REG - Challenger Energy - AUDITED ANNUAL RESULTS FOR THE YEAR ENDED 31/12/23
27/06/2024 07:00
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RNS Number : 0504U Challenger Energy Group PLC 27 June 2024
27 June 2024
Challenger Energy Group PLC
("Challenger Energy" or the "Company")
AUDITED ANNUAL RESULTS FOR THE YEAR ENDED 31 DECEMBER 2023
Challenger Energy (AIM: CEG), an Atlantic margin focused oil and gas company,
is pleased to announce its audited Annual Results for the year ended 31
December 2023.
The 2023 Annual Report and Financial Statements will be posted to shareholders
by 30 June 2023 along with the notice of the Company's Annual General Meeting
to be held on 29 July 2024 at 11.00 a.m. British Summer Time at The Engine
House, Alexandra Road, Castletown, Isle of Man IM9 1TG.
The 2023 Annual Report and Financial Statements are set out in full below and
are also available on the Company's website https://www.cegplc.com/
(https://www.cegplc.com/) .
For further information, please contact:
Challenger Energy Group PLC Tel: +44 (0) 1624 647 882
Eytan Uliel, Chief Executive Officer
WH Ireland - Nomad and Joint Broker Tel: +44 (0) 20 7220 1666
Antonio Bossi / Darshan Patel / Isaac Hooper
Zeus Capital - Joint Broker Tel: +44 (0) 20 3829 5000
Simon Johnson
Gneiss Energy Limited - Financial Adviser Tel: +44 (0) 20 3983 9263
Jon Fitzpatrick / Paul Weidman / Doug Rycroft
CAMARCO Tel: +44 (0) 20 3757 4980
Billy Clegg / Hugo Liddy / Sam Morris
Tel: +44 (0) 20 3983 9263
CAMARCO
Billy Clegg / Hugo Liddy / Sam Morris
Tel: +44 (0) 20 3757 4980
Notes to Editors
Challenger Energy is an Atlantic-margin focused energy company, with
production, development, appraisal, and exploration assets in the region. The
Company's primary assets are located in Uruguay, where the Company holds high
impact offshore exploration licences. Challenger Energy is quoted on the AIM
market of the London Stock Exchange.
https://www.cegplc.com (https://www.cegplc.com/)
Chairman's Letter to the Shareholders
Dear Shareholders,
It is my pleasure to report to you as Chairman of your Company.
In my last report I commented on our strategic objectives for 2023: achieving
value for our Uruguay AREA OFF-1 licence, and resetting our business in
Trinidad and Tobago. I am pleased to be reporting that as of this Annual
Report, both strands of our objectives have been achieved.
In Trinidad and Tobago, disposals of non-core assets have successfully
completed, and the reset of 'efficiency and profit' around our core assets of
Goudron and Inniss-Trinity continues. It is a credit to our team in Trinidad
and Tobago that we continue to have safe and sustained operations in country,
and I take this opportunity of thanking that team on behalf of shareholders
and the Board of Directors. In 2023, we also exited our acreage position in
Suriname, ensuring that all operational focus is on Trinidad and Tobago.
In Uruguay, we had a very clear objective of creating value for our
shareholders by the farm-out of AREA OFF-1. We announced a successful farm-out
to Chevron earlier this year, which came as a result of a well-run process. As
reported, the transaction is yet to close, but we do expect to have completed
all regulatory matters in the course of the coming months.
In Uruguay, we also secured the award of AREA OFF-3, and as was the case with
AREA OFF-1, with a prudent work programme.
Overall, Uruguay acreage is still benefitting from the almost constant stream
of good news coming from the African side of the Atlantic conjugate margin. We
look forward to working closely and supportively with Chevron over the coming
months and years to make AREA OFF-1 a highly successful venture. We are
equally excited about our plans to enhance value at AREA OFF-3. Eytan, in his
CEO report, expands on the detail behind the work undertaken and planned on
both our Uruguayan licences.
In April 2024, we reported on the strategic investment by Charlestown Energy
Partners in the Company, and I look forward to working with Robert Bose on the
Board.
Finally, and as always, I thank the staff of Challenger Energy for their
efforts last year, the Board for their guidance and insight and, of course,
our shareholders for their continued support.
Iain McKendrick
Chairman
26 June 2024
Chief Executive Officer's Report to the
Shareholders
Dear fellow Shareholders,
This is my fourth report to you, the owners of the Company, in my capacity as
Chief Executive Officer.
The last 18 months has been a period of excellent progress for Challenger
Energy. During this period, we did what we said we would do and we delivered
most of what we promised we would deliver. The highlight event being the
farm-out of our AREA OFF-1 block in Uruguay to Chevron, a transaction which is
transformational for our Company in that it will lead to an exciting program
of value-adding activity over the coming 18 months, as well as ensuring that
we are fully-funded for the foreseeable future. Therefore, as we look to the
second half of 2024 and beyond, I believe that our Company is in the best
position it has been in for many years. Details are provided in my commentary
below.
Strategic Context
In last year's Annual Report, I reported on several key developments in
Challenger Energy's business during the 2022 period.
In summary, these were (i) the Company and its business had been successfully
"reset", both operationally and financially;
(ii) significant exploration discoveries had been made in the Namibian
conjugate margin, analogous to the Company's licenced
acreage in Uruguay; and (iii) endeavours to increase production from our
Trinidad assets had proved difficult.
As a result of these factors the Company responded during 2023 with a shift in
strategy to place primary emphasis on our Uruguayan assets, and to deemphasise
growth in Trinidad in favour of achieving cashflow breakeven from the core
Trinidadian assets while divesting any assets non-core to this objective.
Uruguay
In a relatively short space of time, our interests in Uruguay have become the
centrepiece of our business. It is the place where we expect to be able to
realise the greatest incremental value over the coming years, and it is thus
the place where we are now focusing much of our efforts.
Shareholders will recall that in 2020 we were awarded the licence for the AREA
OFF-1 block, offshore Uruguay. At the time we saw Uruguay as being an
underexplored frontier basin location with reasonable potential, although at
that time Uruguay was not on the global sector radar, so when we were awarded
the AREA OFF-1 licence Challenger Energy became Uruguay's sole licence holder.
However, in geological terms Uruguay, we believe, is the "mirror" of Namibia's
Orange Basin, and thus when very large new discoveries were made by
supermajors in the Orange Basin in 2022, Uruguay become a global exploration
"hotspot". In less than two years Uruguay's offshore went from being
completely unlicenced to being 100% licenced, with every offshore block (other
than Challenger Energy's) licenced to majors / NOC. Moreover, new entrants
committed to significant work programs to secure their licences, in contrast
to the modest work program we bid to secure AREA OFF-1.
In this context we decided to strategically prioritise Uruguay. We laid out a
plan of action, and over the last 18 months we successfully executed on that
plan, as follows:
(i) We accelerated our technical work program on AREA OFF-1, thereby
rapidly enhancing the value of the asset. Our work program was thorough and
focused, including reprocessing of legacy 2D seismic data, advanced amplitude
variation with offset (AVO) analysis, seabed geochemical and satellite seep
studies and full reinterpretation and remapping of all data, leading to lead
and then prospect definition and an initial volumetric assessment. The result
was delineation and high grading of three primary prospects, in aggregate
representing an inventory of approximately 2 billion barrels (Pmean) and up to
5 billion barrels in an upside case (P10). This served to establish AREA OFF-1
as a high-quality asset of global scale and materiality. Focused technical
work continued throughout 2023, in support of maximising the potential for
securing a farm-out. This also meant that by the end of 2023 our minimum work
program commitment for the first four-year period of the AREA OFF-1 licence -
initially meant to be completed by August 2026 - had been completed, more than
two years ahead of schedule.
(ii) To fully leverage the value of our acquired knowledge and
understanding, the excellent working relationship established with the
Uruguayan authorities and regulators, and the attractive conditions in that
country for hydrocarbon industry activity, we decided to bid for a second
licence. We were successful in this endeavour, and in June 2023 Challenger
Energy was designated as the party to whom the AREA OFF-3 licence - the last
available offshore acreage in Uruguay - would be awarded, on attractive terms.
This award was subsequently finalised in March 2024, with the initial
four-year exploration period for AREA OFF-3 commencing in June 2024. As a
result of this award, our Company has emerged as the 3(rd) largest net acreage
holder in Uruguay, and the only junior E&P company with any position in
the Uruguay offshore, holding two world class assets and a growing prospect
inventory in what has fast become a highly desirable exploration "postcode".
(iii) On the basis of our excellent technical results, in mid-2023 we
launched a formal, adviser-led farm-out process for AREA OFF-1. The objective
was to secure an industry heavyweight as a partner for the project, who could
provide the further expertise and capital needed to rapidly take AREA OFF-1
forward to 3D seismic acquisition and ultimately exploration well drilling.
Our target was to secure a farm-out by the end of 2023, and whilst ultimately
the process took a few months longer than planned, in March 2024 we entered
into a farm-out agreement with Chevron. Under the terms of that agreement,
Chevron will assume a 60% operating interest in AREA OFF-1, will pay the
Company US$12.5 million cash as an entry fee, will carry 100% of the costs of
an agreed accelerated 3D seismic acquisition on the block (up to a total net
cash value to the Company of US$15 million), and thereafter if the decision is
made to proceed to drilling of an initial exploration well, carry 50% of the
Company's share of costs associated with that well (up to a total net cash
value to the Company of US$20 million). As at the date of this Annual Report,
Chevron's entry into the project awaits approval from the Uruguayan regulatory
authorities, a normal industry formality for any farm-out and one which we
expect will be concluded in the coming months, well within the time needed to
allow for Chevron's proposed 3D seismic acquisition to commence at the end of
2024/early 2025. We anticipate thereafter that we will see Chevron undertake
significant activity on AREA OFF-1, and it is this activity which we believe
will ultimately realise the considerable value we see in this asset.
In summary, the recap for 2023 insofar as our business in Uruguay is concerned
is that we completed a high-quality and value-accretive technical work program
for AREA OFF-1, we materially expanded our Uruguayan asset base through adding
the AREA OFF-3 licence to the portfolio, and we secured a market-leading
farm-out for AREA OFF-1.
However, before moving on to considering the rest of our business, I think it
is worth making a brief, specific comment on the value and impact of this last
item - the farm-out agreement with Chevron. As already noted, entry into this
agreement was undoubtedly the highlight of the last 18 months for Challenger
Energy, and represented the culmination of a huge amount of technical and
commercial work, by many people over more than a year. It is thus an outcome
we are extremely proud of, and is important for two reasons.
Firstly, the farm-out metrics achieved in this transaction are in our view,
excellent. All CEOs will have you know that their Company is undervalued, but
in this case, if properly analysed, the embedded value to our Company in the
AREA OFF-1 farm-out arrangement is many multiples of our current share price -
something I believe the equity market is yet to appreciate.
Secondly, over and above the mere numbers, the AREA OFF-1 farm-out is
genuinely transformational for Challenger Energy's future, in that (i) our
strategy and technical work has been validated by one of the world's leading
energy companies - the resulting intangible benefit in terms of our industry
"credentials" is immeasurable, (ii) going forward, operation of the AREA OFF-1
project will be in the hands of an operator and partner who has made a clear
commitment to accelerating 3D seismic acquisition (and hopefully thereafter,
exploration well drilling), and (iii) we will retain a material stake of 40%
in the AREA OFF-1 licence, which will give us enormous flexibility when it
comes time to consider how we participate in any future success case.
Trinidad and Tobago
By the end of 2022 we had come to the conclusion that achieving a material
increase in production from our Trinidadian onshore asset portfolio was not
commercially viable, due to the age of the fields and the technical
characteristics of the relevant reservoirs. We thus shifted our objective from
production growth to achieving financial breakeven from core assets, and
streamlining our operations by divesting any assets considered non-core to
this objective.
Thus, in early 2023, we sold the small and geographically removed South Erin
asset, and in late 2023 we completed the sale of the non-producing Cory Moruga
appraisal asset. In both cases the sales not only realised cash, but also
relieved the group of significant liabilities, work program commitments, and
administrative burden and cost associated with management of those assets.
At the same time, we concentrated our operational efforts on our two primary
producing assets - the Goudron and Inniss-Trinity fields in south-east
Trinidad. There, the focus was very clear: maintain constant production,
eliminate excess cost, realise operating efficiencies from our people and
equipment, and achieve cashflow breakeven.
In terms of results, 2023 production from these two fields was generally
constant (on a like-for-like basis almost identical to 2022 production), and
total operating expenses and G&A were reduced considerably (33%) as
compared to 2022. However, realised oil prices across 2023 were lower than
across 2022, so many of the operational gains we made were offset by lower
revenue, such that whilst we were successful in operating on a cashflow
breakeven basis, we did record a (relatively small) net operating loss (as
compared to a small positive operating cash surplus in 2022). This financial
performance also necessitated us reconsidering the carrying value of the
Trinidadian licences on our balance sheet, and at the end of 2023 we decided
to write down both the goodwill and asset values associated with these
licences.
Through 2023 we also spent a substantial amount of time and effort on trying
to develop options to expand our Trinidad business into a more sizeable and
profitable production operation, either through organic growth or through
adding new acreage to our portfolio. However, despite our best efforts, we did
not make any progress of note on this important task.
In summary therefore, insofar as our business in Trinidad is concerned, I can
report that 2023 was a mixed year. We largely met our core objectives of
achieving cashflow breakeven operations and selling non-core assets. But, we
did not turn a profit, and we did not "crack the code" as to how, in the
longer term, we can transform the Trinidad business into a profitable
production base of greater scale. We will continue our efforts to make
progress on this front in the coming year.
Other Assets
In relation to the Company's licences in The Bahamas, throughout the course of
2023 we continued to pursue a renewal of the licences into a third exploration
period. In parallel we continued to explore various alternative strategies
seeking to monetise those assets. The process has been frustratingly slow, but
we expect to make better progress in the coming 12 months.
During 2023 we also undertook a detailed "economic basement to surface"
technical review of the Weg Naar Zee project in Suriname, and concluded that
the project did not offer the prospect of long-term commerciality (especially
as compared to the better return potential we saw available from other assets
in our portfolio). We thus made the decision to exit from the Suriname
project, a process which was fully completed by the end of 2023.
Financial Performance
For the 2023 period under review, we recorded a loss of $13.4 million,
although this includes the impact of various non-cash items, including
non-cash losses arising from accounting impairments associated with the
Trinidadian assets of approximately $12.9 million. Therefore, a more relevant
metric to evaluate our financial performance during the period would, in my
view, be a consideration of our "burn" - that is, cash used in
running/sustaining our business across the period. In that respect, as noted,
our Trinidadian operations operated on a largely self-sustaining basis through
2023 (thus requiring no cash support from the group), and the general and
administration cost for the rest of our business was reduced to under
US$200,000 per month (this being a reduction of 37% as compared to 2022).
Based on benchmarking, we believe that this level of "burn" which represents
the basic costs needed to stay in business as an AIM-listed vehicle, compares
favourably with most of our peers. That said, we are always considering ways
in which we can reduce our cost base further.
Capital Allocation and Funding
For a junior E&P company, effective capital allocation is one of
management's most important tasks. This is because within any given portfolio
of assets, there will almost always be more opportunities and activities in
need of funding than there are funds available. With this in mind, prudently
managing our available capital has always been a key priority, with the
overriding goal being to strike a balance between advancing our business
quickly and in the most advantageous way, but at the same time making the most
out of every dollar spent, and avoiding to the greatest extent possible the
need to seek additional funding by way of dilutive equity raisings.
Pleasingly, over the last 18 months we have largely been able to achieve this
goal. Specifically, Challenger Energy's last equity capital raising was in
March 2022 as part of a broader corporate restructure / recapitalisation. At
that time, we raised an amount that was then estimated to be sufficient to
sustain 12 months of future operations, but we have "stretched" the funds
raised such that we have operated without needing to undertake an equity
placing for more than two years now. We have done this by:
(i) keeping overheads lean and efficient: as mentioned, through the
course of 2023 our corporate overhead was low, both in an absolute sense and
as compared to 2022;
(ii) ensuring any incremental expenditure is very focused in its
application: in 2023, we only allocated discretionary capital to value-adding
technical work in Uruguay, and, as noted, operations in Trinidad and Tobago
were largely self-funding through the period, thus requiring almost no
financial support from the Group; and
(iii) successfully selling non-core assets: the sales of the South Erin
and Cory Moruga assets supplemented available working capital, and whilst a
delay in regulatory approval for the sale of the Cory Moruga asset
necessitated a bridge funding facility being put in place in mid-2023, we were
eventually able to deliver on that transaction, which in addition to releasing
capital back to the business also allowed for the bridge funding facility to
be fully repaid and cancelled.
Subsequently, in May 2024 we secured a meaningful equity investment - at a
premium price - from specialist E&P investor Charlestown Energy, and as
previously noted, on closing of the farm-out for the AREA OFF-1 licence in
Uruguay we will receive US$12.5 million in cash. Against this we have no debt,
our cost base is low, the minimum work program on AREA OFF-1 in Uruguay has
been completed and our share of 3D seismic costs will be carried by Chevron,
the work program for AREA OFF-3 is modest, and we have no unfunded forward
work program commitments. This means that once the AREA OFF-1 farm-out
completes we will have cash reserves more than adequate to ensure ongoing
operations on a "fully-funded" basis for the foreseeable future. This puts our
Company in the best financial position it has been in for many years.
ESG
As I noted in last year's Annual Report, the broad category of activities
generally referred to nowadays as Environment, Social and Governance, or ESG,
are central to everything we do. It is a core value in our business to ensure
that achieving our commercial objectives never comes at the expense of harm to
people or the environment, and that our "social licence to operate" is
maintained intact at all time. We want to be known as a responsible, reliable
operator and a partner / employer of choice.
In 2023, our excellent track record in this all-important area was maintained.
Across all of our operations there were no incidents of note - whether
personal injury, property damage or environmental. We maintained productive
and positive relationships with all relevant Governments and regulatory
bodies, we continued our policy of investing considerably in Company-wide
training programs and ESG awareness activities, and we made a number of
targeted social and welfare contributions in the communities where we operate.
A tangible expression of our record of achievement in this area was the
considerable body of work undertaken in support of renewing our Safe-to-Work
(STOW) accreditation in Trinidad, a regulatory certification granted to only a
few operators in that country. After almost a full year of preparation and
audits this renewal was granted in April 2024, a testament to the strong
culture of workplace health and safety awareness, commitment, accountability
and performance that we have fostered and maintained.
In summary, the Company's excellent ESG performance record continued in 2023,
and everyone at Challenger Energy is 100% aligned to ensure that this
continues into the future.
Outlook
I believe that the outlook for our Company over the coming period is as strong
as it has ever been.
In the next 12 months we will be looking to see a result from efforts to
realise value from our assets in Trinidad, and, as noted, we hope to reach a
resolution in relation to our licences in The Bahamas in the same timeframe.
But, undoubtedly, the key area of focus and value creation for Challenger
Energy going forward will be Uruguay.
There, we expect the AREA OFF-1 farm-out to be finalised in the coming months,
following which we expect that Chevron will begin to rapidly take the project
forward. 3D seismic acquisition may happen as soon as the end of 2024, meaning
that we could see new data for AREA OFF-1 as soon as the middle of 2025,
leading to a decision on exploration well drilling thereafter.
Meanwhile, we will shortly kick off our technical work program for AREA OFF-3,
which will see reprocessing of legacy 2D and 3D seismic, as well as a number
of other work streams similar to those we found leveraging for the AREA OFF-1
farm-out strategy. We will be looking to replicate our AREA OFF-1 farm-out
success for AREA OFF-3, this time with a process we expect will commence in
early-to-mid 2025, with a goal to secure a new partner during 2025/early 2026,
and exploration well drilling thereafter. And, all of this activity in Uruguay
will occur against a backdrop of heightened industry interest, and substantial
offshore exploration work being undertaken by others in Uruguay, northern
Argentina, and southern Brazil - so it will be a busy and exciting time.
In concluding my review of 2023, I would like to take this opportunity to
thank all of our team. We may be a small company, but we have highly-skilled,
committed, and fiercely loyal employees, whose hard work and dedication
deserves recognition. I also wish to express my deep appreciation for the
support we receive from our Board, stakeholders, regulators, suppliers,
contractors and shareholders.
2023 was a period of great progress for Challenger Energy. Now, with the
benefit of the excellent foundations put in place over the past few years, our
task is to realise the value we see in our assets. All of us who work at
Challenger Energy are very much looking forward to doing just that.
Eytan Uliel
Chief Executive Officer
26 June 2024
Challenger Energy Overview
Challenger Energy is an Atlantic-margin focused energy company, with a range
of offshore and onshore oil and gas assets in the region. The Company's shares
are traded on the AIM Market of the London Stock Exchange (AIM: CEG).
The following is a brief summary of key aspect of the Company's assets,
operations and business. Additional information is available on the Company's
website: www.cegplc.com (http://www.cegplc.com) .
Challenger Energy's Uruguay Assets
Challenger Energy principal area of focus is offshore Uruguay, where the
Company has an interest in two blocks: AREA OFF-1 and AREA OFF-3. Together
these represent a total licence holding of approximately 27,800 km(2) (net to
Challenger approximately 19,000 km(2)) - the third largest offshore acreage
holding in Uruguay.
FIGURE 1: OFFSHORE LICENCE HOLDERS, URUGUAY
Uruguay is located on the Southern Atlantic coast of South America, bordering
Brazil to the north and Argentina to the south and west. The country has the
highest per-capita income in South America, and represents an advantaged
operating regime, frequently ranking first in Latin America in measures such
as democracy, anti-corruption, and ease of doing business. Uruguay is also a
leader in providing reliable, sustainable and affordable energy and therefore
has a highly supportive policy environment for exploration and production,
with an emphasis on promoting responsible development of the nation's energy
mix.
Recent conjugate margin discoveries offshore Southwest Africa have renewed
interest in the types of plays present offshore Uruguay. The data and enhanced
technical understanding provided from recent discoveries offshore Namibia has
accelerated the licensing, seismic acquisition, and drilling across the
offshore basins of Uruguay, northern Argentina and southern Brazil. In
particular, developments in offshore Namibia have provided greater confidence
for the potential of a new, prolific petroleum system offshore Uruguay,
including Challenger Energy's blocks.
As at the date of this Annual Report, all blocks offshore Uruguay have been
licenced, with the final block, AREA OFF-3, having being awarded to Challenger
Energy in May 2023. With the exception of the two licences awarded to the
Company, all offshore Uruguayan blocks have been awarded to international oil
and gas majors / national oil companies. The collective work program of other
Uruguay licence holders is estimated to be in excess of $200 million over the
next few years. Additionally, adjacent areas in Brazil's Pelotas Basin,
proximal to Uruguay, were awarded in December 2023 to supermajors and national
oil companies, and licence holders in Argentina have begun undertaking 3D
acquisition and deepwater drilling.
AREA OFF-1
The AREA OFF-1 block is a large block covering approximately 14,557 km(2) and
located approximately 100 kms offshore Uruguay in relatively shallow water
depth (from 80 to 1,000 meters). Challenger Energy bid for the block in May
2020 - this was the first bid by any company in the new Uruguay Open Round. In
June 2020, the Company was awarded the block, with the licence signed
post-Covid on 25 May 2022, and the licence's initial four-year exploration
period commencing on 25 August 2022.
In late 2022, the Company made a decision to both accelerate and expand the
work required to be completed during the first four-year exploration period.
As a result, during the course of 2023 all first period minimum work
obligations were completed, as well as a considerable body of additional
discretionary work. The result of this technical work program was the
identification, delineation and high grading of three materials prospects with
significant resource potential. These prospects have been named Teru Teru,
Anapero and Lenteja, and are summarised as follows:
ESTIMATED EUR
STRATIGRAPHIC AERIEL EXTENT WATER RESERVOIR (mmboe)
PROSPECT DEPOSITIONAL ENVIRONMENT AGE P10/50/90 DEPTH DEPTH P10/Pmean/P50/P90
TERU TERU Slope turbidite to shelf margin wave delta AVO supported - Class I to II Mid to Upper Cretaceous Albian to Campanian 360/210/106 km(2) ~ 800m ~3,800m 1,627/740/547/158
ANAPERO Outer shelf margin stacked sands Upper Cretaceous 304/214/101 km(2) ~ 550m ~3,400m 1,627/670/445/88
AVO supported - Class II Campanian
LENTEJA Lacustrine alluvial syn-rift sealed by regional unconformity Lower Cretaceous Neocomian 246/85/14 km(2) ~ 85m ~4,500m 1,666/576/198/17
On 6th of March 2024, following a formal process, the Company announced that
it has entered into a farm-out agreement with a subsidiary of Chevron for the
AREA OFF-1 block. The key terms of the farm-out agreement are (i) Chevron will
acquire a 60% participating interest in AREA OFF-1 and will take over
operatorship of the block, (ii) Challenger Energy will retain a 40%
non-operating interest in the block, (iii) Challenger Energy will receive
US$12.5 million from Chevron as an entry fee, with these funds available to
support the further development of the Company's business, (iv) Chevron will
carry 100% of Challenger Energy's share of the costs associated with a 3D
seismic campaign on AREA OFF-1 block, up to a maximum of US$15 million (net to
Challenger Energy), and (v) following the 3D seismic campaign, should Chevron
decide to drill an initial exploration well on the AREA OFF-1 block, Chevron
will carry 50% of Challenger Energy's share of costs associated with that
well, up to a maximum of US$20 million (net to Challenger Energy). As at the
date of this Annual Report, formal approval of the farm-in from Uruguayan
regulatory authorities is pending, and is expected to be concluded in the
coming months, so as to facilitate commencement of a 3D seismic campaign on
AREA OFF-1 towards the end of 2024 / early 2025.
AREA OFF-3
The AREA OFF-3 block is a large block covering an area of 13,252 km(2) and
located approximately 75 to 150kms offshore Uruguay in relatively shallow
water depths (from 20 to 1,000 meters), prospects in ~200 meters. Challenger
Energy bid for the block in May 2023 and was awarded the licence in June 2023.
Subsequently, the licence was signed on 7 March 2024, with the initial
four-year exploration period commencing on 7 June 2024. Challenger Energy hold
a 100% working interest in and is the operator of the block.
There has been considerable prior technical work and seismic acquisition on
and adjacent to the area of the AREA OFF-3 block (what is now AREA OFF-3 was
previously held by BP until 2016). That prior activity had identified and
mapped two primary prospects:
PROSPECT
LOCATION
ESTIMATED
P10/P50/P90
AMALIA Straddles the boundary with Shell's AREA OFF-2,
an estimated 30% is contained within AREA OFF-3 EUR
(mmbbl) gross
2,189/980/392
MORPHEUS Entirely contained within AREA
OFF-3
EUR (TCF) gross
-8.96/2.69/0.84
The AREA OFF-3 licence has a modest work commitment in the initial four-year
exploration period, comprising of reprocessing 1,000 kms of legacy 2D seismic
data and undertaking two geotechnical studies. There is no drilling obligation
in the initial four-year exploration period. However, similar to AREA OFF-1,
Challenger Energy's plan during the initial four-year exploration period is to
accelerate and expand the technical work program, with a primary objective
being to reprocess existing 3D seismic data. This is because the Company
considers that the geological prospectivity and petroleum system understanding
has changed drastically since the 2022 Namibian discoveries specifically
regarding the new Cretaceous petroleum system and seismic identification, and
therefore the application of latest 3D reprocessing technology and amplitude
analysis will assist to delineate the extent of the previously identified
plays and their coverage onto AREA OFF-3. The Company is also planning to
pursue an early partnering strategy in the form of a farm-out. As with AREA
OFF-1, the objective is to secure cash and a significant carry in an
accelerated work program.
Trinidad and Tobago Assets
The Republic of Trinidad and Tobago is a Caribbean nation consisting of the
two islands of Trinidad and Tobago, approximately 7 kms offshore from
Venezuela. The nation has a long history of oil and gas activity, both onshore
on the island of Trinidad, and offshore, with some of the world's oldest
hydrocarbon producing fields located in the country.
Challenger Energy holds a 100% interest in, and is the operator of, three
producing fields, all onshore Trinidad. Across these fields, there are a total
of approximately 250 wells, of which approximately 60 are in production at any
given time. Within the fields, regular well workover operations are undertaken
on the existing productive well stock, including well stimulation operations,
reperforations, reactivations and repairs to shut-in wells, as and when
appropriate. Production from the three producing fields - Goudron,
Inniss-Trinity and Icacos, averages approximately 275 - 300 bopd.
Other Assets
The Bahamas: Challenger Energy holds four exploration licences offshore The
Bahamas. In early 2021, the Perseverance-1 exploration well was drilled in
this licence area, but it did not result in a commercial discovery at that
location. However, several other structures and drill targets across the
licence areas remain prospective, and the technical findings from
Perseverance-1 suggest potential in deeper Jurassic horizons. In March 2021,
the Group notified the Government of The Bahamas of its intent to renew the
licences for a third three-year exploration period. This renewal is still
pending. Additionally, the Company is considering various other options for
achieving value from these assets.
Suriname: during 2023, the Company relinquished the Weg Naar Zee licence held
onshore Suriname, and completed a withdrawal from operations in that country.
People and Operations
The Group's registered office is in the Isle of Man. Additionally, the Group
has operational offices in London (United Kingdom), Montevideo (Uruguay), and
San Fernando (Trinidad). The business employs approximately 75 staff, with the
majority being operational staff in Trinidad. To support its active field
operations in Trinidad, the Group owns and operates two workover rigs, one
swabbing rig, and various items of heavy field equipment.
The Company's Board, management team, and staff possess a wide range of skills
and extensive technical and industry experience - profiles of Board and senior
executive members can be found on the Company's website, www.cegplc.com
(http://www.cegplc.com) .
The Company takes great pride in its exemplary HSE&S track record and
strives to be an employer and partner of choice, and to make a valued
contribution to the communities and nations in which it operates.
Environmental, Social & Governance
ESG Philosophy and Management
At Challenger Energy, we believe that pursuing our commercial objectives
should never come at the cost of harm to people, communities, or the
environment. We acknowledge our responsibility and duty of care to our
employees, contractors, suppliers, and the broader communities where we
operate. We take every possible step to ensure the health, wellbeing, and
safety of everyone involved in our projects, with the goal of achieving zero
lost time injuries or incidents.
Challenger Energy is committed to conducting business with integrity and high
ethical standards, and fostering a respectful working environment for all
employees. We support the personal and professional development of our people
and recognise the importance of diversity in our business, including gender,
nationality, faith, and personal background. We value how diversity benefits
our business and how the unique experiences of our employees contribute to a
positive environment within the Group.
Operating in various international locations, we both rely on and impact the
people and institutions in these areas. Our business is part of the societies
in which we operate, and we are committed to being a responsible business and
good corporate citizen, making meaningful and valued contributions to these
communities.
We are acutely aware of the natural environments we operate in and strive to
minimize our impact. The Group is dedicated to responsible environmental
stewardship and aims for zero environmental incidents, spills, or leaks.
Recognising ESG as a core business priority, the Group maintains a structured
Health, Safety, Environment & Security (HSES) Management System. This
system includes a documented set of policies, procedures, and practices, which
are revised and updated regularly, with company-wide application designed to
promote and foster excellence in all relevant HSES areas.
Governance
Challenger Energy operates in the energy sector, which is governed by
stringent laws and regulations imposed by host Governments and international
regulators, and is also subject to intense public scrutiny. Additionally, as
the Group's shares are traded on the AIM Market of the London Stock Exchange,
it is subject to various additional rules and regulations associated with
being a publicly traded entity.
Consequently, the Board is dedicated to upholding the highest standards of
corporate governance at all times.
QCA Code
In accordance with the rules of the AIM Market of the London Stock Exchange,
the Group is required to apply a recognized corporate governance code and
demonstrate its compliance with that code, including any deviations. Since the
Group is not obligated to follow the UK Corporate Governance Code, its
Directors have chosen to apply the QCA Corporate Governance Code (the "QCA
Code") as their standard of measurement.
In accordance with the AIM Rules for Companies, Challenger Energy departs from
the QCA Code in relation to Principle 7 - "Evaluate board performance based on
clear and relevant objectives, seeking continuous improvement." Challenger
Energy's board is small and extremely focused on implementing the Company's
strategy. However, given the size and nature of the Company, the Board does
not consider it appropriate to have a formal performance evaluation procedure
in place, as described and recommended in Principle 7 of the QCA Code. The
Board will closely monitor the situation as and when the Company grows.
The Board and its Committees
The Board meets regularly to discuss and review all aspects of the Group's
activities. A Board Charter has been approved and adopted, outlining the
membership, roles, and responsibilities of the Board. The Board is primarily
responsible for formulating, reviewing, and approving the Group's strategy,
budgets, major capital expenditures, acquisitions, and divestments. The Board
currently consists of the Non-executive Chairman (Iain McKendrick), the Chief
Executive Officer (Eytan Uliel), and three Non-executive Directors (Stephen
Bizzell, Simon Potter and Robert Bose). Iain McKendrick and Stephen Bizzell
are deemed independent by the Board. All Directors have access to the Company
Secretary and the Group's professional advisers. Overall, the Board is
responsible for the long-term success of the Company and providing leadership
to the business including culture, values and ethics and ensuring effective
corporate governance and succession planning. The Board operates in an
accountable open and transparent environment where the views of all Directors
and the actions of Executive Directors can be challenged. The Board is
satisfied it has the appropriate balance of skills and experience on the one
hand, and, independence and knowledge on the other, to enable it to discharge
its respective duties and responsibilities effectively, and that all Directors
have adequate time to fill their roles.
Iain McKendrick has over 30 years of industry experience, holding Board
positions across several listed companies. He was previously with NEO Energy,
was Chief Executive Officer of Ithaca Energy, was Executive Chairman of Iona
Energy, and spent several years with Total, including acting as Commercial
Manager of Colombia. Iain is the Chairman of the Company's Remuneration and
Nomination Committee and a member of the Company's Audit Committee.
Eytan Uliel assumed the position as Chief Executive Officer from 27 May 2021,
having previously served as the Company's Commercial Director since 2014.
Eytan is a finance executive with significant oil and gas industry experience.
He has significant experience in mergers and acquisitions, capital raisings,
general corporate advisory work, oil and gas industry-specific experience in
public market takeovers and transactions, private treaty acquisitions and
farm-in / farm-out transactions. He has held executive roles in various ASX
and SGX listed companies. Prior to working with Challenger Energy, from 2009 -
2014 Eytan was Chief Financial Officer and Chief Commercial Officer of Dart
Energy Limited, an ASX listed company that had unconventional gas assets (coal
bed methane and shale gas) in Australia, Asia and Europe, and Chief Commercial
Officer of its predecessor company, Arrow International Ltd, a Singapore based
company that had unconventional gas asset primarily in Asia and Australia. He
holds a Bachelor of Arts (Political Science) and Bachelor of Laws (LLB) degree
from the University of New South Wales, and was admitted as a solicitor in the
Supreme Court of New South Wales in 1997. Eytan is a member of the Company's
Remuneration Committee, Nomination Committee and the Health, Safety,
Environmental and Security Committee.
Simon Potter was previously the Chief Executive Officer of the Company for
nearly 10 years and oversaw the safe drilling of the Perseverance-1 well in
the Bahamas. Simon assumed the role of a Non-Executive Director in May 2021.
Simon qualified as a geologist with an M.Sc. in Management Science, has over
30 years oil and gas industry and mining sector experience. From the Zambian
Copperbelt to a 20-year career with BP he has held executive roles in
companies managing oil and gas exploration, development and production; gas
processing, sales and transport; LNG manufacture, marketing and contracting in
Europe, Russia, America, Africa and Australasia. On leaving BP, having helped
create TNK-BP, he took up the role of CEO at Hardman Resources where he
oversaw growth of the AIM and ASX listed Company into an oil producer and
considerable exploration success ahead of executing a corporate sale to Tullow
Oil. Simon is a member of the Company's Remuneration Committee, Nomination
Committee and the Health, Safety, Environmental and Security Committee.
Stephen Bizzell has over 25 years' corporate finance and public company
management experience in the resources sector in Australia and Canada with
various public companies. He is the Chairman of boutique corporate advisory
and funds management group Bizzell Capital Partners Pty Ltd. He is also the
Chairman of ASX listed MAAS Group Holdings Ltd and Savannah Goldfields Ltd,
and a Non-executive Director of ASX listed Renascor Resources Limited and
Strike Energy Ltd. He was an Executive Director of ASX listed Arrow Energy Ltd
from 1999 until its acquisition in 2010 by Shell and PetroChina for A$3.5
billion. He was instrumental in Arrow's corporate and commercial success and
its growth from a junior explorer to a large integrated energy company. He was
also a founding director of Bow Energy Ltd until it's A$550 million takeover
and was also a founding director of Stanmore Resources Ltd. Stephen qualified
as a Chartered Accountant and early in his career was employed in the
Corporate Finance division of Ernst & Young and the Corporate Tax division
of Coopers & Lybrand. Stephen is also the Chairman of Challenger Energy
Audit Committee.
Robert Bose is the Managing Member of Charlestown Energy Partners, a private
investment company associated with a New York-based family office that has
been making investments globally in the upstream business since 2016. Robert
is also the Chief Executive Officer and a member of the Board of Directors of
Sintana Energy, Inc., a Toronto Venture listed oil and gas exploration with a
portfolio of licenses in Namibia. Robert is also a non-executive director of
New Zealand Energy, Corp., a company providing gas, gas storage and liquids
solutions to support the domestic energy economy and is also on the Board of
Managers of Black Bayou Energy Hub, a private company developing a gas storage
opportunity on the Gulf Coast of the U.S. Prior to joining Charlestown, Robert
spent 17 years in the Investment Banking Group at Scotiabank, latterly as
Managing Director and Industry Head, Global Power & Utilities. Effective 1
July 2024, Robert will replace Iain McKendrick as the member of the Company's
Audit Committee.
Audit Committee
The Audit Committee of the Board consists of Stephen Bizzell (Chair) and Iain
McKendrick, with input from the Chief Financial Officer as needed. The Audit
Committee is primarily responsible for ensuring the Group's financial
performance is accurately reported and monitored, reviewing the scope and
results of the audit, evaluating its cost-effectiveness, and maintaining the
independence and objectivity of the auditor. Additionally, the Audit Committee
oversees public reporting and the Group's internal controls. A Charter of the
Audit Committee, which defines its membership, roles, and responsibilities,
has been approved and adopted. All members of the Audit Committee have access
to the Company Secretary and the Group's professional advisers, including
direct access to the Group's auditor. The Audit Committee meets regularly and
convened twice in 2023, with all members present at both meetings. Effective 1
July 2024, Robert Bose will replace Iain McKendrick on the Audit Committee.
Renumeration & Nomination Committee
The Remuneration & Nomination Committee consists of Simon Potter (Chair),
Iain McKendrick, and Eytan Uliel. This committee is responsible for
recommending executive remuneration packages, including bonus awards and share
options, to the Board of Directors. It also assists the Board in identifying
and evaluating potential new Directors, ensuring that the size, composition,
and performance of the Board are suitable for the Group's and Company's
activities. Shareholders of the Group ultimately have the responsibility for
determining Board representation. The Remuneration & Nomination Committee
meets as needed and convened once in 2023, with all members present.
Health, Safety, Environmental and Security Committee
The Board has a Health, Safety, Environmental, and Security (HSES) Committee,
currently comprising Iain McKendrick (Chair), Simon Potter, and Eytan Uliel.
The Committee's purpose is to assist the Directors in establishing ESG
strategy, reviewing, reporting, and managing the Group's performance,
assessing compliance with applicable regulations, internal policies, and
goals, and contributing to the Group's risk management processes. The HSES
Working Group reports to the HSES Committee, which meets regularly. In 2023,
the HSES Committee met four times, with all members present at each meeting.
Record of the board meetings
There were 3 formal meetings of the board of the parent entity in the period 1
January 2023 to 31 December 2023. In addition,
there were a number of other ad-hoc gatherings of the Board through the
period.
Internal Control
The Directors acknowledge their responsibility for the Group's system of
internal control and for reviewing its effectiveness.
The system of internal control is designed to manage the risk of failure to
achieve the Group's strategic objectives. It cannot totally
eliminate the risk of failure but will provide reasonable, although not
absolute, assurance against material misstatement or loss.
Going Concern
These financial statements have been prepared on a going concern basis, which
assumes that the Group will continue in
operation for the foreseeable future.
The Group has incurred an operating loss of $19.9 million for the financial
year ended 31 December 2023 (2022: loss of $4.2 million) and the Group's
current liabilities exceeded current assets by approximately $2.9 million as
of 31 December 2023 (2022: $2.0 million), however this includes approximately
$4.1m in respect of taxes and penalties owed in Trinidad and Tobago that the
Group expects to settle by way of offset against future tax refunds or are
derived from notional estimates of tax penalties dating back to 2021 that the
Group does not expect will be levied or assessed with final resolution still
pending with the local tax authorities (refer to note 18 for further details).
At 31 December 2023, the Group had approximately $1.0 million (2022: $2.5
million) in unrestricted cash funding and at the date of authorisation of
these financial statements, the Group continues to have approximately $1.5
million in unrestricted cash funding.
On 6 March 2024, the Group entered into a farm-out agreement with Chevron, a
leading global energy super-major, in relation to the Group's AREA OFF-1
licence offshore Uruguay pursuant to which the Group will receive $12.5
million upfront payment at completion along with Chevron carrying the Group's
share of certain future work programme costs (the "Farm-out"). The Farm-out is
subject to Uruguayan regulatory approval. Management is highly confident that
the requisite regulatory approvals will be forthcoming in the near-term, as
Chevron meets all requirements to operate an energy project in Uruguay, and
the submissions for regulatory approvals were made in consultation with ANCAP,
the Uruguayan regulatory body. In addition, the Group expects $0.3 million of
presently restricted cash (in support of AREA OFF-1 performance bond) to
become unrestricted shortly after the Farm-out completion.
On 18 April 2024 the Group announced that it had entered into a legally
binding term sheet for an investment by Charlestown Energy Partners LLC,
whereby Charlestown will invest £1.5 million in the Group, initially in the
form of a loan, This investment was completed on 28 May 2024 and provides the
Group with finance in the medium term until the completion of the farm-out
agreement with Chevron, and, on completion of the farm-out, the Charlestown
investment will convert into a shareholding of approximately 8.7% in the
Company.
The Directors have thus prepared these financial statements on a going concern
basis, as based on the Group's cash flow forecasts (which include the proceeds
from Charlestown investment and the Farm-out described above), the Group
expects to have adequate financial resources to support its operations for the
next 12 months (and well into the foreseeable future beyond that). In
addition, the Directors note that the Company is a publicly listed company on
a recognised stock exchange, thus affording the Company the ability to raise
capital equity, debt and/or hybrid financing alternatives as and when the need
arises. The Company has a robust track record in this regard, having raised in
excess of US$100 million in equity and alternative financing in the recent
past.
Anti-bribery and Corruption ('ABC')
Challenger Energy enforces a zero-tolerance policy for bribery, corruption, or
unethical conduct in our business. Our policies mandate compliance with
applicable anti-bribery and corruption (ABC) laws, particularly the UK Bribery
Act 2010, as well as all relevant laws in the jurisdictions where we operate.
We have implemented a documented system of ABC policies and procedures that
provide a consistent framework across The Group, ensuring our employees are
aware of potential threats and maintaining appropriate governance of ABC
matters. In 2023, all employees were required to attend mandatory ABC
training, focusing on the most relevant legislation for the Group.
Anti-Money Laundering ('AML')
Challenger is acutely aware of the risks posed by money laundering and
terrorist financing. These criminal activities not only threaten society but
also impact The Group, its partners, shareholders, and staff. The Group
exercises the highest level of vigilance in all its operations to combat these
threats. This vigilance also applies to third-party associates involved with
The Group. Annual AML training is mandatory for all Group staff, and in 2023,
various employees and contractors participated in money laundering training
courses.
Taxation
Depending on the jurisdiction of operation, The Group is subject to various
taxes, including corporate income tax, supplemental petroleum taxes,
royalties, other fiscal deductions, VAT, and payroll taxes. As a responsible
operator and corporate citizen, The Group is committed to complying with all
relevant tax laws in every jurisdiction where we operate. Adhering to tax laws
and regulations is fundamental to our license to operate, and we take this
obligation seriously.
Risk Management
Understanding our principal risks and ensuring that Challenger Energy has the
appropriate controls in place to manage those risks is critical to our
business operations. Managing business risks and opportunities is a key
consideration in determining and then delivering against the Group's strategy.
The Group's approach to risk management is not intended to eliminate risk
entirely, but provides the means to identify, prioritise and manage risks and
opportunities. This, in turn, enables the Group to effectively deliver on its
strategic objectives in line with its appetite for risk.
The Board's Responsibility for Risk Management
The board has overall responsibility for ensuring the Group's risk management
and internal control frameworks are appropriate and are embedded at all levels
throughout the organisation. Principal risks are reviewed by the board and are
specifically discussed in relation to setting the Group strategy, developing
the business plan to deliver that strategy and agreeing annual work programmes
and budgets. See "Principal Risks and Uncertainties" section below and the
mitigation steps taken to minimise these risks.
Principal risks and uncertainties
The principal risks facing the Group together with a description of the
potential impacts, mitigation measures and the appetite for the risk are
presented below. The analysis includes an assessment of the potential
likelihood of the risks occurring and their potential impact. Identified risks
are segregated between those that we can influence and those which are outside
our control. Where we can influence risks, we have more control over outcomes.
Where risks are external to the business, we focus on how we control the
consequences of those risks materialising.
RISKS THAT WE CAN INFLUENCE
1. Health, safety and environment (HSE)
Oil and gas exploration, development and production activities can be complex
and are physical in nature. HSE risks cover many
areas including major accidents, personal health and safety, compliance with
regulations and potential environmental harm.
Potential impact: High Probability: Low
Risk Appetite
The Group has a very low appetite for risks associated with HSE and strives to
achieve a zero-incident rate.
Mitigation
The Group strives to ensure the safety of its employees, contractors and
visitors. We are very conscious of the natural
environment that we operate in and seek to minimise our environmental impact
and footprint.
2. Exploration, development and production
The ultimate success of the Group is based on its ability to maintain and grow
production from existing assets and to create value
through exploration activity across the existing portfolio together with
selective acquisition activity to grow the asset portfolio.
Potential impact: High Probability: Moderate
Risk appetite
The Group's current production is derived from later-life production assets
that are in the latter portion of the production decline curve. The
development of later life assets can be complex and technically challenging.
This can expose the Group to higher levels of risk, particularly in
stimulating existing wells through workover or enhanced oil recovery
techniques which may, due to their nature, not be successful or may compromise
existing production. Identifying locations for optimal locations new infill
wells that do not interfere with existing production can be challenging.
The Group has some tolerance for this risk and acknowledges the need to have
effective controls in place in this area.
Mitigation
The production team responsible for operating the Group's assets is very
experienced in the industry and in the management, workover and enhancement of
the Group's assets. In addition, the Group has built a trusted network of
service providers who are similarly familiar with the assets and who support
production enhancing activity including targeted recompletions and other well
interventions to further extend the productive life of the Group's well stock.
3. Reserves and resources
The estimation of oil and gas reserves and resources involves a high level of
subjective judgment based on available geological, technical and economic
information.
Potential impact: Medium Probability: Low
Risk appetite
The Group has a strong focus on subsurface analysis. We employ industry
technical specialists and qualified reservoir engineers and geologists who
work closely with our operational teams who are responsible for delivering
asset performance.
The Group tolerates some risk related to the estimation of reserves and
resources.
Mitigation
Reserve and resource volumes are assessed periodically using the Petroleum
Resource Management System (PRMS) developed by the Society of Petroleum
Engineers. An external assessment of reserve volumes may also be undertaken
periodically by an independent petroleum engineering firm. CEG has staff and
consultants who are qualified reservoir engineer with significant
international experience.
4. Portfolio concentration
The Group's producing assets are concentrated in Trinidad and are principally
characterised as later-life assets. This concentrates production risk in a
single jurisdiction and in an asset group with a particular age and production
profile
Potential impact: Medium Probability: High
Risk appetite
The principal location of the Group's producing assets and their age profile
places emphasis on the Group's ability to successfully
maintain existing production in Trinidad. The Group has a moderate appetite
for this risk.
Mitigation
The Group is continuously seeking to selectively add new development or
production onshore Trinidad or elsewhere in the Atlantic margin through new
licence applications, M&A activity or partnering arrangements with service
providers.
Progressing exploration and eventual development of Uruguay, if successful,
will similarly mitigate this risk over time.
5. Financing
Oil and gas exploration, development and production activity are capital
intensive. The Group currently generates modest levels of cash from operations
and relies on investment capital to enhance the asset base and, in turn,
production and consequential cash generation.
Potential impact: High Probability: Moderate
Risk appetite
The Group has a low appetite for financing risk. The inability to fund
financial commitments, including licence obligations, could significantly
delay the development of the Group's assets and consequent value creation.
Financial or operational commitments are often a pre-condition to the grant of
a licence. The Group's inability to satisfy these could result in financial
penalty and/or termination of licences.
Mitigation
The Group has a strong track record over many years of successfully raising
finance to fund its activities as and when required.
6. Bribery and corruption
There is a risk that third parties or staff could be encouraged to become
involved in corrupt or questionable practices. Transparency International's
rankings (out of 180 countries) and respective scores (out of a maximum of 100
points) on their 2022 Corruption Perceptions Index for the jurisdictions where
the Group has presence are as below:
Jurisdiction 2023 2023
(2022) Rank (2022) score
Uruguay 16 (14) 73 (74)
Trinidad and Tobago 76 (77) 42 (42)
The Bahamas 30 (30) 64 (64)
United Kingdom 20 (18) 71 (73)
Potential impact: High Probability: Moderate
Risk appetite
The Group has a zero-tolerance policy regarding bribery and corruption.
Mitigation
The Group, its board and management have an established anti-bribery and
corruption (ABC) policy that requires all new hires to confirm that they have
read and understood the contents and personal requirements of the policy. The
Group ensures that our third-party contractors and advisers follow our
procedures and policies related to ABC. Annual ABC training and briefings are
carried out.
RISKS BEYOND OUR INFLUENCE
7. Commodity prices
The Group is exposed to commodity price risk in relation to sales of crude
oil.
Potential impact: High Probability: Moderate
Risk appetite
The Group has a moderate appetite for commodity price risk. A material decline
in oil prices could adversely affect the Group's profitability, cash flow,
financial position, and ability to invest.
Mitigation
All the Group's production in Trinidad is sold to Heritage under the terms of
the respective production licences and the Group is fully exposed to adverse
commodity price fluctuation (and also conversely benefits from favourable
commodity price movement).
The Group does not currently use hedging instruments to mitigate oil price
risk as the volumes are relatively small and significant volatility observed
in crude prices in the recent years coupled with oil futures curve
backwardation make it difficult to assess effectiveness of a hedge. The Group
monitors the oil and gas benchmark prices, principally WTI and Brent Crude,
and may consider enter hedging arrangements if market conditions and financial
and risk analysis suggest that price risk is lowered by doing so.
8. Demand/ limited sales routes
All the Group's current production is derived from its Trinidad assets and
sold to a single customer, Heritage Petroleum Company Limited, the state-owned
oil and gas company.
Potential impact: High Probability: Low
Risk appetite
Demand can be negatively affected by economic conditions in Trinidad and
globally. The Group accepts demand risk related to its crude oil production.
Mitigation
All the Group's production is sold to Heritage as required under the terms of
the licence agreements with Heritage. There is no history of Heritage refusing
delivery of crude produced by the Group. The Group accepts this potential
risk.
9. Fiscal and political
The Group's operations are located in Uruguay and Trinidad and Tobago, with
legacy assets in The Bahamas, and the Group is therefore exposed to both
in-country fiscal and political risk.
Potential impact: High Probability: Moderate
Appetite
The Group accepts a modest amount of fiscal risk. The Group is exposed to
currency risk resulting from fluctuations between currencies in various
jurisdictions of operation, and in particular between the US Dollar (in which
most expenses are denominated) and the Pound Sterling (as a significant amount
of the Group's cash holdings are denominated in Pound Sterling). Currency
hedging instruments are not used.
Mitigation
The Group closely monitors fiscal and political situation in the jurisdictions
it operates in with a view to identifying and minimising the downside risk
presented by changes in fiscal and political circumstances. While the Group
has not hedged its currency exposure in the past, the Group closely monitors
currency fluctuations with a view to assessing potential downside risk
vis-à-vis foreign currency requirements (and the timing thereof) so as to
determine the efficacy of a potential hedge. The Group monitors political risk
and political developments of the countries of its operations and considers
the structure and operation of the respective governments in each of the
jurisdictions of its operations to present low risk to the Group. Further, the
Group interacts with relevant Governments, Government Ministries and Agencies,
and the state-owned oil and gas companies in the jurisdictions in which it
operates. The Group has no exposure to Russian oil production, and recently
enacted sanctions have had no impact on the Group's business or operations.
Directors' Report
The Company's Directors present their report and audited financial statements
of the Company and the consolidated group consisting of Challenger Energy
Group PLC ("Challenger Energy" or "the Company") and the entities it
controlled (the "Group") at the end of, or during, the financial year ended 31
December 2023.
Directors
The following persons were Directors of the Company during the financial year
under review:
Iain McKendrick
Eytan Uliel
Simon Potter
Stephen Bizzell
On 28 May 2024 the Group announced that Mr Robert Bose joined the Board
following the completion of the investment in the Company by Charlestown
Energy Partners LLC.
Principal Activity
The principal activity of the Group and the Company consists of oil & gas
exploration, appraisal, development and production, in Uruguay, Trinidad and
Tobago and The Bahamas.
Results and dividends
The results of the Group for the year are set out on page 25 and show a loss
for the year ended 31 December 2023 of $13,421,000 (2022: profit of
$4,382,000). The total comprehensive loss for the year of $10,986,000 (2022:
loss of $1,360,000) has been transferred to the retained deficit. The results
include an impairment charge of intangible and tangible assets in Trinidad and
Suriname totaling $12,957,000 (2022: $2,201,000) which includes a full write
down of goodwill of $4,610,000 (2022: nil).
The Directors do not recommend payment of a dividend (2022: nil).
Significant Shareholders
The following tables represent shareholdings of 3% or more notified to the
Company at 31 December 2023: Top shareholders (by parent company)
Shareholder 31-Dec-23 %
Hargreaves Lansdown Asset Management 1,311,320,999 12.50
Bizzell Capital Partners 914,633,600 8.72
Choice Investments (Dubbo) Pty Ltd 837,000,000 7.98
Mr Eytan M Uliel 606,121,613 5.78
Mr Mark Carnegie 560,000,000 5.34
Rookharp Capital Pty Ltd 528,000,000 5.03
Interactive Investor 500,026,349 4.76
GP (Jersey) Ltd 465,904,219 4.44
Merseyside Pension Fund 417,350,000 3.98
Mr Baktash Manavi 388,553,500 3.70
RAB Capital 365,900,000 3.49
Halifax Share Dealing 317,091,720 3.02
TOTAL 7,211,902,000 68.74
Directors' Shareholding and Options
The interests in the Company at balance sheet date of all Directors who hold
or held office on the Board of the Company at the year-end and subsequent to
year end are stated below.
Director Number of Shares Number of Options
31-Dec-23 31-Dec-23
Iain McKendrick 50,000,000 112,000,000
Stephen Bizzell 51,189,286 74,000,000
Simon Potter 71,462,807 74,000,000
Eytan Uliel 606,121,613 340,000,000
On 28 May 2024 the Group announced that Mr Robert Bose joined the Board
following the completion of an investment in the Company by Charlestown Energy
Partners [[C.
Record of Board Meetings
There were 3 board meetings of the parent entity of the Group during the
financial year.
Director Number of Board Meetings Number of Board Meetings Eligible to Attend
Attended
Eytan Uliel 3 3
Simon Potter 3 3
Stephen Bizzell 3 3
Iain McKendrick 3 3
In addition to the Board Meetings, there were a number of informal gatherings
of the Board to discuss various items during the period.
Statement of Directors' Responsibilities in
respect of the financial statements
The Directors are responsible for preparing the Annual Report and the
Financial Statements in accordance with applicable Isle of Man law and
regulation.
Company law requires the Directors to prepare financial statements for each
financial year. The Directors have elected to prepare the Group and Company
financial statements in accordance with International Financial Reporting
Standards ("IFRSs").
The financial statements are required by law to give a true and fair view of
the state of affairs of the Group and the Company and of the profit or loss of
the Group for that period.
In preparing the financial statements, the Directors are required to:
· select suitable accounting policies and then apply them
consistently;
· state whether IFRSs have been followed, subject to any
material departures disclosed and explained in the financial statements;
· make judgements and accounting estimates that are reasonable
and prudent; and
· prepare the financial statements on the going concern basis
unless it is inappropriate to presume that the Group and the Company will
continue in business.
The Directors are responsible for keeping proper accounting records that are
sufficient to show and explain the Group and Company's transactions and
disclose with reasonable accuracy at any time the financial position of the
Group and the Company and to enable them to ensure that the financial
statements comply with the Isle of Man Companies Acts 1931 to 2004. They are
also responsible for safeguarding the assets of the Group and the Company and
hence for taking reasonable steps for the prevention and detection of fraud
and other irregularities. The Directors are responsible for the maintenance
and integrity of the Company's website. Legislation in the Isle of Man
governing the preparation and dissemination of financial statements may differ
from legislation in other jurisdictions.
On behalf of the Board
Eytan Uliel
Director
26 June 2024
Independent auditor's report to the members of Challenger Energy Group PLC
Opinion
We have audited the financial statements of Challenger Energy Group PLC (the
"Company") and its subsidiaries (the "Group"), which comprise the Consolidated
Statement of Comprehensive Income, Consolidated and Company Statements of
Financial Position, Consolidated and Company Statements of Cash Flows and
Consolidated and Company Statements of Changes in Equity for the year ended 31
December 2023, and the related notes to the financial statements, including a
summary of material accounting policies.
The financial reporting framework that has been applied in the preparation of
the financial statements is applicable law and International Financial
Reporting Standards (IFRS).
In our opinion, Challenger Energy Group PLC's consolidated and company
financial statements:
· give a true and fair view in accordance with IFRS of the
assets, liabilities and financial position of the Group and Company as at 31
December 2023, and of the Group's financial performance and the Group and
Company cash flows for the year then ended; and
· have been properly prepared in accordance with the
requirements of the Isle of Man Companies Acts of 1931 to 2004.
Basis for opinion
We conducted our audit in accordance with International Standards on Auditing
(UK) ('ISAs (UK)') and applicable law. Our responsibilities under those
standards are further described in the 'Responsibilities of the auditor for
the audit of the financial statements' section of our report. We are
independent of the Group and Company in accordance with the ethical
requirements that are relevant to our audit of the financial statements in the
Isle of Man, including the FRC's Ethical Standard and the ethical
pronouncements established by Chartered Accountants Ireland, applied as
determined to be appropriate in the circumstances for the entity. We have
fulfilled our other ethical responsibilities in accordance with these
requirements. We believe that the audit evidence we have obtained is
sufficient and appropriate to provide a basis for our opinion.
Conclusions relating to going concern
In auditing the financial statements, we have concluded that the directors'
use of going concern basis of accounting in the preparation of the financial
statements is appropriate. Our evaluation of the validity of the directors'
assessment of the Group and Company's ability to continue to adopt the going
concern basis of accounting included:
· verifying the mathematical accuracy of management's cash flow
forecast and agreeing the opening cash position;
· assessing management's underlying cash flow projections for
the Group for the period to December 2025 and evaluating and challenging the
assumptions including production, prices and operating expenditure. In doing
so we compared production forecasts to historical trends and considered the
price assumptions against consensus market prices and historical prices. We
compared forecast costs with historical expenditure and to other external and
internal sources, including the impairment assessments, where appropriate;
· assessing and validating the impact of post year end cash
inflow sources including the proceeds from capital raising and farm-out
payment related to a 60% interest in the Area Off-1 block;
· assessing management's ability to take mitigating actions, if
required; and
· assessing the completeness and appropriateness of
management's going concern disclosures in the financial statements.
Based on the work we have performed, we have not identified any material
uncertainties relating to events or conditions that, individually or
collectively, may cast significant doubt on the Group and Company's ability to
continue as a going concern for a period of at least twelve months from the
date when the financial statements are authorised for issue.
We have nothing material to add or draw attention to in relation to the
directors' statement in the financial statements about whether the directors
considered it appropriate to adopt the going concern basis of accounting in
preparing the financial statements.
Our responsibilities and the responsibilities of the directors with respect to
going concern are described in the relevant sections of this report.
Key audit matters
Key audit matters are those matters that, in our professional judgement, were
of most significance in our audit of the financial statements of the current
financial period and include the most significant assessed risks of material
misstatement (whether or not due to fraud) we identified, including those
which had the greatest effect on: the overall audit strategy, the allocation
of resources in the audit, and the directing of efforts of the engagement
team. These matters were addressed in the context of our audit of the
financial statements as a whole, and in forming our opinion thereon, and
therefore we do not provide a separate opinion on these matters.
Overall audit strategy
We designed our audit by determining materiality and assessing the risks of
material misstatement in the financial statements. In particular, we looked at
where the directors made subjective judgements, for example, in respect of
significant accounting estimates that involved making assumptions and
considering future events that are inherently uncertain. We also addressed the
risk of management override of internal controls, including evaluating whether
there was any evidence of potential bias that could result in a risk of
material misstatement due to fraud.
Based on our considerations as set out below, our areas of focus included:
· Valuation of the Group's intangible exploration and evaluation
assets;
· Going concern; and
· Valuation of the Group's tangible oil and gas assets.
How we tailored the audit scope
Challenger Energy Group Plc is the holders of several oil & gas
exploration and production licences located in Uruguay, Trinidad &
Tobago and The Bahamas.
Our Group audit was scoped by obtaining an understanding of the Group and its
environment, including the Group's system of internal control and assessing
the risks of material misstatement in the financial statements. We also
addressed the risk of management override of internal controls, including
assessing whether there was evidence of bias by the directors that may have
represented a risk of material misstatement.
We performed an audit of the complete financial information of four
components, audit of one or more classes of transactions of two components
which includes the assessment of impairment of intangible exploration and
evaluation assets and performed audit procedures on specific balances for a
further four components. The remaining components of the Group were considered
non-significant and these components were subject to analytical review
procedures.
Components represent business units across the Group considered for audit
scoping purposes.
Materiality and audit approach
The scope of our audit is influenced by our application of materiality. We set
certain quantitative thresholds for materiality. These, together with
qualitative considerations, such as our understanding of the entity and its
environment, the history of misstatements, the complexity of the Group and the
reliability of the control environment, helped us to determine the scope of
our audit and the nature, timing and extent of our audit procedures and to
evaluate the effect of misstatements, both individually and on the financial
statements as a whole.
Based on our professional judgement, we determined materiality for the Group
and Company at 0.75% of total assets at 31 December 2023. We have applied this
benchmark because the main objective of the Group is to utilise its existing
oil and gas assets and exploration and evaluation assets to provide investors
with returns on their investments.
We have set performance materiality for the Group and Company at 65% of
materiality, having considered business risks and fraud risks associated with
the entity and its control environment. This is to reduce to an appropriately
low level the probability that the aggregate of uncorrected and undetected
misstatements in the financial statements exceeds materiality for the
financial statements as a whole.
We agreed with the audit committee and directors that we would report to them
misstatements identified during our audit above 2.5% of Group materiality and
3% of Company materiality, as well as misstatements below that amount that, in
our view, warranted reporting for qualitative reasons.
Significant matters identified
The risks of material misstatement that had the greatest effect on our audit,
including the allocation of our resources and effort, are set out below as
significant matters together with an explanation of how we tailored our audit
to address these specific areas in order to provide an opinion on the
financial statements as a whole. This is not a complete list of all risks
identified by our audit.
We completed our planned audit procedures, with no exceptions noted.
Other information
Other information comprises information included in the annual report, other
than the financial statements and our auditor's report thereon, including the
Chief Executive Officer's Report to the Shareholders and Directors' Report.
The directors are responsible for the other information. Our opinion on the
financial statements does not cover the other information and, except to the
extent otherwise explicitly stated in our report, we do not express any form
of assurance conclusion thereon.
In connection with our audit of the financial statements, our responsibility
is to read the other information and, in doing so, consider whether the other
information is materially inconsistent with the financial statements or our
knowledge obtained in the audit, or otherwise appears to be materially
misstated. If we identify such material inconsistencies in the financial
statements, we are required to determine whether there is a material
misstatement in the financial statements or a material misstatement of the
other information. If, based on the work we have performed, we conclude that
there is a material misstatement of this other information, we are required to
report that fact.
We have nothing to report in this regard.
Matters on which we are required to report by exception
We have nothing to report in respect of the following matters where the
Companies Acts 1931 to 2004 require us to report to you if, in our opinion:
· the Group and Company has not kept proper books of account, or if
proper returns adequate for our audit have not been received from branches not
visited by us; or
· the financial statements are not in agreement with the books of
account and returns; or
· the financial statements do not contain particulars as to loans
to, and remuneration of, Directors; or
· we have not received all the information and explanations which
are necessary for the purposes of our audit.
Responsibilities of management and those charged with governance for the
financial statements
As explained more fully in the Statement of Directors' Responsibilities,
management is responsible for the preparation of the financial statements
which give a true and fair view in accordance with IFRS, and for such internal
control as directors determine necessary to enable the preparation of
financial statements are free from material misstatement, whether due to fraud
or error.
In preparing the financial statements, management is responsible for assessing
the Group and Company's ability to continue as a going concern, disclosing, as
applicable, matters related to going concern and using the going concern basis
of accounting unless management either intends to liquidate the Group or
Company or to cease operations, or has no realistic alternative but to do so.
Those charged with governance are responsible for overseeing the Group and
Company's financial reporting process.
Responsibilities of the auditor for the audit of the financial statements
The objectives of an auditor are to obtain reasonable assurance about whether
the financial statements as a whole are free from material misstatement,
whether due to fraud or error, and to issue an auditor's report that includes
their opinion. Reasonable assurance is a high level of assurance, but is not a
guarantee that an audit conducted in accordance with ISAs (UK) will always
detect a material misstatement when it exists. Misstatements can arise from
fraud or error and are considered material if, individually or in the
aggregate, they could reasonably be expected to influence the economic
decisions of users taken on the basis of these financial statements.
A further description of an auditor's responsibilities for the audit of the
financial statements is located on the Financial Reporting Council's website
at: www.frc.org.uk/auditorsresponsibilities
(http://www.frc.org.uk/auditorsresponsibilities) . This description forms part
of our auditor's report.
Explanation as to what extent the audit was considered capable of detecting
irregularities, including fraud
Irregularities, including fraud, are instances of non-compliance with laws and
regulations. We design procedures in line with our responsibilities, outlined
above, to detect material misstatements in respect of irregularities,
including fraud. Owing to the inherent limitations of an audit, there is an
unavoidable risk that material misstatement in the financial statements may
not be detected, even though the audit is properly planned and performed in
accordance with the ISAs (UK). The extent to which our procedures are capable
of detecting irregularities, including fraud is detailed below.
Based on our understanding of the Group and industry, we identified that the
principal risks of non-compliance with laws and regulations related to
compliance with AIM Listing Rules, Data Privacy law, Employment Law,
Environmental Regulations, Health & Safety, and we considered the extent
to which non-compliance might have a material effect on the financial
statements. We also considered those laws and regulations that have a direct
impact on the preparation of the financial statements such as the local law,
Isle of Man Companies Act 1931 to 2004 and local tax legislations. The Audit
engagement partner considered the experience and expertise of the engagement
team to ensure that the team had appropriate competence and capabilities to
identify or recognise non-compliance with the laws and regulation. We
evaluated management's incentives and opportunities for fraudulent
manipulation of the financial statements (including the risk of override of
controls), and determined that the principal risks were related to posting
inappropriate journal entries to manipulate financial performance and
management bias through judgements and assumptions in significant accounting
estimates, in particular in relation to significant one-off or unusual
transactions. We apply professional scepticism through the audit to consider
potential deliberate omission or concealment of significant transactions, or
incomplete/inaccurate disclosures in the financial statement.
The group engagement team shared the risk assessment with the component
auditors so that they could include appropriate audit procedures in response
to such risks in their work.
In response to these principal risks, our audit procedures included but were
not limited to:
· enquiries of management, board and audit committee on the policies
and procedures in place regarding compliance with laws and regulations,
including consideration of known or suspected instances of non-compliance and
whether they have knowledge of any actual, suspected or alleged fraud;
· inspection of the Group and Company's regulatory and legal
correspondence and review of minutes of board and audit committee meetings
during the year to corroborate inquiries made;
· gaining an understanding of the entity's current activities, the
scope of authorisation and the effectiveness of its control environment to
mitigate risks related to fraud;
· discussion amongst the engagement team in relation to the
identified laws and regulations and regarding the risk of fraud, and remaining
alert to any indications of non-compliance or opportunities for fraudulent
manipulation of financial statements throughout the audit;
· identifying and testing journal entries to address the risk of
inappropriate journals and management override of controls;
· designing audit procedures to incorporate unpredictability around
the nature, timing or extent of our testing;
· challenging assumptions and judgements made by management in their
significant accounting estimates, including impairment assessment of
intangible exploration and evaluation assets, tangible oil and gas assets,
investment in subsidiaries and amounts owed by subsidiary undertakings;
· review of the financial statement disclosures to underlying
supporting documentation and inquiries of management; and
· requesting information from component auditors on instances of
non-compliance with laws or regulations that could give rise to a material
misstatement of the group financial statements.
The primary responsibility for the prevention and detection of irregularities
including fraud rests with those charged with governance and management. As
with any audit, there remains a risk of non-detection or irregularities, as
these may involve collusion, forgery, intentional omissions,
misrepresentations or override of internal controls.
The purpose of our audit work and to whom we owe our responsibilities
This report is made solely to the company's members, as a body, in accordance
with Section 15 of the Companies Act 1982. Our audit work has been undertaken
so that we might state to the company's members those matters we are required
to state to them in an auditor's report and for no other purpose. To the
fullest extent permitted by law, we do not accept or assume responsibility to
anyone other than the company and the company's members as a body, for our
audit work, for this report, or for the opinions we have formed.
Grant Thornton
Chartered Accountants & Statutory Auditors
13-18 City Quay
Dublin 2
Ireland
Consolidated Statement of Comprehensive
Income
For the year ended 31 December 2023
Note Year ended 31 December 2023 $ 000's Year ended 31 December 2022 $ 000's
Continuing operations
Net petroleum revenue 2 3,588 4,266
Cost of sales (4,162) (4,737)
Gross loss (574) (471)
Administrative expenses 3 (4,362) (8,027)
Impairment 3/10/11 (12,957) (2,201)
Operating foreign exchange (losses)/gains (1,969) 6,458
Operating loss (19,862) (4,241)
Other income 429 8,743
Finance (costs)/income, net 9 (99) 1,675
(Loss)/profit before taxation (19,532) 6,177
Income tax expense 5 (30) (28)
(Loss)/profit for the year from continuing operations (19,562) 6,149
Discontinued operations
Profit/(loss) after tax for the year from discontinued operations 14 6,141 (1,767)
(Loss)/profit for the year attributable to equity holders of the parent (13,421) 4,382
company
Other comprehensive income
Exchange differences on translation of foreign operations 2,435 (5,742)
Other comprehensive income/(expense) for the year net of taxation 2,435 (5,742)
Total comprehensive expense for the year attributable to (10,986) (1,360)
equity holders of the parent company
(Loss)/earnings per share (cents) 8
Basic (loss)/earnings per share
- From continuing operations (0.20) 0.08
- From discontinued operations 0.06 (0.03)
Total (0.14) 0.05
Diluted earnings (loss) per share
- From continuing operations - 0.07
- From discontinued operations - (0.02)
Total - 0.05
The accompanying accounting policies and notes form an integral part of these
financial statements. Refer to note 28 for the Company's comprehensive
income/(expense) for the year.
Consolidated Statement of Financial Position
At 31 December 2023
Note At 31 December 2023 $ 000's At 31 December 2022 $ 000's
Assets
Non-current assets
Intangible exploration and evaluation assets 10 95,726 94,660
Goodwill 10 - 4,610
Tangible assets 11 9,734 19,556
Right of use assets 12 - -
Escrow and abandonment funds 15 1,601 1,532
Deferred tax asset 5 4,637 7,375
Total non-current assets 111,698 127,733
Current assets
Trade and other receivables 15 3,202 2,721
Inventories 16 280 165
Restricted cash 17 825 824
Cash and cash equivalents 20 1,005 2,453
Total current assets 5,312 6,163
Assets held for sale 14 - 2,591
Total assets 117,010 136,487
Liabilities
Non-current liabilities
Provisions 21 (5,669) (5,545)
Deferred tax liability 5 (4,707) (7,415)
Total non-current liabilities (10,376) (12,960)
Current liabilities
Trade and other payables 18 (8,182) (8,099)
Lease liabilities 19 - (22)
Borrowings 20 - -
Total current liabilities (8,182) (8,121)
Liabilities directly associated with the assets held for sale 14 - (6,449)
Total liabilities (18,558) (27,530)
Net assets 98,452 108,957
Shareholders' equity
Called-up share capital 22 2,753 2,540
Share premium reserve 22 180,507 180,240
Share based payments reserve 23 5,636 5,635
Retained deficit (109,672) (96,999)
Foreign exchange reserve (4,056) (5,743)
Convertible debt option reserve 20 - -
Other reserves 22 23,284 23,284
Total equity attributable to equity holders of the parent company 98,452 108,957
The accompanying accounting policies and notes form an integral part of these
financial statements. Refer to note 28 for the Company's comprehensive
income/(expense) for the year.
These financial statements were approved and authorised for issue by the Board
of Directors on 26 June 2024 and signed on its behalf by:
Eytan Uliel Iain
McKendrick
Director
Director
Company Statement of Financial Position
At 31 December 2023
Note At 31 December 2023 $ 000's At 31 December 2022 $ 000's
Assets
Non-current assets
Property, plant and equipment 11 5 47
Right of use assets 12 - -
Investment in subsidiaries 13 43,650 50,940
Trade and other receivables 15 114,903 113,600
Total non-current assets 158,558 164,587
Current assets
Trade and other receivables 15 165 292
Restricted cash 17 525 524
Cash and cash equivalents 594 2,174
Total current assets 1,284 2,990
Total assets 159,842 167,577
Liabilities
Non-current liabilities
Borrowings 20
Total non-current liabilities - -
Current liabilities
Trade and other payables 18 (1,978) (1,124)
Lease liabilities 19 - -
Borrowings 20 - -
Total current liabilities (1,978) (1,124)
Total liabilities (1,978) (1,124)
Net assets 157,864 166,453
Shareholders' equity
Called-up share capital 22 2,753 2,540
Share premium reserve 22 180,507 180,240
Share based payments reserve 23 5,266 5,265
Retained deficit (60,197) (51,127)
Convertible debt option reserve 20 - -
Other reserve 22 29,535 29,535
Total equity attributable to equity holders of the parent company 157,864 166,453
The accompanying accounting policies and notes form an integral part of these
financial statements.
These financial statements were approved and authorised for issue by the Board
of Directors on 26 June 2024 and signed on its behalf by:
Eytan Uliel Iain
McKendrick
Director
Director
Consolidated Statement of Cash Flows
For the year ended 31 December 2023
Company Statement of Cash Flows
For the year ended 31 December 2023
Year ended 31 December 2023 $ 000's Year ended 31 December 2022 $ 000's
Cash flows from operating activities
(Loss)/Profit before taxation (9,070) 1,330
Decrease/(increase) in trade and other receivables 127 (540)
Decrease in trade and other payables (155) (1,473)
Depreciation (notes 11 and 12) 12 35
Provision for doubtful/(recovery) of intercompany receivable (161) 1,948
Impairment of investment in subsidiaries 7,300 -
Loss on disposal of property, plant and equipment 35 -
Share settled payments 102 1,173
Other income - (6,639)
Finance (income)/costs, net 94 (1,735)
Foreign exchange loss on operating activities (217) 786
Share based payments (note 23) 1 323
Net cash outflow from operating activities (1,932) (4,792)
Cash flows from investing activities
Payments to acquire tangible assets (note 11) (5) (9)
Increase in restricted cash (1) (467)
Proceeds from disposal of subsidiaries (note 14) 1,900 -
Advances to and payments on behalf of group companies (note 26) (1,750) (2,527)
Net cash inflow/(outflow) from investing activities 144 (3,003)
Cash flows from financing activities
Issue of ordinary share capital - 9,114
Principle elements of lease payments (note 19) - (14)
Payment of finance costs (6) (2)
Proceeds of borrowings (note 20) 636 -
Repayment of borrowings (note 20) (432) -
Net cash inflow from financing activities 198 9,098
Net (decrease)/increase in cash and cash equivalents (1,590) 1,303
Effects of exchange rate changes on cash and cash equivalents 10 (43)
Cash and cash equivalents at beginning of year 2,174 914
Cash and cash equivalents at end of year 594 2,174
The accompanying accounting policies and notes form an integral part of these
financial statements.
Statement of Changes in Equity - the Company
For the year ended 31 December 2023
Called up share capital $ 000's Share premium reserve $ 000's Share based payments reserve $ 000's Retained deficit $ 000's Convertible Other Total
debt option
reserve
Equity
$ 000's
$ 000's
reserve
$ 000's
Company
At 1 January 2022 218 171,734 4,942 (52,457) 114 29,535 154,086
Profit for the year - - - 1,330 - - 1,330
Total comprehensive expense - - - 1,330 - - 1,330
Share capital issued 2,322 8,506 - - - - 10,828
Realisation of conversion
feature (note 20) - - - - (114) - (114)
Share based payments - - 323 - - - 323
Total contributions by 2,322 8,506 323 - (114) - 11,037
and distributions to
owners of the Company
At 31 December 2022 2,540 180,240 5,265 (51,127) - 29,535 166,453
Loss for the year - - - (9,070) - - (9,070)
Total comprehensive expense - - - (9,070) - - (9,070)
Share capital issued 213 267 - - - - 480
Share based payments - - 1 - - - 1
Total contributions by 213 267 1 - - - 481
and distributions to
owners of the Company
At 31 December 2023 2,753 180,507 5,266 (60,197) - 29,535 157,864
31
The accompanying accounting policies and notes form an integral part of these financial statements.
Notes to the financial statements for the year
ended 31 December 2023
1 Summary of material accounting policies
1.01 General information and authorisation of financial statements
Challenger Energy Group PLC (the "Company") and its subsidiaries (together,
the "Group") is the holders of several oil & gas
exploration and production licences located in Uruguay, Trinidad & Tobago
and The Bahamas.
The Company is a limited liability company incorporated and domiciled in the
Isle of Man. The address of its registered office is The Engine House,
Alexandra Road, Castletown, Isle of Man IM9 1TG. The Company's review of
operations and principal activities is set out in the Directors' Report. See
note 13 to the financial statements for details of the Company's principal
subsidiaries.
The accounting reference date of the Company is 31 December.
1.02 Statement of compliance with IFRS
The Group's financial statements have been prepared in accordance with
International Financial Reporting Standards (IFRS). The Company's financial
statements have been prepared in accordance with IFRS and as applied in
accordance with the provisions of the Isle of Man Companies Acts 1931 to 2004.
As permitted by part 1 Section 3(5) of the Isle of Man Companies Act 1982, the
Company has elected not to present its own Statement of Comprehensive Income
for the year. The principle accounting policies adopted by the Group and
Company are set out below.
New standards, interpretations and amendments adopted without an impact on the
Group's consolidated financial statements
Amendments to IAS 1 Presentation of Financial Statements and IFRS Practice
Statement 2: Disclosure of Accounting policies require the disclosures of
material accounting policies rather than significant accounting policies.
Amendments to IAS 8 Accounting policies, Changes in Accounting Estimates and
Errors: Definition of Accounting Estimates replace the definition of change in
accounting estimates with the definition of accounting estimates as monetary
amounts subject to measurement uncertainty following accounting policies
requirements.
Amendments to IAS 12 Income Taxes: Deferred Tax related to Assets and
Liabilities arising from a Single Transaction clarify that the recognition
exemption in paragraphs 15 and 24 of IAS 12 does not apply to transactions
that, on initial recognition, give rise to equal taxable and deductible
temporary differences.
Amendments to IAS 12 International Tax Reform - Pillar Two Model Rules
introduce disclosure requirements related to pillar two income taxes. The
Group is not in scope of the Pillar Two model rules as its revenue is less
than 750 million Euros per year.
New and revised standards and interpretations not applied
Certain new accounting standards and interpretations have been published that
are not mandatory for 31 December 2023 reporting period and have not been
early adopted by the Group and the Company. These standards are not expected
to have a material impact on the Group and the Company in the current or
future reporting periods and on foreseeable future transactions.
1.03 Basis of preparation
The financial statements have been prepared on the historical cost basis,
except for the measurement of certain assets and
financial instruments at fair value as described in the accounting policies
below.
The financial statements have been prepared on a going concern basis, refer to
note 1.29 for more details.
The financial statements are presented in United States Dollars ($) and all
values are rounded to the nearest thousand dollars ($'000) unless otherwise
stated.
1.04 Basis of consolidation
The financial statements incorporate the results of the Company and its
subsidiaries (collectively, the "Group") using the acquisition method. Control
is achieved where the Company has power over the investee, is exposed to, or
has rights to, variable returns from its involvement with the entity and has
the ability to affect those returns through its power over the entity.
The Group re-assesses whether or not it controls an investee if facts and
circumstances indicate that there are changes to one or more of the three
elements of control. Consolidation of a subsidiary begins when the Group
obtains control over the subsidiary and ceases when the Group loses control of
the subsidiary. Assets, liabilities, income and expenses of a subsidiary
acquired or disposed of during the year are included in the consolidated
financial statements from the date the Group gains control until the date the
Group ceases to control the subsidiary. If the Group loses control over a
subsidiary, it derecognises the related assets (including goodwill),
liabilities, non-controlling interest and other components of equity, while
any resultant gain or loss is recognised in profit or loss.
Inter-company transactions and balances between Group companies are eliminated
in full.
Where necessary, adjustments are made to the financial statements of
subsidiaries to bring the accounting policies used in line with those used by
the Group.
1.05 Business combinations
On the acquisition of a subsidiary, the business combination is accounted for
using the acquisition method. In the consolidated statement of financial
position, the acquiree's identifiable assets and liabilities are initially
recognised at their fair values at the acquisition date. The cost of an
acquisition is measured as the fair value of aggregated amount of the
consideration transferred, measured at the date of acquisition. The
consideration paid is allocated to the assets acquired and liabilities assumed
on the basis of fair values at the date of acquisition. Acquisition costs not
directly related to the issuance of shares in consideration are expensed when
incurred and included in administrative expenses. Acquisition costs which are
directly related to the issuance of shares in consideration are deducted from
share premium. The results of acquired operations are included in the
consolidated statement of comprehensive income from the date on which control
is obtained.
If the cost of acquisition exceeds the fair value of the identifiable net
assets attributable to the Group, the difference is considered as purchased
goodwill, which is not amortised but annually reviewed for impairment. In the
case that the identifiable net assets attributable to the Group exceed the
cost of acquisition, the difference is recognised in profit or loss as a gain
on bargain purchase.
If the initial accounting for a business combination cannot be completed by
the end of the reporting period in which the combination occurs, only
provisional amounts are reported, which can be adjusted during the measurement
period of up to 12 months after acquisition date.
After initial recognition, goodwill is measured at cost less any accumulated
impairment losses.
1.06 Intangible assets - exploration and evaluation assets
Exploration and evaluation expenditure incurred which relates to more than one
area of interest is allocated across the various areas of interest to which it
relates on a proportionate basis. Exploration and evaluation expenditure
incurred by or on behalf of the Group is accumulated separately for each area
of interest. The area of interest adopted by the Group is defined as a
petroleum title.
Expenditure in the area of interest comprises direct costs and an appropriate
portion of related overhead expenditure but does not include general overheads
or administrative expenditure not linked to a particular area of interest.
As permitted under IFRS 6, exploration and evaluation expenditure for each
area of interest, other than that acquired from the purchase of another
entity, is carried forward as an asset at cost provided that one of the
following conditions is met:
· the costs are expected to be recouped through successful
development and exploitation of the area of interest, or alternatively by its
sale; or
· exploration and/or evaluation activities in the area of
interest have not, at the reporting date, reached a stage which permits a
reasonable assessment of the existence or otherwise of economically
recoverable reserves, and active and significant operations in, or in relation
to, the area of interest are continuing.
Such costs are initially capitalised as intangible assets and include payments
to acquire the legal right to explore, together with the directly related
costs of technical services and studies, seismic acquisition, exploratory
drilling and testing. Exploration and evaluation expenditure which fails to
meet at least one of the conditions outlined above is taken to the
consolidated statement of comprehensive income.
Expenditure is not capitalised in respect of any area of interest unless the
Group's right of tenure to that area of interest is current.
Intangible exploration and evaluation assets in relation to each area of
interest are not amortised until the existence (or otherwise) of commercial
reserves in the area of interest has been determined.
Exploration and evaluation assets are assessed for impairment when facts and
circumstances suggest that the carrying amount may exceed its recoverable
amount. In accordance with IFRS 6, the Group reviews and tests for impairment
on an ongoing basis and specifically if the following occurs:
a) the period for which the Group has a right to explore in the
specific area has expired during the period or will expire in the near future,
and is not expected to be renewed;
b) substantive expenditure on further exploration for and evaluation
of hydrocarbon resources in the specific area is neither budgeted nor planned;
c) exploration for and evaluation of hydrocarbon resources in the
specific area have not led to the discovery of commercially viable quantities
of mineral resources and the Group has decided to discontinue such activities
in the specific area; and
d) sufficient data exists to indicate that although a development in
the specific area is likely to proceed the carrying amount of the exploration
and evaluation asset is unlikely to be recovered in full from successful
development or by sale.
An impairment loss is recognised for the amount by which the asset's carrying
value exceeds its recoverable amount. The recoverable amount is the higher of
an asset's fair value less costs to sell and value in use. For the purposes of
assessing impairment, assets are grouped at the lowest levels for which there
are separately identifiable cash inflows which are largely independent of the
cash inflows from other assets or groups of assets (cash-generating units).
Net proceeds from any disposal of an exploration asset are initially credited
against the previously capitalised costs. Any surplus proceeds are credited to
the consolidated statement of comprehensive income.
1.07 Oil and gas development/producing assets and commercial reserves
If the field is determined to be commercially viable, the attributable costs
are transferred to development/production assets
within tangible assets in single field cost centres.
Subsequent expenditure is capitalised only where it either enhances the
economic benefits of the development/producing asset or replaces part of the
existing development/producing asset.
Decreases in the carrying amount are charged to the consolidated statement of
comprehensive income.
Net proceeds from any disposal of development/producing assets are credited
against the previously capitalised cost. A gain or loss on disposal of a
development/producing asset is recognised in the consolidated statement of
comprehensive income to the extent that the net proceeds exceed or are less
than the appropriate portion of the net capitalised costs of the asset.
Commercial reserves are proven and probable oil and gas reserves, which are
defined as the estimated quantities of crude oil, natural gas and natural gas
liquids which geological, geophysical and engineering data demonstrate with a
specified degree of certainty to be recoverable in future years from known
reservoirs and which are considered commercially producible. There should be
at least a 50% statistical probability that the actual quantity of recoverable
reserves will be more than the amount estimated as a proven and probable
reserves.
1.08 Depletion and amortisation
All expenditure carried within each field is amortised from the commencement
of production on a unit of production basis, which is the ratio of oil and gas
production in the period to the estimated quantities of commercial reserves at
the end of the period plus the production in the period, generally on a
field-by-field basis. In certain circumstances, fields within a single
development area may be combined for depletion purposes. Costs used in the
unit of production calculation comprise the net book value of capitalised
costs plus the estimated future field development costs necessary to bring the
reserves into production. Changes in the estimates of commercial reserves or
future field development costs are dealt with prospectively.
1.09 Decommissioning
Where a material liability for the removal of production facilities and site
restoration at the end of the productive life of a field exists, a provision
for decommissioning is recognised. The amount recognised is the present value
of estimated future expenditure determined in accordance with local conditions
and requirements. The cost of the relevant tangible fixed asset is increased
with an amount equivalent to the provision and depreciated on a unit of
production basis. Changes in estimates are recognised prospectively, with
corresponding adjustments to the provision and the associated fixed asset.
1.10 Property, plant and equipment
Property, plant and equipment is stated in the consolidated statement of
financial position at cost less accumulated depreciation and any recognised
impairment loss. Depreciation on property, plant and equipment other than
exploration and production assets, is provided at rates calculated to write
off the cost less estimated residual value of each asset on a straight-line
basis over its expected useful economic life. Depreciation rates applied for
each class of assets are detailed as follows:
Furniture, fittings and equipment 1 - 4
years
Motor
vehicles
5 years
Leasehold
improvements
Over the life of the lease
The assets' residual values and useful lives are reviewed, and adjusted if
appropriate, at each balance sheet date.
An asset's carrying amount is written down immediately to its recoverable
amount if the asset's carrying amount is greater than its estimated
recoverable amount with any impairment charge being taken to the consolidated
statement of comprehensive income.
Gains and losses on disposals are determined by comparing proceeds with
carrying amount and are recognised in the consolidated statement of
comprehensive income.
1.11 Non-current assets and liabilities classified as held for sale and
discontinued operations
A discontinued operation is a component of the Group that either has been
disposed of, or is classified as held for sale.
A discontinued operation represents a separate major line of the business.
Profit or loss from discontinued operations comprises
the post-tax profit or loss of discontinued operations and the post-tax gain
or loss recognised on the measurement to fair value less costs to sell or on
the disposal group(s) constituting the discontinued operation.
Non-current assets classified as held for sale are presented separately and
measured at the lower of their carrying amounts immediately prior to their
classification as held for sale and their fair value less costs to sell.
However, some held for sale assets such as financial assets or deferred tax
assets, continue to be measured in accordance with the Group's relevant
accounting policy for those assets. Once classified as held for sale, the
assets are not subject to depreciation or amortisation.
Any profit or loss arising from the sale of a discontinued operation or its
remeasurement to fair value less costs to sell is presented as part of a
single line item, profit or loss from discontinued operations. See Note 14 for
further details.
1.12 Inventories
Inventories are stated at the lower of cost and net realisable value. Cost is
determined by the weighted average cost formula, where cost is determined from
the weighted average of the cost at the beginning of the period and the cost
of purchases during the period. Net (http://period.Net) realisable value
represents the estimated selling price less all estimated costs of completion
and costs to be incurred in marketing, selling and distribution.
1.13 Revenue recognition
Revenue from sales of oil and natural gas is recognised at the transaction
price to which the group expects to be entitled, exclusive of indirect taxes
and excise duties. Revenue is recognised when performance obligations have
been met, on delivery of product or when control of the product is transferred
to the customer.
1.14 Foreign currencies
Transactions in foreign currencies are translated at the exchange rate ruling
at the date of each transaction. Foreign currency monetary assets and
liabilities are retranslated using the exchange rates at the balance sheet
date. Gains and losses arising from changes in exchange rates after the date
of the transaction are recognised in the consolidated statement of
comprehensive income. This treatment of monetary items extends to the Group's
intercompany loans whereby gains and losses arising from changes in the
exchange rate after the date of transaction are also recognised in the
consolidated statement of comprehensive income. Intercompany loans are
provided to subsidiaries in the Group with the expectation that these loans
will be collected in the foreseeable future. Non-monetary assets and
liabilities that are measured in terms of historical cost in a foreign
currency are translated at the exchange rate at the date of the original
transaction.
In the financial statements, the net assets of the Group are translated into
its presentation currency at the rate of exchange at the balance sheet date.
Income and expense items are translated at the average rates for the period.
The resulting exchange differences are recognised in equity and included in
the translation reserve. The consolidated financial statements and company
financial statements are presented in United States Dollars ("$"), which is
the functional currency of the Company. Subsidiaries in the Group have a range
of functional currencies including United States Dollars, UK Pound Sterling,
Trinidad and Tobago Dollars and Euros.
1.15 Leases
The Group leases various offices, warehouses, equipment and vehicles. Rental
contracts are typically made for fixed periods of 6 months to 3 years, but may
have extension options.
Lease terms are negotiated on an individual basis and contain a wide range of
different terms and conditions. The lease agreements do not impose any
covenants other than the security interests in the leased assets that are held
by the lessor. Leased assets may not be used as security for borrowing
purposes.
Where applicable leases are recognised as a right-of-use asset and a
corresponding liability at the date at which the leased asset is available for
use by the Group.
Assets and liabilities arising from a lease are initially measured on a
present value basis. Lease liabilities include the net present value of the
following lease payments:
· fixed payments (including in-substance fixed payments), less
any lease incentives receivable;
· variable lease payment that are based on an index or a rate,
initially measured using the index or rate at the commencement date;
· amounts expected to be payable by the Group under residual
value guarantees;
· the exercise price of a purchase option if the Group is
reasonably certain to exercise that option; and
· payments of penalties for terminating the lease, if the
lease term reflects the Group exercising that option.
1.15 Leases
Lease payments to be made under reasonably certain extension options are also
included in the measurement of the liability. The lease payments are
discounted using the interest rate implicit in the lease. If that rate cannot
be readily determined, which is generally the case for leases in the Group,
the lessee's incremental borrowing rate is used, being the rate that the
individual lessee would have to pay to borrow the funds necessary to obtain an
asset of similar value to the right-of-use asset in a similar economic
environment with similar terms, security and conditions.
To determine the incremental borrowing rate, the Group:
· where possible, uses recent third-party financing received by
the individual lessee as a starting point, adjusted to reflect changes in
financing conditions since third party financing was received;
· uses a build-up approach that starts with a risk-free
interest rate adjusted for credit risk for leases held by the Group, which
does not have recent third-party financing; and
· makes adjustments specific to the lease, for example term,
country, currency and security.
The Group is exposed to potential future increases in variable lease payments
based on an index or rate, which are not included in the lease liability until
they take effect. When adjustments to lease payments based on an index or rate
take effect, the lease liability is reassessed and adjusted against the
right-of-use asset.
Lease payments are allocated between principal and finance cost. The finance
cost is charged to profit or loss over the lease period so as to produce a
constant periodic rate of interest on the remaining balance of the liability
for each period.
Right-of-use assets are measured at cost comprising the following:
· the amount of the initial measurement of lease liability;
· any lease payments made at or before the commencement date
less any lease incentives received;
· any initial direct costs; and
· restoration costs.
Right-of-use assets are generally depreciated over the shorter of the asset's
useful life and the lease term on a straight-line basis. If the Group is
reasonably certain to exercise a purchase option, the right-of-use asset is
depreciated over the underlying asset's useful life.
Payments associated with short-term leases of equipment and vehicles and all
leases of low-value assets are recognised on a straight-line basis as an
expense in profit or loss. Short-term leases are leases with a lease term of
12 months or less. Low-value assets comprise IT equipment and small items of
office furniture.
1.16 Financial instruments
Financial assets
The Group classifies its financial assets as financial assets held at
amortised cost. Management determines the classification of its financial
assets at initial recognition.
The Group classifies its financial assets as financial assets held at
amortised cost only if both of the following criteria are met:
- the asset is held within a business model whose objective
is to collect the contractual cash flows; and
- the contractual terms give rise to cash flows that are
solely payments of principal and interest.
Measurement
Financial assets held at amortised cost are initially recognised at fair
value, and are subsequently stated at amortised cost using the effective
interest method. Financial assets at amortised cost comprise 'cash and cash
equivalents' at variable interest rates, 'restricted cash', 'escrowed and
abandonment funds' and 'trade and other receivables' excluding 'prepayments'.
Impairment of financial assets
The Group assesses, on a forward-looking basis, the expected credit losses
associated with its financial assets held at amortised
cost. The impairment methodology applied depends on whether there has been a
significant increase in credit risk.
The Group applies the expected credit loss model to financial assets at
amortised cost. Given the nature of the Group's receivables, expected credit
losses are not material.
Financial liabilities
The Group classifies its financial liabilities as other financial liabilities.
Other financial liabilities are recognised initially at fair value and are
subsequently measured at amortised cost using the effective interest method.
Other financial liabilities consist of 'trade and other payables' and 'lease
liabilities'. Trade and other payables represent liabilities for goods and
services provided to the Group prior to the end of the financial period which
are unpaid. The amounts are unsecured and are usually paid within 30 days of
recognition.
Fair value measurement
Fair value is the price that would be received when selling an asset or paid
to transfer a liability in an orderly transaction between market participants
in its principal or most advantageous market at the measurement date. All
assets and liabilities for which fair value is measured or disclosed in the
financial statements are further categorised using the following three-level
hierarchy that reflects the significance of the lowest level of inputs used in
determining fair value.
- Level 1 - Quoted prices are available in active markets
for identical assets or liabilities as of the reporting date. Active markets
are those in which transactions occur in sufficient frequency and volume to
provide pricing information on an ongoing basis.
- Level 2 - Pricing inputs are other than quoted prices in
active markets used in Level 1. Prices in Level 2 are either directly or
indirectly observable as of the reporting date. Level 2 valuations are based
on inputs, included quoted forward price for
commodities, time value and volatility factors, which can be substantially
observed or corroborated in the marketplace.
- Level 3 - Valuations in this level are those with inputs
that are not based on observable market data.
At each reporting date, the Group determines whether transfers have occurred
between levels in the hierarchy by reassessing the level of classification for
each financial asset and financial liability measured or disclosed at fair
value in the financial statements based on the lowest level input that is
significant to the fair value measurement as a whole. Assessments of the
significance of a particular input to the fair value measurement require
judgement and may affect the placement within the fair value hierarchy.
1.17 Cash and cash equivalents
Cash and cash equivalents include cash on hand and deposits held at call with
financial institutions with original maturities of three months or less. For
the purposes of the statement of cash flows, restricted cash is not included
within cash and cash equivalents.
1.18 Share capital
Ordinary shares are classified as equity. Incremental costs directly
attributable to the issue of new shares or options are deducted, net of tax,
from the share premium. Net (http://premium.Net) proceeds are disclosed in the
statement of changes in equity.
1.19 Finance costs
Borrowing costs are recognised as an expense when incurred.
1.20 Borrowings
Borrowings are initially recognised at fair value, net of any applicable
transaction costs incurred. Borrowings are subsequently carried at amortised
cost; any difference between the proceeds (net of transaction costs) and the
redemption value is recognised in the income statement over the period of the
borrowings using the effective interest method (if applicable).
Interest on borrowings is accrued as applicable to that class of borrowing.
Convertible loans
Loans with certain conversion rights at the option of the holder to convert to
a fixed number of ordinary shares are identified as compound instruments with
the liability and equity components separately recognised. If the fixed for
fixed test is not met at contract inception, the loan is treated as a
liability only. On initial recognition the fair value of the liability
component is calculated by discounting the contractual stream of future cash
flows using the prevailing market interest rate for similar non-convertible
debt. The difference between the fair value of the liability component and the
fair value of the whole instrument is recorded as equity within the
convertible debt option reserve. Transaction costs are apportioned between the
liability and the equity components of the instrument based on the amounts
initially recognised. The liability component is subsequently measured at
amortised cost using the effective interest rate method, in line with other
financial liabilities. The equity component is not remeasured. On conversion
of the instrument, equity is issued and the liability component is
derecognised. The original equity component recognised at inception remains in
equity. No gain or loss is recognised on conversion.
1.21 Provisions
Provisions are recognised when the Group has a present obligation (legal or
constructive) as a result of a past event, it is probable that an outflow of
resources embodying economic benefits will be required to settle the
obligation and a reliable estimate can be made of the amount of the
obligation.
When the Group expects some or all of a provision to be reimbursed, for
example under an insurance contract, the reimbursement is recognised as a
separate asset but only when the reimbursement is virtually certain. The
expense relating to any provision is presented in the statement of
comprehensive income net of any reimbursement.
1.22 Dividends
Dividends are reported as a movement in equity in the period in which they are
approved by the shareholders.
1.23 Taxation
The tax expense represents the sum of the tax currently payable and deferred
tax.
Current tax, including overseas tax, is provided at amounts expected to be
paid (or recovered) using the tax rates and laws that have been enacted or
substantially enacted by the balance sheet date.
Deferred tax is the tax expected to be payable or recoverable on differences
between the carrying amounts of assets and liabilities in the financial
statements and the corresponding tax bases used in the computation of taxable
profit, and is accounted for using the balance sheet liability method.
Deferred tax liabilities are generally recognised for all taxable temporary
differences and deferred tax assets are recognised to the extent that it is
probable that taxable profits will be available against which deductible
temporary differences can be utilised. Such assets and liabilities are not
recognised if the temporary difference arises from goodwill or from the
initial recognition (other than in a business combination) of other assets and
liabilities in a transaction that affects neither the tax profit nor the
accounting profit.
Deferred tax liabilities are recognised for taxable temporary differences
arising on investments in subsidiaries and associates, except where the Group
is able to control the reversal of the temporary difference and it is probable
that the temporary difference will not reverse in the foreseeable future.
The carrying amount of deferred tax assets is reviewed at each balance sheet
date and adjusted to the extent that it is probable that sufficient taxable
profits will be available to allow all or part of the asset to be recovered.
Deferred tax is calculated at the tax rates that are expected to apply in the
period when the liability is settled or the asset is realised. Deferred tax is
charged or credited in the consolidated statement of comprehensive income,
except when it relates to items charged or credited directly to equity, in
which case the deferred tax is also dealt with in equity.
1.24 Impairment of assets
At each balance sheet date, the Group assesses whether there is any indication
that its tangible and intangible assets have become impaired. Exploration and
evaluation assets are also tested for impairment when reclassified to oil and
natural gas assets. If any such indication exists, the recoverable amount of
the asset is estimated in order to determine the extent of the impairment, if
any. If it is not possible to estimate the recoverable amount of the
individual asset, the recoverable amount of the cash-generating unit to which
the asset belongs is determined.
The recoverable amount of an asset or a cash-generating unit is the higher of
its fair value less costs to sell and its value in use. The value in use is
the present value of the future cash flows expected to be derived from an
asset or cash-generating unit. This present value is discounted using a
pre-tax rate that reflects current market assessments of the time value of
money and of the risks specific to the asset, for which future cash flow
estimates have not been adjusted. If the recoverable amount of an asset is
less than its carrying amount, the carrying amount of the asset is reduced to
its recoverable amount. That reduction is recognised as an impairment loss.
The Group's impairment policy is to recognise a loss relating to assets
carried at cost less any accumulated depreciation or amortisation immediately
in the consolidated statement of comprehensive income.
Impairment of goodwill
Goodwill acquired in a business combination is, from the acquisition date,
allocated to each of the cash-generating units, or groups of cash-generating
units, that are expected to benefit from the synergies of the combination.
Goodwill is tested for impairment at least annually, and whenever there is an
indication that the asset may be impaired. An impairment loss is recognised on
cash-generating units, if the recoverable amount of the unit is less than the
carrying amount of the unit. The impairment loss is allocated to reduce the
carrying amount of the assets of the unit by first reducing the carrying
amount of any goodwill allocated to the cash-generating unit, and then
reducing the other assets of the unit, pro rata on the basis of the carrying
amount of each asset in the unit.
If an impairment loss subsequently reverses, the carrying amount of the asset
is increased to the revised estimate of its recoverable amount but limited to
the carrying amount that would have been determined had no impairment loss
been recognised in prior years. A reversal of an impairment loss is recognised
in the statement of comprehensive income. Impairment losses on goodwill are
not subsequently reversed.
1.25 Employee benefits
Wages and salaries, and annual leave
Liabilities for wages and salaries, including non-monetary benefits, expected
to be settled within 12 months of the reporting date are recognised in other
payables in respect of employees' services up to the reporting date and are
measured at the amounts expected to be paid when the liabilities are settled.
Share-based payments
Where equity settled share-based instruments are awarded to employees or
Directors, the fair value of the instruments at the date of grant is charged
to the consolidated statement of comprehensive income over the vesting period.
Non-market vesting conditions are taken into account by adjusting the number
of equity instruments expected to vest at each balance sheet date so that,
ultimately, the cumulative amount recognised over the vesting period is based
on the number of instruments that eventually vest. Market vesting conditions
are factored into the fair value of the instruments granted. As long as all
other vesting conditions are satisfied, a charge is made irrespective of
whether the market vesting conditions are satisfied. The cumulative expense is
not adjusted for failure to achieve a market vesting condition.
Where equity instruments are granted to persons other than employees or
Directors, the consolidated statement of comprehensive income is charged with
the fair value of goods and services received.
Bonuses
The Group recognises a liability and an expense for bonuses. Bonuses are
approved by the Board and a number of factors are taken into consideration
when determining the amount of any bonus payable, including the recipient's
existing salary, length of service and merit. The Group recognises a provision
where contractually obliged or where there is a past practice that has created
a constructive obligation.
Pension obligations
For defined contribution plans, the Group pays contributions to privately
administered pension plans. The Group has no further payment obligations once
the contributions have been paid. The contributions are recognised as an
employee benefit expense when they are due.
Termination benefits
Termination benefits are payable when employment is terminated by the Group
before the normal retirement date, or whenever an employee accepts voluntary
redundancy in exchange for these benefits. The Group recognises termination
benefits when it is demonstrably committed to a termination and when the
entity has a detailed formal plan to terminate the employment of current
employees without the possibility of withdrawal. Benefits falling due more
than 12 months after the end of the reporting period are discounted to their
present value.
1.26 Segmental reporting
Operating segments are reported in a manner consistent with the internal
reporting provided to the chief operating decision-maker. The chief operating
decision-maker, who is responsible for allocating resources and assessing
performance of the operating segments, has been identified as the Board of
Directors that makes strategic decisions. The performance of operating
segments is assessed on the basis of key metrics applicable, such as barrels
of oil produced per day, "netbacks" per barrel, revenue and operating profit.
The Board has determined there is a single operating segment: oil and gas
exploration, development and production. However, there are four geographical
segments: Trinidad & Tobago (including a single operating segment and a
separate disposal group (refer to note 14)), The Bahamas (operating), Uruguay
(operating) and The Isle of Man, UK, Spain, Saint Lucia, Cyprus, Netherlands
and Suriname (all non-operating).
1.27 Share issue expenses and share premium account
Costs of share issues are written off against the premium arising on the
issues of share capital.
1.28 Share based payments reserve
This reserve is used to record the value of equity benefits provided to
employees and Directors as part of their remuneration and
provided to consultants and advisors hired by the Group from time to time as
part of the consideration paid.
1.29 Critical accounting estimates, judgements and assumptions
The Group makes estimates and assumptions concerning the future. The resulting
accounting estimates will, by definition, seldom equal the related actual
results. The estimates and assumptions that have a risk of causing material
adjustment to the carrying amounts of assets and liabilities within the next
financial year are discussed below.
(i) Recoverability of oil and gas exploration and production
assets
Impairment of Trinidad and Tobago and Suriname intangible and tangible oil and
gas assets and property plant and equipment
The Directors carried out an impairment review of the Group's tangible and
intangible assets in Trinidad and Tobago, including goodwill, to determine
whether the carrying value of these assets exceeded their fair value. The
impairment assessment was undertaken by reference to various market data
points and industry valuation standards, including, where applicable,
discounted cashflows. Following this exercise, the Directors determined to
record a full write down of goodwill totalling $4,610,000 (2022: nil).
In addition to this, two of the cash generating units ("CGU") located in
Trinidad and Tobago have not met performance expectations. For these
continuing operations, an impairment assessment was prepared on a "value in
use" basis using discounted future cash flows based on expected future field
performance, a forward oil price of $70 per barrel and a pre-tax discount rate
of 10%. Applying this methodology impairments were identified in the relevant
cash generating units (CGUs). Consequently, an impairment of related Trinidad
and Tobago tangible assets of $8,290,000 (2022: $2,289,000) within these CGUs
was recognised at balance sheet date.
A further write down of $57,000 (2022: nil) was recorded to the intangible
asset in Suriname following the Group's decision to relinquish licence there
during the year.
Further sensitivity analysis determined the following:
- A $5 per barrel decrease in the oil prices would result
increase the overall impairment charge to $8,879,000 to the CGUs;
- A 5% decrease in production would increase the overall
impairment charge to $8,972,000 to the CGUs; and
- A 5% increase in the pre-tax discount rate would increase
the overall impairment charge to $8,542,000 to the CGUs. Refer to note 10
(intangible assets) and note 11 (tangible assets).
Carrying value of capitalised exploration costs
Costs capitalised as exploration assets are assessed for impairment when
circumstances suggest that the carrying value may exceed its recoverable
value. This assessment involves judgement as to the likely commerciality of
the asset, the future revenues and costs pertaining and the discount rate to
be applied for the purposes of deriving a recoverable value.
The carrying value of exploration costs at 31 December 2023 is $93,963,000
(2022: $93,963,000) relating almost entirely to the cost of exploration
licences, geological and geophysical consultancy, seismic data acquisition and
interpretation and the drilling of exploration wells in the Bahamian offshore
licences. The Group's exploration activities are subject to a number of
significant and potential risks including licence obligations, requirement for
further funding, geological and development risks, and political risk.
The recoverability of these assets is dependent on the discovery and
successful development of economic reserves, including the ability to raise
finance to develop future projects or alternatively, sale of the respective
licence areas. The carrying value of the Group's exploration and evaluation
expenditure is reviewed at each balance sheet date and, if there is any
indication that it is impaired, its recoverable amount is estimated. Estimates
of impairment are limited to an assessment by the Directors of any events or
changes in circumstances that would indicate that the carrying value of the
asset may not be fully recoverable. Any impairment loss arising is charged to
the consolidated statement of comprehensive income.
On 21 February 2019, the Group received notification from the Bahamian
Government of an extension of the term of its four southern licences to 31
December 2020, with the requirement that the Company commence an exploration
well before the end of the extended term. On 23 March 2020, the Group notified
the Government of The Bahamas that, due to the impacts of the global response
to the Covid-19 pandemic, a force majeure event had occurred under the terms
of its exploration licences, such that the term of the licences needed to be
extended beyond 31 December 2020 commensurate with the duration of the force
majeure event. In November 2020 the Group received notification per the
Government of The Bahamas agreeing to an extension of these licences to 30
June 2021 as a result of the force majeure event. On 20 December 2020, the
Group commenced drilling of the Perseverance-1 exploration well on its
offshore licence area in The Bahamas, with drilling activity ceasing on 7
February 2021. Whilst the well demonstrated presence of hydrocarbons,
commercial volumes of movable hydrocarbons were not present at this drilling
location. Subsequently the Group undertook an extensive review of the data
gathered from the Perseverance-1 well to determine the extent to which this
data indicates remaining prospectivity in deeper, untested horizons, as well
as horizons of interest at other locations along the B and C structures. The
results of this review indicate that substantial prospectivity remains in
sufficient potential volumes such that further exploration activity on these
licences is merited. On the basis of the revised prospect volume inventory for
these untested horizons and structures, the Group undertook an exercise to
determine whether the present value of any future economic benefit which may
be derived from hydrocarbon extraction from these licences is sufficient to
support the carrying value of the capitalised costs at 31 December 2023.
Following this review, the Group has determined that the present value of
these future economic benefits exceeds the carrying value of this asset and
that consequently no impairment of this asset is required.
Given this, in March 2021, the Group notified the then Government of The
Bahamas of its election to renew the four southern licences into a further
three-year exploration period, having discharged the licence obligation to
drill an exploration well before the expiry of the second exploration term
which expired on 30 June 2021. Since then, the Group has been in discussions
with The Bahamas administration regarding the renewal of these licences. As at
the current time, however, the renewal application remains under review with
The Bahamas administration. Notwithstanding that the Group's application to
renew the southern licences into third exploration period has now been pending
for a considerable length of time, management considers this to be within the
bounds of normal expectation in The Bahamas, given that (i) the renewal of the
southern licences from the first exploration period into the second
exploration period took almost five years, (ii) a new Government was elected
in The Bahamas in September 2021, and (iii) Covid-19 pandemic related lock
downs caused significant administrative delays all across the world. Once this
renewal process is completed, the key licence obligation for the new
three-year period would be the drilling of a further exploration well within
the licence area before the expiry of the renewed licence term. The ability of
the Group to discharge this obligation would be contingent on securing the
funding required to execute a second exploration well.
(ii) Going concern
These financial statements have been prepared on a going concern basis, which
assumes that the Group will continue in operation for the foreseeable future.
The Group has incurred an operating loss of $19.9 million for the financial
year ended 31 December 2023 (2022: loss of $4.2 million) and the Group's
current liabilities exceeded current assets by approximately $2.9 million as
of 31 December 2023 (2022: $2.0 million), however this includes approximately
$4.1m in respect of taxes and penalties owed in Trinidad and Tobago that the
Group expects to settle by way of offset against future tax refunds or are
derived from notional estimates of tax penalties dating back to 2021 that the
Group does not expect will be levied or assessed with final resolution still
pending with the local tax authorities (refer to note 18 for further details).
At 31 December 2023, the Group had approximately $1.0 million (2022: $2.5
million) in unrestricted cash funding and at the date of authorisation of
these financial statements, the Group continues to have approximately $1.5
million in unrestricted cash funding.
On 6 March 2024, the Group entered into a farm-out agreement with Chevron, a
leading global energy super-major, in relation to the Group's AREA OFF-1
licence offshore Uruguay pursuant to which the Group will receive US$12.5
million upfront payment at completion along with Chevron carrying the Group's
share of certain future work programme costs (the "Farm-out"). The Farm-out is
subject to Uruguayan regulatory approval. Management is highly confident that
the requisite regulatory approvals will be forthcoming in the near-term, as
Chevron meets all requirements to operate an energy project in Uruguay, and
the submissions for regulatory approvals were made in consultation with ANCAP,
the Uruguayan regulatory body. In addition, the Group expects US$0.3 million
of presently restricted cash (in support of AREA OFF-1 performance bond) to
become unrestricted shortly after the Farm-out completion.
On 18 April 2024 the Group announced that it had entered into a legally
binding term sheet for an investment by Charlestown Energy Partners [[C,
whereby Charlestown will invest £1.5 million in the Group, initially in the
form of a loan, This investment was completed on 28 May 2024 and provides the
Group with finance in the medium term until the completion of the farm-out
agreement with Chevron, and, on completion of the Farm-out, the Charlestown
investment will convert into a shareholding of approximately 8.7% in the
Company.
The Directors have thus prepared these financial statements on a going concern
basis, as based on the Group's cash flow forecasts (which include the proceeds
from Charlestown investment and the Farm-out described above), the Group
expects to have adequate financial resources to support its operations for the
next 12 months (and well into the foreseeable future beyond that). In
addition, the Directors note that the Company is a publicly listed company on
a recognised stock exchange, thus affording the Company the ability to raise
capital equity, debt and/or hybrid financing alternatives as and when the need
arises. The Company has a robust track record in this regard, having raised in
excess of US$100 million in equity and alternative financing in the recent
past.
(iii) Recoverability of investment in subsidiaries and amounts owed by
subsidiary undertakings in the Company statement of financial position
The investment in the Company's direct subsidiaries and amounts owed by
subsidiary undertakings at 31 December 2023 stood at $43,650,000 (2022:
$50,940,000) and $128,924,000 (2022: $128,338,000) respectively.
Ultimate recoverability of investments in subsidiaries and amounts owed by
subsidiary undertakings is dependent on successful development and commercial
exploitation, increasing production through optimisation of existing wells,
drilling of new infill wells and/or the application of improved oil recovery
methods or alternatively, sale of the respective licence areas. The carrying
value of the Company's investments in subsidiaries is reviewed at each balance
sheet date and, if there is any indication of impairment, the recoverable
amount is estimated. Estimates of impairments are limited to an assessment by
the directors of any events or changes in circumstances that would indicate
that the carrying values of the assets may not be fully recoverable.
Similarly, the expected credit losses on the amounts owed by subsidiary
undertakings are intrinsically linked to the recoverable amount of the
underlying assets. Any impairment losses arising are charged to the statement
of comprehensive income.
At 31 December 2023, an impairment of the Company's investment in Columbus
Energy Resources Limited of $7,300,000 (2022: nil) was recorded. In addition
to this a loss allowance for expected credit losses of $14,021,000 (2022:
$14,737,000) was held in respect of the recoverability of amounts due from
subsidiary undertakings.
1.30 Earnings/(loss) per share
Basic earnings per share is calculated as net profit attributable to members
of the parent company, adjusted to exclude any costs of servicing equity
(other than dividends) and preference share dividends, divided by the weighted
average number of ordinary shares, adjusted for any bonus element.
Diluted earnings per share is calculated as net profit attributable to members
of the parent company, adjusted for:
(i) Costs of servicing equity (other than dividends) and preference
share dividends;
(ii) The post-tax effect of dividends and interest associated with
dilutive potential ordinary shares that have been recognised as expenses; and
(iii) Other non-discretionary changes in revenues or expenses during the
period that would result from the dilution of potential ordinary shares,
divided by the weighted average number of ordinary shares and dilutive
potential ordinary shares, adjusted for any bonus element.
1.31 Investment in subsidiary in the Company statement of financial position
Investments in subsidiaries are recognised at initial cost of acquisition,
less any impairment to date.
2 Turnover and segmental analysis
Management has determined the operating segments based on the reports reviewed
by the Board of Directors that are used to make strategic decisions. The Board
has determined there is a single operating segment: oil and gas exploration,
development and production. However, there are four geographical segments:
Uruguay (operating), Trinidad & Tobago (including a single operating
segment and a separate disposal group (refer to note 14)), The Bahamas
(operating), and The Isle of Man, UK, Spain, Saint Lucia, Cyprus, Netherlands
and Suriname (all non-operating).
The Uruguay segment includes the exploration licences and appraisal works
which have commenced in 2022. The segment including Trinidad & Tobago has
been reported as the Group's direct oil and gas producing and revenue
generating operating segment. The Bahamas segment includes the Bahamian
exploration licences on which drilling activities were conducted in 2020 and
2021. The non-operating segment including the Isle of Man (the Group's
parent), provides management services to the Group and entities in Saint
Lucia, Cyprus, Spain, Netherlands and Suriname all of which are non-operating
or in that they either hold investments or are dormant/in the process of being
wound up. Their results are consolidated and reported on together as a single
segment.
Trinidad & St Lucia Disposal Group Bahamas Non-Operating Entities (*) Total
Uruguay Trinidad
Operating
$'000
$'000 $'000
$'000
Operating Operating
Year ended 31 December
2023
$'000 $'000
Operating loss by geographical area
Net petroleum revenue (**) - 3,588 - - - 3,588
Operating loss (29) (11,802) - (96) (7,935) (19,862)
Other income - 407 - 22 - 429
Finance costs, net (5) (94) (99)
Loss before taxation (29) (11,400) - (74) (8,029) (19,532)
Other information - - 6,141 - - 6,141
Gain after tax for the year from
discontinued operations
Administrative expenses (29) (1,800) - (96) (2,437)*** (4,362)
Depreciation, amortisation - (1,605) (2) (36) (1,643)
Impairment (8,214) - - (4,743) (12,957)
Capital additions (1,149) (149) (5) (1,303)
Segment assets
Tangible and intangible assets 1,363 9,800 - 93,964 333 105,460
Deferred tax asset - 4,637 - - - 4,637
Escrow and abandonment funds - 1,601 - - - 1,601
Trade and other receivables 1 2,558 - 500 143 3,202
Inventories - 280 - - - 280
Restricted cash - 299 - - 526 825
Cash and cash equivalents - 368 - - 637 1,005
Consolidated total assets 1,364 19,543 - 94,464 1,639 117,010
Segment liabilities
Trade and other payables - (6,047) - (1,053) (1,082) (8,182)
Deferred tax liability - (4,707) - - (4,707)
Provisions - (3,194) - - (2,475) (5,669)
Consolidated total liabilities - (13,948) - (1,053) (3,557) (18,558)
(*) Intercompany balances and transactions between Group entities have
been eliminated.
(**) Sales revenues were derived from a single customer within each of these
operating countries.
(***) Administrative expenses includes various non-cash items including
depreciation and amortisation, share based payments expense, share settled
payment expenses and loss on disposal of fixed assets. Removing these items
results in a corporate administration cash cost of approximately $2.29 million
for the year ended 31 December 2023, or approximately $190,000 per month.
14 Discontinued operations
Sale of T-Rex (Cory Moruga asset):
On 20 December 2022, the Company announced that it had entered into a binding
heads of terms with Predator Oil & Gas Holdings Plc (PRD), providing for
the conditional sale of the Company's interest in the non-producing Cory
Moruga licence in Trinidad through the sale of 100% of the share capital in
T-Rex Resources (Trinidad) Limited (TREX), with retention of 25% future
back-in right (at the Company's option) based on the outcomes of future
drilling / EOR activity and associated future production.
The sale of the Cory Moruga licence, onshore Trinidad, to PRD, was completed
on 6 November 2023.
As a consequence of negotiations associated with reaching an agreed position
with the Trinidadian Ministry of Energy and Energy
Industries ("MEEI"), the Company and PRD agreed to vary certain terms of the
previously announced agreement between them,
as follows:
- On completion, PRD paid the Company US$1 million in cash;
- A further US$1 million, which was due to be paid by PRD to the
Company six months from completion, was instead paid immediately by PRD direct
to MEEI, in part agreed settlement of past dues on the Cory Moruga licence;
and
- A contingent US$1 million payable by PRD to the Company in the
event of the Cory Moruga field achieving certain future production benchmarks,
and PRD granting to the Company a future back-in right to a 25% interest in
the Cory Moruga field at an uplifted multiple of cost base, will no longer
apply, reflective of the Company's contribution to the value of settlement of
the balance of past dues on the Cory Moruga licence, which will be recovered
by MEEI via agreed quarterly arrears payments.
In addition to the cash consideration received, completion of the transaction
had the effect of extinguishing various liabilities in the Company's accounts
relating to the Cory Moruga licence, amounting to approximately US$4.5
million. Further, in parallel with completion, all historical differences and
disputes between the Company and PRD in relation to the Inniss-Trinity pilot
CO2 EOR Project were fully and amicably resolved, pursuant to the terms of the
previously announced Settlement Agreement between the Company and PRD.
Consideration was received in cash during the period. At the date of the
disposal the carrying amounts of T-Rex net assets were as follows:
$ 000's
Assets 852
Trade and other receivables
Total assets 852
Liabilities (3,365)
Trade and other payables (1,203)
Provisions (note 21)
Total liabilities (4,568)
Total net liabilities (3,716)
Total consideration received in cash 1,000
Less cash and cash equivalents disposed of -
Net cash received 1,000
Gain on disposal (*) 4,716
(*) The gain on disposal is included in the gain/(loss) for the year
from discontinued operations in the consolidated statement of profit and loss.
Sale of Caribbean Rex Limited ("CREX") (South Erin asset):
On 14 February 2023, the Company announced it had entered into and completed a
transaction for the sale of its St Lucia domiciled subsidiary company, CREX
which included its associated assets and subsidiary entities. This includes
(via interposed subsidiaries) CEG South Erin Trinidad Limited ("CSETL") a
Trinidadian company that is party to a farm-out agreement for, and is the
operator of, the South Erin field, (onshore Trinidad) and West Indian Energy
Group Limited (a Trinidadian service company).
1) On 31 August 2023, the Company drew down a £550,000
(US$636,000) first tranche of a £3,300,000 (US$4,198,000) convertible loan
notes agreed with a UK based alternative asset management and investment firm.
The loan notes once drawn down were repayable within 36 months. Interest was
fully pre-paid on draw down such that on draw down 90% of the value of the
notes was advanced in cash to the Company. The holder had the right, at any
time prior to repayment, to elect to convert the Notes into fully paid
ordinary shares in the Company at the lesser of (i) 140% of the Company's
closing bid price on the trading day immediately prior to the date of draw
down, or (ii) 90% of the lowest closing bid price in the five trading days
immediately preceding the date of the conversion. The loan notes were
redeemable in cash by the Company, all or in part, at any time after draw down
at 105% of the par value.
On 29 September 2023, the Company received a conversion notice in respect of
£165,000 of outstanding convertible notes requiring the Company to issue
458,333,333 new ordinary shares. The new shares were issued on 5 October 2023
(see note 22).
On 27 October 2023, the Company announced it had re-financed the convertible
loan notes and secured a short-term bridge loan of £350,000 (US$432,000)
which immediately settled the unconverted balance of the convertible loan
notes including early redemption charges. As part of this settlement the
holder of the notes issued a further conversion notice in respect of £55,000
of outstanding convertible notes requiring the Company to issue 100,000,000
new ordinary shares which were issued on 2 November 2023 (see note 22). In
addition to this, a further 250,000,000 warrants in the Company were granted
to the holder at an exercise price of 0.1p per share which will remain valid
for 36 months from date of grant. The outstanding bridge loan also included a
12% annual coupon accruing monthly. The bridge loan was subsequently fully
repaid on 7 November 2023.
2) On 30 December 2020, the Company drew down £1,110,000
(US$1,511,000) of a £3,000,000 (US$4,084,000) first tranche of a convertible
loan previously agreed with Bizzell Capital Partners Pty Ltd. As part of this
initial draw down in 2020, £287,000 (US$396,000) was recognised as the equity
component. Tranche 1 had a total fair value, after deduction of all facility
costs, of £2,800,000 (US$3,812,000). The term of the loan was 3 years from
the date of draw-down. The holder had the right, at any time prior to
maturity, to elect to convert the Notes (principal plus any accrued interest)
into fully paid ordinary shares in the Company. Initially, the conversion
price was set at a 25% premium to the price of the Company's next capital
raising (if any) or at 6p per share, whichever was the lower. Subsequently, in
February 2021 the conversion price was amended by agreement to 0.8p per share.
In May 2021 the balance of the £3,000,000 facility was drawn down in full,
resulting in a further £370,000 (US$505,000) equity component being
recognised. Thereafter £2,500,000 (US$3,496,000) of the facility amount was
converted into ordinary shares resulting in a £579,000 (US$787,000) equity
conversion, leaving a remaining principal outstanding of £342,000
(US$462,000) and residual equity component of £84,000 (US$114,000) at 31
December 2021. The remaining balance was converted into ordinary shares as
part of the restructuring completed in March 2022.
(*) The provisions relate to
the estimated costs of the removal of Trinidadian and Spanish production
facilities and site restoration at the end of the production lives
of the facilities. Decommissioning provisions in Trinidad and Tobago have been
subject to a discount rate of 4.32% -4.94% (2022: 3.8%-4.98%), expected cost
inflation of 1.87% (2022: 2.06%-3.22%) and assumes an average expected year of
cessation of production of 2032. Decommissioning provisions relating to
facilities in Spain are undiscounted and uninflated as the field is no longer
operating. The Spanish subsidiary is currently in the process of being
liquidated and management's expectation is that the provision for
decommissioning relating to Spanish assets will be released on completion of
this process.
On 7 March 2022, 73,803,215 options to various parties including management
and various consultants were cancelled by mutual consent with the option
holders and 1,536,559,845 new options were issued.
On 2 November 2023 250,000,000 warrants were granted to a finance provider in
relation to the settlement of a bridging loan facility, refer to note 20 for
further details.
The fair value of the warrants and options granted in the year was estimated
using the Black Scholes model. The inputs and assumptions used in calculating
the fair value of options granted in the year were as follows:
Warrants and options granted in 2023
Share price at date of Vesting Exercise price Expected Expected Risk free Dividend Fair value
grant per
Name Date granted pence date/criteria Number pence Expiry date volatility life (years) return yield option $
Management options (Tranche A) 30/08/2023 0.073 31/03/2024 240,000,000 0.100 29/08/2028 9% 1.24 5.23% - $0.00
Management options (Tranche B) 30/08/2023 0.073 30/06/2024 240,000,000 0.150 29/08/2028 8% 1.24 5.23% - $0.00
Management options (Tranche C) 30/08/2023 0.073 30/09/2024 240,000,000 0.225 29/08/2028 7% 1.24 5.23% - $0.00
Management options (Tranche D) 30/08/2023 0.073 30/11/2024 240,000,000 0.300 29/08/2028 5% 1.24 5.23% - $0.00
Finance provider 02/11/2023 0.065 03/11/2023 250,000,000 0.100 01/11/2026 21% 1.08 4.74% - $0.00
1,210,000,000
Warrants and options granted in 2022
Share price at date of Vesting Exercise price Expected Expected Risk free Dividend Fair value
grant per
Name Date date/criteria Number pence Expiry date volatility life (years) return yield option $
granted
pence
Management options (Tranche A) 07/03/2022 0.095 06/03/2023 240,000,000 0.100 06/03/2027 70% 1.68 1.17% - $0.03
Management options (Tranche B) 07/03/2022 0.095 06/03/2023 240,000,000 0.150 06/03/2027 70% 1.68 1.17% - $0.01
Management options (Tranche C) 07/03/2022 0.095 06/03/2023 240,000,000 0.225 06/03/2027 70% 1.68 1.17% - $0.00
Management options (Tranche D) 07/03/2022 0.095 06/03/2023 240,000,000 0.300 06/03/2027 70% 1.68 1.17% - $0.00
Consultant 12/03/2022 12/03/2022 371,992,563 0.100 11/03/2027 70% 0.74 1.33% - $0.04
0.103
Consultant 12/03/2022 12/03/2022 179,566,922 0.100 11/03/2027 70% 0.74 1.33% - $0.04
0.103
Finance provider 12/03/2022 12/03/2022 25,000,000 0.100 11/03/2027 70% 0.74 1.33% - $0.04
0.103
1,536,559,485
The weighted average remaining contractual life of the options and warrants in
issue at 31 December 2023 was 3.61 years (2022: 4.98 years) and the weighted
average exercise price of these instruments was 0.2p pence per share (2022:
0.24 pence). The range of exercise prices for options and warrants outstanding
at 31 December 2023 was 0.10 pence to 28 pence (2022: 0.1 pence to 28 pence).
The expected price volatility used in calculating the fair value of options
and warrants granted by the Company is determined based on the historical
volatility of the Company share price (based on the remaining life of the
options), adjusted for any expected changes to future volatility due to
publicly available information.
b) Expense arising from share-based payment transactions
Total expense arising from equity-settled share-based payment transactions:
2023 2022
$ 000's $ 000's
Options and warrants 1 323
Total 1 323
The above charges in relation to share-based payments include $nil relating to
Directors (2022: $76,000), $nil related to staff and consultants (2022:
$45,000), $nil relating to warrants granted to the Company's advisors (2022:
$130,000) and $1,000
59
(2022: $72,000) relating to options granted to potential providers of conditional convertible note finance.
Share settled payments 2023 2022 $ 000's
$ 000's
Professional advisory fees (*) 30 222
Issuance of shares in satisfaction of deferred salaries and contractual 72 1,044
payments to staff (**)
Total 102 1,266
(*) Represents the fair value of shares issued to various
advisors and consultants in lieu of cash for their fees. The fair value of
these shares has been calculated based on the number of shares issued and the
market price of the Company shares on the date of issuance. These expenses
have been recognised in the Group statement of comprehensive income under
"Professional fees - share settled" within administrative expenses or share
premium with respect to advisory fees for raising share capital. These
transactions do not fall within the scope of IFRS 2, Share based payments.
(**) Represents the fair value of shares issued to directors
and staff during the year in settlement of deferred salary and fees, less the
total value of accrued salaries and fees on the date of settlement. The fair
value of these shares has been calculated based on the number of shares issued
and the market price of the Company shares on the date of issuance. Accruals
for deferred salary and fees had been recognised based on the value of
contractual payments forgone. The excess of the fair value of these shares
issued over the total accrued costs for deferred salary and fees to the date
of settlement has been recognised in the Group statement of comprehensive
income under "Staff costs - share settled" within Administrative expenses.
These transactions do not fall within the scope of IFRS 2, Share based
payments.
The table below discloses the total share-based payment charges for the year
included in the statement of comprehensive income by expense category.
2023 $ 000's 2022 $ 000's
Staff costs - 120
Professional fees - 131
Finance costs 1 72
Total 1 323
24 Financial instruments and risk management - Group & Company
The Group's activities expose it to a variety of financial risks: oil price,
liquidity, interest rate, foreign exchange, credit and capital risk. The
Group's overall risk management programme focuses on minimising potential
adverse effects on the financial performance of the Group.
Risk management is carried out by the CEO under policies approved by the Board
of Directors. The CEO identifies, evaluates and addresses financial risks in
close cooperation with the Group's management. The Board provides principles
for overall risk management, as well as policies covering specific areas, such
as mitigating foreign exchange risk, interest rate risk, credit risk and
investing excess liquidity.
The Group uses financial instruments comprising cash, and debtors/creditors
that arise from its operations. The net fair value of financial assets and
liabilities approximates the carrying values disclosed in the financial
statements. The financial assets comprise cash balances in bank accounts at
call.
Oil Price Risk
The Group has been exposed to commodity price risk regarding its sales of
crude oil which is an internationally traded commodity. The Group sales prices
are closely linked to the West Texas Intermediate (WTI) Crude Oil benchmark
for sales in Trinidad and Tobago. The pricing of Group oil sales in Trinidad
and Tobago is set by the state oil company Heritage and the price realised by
the Company is typically at approximately 10% discount to WTI benchmark. The
Group does not take out hedging instruments for changes in oil prices, with
the risks to Group cashflows associated with changes in the oil price obtained
from Heritage being mitigated by controls over elective costs of well
workovers and other such production enhancing expenditure.
The spot prices per barrel for WTI are shown below:
Interest rate risk
The Group's strategy for managing cash is to maximise interest income whilst
ensuring its availability to match the profile of the
Group's expenditure. This is achieved by regular monitoring of interest rates
and monthly review of expenditure forecasts.
The Group's exposure to interest rate risk relates to the Group's cash
deposits which are linked to short term deposit rates and therefore affected
by changes in bank base rates. At 31 December 2023, short term deposit rates
were in the range of 0% to 0.5% (31 December 2022: 0% to 0.5%) and therefore
the interest rate risk is not considered significant to the Group. An increase
in interest rate of 0.25% in the year would have had an insignificant effect
on the Group's loss for the year and profit in the prior year.
Group borrowings are at fixed interest rates and therefore do not present an
interest rate risk.
Foreign currency risk
The Group operates internationally and therefore is exposed to foreign
exchange risk arising from currency exposures, primarily
with regard to UK Sterling, Trinidad and Tobago Dollars and Euros.
The Company has a policy of not hedging foreign exchange and therefore takes
market rates in respect of currency risk; however it does review its currency
exposures on an ad hoc basis. Currency exposures relating to monetary assets
held by foreign operations are included within the foreign exchange reserve in
the Group statement of financial position.
The following table details the Group's sensitivity to a 10% increase and
decrease in the US Dollar against the relevant foreign currencies of Pound
Sterling, Euro and Trinidadian Dollar. 10% represents management's assessment
of the reasonably possible change in foreign exchange rates.
The sensitivity analysis includes only outstanding foreign currency
denominated investments and other financial assets and liabilities and adjusts
their translation at the year-end for a 10% change in foreign currency rates.
The table below sets out the potential exposure, where the 10% increase or
decrease refers to a strengthening or weakening of the US Dollar:
Annual licence rental commitments
The Group is required under its Bahamian exploration licences to remit annual
rentals in advance to the Government in respect of the licenced areas. On 27
February 2020, the Company advised that, consequent upon the granting of
Environmental Authorisation for the Perseverance-1 well, the Company and the
Government of The Bahamas had agreed a process seeking a final agreement on
the amount of licence fees payable for the balance of the second exploration
period (including the additional period of time to which the licence period
was extended as a result of force majeure). At the time, the parties entered
into discussions with a view to finalising this outstanding matter, although
as at the date of this report there has been no substantive progress on this
issue with the Government of The Bahamas. The amount which the Group considers
to be outstanding is small, and the Group expects this will be addressed as
part of the broader discussion around renewal of the licence areas, as
previously noted.
The Group does not have any material annual rental payments payable on its
licences in Trinidad and Tobago, and Uruguay.
26 Related party transactions - Group & Company
Transactions between the Company and its subsidiaries, which are related
parties, have been eliminated on consolidation. Transactions between other
related parties are outlined below.
Remuneration of Key Management Personnel
The Directors of the Company are considered to be the Key Management
Personnel. Details of the remuneration of the Directors
of the Company are disclosed below, by each of the categories specified in
IAS24 Related Party Disclosures.
2023 $ 000's 2022 $ 000's
Short-term employee benefits (paid in cash) 637 546
Share-settled payments (*) - 440
Share-based payments - 76
Total 637 1,062
(*) Represents the fair value of shares issued to directors during
the year in settlement of deferred salary and fees, less the total value of
accrued salaries and fees on the date of settlement.
See note 7 for further details of the Directors' remuneration and note 23 for
details of the Directors' share-based payment benefits. Share options that
have been granted to key management personnel are as follows:
Tranche A Options Tranche B Options Tranche C Options Tranche D Options Total
Iain McKendrick 28,000,000 28,000,000 28,000,000 28,000,000 112,000,000
Eytan Uliel 85,000,000 85,000,000 85,000,000 85,000,000 340,000,000
Simon Potter 18,500,000 18,500,000 18,500,000 18,500,000 74,000,000
Stephen Bizzell 18,500,000 18,500,000 18,500,000 18,500,000 74,000,000
Total 150,000,000 150,000,000 150,000,000 150,000,000 600,000,000
There is no ultimate controlling party of the Group.
Other related party transactions
Transactions between the Company and its subsidiaries during the year are as
follows:
27 Events after the reporting period - Group & Company
On 6 March 2024, the Group announced that it and its wholly-owned Uruguayan
subsidiary, CEG Uruguay SA have entered into a farm-out agreement (the
"Transaction") with Chevron Uruguay Exploration Limited, a wholly-owned
subsidiary of Chevron Corporation, related to a 60% interest in the AREA OFF-1
block, offshore Uruguay. The primary terms of the Transaction include a
payment to the Group of US$12.5 million cash on completion of the Transaction.
Completion and financial close of the Transaction are subject to the
satisfaction of conditions precedent and customary third-party approvals from
the Uruguayan regulatory authorities, which are anticipated to finalise in the
near-term.
On 11 March 2024, the Group announced that following final regulatory
approvals being granted, the AREA OFF-3 licence, offshore Uruguay, was signed
in Montevideo on 7 March 2024. Accordingly, AREA OFF-3's first exploration
period commenced on 7 June 2024, and runs for four years, until 6 June 2028.
On 18 April 2024, the Group announced that it had entered into a legally
binding term sheet for an investment by Charlestown Energy Partners LLC,
whereby Charlestown will invest £1.5 million in the Group, initially in the
form of a loan, which upon closing of the AREA-OFF-1 farm-out to Chevron and
subject to prior completion of an agreed share consolidation shall convert at
a fixed price of 0.168 pence per share (being approximately a 20% premium to
the current share price at the date of the announcement) and resulting in a
shareholding of approximately 8.7% of the Group. It was subsequently announced
on 7 May 2024 that the long-form legal documentation for the Charlestown loan
had been finalised in line with the original term sheet as detailed on the 18
April, and the loan proceeds were received on 28 May 2024.
On 28 May 2024, the Group announced that Mr. Robert Bose joined the Board
following the completion of the investment in the Company by Charlestown
Energy Partners LLC.
28 Comprehensive income/(expense) for the year - Company
The Company's loss after tax for the year was $9,070,000 (2022: profit of
$1,330,000).
Corporate Directory
Company
Number
Registered in the Isle of Man with registered number 123863C
Current
Directors
Iain
McKendrick
Eytan Uliel
Non-Executive
Chairman
Chief Executive Officer
Simon
Potter
Stephen Bizzell
Non-Executive
Non-Executive
Robert Bose
Non-Executive
Secretary
Benjamin
Proffitt
Jonathan Gilmore
Company
Secretary
Joint Company Secretary
Registered Office
and The
Engine House
Corporate Headquarters
Alexandra Road,
Castletown
Isle of Man
IM9 1TG
Registrar
Link Market Services (IOM) Limited
PO Box 227
Peveril Buildings
Peveril Square
Douglas
Isle of Man
IM99 1RZ
Auditor
Grant Thornton
13-18 City Quay
Dublin 2
Ireland
Principal Legal
Advisors Clyde
& Co
St Botolph Building
138 Houndsditch
London
EC3A 7AR
United Kingdom
Nominated
Advisor
WH Ireland
24 Martin Lane
London
EC4R 0DR
United Kingdom
Joint
Brokers
WH
Ireland
Zeus Capital PLC
24 Martin
Lane
125 Old Broad Street
London
London
EC4R
0DR
EC2N 1AR
United Kingdom
United Kingdom
ENDS
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