41,519

)



172,211



138,295



267,263



201,147

Condensed Consolidated Interim Statements of Changes in Shareholders' Equity

(Unaudited - Expressed in thousands of U.S. Dollars)



Nine Months Ended September 30




2021



2020









Share Capital






Balance, beginning and end of period


152,805



152,805






Accumulated Other Comprehensive Income (Loss)





Balance, beginning of period


1,900



1,134


Currency translation adjustment


(130

)


(1,371

)

Balance, end of period


1,770



(237

)






Contributed Surplus





Balance, beginning of period


25,109



24,673


Share-based compensation expense


268



340


Balance, end of period


25,377



25,013







(Deficit) Retained Earnings





Balance, beginning of period


(41,519

)


35,878

Net earnings (loss)


33,778



(74,542

)

Balance, end of period


(7,741

)


(38,664

)

Condensed Consolidated Interim Statements of Cash Flows

(Unaudited - Expressed in thousands of US Dollars)



Three Months Ended
September 30



Nine Months Ended
September 30




2021



2020



2021



2020















OPERATING













Net earnings (loss)


37,080



(5,957

)


33,778



(74,542

)

Adjustments for:









Depletion, depreciation and amortization


6,592



5,493



18,366



23,402


Asset retirement obligation accretion


47



66



158



194


Impairment (recovery) loss


(31,521

)


-



(31,521

)


73,495


Share-based compensation


1,403



(72

)


4,990



(489

)

Finance costs


227



552



1,030



1,956


Unrealized (gain) loss on financial instruments


(1,327

)


267



2,891



(761

)

Unrealized loss (gain) on foreign currency translation


2



(26

)


14



6


Gain on overlift


(120

)


-



(120

)


-


Asset retirement obligations settled


(2

)


-



(24

)


(20

)

Changes in non-cash working capital


14,645



(3,672

)


17,356



(5,712

)

Net cash generated by (used in) operating activities


27,026



(3,349

)


46,918



17,529











INVESTING









Additions to intangible exploration and evaluation assets


(83

)


-



(661

)


(337

)

Additions to petroleum and natural gas assets


(11,494

)


(399

)


(17,381

)


(6,721

)

Additions to other assets


(47

)


(38

)


(86

)


(185

)

Changes in non-cash working capital


5,642



(1,883

)


7,989



(2,545

)

Net cash used in investing activities


(5,982

)


(2,320

)


(10,139

)


(9,788

)










FINANCING









Interest paid


(190

)


(396

)


(774

)


(1,526

)

Increase in long-term debt


95



114



320



282


Payments on lease obligations


(499

)


(366

)


(1,570

)


(1,141

)

Repayments of long-term debt


(10,000

)


(1,504

)


(15,000

)


(11,504

)

Changes in non-cash working capital


3



-



(6

)


-


Net cash used in financing activities


(10,591

)


(2,152

)


(17,030

)


(13,889

)










Currency translation differences relating to cash and cash equivalents


(140

)


49



(307

)


(38

)

NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS


10,313



(7,772

)


19,442



(6,186

)

CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD


43,639



34,837



34,510



33,251


CASH AND CASH EQUIVALENTS, END OF PERIOD


53,952



27,065



53,952



27,065


Advisory on Forward-Looking Information and Statements

Certain statements included in this news release constitute forward-looking statements or forward-looking information under applicable securities legislation. Such forward-looking statements or information are provided for the purpose of providing information about management's current expectations and plans relating to the future. Readers are cautioned that reliance on such information may not be appropriate for other purposes. Forward-looking statements or information typically contain statements with words such as "anticipate", "strengthened", "confidence", "believe", "expect", "plan", "intend", "estimate", "may", "will", "would" or similar words suggesting future outcomes or statements regarding an outlook. In particular, forward-looking information and statements contained in this document include, but are not limited to, the Company's strategy to grow its annual cash flow; anticipated drilling, completion and testing plans, including, the anticipated timing thereof, prospects being targeted by the Company, and rig mobilization plans; expected future production from certain of the Company's drilling locations; TransGlobe's plans to drill additional wells, including the types of wells, anticipated number of locations and the timing of drilling thereof; the timing of rig movement and mobilization and drilling activity; the Company's plans to file development lease applications for certain of its discoveries, including the expected timing of filing of such applications and the expected timing of receipt of regulatory approvals; anticipated production and ultimate recoveries from wells; to negotiate future military access (including the expected timing thereof), including the anticipated timing of wells on production; TransGlobe's plans to continue exploration, development and completion programs in respect of various discoveries; future requirements necessary to determine well performance and estimated recoveries; the ratification of the amendment, extension, and consolidation of the Company's Eastern Desert Concessions; and other matters.

Forward-looking statements or information are based on a number of factors and assumptions which have been used to develop such statements and information but which may prove to be incorrect. 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 because the Company can give no assurance that such expectations will prove to be correct. Many factors could cause TransGlobe's actual results to differ materially from those expressed or implied in any forward-looking statements made by, or on behalf of, TransGlobe.

In addition to other factors and assumptions which may be identified in this news release, assumptions have been made regarding, among other things, anticipated production volumes; the timing of drilling wells and mobilizing drilling rigs; the number of wells to be drilled; the Company's ability to obtain qualified staff and equipment in a timely and cost-efficient manner; the regulatory framework governing royalties, taxes and environmental matters in the jurisdictions in which the Company conducts and will conduct its business; future capital expenditures to be made by the Company; future sources of funding for the Company's capital programs; geological and engineering estimates in respect of the Company's reserves and resources; the geography of the areas in which the Company is conducting exploration and development activities; current commodity prices and royalty regimes; availability of skilled labour; future exchange rates; the price of oil; the impact of increasing competition; conditions in general economic and financial markets; availability of drilling and related equipment; effects of regulation by governmental agencies; future operating costs; uninterrupted access to areas of TransGlobe's operations and infrastructure; recoverability of reserves and future production rates; that TransGlobe will have sufficient cash flow, debt or equity sources or other financial resources required to fund its capital and operating expenditures and requirements as needed; that TransGlobe's conduct and results of operations will be consistent with its expectations; that TransGlobe will have the ability to develop its properties in the manner currently contemplated; current or, where applicable, proposed industry conditions, laws and regulations will continue in effect or as anticipated as described herein; that the estimates of TransGlobe's reserves and resource volumes and the assumptions related thereto (including commodity prices and development costs) are accurate in all material respects; and other matters.

Forward-looking statements or information are based on current expectations, estimates and projections that involve a number of risks and uncertainties which could cause actual results to differ materially from those anticipated by the Company and described in the forward-looking statements or information. These risks and uncertainties which may cause actual results to differ materially from the forward-looking statements or information include, among other things, operating and/or drilling costs are higher than anticipated; 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 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; competition; lack of availability of qualified personnel; the results of exploration and development drilling and related activities; obtaining required approvals of regulatory authorities; volatility in market prices for oil; fluctuations in foreign exchange or interest rates; environmental risks; ability to access sufficient capital from internal and external sources; failure to negotiate the terms of contracts with counterparties; failure of counterparties to perform under the terms of their contracts; and other factors beyond the Company's control. Readers are cautioned that the foregoing list of factors is not exhaustive. Please consult TransGlobe's public filings at www.sedar.com and www.sec.goedgar.shtml for further, more detailed information concerning these matters, including additional risks related to TransGlobe's business.

The forward-looking statements or information contained in this news release are made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise unless required by applicable securities laws. The forward-looking statements or information contained in this news release are expressly qualified by this cautionary statement.

Oil and Gas Advisories

Mr. Ron Hornseth, B.Sc., General Manager - Canada for TransGlobe Energy Corporation, and a qualified person as defined in the Guidance Note for Mining, Oil and Gas Companies, June 2009, of the London Stock Exchange, has reviewed the technical information contained in this report. Mr. Hornseth is a professional engineer who obtained a Bachelor of Science in Mechanical Engineering from the University of Alberta. He is a member of the Association of Professional Engineers and Geoscientists of Alberta ("APEGA") and the Society of Petroleum Engineers ("SPE") and has over 20 years' experience in oil and gas.

BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil equivalent (6 MCF: 1 Bbl) is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6:1, utilizing a conversion on a 6:1 basis may be misleading as an indication of value.

References in this press release to production test rates, are useful in confirming the presence of hydrocarbons, however such rates are not determinative of the rates at which such wells will commence production and decline thereafter and are not indicative of long term performance or of ultimate recovery. While encouraging, readers are cautioned not to place reliance on such rates in calculating the aggregate production for TransGlobe. A pressure transient analysis or well-test interpretation has not been carried out in respect of all wells. Accordingly, the Company cautions that the production test results should be considered to be preliminary.

The following abbreviations used in this press release have the meanings set forth below:

bbl

barrels

bbls/d

barrels per day

Mbbls

thousand barrels

boe

barrel of oil equivalent

boe/d

barrels of oil equivalent per day

MMBtu

One million British thermal units

Mcf

thousand cubic feet

Mcf/d

thousand cubic feet per day

NGL

Natural Gas Liquids

Production Disclosure

Production Summary (WI before royalties and taxes):


Oct - 21

Q3 - 21

Q2 - 21

Q1 - 21

Q4 - 20

Q3 - 20

Egypt (bbls/d)

10,964

11,276

10,727

10,238

10,268

9,812

Eastern Desert of Egypt (bbls/d)

10,445

10,653

9,917

10,052

10,132

9,635

Heavy Crude (bbls/d)

9,818

10,014

9,736

9,419

9,490

9,066

Light and Medium Crude (bbls/d)

627

639

181

633

642

569

Western Desert of Egypt (bbls/d)

519

623

810

186

136

177

Light and Medium Crude (bbls/d)

519

623

810

186

136

177

Canada (boe/d)

2,918

2,066

2,350

1,983

2,116

2,232

Light and Medium Crude (bbls/d)

1,310

601

687

564

618

661

Natural Gas (Mcf/d)

4,766

4,734

4,834

4,259

4,454

4,633

Associated Natural Gas Liquids (bbls/d)

794

677

857

710

755

798

Total (boe/d)

13,882

13,342

13,077

12,221

12,384

12,044

Production Guidance


Low

High

Mid-Point

Egypt (bbls/d)

9,700

10,500

10,100

Heavy Crude (bbls/d)

8,940

9,678

9,309

Light and Medium Crude (bbls/d)

760

822

791

Canada (boe/d)

2,300

2,500

2,400

Light and Medium Crude (bbls/d)

767

833

800

Natural Gas (Mcf/d)

4,600

5,000

4,800

Associated Natural Gas Liquids (bbls/d)

767

833

800

Total (boe/d)

12,000

13,000

12,500

About TransGlobe

TransGlobe Energy Corporation is a cashflow focused oil and gas exploration and development company whose current activities are concentrated in the Arab Republic of Egypt and Canada. TransGlobe's common shares trade on the Toronto Stock Exchange and the AIM market of the London Stock Exchange under the symbol TGL and on the NASDAQ Exchange under the symbol TGA.

For further information, please contact:

TransGlobe Energy Corporation
Randy Neely, President and CEO
Eddie Ok, CFO
+1 403 264 9888
investor.relations@trans-globe.com
http://www.trans-globe.com
or via Tailwind Associates

Tailwind Associates (Investor Relations)
Darren Engels
+1 403 618 8035
darren@tailwindassociates.ca
http://www.tailwindassociates.ca

Canaccord Genuity (Nomad & Joint-Broker)
Henry Fitzgerald-O'Connor
James Asensio
+44(0) 20 7523 8000

Shore Capital (Joint Broker)
Jerry Keen
Toby Gibbs
+44(0) 20 7408 4090

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/101801