TIDMVLU
RNS Number : 6071O
Valeura Energy Inc.
13 June 2022
THAILAND ASSETS RESERVES AND RESOURCES REPORT
Calgary, June 13, 2022: Valeura Energy Inc. (TSX:VLE, LSE:VLU)
("Valeura" or the "Company"), an upstream oil and gas company with
assets in the Thrace Basin of Turkey and an announced acquisition
in the offshore Gulf of Thailand, is pleased to report the results
of an independent third party reserves and resources assessment
pertaining to its Gulf of Thailand acquisition announced April 28,
2022 and expected to close this month (the "Acquisition").
Highlights
-- Proved (1P) reserves of 2,749 Mbbl of oil;
-- Proved and probable (2P) reserves of 6,456 Mbbl of oil, with
an estimated future net revenue after income taxes of US$59.3
million, using a discount rate of 10%;
-- Best estimate (2C) unrisked contingent resources of 4,696
Mbbl for the Rossukon oil field, classified as 'development
pending;' and
-- Additional 2C unrisked contingent resources of 8,615 Mboe
relating to various other accumulations on the licences, classified
as 'development unclarified.'
The report, dated June 10, 2022, was prepared for Valeura by
Netherland, Sewell & Associates, Inc. ("NSAI") to assess
reserves and contingent resources associated with licences G10/48
and G6/48, in the Gulf of Thailand, as of March 31, 2022 (the "NSAI
Report"). As announced on April 28, 2022, Valeura has signed a
share purchase agreement to acquire all of the shares of KrisEnergy
International (Thailand) Holdings Ltd. which, through two
subsidiary companies, holds an 89% operated working interest in
licence G10/48 and a 43% operated working interest in licence
G6/48. Unless otherwise noted, reserves and resources estimates are
presented on a before royalties, working interest acquired
basis.
Sean Guest, President and CEO of Valeura commented:
"This third party, independent evaluation underscores the
tremendous value we are acquiring in Thailand. The externally
evaluated 2P reserves associated with the Wassana field in licence
G10/48 are 63% larger than we had originally estimated, meaning our
deal metrics are even stronger than initially presented.
For total consideration of US$19.3 million (including initial,
contingent, and facilities consideration) we are acquiring 6.5
million bbls of 2P oil reserves, valued at US$59.3 million on an
after-tax basis, using a 10% discount rate. At current exchange
rates of approximately 1.25 US$/C$, that equates to approximately
C$0.86 per share in tangible value, demonstrating the highly
accretive nature of this transaction.
In addition, 2C contingent oil resource volumes for the Rossukon
field are 4.7 million bbls on an unrisked, best estimate basis, and
carry an asse ssed 84% chance of development, reflecting the
field's status as 'development pending.' We will provide more
details on the Rossukon field development once we take the final
investment decision, anticipated in the coming months.
With these values in hand, our team is invigorated to work with
our counterparties to progress and complete the transaction and
thereafter to pursue both re-activation of Wassana and development
of Rossukon as soon as possible. We remain on track to close the
Acquisition this month and believe it will solidify significant
shareholder value in both the immediate and longer term."
Reserves and Resources Summary
The following is a summary of the NSAI Report. Unless otherwise
noted, all production, reserves and resources estimates are
presented on a working interest acquired basis to the
Valeura-controlled special purpose vehicle corporation ("SPV"),
Panthera Resources Pte. Ltd., which will serve as the buyer entity
in respect of the Acquisition. Valeura holds an 85% interest in the
SPV. Values may not add due to rounding.
Oil and Gas Reserves Based on Forecast Prices and Costs (Wassana
field, licence G10/48)
Oil reserves on licence G10/48 are associated with the Wassana
oil field, and have been presented as heavy crude oil volumes,
divided amongst the proved, probable and possible reserves
categories on a gross working interest (i.e. before royalties) and
net working interest (i.e. after royalties) basis.
Light and Heavy Conventional Natural Total Oil
Medium Crude Oil Natural Gas Equivalent
Crude Oil Gas Liquids
Gross Net Gross Net Gross Net Gross Net Gross Net
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
(Mbbl) (Mbbl) (Mbbl) (Mbbl) (MMcf) (MMcf) (Mbbl) (Mbbl) (Mboe) (Mboe)
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Proved Developed - - - - - - - - - -
Producing
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Proved Developed
Non-Producing - - 1,838.6 1,732.9 - - - - 1,838.6 1,732.9
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Proved Undeveloped - - 910.7 858.4 - - - - 910.7 858.4
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Total Proved - - 2,749.3 2,591.2 - - - - 2,749.3 2,591.2
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Total Probable - - 3,706.9 3,493.7 - - - - 3,706.9 3,493.7
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Total Proved
Plus Probable - - 6,456.2 6,085.0 - - - - 6,456.2 6,085.0
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Total Possible - - 949.1 894.5 - - - - 949.1 894.5
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Total Proved
Plus Probable
Plus Possible - - 7,405.3 6,979.4 - - - - 7,405.3 6,979.4
-------- -------- -------- -------- ------- ------- ------- ------- -------- --------
Net Present Values of Future Net Revenue Based on Forecast
Prices and Costs (Wassana field, licence G10/48)
Net present values of future net revenue from oil reserves on
licence G10/48 are based on cost estimates as of the date of the
NSAI Report, and forecast Brent crude oil reference prices of
US$97.50, US$87.07, US$78.25, and US$77.34 per bbl for the years
ending December 31, 2022, 2023, 2024, and 2025, respectively, with
2% escalation thereafter, and assuming a differential of (US$4.34)
per bbl based on historical realised prices. Given available tax
pools, NSAI has anticipated no taxes payable in relation to the
reserves and accordingly values are presented as both before and
after deducting income taxes.
Before and After Deducting Income Taxes
Discounted At
---------------------------------------------------------------
0% 5% 10% 15% 20%
----------- ----------- ----------- ----------- -----------
(M US$) (M US$) (M US$) (M US$) (M US$)
----------- ----------- ----------- ----------- -----------
Proved Developed Producing - - - - -
----------- ----------- ----------- ----------- -----------
Proved Developed Non-Producing (25,890.4) (21,237.6) (17,465.6) (14,382.2) (11,842.8)
----------- ----------- ----------- ----------- -----------
Proved Undeveloped 30,898.0 25,761.7 21,500.3 17,937.7 14,938.8
----------- ----------- ----------- ----------- -----------
Total Proved 5,007.5 4,524.1 4,034.7 3,555.5 3,096.0
----------- ----------- ----------- ----------- -----------
Total Probable 82,568.5 67,338.8 55,263.6 45,605.6 37,819.3
----------- ----------- ----------- ----------- -----------
Total Proved Plus Probable 87,576.1 71,862.8 59,298.3 49,161.1 40,915.3
----------- ----------- ----------- ----------- -----------
Total Possible 59,380.8 51,278.1 44,743.7 39,407.4 34,999.9
----------- ----------- ----------- ----------- -----------
Total Proved Plus Probable
Plus Possible 146,956.8 123,140.9 104.041.9 88.568.5 75,915.3
----------- ----------- ----------- ----------- -----------
Contingent Oil Resources, Development Pending (Rossukon oil
field, licence G6/48)
Contingent oil resources for the Rossukon oil field on licence
G6/48 are light and medium crude Oil classified as "Development
Pending" and carry an assessed chance of development of 84%. The
Company believes the unrisked best estimate provides the most
appropriate indication of volumes that will become 2P oil reserves
upon development sanction of the Rossukon field.
Light Heavy Conventional Natural Total Oil
and Medium Crude Oil Natural Gas Equivalent
Crude Gas Liquids
Oil
Gross Net Gross Net Gross Net Gross Net Gross Net
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
(Mbbl) (Mbbl) (Mbbl) (Mbbl) (MMcf) (MMcf) (Mbbl) (Mbbl) (Mboe) (Mboe)
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
Unrisked
Low Estimate
(1C) 3,231.4 3,037.6 - - - - - - 3,231.4 3,037.6
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
Best Estimate
(2C) 4,696.1 4,380.2 - - - - - - 4,696.1 4,380.2
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
High Estimate
(3C) 6,438.9 5,958.4 - - - - - - 6,438.9 5,958.4
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
Risked, with Chance of Development = 84%
Low Estimate
(1C) 2,714.4 2,551.5 - - - - - - 2,714.4 2,551.5
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
Best Estimate
(2C) 3,944.7 3,679.4 - - - - - - 3,944.7 3,679.4
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
High Estimate
(3C) 5,408.7 5,005.0 - - - - - - 5,408.7 5,005.0
-------- -------- ------- ------- ------- ------- ------- ------- -------- --------
The Rossukon oil field has a regulator-approved development plan
which contemplates peak oil production rates of 12,000 bbls/d gross
(5,160 bbls/d net working interest basis) and sets a first-oil
requirement by November 2023. The development scheme evaluated by
NSAI assumes a two-phase drilling programme of 10 horizontal
production wells, seven water injection wells, and one water source
well connected to a Mobile Offshore Production Unit. The first
phase of the development aims to achieve first oil from three
horizontal producers in Q4 2023. The second phase will complete the
remaining scope of the development plan.
Contingent Oil and Gas Resources, Development Unclarified
(licences G6/48 and G10/48)
Contingent oil resources for additional reservoir accumulations
on licence G6/48 and G10/48 are heavy crude oil and conventional
natural gas classified as "Development Unclarified" and carry an
assessed chance of development ranging from 10% to 22%. These
accumulations provide a future opportunity to access additional
hydrocarbon volumes on the licence interests being acquired.
Light and Heavy Crude Conventional Natural Total Oil
Medium Crude Oil Natural Gas Gas Liquids Equivalent
Oil
Gross Net Gross Net Gross Net Gross Net Gross Net
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
(Mbbl) (Mbbl) (Mbbl) (Mbbl) (MMcf) (MMcf) (Mbbl) (Mbbl) (Mboe) (Mboe)
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
Unrisked
Low Estimate
(1C) - - 6,823.7 n/a 4,935.1 n/a - - 7,646.2 n/a
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
Best Estimate
(2C) - - 7,666.7 n/a 5,692.5 n/a - - 8,615.5 n/a
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
High Estimate
(3C) - - 12,602.8 n/a 6,608.8 n/a - - 13,704.3 n/a
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
Risked, with Chance of Development = 10% - 22%
Low Estimate
(1C) - - 1,196.4 n/a 987.0 n/a - - 1,360.9 n/a
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
Best Estimate
(2C) - - 1,383.0 n/a 1,138.5 n/a - - 1,572.8 n/a
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
High Estimate
(3C) - - 2,153.6 n/a 1,321.8 n/a - - 2,373.9 n/a
-------- -------- --------- ------- -------- ------- ------- ------- --------- -------
For further information, please contact:
Valeura Energy Inc. (General Corporate Enquiries) +1 403 237
7102
Sean Guest, President and CEO
Heather Campbell, CFO
Contact@valeuraenergy.com
Valeura Energy Inc. (Capital Markets / Investor Enquiries) +1 403 975 6752
Robin James Martin, Investor Relations Manager +44 7392
940495
IR@valeuraenergy.com
Auctus Advisors LLP (Corporate Broker to Valeura) +44 (0) 7711
627 449
Jonathan Wright
Valeura@auctusadvisors.co.uk
CAMARCO (Public Relations, Media Adviser to Valeura) +44 (0) 20 3757 4980
Owen Roberts, Billy Clegg
Valeura@camarco.co.uk
Oil and Gas Advisories
Reserves and contingent resources disclosed in this announcement
in respect of the Acquisition are based on an independent
evaluation conducted by the incumbent independent petroleum
engineering firm, NSAI with an effective date of March 31, 2022.
The NSAI estimates of reserves and resources were prepared using
guidelines outlined in the Canadian Oil and Gas Evaluation Handbook
and in accordance with National Instrument 51-101 - Standards of
Disclosure for Oil and Gas Activities. The reserves and contingent
resources estimates disclosed in this announcement in respect of
the Acquisition are estimates only and there is no guarantee that
the estimated reserves and contingent resources 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.
Developed reserves are those reserves that are expected to be
recovered from existing wells and installed facilities or, if
facilities have not been installed, that would involve a low
expenditure (e.g. when compared to the cost of drilling a well) to
put the reserves on production.
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.
Developed non-producing reserves are those reserves that either
have not been on production, or have previously been on production,
but are shut in, and the date of resumption of production is
unknown.
Undeveloped 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 classification (proved, probable, possible) to
which they are assigned.
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.
Possible reserves are those additional reserves that are less
certain to be recovered than probable reserves. It is unlikely that
the actual remaining quantities recovered will exceed the sum of
the estimated proved plus probable plus possible reserves. There is
a 10% probability that the quantities actually recovered will equal
or exceed the sum of the estimated proved plus probable plus
possible reserves.
The estimated future net revenues disclosed in this announcement
in respect of the Acquisition do not necessarily represent the fair
market value of the reserves associated with the Wassana oil
field.
Contingent Resources
Contingent resources are those quantities of petroleum
estimated, as of a given date, to be potentially recoverable from
known accumulations using established technology or technology
under development, but which are not currently considered to be
commercially recoverable due to one or more contingencies.
Contingencies are conditions that must be satisfied for a portion
of contingent resources to be classified as reserves that are: (a)
specific to the project being evaluated; and (b) expected to be
resolved within a reasonable timeframe.
Contingent resources are further categorised according to the
level of certainty associated with the estimates and may be
sub--classified based on a project maturity and/or characterised by
their economic status. There are three classifications of
contingent resources: low estimate, best estimate and high
estimate. Best estimate is a classification of estimated resources
described in the Canadian Oil and Gas Evaluation Handbook as the
best estimate of the quantity that will be actually recovered; it
is equally likely that the actual remaining quantities recovered
will be greater or less than the best estimate. If probabilistic
methods are used, there should be at least a 50 percent probability
that the quantities actually recovered will equal or exceed the
best estimate.
The project maturity subclasses include development pending,
development on hold, development unclarified and development not
viable. All of the contingent resources disclosed in this
announcement are classified as either development pending or
development unclarified. Development pending is defined as a
contingent resource where resolution of the final conditions for
development is being actively pursued. Development unclarified is
defined as a contingent resource that requires further appraisal to
clarify the potential for development and has been assigned a lower
chance of development until commercial considerations can be
clearly defined. Chance of development is the likelihood that an
accumulation will be commercially developed.
Conversion of the development pending contingent resources
referred to in this announcement to reserves is dependent upon a
Final Investment Decision for the oil development of the Rossukon
field. The major positive factors relevant to the estimate of the
development pending contingent resources are the successful
appraisal of the Rossukon field through existing drilled and tested
wells and the existing Thailand Government approved development
plan which is economically attractive at current product prices and
capital cost estimates. The major negative factor relevant to the
estimate of the contingent resources is the pending nature of a
finalised development plan and a Final Investment Decision required
to proceed with development. If these contingencies are
successfully addressed, some portion of these contingent resources
may be reclassified as reserves.
Conversion of the development unclarified resources referred to
in this announcement is dependent upon (1) improved economic
conditions and continued development beyond what is currently
planned for the Wassana field, (2) the collection of additional
technical data through delineation wells and flow tests on the
Mayura field to establish the size and commercial viability of the
project, (3) commitment of the G10/48 license partners to develop
the Mayura field resources, (4) approval of a plan to market the
Rossukon field gas, and (5) completion of a Rossukon gas sales
agreement. The major positive factor relevant to the estimate of
the development unclarified contingent resources is the successful
evaluation of resources encountered in appraisal wells within the
Wassana, Rossukon and Mayura fields. The major negative factors
relevant to the estimate of the development unclarified contingent
resources are that (1) current economic conditions do not support
certain resource development, (2) the requirement for further
appraisal to reduce resource uncertainties prior to development,
and (3) the requirement to enter definitive agreements to market
the Rossukon gas. If these contingencies are successfully
addressed, some portion of these contingent resources may be
reclassified as reserves.
The NSAI estimates have been risked, using the chance of
development, to account for the possibility that the contingencies
are not successfully addressed. Due to the early stage of
development for the development unclarified resources, NSAI did not
perform an economic analysis of these resources; as such, the
economic status of these resources is undetermined and there is
uncertainty that any portion of the contingent resources disclosed
in this announcement will be commercially viable to produce.
Barrels of Oil Equivalent
A boe is determined by converting a volume of natural gas to
barrels using the ratio of 6 Mcf to one barrel. Boe values may be
misleading, particularly if used in isolation. A boe conversion
ratio of 6 Mcf:1 boe is based on an energy equivalency conversion
method primarily applicable at the burner tip and does not
represent a value equivalency at the wellhead. Further, a
conversion ratio of 6 Mcf:1 boe assumes that the gas is very dry
without significant natural gas liquids. Given that the value ratio
based on the current price of oil as compared to natural gas is
significantly different from the energy equivalency of 6:1,
utilising a conversion on a 6:1 basis may be misleading as an
indication of value.
Glossary
bbl barrel
boe barrel of oil equivalent
M US$ thousands of US dollars
Mbbl thousand barrels
Mboe thousand barrels of oil equivalent
Mcf thousand curbic feet
MMcf million cubic feet
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 anticipated
benefits of the Acquisition and associated benefits to Valeura's
stakeholders; the completion of the Acquisition and the timing
thereof; the total cash consideration for the Acquisition,
including contingent payments and the timing thereof; statements
with respect to the net working interest reserves and resources in
the acquired assets; and statements with respect to regulatory and
partner approvals for a development plan for the Rossukon field
being pending. In addition, statements related to "reserves" and
"resources" are deemed to be forward-looking information as they
involve the implied assessment, based on certain estimates and
assumptions, that the resources can be discovered and 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 ability to successfully re-start
production from the Wassana field; 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 future sources of funding; future economic conditions;
future currency exchange rates; 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,
high-pressure stimulation and other specialised oilfield equipment
and service providers for onshore and offshore operations, 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 and resources 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: inability
to close the Acquisition in June 2022; the ability of management to
execute its business plan or realise anticipated benefits from the
Acquisition; inability to integrate the Acquisition if it closes;
inability to secure a new partner for the tight gas appraisal play
and execute potential mergers and acquisitions; evolving impacts of
the COVID-19 pandemic including disruptions in global supply
chains; the Company's ability to manage growth; the Company's
ability to manage the costs related to inflation; uncertainty in
capital markets and ability to raise debt and equity, as required,
particularly for companies with a small market capitalisation; the
ability to finance future development and/or inorganic growth; the
risks of currency fluctuations; changes in oil and gas prices and
netbacks in Thailand and Turkey; potential changes in joint venture
partner strategies
and participation in work programmes; potential assertions of
pre-emptive rights by a partner or potential disputes with a
partner in connection with the Acquisition; uncertainty regarding
the contemplated timelines and costs for offshore development plans
in Thailand and the tight gas appraisal play evaluation in Turkey;
the risks of disruption to operations and access to worksites
(including the impact of the COVID-19 pandemic); the ability of the
Company to maintain its directors, senior management team and
employees with relevant experience; potential changes in laws and
regulations, and the uncertainty regarding government and other
approvals; counterparty risk; the ability of the Company to
maintain effective internal control over financial reporting;
counterparty risk; risks associated with weather delays and natural
disasters; and the risk associated with international activity. The
forward-looking information included in this announcement is
expressly qualified in its entirety by this cautionary statement.
See the Company's annual information form for the year ended
December 31, 2021 for a detailed discussion of the risk
factors.
The forward-looking information contained in this announcement
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 announcement is
expressly qualified by this cautionary statement.
Additional information relating to Valeura is also available on
SEDAR at www.sedar.com .
This Announcement contains inside information as defined in
Article 7 of the Market Abuse Regulation No. 596/2014 ("MAR") which
is part of UK law by virtue of the European Union (Withdrawal) Act
2018. Upon the publication of this Announcement, this inside
information is now considered to be in the public domain.
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 RNS, the news service of the
London Stock Exchange. RNS is approved by the Financial Conduct
Authority to act as a Primary Information Provider in the United
Kingdom. Terms and conditions relating to the use and distribution
of this information may apply. For further information, please
contact rns@lseg.com or visit www.rns.com.
RNS may use your IP address to confirm compliance with the terms
and conditions, to analyse how you engage with the information
contained in this communication, and to share such analysis on an
anonymised basis with others as part of our commercial services.
For further information about how RNS and the London Stock Exchange
use the personal data you provide us, please see our Privacy
Policy.
END
MSCFIFEERSIVLIF
(END) Dow Jones Newswires
June 13, 2022 02:00 ET (06:00 GMT)
Valeura Energy (LSE:VLU)
Gráfico Histórico do Ativo
De Dez 2024 até Jan 2025
Valeura Energy (LSE:VLU)
Gráfico Histórico do Ativo
De Jan 2024 até Jan 2025
