Transformative Gulf of Thailand Acquisition
CALGARY, AB / ACCESSWIRE / December 6, 2022 / Valeura Energy Inc. (TSX:VLE) (“Valeura” or the “Company”) is pleased to announce that Valeura Energy Asia Pte. Ltd. (the “SPV”), a special purpose vehicle and a subsidiary of the Company, has entered into a Sale and Purchase Agreement with Mubadala Petroleum (Thailand) Holdings Limited (the “Seller”) to acquire the Thailand upstream oil producing portfolio of Busrakham Oil and Gas Ltd (“Busrakham”), a subsidiary of Mubadala Energy (the “Acquisition”).
This Acquisition consists of operated interests in three offshore licences in the Gulf of Thailand that include the Nong Yao, Jasmine/Ban Yen and Manora oil fields, which collectively currently produce approximately 21,200 bbls/d of oil, net to the interest being acquired. The purchase consideration for the Acquisition is US$10.4 million plus up to an additional US$50 million, contingent upon certain upside price scenarios. The acquisition has an effective date of August 31, 2022 (“Effective Date”) and is subject to customary closing conditions.
Acquisition Highlights
- A substantial expansion of Valeura’s presence in Thailand, adding a portfolio of cash generative assets;
- Operatorship of three additional offshore licences in the Gulf of Thailand;
- Current production add of 21,200 bbls/d of oil, net to the acquired interests;
- Weighted average cash operating costs across the assets of approximately US$22/bbl, comprised primarily of fixed costs associated with offshore facilities;
- Immediate pre-tax cash flows of approximately US$30 million per month1;
- Total proved plus probable (2P) reserves of approximately 24.1 mmbbls oil2;
- Deal consideration of US$10.4 million as of the Effective Date plus up to an additional US$50 million, contingent upon certain upside price scenarios;
- Value accretive transaction, with no requirement for additional equity to complete the Acquisition, and hence no dilution to shareholders;
- Near-term production growth opportunity through Nong Yao field development project planned to be onstream in early 2024;
- Field life extension opportunities through ongoing infill drilling to continue the assets’ long history of reserves additions, amounting to approximately 80% replacement of produced reserves over the past five years;
- A largely autonomous business unit organisation comprised of an approximately 180-person strong operating workforce in Thailand; and
- Expected organisational and financial synergies with Valeura’s acquisition of the KrisEnergy Gulf of Thailand assets as announced in Q2 2022.
Unless otherwise noted, all production and reserves estimates in this announcement are presented on a working interest acquired basis, net to the SPV, which is controlled and 85% owned by Valeura.
1 Management estimate, based on current operating conditions and US$85/bbl Brent oil.
2 Reserves estimates are based on the Company’s internal assessment (non-independent) as of December 31, 2021.
Sean Guest, President and CEO of Valeura commented:
“This is a transformative transaction for Valeura, firmly establishing our Company as the largest independent operator of oil production in Thailand. By adding 21,200 bbls/d net to the SPV, we expect to immediately generate pre-tax cash flows of approximately $30 million per month, and this amount is expected to grow in the very near term as we increase production to 25,000 bbls/d and beyond with the addition of production from our pre-existing portfolio. We set out to build a business that generates cash now, while providing re-investment opportunities for the medium-term, and we believe that the two acquisitions we have signed in 2022 accomplish these goals and more, creating significant value for our shareholders without dilution.
Our forward efforts will focus on developing the potential of these assets, by projects including further development of the Nong Yao field where we are forecasting peak production rates in 2024, re-investment into the Jasmine and Ban Yen fields to continue their long history of reserves replacement, and on selective step-out opportunities where we see the potential to more fully utilise the fields’ extensive infrastructure to commercialise new accumulations. As of the end of 2021, the assets held 24.1 million bbls of estimated 2P oil reserves, representing approximately a four-fold increase over our pre-existing corporate reserves.
Moreover, we see the new assets and the workforce as an excellent fit with our highest priorities. In particular, the team’s demonstrated history in safe operations with a strong environmental performance is well aligned with our sustainability goals and we are delighted to welcome the approximately 180 like-minded individuals to the Valeura team. Just as we’ve routinely done with producing assets under our care, we intend to pursue opportunities to extend the value and economic life of these fields, whilst remaining mindful of our longer-term responsibility to ensure their eventual decommissioning is planned and appropriately funded. This line of thinking has been incorporated into all aspects of our commercial evaluation of this transaction.
We look forward to starting this exciting chapter in our Company’s history, further expanding into a region of the world we know well and charging into 2023 as a transformed company with substantial cash generation capacity and a clear path to further grow our potential value.”
Acquisition
The Acquisition is structured as a corporate acquisition whereby the SPV will purchase all of the shares of Busrakham, a company established in 2021 to hold the Thailand assets being sold by the Seller, under the terms of a Sale and Purchase Agreement (“SPA”). Upon completion of the Acquisition, the SPV will become the operator and the owner of working interests in the three offshore licences being acquired, as well as all related production infrastructure and onshore support facilities including supply bases, offices, and warehouses.
Under the SPA, the Acquisition has an initial headline purchase price of US$10.4 million and entails Valeura assuming the current work programme and future abandonment liabilities. The Acquisition is subject to customary closing conditions and will require the lodging of a Valeura parent company guarantee, in place of the Seller’s guarantee with the Thailand regulator. Valeura will pay the Seller a deposit of US$6 million and anticipates closing the Acquisition in Q1 2023. As of the Effective Date, Busrakham had approximately a nil working capital balance.
Further contingent consideration under the SPA will become due to the Seller under certain upside benchmark oil price scenarios in 2022, 2023, or 2024. Such contingent consideration is capped at a maximum of US$50 million.
Funding
Given Valeura’s cash position at the end of Q3 2022 of US$23.1 million, the modest headline consideration price, the impact of ongoing cash flows from the assets and the expected closing date, Valeura is able to fund the Acquisition without an equity raise. Accordingly, the Acquisition is expected to be non-dilutive to current shareholders of Valeura.
Upon closing of the Acquisition, a drawdown of up to US$50 million is advanceable to the SPV from Trafigura Pte. Ltd., which is in addition to the initial potential maximum capacity of discrete drawdowns of up to US$30 million, under the facility announced on November 11, 2022 (the “Facility”). Such additional drawdown is subject to the satisfaction of certain conditions precedent. While the assets acquired through the Acquisition are anticipated to be strongly cash generative, the Facility provides additional financial liquidity.
Human Capital
As part of the Acquisition, the Seller’s organisation in Thailand and support infrastructure including supply bases, warehouses and offices will join Valeura. This includes substantially all of the Seller’s Thailand-based staff, comprised of approximately 180 individuals.
The team is specifically tailored to the continuing opportunity set presented by the assets, with a strong emphasis on technical expertise in the areas of subsurface, drilling, production, engineering, and supporting departments. As such, the organisation will continue to function as a largely autonomous business unit, under Valeura’s direction.
Several leaders within the organisation have worked with the assets throughout their life cycle, starting with the fields’ original discovery and development. Valeura intends to retain this depth of experience within the Company and to ensure key in-country relationships are maintained throughout the integration process and thereafter.
Licence G11/48 (Nong Yao oil field)
The SPV will acquire operatorship and a 90% working interest in Licence G11/48, which contains the partially developed Nong Yao oil field. The 10% partner in the block is Palang Sophon Limited who is also Valeura’s partner in its G10/48 Licence, acquired earlier this year. The Nong Yao oil field is located in the central portion of the Pattani basin of the Gulf of Thailand, approximately 160 km offshore and in 75 metres water depth. The Nong Yao oil field contains 12.4 million bbls of 2P oil reserves, on a net working interest acquired basis, as of December 31, 2021, based on the Company’s internal (non-independent) management estimate. By the end of 2021, the Nong Yao oil field had produced over 20 million bbls of oil and every year the expected ultimate recovery (combination of actual production and expected reserves) of oil from the field has increased with the identification and development of additional accumulations. Management’s reserves estimate is substantially higher than the original 2P reserves as represented in the field’s development plan, prior to production start-up in 2015 (2.7 million bbls on a net 90% basis), reflecting that the original estimated reserves have been replaced many times over through ongoing activity.
Current production at the Nong Yao field is approximately 8,100 bbls/d, net to the 90% working interest, and is forecast to increase in 2024 through further development activity.
The Nong Yao oil field has been thus far developed from two interconnected fixed platforms, including 37 wells and a processing facility. Processed oil is stored in a leased Floating Storage and Offloading (“FSO”) vessel on location, and is offloaded to shuttle tankers for international sale. Operating costs for the Nong Yao field are approximately US$12/bbl at predicted near-term rates. Nong Yao production is light, sweet crude oil which typically receives prices approximately on par with the Brent crude oil benchmark.
Licence G11/48 is based on Thailand’s Thai III fiscal terms which entail a sliding scale royalty from 5% to 15% on gross production (approximately 8% at current rates), a Special Remuneration Benefit (“SRB”) on net windfall profits ranging from 0% to 75% (approximately 20% under current circumstances), and petroleum income tax of 50% on net profits.
Further development activities are currently underway on Licence G11/48, in support of commercialising a south-eastern area of the field known as the Nong Yao extension. The project seeks to add a new Mobile Offshore Production Unit (“MOPU”) which will be connected by pipeline to the existing infrastructure and to drill an additional 12 development wells. Construction of the new MOPU is in the under way, with the MOPU expected to mobilise to the Nong Yao oil field in Q4 2023, with commissioning and drilling activity scheduled to take place immediately thereafter. Valeura forecasts peak production from the field in 2024 at a rate of approximately 11,000 bbls/d, net to the 90% working interest.
With the Nong Yao extension facilities in place, Valeura intends to pursue a work programme aimed at identifying further opportunities on the south-eastern area of the field and beyond, with the objective of replicating the history of reserves renewal characteristic of Pattani basin fields. In particular, the Company aims to add incremental reserves and production to offset natural declines such that the field’s economic life extends beyond the currently calculated limit of end 2028 and toward the ultimate licence expiry of 2036.
The Company believes the southern portion of Licence G11/48 may contain potential upside opportunities including a string of prospective small oil accumulations in the Nong Nuch area identified on 3D seismic. Valeura intends to conduct further study on these opportunities, including assessing the potential for incremental volumes through additional near-field exploration or a cluster development scenario.
Licence B5/27 (Jasmine and Ban Yen oil fields)
The SPV will acquire operatorship and a 100% interest in Licence B5/27, which contains the developed Jasmine and Ban Yen oil fields. The Jasmine and Ban Yen oil fields are located in the northern portion of the Pattani basin of the Gulf of Thailand, approximately 180 km offshore and in 60 metres of water. Together, the Jasmine and Ban Yen fields contain 9.9 million bbls of 2P oil reserves on a net working interest acquired basis as of December 31, 2021, based on management’s internal (non-independent) estimate. The estimated ultimate recovery for the Jasmine and Ban Yen fields (defined as cumulative production to date plus reserves) has grown steadily throughout the fields’ life, and by the end of 2021 the fields had produced over 85 million bbls of oil.
Current production at the Jasmine and Ban Yen oil fields is approximately 10,100 bbls/d and the Company anticipates mitigating natural production decline through infill drilling and further development opportunities, thereby further increasing the estimated ultimate recovery.
The Jasmine and Ban Yen oil fields have been developed through a total of six fixed topside facilities and a leased Floating Production Storage and Offloading vessel (“FPSO”), the Jasmine Venture MV7. The facilities include well slots for 132 wells, of which 110 slots are utilised by producer wells and 22 slots by injection and disposal wells. Processed oil is stored at the FPSO, and is offloaded to shuttle tankers for sale into the domestic Thai market. Given the fixed nature of facilities associated with Licence B5/27, operating costs are relatively stable at approximately US$30/bbl at current production rates. Production from the Jasmine and Ban Yen fields is light, sweet crude oil, which typically receives a discount of approximately US$2/bbl below the Brent crude oil benchmark.
Licence B5/27 is based on Thailand’s Thai I fiscal terms which entail a flat 12.5% royalty in addition to a petroleum income tax rate of 50% on net profits. Licence B5/27 is also encumbered by certain private legacy commercial arrangements approximately equivalent to an additional royalty of 4.5%.
The Jasmine and Ban Yen fields are mid-life oil producing assets which present opportunities to access additional reserves and hence to bring new volumes through fixed facilities, thereby mitigating overall field decline rates and potentially extending field life. A programme of ongoing infill development drilling is underway on Licence B5/27 which has included nine wells drilled to date in 2022 plus approximately 19 further wells planned over the 2023 – 2026 time frame. Valeura intends to continue this work programme with the aim of adding additional reserves and production to offset natural declines such that the fields’ target production rate remains broadly stable while its economic life extends beyond the currently calculated limit of end 2027 and toward the ultimate licence expiry of 2032.
Valeura has identified several opportunities for further development of the licence, including potential oil accumulations within reach of the existing wellhead infrastructure and the potential for additional exploration within the licence area. These prospects require further commercial and technical evaluation, however, the projects appear to be representative of the type of opportunity which has historically resulted in repeated extensions of the asset’s economic life.
Licence G1/48 (Manora oil field)
The SPV will acquire operatorship and a 70% working interest in Licence G1/48, which contains the developed Manora oil field. The 30% partner is Tap Oil. The Manora oil field is located in the Kra sub-basin, a north-west extension of the Pattani basin in the Gulf of Thailand, approximately 84 km offshore and in 45 metres water depth. The Manora field contains 1.7 million bbls of 2P oil reserves on a net working interest acquired basis, as of the December 31, 2021, based on management’s internal (non-independent) reserves assessment.
Current production at the Manora oil field is approximately 3,000 bbls/d, net to the 70% working interest.
The Manora oil field has been developed by a single fixed wellhead and processing platform and a leased FSO vessel on location. The platform includes 30 well slots, of which 15 are utilised by production wells and seven by injection and disposal wells. Processed oil is stored in the FSO and is offloaded to shuttle tankers for international sale. Operating costs for the Manora oil field are approximately US$25/bbl at current rates. Manora production is medium-weight, sweet crude which typically receives a price approximately on par with the Brent crude oil benchmark.
Licence G1/48 is based on Thailand’s Thai III fiscal terms which entails a sliding scale royalty from 5% to 15% (approximately 8% at current rates), a SRB on net windfall profits ranging from 0% to 75% (approximately 8% under current circumstances), and petroleum income tax of 50% on net profits.
The Manora field is a mature asset for which a decommissioning plan has been prepared and submitted to Thailand’s upstream regulator. While that plan contemplated an end to the field’s economic life in 2022, recent activity has materially changed the Company’s outlook for the field. In particular, two infill development wells drilled in Q4 2022 have encountered oil and planning is currently underway to bring these wells online which the Company anticipates will be additive to production rates. The Company anticipates that information from these wells will be incorporated into a future reserves evaluation, effective December 31, 2022.
In addition, the Company intends to apply learnings from these wells toward its future planning for the field, as part of an aim to extend the field’s economic limit beyond its currently calculated limit of early 2025, and further toward the licence’s final expiry in 2033.
Reserves
Reserves estimates disclosed in this announcement are based on an internal evaluation (non-independent) conducted by Valeura with an effective date of December 31, 2021.
Reserves estimates are based on year-end 2021 information, and as such they do not include the impact of recent adjustments to work programmes, including the positive effect of additional wells, not previously contemplated for 2022, or include the production to date in 2022. With successful ongoing drilling operations on all fields, the Company is optimistic that future reserves evaluations will continue to illustrate the notion of reserves renewal and an increase in the expected ultimate oil recovery. This is underscored by the fact that the most recent monthly production from the fields of 21,255 bbls/d is a less than 10% reduction from the published oil production rates from these fields in 2021.
Valeura intends to commission Netherland, Sewell & Associates, Inc. to conduct a reserves and contingent resources evaluation for all of its Thailand assets effective December 31, 2022, in accordance with the Canadian Oil and Gas Evaluation Handbook, with results to be published by the Company in due course in the first quarter of 2023 subject to closing of the Acquisition.
Sustainability
Valeura’s management believes the most efficient way to ensure a sustainable ongoing supply of liquid hydrocarbons is through more fully exploiting discovered or partly developed accumulations. Valeura’s investment strategy is to continually strive to more fully utilise existing infrastructure to add incremental oil volumes as efficiently as possible from both a value and an environmental standpoint.
At the same time, Valeura has prioritised minimising greenhouse gas (“GHG”) emissions and responsibly managing waste disposal across all its operations. All assets to be acquired are equipped with water disposal wells and do not undertake any overboard discharge of produced water. Once the Acquisition has closed, Valeura intends to gather baseline data on GHG and other emissions, fuel consumption, and waste generated, in order to establish a continuous improvement programme on each of these metrics. The Company intends to begin reporting on these data, in due course, to enhance the transparency of its efforts. The Company will also examine ways to further conserve the small levels of solution gas production, including as an offshore fuel source as currently implemented at the Manora field.
Valeura believes sustainable operations must also focus on supporting its human capital. The Company has a history of utilising a predominantly local workforce wherever it operates and the current organisation will continue to be comprised of approximately 95% local Thai staff. Valeura intends to continue this approach with the team joining Valeura, by providing exposure to international standards, leading-edge support resources, and training across the business.
Decommissioning
The geology of the Gulf of Thailand, with multiple stacked sandstone reservoirs, lends itself to a continual programme of reserves replacement through ongoing infill drilling aimed at more fully commercialising discovered oil accumulations at each of the fields and maximising the use of fixed infrastructure. This has been successfully applied year after year with these assets. Particularly the Nong Yao and Jasmine fields are typical examples, wherein the expected ultimate oil recovery in both fields reflects a more than 10-fold increase over the initial field development plan. Additionally, while the forward plan of the fields consistently indicate that production decline is imminent, the current production of the acquired indicates a very stable profile. The Company sees the potential to continue this trend in the near-term and intends to pursue opportunities to economically extend field-life. This is central to its Gulf of Thailand strategy.
Valeura recognises its obligation to plan and fund the ultimate decommissioning of the assets being acquired and has included estimates in all of its economic evaluations. Total decommissioning costs have been currently estimated by the operator, using internal and/or external engineering estimates, to be an aggregate net outlay of approximately US$214 million on an undiscounted basis. Under Thailand’s regulations, of the three licences in the Acquisition, to date, only Licence G1/48 (Manora) has reached a reserves recovery level that required a decommissioning plan to be submitted, and approximately one third of the estimated decommissioning obligation has already been guaranteed with the Thailand regulator. Anticipated future decommissioning spending for all assets will be recorded as a long-term liability on the Company’s balance sheet.
With the increase in decommissioning activity in the Gulf of Thailand, the Company has been monitoring the recent public successes by other independent operators in the Gulf of Thailand and recognises that collaborating with industry peers may yield efficiencies in decommissioning practices. Through the advent of such approaches as rigless well abandonments, wellhead platform and equipment reuse, and potential equipment sharing within the region, Valeura intends to explore how best to satisfy its decommissioning obligations while reducing GHG and other emissions and reducing the total expenditure required. Accordingly, the Company believes there is scope to reduce the long-term financial liability associated with decommissioning, alongside its aforementioned approach to pursuing economic life extension projects on all assets.
Financial Synergy
Valeura anticipates future operating and economic synergies by consolidating the assets being acquired with its existing business, particularly the assets acquired with its initial Thailand acquisition, as announced on April 28, 2022. The Company intends to explore opportunities for cost optimisation through shared logistics and corporate services, as well as potential savings throughout its supply chain as a result of the economies of scale built through combining portfolios.
Outlook
Valeura anticipates closing the Acquisition in Q1 2023 subject to the satisfaction and/or waiver of all conditions under the SPA. Thereafter, the Company intends to provide an operational guidance outlook for 2023. The Company anticipates integration of the joining Thailand organisation with its pre-existing Thailand organisation and head office will progress through at least the first half of 2023.
Conference call
Valeura’s management team will host an investor and analyst webcast at 09:00 Calgary (16:00 London, 23:00 Bangkok) today, Tuesday December 6, 2022 to discuss the Acquisition. The live audio and video feed can be accessed via the link below. Questions may be submitted in writing through the webcast system or by email to [email protected].
An audio only feed of the event is available by phone using the Conference ID and dial-in numbers below and the related presentation will be made available on the Company’s website at https://www.valeuraenergy.com/investor-information/presentations/.
Conference ID: 472 086 595#
Dial-in numbers:
Canada: (833) 845-9589
Singapore: +65 6450 6302
Thailand: +66 2 026 9035
Turkey: 00800142034779
UK: 0800 640 3933
USA: (833) 846-5630
For further information, please contact:
Valeura Energy Inc. (General Corporate Enquiries) +1 403 237 7102
Sean Guest, President and CEO
Heather Campbell, CFO
[email protected]
Valeura Energy Inc. (Capital Markets / Investor Enquiries) +1 403 975 6752
Robin James Martin, Investor Relations Manager +44 7392 940495
Auctus Advisors LLP (Corporate Broker to Valeura) +44 (0) 7711 627 449
Jonathan Wright
CAMARCO (Public Relations, Media Adviser to Valeura) +44 (0) 20 3757 4980
Owen Roberts, Billy Clegg
[email protected]
Oil and Gas Advisories
Reserves disclosed in this announcement are based on an internal evaluation (non-independent) conducted by Valeura with an effective date of December 31, 2021. The reserves estimates disclosed in this announcement are estimates only and there is no guarantee that the estimated reserves will be recovered.
Reserves
Reserves are estimated remaining quantities of commercially recoverable oil, natural gas, and related substances anticipated to be recoverable from known accumulations, as of a given date, based on the analysis of drilling, geological, geophysical, and engineering data, the use of established technology, and specified economic conditions, which are generally accepted as being reasonable. Reserves are further categorised according to the level of certainty associated with the estimates and may be sub-classified based on development and production status.
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.
Advisory and Caution Regarding Forward-Looking Information
Certain information included in this announcement constitutes forward-looking information under applicable securities legislation. Such forward-looking information is for the purpose of explaining management’s current expectations and plans relating to the future. Readers are cautioned that reliance on such information may not be appropriate for other purposes, such as making investment decisions. Forward-looking information typically contains statements with words such as “anticipate”, “believe”, “expect”, “plan”, “intend”, “estimate”, “propose”, “project”, “target” or similar words suggesting future outcomes or statements regarding an outlook. Forward-looking information in this announcement includes, but is not limited to: the total cash consideration; the timing and quantum for any contingent consideration; the expected addition of 21,200 bbls/d of oil production from the Acquisition; the expected cash operating costs across the assets; the anticipated monthly pre-tax cash flows of approximately US$30 million per month from the assets being acquired; the expected uses of the anticipated cash flows; the ability to mitigate natural production declines on the acquired assets and extend field-life; the ability to realise near-term growth through further field development projects; the ability to identify and execute field life extension opportunities including through reserves replacement; the satisfaction of the conditions precedent to closing the Acquisition; closing of the Acquisition in Q1 2023; the anticipated working capital of Busrakham; the funding of the Acquisition; the expansion of the scope and capacity of the agreements with Trafigura Pte. Ltd.; the timing for the Nong Yao extension project including mobilisation of the MOPU to the field, drilling activity, and commissioning including the belief that there is scope to reduce the long-term financial liability associated with decommissioning; timing to achieve peak production from the Nong Yao field, and rates of approximately 11,000 bbls/d, net; anticipated end of field life for all assets being acquired; the Thailand fiscal regime; the ability minimise GHG emissions and responsibly manage waste disposal across operation; the ability to achieve operating and economic synergies between the assets being acquired and the existing portfolio; the opportunities for cost optimisation through shared logistics and corporate services; statements with respect to commission an NSAI evaluation of the reserves and resources associated with the Company’s Thailand assets and that the optimism that future reserves evaluations will continue to illustrate the notion of reserves renewal and an increase in the expected ultimate oil recover; statements with respect to employing the Seller’s Thailand workforce; the Company’s objectives with respect to sustainability; and all statements regarding the Company’s forward guidance expectations for 2023. In addition, statements related to “reserves” are deemed to be forward-looking information as they involve the implied assessment, based on certain estimates and assumptions, that the reserves can be profitably produced in the future.
Forward-looking information is based on management’s current expectations and assumptions regarding, among other things: the ability to close the Acquisition and to fund it from cash on hand and future cash flow; the continuation of operations following the COVID-19 pandemic; political stability of the areas in which the Company is operating and completing transactions; continued safety of operations and ability to proceed in a timely manner; continued operations of and approvals forthcoming from governments and regulators in a manner consistent with past conduct; future drilling activity on the required/expected timelines; the prospectivity of the Company’s lands; the continued favourable pricing and operating netbacks across its business; future production rates and associated operating netbacks and cash flow; decline rates; the ability to satisfy the conditions precedent under the Facility; future sources of funding; future economic conditions; future currency exchange rates; the ability to meet drilling deadlines and other requirements under licences and leases; and the Company’s continued ability to obtain and retain qualified staff and equipment in a timely and cost efficient manner. In addition, the Company’s work programmes and budgets are in part based upon expected agreement among joint venture partners and associated exploration, development and marketing plans and anticipated costs and sales prices, which are subject to change based on, among other things, the actual results of drilling and related activity, availability of drilling, offshore storage and offloading facilities and other specialised oilfield equipment and service providers, changes in partners’ plans and unexpected delays and changes in market conditions. Although the Company believes the expectations and assumptions reflected in such forward-looking information are reasonable, they may prove to be incorrect.
Forward-looking information involves significant known and unknown risks and uncertainties. Exploration, appraisal, and development of oil and natural gas reserves are speculative activities and involve a degree of risk. A number of factors could cause actual results to differ materially from those anticipated by the Company including, but not limited to: the ability of management to execute its business plan or realise anticipated benefits from the Acquisition; the risks of further disruptions from the COVID-19 pandemic; competition for specialised equipment and human resources; disruption in supply chains; the risks of currency fluctuations; changes in oil and gas prices and netbacks; potential changes in joint venture partner strategies and participation in work programmes; uncertainty regarding the contemplated timelines and costs for work programme execution; the risks of disruption to operations and access to worksites; potential changes in laws and regulations, the uncertainty regarding government and other approvals; counterparty risk; the risk that the conditions precedent under the Facility will not be satisfied and that other financing may not be available; risks associated with weather delays and natural disasters; and the risk associated with international activity. The forward-looking information included in this new release is expressly qualified in its entirety by this cautionary statement. See the most recent AIF and MD&A for a detailed discussion of the risk factors.
The forward-looking information contained in this new release is made as of the date hereof and the Company undertakes no obligation to update publicly or revise any forward-looking information, whether as a result of new information, future events or otherwise, unless required by applicable securities laws. The forward-looking information contained in this new release is expressly qualified by this cautionary statement.
Additional information relating to Valeura is also available on SEDAR at www.sedar.com.
This announcement does not constitute an offer to sell or the solicitation of an offer to buy securities in any jurisdiction, including where such offer would be unlawful. This announcement is not for distribution or release, directly or indirectly, in or into the United States, Ireland, the Republic of South Africa or Japan or any other jurisdiction in which its publication or distribution would be unlawful.
Neither the Toronto Stock Exchange nor its Regulation Services Provider (as that term is defined in the policies of the Toronto Stock Exchange) accepts responsibility for the adequacy or accuracy of this news release.
This information is provided by Reach, the non-regulatory press release distribution service of RNS, part of the London Stock Exchange. Terms and conditions relating to the use and distribution of this information may apply. For further information, please contact [email protected] or visit www.rns.com.
SOURCE: Valeura Energy Inc.
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