PetroTal Announces Sales Update

ONP accelerated oil deliveries to Bayovar port allowing for a 720,000 barrel oil lifting

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - June 16, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce the following sales related update.

720,000 barrels of oil under contract for export from Bayovar. Approximately 720,000 barrels of PetroTal's Bretana oil has now been successfully tendered at the Bayovar port by Petroperu for the July lifting. Following an accelerated and temporary re-opening of section II of the Northern Peruvian Pipeline ("ONP") which had been previously closed due to maintenance operations, Petroperu has been able to deliver a material amount of oil to Bayovar over recent weeks. This oil previously entered the ONP in 2020 and was part of the restructured oil sales arrangement with Petroperu, announced in late 2020, with the Company receiving approximately $45/bbl of value. PetroTal will receive the difference between this tender price and the restructured $45/bbl price in the contract, generating over $60 million of price adjustment revenue.

Section II of the ONP line temporarily online. Petroperu recently informed PetroTal that it was able to temporarily pump all the oil from Station 5 (approximately 550,000 barrels) to the Bayovar port. The ONP section II has an approximate capacity of 2.1 million barrels with an estimated 82% being Bretana oil. Section I of the line between pump stations 1 and 5 remains closed due a maintenance delay from ongoing social protests in one community near pump station 1.

Manuel Pablo Zuniga-Pflucker, President and Chief Executive Officer, commented

"We applaud Petroperu's efforts to resume partial pipeline operations in a safe and reliable way. The true up revenue to be received from this tender was previously anticipated in Q4 2022 and will provide assurance that we can execute our shareholder strategy on time and as indicated in our corporate presentation."

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, PetroTal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

READER ADVISORIES

Notes to Press Release

(a) See "Specified Financial Measures".

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's revised 2022 guidance and budget including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; the intention to redeem the outstanding bonds; PetroTal plans to deliver strong operational performance and to generate free cash flow and growth; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, impact of inflation on costs, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, wars (including Russia's military actions in Ukraine), access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. Ongoing military actions between Russia and Ukraine have the potential to threaten the supply of oil and gas from the region. The long-term impacts of the actions between these nations remains uncertain. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the Corporation's most recent annual information form and MD&A, which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

SHORT-TERM PRODUCTION RATES: References in this press release peak production, initial 10 days of production and other short-term production 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 PetroTal. The Company cautions that such results should be considered to be preliminary.

OIL REFERENCES: All references to "oil" or "crude oil" production, revenue or sales in this press release mean "heavy crude oil" as defined in NI 51-101. All references to Brent indicate Intercontinental Exchange ("ICE") Brent.

SPECIFIED FINANCIAL MEASURES: This press release includes various specified financial measures, including non-GAAP financial measures, non-GAAP financial ratios and capital management measures as further described herein. These measures do not have a standardized meaning prescribed by generally accepted accounting principles ("GAAP") and, therefore, may not be comparable with the calculation of similar measures by other companies. Management uses these non- GAAP measures for its own performance measurement and to provide shareholders and investors with additional measurements of the Company's efficiency and its ability to fund a portion of its future capital expenditures. "Netback" (non-GAAP financial ratio) equals total petroleum sales less quality discount, lifting costs, transportation costs and royalty payments calculated on a bbl basis. The Company considers netbacks to be a key measure as they demonstrate Company's profitability relative to current commodity prices. "Funds flow provided by operations" (non-GAAP financial measure) includes all cash generated from operating activities and is calculated before changes in non-cash working capital. "Adjusted EBITDA" (non-GAAP financial measure) is calculated as consolidated net income (loss) before interest and financing expenses, income taxes, depletion, depreciation and amortization and adjusted for G&A impacts and certain non-cash, extraordinary and non-recurring items primarily relating to unrealized gains and losses on financial instruments and impairment losses, including derivative true-up settlements. PetroTal utilizes adjusted EBITDA as a measure of operational performance and cash flow generating capability. Adjusted EBITDA impacts the level and extent of funding for capital projects investments. Reference to EBITDA is calculated as net operating income less G&A. "Free cash flow" (non-GAAP financial measure) is calculated as net operating income less G&A less exploration and development capital expenditures and is calculated prior to all debt service, taxes, lease payments, hedge costs, factoring, and lease payments. Management uses free cash flow to determine the amount of funds available to the Company for future capital allocation decisions. Please refer to the MD&A for additional information relating to specified financial measures.

FOFI DISCLOSURE: This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about PetroTal's revised budget and guidance, prospective results of operations, production and production capacity, free cash flow, revenue, adjusted EBITDA, debt repayment, liquidity, shareholder returns and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was approved by management as of the date of this press release and was included for the purpose of providing further information about PetroTal's anticipated future business operations. PetroTal disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/128006


PetroTal Announces Q1 2022 Financial and Operating Results

Achieved record production, free cash flow and sales volumes in quarter

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - May 26, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce its financial and operating results for the three months ended March 31, 2022 ("Q1 2022").

Selected financial, and operational information is outlined below and should be read in conjunction with the Company's unaudited consolidated financial statements ("Financial Statements"), and management's discussion and analysis ("MD&A") for the three months ended March 31, 2022, which are available on SEDAR at www.sedar.com and on the Company's website at https://petrotal-corp.com/. All amounts herein are in United States dollars ("USD") unless otherwise stated.

Q1 2022 Highlights

  • Achieved record quarterly production of 11,746 barrels of oil per day ("bopd") and record quarterly sales of 15,518 bopd, up 60% and 80%, respectively, from Q1 2021, representing the Company's sixth straight quarter of growth, despite production being either constrained or completely shut down during six weeks of the quarter due to social protests;
  • Based on the 67 production days in the quarter, average production was 15,778 bopd;
  • Completed well 10H on January 30, 2022, Peru's longest ever horizontal well, with an all-in cost of $11.5 million that averaged 10,500 bopd over its first ten days, accumulating 251,320 barrels in the month of February 2022, delivering a pay back of four weeks;
  • Achieved a new daily Company production record of 21,000 bopd twice in the month of February 2022;
  • Received Ministry approval for the Company's central processing facility ("CPF-2") to operate Bretana to its maximum capacity range of 24,000 to 26,000 bopd allowing the Company significant running room for development;
  • Generated record net operating income ("NOI") and EBITDA(a) of $64.2 million and $58.7 million, respectively, more than tripling the equivalent amounts from Q1 2021;
  • Generated record free cash flow(a) of $41.2 million before changes in non cash working capital and debt service, providing the Company with a liquidity buffer which allowed it to navigate the downtime experienced in March due to social unrest and repay $20 million of its long term debt, on April 1, 2022;
  • Invested $17.5 million in capital expenditures, under budget by $18.5 million (50%) due to drilling delays from the March social protests. Of the $17.5 million invested, approximately 65% was related to drilling activities and the remainder mostly on infrastructure projects; and,
  • On February 22, 2022, PetroTal announced a $120 million fully funded capital program that could potentially generate up to $230 million of free cash flow in 2022, allowing the Company the optionality to redeem the remaining $80 million in bonds early and implement its strategy of returning capital to shareholders in Q4 2022 or Q1 2023, subject to Board approval and economic viability.

Selected Financial and Operational Highlights

    Three Months Ended   
(in thousands USD) Mar 31, 2022 Mar 31, 2021 Dec 31, 2021  
Financial
    Crude oil revenues 92,752 32,356 39,243
    Royalties (6,373) (1,748) (2,304)
    Net operating income (1) 64,194 19,969 25,726
    Commodity price derivative (gain)/loss (21,014) (22,512) 5,622
    Net income 64,511 30,785 6,843
    Diluted net income (US$/share)    0.07 0.04 0.01
    Capital expenditures 17,529 7,113 26,601  
Operating      
    Average production (bopd)(3) 11,746 7,331 10,147
    Average sales (bopd) 15,518 8,578 7,242
    Average Brent price ($/bbl) 97.49 61.06 79.79
    Contracted sales price, gross ($/bbl) 88.02 58.88 77.46
    Netback ($/bbl)(2) 45.96 25.87 38.61
    Funds flow provided by operations(3)    5,743 4,467 34,714  
Balance sheet      
    Cash and restricted cash 52,886 75,824 74,459
    Working capital 54,226 68,213 47,319
    Total assets 455,370 342,583 398,288
    Current liabilities 100,904 69,348 84,767
    Equity 270,855 168,405 204,257  

 

  1. Net operating income obtained from revenues less royalties, operating expenses, and direct transportation.
  2. Netback per barrel ("bbl") and funds flow provided by operations do not have standardized meaning prescribed by GAAP and therefore may not be comparable with the calculation of similar measures for other entities. See "Selected Financial Measures" section.
  3. Average production in Q1 2022 based on the 67 days of full or partial production was 15,778 bopd.

Q1 2022 Financial Results

Record net revenue. Delivered net revenue after differentials of $92.7 million ($66.41/bbl) compared to Q1 2021 of $32.4 million ($41.91/bbl) and Q4 2021 of $39.2 million ($58.90/bbl).

Record net operating income. Generated record NOI and EBITDA(a) of $64.2 million ($45.96/bbl) and $58.7 million ($42.05/bbl), respectively, as compared to $20.0 million ($25.87/bbl) and $16.4 million ($21.16/bbl), respectively, in Q1 2021 and $25.8 million ($38.61/bbl) and $21.8 million ($32.66/bbl) in Q4 2021.

Tactical Q1 2022 capital spend. Spent $17.5 million in capital expenditures focused on drilling and completing well 10H and advancing a number of small infrastructure projects. This was approximately half of what was budgeted for Q1 2022 due to deferral of drilling activity into Q2 2022 resulting from the social protest activity in March 2022.

Positive Q1 2022 free cash flow. Generated net positive free cash flow(a) before changes in non cash working capital and debt service of $41.2 million, which allowed the Company sufficient liquidity to execute its phase one debt reduction strategy and retire 20% of its long term debt on April 1, 2022.

Stable Q1 2022 lifting costs. Total lifting costs of $10.1 million ($7.20/bbl) were incurred in the quarter, in line on a per barrel basis with $5.5 million ($7.17/bbl) in Q1 2021, which included some elevated and one time COVID-19 mitigation costs, and slightly down from $5.1 million ($7.60/bbl) in Q4 2021.

Variable costs in line with expectations. Diluent and barging costs were $12.1 million ($8.68/bbl) in the quarter compared to $5.1 million ($6.61/bbl) in Q1 2021, driven by higher barging standby, diluent and diesel costs, and down from $6.15 million ($9.23/bbl) in Q4 2021. On a percentage basis, the Company's Q1 2022 contracted Brent price has increased approximately 50% from Q1 2021 with core variable costs only up 31% from Q1 2021, on a per barrel basis.

G&A per barrel reductions. Q1 2022 G&A was $4.7 million ($3.38/bbl) compared to $3.6 million ($4.70/bbl) in Q1 2021 and $4.0 million ($5.95/bbl) in Q4 2021 representing a 28% and 43% reduction on a per barrel basis compared to Q1 2021 and Q4 2021, driven by higher sales.

Record Q1 2022 net income. Q1 2022 net income was a record $64.5 million surpassing the entire 2021 yearly amount, doubling the Q1 2021 level of $30.8 million and significantly exceeding $6.8 million in Q4 2021. This was driven by further increases in the derivative value of the Company's crude in the ONP, and stable DD&A expense from an efficient cumulative investment in the Bretana project.

Net debt free. Q1 2022 net debt(cash) was ($9.2) million representing a net cash position as at March 31, 2022 as defined internally by the Company and not for bond covenant purposes.

Operation and Financial Highlights Subsequent to March 31, 2021

Social protest conclusion. The Company's loading dock was re-opened on April 8, 2022 and PetroTal was producing two days later after freeing space in the oil storage tanks, averaging 17,411 bopd from April 9 until April 30, 2022 with priority sales going to Brazil exports and the Iquitos refinery. Exports through Brazil restarted on April 12, 2022 and totaled 355,312 barrels of oil during the month of April.

Robust production levels resumed. Current production from May 1, 2022 to May 23, 2022, has been approximately 15,724 bopd. Even with sales into the Northern Peruvian Pipeline ("ONP") curtailed due to repairs by Petroperu, the Company's production has been largely unconstrained due to upsized offtake options for Brazil exports and general supply to the Iquitos refinery.

Brazil shipments upsized and optimized. PetroTal is pleased to announce that it has secured Brazilian export sizes of nearly 500,000 barrels per month. In addition, with Iquitos now being able to accept 60,000 barrels per month, the Company can sell the equivalent of 18,000 bopd without requiring access to the ONP.

Diluent free Brazilian route. The Company has successfully completed a pilot Brazilian shipment without diluent and will be able to export to Brazil diluent free going forwards, saving the Company over $30 million per year in diluent costs and improving net operating income by approximately $10 million per year when considering the net impact of reduced revenue from diluent in sales.

Commenced drilling on well 11H. On May 7, 2022, PetroTal commenced drilling well 11H which has an approximate cost of $13.5 million, a total depth of around 4,300 meters, and includes a synthetic mud system. The estimated completion date will be in late June 2022 with flush production expected to impact July production levels.

Social trust working table established. PetroTal facilitated the formation of a working group consisting of various community and government leaders with a mandate of discussing and prioritizing community needs for the Puinahua district and to properly establish the proposed 2.5% social trust. The working table meets regularly and has been making progress on various administrative components related to its mandate of facilitating responsible dialogue to prioritize development issues in the Puinahua region.

ONP down for maintenance. As previously announced on April 28, 2022, the ONP remains shut down for maintenance to repair significant erosion damage. The estimated completion date is late September with operations estimated to resume in Q4 2022, thus deferring the next Bayovar oil delivery with associated true up revenue until approximately October 2022.

Liquidity remains robust. Total cash at March 31, 2022 was $52.9 million with $19.0 million unrestricted compared to $75.0 million at year end of which $45.0 million was unrestricted. Accounts receivable were $54.5 million from Q1 2022 sales, and lower payables of $41.3 million, due to field downtime in March from the social protests.

Deleveraging underway. Bondholders accepted PetroTal's call provision notice regarding repayment of the $20 million in bonds dedicated to M&A activities. PetroTal made the payment on April 1, 2022 and now has $80 million in bonds remaining with no required amortization payments in 2022. The payment of $20 million was made from restricted cash, which on a proforma basis at March 31, 2022, represents $32.9 million of total cash with $19.0 million being unrestricted.

Guidance Revisions for 2022

Given that the social protest impact during the first four months of the year have already surpassed the 13% downtime assumed on our 2022 production guidance and have also delayed the Company's 2022 drilling schedule, we have adjusted our 2022 guidance, now assuming a 5% social unrest impact for the remainder of the year plus the normal 5% technical downtime. Below is a summary of adjusted guidance for the year:

Adjusted Guidance Q1 (actual) Q2 Q3 Q4 2022
Oil wells completed 1 (10H) 1 (11H) 1 (12H) 1 (13H) 4
Average Production (bopd) 11,746 ~13,500 ~16,600 ~20,000 ~15,500
CAPEX (millions) $18 $29 $34 $30 $111

 

In USD millions Original Budget Adjusted Budget
Contracted Brent (USD/bbl) $88 $102
Average Production (bopd) 18,250 (13% downtime) 15,500 (22% downtime)
Net operating income $335 $351
G&A ($22) ($22)
Net derivative settlements(1) $37 $13
Adjusted EBITDA1,a $350 $342
CAPEX ($120) ($111)
Free cash flow $230 $231

 

(1) Approximately $34 million in anticipated 2022 true-up revenue has now been deferred into 2023 as a result of the ONP maintenance.

Adjusted Guidance Summary

The cash flow impact of the 2,750 bopd reduction to the production guidance is more than offset by a higher Brent future price strip, which has maintained EBITDA and increased free cash flow estimates.

March's downtime from the social protests contributed approximately 1,140 bopd to the production guidance reduction, with the remaining 1,620 bopd of the decrease related to the delayed drilling impact for the remainder of the year's drilling schedule. The Q2-Q4 2022 drilling schedule now anticipates well 14H being drilled in late 2022 with completion deferred into early 2023. The Company expects to surpass production of 20,000 bopd, and will require use of the ONP route by Q4 2022, which coincides with its estimated maintenance completion.

The 2022 capital program has been reduced by approximately $9 million comprised of infrastructure project deferrals into 2023.

Updated Corporate Presentation and investor webcast

PetroTal is excited to announce it will be hosting an extended virtual investor meeting on May 26, 2022 at 9:00 am CT, following release of the Q1 2022 results. The objective of management will be to provide in depth information regarding certain aspects of the Bretana asset and to communicate the Company's short and long term strategy. The Company has also provided an updated corporate presentation with the Q1 2022 results, on its website.

Link to PetroTal investor morning webcast

https://stream.brrmedia.co.uk/broadcast/6274f7b58eb4f178d1ef9592

Manuel Pablo Zuniga-Pflucker, President and Chief Executive Officer, commented:

"PetroTal was able to pivot through social downtime challenges extremely well while still showing quarter over quarter production growth and a revised 2022 budget that shareholders should be very excited about considering the drilling delays encountered in March. The social trust working table has been formed, met initially on May 3, 2022 and ongoing meetings will continue to advance the formal policy and procedure formation for the social trust. The positive response for this initiative has been overwhelming and we are excited about formalizing additional items as the year progresses."

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, PetroTal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

READER ADVISORIES

Notes to Press Release
(a) See "Specified Financial Measures".

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's revised 2022 guidance and budget including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; the intention to redeem the outstanding bonds; PetroTal plans to deliver strong operational performance and to generate free cash flow and growth; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, impact of inflation on costs, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, wars (including Russia's military actions in Ukraine), access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. Ongoing military actions between Russia and Ukraine have the potential to threaten the supply of oil and gas from the region. The long-term impacts of the actions between these nations remains uncertain. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the Corporation's most recent annual information form and MD&A, which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

SHORT-TERM PRODUCTION RATES: References in this press release peak production, initial 10 days of production and other short-term production 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 PetroTal. The Company cautions that such results should be considered to be preliminary.

OIL REFERENCES: All references to "oil" or "crude oil" production, revenue or sales in this press release mean "heavy crude oil" as defined in NI 51-101. All references to Brent indicate Intercontinental Exchange ("ICE") Brent.

SPECIFIED FINANCIAL MEASURES: This press release includes various specified financial measures, including non-GAAP financial measures, non-GAAP financial ratios and capital management measures as further described herein. These measures do not have a standardized meaning prescribed by generally accepted accounting principles ("GAAP") and, therefore, may not be comparable with the calculation of similar measures by other companies. Management uses these non- GAAP measures for its own performance measurement and to provide shareholders and investors with additional measurements of the Company's efficiency and its ability to fund a portion of its future capital expenditures. "Netback" (non-GAAP financial ratio) equals total petroleum sales less quality discount, lifting costs, transportation costs and royalty payments calculated on a bbl basis. The Company considers netbacks to be a key measure as they demonstrate Company's profitability relative to current commodity prices. "Funds flow provided by operations" (non-GAAP financial measure) includes all cash generated from operating activities and is calculated before changes in non-cash working capital. "Adjusted EBITDA" (non-GAAP financial measure) is calculated as consolidated net income (loss) before interest and financing expenses, income taxes, depletion, depreciation and amortization and adjusted for G&A impacts and certain non-cash, extraordinary and non-recurring items primarily relating to unrealized gains and losses on financial instruments and impairment losses, including derivative true-up settlements. PetroTal utilizes adjusted EBITDA as a measure of operational performance and cash flow generating capability. Adjusted EBITDA impacts the level and extent of funding for capital projects investments. Reference to EBITDA is calculated as net operating income less G&A. "Free cash flow" (non-GAAP financial measure) is calculated as net operating income less G&A less exploration and development capital expenditures and is calculated prior to all debt service, taxes, lease payments, hedge costs, factoring, and lease payments. Management uses free cash flow to determine the amount of funds available to the Company for future capital allocation decisions. Please refer to the MD&A for additional information relating to specified financial measures.

FOFI DISCLOSURE: This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about PetroTal's revised budget and guidance, prospective results of operations, production and production capacity, free cash flow, revenue, adjusted EBITDA, debt repayment, liquidity, shareholder returns and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was approved by management as of the date of this press release and was included for the purpose of providing further information about PetroTal's anticipated future business operations. PetroTal disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/125348


PetroTal to Release Q1 2022 Results on May 26, 2022, Along with an Investor Webcast

Well 11H Drilling Commenced on May 7, 2022

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - May 19, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce that Q1 2022 results will be released on May 26, 2022, along with an extended investor webcast. Additionally, the Company commenced drilling the 11H well on May 7, 2022.

Commenced drilling well 11H. On May 7, 2022, PetroTal commenced drilling well 11H, which has an approximate cost of $13.5 million, a total depth of around 4,300 meters, and includes a synthetic mud system. The estimated completion date will be in late June 2022 with flush production expected to contribute to July 2022 operating results.

Extended investor webcast. PetroTal is pleased to announce it will be hosting an extended virtual investor meeting commencing at 9:00 am CT (3:00 pm BST) on May 26, 2022 following release of Q1 2022 results. The webcast is expected to last approximately two hours and will include presentation of the Q1 2022 results, an investor Q&A session and additional management commentary on a number of PetroTal's operational and financial aspects as well as the Company's short and long term strategy.

Link to PetroTal investor morning webcast
https://stream.brrmedia.co.uk/broadcast/6274f7b58eb4f178d1ef9592

New technically focused presentation available on website. PetroTal's technical team is presenting an in-depth technical view of the Bretana asset at the FEX Energia conference in Quito, Ecuador on May 19, 2022. The technical presentation is now available on the Company's website.

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, Petrotal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

READER ADVISORIES

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's anticipated operational results for 2022 including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; the intention to redeem the outstanding bonds; PetroTal plans to deliver strong operational performance and to generate free cash flow and growth; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. Without limitation of the foregoing, future dividend payments, if any, and the level thereof, is uncertain, as the Company's dividend policy and the funds available for the payment of dividends from time to time is dependent upon, among other things, free cash flow financial requirements for the Company's operations and the execution of its growth strategy, fluctuations in working capital and the timing and amount of capital expenditures, debt service requirements and other factors beyond the Company's control. Further, the ability of PetroTal to pay dividends will be subject to applicable laws (including the satisfaction of the solvency test contained in applicable corporate legislation) and contractual restrictions contained in the instruments governing its indebtedness. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, impact of inflation on costs, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, wars (including Russia's military actions in Ukraine), access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. Ongoing military actions between Russia and Ukraine have the potential to threaten the supply of oil and gas from the region. The long-term impacts of the actions between these nations remains uncertain. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the AIF and MD&A, which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/124676


PetroTal Announces 2021 Year-End Financial and Operating Results

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - April 28, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce its financial and operating results for the year and three months ("Q4") ended December 31, 2021.

Selected financial, reserves and operational information is outlined below and should be read in conjunction with the Company's audited consolidated financial statements ("Financial Statements"), management's discussion and analysis ("MD&A") and annual information form ("AIF") for the year ended December 31, 2021, which are available on SEDAR at www.sedar.com and on the Company's website at www.PetroTal‐Corp.com. Reserve amounts presented herein were derived from an independent reserves report (the "NSAI Report") prepared by Netherland, Sewell & Associates, Inc. ("NSAI") effective December 31, 2021. All amounts herein are in United States dollars ("USD") unless otherwise stated.

2021 Significant Milestones and Highlights

  • Achieved production of 8,966 barrels of oil per day ("bopd") and sales of 8,449 bopd, up 58% and 48%, respectively, from 2020;
  • Recorded a 5th straight quarter of production growth; reaching 10,147 bopd in Q4 2021 from 9,508 bopd in Q3 2021;
  • Achieved a four year Company target of 20,000 bopd in mid December 2021 underpinned by strong production rates from the newly drilled 8H and 9H wells in late Q3 and Q4 2021 that each reached over 8,500 bopd, respectively;
  • Generated record net operating income ("NOI") and EBITDA(a) in 2021 of $105 million and $90 million, up approximately 3.6x and 5x, respectively, from 2020;
  • Generated record funds flow provided by operations(a), before changes in working capital of $86.7 million, up over 5x from 2020;
  • Grew proved plus probable ("2P") and proved plus probable plus possible ("3P") reserves by 53% and 39%, respectively, to 78 and 147 million barrels of oil ("bbl");
  • Material progression of 2P after tax net present value discounted at 10% ("NPV-10") reserve value per share of $1.23, up 62% from 2020;
  • Generated 2021 proved ("1P") and 2P reserve replacement ratios of 457% and 816%, respectively; and,
  • Created the framework for a social trust representing 2.5% of production, to create long standing alignment between communities and government, with a view to minimizing social downtime, maximizing social profitability, and developing community projects that will have a significant positive impact near the Company's Bretana oilfield.

Selected Financial and Operational Highlights

Three Months Ended Twelve Months Ended  
(in thousands USD) Dec 31, 2021 Sept 30, 2021 Dec 31, 2021 Dec 31, 2020  
Financial
Crude oil revenues 39,243 44,781 159,189 76,593
Royalties (2,304 ) (2,604 ) (8,962 ) (2,877 )
Net operating income (1) 25,726 29,587 104,960 28,881
Commodity price derivative (income)/loss 5,622 (293 ) (13,036 ) 4,788
Net income (loss) 6,843 14,970 63,972 (1,524 )
Basic and diluted net income (loss) (US$/share) 0.01 0.02 0.08 (0.00 )
Capital expenditures 26,601 26,114 82,191 42,297  
Operating        
Average production (bopd) 10,147 9,508 8,966 5,675
Average sales (bopd) 7,242 9,142 8,449 5,700
Average Brent price ($/bbl) 79.79 73.21 70.82 43.20
Contracted sales price, gross ($/bbl) 77.46 71.06 68.22 43.02
Netback ($/bbl)(1) 38.61 35.18 34.03 13.84
Funds flow provided by operations(2) 34,714 18,648 77,456 13,341  
Balance sheet        
Cash and restricted cash 74,459 57,655 74,459 9,628
Working capital 47,319 56,455 47,319 (22,157 )
Total assets 398,288 373,261 398,288 215,138
Current liabilities 84,767 69,785 84,767 58,608
Equity 204,257 195,572 204,257 137,163  

 

(1) Net operating income obtained from revenues less royalties, operating expenses, and direct transportation.
(2) Netback per barrel ("bbl") and funds flow provided by operations do not have standardized meaning prescribed by GAAP and therefore may not be comparable with the calculation of similar measures for other entities. See "Selected Financial Measures" section.

2021 Operational highlights

  • Robust well results. Completed one deviated and two horizontal oil wells in 2021. Both horizontal wells had the longest laterals ever drilled in Peru with production rates in excess of 8,500 bopd during the first month, and both paying out in under two months. Well 7D, drilled as a deviated well in the spring of 2021, had rates in excess of 4,000 bopd and has produced over 0.5 million bbl in under one year.
  • Infrastructure achievements. Achieved significant infrastructure milestones in 2021 with the completion of all major construction work on CPF-2 and the completion and coring of an additional water disposal well, essentially doubling water disposal capacity to 100,000 barrels of water per day and allowing the field to produce up to 26,000 bopd of oil.
  • Material reserves increases. Delivered excellent 2021 reserve report upgrades with increases for 1P, 2P, and 3P reserves by 68%, 53%, and 39% to 37.4, 77.9 and 147.1 million barrels, respectively. In addition, PetroTal was able to decrease 2P Finding and Development Costs ("F&D") by 6% to $4.68/bbl while adding seven 2P locations plus related infrastructure, leading to a record 2P after tax NPV-10 of just over $1 billion.
  • Expanded Brazilian sales. Created a highly successful third sales route to market into the Atlantic region through Brazil that has surpassed the Northern Peruvian Pipeline ("ONP") as the Company's second most profitable sales route. The first pilot cargo, completed in December 2020 was 106,000 barrels, and during 2021 PetroTal built a strong trusted commercial relationship that will allow Brazilian shipments of 400,000 barrel cargos (without the need for diluent blending), thereby providing a safe and stable offtake of nearly 14,000 bopd at attractive netbacks.
  • Social alignment mechanism established. In an effort to facilitate long standing alignment between the government and communities, PetroTal announced and submitted a proposal to the Peruvian Ministry of Energy and Mines for creation of a new social trust aimed to promote direct investments into the Loreto region. The fund will be based on 2.5% of crude oil production, payable over two week periods and calculated using the same methodology as Perupetro applies for royalties. The fund committee and investment legal entities are in the process of being created with full transparency and auditability to the public.
  • 2021 capital program executed and optimized. PetroTal's 2021 Capex investment totaled $82 million in 2021 compared to $42 million in 2020, which was significantly curtailed due to the COVID-19 pandemic.

2021 Financial highlights

  • Leverage to kickstart development. Successfully executed a $100 million senior secured bond issue at the trough of the oil price commodity price cycle with payment terms and amortization optimized to impact the Company in a much stronger oil macro backdrop, allowing PetroTal to commence its 2021 capital program in March 2021 with a sound liquidity injection.
  • Record net revenue. Delivered net revenue after differentials and royalties of $150 million ($48.70/bbl) compared to 2020 of $74 million ($35.58/bbl).
  • Record net operating income. Generated record NOI and EBITDA(a) of $105 million ($34.03/bbl) and $90 million ($29.31/bbl), respectively, as compared to $28.9 million ($13.84/bbl) and $18.3 million ($8.77/bbl), respectively, in 2020.
  • Successful 2021 capital program. Executed an $82 million Capex program (originally budgeted at $101 million), deferring some non-essential infrastructure projects into 2022 to match with higher Brent pricing and more fluid labor movement.
  • Positive 2021 free cash flow. Generated annual net positive free cash flow(a) before changes in non cash working capital and debt service of $8.4 million, a first for PetroTal.
  • True up revenue realized. Received true-up payments from Petroperu of approximately $28.6 million in 2021 from oil reaching the Bayovar port and being sold at a higher price than originally received at pump station 1 of the ONP, enhancing financial metrics, and provided tailwind liquidity throughout the year.
  • Scalable lifting costs. Maintained total lifting costs between $5.1 and $5.5 million per quarter in 2021 demonstrating significant scalability as production grew 60% from Q4 2020 to Q4 2021. On an annualized basis lifting costs were $21.5 million ($6.99/bbl) for 2021 compared to $15.7 million ($7.51/bbl) in 2020.
  • Variable costs impacted by higher Brent pricing. Diluent and barging costs were $23.7 million ($7.68/bbl) in 2021 as compared to approximately $14.3 million ($6.85/bbl) in 2020. Increased per barrel metrics are attributed to higher barging diesel, diluent, and floating storage costs in 2021, compared to 2020.
  • Reduced G&A per barrel. 2021 G&A of $14.3 million ($4.63/bbl) compared to $10.6 million ($5.07/bbl) in 2020, demonstrating a per barrel reduction of 10% and less than a 10% burden on adjusted EBITDA margins.
  • Record 2021 net income. 2021 net income was a record $63.2 million ($0.08/share) compared to a net loss of $1.5 million ($0.00/share) in 2020 driven by higher commodity prices, sales volumes and a derivative gain related to sales volumes moving through the ONP valued at a higher Brent price compared to initial entry into the ONP.

Operation and Financial Highlights Subsequent to December 31, 2021

  • Leverage reduction. Due to early robust 2022 free cash flow generation and strong liquidity, PetroTal elected to repay $20 million of the original $100 million bond issue, on April 1, 2022, reducing its total long term debt to $80 million, thereby lowering future interest costs.
  • Exceptional continued well performance. Achieved a 10 day record production level for well 10H of 10,050 bopd allowing the Company to set a new total production record of 20,891 bopd for February 2022, and well payout in under a month.
  • CPF-2 approved. Received approval by Peruvian regulators for full commissioning and fluid processing of CPF-2 so that up to 26,000 bopd can be processed by PetroTal.
  • Free cash flow focused 2022 budget. On February 22, 2022, PetroTal announced a $120 million fully funded capital program that could potentially generate up to $230 million of free cash flow in 2022, allowing the Company the optionality to redeem the remaining $80 million in bonds early and implement its return of capital to shareholders strategy in Q4 2022, subject to Board approval.
  • TSX-V award winner and OTCQX Best Market upgrade. PetroTal was recognized as a top TSX Venture exchange performer for 2021 ranking 10th in the energy sector and in mid January 2022, PetroTal upgraded to the OTCQX Best Market in the United States under the ticker symbol PTALF.
  • Establishment of the 2.5% social trust brings interim dispute. The establishment of the 2.5% social trust brought some anticipated demands from a minority group wanting to control the trust capital allocation process. This resulted in the Company's oil loading dock been blocked for five weeks requiring the intervention of Peru's Prime Minister and the government's full attention to the area's social disputes.

Operational and Financial Highlights for Q4 2021

  • Continued production growth. PetroTal produced 10,147 bopd and averaged 7,242 bopd in sales, which was impacted by social disruptions at the ONP, along with intermittent downtime leading to constrained production schedules, compared to Q3 2021 production and sales of 9,508 bopd and 9,142 bopd, respectively.
  • 20,000 bopd production target achieved. The Company, with boosts from well 8H and 9H, achieved a five day trailing production rate of 20,000 bopd ending December 15, 2021, reaching its long standing target only four years after commencing operations at the Bretana oil field.
  • Completion of well 8H. Well 8H was completed in late Q3 2021 for under $12 million, had initial production rates in excess of 8,500 bopd, paying out in Q4 2021 from realized netbacks of over $38.00/bbl.
  • Completion of well 9H. Well 9H, completed in early December 2021, achieved approximately 9,000 bopd in early testing, averaging 8,200 bopd for the subsequent ten-day period.
  • Strong net operating income despite constrained sales. PetroTal generated $25.7 million in net operating income in Q4 2021, a decrease from $29.6 million in Q3 2021, driven by lower sales volumes stemming from social protests in November and December 2021.
  • Capex optimization. The Company invested $26.6 million in Q4 2021, up slightly from the prior quarter due to ongoing consistent drilling activities in the second half of 2021.
  • Continued and expanding Brazilian exports. PetroTal continued to utilize the Brazilian shipping route in Q4 2021, exporting 320,000 barrels in November and December 2021 compared to only 106,000 barrels in Q4 2020.
  • Opex and Transportation cost flexibility. Lifting expense and direct transportation costs were $11.2 million ($16.82/bbl) in Q4 2021 compared to $12.6 million ($14.97/bbl) in Q3 2021, and $10.7 million ($21.23/bbl) in Q4 2020. During Q4 2022, the Company effectively utilized barges for oil storage to manage production and sales fluctuations during social disruptions.
  • Strong Q4 2021 exit liquidity. Exited 2021 with strong balance sheet liquidity of $75.0 million in total cash and approximately $57.0 million of net debt which was approximately 0.63x net debt to 2021 EBITDA.
  • Growing derivative asset. The exit Q4 2021 net derivative asset was $36.7 million, representing the mark to market value of oil in the ONP, corporate hedges, and ONP hedges.

Operation and Financial Highlights Subsequent to December 31, 2021

  • Leverage reduction. Due to early robust 2022 free cash flow generation and strong liquidity, PetroTal elected to repay $20 million of the original $100 million bond issue, on April 1, 2022, reducing its total long term debt to $80 million, thereby lowering future interest costs.
  • Exceptional continued well performance. Achieved a 10 day record production level for well 10H of 10,050 bopd allowing the Company to set a new total production record of 20,891 bopd for February 2022, and well payout in under a month.
  • CPF-2 approved. Received approval by Peruvian regulators for full commissioning and fluid processing of CPF-2 so that up to 26,000 bopd can be processed by PetroTal.
  • Free cash flow focused 2022 budget. On February 22, 2022, PetroTal announced a $120 million fully funded capital program that could potentially generate up to $230 million of free cash flow in 2022, allowing the Company the optionality to redeem the remaining $80 million in bonds early and implement its return of capital to shareholders strategy in Q4 2022, subject to Board approval.
  • TSX-V award winner and OTCQX Best Market upgrade. PetroTal was recognized as a top TSX Venture exchange performer for 2021 ranking 10th in the energy sector and in mid January 2022, PetroTal upgraded to the OTCQX Best Market in the United States under the ticker symbol PTALF.
  • Establishment of the 2.5% social trust brings interim dispute. The establishment of the 2.5% social trust brought some anticipated demands from a minority group wanting to control the trust capital allocation process. This resulted in the Company's oil loading dock been blocked for five weeks requiring the intervention of Peru's Prime Minister and the government's full attention to the area's social disputes.

Current Operations

The Company's loading dock was re-opened on April 7, 2022 and PetroTal has been producing approximately 18,200 bopd over the last 10 days with priority sales going to Iquitos and Brazil thereafter. Until the ONP maintenance is completed, the Company will be managing production volumes to fit the Iquitos and Brazil sales threshold of nearly 16,000 bopd.

PetroTal is currently preparing to drill well 11H in early May with a late June or early July completion, at an estimated cost of $15.6 million.

Updated Corporate Presentation and upcoming investor update

PetroTal is excited to announce it will be hosting a virtual investor meeting on May 26, 2022 following the release of Q1 2022 results. The objective of management will be to provide updates on certain aspects of the Bretana asset and to communicate the Company's short and long term strategy. The Company has provided an updated corporate presentation with these 2021 results, on its website.

Manuel Pablo Zuniga-Pflucker, President and Chief Executive Officer, commented

"2021 will be remembered for many significant operational, commercial and financial milestones achieved by the PetroTal team. When unconstrained, PetroTal is the largest crude oil producer in Peru and our management team is well aware of the responsibilities and deliverables that accompany that stature. Our goals for 2022 are very clear, and given the tailwind of a robust commodity price environment aiding us, we believe the Company can add tremendous value. Having met our original goal of 20,000 bopd, the team is now focused on achieving a new production target of 25,000 bopd with minimal social downtime. I would like to thank PetroTal's shareholders, directors, employees, and contractors for their continued support and I look forward to keeping the market updated on the Company's progress throughout the remainder of 2022."

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) and (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, Petrotal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

READER ADVISORIES

Notes to Press Release
(a) See "Specified Financial Measures".

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's anticipated operational results for 2022 including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; the intention to redeem the outstanding bonds; PetroTal plans to deliver strong operational performance and to generate free cash flow and growth; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. Without limitation of the foregoing, future dividend payments, if any, and the level thereof, is uncertain, as the Company's dividend policy and the funds available for the payment of dividends from time to time is dependent upon, among other things, free cash flow financial requirements for the Company's operations and the execution of its growth strategy, fluctuations in working capital and the timing and amount of capital expenditures, debt service requirements and other factors beyond the Company's control. Further, the ability of PetroTal to pay dividends will be subject to applicable laws (including the satisfaction of the solvency test contained in applicable corporate legislation) and contractual restrictions contained in the instruments governing its indebtedness. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, impact of inflation on costs, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, wars (including Russia's military actions in Ukraine), access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. Ongoing military actions between Russia and Ukraine have the potential to threaten the supply of oil and gas from the region. The long-term impacts of the actions between these nations remains uncertain. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the AIF and MD&A, which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

PRESENTATION OF OIL AND GAS INFORMATION: The reserves information herein sets forth PetroTal's reserves as at December 31, 2021, as presented in the independent reserves report prepared by NSAI, a qualified reserves evaluator, in accordance with the standards contained in the most recent publication of the Canadian Oil and Gas Evaluation Handbook (the "COGE Handbook") and the reserve definitions contained in National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). In addition to the summary information disclosed in this announcement and the press release dated February 15, 2022, more detailed information is included in the AIF. All oil and gas disclosure contained in this press release complies with the requirements of NI 51-101.

OIL AND GAS MEASURES: This press release contains metrics commonly used in the oil and natural gas industry which have been prepared by management, such as "F&D costs". These terms do not have a standardized meaning and may not be comparable to similar measures presented by other companies, and therefore should not be used to make such comparisons. ""Finding and development costs" or "F&D costs" are calculated as the sum of field capital plus the change in future development costs for the period divided by the change in reserves that are characterized as development for the period. Finding and development costs take into account reserves revisions during the year on a per bbl basis. The aggregate of the exploration and development costs incurred in the financial year and changes during that year in estimated future development costs generally will not reflect total finding and development costs related to reserves additions for that year. Management uses these oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare PetroTal's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this press release, should not be relied upon for investment or other purposes.

SHORT-TERM PRODUCTION RATES: References in this press release peak production and other short-term production 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 PetroTal. The Company cautions that such results should be considered to be preliminary.

OIL REFERENCES: All references to "oil" or "crude oil" production, revenue or sales in this press release mean "heavy crude oil" as defined in NI 51-101. All references to Brent indicate Intercontinental Exchange ("ICE") Brent.

SPECIFIED FINANCIAL MEASURES: This press release includes various specified financial measures, including non-GAAP financial measures, non-GAAP financial ratios and capital management measures as further described herein. These measures do not have a standardized meaning prescribed by generally accepted accounting principles ("GAAP") and, therefore, may not be comparable with the calculation of similar measures by other companies. Management uses these non- GAAP measures for its own performance measurement and to provide shareholders and investors with additional measurements of the Company's efficiency and its ability to fund a portion of its future capital expenditures. "Netback" (non-GAAP financial ratio) equals total petroleum sales less quality discount, lifting costs, transportation costs and royalty payments calculated on a bbl basis. The Company considers netbacks to be a key measure as they demonstrate Company's profitability relative to current commodity prices. "Funds flow provided by operations" (non-GAAP financial measure) includes all cash generated from operating activities and is calculated before changes in non-cash working capital. "Adjusted EBITDA" (non-GAAP financial measure) is calculated as consolidated net income (loss) before interest and financing expenses, income taxes, depletion, depreciation and amortization and adjusted for G&A impacts and certain non-cash, extraordinary and non-recurring items primarily relating to unrealized gains and losses on financial instruments and impairment losses, including derivative true-up settlements. PetroTal utilizes adjusted EBITDA as a measure of operational performance and cash flow generating capability. Adjusted EBITDA impacts the level and extent of funding for capital projects investments. Reference to EBITDA is calculated as net operating income less G&A. "Free cash flow" (non-GAAP financial measure) is calculated as net operating income less G&A less exploration and development capital expenditures and is calculated prior to all debt service, taxes, lease payments, hedge costs, factoring, and lease payments. Management uses free cash flow to determine the amount of funds available to the Company for future capital allocation decisions. Please refer to the MD&A for additional information relating to specified financial measures.

FOFI DISCLOSURE: This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about PetroTal's budget and guidance, prospective results of operations, production and production capacity, free cash flow, revenue, adjusted EBITDA, debt repayment, liquidity, shareholder returns and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was approved by management as of the date of this press release and was included for the purpose of providing further information about PetroTal's anticipated future business operations. PetroTal disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein. All FOFI contained in this press release complies with the requirements of Canadian securities legislation, including NI 51-101.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/121945


PetroTal Announces Social and Operational Updates

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - April 7, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce a signed government agreement to end the social protest, previously announced on March 3, 2022, and recommencement of production and oil sales upon opening of the loading dock.

Protest Conclusion

On Wednesday April 6, 2022, Peruvian government officials reached an agreement with the Asociación Indigena de Desarrollo y Conservación de Bajo Puinahua ("AIDECOBAP"), to end the social protest, which has been blocking PetroTal's loading dock. AIDECOBAP was protesting against the government on three core issues: prosecution of protesting rights, allocation of the Basic Needs Trust capital to close the social gaps that exist in Peru, and that the government expedite the formalization of the Bretana 2.5% social fund, offered by PetroTal, into the Block 95 license contract.

Peruvian government officials, which included the Prime Minister, with support from PetroTal and local community members, agreed to the following items:

  • The Ministry of Energy and Mines presented the proposal for a Ministerial Resolution for the creation of a technical working group to analyze the needs of local communities in the Block 95 area;
  • Perupetro has agreed to propose the incorporation of the 2.5% social development fund as an addenda into the license contract through a supreme decree; and,
  • AIDECOBAP will immediately lift the blockade near PetroTal's loading dock.

Based on the current trust framework, PetroTal has funded trust allocations totaling $1.1 million to date, for the eligible fortnight periods in 2022. The working group will observe, recommend and support social trust policy, while day to day operations of the social trust will be managed by an independent third party. PetroTal will also continue to fund and support its ongoing social project commitments directly or via independent project contractors. PetroTal wishes to thank local residents and government officials for continued support through this protest period.

Production Restoration Plan

In anticipation of an agreement being reached, PetroTal has oil barge support ready to arrive within hours of the loading dock's formal reopening. The first technical priority is to unload approximately 90,000 barrels of crude oil stored at the oil field, with four to five barges currently engaged. Next, the operations team will ramp production back up over a five to seven day period. This production, along with the stored volumes, will be sold to the Iquitos refinery and through the Brazilian sales export route thereafter.

In Q1 2022, PetroTal produced over 1 million barrels of oil, approximately 11,700 bopd, despite being significantly production constrained for most of March 2022. This is a PetroTal record for quarterly production and equates to a sixth straight quarter of production growth for the Company.

ONP Pipeline Status

As previously announced on March 3, 2022, the Petroperu operated Northern Peruvian Pipeline remains closed due to erosion caused by the rainy season, with no firm timeline of maintenance completion provided by Petroperu. The Company is now focusing all efforts to maximize sales to the Iquitos refinery and the Brazilian export route. Commercial and technical efforts to eventually sell 400,000 barrel (13,000 bopd) monthly cargos through the Brazil route are being explored.

CPF-2 Approval

The Company's fully commissioned central processing facility ("CPF-2") received ministry approval on March 11, 2022 and is now able to operate up to 26,000 bopd.

Bond Update

Bondholders have formally accepted PetroTal's call provision notice regarding repayment of the $20 million in bonds dedicated to M&A activities. PetroTal made the payment on April 1, 2022, and now has $80 million in bonds remaining with no required amortization payments in 2022.

Liquidity Update

The Company's cash position at March 31, 2022 is approximately $53 million, of which $32 million is restricted.

Manuel Pablo Zuniga-Pflucker, President and Chief Executive Officer, commented

"We are pleased with this agreement that has ended the protesting near our loading dock. We are also extremely appreciative of Perupetro and the Peruvian government's support towards PetroTal's social fund initiative that is aimed at creating long lasting peace in the region for the benefit of all and without any discrimination whatsoever. We can now turn our focus to operational optimization and continued development of Bretana."

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL, AIM: PTAL and OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, Petrotal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

READER ADVISORIES

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's 2022 budget and financial/operational guidance; PetroTal's anticipated operational results for 2022 including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. Without limitation of the foregoing, future dividend payments, if any, and the level thereof, is uncertain, as the Company's dividend policy and the funds available for the payment of dividends from time to time is dependent upon, among other things, free cash flow financial requirements for the Company's operations and the execution of its growth strategy, fluctuations in working capital and the timing and amount of capital expenditures, debt service requirements and other factors beyond the Company's control. Further, the ability of PetroTal to pay dividends will be subject to applicable laws (including the satisfaction of the solvency test contained in applicable corporate legislation) and contractual restrictions contained in the instruments governing its indebtedness. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru and abroad, wars (including Russia's military actions in Ukraine), hostilities, civil insurrections, access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Ongoing military actions between Russia and Ukraine have the potential to threaten the supply of oil and gas from the region. The long-term impacts of the actions between these nations remains uncertain. Please refer to the risk factors identified in the Company's annual information form for the year ended December 31, 2020 and management's discussion and analysis for the three and nine months ended September 30, 2021 which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/119615


PetroTal Announces Grant of Performance Share Units

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - March 18, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) and (OTCQX: PTALF) ("PetroTal" or the "Company") announces the annual grant of performance share units ("PSUs") to employees and officers of the Company.

2022 PSU Issuance

PetroTal granted an aggregate of 4,993,859 PSUs, of which 3,169,560 are to officers of the Company in accordance with the provisions of the Company's PSU plan. The PSUs issued to the officers will vest three years from the date of grant and each PSU will entitle the holder to acquire, for nil cost, between zero and two common shares of the Company ("Shares"), subject to the achievement of performance conditions relating to the Company's total shareholder return, net asset value and certain production and operational milestones. The remaining PSUs vest annually, on an equal basis, over the next three years. The Corporate Governance and Compensation Committee of the Board is charged with overseeing the PSU plan.

Summary of PSU grants to officers

Manuel Pablo Zuniga-Pflucker President and CEO 2,120,000
Douglas Urch Executive Vice President and CFO 587,818
Dewi Jones Vice President, Exploration and Development 461,742

 

Further details regarding the PSU plan are set out in the management information circular of the Company dated May 13, 2021, which is available on SEDAR at www.sedar.com.

Following this grant, the Company has a total of 28,577,181 PSUs outstanding.

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) and (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, Petrotal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

READER ADVISORIES

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus, including executing 2P development plans to prevent base declines and optimize water handling peaks; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's 2022 budget and financial/operational guidance; PetroTal's anticipated operational results for 2022 including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; the intention to redeem the outstanding bonds; PetroTal plans to deliver strong operational performance and to generate free cash flow and growth; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. Without limitation of the foregoing, future dividend payments, if any, and the level thereof, is uncertain, as the Company's dividend policy and the funds available for the payment of dividends from time to time is dependent upon, among other things, free cash flow financial requirements for the Company's operations and the execution of its growth strategy, fluctuations in working capital and the timing and amount of capital expenditures, debt service requirements and other factors beyond the Company's control. Further, the ability of PetroTal to pay dividends will be subject to applicable laws (including the satisfaction of the solvency test contained in applicable corporate legislation) and contractual restrictions contained in the instruments governing its indebtedness. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the Company's annual information form for the year ended December 31, 2020 and management's discussion and analysis for the three and nine months ended September 30, 2021 which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/117235


PetroTal Advises of Reduced Production Level Due to Social Unrest

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - March 3, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") advises that it has reduced production to ensure field safety and manage storage levels due to social protests at PetroTal's loading dock.

On February 28, 2022 a small group from the Asociación Indígena de Desarrollo y Conservación de Bajo Puinahua ("AIDECOBAP") commenced gathering outside the Bretana oilfield that led to access to the Company's loading dock being blocked. To ensure employee / contractor safety and minimize environmental risk, the Company has constrained its production level to approximately 4,000 barrels of oil per day, accumulating into field storage facilities, while aiding in protest negotiations.

AIDECOBAP continues to push for fulfillment of their demands from the government. AIDECOBAP claims they are being persecuted by the government for protesting their requests. They are also requesting the establishment of an indigenous trust to allow them to execute projects whose funding was approved by the government in late 2020 to reduce the basic needs gap in local communities. Lastly, AIDECOBAP is also requesting that the government expedite the formalization of the Bretana 2.5% social fund, offered by PetroTal, into the Block 95 license contract.

For the second fortnight of January and all of February 2022, PetroTal had been segregating the 2.5% social fund into a separate bank account, but due to the current protests and resulting production curtailment, no funds will be allocated for the upcoming fortnight as per the guidelines of the social trust.

The Company is also monitoring the progress of necessary maintenance repairs to the Northern Peruvian Pipeline ("ONP"). While the repairs have been ongoing, PetroTal has been selling oil through the Brazil export route. Last month the Company completed a 240,000 barrel oil sale through Brazil, for the first time without diluent blending, which will have a positive impact on diluent costs in Q1 2022.

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, Petrotal became the second largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/115575


PetroTal Announces TSX Venture Exchange Recognition and Bond Update

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - February 28, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce that it has been recognized as one of the top 50 performing TSX-V listed issuers, ranking tenth in the energy industry sector. All amounts are quoted in US dollars.

TSX Venture 50

The 2022 Venture 50 is an annual program of the TSX Venture Exchange that recognizes the top performing TSXV-listed companies from five industry sectors. The 2022 Venture 50 winners are chosen based on 2021 annual performance for market capitalization growth, share price appreciation and trading volume. A video featuring PetroTal can be found at the link below. For more information and the full 2022 Venture 50 ranking, visit: www.tsx.com/venture50.

2022 TSX Venture 50 video link

https://vimeo.com/marketonemediagroup/review/676647431/6fd32a3512

Bond Update

PetroTal also advises that is has provided the required notice to bondholders, per the bond indenture, of its intention to repay $20 million in bonds, previously reserved for M&A activities. The cash settlement will occur on or around April 1, 2022. Subsequent to this payment, the Company estimates long term debt, excluding lease obligations and abandonment costs, will be $80 million.

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, Petrotal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer

Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer

Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

READER ADVISORIES

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus, including executing 2P development plans to prevent base declines and optimize water handling peaks; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's 2022 budget and financial/operational guidance; PetroTal's anticipated operational results for 2022 including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; the intention to redeem the outstanding bonds; PetroTal plans to deliver strong operational performance and to generate free cash flow and growth; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. Without limitation of the foregoing, future dividend payments, if any, and the level thereof, is uncertain, as the Company's dividend policy and the funds available for the payment of dividends from time to time is dependent upon, among other things, free cash flow financial requirements for the Company's operations and the execution of its growth strategy, fluctuations in working capital and the timing and amount of capital expenditures, debt service requirements and other factors beyond the Company's control. Further, the ability of PetroTal to pay dividends will be subject to applicable laws (including the satisfaction of the solvency test contained in applicable corporate legislation) and contractual restrictions contained in the instruments governing its indebtedness. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the Company's annual information form for the year ended December 31, 2020 and management's discussion and analysis for the three and nine months ended September 30, 2021 which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

OIL REFERENCES: All references to "oil" or "crude oil" production, revenue or sales in this press release mean "heavy crude oil" as defined in NI 51-101. All references to Brent indicate Intercontinental Exchange ("ICE") Brent.

NON-GAAP FINANCIAL MEASURES: This press release contains financial terms that are not considered measures under generally accepted accounting principles ("GAAP") such as EBITDA and free cash flow that do not have any standardized meaning under GAAP and may not be comparable to similar measures presented by other companies. Management uses these non-GAAP measures for its own performance measurement and to provide shareholders and investors with additional measurements of the Company's efficiency and its ability to fund a portion of its future capital expenditures. EBITDA is calculated as consolidated net income (loss) before interest and financing expenses, income taxes, depletion, depreciation and amortization and adjusted for G&A impacts and certain non-cash, extraordinary and non-recurring items primarily relating to unrealized gains and losses on financial instruments and impairment losses, including derivative true-up settlements. PetroTal utilizes EBITDA as a measure of operational performance and cash flow generating capability. EBITDA impacts the level and extent of funding for capital projects investments. Free cash flow is calculated as cash flow from operating activities less exploration and development capital expenditures and is calculated prior to all debt service, taxes, lease payments, hedge costs, factoring, and lease payments. Management uses free cash flow to determine the amount of funds available to the Company for future capital allocation decisions.

FOFI DISCLOSURE: This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about PetroTal's budget and guidance, prospective results of operations, production and production capacity, free cash flow, revenue, NOI, adjusted EBITDA, debt repayment, liquidity, shareholder returns and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was approved by management as of the date of this press release and was included for the purpose of providing further information about PetroTal's anticipated future business operations. PetroTal disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein. All FOFI contained in this press release complies with the requirements of Canadian securities legislation, including National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities. Changes in forecast commodity prices, differences in the timing of capital expenditures, and variances in average production estimates can have a significant impact on the key performance measures included in PetroTal's guidance. The Company's actual results may differ materially from these estimates.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/115020


PetroTal Announces a 2022 Capital Budget of US $120 million

Targeting a 100% growth rate in average oil production to between 17,500 and 19,500 bopd
Free cash flow pre debt service of $230 million

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - February 22, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce a fully funded 2022 capital program of $120 million that is expected to generate material free cash flow, allowing for an expected resumption of a dividend to shareholders by Q4 2022. All amounts are quoted in US dollars.

2022 Key Highlights

  • Invest $75 million in drilling and completing four horizontal development wells in 2022. Inclusive of well 10H, which commenced production on January 31, 2022, a total of five new wells will commence production in 2022;
  • Target a 2022 average production range between 17,500 bopd and 19,500 barrels of oil per day ("bopd") with an estimated exit December 2022 production rate of approximately 21,500 bopd;
  • Generate an adjusted EBITDA1 range of $340 to $365 million, assuming a 2022 average Brent price of $88/bbl and a $37 million net derivative true-up payment from oil arriving and being commercialized at Bayovar through the Northern Peruvian Pipeline ("ONP");
  • Execute a facilities and infrastructure expansion program of approximately $43 million which includes a new diluent tank, additional separators, a power plant expansion, additional injection facilities and key process optimization projects;
  • Generate free cash flow (before debt service)1 of between $220 and $245 million in 2022;
  • Repay $20 million of the 2021 $100 million bond issue in H1 2022;
  • Redeem the balance of the bonds in Q3 2022, should cash and working capital levels permit;
  • Assuming the entire bond is retired, PetroTal intends to reinstate a stable and rewarding return of capital program as early as Q4 2022; and,
  • Allocate approximately $15 million in community social trust payments and direct community investment projects in 2022.

(1) See "Non-GAAP Financial Measures"

Drilling and Completion Budget

PetroTal will invest approximately $75 million to drill four separate producing development wells in 2022, and complete well 10H which commenced drilling in late 2021 and started production on January 31, 2022. The four new drills in the remainder of 2022 are 11H, 12H, and 13H in the south eastern part of the field and 14H in the north west. These proved undeveloped wells were strategically selected to maximize production

increases, and to continue the extension of the reservoir boundaries. Rig maintenance programs are budgeted to ensure a safe and stable drilling campaign.

Facilities Budget

In 2022, PetroTal will focus on developing necessary infrastructure needed to support continued growth. Approximately $25 million is allocated for a new diluent tank, a three-phase separator unit including engineering and mechanical works, central processing facilities ("CPF-3") planning and construction costs, which will commence in April 2022 and enhance the water injection system with new water injection pumps. This will enable the Company to manage diluent levels to avoid frequent diluent shipments and allow the field to process nearly 200,000 barrels of fluid when completed, which is expected to be by mid 2023.

Over 20 key field infrastructure projects have been identified, totaling $18 million, which will be allocated for optimization, process/production improvement, power expansion, maintenance, and security projects. These projects will be completed in priority of near-term need and are subject to changes given the material and logistical challenges caused by the COVID-19 pandemic.

Block 107 Budget

A total of $2 million is budgeted in 2022 for Block 107 permits. PetroTal expects approval of the Constitucion and Kametza (Osheki) permits in 1H 2022 and 1H 2023, respectively. With these permit approvals, PetroTal will continue to evaluate the Company's deep portfolio of exploration assets for ways to maximize shareholder value.

Community Investment Budget

PetroTal will substantially increase its allocations to community investment in 2022. An estimated $6 million will be dedicated towards the following key project areas:

  • Direct social investments in programs, training and education - $0.8 million
  • Diesel for electricity generation in Puinahua and other areas - $1.3 million
  • Community river erosion control - $1.2 million
  • Social space construction projects - $0.3 million
  • Environmental innovation - $0.4 million
  • Community relations projects - $1.9 million

In addition, the Company expects to generate material net revenue in 2022 and will contribute, on a fortnight basis, an estimated 2022 total of $9 million into community social trust payments assuming no disruptions to PetroTal's ability to produce or sell oil through the ONP, Brazil, Iquitos, or other sales routes planned in the future. PetroTal believes this will create a long-standing alignment between the government, communities, and the Company.

Production Guidance

The Company generates various sensitivities for possible production downtime attributable to social and technical issues. Considering the implementation of the social trust, the Company's current assessment of likely downtime, mostly due to social unrest, and the planned $120 million capital expenditure program, PetroTal's 2022 oil production is expected to range between 17,500 bopd and 19,500 bopd. At the mid point of the range, PetroTal would produce about 6.6 million barrels of oil in 2022, representing a 100% production growth rate over 2021. In addition, the Company expects to exit 2022 with production at approximately 21,500 bopd and with production materially surpassing the 20,000 bopd mark at certain flush production points during the year.

OPEX Guidance

OPEX run rates have increased over 2020 and 2021 levels due to increased activity, inflation pressures, and the Company's continued commitment to manage COVID-19, safety and security. Summarized below are the estimated cost run rates expected in 2022:

Fixed and semi-variable lifting costs that scale with production - estimated at $2.8 million per month including:

  • Fuel
  • Well and various contract services

Variable transportation costs - $7.2/bbl or ($45 - $50 million for 2022)

  • Gross diluent cost and diluent transportation - $4.2/bbl ($1.4/bbl net with diluent sales)
  • Barging - $1.7/bbl
  • Barging standby, diesel, and supervision - $1.3/bbl

The variable costs outlined above assume that PetroTal is able to sell oil consistently. Interruptions to the ability to sell production may create material volatility to the above per barrel run rates if the Company produces into storage for an extended period of time. Currently, PetroTal uses a 4% diluent blend into the oil mix to facilitate productivity, representing a gross cost of $4.2/bbl. As oilfield dynamics change from increased oil production, the Company expects to reduce its diluent blend. Lastly, tariffs, ONP fees, and differentials that are variable in nature are netted with revenue for financial statement and planning purposes.

Cash Flow Guidance

Assuming an $88/bbl average 2022 Brent price, the current run rate cost structure, and sales agreements for oil exports, PetroTal expects to generate $325 to $350 million of net operating income ("NOI") and between $340 and $365 million of EBITDA1 inclusive of $37 million of derivative true-up settlements. The resulting free cash flow (prior to debt service)1 is expected to be between $220 - $245 million, thereby allowing the Company to facilitate full payout of the bonds in Q3 2022 and implement shareholder returns2 by Q4 2022, along with maintaining a healthy cash balance.

(1) See "Non-GAAP Financial Measures"
(2) The bonds restrict any shareholder returns until fully paid out

Quarterly Production and Capital Profile (Mid Case)

Q1 Q2 Q3 Q4
Oil wells completed 1 (10H) 1 (11H) 2 (12H & 13H) 1 (14H)
Production (bopd) 16,300 15,000 20,500 21,000
CAPEX (millions) $35 $35 $37 $13

 

PetroTal 2022 Budget Summary ($ millions, unless otherwise stated)

Budget Range (Low - High Case)
Brent Price $/bbl (Feb 7, 2022 strip forecast) $88.0
Production bopd 17,500 - 19,500
NOI $325 - $350
G&A $22
Derivative settlements (Feb 7, 2022 strip forecast) $37
EBITDA $340 - $365
CAPEX $120
Free cash flow1 $220 - $245

 

1) See "Non-GAAP Financial Measures"

Reimplementation of a Return of Capital policy

PetroTal anticipates material free cash flow generation in 2022. Based on $88/bbl Brent, free cash flow1 is expected to range from $220 to $245 million prior to debt service, taxes, lease payments, hedge costs, factoring, and VAT. In H1 2022, PetroTal intends to repay $20 million of the 2021 $100 million bond issue and $30 million in interest, factoring, lease payments and VAT.

(1) See "Non-GAAP Financial Measures"

In Q3 2022, the Company expects to be in a position to retire the remaining $80 million in bonds with a 6% call premium of $5 million. Interest saved for the remainder of the year will materially offset this prepayment charge thereby allowing PetroTal to implement a return of capital policy by Q4 2022. When the bonds are fully repaid, the Company intends to reinstate a quarterly dividend (as was done in Q4 2019).

The Company notes that the above intention to reinstate a return of capital policy is dependent on a number of interplaying factors materializing as expected.

Hedging Update

During January and February 2022, the Company hedged approximately 1,100,000 barrels using a combination of puts with an $85/bbl strike and collars with a range of $63/bbl to $70/bbl allowing PetroTal to share in any continued commodity price increases.

In total, PetroTal has approximately 2.2 million barrels hedged, representing approximately 33% of the 2022 mid case production guidance, and in line with the Company's hedging strategy.

2022 EBITDA Sensitivities for Production Ranges ($ millions)

Production (bopd)
Brent Price $/bbl EBITDA Matrix 17,500 18,500 19,500 2022 derivative settlement
   
$100 357 376 395 +63
$95 332 350 367 +52
$90 306 323 340 +41
$85 281 297 312 +30
$80 256 270 284 +19
$75 233 246 259 +8
$70 207 218 230 -3
$65 182 193 203 -14

 

Assuming 2022 average production of 18,250 bopd, PetroTal will be in a position to fully cash fund its 2022 CAPEX program and all debt service, VAT, and lease obligations down to $60/bbl Brent while maintaining a liquidity buffer of approximately $25 million throughout 2022.

Updated Corporate Presentation

Please see PetroTal's website for an updated version of its corporate presentation.

2022 Guidance and Reserves Webcast

On February 22, 2022, please join the Company for a summary of 2022 guidance and 2021 year end reserves by clicking on the link below:

UK - 3:00pm, Calgary - 8:00am, Houston - 9:00am, Lima - 10:00am

https://webcasting.brrmedia.co.uk/broadcast/61f90806d0a01d0d75c3c4e0

Manuel Pablo Zuniga-Pflucker, President and Chief Executive Officer, commented

"We are excited to communicate our 2022 development plans to the market. 2022 will be a year of achievement and rewarding shareholders who continue to believe in our story and management team. It is vital that we continue drilling wells and executing our 2P development plans by drilling proved-undeveloped locations that should allow future booked location upgrades, prevent base declines, and optimize water handling peaks based on our current infrastructure. We will continue to deliver investment grade well results and manage our balance sheet prudently, as we have over the past four years our team has been together."

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2022, Petrotal became the largest crude oil producer in Peru. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

READER ADVISORIES

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus, including executing 2P development plans to prevent base declines and optimize water handling peaks; the impact of social disruption on the Company's operations; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; PetroTal's 2022 budget and financial/operational guidance; PetroTal's anticipated operational results for 2022 including, but not limited to, estimated or anticipated production levels, capital expenditures and drilling plans; the intention to redeem the outstanding bonds; PetroTal plans to deliver strong operational performance and to generate free cash flow and growth; capital requirements; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production and revenue; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including average and exit production in 2022; sales expansion through alternative exports routes, including barging and trucking; the Company's proposals for collaboration with local communities; and future development and growth prospects. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. Without limitation of the foregoing, future dividend payments, if any, and the level thereof, is uncertain, as the Company's dividend policy and the funds available for the payment of dividends from time to time is dependent upon, among other things, free cash flow financial requirements for the Company's operations and the execution of its growth strategy, fluctuations in working capital and the timing and amount of capital expenditures, debt service requirements and other factors beyond the Company's control. Further, the ability of PetroTal to pay dividends will be subject to applicable laws (including the satisfaction of the solvency test contained in applicable corporate legislation) and contractual restrictions contained in the instruments governing its indebtedness. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, legal, political and economic instability in Peru, access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, increased operating and capital costs due to inflationary pressures, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the Company's annual information form for the year ended December 31, 2020 and management's discussion and analysis for the three and nine months ended September 30, 2021 which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

OIL REFERENCES: All references to "oil" or "crude oil" production, revenue or sales in this press release mean "heavy crude oil" as defined in NI 51-101. All references to Brent indicate Intercontinental Exchange ("ICE") Brent.

NON-GAAP FINANCIAL MEASURES: This press release contains financial terms that are not considered measures under generally accepted accounting principles ("GAAP") such as EBITDA and free cash flow that do not have any standardized meaning under GAAP and may not be comparable to similar measures presented by other companies. Management uses these non-GAAP measures for its own performance measurement and to provide shareholders and investors with additional measurements of the Company's efficiency and its ability to fund a portion of its future capital expenditures. EBITDA is calculated as consolidated net income (loss) before interest and financing expenses, income taxes, depletion, depreciation and amortization and adjusted for G&A impacts and certain non-cash, extraordinary and non-recurring items primarily relating to unrealized gains and losses on financial instruments and impairment losses, including derivative true-up settlements. PetroTal utilizes EBITDA as a measure of operational performance and cash flow generating capability. EBITDA impacts the level and extent of funding for capital projects investments. Free cash flow is calculated as cash flow from operating activities less exploration and development capital expenditures and is calculated prior to all debt service, taxes, lease payments, hedge costs, factoring, and lease payments. Management uses free cash flow to determine the amount of funds available to the Company for future capital allocation decisions.

FOFI DISCLOSURE: This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about PetroTal's budget and guidance, prospective results of operations, production and production capacity, free cash flow, revenue, NOI, adjusted EBITDA, debt repayment, liquidity, shareholder returns and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was approved by management as of the date of this press release and was included for the purpose of providing further information about PetroTal's anticipated future business operations. PetroTal disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein. All FOFI contained in this press release complies with the requirements of Canadian securities legislation, including National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities. Changes in forecast commodity prices, differences in the timing of capital expenditures, and variances in average production estimates can have a significant impact on the key performance measures included in PetroTal's guidance. The Company's actual results may differ materially from these estimates.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/114399


PetroTal Announces Significant Increases in 2021 Year-End Oil Reserves

68% increase in 1P Reserves to 37 million barrels

53% increase in 2P Reserves to 78 million barrels

39% increase in 3P Reserves to 147 million barrels

Calgary, Alberta and Houston, Texas--(Newsfile Corp. - February 15, 2022) - PetroTal Corp. (TSXV: TAL) (AIM: PTAL) (OTCQX: PTALF) ("PetroTal" or the "Company") is pleased to announce the results of its 2021 year-end reserve evaluation by Netherland, Sewell & Associates, Inc. ("NSAI") for the Bretana oil field, operated 100% by PetroTal (the "NSAI Report"). All currency amounts are in United States dollars (unless otherwise stated) and comparisons refer to December 31, 2020.

Highlights:

  • Significant increases in all reserve categories:
    • Proved ("1P") reserves increasing by 68% to 37.4 million barrels. Net Present Value (before tax, discounted at 10% ("NPV-10")) is $724 million ($19.38/bbl) for 1P reserves;
    • Proved plus Probable ("2P") reserves increasing by 53% to 78 million barrels. Net Present Value (before tax, discounted at 10% ("NPV-10") is $1.39 billion ($17.82/bbl) for 2P reserves; and,
    • Proved plus Probable plus Possible ("3P") reserves increasing by 39% to 147 million barrels.
  • NPV-10 values have increased 129% for 1P and 67% for 2P, over year-end 2020, due to reserves growth and an increase in the Brent price forecast used by NSAI at year-end 2021;
  • Material progression of after tax NPV-10 per share to US$0.69/share, US$1.23/share, and US$2.00/share for 1P, 2P, and 3P categories;
  • 2021 Proved Developed Producing ("PDP") reserves increased 35% to 16.15 million barrels, representing 43% of 1P reserves, reflecting an attractive ratio of base production to low risk drilling targets;
  • Three key reserves parameters had material positive upgrades in the NSAI Report, compared to the prior year:
    • Original Oil in Place ("OOIP"): Increases of 5%, 7%, and 7% to 247, 389, and 618 million barrels, respectively, for the 1P, 2P and 3P cases;
    • Due to continued drilling success and additional subsurface data, 1P, 2P and 3P total booked well counts for 2021 are 17, 22, and 29, respectively, up materially from the 2020 well counts of 11, 15, and 20; and,
    • With additional subsurface similarities to Bretana's analogous fields now recognized, all three recovery factor percentages materially increased in 2021 to 18% (from 11%), 22% (from 15%), and 25% (from 19%) for 1P, 2P, and 3P reserve categories, respectively.
  • 2P Future Development Capital ("FDC") increased $96 million or 49% to $289 million from 2020 reflecting an additional 7 wells booked at year-end 2021 and the required associated water disposal capacity needed to accommodate higher anticipated flush and run rate production volumes;
  • 2021 Finding and Development ("F&D") cost per barrel of $6.63, $4.68 and $3.85 for 1P, 2P, and 3P reserve categories, respectively. The 1P and 2P per barrel costs were reduced 42%, and 6% from year-end 2020;
  • Attractive year-end 2021 reserves-based metrics:
    • Doubling 2021 Reserve Life Index ("RLI") for 1P and 2P reserves, to 13.8 and 28.9 years, respectively, compared to 6.4 and 14.6 years in 2020; and,
    • Robust 2021 production reserve replacement ratios of 457% and 816% for 1P and 2P reserves.
  • On a 2P per barrel basis, the NSAI Report reflected a 3.5% decrease in operating costs per barrel, which, given the inflationary pressures from higher Brent oil prices and the COVID-19 pandemic, is an important success story for PetroTal; and,
  • On a 3P basis, the 2021 NSAI production forecast shows a 16-year plateau above 10,000 barrels of oil per day ("bopd) instead of the prior 12-year plateau in NSAI's 2020 reserves report.

Manuel Pablo Zuniga-Pflucker, President and Chief Executive Officer, commented

"The Bretana field is proving itself to be a prolific investment given the significant achievements in 2021 and the 2021 year-end reserves report results. Based on the increased recovery factors and additional booked drilling locations, we have significantly extended the running room and future development potential of our asset. This should allow Bretana to generate free cash flow for a much longer period of time."

2021 Year-end Reserves Summary

The summary below sets forth PetroTal's reserves as at December 31, 2021, as presented in the reserves report prepared by NSAI, an independent qualified reserves evaluator. The figures in the following tables have been prepared in accordance with the standards contained in the most recent publication of the Canadian Oil and Gas Evaluation Handbook (the "COGEH") and the reserve definitions contained in National Instrument 51-101 - Standards of Disclosure for Oil and Gas Activities ("NI 51-101"). In addition to the summary information disclosed in this announcement, more detailed information will be included in PetroTal's annual information form for the year ended December 31, 2021 (the "AIF") to be filed on SEDAR (www.sedar.com) and posted on PetroTal's website (www.petrotal-corp.com) in April 2022.

Six Year Crude Oil Price Forecast - NSAI Report

Year-End Forecast: 2022 2023 2024 2025 2026 2027 6 Yr Avg
Brent (USD$/bbl) - January 1, 2021 $52.85 $56.04 $57.87 $59.00 $60.15 $61.33 $57.87
Brent (USD$/bbl) - January 1, 2022 $75.33 $71.46 $69.62 $71.01 $72.44 $73.88 $72.31

 

The oil price projections used by NSAI are based upon an average of December 31, 2021 and 2020 forecasts of Brent Crude futures prices prepared by three qualified reserves evaluators: GLJ Petroleum Consultants Ltd., McDaniel & Associates Consultants Ltd. and Sproule Associates Limited. The six year average for the NSAI Report reflects an average Brent price of $72.31, which as at the time of this press release, is approximately $24/bbl lower than current market Brent prices.

Year-End Crude Oil Reserves (million barrels)

CATEGORY 2021 2020 Change
Proved
Developed Producing 16.2 12.0 +35%
Undeveloped 21.2 10.3 +106%
Total Proved 37.4 22.3 +68%
Probable 40.5 28.7 +41%
Total Proved plus Probable 77.9 51.0 +53%
Possible 69.1 55.1 +25%
Total Proved plus Probable & Possible 147.1 106.1 +39%

 

Represents gross and net barrels since PetroTal has a 100% working interest and a 100% net revenue interest in these properties. Royalties are paid from sales proceeds.

Year-End Net Present Value at 10% - Before Tax ($ millions)

CATEGORY 2021 2020 Change
Proved
Developed Producing $250 $135 +85%
Undeveloped $474 $182 +160%
Total Proved $724 $317 +129%
Probable $665 $513 +30%
Total Proved plus Probable $1,389 $830 +67%
Possible $932 $891 +5%
Total Proved plus Probable & Possible $2,321 $1,721 +35%

 

Year-End Net Present Value at 10% - After Tax ($ millions)

CATEGORY 2021 2020 Change
Proved
Developed Producing $244 $134 +82%
Undeveloped $326 $137 +138%
Total Proved $570 $271 +110%
Probable $449 $350 +28%
Total Proved plus Probable $1,020 $621 +64%
Possible $633 $607 +4%
Total Proved plus Probable & Possible $1,653 $1,228 +35%

 

Forecast Revenues and Costs(1-5) ($ millions)

Undiscounted Discounted Discounted
CATEGORY Revenue Royalties OPEX FDC B-Tax Net
Revenue
B-Tax Net
Revenue
A-Tax Net
Revenue
Total Proved $2,299 $160 $921 $141 $1,076 $724 $570
Total Proved plus Probable $4,865 $367 $1,488 $289 $2,722 $1,389 $1,020
Total Proved plus Probable & Possible $9,735 $813 $2,756 $504 $5,662 $2,321 $1,653

 

1) Royalties include the 2.5% social fund for all years.
2) FDC includes abandonment.
3) Net Revenue is defined as revenue less royalties less operating costs less FDC.
4) B-tax and A-tax refer to before and after tax.
5) Discounted values are discounted at 10%.

Year-End Reserves Value per Share - After tax

CATEGORY Dec. 31, 2021 Dec. 31, 2020
Reserves per share US$/sh CAD$/sh GBP/sh US$/sh CAD$/sh GBP/sh
Proved $0.69 $0.88 0.51 $0.33 $0.43 0.24
Proved plus Probable $1.23 $1.57 0.91 $0.76 $0.98 0.56
Proved plus Probable & Possible $2.00 $2.54 1.48 $1.50 $1.93 1.10

 

Represents NPV-10 (after tax) divided by the number of common shares issued as of December 31 of each respective year and excludes other balance sheet items at the relevant date. Canadian and GBP share prices are converted at the respective year end foreign exchange conversion rates. Common share count as at December 31, 2021 totaling 828.2 million shares and as at December 31, 2020 totaling 816.2 million shares.

Reserve Life Index(1-3) ("RLI")

CATEGORY Dec. 31, 2021 Dec. 31, 2020
Proved 13.8 years 6.4 years
Proved plus Probable 28.9 years 14.6 years
Proved plus Probable & Possible 54.5 years 30.3 years

 

(1) 2021 values based on 2021 year-end reserves divided by annualized Q1 2021 production of approximately 7,331 bopd.
(2) The license for Block 95 expires in 2041.
(3) 2020 values based on 2020 year-end reserves divided by annualized Q1 2020 production of approximately 9,686 bopd.

Future Development Costs

The following information sets forth development and abandonment costs deducted in the estimation of PetroTal's future net revenue attributable to the reserve categories noted below:

CATEGORY ($ million) 2021 2020 Change
Proved
Developed Producing $16 $15 +6%
Undeveloped $125 $104 +20%
Total Proved $141 $119 +19%
Probable $148 $75 +98%
Total Proved plus Probable $289 $193 +49%
Possible $215 $104 +108%
Total Proved plus Probable & Possible $504 $297 +70%

 

Future development costs ($/bbl) 2021 2020 Change
Proved $6.63 $11.52 -42%
Proved plus Probable $4.68 $4.96 -6%
Proved plus Probable & Possible $3.85 $3.16 +22%

 

The future development and abandonment costs are estimates of the future capital expenditures required to convert the corresponding reserves to proved developed producing ("PDP") reserves. Future development per barrel is determined using the future development capital divided by the 1P, 2P, or 3P reserves, less cumulative PDP.

2021 Year-End Gross Reserves Reconciliation (million barrels)

Proved Proved plus Probable Proved plus Probable & Possible
December 31, 2020 22.3 51.0 106.1
Technical Revisions 18.2 30.2 44.2
Economic Factors 0.2 0.0 0.0
Production (3.3) (3.3) (3.3)
December 31, 2021 37.4 77.9 147.0

 

Qualified Person's Statement

Dewi Jones, the Company's Vice President, Exploration and Development, who has over 35 years of relevant experience in the oil industry, has approved the technical information contained in this announcement. Mr. Jones received a Bachelor of Science degree in Geology from Louisiana State University in Baton Rouge and is registered on the Texas and Louisiana Board of Professional Geoscientists.

The recovery and reserve estimates provided in this news release are estimates only, and there is no guarantee that the estimated reserves will be recovered. Actual reserves may eventually prove to be greater than, or less than, the estimates provided herein. In certain of the tables set forth below, the columns may not add due to rounding.

ABOUT PETROTAL

PetroTal is a publicly traded, tri‐quoted (TSXV: TAL) (AIM: PTAL) and (OTCQX: PTALF) oil and gas development and production Company domiciled in Calgary, Alberta, focused on the development of oil assets in Peru. PetroTal's flagship asset is its 100% working interest in Bretana oil field in Peru's Block 95 where oil production was initiated in June 2018. In early 2020, PetroTal became the second largest crude oil producer in Peru and more recently the top crude oil producer. The Company's management team has significant experience in developing and exploring for oil in Peru and is led by a Board of Directors that is focused on safely and cost effectively developing the Bretana oil field. It is actively building new initiatives to champion community sensitive energy production, benefiting all stakeholders.

For further information, please see the Company's website at www.petrotal-corp.com, the Company's filed documents at www.sedar.com, or below:

Douglas Urch
Executive Vice President and Chief Financial Officer
Durch@PetroTal-Corp.com
T: (713) 609-9101

Manolo Zuniga
President and Chief Executive Officer
Mzuniga@PetroTal-Corp.com
T: (713) 609-9101

PetroTal Investor Relations
InvestorRelations@PetroTal-Corp.com

Celicourt Communications
Mark Antelme / Jimmy Lea
petrotal@celicourt.uk
T : 44 (0) 208 434 2643

Strand Hanson Limited (Nominated & Financial Adviser)
Ritchie Balmer / James Spinney / Robert Collins
T: 44 (0) 207 409 3494

Stifel Nicolaus Europe Limited (Joint Broker)
Callum Stewart / Simon Mensley / Ashton Clanfield
Tel: +44 (0) 20 7710 7600

Auctus Advisors LLP (Joint Broker)
Jonathan Wright
T: +44 (0) 7711 627449

READER ADVISORIES

FORWARD-LOOKING STATEMENTS: This press release contains certain statements that may be deemed to be forward-looking statements. Such statements relate to possible future events, including, but not limited to: PetroTal's business strategy, objectives, strength and focus; drilling, completions, workovers and other activities and the anticipated costs and results of such activities; the ability of the Company to achieve drilling success consistent with management's expectations; the ability of the Company to achieve near term production targets and operate at unrestricted levels; anticipated future production, revenue and free cash flow; drilling plans including the timing of drilling, commissioning, and startup and the impact of delays thereon; oil production levels, including production 2022; future development and growth prospects; and the timing of filing the AIF. All statements other than statements of historical fact may be forward-looking statements. In addition, statements relating to expected production, reserves, recovery, costs and valuation are deemed to be forward-looking statements as they involve the implied assessment, based on certain estimates and assumptions that the reserves described can be profitably produced in the future. Forward-looking statements are often, but not always, identified by the use of words such as "anticipate", "believe", "expect", "plan", "estimate", "potential", "will", "should", "continue", "may", "objective" and similar expressions. The forward-looking statements are based on certain key expectations and assumptions made by the Company, including, but not limited to, expectations and assumptions concerning the ability of existing infrastructure to deliver production and the anticipated capital expenditures associated therewith, the ability of the Ministry of Energy to effectively achieve its objectives in respect of reducing social conflict and collaborating towards continued investment in the energy sector, reservoir characteristics, recovery factor, exploration upside, prevailing commodity prices and the actual prices received for PetroTal's products, including pursuant to hedging arrangements, the availability and performance of drilling rigs, facilities, pipelines, other oilfield services and skilled labour, royalty regimes and exchange rates, impact of inflation on costs, the application of regulatory and licensing requirements, the accuracy of PetroTal's geological interpretation of its drilling and land opportunities, current legislation, receipt of required regulatory approval, the success of future drilling and development activities, the performance of new wells, the Company's growth strategy, general economic conditions and availability of required equipment and services. Although the Company believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because the Company can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses; and health, safety and environmental risks), commodity price volatility, price differentials and the actual prices received for products, exchange rate fluctuations, increased operating and capital costs due to inflationary pressures, legal, political and economic instability in Peru, access to transportation routes and markets for the Company's production, changes in legislation affecting the oil and gas industry and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. In addition, the Company cautions that current global uncertainty with respect to the spread of the COVID-19 virus and its effect on the broader global economy may have a significant negative effect on the Company. While the precise impact of the COVID-19 virus on the Company remains unknown, rapid spread of the COVID-19 virus may continue to have a material adverse effect on global economic activity, and may continue to result in volatility and disruption to global supply chains, operations, mobility of people and the financial markets, which could affect interest rates, credit ratings, credit risk, inflation, business, financial conditions, results of operations and other factors relevant to the Company. Please refer to the risk factors identified in the Company's annual information form for the year ended December 31, 2020 and management's discussion and analysis for the three and nine months ended September 30, 2021 which are available on SEDAR at www.sedar.com. The forward-looking statements contained in this press 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 so required by applicable securities laws.

OIL REFERENCES: All references to "oil" or "crude oil" production, revenue or sales in this press release mean "heavy crude oil" as defined in NI 51-101. All references to Brent indicate Intercontinental Exchange ("ICE") Brent.

RESERVES DISCLOSURE: PetroTal's Statement of Reserves Data and Other Oil and Gas Information on Form 51-101F1 dated effective as at December 31, 2021, which will include further disclosure of PetroTal's oil and gas reserves and other oil and gas information in accordance with NI 51-101 and COGEH forming the basis of this press release, will be included in the AIF, which will be available on SEDAR at www.sedar.com in April 2022. All reserves values, future net revenue and ancillary information contained in this press release are derived from the NSAI Report unless otherwise noted. Estimates of reserves and future net revenue for individual properties may not reflect the same level of confidence as estimates of reserves and future net revenue for all properties, due to the effect of aggregation. There is no assurance that the forecast price and cost assumptions applied by NSAI in evaluating PetroTal's reserves will be attained and variances could be material. It should not be assumed that the estimates of future net revenues presented in the tables below represent the fair market value of the reserves. The recovery and reserve estimates of PetroTal's oil reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual oil reserves may be greater than or less than the estimates provided herein. There are numerous uncertainties inherent in estimating quantities of crude oil, reserves and the future cash flows attributed to such reserves. The reserve and associated cash flow information set forth herein are estimates only. Proved reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved reserves. Probable reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the sum of the estimated proved plus probable reserves. Proved developed producing reserves are those reserves that are expected to be recovered from completion intervals open at the time of the estimate. These reserves may be currently producing or, if shut-in, they must have previously been on production, and the date of resumption of production must be known with reasonable certainty. Possible reserves are those reserves expected to be recovered from known accumulations where a significant expenditure (e.g., when compared to the cost of drilling a well) is required to render them capable of production. They must fully meet the requirements of the reserves category (proved, probable, possible) to which they are assigned. Certain terms used in this press release but not defined are defined in NI 51-101, CSA Staff Notice 51-324 - Revised Glossary to NI 51-101, Revised Glossary to NI 51-101, Standards of Disclosure for Oil and Gas Activities ("CSA Staff Notice 51-324") and/or the COGEH and, unless the context otherwise requires, shall have the same meanings herein as in NI 51-101, CSA Staff Notice 51-324 and the COGEH, as the case may be.

DRILLING LOCATIONS: This press release discloses drilling inventory in three categories: (a) proved locations; (b) probable locations; and (c) possible locations, all of which are derived from the NSAI Report and account for drilling locations that have associated proved, probable and/or possible reserves, as applicable. There is no certainty that PetroTal will drill all booked drilling locations and if drilled there is no certainty that such locations will result in additional oil reserves or production. The drilling locations considered for future development will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil prices, costs, actual drilling results, additional reservoir information that is obtained and other factors. While certain of the possible drilling locations have been de-risked by drilling existing wells in relative close proximity to such drilling locations, other possible drilling locations are farther away from existing wells where management has less information about the characteristics of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil reserves or production.

OIL AND GAS MEASURES: This press release contains metrics commonly used in the oil and natural gas industry which have been prepared by management, such as "netback", "OOIP", "development capital", "F&D costs", "net asset value", "recycle ratio" and "reserves life index". These terms do not have a standardized meaning and may not be comparable to similar measures presented by other companies, and therefore should not be used to make such comparisons. "Netback" equals total petroleum sales less quality discount, lifting costs, transportation costs and royalty payments calculated on a bbl basis. "OOIP" is equivalent to total petroleum initially-in-place ("TPIIP"). TPIIP, as defined in the COGEH, is that quantity of petroleum that is estimated to exist in naturally occurring accumulations. It includes that quantity of petroleum that is estimated, as of a given date, to be contained in known accumulations, prior to production, plus those estimated quantities in accumulations yet to be discovered. A portion of the TPIIP is considered undiscovered and there is no certainty that any portion of such undiscovered resources will be discovered. If discovered, there is no certainty that it will be commercially viable to produce any portion of such undiscovered resources. With respect to the portion of the TPIIP that is considered discovered resources, there is no certainty that it will be commercially viable to produce any portion of such discovered resources. A significant portion of the estimated volumes of TPIIP will never be recovered. "Development capital" means the aggregate exploration and development costs incurred in the financial year on reserves that are categorized as development. Development capital excludes capitalized administration costs. "Finding and development costs" or "F&D costs" are calculated as the sum of field capital plus the change in future development costs for the period divided by the change in reserves that are characterized as development for the period. Finding and development costs take into account reserves revisions during the year on a per bbl basis. The aggregate of the exploration and development costs incurred in the financial year and changes during that year in estimated future development costs generally will not reflect total finding and development costs related to reserves additions for that year. "Net asset value" is based on present value of future net revenues discounted at 10% before tax on reserves, net of estimated net debt at year end divided by the basic shares outstanding at year end. "Recycle ratio" is measured by dividing the netback for the applicable period by finding and development cost per bbl for the year. The recycle ratio compares netback from existing reserves to the cost of finding new reserves and may not accurately indicate the investment success unless the replacement reserves are of equivalent quality as the produced reserves. "Reserve life index" is calculated as total Company interest reserves divided by annual production. These terms have been calculated by management and do not have a standardized meaning and may not be comparable to similar measures presented by other companies, and therefore should not be used to make such comparisons. Management uses these oil and gas metrics for its own performance measurements and to provide shareholders with measures to compare PetroTal's operations over time. Readers are cautioned that the information provided by these metrics, or that can be derived from the metrics presented in this press release, should not be relied upon for investment or other purposes.

FOFI DISCLOSURE: This press release contains future-oriented financial information and financial outlook information (collectively, "FOFI") about PetroTal's prospective results of operations, production, NPV-10, future net revenue, future development and abandonment costs, and components thereof, all of which are subject to the same assumptions, risk factors, limitations and qualifications as set forth in the above paragraphs. FOFI contained in this press release was approved by management as of the date of this press release and was included for the purpose of providing further information about PetroTal's anticipated future business operations. PetroTal disclaims any intention or obligation to update or revise any FOFI contained in this press release, whether as a result of new information, future events or otherwise, unless required pursuant to applicable law. Readers are cautioned that the FOFI contained in this press release should not be used for purposes other than for which it is disclosed herein. All FOFI contained in this press release complies with the requirements of Canadian securities legislation, including NI 51-101.

Neither the TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this press release.

To view the source version of this press release, please visit https://www.newsfilecorp.com/release/113790