REG - Predator O&G Hldgs - Report and Interim Financial Statements
19/09/2025 07:00
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RNS Number : 9613Z Predator Oil & Gas Holdings PLC 19 September 2025
FOR IMMEDIATE RELEASE
19 September 2025
Predator Oil & Gas Holdings Plc / Index: LSE / Epic: PRD / Sector: Oil
& Gas
Predator Oil & Gas Holdings Plc
("Predator" or the "Company" and together with its subsidiaries "the Group")
Report and Interim Financial Statements for the 6 months to 30 June 2025
Financial highlights:
· Fully funded to satisfy all commitments for the next twelve
months
· Expanded the portfolio of producing assets in Trinidad in order
to achieve economies of scale ; taken critical steps in Morocco to finance and
monetise near-term oil and gas development projects; facilitated future
opportunities to pursue "blue sky" exploration potential for gas and helium in
Morocco.
· First oil revenues realised in Trinidad: £66,815 (2024: £0)
· Loss from operations for the 6 months period includes
administrative expenses of £821,277 (£872,485 for the 6 months period ended
30 June 2024) and the non-cash flow item of £ 1,176,935 (2024: £169,044) for
share-based payments. The total loss attributable to shareholders comprised
£1,634,890 (2024: £978,238)
· Cash balance, at period end of £2,578,090 (2024 year end:
£3,813,371).
· A further £1,093,425 (US$1,500,000) held as restricted cash
· £2,000,000 (before expenses) raised through a placing of 50
million shares at 4.0 pence per share. 10,000,000 warrants have been granted
at 6 pence per share, exercisable within 3 years from 10 February 2025;
4,441,641 shares issued in settlement of a US$250,000 deposit required for the
acquisition of a Trinidad based group of companies
· Shareholder dilution minimized to enhance growth potential
· No loans.
· Negotiations progressing to extend First Extension Period of the
Guercif Petroleum Agreement to 5 November 2026
· Issued share capital 666,316,395 ordinary shares (31 December
2024: 611,874,754 )
Operational highlights:
· Onshore Morocco MOU-5 well was successfully drilled without any
operational incidents
· Helium show on gas chromatograph consistent with Company's
geological model for helium generation
· Post well evaluation confirms the well significantly down-dip
from the culmination of the structure to the northwest
· Presence of mobilised salt, confirmed for the first time in the
area, sets up the potential for an additional deeper Triassic target with
geological analogues at the Meskala and Tendrara gas fields in Morocco and
Hassi R'Mel gas field in Algeria
· Denser seismic coverage required
· Preparations to test the "A" Sand in MOU-3 with, for the first
time, the larger perforating guns
· Memorandum of Understanding executed for the purchase natural
gas; designing, funding, constructing and operating an LNG distribution
network; and to provide the services of selling and distributing LNG to
industrial and commercial users in Morocco
· There has been no change in biogenic gas resources from the last
Independent Technical Report in June 2024
· Onshore Trinidad the acquisition of Caribbean Rex Limited and its
sole asset the Bonasse Field was completed
· There are no outstanding work programme commitments on the
Ministry Licence
· As a consequence of the acquisition the Company was able to
establish a sales point for the Bonasse Field oil at the South Erin gathering
facility
· A Production and Field Services Management Agreement was executed
with NABI Construction (Trinidad and Tobago) Limited ("NABI") whereby the
Company was relieved of the burden of funding field operating costs, workover
and drilling costs in lieu of receiving 30% of gross sales revenues less tax
and royalty and 20% of gross sales revenues less tax and royalty for infill
drilling after recovery of NABI's drilling costs.
· NABI performed 6 light well workovers to restore the Bonasse
Field to initial start-up production.
· Planning for up to 2 heavy workovers and one infill development
well is progressing for execution later in 2025
· The acquisition of the entirety of all of the Challenger Energy
Group's businesses, producing assets and operations in Trinidad subject to
regulatory consent
· Completion is anticipated during Q3 2025
· Upon approval the acquisition will immediately add up to 285 bopd
and increase the Company's revenues from production
· It is anticipated that the Company will manage the producing
assets under similar arrangements with NABI as for the Bonasse field
· The acquisition will provide the Company with the organisational
structure, logistical support and access to facilities and contractual
arrangements necessary to progress the appraisal and testing of the Cory
Moruga Exploration and Production Licence Snowcap-1 oil discovery through the
stages of development, transport and sale of oil production
· Two heavy workovers of existing wells in Cory Moruga are planned
to be carried out in 2025.
· Preparations for drilling Snowcap-1 Q1/Q2 2026 are progressing
and a rig has been identified and inspected for reactivation
· 2C/2P of 1.4/12.91M barrels of oil resources for the Snowcap
structure remain unchanged from the last Independent Technical Report dated
January 2024
· Appraising and developing the Snowcap-1 discovery remains the
core asset for the Company in Trinidad with the potential to deliver at
initial production rates requiring a sales point with no capacity constraints
and a sensible commercial handling fee.
The acquisitions announced in the period under review increases
the Company's footprint and visibility in Trinidad, which in turn creates more
options for establishing a sales point for the Cory Moruga oil
· Offshore Ireland the application for a successor authorisation to
the Corrib South Licensing Option
16/26 is still progressing. At the end of the reporting period the GSRO
indicated that the process was near completion but once again asked for
additional clarification of financial information.
Post reporting date:
On the 1 July 2025 the Company agreed mutually with the Seller to further
extend the date for closing of the sale and purchase transaction to acquire
Challenger Energy Group Plc's business and operations in Trinidad and Tobago
to 7 days after the granting of regulatory approval, with a revised longstop
date of 30 August 2025.
On the 21 July 2025 the Company announced the commencement of the MOU-3 well
intervention and rigless testing operations for the "A" Sand.
On the 21 July 2025 the Company announced the Placing of 20 million new
ordinary shares of no par value in the Company to raise £1M (before expenses)
primarily to be used in lieu of the share consideration due to Challenger
Energy Group Plc on closing of the acquisition of that company's business and
operations in Trinidad and Tobago but also to provide additional working
capital to support future operations in Trinidad and Morocco.
On the 31 July 2025 the Company released an update on the MOU-3 "A" Sand
perforating programme, using for the first time the larger 27/8" perforating
guns, indicating successful perforation and the recovery of samples from the
zone of formation damage. The well was shut in to assess potential for
clean-up and pressure build-up over time. Operations were performed under the
forecast budget. Information was collected to assist with preparing a new well
design and mud programme for an MOU-6 appraisal/development well. There has
been no change to previously released estimates of gas resources.
On the 1 September 2025 the Company announced the Completion of the
acquisition of Challenger Energy Group Plc's business and operations in
Trinidad and Tobago with an effective date of 29 August 2025. A Production and
Field Services Management Agreement with NABI Construction (Trinidad and
Tobago) Limited was executed under which the Company receives 30% of gross
revenues less taxes and royalties from existing production of 285 bopd and 15%
of gross revenues for enhanced production until 100% recovery of NABI costs in
13 heavy well workovers and infield drilling over the next 24 months. The
Company has no exposure to field operating costs nor investment in the firm
licence obligations involving well workovers and drilling and historical
licence liabilities. The acquisition provides the Snowcap downstream
logistical support, additional gathering stations, sales tanks, service
equipment, workover rigs, for development and sale of oil into a pipeline
entry point.
On the 8 September the Company announced the appointment of Equiom Corporate
Secretaries (Jersey) Limited as Company Secretary with effect from 5 September
2025.
Predator Oil & Gas Holdings Plc (PRD), the Jersey-based Oil and Gas
Company with near-term hydrocarbon operations focussed on Morocco and
Trinidad is pleased to announce its unaudited interim results for the
six-month period ended 30 June 2024.
Chairman's Statement:
On behalf of the Board of Directors I am pleased to present the unaudited
interim results for Predator Oil & Gas Holdings plc ("the Group",
"Predator" or the "Company") for the six-month period ended 30 June 2025.
The first half of this year has been another very active period of operations
for the Company, in both its core areas of Trinidad and Morocco. Despite the
drilling, field rehabilitation and corporate acquisition activity the Company
has kept administrative costs below those for the corresponding period in
2024.
In Trinidad the Company has strengthened its position through acquisitions to
establish a revenue-generating business with significant potential for
production growth. The first step of this process was gaining an interest in
the Bonasse Field in February, which was followed by the larger transaction of
acquiring Challenger Energy's onshore production in three fields, which was
recently completed. Predator now has a solid oil production base in Trinidad
with many opportunities to increase this through workovers, infill and
appraisal drilling and the application of new wax treatment technology.
Investment in firm and discretionary commitments has been achieved at no cost
to the Company through an agreement with a highly experienced local service
contractor. Similarly, the Company has no exposure to field operating
expenses. In return the Company receives a percentage of up to 30% of the
gross revenues from the sale of oil. This is an attractive arrangement that
reduces the Company's financial and funding risks. It also allows the senior
management teams to focus on potentially high value projects and further
acquisitions.
Within the Trinidad portfolio there are significant opportunities to increase
reserves and production and the first one of these to be targeted is the
Snowcap-3 appraisal well in 2026, planning for the drilling of which is
progressing using an in-country rig.
In Morocco the MOU-5 exploration well operations, targeting the large
Titanosaurus prospect, went smoothly and cost-effectively. As can be expected
in exploration, the results came up with some surprises. With the presence of
unexpected salt, the location proved to be considerably downdip from the
crest, however a new deeper reservoir was found, water wet in this location,
but offering a new exploration target. Helium was recorded in the well and the
global shortage of this important gas is driving exploration for additional
resources. Predator's Moroccan acreage is well place for further exploration
with emphasis on helium and developing a potential Triassic target within the
structure tested by MOU-5.
Whilst the rig-less testing of the MOU-3 well did not produce the flow of gas
that had been hoped for, the larger perforating guns were successful in
penetrating through to the reservoir sands. Samples collected showed the
impact of over-balanced drilling with heavy drilling mud. The information
collected will provide the data with which to design the programme to unlock
these potentially significant biogenic gas resources discovered by the
Company. Whilst drilling MOU-1 and MOU-3 especially, gas shows were recorded,
but once the mud weight reached a critical threshold gas entry into the wells
was suppressed and in other wells potentially totally suppressed by the
over-balanced drilling. Underpinning the opportunity that our drilling has
created is the new Memorandum of Understanding that was executed with a
downstream pan-African entity. This agreement proposes to fund, construct,
operate and create a pilot micro-LNG business at no cost to the Company,
supported by the potential gas resources around the MOU-3 well.
The third area of the Company's activities is offshore Ireland. The Corrib
Field, Ireland's only gas producing field, continues its decline toward
cessation of production. It would be absurd, particularly given the very high
costs associated with the Corrib Field development, if production should cease
without the exploration of the satellite prospects, such as Predator's Corrib
South. However, sufficient progress has not been made with the Irish
Government and regulatory authorities to award a successor authorisation to
licensing option 16/26 despite the requisite information being provided by the
Company. It may take a dramatic collapse of the energy supply in Ireland, as
occurred in Spain, Portugal and SW France in 2025, before Ireland fully
understands the issue of security of energy supply and the potentially
devastating consequences for the IT, Pharma and Data Centre sectors before
common sense prevails. Remaining engaged with the regulatory authorities is
therefore a sensible option for the Company.
To conclude, I would like to thank existing shareholders for their support and
new shareholders for our recent fund raisings, which have allowed Predator to
continue to pursue a high level of diverse operations and to make strategic
acquisitions. This allows us to maintain a debt-free status and cushions us
from the burden of interest payments and debt repayments that can curtail
growth. We look forward to growing our company further through the rest of
2025 and beyond through the same strategy of acquiring and rehabilitating
producing assets with incremental production potential; exposure to large
scale upside with a moderately higher risk profile; and using management's
creativity and experience to develop new opportunities. At some point in the
growth cycle critical mass may be reached that potentially generates a
divestment opportunity of a well-managed asset.
Stephen Boldy
Non-Executive Chairman
Operational review
Morocco
The MOU-5 well was planned to test the Jurassic prospectivity of the
Titanosaurus structure, which covers 187 km2 based on a loose 2D seismic grid.
The pre-drill reservoir target was a Domerian (earliest Jurassic) carbonate
bank with potential reservoir development based on low impedance intervals
interpreted from a seismic inversion model through the well location.
The reservoir caprock was thought to be Jurassic marls and claystones.
Hydrocarbon generation and migration was interpreted to be from deeply buried
Lower Jurassic source rocks fault-juxtaposed with the target reservoirs mainly
off-structure to the northwest, but potentially also to the southeast.
A chromatograph specific for testing for the presence of helium was to be run
in conjunction with a conventional gas chromatograph. The MOU-5 well was
located close to an area of deep faulting and possible granite intrusion that
may have created the right conditions for helium generation and migration.
MOU-5 is a discretionary well that is not part of the Guercif licence
commitment for the First Extension Period.
On Completion of the MOU-5 well it was intended to use the discretionary well
to extend the First Extension Period to 5 November 2026 and to re-negotiate
the remaining 3D seismic commitment to defer into the Second Extension Period
and/or convert into a 2D seismic reconnaissance programme.
During the period under review a limited amount of the larger 27/8"
perforating guns became available in Morocco for the first time. It was
decided to use these to perforate the "A" Sand in MOU-3, where gas inflow into
the well was experienced whilst drilling before the mud weight was increased
to control gas inflow at the first intermediate casing point.
The MOU-3 perforating programme for the "A" Sand was prepared and submitted to
ONHYM for regulatory approval to carry out the operations using explosives.
The key objective of the perforating programme was to evaluate the
effectiveness of the larger perforating guns and to collect samples, using
nitrogen lift, in any perforated formation damage to evaluate the composition
of the formation damage and mud filtrate. By understanding the critical
threshold at which increased mud weight stops gas inflow and, by inference,
suppresses gas shows and the resistivity response of wireline logs in deeply
invaded reservoir sections, it would be possible to better design
appraisal/development wells to avoid formation damage as a result of
over-balanced drilling and so improve the potential for sustainable gas flow
integrity over the expected production life of the independently confirmed gas
resources.
Furthermore, this perforating programme would provide a better assessment of
the effectiveness of perforating with smaller perforating guns and Sandjet.
Various desktop studies were commissioned and are ongoing. The
gravity-magnetic modelling programme is focussed on the deep structure and the
identification of major faults likely to have provided conduits for thermal
gas migration from the Lower Jurassic source rocks, and areas of Hercynian
granites which potentially may are a source of the helium analysed in the
MOU-3 Moulouya Fan biogenic gas sample.
Biostratigraphic, petrographic, mineralogical and geochemical studies have
been initiated for the well cuttings sampled in MOU-5. The scope of the
studies is to interpret the age of the sediments penetrated by MOU-5; nature
of any porosity developed in the primary Jurassic target and additional
reservoirs in MOU-5; organic richness and level of thermal maturity of the
claystones and marls encountered in MOU-5; and X-ray Fluorescence trace
element composition of the allochthonous salt, subsequently encountered in
MOU-5, for exotic presence of Chromium, Lithium and Lead amongst other trace
elements from a potential deep crustal source.
Operations summary
MOU-5 was drilled using Star Valley's Rig 101.
MOU-5 commenced drilling on 3 March 2025 and reached its intended total depth
of 1137.8 metres measured depth on 12 March 2025 without any operational
incidents. Wireline logs (sonic/resistivity) were run from 530 to 1130 metres
measured depth.
MOU-5 was suspended for potential later re-entry and side-tracking updip to
further evaluate the Domerian carbonate bank and helium show and for potential
deepening to the untested deeper Triassic structure beneath MOU-5.
The well was drilled under pre-drill AFE cost estimate.
Results
MOU-5 encountered the primary Domerian carbonate target 205 metres deeper than
the pre-drill prognosis. An unexpected gross interval of 58 metres of higher
velocity anhydrite and salt was encountered in the section originally
interpreted as "Domerian" pre-drill. This interval generated the high and low
impedance contrasts seen on the seismic inversion modelling pre-drill. The
salt is interpreted as allochthonous being of Triassic age. Salt mobilisation
and lateral intrusion generated the divergent seismic geometries originally
interpreted as onlapping Domerian reservoirs.
The Domerian carbonate target in MOU-5 had poor to non-reservoir
characteristics. The programme of desk top studies will help determine the
potential for improved reservoir development within the extensive 187 km2 area
of the carbonate bank development.
MOU-5 encountered a gross interval of 30 metres of sands below the Domerian
carbonate never encountered before in this part of the Guercif Basin. The
gross interval includes zones with potentially attractive reservoir
characteristics.
Gas chromatograph data and wireline logs do not show evidence of the presence
of hydrocarbons. The helium chromatographic registered a show at the base of
the mobilised salt at a potential fault plane based on post-well seismic
interpretation.
Forward plans
MOU-5 drilling results have importantly established for the first time the
presence of Triassic salt in this part of the Guercif Basin.
Limited legacy 2D seismic coverage incorporating the drilling results now
indicates that the salt is potentially thick and extensive and mobilised in a
number of areas.
Additional seismic data are required to infill and extend the legacy 2D
seismic database to better define the salt distribution and the deeper
potential Triassic structures, assisted by the aforementioned gravity-magnetic
modelling programme.
The Trias gas potential is now the focus for future drilling plans. The deep
Triassic structure below MOU-5 bears similarities with the structures hosting
the Meskala and Tendrara gas fields in Morocco and the Hassi R'Mel gas field
in Algeria. The Triassic, which is regionally a proven gas play, is
potentially prospective over the entire 187 km2 area of the Domerian carbonate
bank.
Desktop studies are planned to assess the potential for the presence of the
Triassic TAGI reservoirs beneath the salt and for the occurrence of underlying
Palaeozoic source rocks that may be mature for gas generation.
An advantage of the MOU-5 structure is that it has not suffered deep Jurassic
to Tertiary burial, as indicated by preliminary post-well analyses of well
cuttings, and therefore Triassic TAGI sands, if present, may have preserved
good reservoir characteristics.
In the area tested by MOU-5 the Domerian target is overlain and laterally
isolated by mobilised Triassic salt, which potentially obstructs hydrocarbon
migration pathways. The Jurassic Domerian carbonate bank however remains a
target for follow-up drilling. Additional infill seismic and desktop studies
will focus on the area north of MOU-5 where improved reservoir potential may
exist and salt mobilisation may be less likely to obstruct hydrocarbon
migration from Jurassic source rocks.
The schedule is well advanced to perforate the MOU-3 "A" Sand in the early
part of Q3 2025.
Trinidad
Bonasse field
Completion by T-Rex Resources (Trinidad) Limited ("TRex"), a wholly owned
subsidiary of Predator Oil & Gas Holdings Plc, of the acquisition of a
controlling interest in Caribbean Rex Limited gave the Company operatorship of
the Bonasse oil field in Trinidad's South West Peninsular.
A Production and Field Services Management Agreement was entered into with
NABI Construction (Trinidad and Tobago) Limited ("NABI"), a highly competent
in-country provider of drilling and workover services, equipment and expertise
particular to the producing onshore oil fields in Trinidad. The commercial
terms of this agreement allows the Company to receive 30% of gross sales
revenues after deduction of royalty and taxes from production resulting from
well-workovers of the existing wells in the field. For new wells drilled by
NABI the Company receives 20% of gross sales revenues less royalty and taxes
after NABI has recovered its drilling costs.
The Company has no exposure therefore to field operating costs or investment
by NABI in well workovers and new drilling.
A throughput and services agreement was signed with Steeldrum Oilfields South
Erin Trinidad Limited ("Steeldrum") that allows the Company to sell all crude
oil from the Bonasse field via access to the existing crude oil sales
arrangement and under the same commercial terms and conditions applicable to
Steeldrum under the said arrangement. The Company has access to Steeldrum' s
infrastructure, including a storage unit of 250 barrels capacity until such
time as the Company puts in place additional storage capacity as production
from Bonasse ramps up.
The commercial arrangements allowed the Company to bring the field back into
production following initial investment by NABI in 6 light workovers of former
production wells. An initial 16 bopd has now stabilized at 10 bopd to support
the establishment of Predator as a producing operator in Trinidad. The profile
is constrained at present to align with the available spare storage capacity
at the South Erin gathering station.
The purpose of the agreements that have been put in place is to allow the
Company a period of time to evaluate the technical database and production
history to rank new opportunities capable of delivering material increases in
production in a success case without exposure to initial workover and drilling
costs.
Forward plans
NABI is expected to perform up to new two heavy workovers in the Bonasse field
before the end of 2025 and to drill at least one new infield development well.
Drilling target is likely to be the upper part of the Middle Cruse sands in an
undrained area where an offset well had an initial production rate of 66 bopd
of 19.8° API oil from 43 feet of net oil sand between 986 to 1,252 feet
measured depth.
Oil sampling and downhole bottom conditions for this new well will provide
reliable analytical data with which to model the possible commercial benefits
of a SGN thermochemical wax treatment in both enhancing and sustaining for
longer optimum oil flow rates.
Cory Moruga Exploration and Production Licence
Snowcap-3 well planning continues and a currently stacked rig with the
capability of drilling to 5,500+/- feet has been identified and inspected. A
rig reactivation programme is being put together and it is expected that the
rig will be "drill-ready" by Q1 2026.
The surface well location has been scouted on the ground and the cost of
building an access road and the well pad construction are expected to be
moderate given the favourable site conditions. The preferred surface location
will facilitate the drilling of a vertical well to target the Herrera sands
with the highest initial production rates in the adjoining Moruga West field.
The Herrera #1 Sand for example has an initial production rate of up to 400
bopd in Moruga West and a long production life.
Potential re-entry of the Jacobin-1 and Snowcap-1 wells for heavy well
workovers and SGN thermochemical wax treatment has been assessed. Some of the
critical contractor well services required to execute a well workover
programme have been reviewed and evaluated.
A factor that has been considered is that re-entry into older legacy wells
carry greater operational risk compared to drilling new modern
appraisal/development wells. Snowcap-1 for example may have an initial
production rate of 80 bopd after a successful well workover, whereas a new
penetration of the Snowcap-1 Herrera #8 Sand beyond the drainage area of the
legacy well is forecast to produce initially 200 bopd.
A key facilities issue has been establishing storage and a sales point with
the available capacity to take the expected higher levels of oil production
from the Snowcap and Jacobin-1 workovers and eventually a potentially
successful Snowcap-3 appraisal/development well.
To address this the Company has been focused on closing out the acquisition of
Challenger Energy Group Plc's entire business and operations in Trinidad and
Tobago. On Completion this will add up to 285 bopd of production. Importantly
the acquisition would provide the Snowcap downstream logistical support for
development and sale of oil into a pipeline entry point.
Forward plans
Prioritise the reactivation programme and well planning, contracting of well
services for the Snowcap-3 appraisal/development well, provisionally scheduled
to be drilled in Q1 2026.
Complete the acquisition of Challenger Energy Group Plc's entire business and
operations in Trinidad and Tobago and re-organise and rationalize resources to
provide economies of scale across the Company's portfolio of Trinidad assets.
Potentially replicate the Bonasse Production and Field Services Management
Agreement with NABI Construction (Trinidad and Tobago) Limited to include
Snowcap-1 and Jacobin-1 well workover activities and the Goudron,
Inniss-Trinity and Icacos fields forming the principal assets of the
transaction to acquire Challenger Energy Group Plc's entire business and
operations in Trinidad and Tobago.
This would relieve the Company of the burden of performing field operations
and free up management resources and capital to deploy on material growth
opportunities such as the drilling of Snowcap-3. Contingent and Prospective
2P/2C oil resources of 14.31M barrels have been assigned to the Snowcap
appraisal and development project based on an Independent Technical Report
produced by ScorpionGeoscience dated January 2024.
Ireland
Company strategy is to focus on satisfying the financial criteria determined
by the GSRO within the DECC to secure the award of a successor authorisation.
The Company received from the GSRO a request for further clarification of the
financial information it provided to the GSRO on 24 December 2024, six months
after submitting the supporting financial information.
The Company is considering its response to the GSRO's request.
Financial review:
The Company reported an operating loss for the 6 months period of £1,650,743
(£978,238: for the 6 months period ended 30 June 2024). The increase in
operating loss is primarily attributable to the £1,176,935 charge for
share-based payments. This charge does not involve a cash outflow.
Administrative expenses for the period to 30 June 2025 totalled £821,277
compared to £872,485 incurred in the six months to 30 June 2024. This
reduction is attributable to tighter control of corporate overheads mostly due
to a headcount reduction of advisors. Fair value expense of share options
comprised £ 1,176,935 (£169,044 for the 6 months period ended 30 June 2024).
The increase is primarily due to the increase in share-based payments in the
six months to 30 June 2025.
The Company is finishing the reporting period with cash reserves of
£2,578,090 (2024: full year £3,813,371) and restricted cash of £1,093,425
(2024: full year £1,195,377) in the form of the security deposit for the
Guercif Bank Guarantee in favour of ONHYM.
£2,000,000 (before expenses) has been raised through the placing of 50
million ordinary shares at a placing price of 4 pence per share. 10,000,000
warrants have been granted at 6 pence per share, exercisable within 3 years
from 10 February 2025.
4,441,641 shares were issued to Challenger Energy Group Plc to satisfy the
terms of a cash equivalent US$250,000 deposit to secure a period of
exclusivity to acquire the Challenger Energy Group's Plc's business and
operations in Trinidad and Tobago
On 20 February 2025, the Company issued 45,000,000 share options to executives
at an exercise price of 5.5p with vesting conditions applying.
The acquisition of two operating companies in Trinidad by the Group's wholly
owned subsidiary T-Rex Resources (Trinidad) Limited was effected during the
period under review. 51% of the issued share capital of Caribbean Rex Limited
was acquired for a consideration of US$1. Caribbean Rex Limited subsequently
acquired 100% of the issued share capital of CEG Bonasse Limited for a
consideration of US$1.
During the period under review the Company commenced production in Trinidad
and began to generate oil sales and an operating income.
The Company has no loans nor outstanding directors' loans.
The Company is well-capitalised for its committed work programmes over the
next 12 months, free of loans and is in a position to deploy prudent levels of
administrative expenditure focused on enhancing and promoting the potential of
the Company's portfolio
Summary
During the period under review, the Company has completed the drilling, under
budget forecast, of the discretionary MOU-5 well in the Guercif licence
onshore Morocco. This was a play-opening well, based on the unexpected
presence of salt, for the previously unrecognised Triassic potential, which is
a proven and well understood target in the Moroccan and Algerian gas fields of
Meskala, Tendrara and Hassi R'Mel. The pre-drill Jurassic target was
encountered confirming the Jurassic play concept but seismic is required to
find the optimum location to the northwest of MOU-5 to test the Jurassic play
in an area where reservoir development may be better developed and potential
oil and/or gas migration from mature Lower Jurassic source rocks can be better
demonstrated in areas not impacted by salt mobilisation. The Trias is an
important new target that offers future growth potential for the Company.
MOU-5 also encountered a helium show which supports the case, and taking into
consideration the helium sampled in the Moulouya volcani-clastic fan in MOU-3,
for helium migration via fractures from a deep crustal source.
Preparations for rigless testing of the "A" Sand in MOU-3, using for the first
time the larger perforating guns, are well advanced.
The testing programme is expected to provide key information on the nature of
the formation damage caused by over-balanced drilling. Desk-top studies are
improving the understanding of the biogenic gas reservoirs encountered to date
in the MOU-1, MOU-2 and MOU-3 wells. These reservoirs are specific to this
area of the Guercif Basin and have no analogues in the gas-producing Rharb
Basin but have been encountered in other parts of the world. It is critical to
understand how the biogenic gas is distributed in these sequences as the
potential may also exist for additional unconventional gas targets.
The Company is pleased to have executed a Memorandum of Understanding for a
pilot micro-LNG project for the biogenic gas that, if a decision to develop is
taken, would relieve the Company of the burden of financing the facility and
the operation and funding of the micro-LNG distribution network to the
Moroccan industrial centre.
Onshore Trinidad we have completed the acquisition of a controlling interest
in Caribbean Rex Limited for no Consideration.
A Production and Field Services Management Agreement was entered into with
NABI Construction (Trinidad and Tobago) Limited for a share of gross sales
revenues less taxes and royalty. Together these transactions have allowed the
Company to establish its first production revenues relieved from the burden of
financing investment in well workovers and drilling and field operating costs.
This has given us the platform and framework of commercial transactions to
progress the acquisition of Challenger Energy Plc's business and operations in
Trinidad and Tobago as an intermediate step to production growth and economies
of operating scale and efficient deployment of resources across our expanding
portfolio of assets.
Snowcap-3 drilling plans are progressing with the identification and
inspection of a suitable rig that is currently stacked awaiting
reactivation. A successful completion of the acquisition of Challenger's
business and operations in Trinidad and Tobago would provide the Snowcap
downstream logistical support for the development and sale of oil into a
pipeline entry point thereby consolidating the production growth strategic
objective during 2026.
Ireland remains a project that is dependent for future realisation on a
third-party regulatory process that the Company has no control over. Until
such time as the regulatory process concludes the Company is not funding any
further work.
We look forward over the next 12 months to concluding further acquisitions in
Trinidad, stimulating production growth under our agreement with NABI, and
preparing to drill Snowcap-3 in 2026. In Morocco we shall continue to focus
on unlocking the biogenic gas potential already established. Desktop studies
to enhance the Trias play concept and the potential for helium will be
undertaken to enhance the overall attractiveness of the Guercif licence.
Paul Griffiths
Chief Executive Officer
Paul Griffiths, Chief Executive Officer of Predator, commented:
"The Interim Financial Statements for the period to 30 June 2025 demonstrate
that we are well capitalised to fund our current work commitments over the
next 12 months. We have established production and revenues through an
acquisition and have entered into agreements in both Morocco and Trinidad that
relieves the Company of the burden of investment and operating costs in field
rehabilitation and potential downstream facilities and gas distribution. This
gives us a stable platform for production growth.
We have continued to generate discretionary drilling opportunities for high
impact rewards. MOU-5 confirmed the presence of the Jurassic target and helium
potential but unexpectedly opened up a new Triassic objective for further
evaluation. Without the MOU-5 well this would never have been possible.
Snowcap-3 will be the next drilling project in 2026. It offers material
production potential and will evaluate multiple reservoir targets.
Critically Snowcap-3 is the chance to establish a new light oil field
development utilising the Company's acquired tax losses and recently
established operating framework. It is an offset well to the producing Moruga
West field which has over 50 years of production history from the same
reservoirs as being targeted by Snowcap-3.
We have maintained a debt free status and, despite the increase in corporate
activity, have reduced administrative costs.
The outlook for the next 12 months is positive and filled with operational
activity. M & A is also a strategy at corporate level if and when the
right opportunities present themselves. Our in-house team has used practical
experience, creativity and expertise in carrying transactions across the line
without the requirement for expensive third-party input. Substantive progress
has been achieved by our team against the background of volatility in the
financial and public markets caused by global events. We see this as an
opportunity and not an excuse."
Paul Griffiths
Chief Executive Officer
18 September 2025
For further information visit www.predatoroilandgas.com (about%3Ablank)
Follow the Company on X @PredatorOilGas.
This announcement contains inside information for the purposes of Article 7 of
the Regulation (EU) No 596/2014 on market abuse.
For more information please visit the Company's website
at www.predatoroilandgas.com (about%3Ablank) :
Enquiries:
Predator Oil & Gas Holdings Plc Tel: +44 (0) 1534 834 600
Paul Griffiths Chief Executive Officer Info@predatoroilandgas.com (about%3Ablank)
Novum Securities Limited Tel: +44 (0)207 399 9425
David Coffman / Jon Belliss
Flagstaff Strategic and Investor Communications Tel: +44 (0)207 129 1474
Tim Thompson predator@flagstaffcomms.com (about%3Ablank)
Mark Edwards
Fergus Mellon
Notes to Editors:
Predator is an oil & gas company with a diversified portfolio of assets
including unique and highly prospective onshore Moroccan gas exposure and
production, appraisal and exploration projects onshore Trinidad.
Morocco offers a potentially faster route to commercialisation of shallow
biogenic gas through a CNG or micro-LNG development. The MOU-3 well is
currently the focus of rigless well testing activities following the
perforation of the shallow "A" Sand and shut in of the well to observe for
potential reservoir clean-up and pressure build-up over time. Moroccan gas
prices are high, and the fiscal terms are some of the best in the world.
Trinidad offers the security of a mature onshore oil province that has been
producing hydrocarbons for over 50 years. Predator is assembling a portfolio
of onshore producing fields with opportunities for production enhancement and
additional infill development and appraisal drilling. Significant legacy tax
losses, economies of scale and the application of new low-cost technologies
are factors that can improve profit margins per barrel of oil produced.
Predator has an experienced management team with particular knowledge of the
Moroccan and Trinidad sub- surface and operations.
Predator Oil & Gas Holdings plc is listed on the Equity Shares
(transition) category of the Official List of the London Stock
Exchange's main market for listed securities (symbol: PRD).
For further information, visit www.predatoroilandgas.com
(https://www.predatoroilandgas.com/)
Going Concern:
The preparation of financial statements requires an assessment on the validity
of the going concern assumption. At 30 June 2025 the Group held £2.6 million
in cash. At the date of these financial statements the Directors do not expect
that the Group will require further funding for the Group's corporate
overheads, the Moroccan Guercif licence, the Trinidad Cory Moruga and Bonasse
licences and the application for a successor authorisation to Licensing Option
16/26 in Ireland.
In Morocco the Group has successfully completed the drilling of a
discretionary well MOU-5 under the forecast pre-drill budget. A proposal has
been submitted to ONHYM to extend the current First Extension Period of the
Guercif Petroleum Agreement to at least 5 November 2026. It is proposed that
the completed MOU-5 discretionary well be treated as additional work programme
for the First Extension Period with the remaining 3D seismic commitment being
converted to a 2D seismic commitment and potentially added to the seismic
programme for the Second Extension Period.
Planning and contracting of well services for rigless testing of the "A" Sand
in MOU-3 was almost complete by the end of the period under review.
The objective of the "A" Sand testing programme is to assess the performance
of the larger 27/8" perforating guns that had previously not been available
for the earlier phases of rigless testing of MOU-1 and MOU-3. Results from
this testing programme are forecast to confirm formation damage as a
consequence of using higher mud weights than required to control borehole
stability, leading to significantly over-balanced drilling in MOU-1, MOU-2,
MOU-3 and MOU-4 and suppression of reservoir pressures that restrict gas flow
into the wellbore. Results from the rigless testing of MOU-3 are expected to
provide information on the presence, depth and nature of formation damage and
the range of well-intervention options available to penetrate the formation
damage and stimulate gas flow.
Confirmation of formation damage would support the existing NuTech
petrophysical log interpretation for the presence of gas reservoirs in MOU-1,
MOU-3 and MOU-4 and for the presence of gas in MOU-2 as indicated from gas
samples whilst drilling the shallow section equivalent to that in MOU-3.
There has been no impact on Contingent Gas Resources for MOU-1, MOU-2, MOU-3
and MOU-4, as defined in the last Independent Technical Report by
ScorpionGeoscience dated 21 June 2024.
On 6 May 2025 Vivo Energy Maroc SA were granted exclusivity to design, fund,
construct and operate a micro-LNG facility and distribution network with an
initial pilot capacity of up to 5M cfg/day. This relieves the Group of any
exposure to development costs and also provides a potential lending facility
based on gas resources for any additional appraisal and development drilling
that may be contemplated as part of a strategy to grow the gas business
targeting Morocco's industrial market.
In Trinidad in the period under review the Completion of the acquisition of
CEG Bonasse Limited (changing its name to Steeldrum Petroleum Cedros Limited)
by Caribbean Rex Limited (changing its name to Steeldrum Ventures Group (St.
Lucia) Limited) for a Consideration of US$1 has established a sales point into
the Heritage oil pipeline infrastructure at South Erin with the initiation of
production and revenue income attributable to the Group. As of 30 June 2025,
accrued sales revenues was £66,815.
The Group executed a Production and Field Services Management Agreement with
NABI Construction (Trinidad and Tobago) Limited ("NABI") for the Bonasse Field
whereby the Group receives 30% of gross oil sales revenues less royalties and
taxes due after 75% offset against tax losses. All field operating costs and
investment in well workers and infill development drilling are borne 100% by
NABI. For infill development drilling, which is subject to AFE approval by the
Group, the Group receives 20% of gross oil sales revenues less royalties and
taxes after 100% cost recovery of NABI's drilling costs. To date six light
well workers have been completed to bring wells back onto production. NABI is
preparing for up to two heavy workovers and an infill development well in 2025
that are expected to significantly increase current production if future
operations are successful.
Completion of the acquisition of CEG Goudron (Trinidad) Limited, CEG
Inniss-Trinity (Trinidad) Limited and CEG Icacos (Trinidad) Limited is set to
occur in Q3 2025 after being paused to allow for the results of the General
Election in Q2 2025 in Trinidad and Tobago to be assessed following a change
in the Government and key positions in the oil and gas sector.
The acquisition includes three currently producing fields: Icacos (a Ministry
licence) and Inniss-Trinity and Goudron (Heritage Incremental Production
Services Contracts).
Upon Completion the Group will execute a Production and Field Services
Management Agreement with NABI Construction (Trinidad and Tobago) Limited for
the three fields whereby the Group receives 30% of gross oil sales revenues
less royalties and taxes due after 75% offset against tax losses and 15%% of
gross oil sales revenues less royalties and taxes from new drilling without
NABI first recovering drilling costs. All field operating costs and investment
in well workers and infill development drilling are borne 100% by NABI.
Currently the fields are producing at a cumulative rate of up to 285 bopd and
will be generating sales revenues for the Group in Q3 2025. NABI, at their
cost, will invest in up to 13 Heavy Workover Wells over the next 12 months,
which, if operations are successful, are forecast to increase overall field
production to up to 407 bopd by Q3 2026. NABI will also drill at their cost an
infill development well to satisfy licence obligations.
Currently two heavy workovers (Snowcap-1 and Jacobin-1), with the possible
application of wax treatments, are still being reviewed for the Cory Moruga
Exploration and Production Licence. The work programme has been delayed to
allow for implementation of the Bonasse Field Production and Field Services
Management Agreement with NABI and a period of time to measure its commercial
benefits to the Group. In addition, the Cory Moruga work programme is
projected to result in, if operations are successful, significant daily oil
production which currently has no sales point. It is not practical or
commercially sensible to store production on site until a sales point is
agreed with Heritage or another operator, or to truck oil long distances to
another sales point. The Group expects negotiations for a sales point to be
concluded in Q3 2025.
Given the successful implementation and working of the Bonasse Production and
Field Services Management Agreement with NABI so far, the Group favours
allowing NABI to carry out the two Cory Moruga heavy workovers on the same
terms as agreed for the Group's other fields.
The Group's primary objective is to drill an appraisal/development well
("Snowcap-3") on the Snowcap field in the Cory Moruga licence in Q1/Q2 2026.
This is potentially a high impact well that aligns with the Group's strategy
of increasing production growth over the next 12 months. Based on offset
production data for the Moruga West field the Group projects an initial well
productivity of 300 to 400 bopd from Snowcap-3.
There may be significant cost savings for the Group by apportioning operating
costs and administrative costs over a larger portfolio of producing assets.
Pursuant to placings executed on 5 February 2025 and 21 July 2025 total
capital of £3.0 million before expenses, has been raised. A quantum of
these funds were applied to drilling MOU-5 in Morocco, which was drilled
significantly under-budget forecast. The MOU-3 "A" Sand rigless testing
scheduled for Q3 2025 is fully funded as is the re-negotiated cash payment to
Challenger Energy Group Plc of US$ 400,000 upon Completion of the transaction
to acquire the Challenger Energy Group's business and operations in Trinidad
and Tobago. Cash Consideration as opposed to shares prevents the risk of a
"share overhang" at a time when the Group is seeking to strengthen its market
capitalisation to reflect assets that are being acquired. Further
Consideration for the transaction will not arise within the next 12 months and
will be subject to verification of the warranties provided by the Challenger
Energy Group under the Sale and Purchase Agreement.
The Group is seeking to preserve cash whilst maintaining the ability to grow
production, as is prudent given the volatile market conditions and global
economic uncertainty that exist. The Group maintains a readiness to exploit
near-term high impact opportunities for production growth where the funding of
any such opportunity is supported by risk versus reward metrics. A key
attribute of the financial strategy has been not to enter into any
interest-bearing loan arrangements that could restrict the flexibility of the
Company's control over its assets.
Discretionary cash resources, which include no contribution from production
revenues, will be utilized to plan and prepare for appraisal/development
drilling MOU-6 in Morocco and Snowcap-3 in Trinidad.
Timing of discretionary drilling is solely within the Group's control.
The Group has multiple funding options which may include any one of the
following or a combination thereof:
• Production revenues
• Reserves-based lending
• Expansion of the NABI Production
and Field Services Management Agreement
• Tax efficient sale of a
rehabilitated producing asset in Trinidad for profit and settlement of any
remaining liabilities.
·
Private equity investment in any or all of the subsidiaries of the Group.
· The
Group has full control of its assets with no third party Joint Venture
partners with pre-emption
Rights, giving it maximum flexibility to sell
assets opportunistically,
· The Group has a track record over seven
years of successfully raising funds in the equity market to
support its operations during the early stages of business development.
Post the period under review it has been announced that ExxonMobil is taking a
large position in Trinidad with a committed expenditure of US$ 42.5M and a
speculative US$16.4 to 21.7B spend on development if initial seismic and other
technical studies are successful. The impact of ExxonMobil's entry into
Trinidad may lift the value of all oil and gas assets and increase the
appetite of potential investors in the same way as ExxonMobil's success in
Guyana has been received.
Directors are confident that the Group will be able to meet its
non-discretionary financial requirements over the course of the next 12 months
until such time as production revenues can carry the 12-month Going Concern
working capital forecast thereafter.
Predator Oil & Gas Holdings Plc
Condensed consolidated statement of comprehensive income
For the 6 months to 30 June 2025
01.01.2025 to 30.06.2025 01.01.2024 to 30.06.2024
(unaudited) (unaudited)
Notes £ £
Revenue 3 66,815 -
Administrative expenses 4 (821,277) (872,485)
Share based payments 5 (1,176,935) (169,044)
Operating loss (1,931,397) (1,041,529)
Finance income 28,578 37,936
Loss for the period before taxation (1,902,819) (1,003,593)
Taxation - -
Loss for the period after taxation (1,902,819) (1,003,593)
Other Comprehensive income
Exchange differences on translation of foreign subsidiaries 252,076 25,355
Loss for the period (1,650,743) (978,238)
Loss for the period attributable to:
Non-controlling interest (15,853) -
Owners of the parent (1,634,890) (978,238)
(1,650,743) (978,238)
Loss per share basic and diluted (pence) 6 (0.250) (0.242)
Predator Oil & Gas Holdings Plc
Condensed consolidated statement of financial position
As at 30 June 2025
30.06.2025 31.12.2024
(unaudited) (audited)
Notes £ £
Non-current assets
Tangible fixed assets 9 7,370 1,144
Intangible asset 7 24,673,364 21,623,394
Trade and other receivables 10 1,093,425 1,195,377
25,774,159 22,819,915
Current assets
Trade and other receivables 10 355,206 213,327
Cash and cash equivalents 11 2,578,090 3,813,371
2,933,296 4,026,698
Total assets 28,707,455 26,846,613
Equity attributable to the owner of the parent
Share capital 12 37,707,584 35,509,502
Reconstruction reserve 283,734 403,734
Warrants issuance cost 14 (1,374,041) (1,374,041)
Share based payments reserve 14 3,650,845 2,473,910
Retained deficit (16,312,759) (14,677,868)
Total equity attributable to the owner of the parent 23,955,363 22,335,237
Non-controlling interest (15,853) -
Total Equity 23,939,510 22,335,237
Current liabilities
Trade and other payables 13 4,100,173 4,511,376
Non-Current liabilities
Provisions 13 667,772 -
Total liabilities 4,767,945 4,511,376
Total liabilities and equity 28,707,455 26,846,613
Predator Oil & Gas Holdings Plc
Condensed consolidated statement of changes in equity
For the 6 months to 30 June 2025
Attributable to owner of the parent
Share Capital Reconstruction reserve Warrants issuance cost reserve Share based payments Retained deficit Non-Controlling Interest (i) Retained deficit Owner of the parent Total
£ £ £ £ £ £ £
Balance at 1 January 2025 35,509,502 403,734 (1,374,041) 2,473,910 - (14,677,869) 22,335,236
Issue of ordinary share capital 2,198,082 - - - - - 2,198,082
Fair value of share options - - - 1,176,935 - - 1,176,935
Transaction costs - (120,000) - - - - (120,000)
Total transactions with owners 2,198,082 (120,000) - 1,176,935 - - 3,255,017
Loss for the period - - - - (15,853) (1,634,890) (1,650,743)
Total comprehensive loss for the period - - - - (15,853) (1,634,890) (1,650,743)
Balance at 30 June 2025 37,707,584 283,734 (1,374,041) 3,650,845 (15,853) (16,312,759) 23,939,510
Balance at 1 January 2024 33,067,028 531,233 (1,711,756) 2,844,770 - (13,822,474) 20,908,800
Issue of ordinary share capital 304,474 - - - - - 304,474
Share based payments charges - - - 169,044 - - 169,044
Share options lapsed - - - (213,306) - 213,306 -
Exercised warrants - - 337,715 (337,715) - - -
Total transactions with owners 304,474 - 337,715 (381,977) - 213,306 473,518
Loss for the period - - - - - (978,238) (978,238)
Total comprehensive loss for the period - - - - - (978,238) (978,238)
Balance at 30 June 2024 33,371,502 531,233 (1,374,041) 2,462,793 - (14,587,406) 20,404,082
Balance 1 January 2024 as previously stated 33,067,028 531,233 (1,711,756) 2,844,770 - (13,822,475) 20,908,800
Prior Year Adjustment 693,103 693,103
Balance at 1 January 2024 as restated 33,067,028 531,233 (1,711,756) 2,844,770 - (13,129,372) 21,601,903
Issue of ordinary share capital 2,138,000 - - - - - 2,138,000
Transaction costs - (127,499) - - - - (127,499)
Cancelled options - - - (513,893) - 513,893 -
Exercised warrants 304,474 - 337,715 (337,715) - - 304,474
Fair value of share options - - - 480,748 - - 480,748
Total contributions by and distributions to owners of the parent recognised 2,442,474 (127,499) 337,715 (370,860) - 513,893 2,795,723
directly in equity
Loss for the year - - - - - (2,062,390) (2,062,390)
Total comprehensive loss for the year - - - - - (2,062,390) (2,062,390)
Balance at 31 December 2024 35,509,502 403,734 (1,374,041) 2,473,910 - (14,677,869) 22,335,236
(i) Retained deficit Non -Controlling Interest: The reserve refers to the
minority shareholder's holding of 49% of the issued share capital of Caribbean
Rex Limited (CRex). A proportionate share of the losses incurred during
period under review by CRex have been shown under this reserve.
Predator Oil & Gas Holdings Plc
Condensed consolidated statement of cash flows
For the 6 months to 30 June 2025
01.01.2025 to 30.06.2025 01.01.2024 to 30.06.2024
(unaudited) (unaudited)
£ £
Cash flows from operating activities
Loss for the period before taxation (1,902,819) (1,003,593)
Adjustments for:
Share based payment expense 1,176,935 169,044
Finance income (28,578) (37,936)
Depreciation 318 118
Foreign exchange (ii) 445,850 (52,317)
Decrease / (increase) in trade and other receivables 56,203 (211,474)
(Decrease) / increase in trade and other payables 256,569 49,825
Net cash generated from / (used in) operating activities 4,478 (1,086,334)
Cash flow from investing activities
Capitalised costs - Project Guercif - Morocco (2,310,317) (1,392,570)
Capitalised costs - Cory Moruga - Trinidad (47,495) (20,466)
Addition of fixed assets (6,544) -
Intangible asset on acquisition of CRex (692,158) -
Net cash used in investing activities (3,056,514) (1,413,036)
Cash flows from financing activities
Proceeds from issuance of shares, net of issue costs (i) 1,880,000 304,476
Finance Income received 28,578 37,936
Net cash generated from financing activities 1,908,578 342,412
Effect of exchange rates on cash (91,823) 25,114
Net (decrease) in cash and cash equivalents (1,235,281) (2,131,844)
Cash and cash equivalents at the beginning of the period 3,813,371 6,484,034
Cash and cash equivalents at the end of the period 2,578,090 4,352,190
(i) 4,441,641 shares were issued to
Challenger Energy Group Plc to satisfy the terms of a cash equivalent
US$250,000 (£198,082) deposit to secure a period of exclusivity to acquire
the Challenger Energy Group's Plc's business and operations in Trinidad and
Tobago.
(ii) The movement in Foreign Exchange
includes exchange differences on translation, the effect of exchange rates on
cash and the exchange movement in respect of the security deposit detailed in
note 10.
Predator Oil & Gas Holdings Plc
Notes to the condensed consolidated interim financial statements
For the 6 months to 30 June 2025
General information
Predator Oil & Gas Holdings Plc ("the Company") and its subsidiaries
(together "the Group") are engaged principally in the operation of an oil and
gas development business in the Republic of Trinidad and Tobago and an
exploration and appraisal portfolio in Ireland and Morocco. The Company's
ordinary shares are on the Official List of the UK Listing Authority in the
standard listing section of the London Stock Exchange.
Predator Oil & Gas Holdings plc was incorporated in 2017 as a public
limited company under Companies (Jersey) Law 1991 with registered number
125419. It is domiciled and registered at IFC5, 3rd Floor, Castle Street, St
Helier, Jersey, JE2 3BY.
Basis of preparation
The condensed consolidated interim financial statements are prepared under the
historical cost convention and on a going concern basis and in accordance with
UK adopted international accounting standards and IFRIC interpretations
adopted for use in the United Kingdom ("IFRS").
The condensed consolidated interim financial statements contained in this
document do not constitute statutory accounts under Companies (Jersey) Law
1991. In the opinion of the directors, the condensed consolidated interim
financial statements for this period fairly presents the financial position,
result of operations and cash flows for this period.
Statutory financial statements for the year ended 31 December 2024 were
approved by the Board of Directors on 15 April 2025. The report of the
auditors on those financial statements was unqualified with the capitalisation
and valuation of intangible assets being considered the key audit matter.
The Board of Directors approved this Interim Financial Report on 18 September
2025.
Statement of compliance
The Interim Report includes the consolidated interim financial statements
which have been prepared in accordance with International Accounting Standard
34 'Interim Financial Reporting'. The condensed interim financial statements
should be read in conjunction with the annual financial statements for the
year ended 31 December 2024, which have been prepared in accordance with
UK-adopted International accounting standards.
Going concern
The Group's cash flow projections indicate that the Group should have
sufficient resources to continue as a going concern. As at 30 June 2025 the
Group had cash of £2.6 million, no borrowings and minimal licence commitments
for the ensuing year. As a result, the Group's overheads will not require
funding for a minimum of 12 months from the date of this review, even without
taking into account the forecast production revenues from Trinidad. In
addition, the Group is fully funded for all firm operational commitments for
H2 2025 and H1 2026.
The Group is generating revenues from operations but the producing assets
acquired from the Challenger Energy Group are and will generate cash revenues.
Under the current proposed NABI Production and Field Services Management
Agreements the Group will have no exposure to capital investment unless it
opts at its sole discretion to exercise a right under the agreements to fund
any high-impact opportunity to retain 100% of sales revenues.
Going forward the Group has presented above a wide range of options for
implementing discretionary funding for any new opportunities that crystallize.
The Board have reviewed a range of potential cash flow forecasts for the
period to 30 September 2026, including reasonable possible downside scenarios.
This includes the following assumptions:
1. Trinidad - Cory Moruga licence
For Predator Oil & Gas Trinidad Ltd., where production revenues from its
wholly Trinidad owned subsidiary, T-Rex Resources (Trinidad) Limited ('Trex')
are forecast to be generated over the next 12 months through implementation of
the proposed NABI Production and Field Services Management Agreement and the
execution of a heavy workover programme for Snowcap-1 and Jacobin-1.
The timing of appraisal/development drilling (Snowcap-3) in 2026 is
discretionary and subject to a range of funding options. If implemented the
impact on production growth and cashflow is likely to be significant if
operations are successfully executed. Any further staged field development
after a potentially successful Snowcap-3 well may be organically funded from
cash flow and/or an asset sale. The Group may resort to the option of raising
equity funding or entering into a reserves-based loan facility if the
Snowcap-3 well results demonstrate a short-term timescale to accelerate
development and if this proves to be advantageous for accelerating cashflow
and paying back capital investment
The Initial Work Programme agreed by TRex with the MEEI will be conducted over
the next eighteen months without any firm drilling commitment to be met in the
next 12 months.
2. Trinidad - Bonasse, Goudron, Innis-Trinity and Icacos Field
The producing assets acquired from the Challenger Energy Group are and will
generate cash revenues. Under the current proposed NABI Production and Field
Services Management Agreements the Group will have no exposure to capital
investment unless it opts at its sole discretion to exercise a right under the
agreements to fund any high-impact opportunity to retain 100% of sales
revenues.
Rehabilitation of the acquired fields over the next 12 months by NABI
potentially enhances the value of the assets if, at the Group's sole
discretion, an asset sale with or without valuable tax losses was
contemplated.
3. Morocco - Guercif licence
In the case of Predator Gas Ventures Ltd., recovery of inter-company loans is
dependent upon the outcome and interpretation of the Guercif rigless testing
programme scheduled to evaluate the "A" Sand in MOU-3 in Q3 2025. If, as
suspected, formation damage as a consequence of drilling over-balanced, then a
range of remedial well-intervention strategies can be evaluated.
The execution of the agreement with Vivo Energy Limited during the period
under review, for a micro-LNG rather than a CNG development, reassures the
Group that potential Contingent Gas Resources independently verified remain
commercially viable once the subsurface development strategy can be
finalised.
Vivo Energy Limited are seeking up to 5M cfg/day pilot production profile and
will fund a micro-LNG facility and distribution network to Moroccan's
industrial gas users. This reinforces the commercial proposition for the
development of gas in the Guercif Licence, particularly in the context of
achievable gas prices and a benign taxation policy.
If required, the Group may drill an appraisal/development well to gather
additional information on reservoir and rock properties with which to refine
the design of a well intervention programme to establish gas flow in existing
wells where NuTech petrophysics are interpreted as demonstrating gas pay.
Discretionary funding options for such a well have previously been presented
above.
4. Ireland
In the case of Predator Oil and Gas Ventures Ltd., the quantum of
inter-company loan is relatively small, and no substantive expenditures are
anticipated going forward over the next 12months.
The Group is awaiting the outcome of an applications for a successor
authorisation to Licensing Option 16/26 (Corrib South) which is under active
consideration as confirmed by the GSRO within Department of the Environment,
Climate and Communications ("DECC") in correspondence dated 30 June 2025.
There are not likely to be any significant funding implications emerging from
this process in the next 12 months. Acceptance of a licence award is
discretionary and would only be considered by the Group if a Joint Venture
partner or private equity investment in Predator Oil and Gas Ventures Limited
could be negotiated before acceptance.
A potential award of the Corrib South successor authorisation could
potentially grant the Group access rights to the Corrib infrastructure with
which to re-purpose the Mag Mell FSRU project to deliver LNG to the Corrib
pipeline and for potential gas storage at Corrib South. However, the Group
will not proceed with any FSRU project unless it is totally funded by a third
party.
In the future therefore, the potential may exist for the Group, as promoters
of a LNG project and holders of a successor authorisation for Corrib South, to
receive introductory and service providers' fees and a carried minority equity
position in a joint venture vehicle to move to the project development stage.
Under these circumstances the inter-company loan would constitute past costs
contributing to the level of carried equity. Recovery of the relatively modest
inter-company loan therefore is ultimately dependent on the award of the
Corrib South successor authorisation, which at this time is still actively
under consideration.
Given the long delay in the GSRO and DECC's regulatory approval process
(over seven years now), a request for compensation has been requested should
the application for a successor authorisation be ultimately rejected.
Cyclicality
The interim results for the six months ended 30 June 2025 are not necessarily
indicative of the results to be expected for the full year ending 31 December
2025. Due to the nature of the entity, the operations are not affected by
seasonal variations at this stage.
New Standards adopted at 1 January 2025
There are no accounting pronouncements which have become effective from 1
January 2025 that have a significant impact on the Group's interim condensed
consolidated financial statements.
Significant accounting policies
The accounting policies applied by the Group in these half-yearly results are
the same as those applied by the Group in its consolidated financial
information in its 2024 Annual Report and Accounts.
Areas of estimates and judgement
When preparing the Group's consolidated interim financial statements,
management undertakes a number of judgements, estimates and assumptions about
recognition and measurement of assets, liabilities, income and expenses. The
actual results may differ from the judgements, estimates and assumptions made
by management, and will seldom equal the estimated results.
The judgements, estimates and assumptions applied in the Group's consolidated
interim financial statements, including the key sources of estimation
uncertainty, were the same as those applied in the Group's last annual
financial statements for the year ended 31 December 2024.
An assessment of the fair value assets and liabilities of Caribbean Rex
Limited (CRex) and CEG Bonasse Limited acquired in January 2025 have been
undertaken. The board has determined that these assets taken as an integrated
set of activities are capable of being managed and conducted for the purpose
of providing a return and therefore constitute a business. Accordingly, the
transaction has been accounted for in accordance with IFRS 3 'Business
Combinations' which requires the assets acquired and liabilities assumed to be
recognised on the acquisition date at their fair value.
The Company is assessing the assets and liabilities acquired in respect of CEG
Bonasse and CRex. In the course of the next six months a decision will be
taken on whether to show the Goodwill on acquisition as a tangible asset after
an evaluation of its value and their usefulness.
Foreign currencies
The functional currency of the Group and all of its subsidiaries is the
British Pound Sterling.
Transactions entered into by the Group entities in a currency other than the
currency of the primary economic environment in which it operates (the
"functional currency") are recorded at the rates ruling when the transactions
occur. Foreign currency monetary assets and liabilities are translated at the
rates ruling at the date of the statement of financial position. Exchange
differences arising on the retranslation of unsettled monetary assets and
liabilities are similarly recognised immediately in profit or loss, except for
foreign currency borrowings qualifying as a hedge of a net investment in a
foreign operation.
Revenue recognition
Following the commencement of sales in the recently acquired companies in
Trinidad.
The Group has added a revenue recognition policy as follows:
Crude oil sales are recognised when control of the crude oil has transferred,
being when the crude is delivered to the customer by means of a custody
transfer ticket document, the customer has full discretion over the channel
and price to sell the crude oil, and there is no unfulfilled obligation that
could affect the customer's acceptance of the crude oil. Revenue is recognised
as this is the point in time that the consideration is unconditional because
only the passage of time is required before the payment is due.
No element of financing is deemed present as typically, payment for the sale
of the oil is received by the end of the month following the month in which
the sale is recognised, which is consistent with market practice.
Decommissioning
The Company is evaluating the potential of licences acquired with the recent
Trinidad company acquisitions. The decommissioning values will be estimated in
the course of the next 6 months. The Company has deemed it necessary to adopt
the following policy:
A provision for decommissioning is recognised in accordance with the
contractual obligations at the commencement of oil and gas activity. The
amount recognised is the net present value of the estimated cost of
decommissioning at the end of the economic producing lives of the wells and
the end of the useful lives of associated storage units and other
infrastructure. Such costs include removal of equipment and the restoration
of land. The unwinding of the discount on the provision is included in the
statement of comprehensive income within finance costs.
A corresponding asset is also created at an amount equal to the provision.
This is subsequently depreciated/amortised as part of the capital costs of the
production assets. Any change in the present value of the estimated
expenditure or discount rates are reflected as an adjustment to the provision
and the asset and dealt with prospectively.
The assets' residual values and useful lives are reviewed and adjusted if
appropriate at each statement of financial position 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.
1. Financial risk management
The Board continually assesses and monitors the key risks of the business.
The key risks that could affect the Group's medium-term performance and the
factors that mitigate those risks have not substantially changed from those
set out in the Group's 2024 Annual Report and Financial Statements, a copy of
which is available from the Group's website: www.predatoroilandgas.com. The
key financial risks are market risk (including cash flow interest rate risk
and foreign currency risk), credit risk and liquidity.
2. Segmental analysis
The Group operates in one business segment, the exploration, appraisal and
development of oil and gas assets. The Group has interests in three
geographical segments being Africa (Morocco), Europe (Ireland) and the
Caribbean (Trinidad and Tobago).
The Group's operations are reviewed by the Board (which is considered to be
the Chief Operating Decision Maker ('CODM')) and split between oil and gas
exploration and development and administration and corporate costs.
Operating segments are disclosed below on the basis of the split between
exploration and development and administration and corporate.
Europe Caribbean Africa Corporate
For the 6 months to 30 June 2025 (unaudited) £ £ £ £
Income - 66,815 - -
Gross profit - 66,815 - -
Administrative and overhead expenses (39,787) 251,037 724,292 (1,504,268)
Share option and warrant expense - - - (1,176,935)
Finance Income - 6 - 28,571
Taxation - - (476) -
Profit/(loss) for the period from continuing operations (39,787) 317,858 723,816 (2,652,632)
Total reportable segment intangible assets - 5,924,688 18,748,676 -
Total reportable segment tangible assets - 7,201 - 169
Total reportable segment non-current assets - - - 1,093,425
Total reportable segment current assets - 196,195 1,245,832 1,397,376
Total reportable segment assets - 6,128,084 19,994,508 2,490,970
Total reportable segment liabilities (10,000) (3,409,311) (873,548) (381,192)
Europe Caribbean Africa Corporate
For the 6 months to 30 June 2024 (unaudited) £ £ £ £
Gross Loss
Administrative and overhead expenses (22,558) (139,834) (148,890) (468,313)
Share option and warrant expense - - - (169,044)
Finance Income - - - 37,936
Taxation - - (67,535) -
Loss for the period from continuing operations (22,558) (139,834) (216,425) (599,421)
Total reportable segment intangible assets - 4,497,180 13,728,562 -
Total reportable segment non-current assets - - - 1,063
Total reportable segment current assets - 632,710 1,217,629 4,637,844
Total reportable segment assets - 5,129,889 14,946,191 4,638,907
Total reportable segment liabilities - (2,841,327) (558,939) (910,641)
There are no non-current assets held in the Group's country of domicile, being
Jersey, Channel Islands (2024: £nil).
30.06.2025 30.06.2024
(unaudited) (unaudited)
3. Total Revenue £ £
Revenue from Oil sales 66,815 -
66,815 -
30.06.2025 30.06.2024
(unaudited) (unaudited)
4. Administrative expenses £ £
Technical Consultancy fees (i) 129,639 101,432
Advisory fees 10,000 -
Listing costs 69,921 56,101
Reversal of bonus and incentive fee (ii) (183,813) -
Broker fees - 30,000
Directors fees 93,966 196,835
Office costs 13,143 -
Administration fees 80,715 85,285
Bank charges 33,089 28,498
Legal and professional fees 43,710 129,217
Travel expenses 56,225 45,241
Computer/system costs/IT support 19,644 480
Insurance 7,959 30,800
Sundry expenses 5,297 3,959
Annual return fee 7,685 1,320
Depreciation 318 118
Website costs - 5,277
Foreign exchange 341,564 (52,559)
Audit fee 43,199 55,455
Cory Moruga operating expenses 48,341 87,491
WHT Payable 676 67,535
821,277 872,485
(i) During the period ended 30 June 2025, all
Executive Directors' technical consultancy fees for Predator Gas Ventures
Limited were capitalised accordingly (£33,746).
(ii) During the period ended 30 June 2025, the
directors agreed to reverse the bonus accrual in respect of amounts owed to a
director that resigned on the 11th September 2024, who did not meet the
termination agreement conditions.
30.06.2025 30.06.2024
(unaudited) (unaudited)
5. Share Options and Warrants £ £
Share based payments - options (see note 14) 1,176,935 169,044
1,176,935 169,044
30.06.2025 30.06.2024
6. Loss per share (unaudited) (unaudited)
Weighted average number of shares 655,169,210 403,884,950
Loss attributable to ordinary equity holders of the company (1,634,890) (978,238)
(0.250) (0.242)
Total basic and diluted loss per share attributable to the ordinary equity
holders (pence)
Diluted loss per Ordinary share equals basic loss per ordinary share as, due
to the losses incurred in 2025 and 2024, there is no dilutive effect from the
subsisting share options.
7. Intangible asset Project Guercif Cory Moruga Total
Gross carrying amount
Balance at 1 January 2024 as restated 13,029,095 4,476,714 17,505,809
Additions 3,409,264 708,321 4,117,585
Balance at 1 January 2025 16,438,359 5,185,035 21,623,394
Additions 2,310,317 739,653 3,049,970
Balance at 30 June 2025 18,748,676 5,924,688 24,673,364
Depreciation and impairment
Balance at 1 January 2025 - - -
Depreciation - - -
Balance at 30 June 2025 - - -
Carrying amount 31 December 2024 16,438,359 5,185,035 21,623,394
Carrying amount 30 June 2025 18,748,676 5,924,688 24,673,364
All costs relating to Project Guercif have been capitalised and will be
depreciated once gas discovery is declared commercial and a Plan of
Development has been approved.
The Directors have undertaken an assessment of the following areas and
circumstances that could indicate the existence of impairment:
· The Group's right to explore in an area has expired, or will
expire in the near future without renewal;
· No further exploration or evaluation is planned or budgeted for;
· A decision has been taken by the Board to discontinue exploration
and evaluation in an area due to the absence of a commercial level of
reserves; or
· Sufficient data exists to indicate that the book value will not
be fully recovered from future development and production.
Cory Moruga
The current capitalised value of the Cory Moruga licence is £5,924,688.
On 12 January 2024 the Company announced the results of an independent
Technical Report ("ITR") by Scorpion Geosciences Ltd for the Cory Moruga
licence with project economics supporting a valuation of NPV @10% of $85m.
No operations have been carried out that would require an adjustment to this
independent valuation.
Well workovers will be underway during 2025. Up to two well workovers in Q3
and Q4 2025 are expected to deliver enhanced production volumes with or
without application of patented chemical wax treatment technology. Further
desktop technical work is planned for during 2025 to address planning and
scheduling of well services for the Snowcap-3 appraisal/development well. Cash
flow forecasts for the 2 well workovers and the Snowcap-3 well generate
positive cash flow from production.
Guercif
The capitalised value at 30 June 2025 of the Guercif licence costs is
£18,748,676.
The Guercif licence is valid until 2028. The Company has applied for an
extension of the First Extension Period to 5 November 2026 to provide
additional time to demonstrate a CNG or micro-LNG pilot development project
with Vivo Energy to support an application for an Exploitation Concession.
Currently no operations have been carried out on MOU-1, MOU-2, MOU-3 and MOU-4
that have resulted in any change to pre-rigless testing Contingent Gas
Resources as determined by Scorpion Geoscience's Independent Technical Report
dated 21 June 2024. Therefore, currently no impairment of drilling and
testing costs is warranted.
Evaluation of the prospectivity of the licence area including the Moulouya
Fan, and the deeper Triassic prospectivity below the total depth of the MOU-5
well is ongoing and substantive drilling is planned for 2027.
There is no indication from data obtained and activities to date that a
development in the area is likely to proceed where the carrying amounts of the
E&E assets is unlikely to be recovered in full.
8. Acquisition of Caribbean Rex Limited
An assessment of the fair value assets and liabilities of Caribbean Rex
Limited (CRex) and CEG Bonasse Limited acquired in January 2025 have been
undertaken. The board has determined that these assets taken as an integrated
set of activities are capable of being managed and conducted for the purpose
of providing a return and therefore constitute a business. Accordingly, the
transaction has been accounted for in accordance with IFRS 3 'Business
Combinations' which requires the assets acquired and liabilities assumed to be
recognised on the acquisition date at their fair value.
As at 1 January 2025 Caribbean Rex Limited CEG Bonasse Limited Caribbean Rex Limited Consolidated Trex Resources (Trinidad) Limited Trex Resources (Trinidad) Limited Consolidated
Non-current assets
Investments 1 - - - -
Fixed Assets - - - 657 657
Intangible asset - - - 708,321 708,321
Goodwill - - 756,695 - 756,695
Total non-current assets 1 - 756,695 708,978 1,465,673
Current assets
Inventory - 22,049 22,049 - 22,049
Trade and other receivables - 2,717 2,717 78,030 80,747
VAT recoverable - 263,325 263,325 52,316 315,641
Cash and cash equivalents 4,102 646 4,748 28,010 32,758
Total current assets 4,102 288,737 292,839 158,356 451,195
Total assets 4,103 288,737 1,049,533 867,334 1,916,868
Long Term liabilities
Abandonment provision - 546,338 546,338 174,097 720,435
Current liabilities
Trade and other payables 916 212,988 213,904 10,193 224,097
Accruals - - - 2,740,270 2,740,270
Other liabilities - 231,978 231,978 - 231,978
VAT payable - 54,128 54,128 - 54,128
Total current liabilities 916 499,094 500,010 2,750,463 3,250,473
Loans payable
Predator Group companies - - - 1,133,933 1,133,933
Total liabilities 916 1,045,432 1,046,348 4,058,493 5,104,841
Equity attributable to the owner of the parent
Share capital 29,646,159 9,749,647 29,646,159 13,183,136 13,183,136
Share premium - - - 83,558,924 83,558,924
Other reserves - - - - -
Retained deficit (29,642,972) (10,506,342) (29,642,974) (99,933,219) (99,930,033)
Deficit for the period - - - - -
Total equity 3,187 (756,695) 3,185 (3,191,159) (3,187,973)
Total liabilities and equity 4,103 288,737 1,049,533 867,334 1,916,868
30.06.2025 31.12.2024
(unaudited) (audited)
9. Property, plant and equipment £ £
Cost
At 31 December 11,838 11,181
Additions 6,544 657
At 31 December 18,382 11,838
Amortisation
At 31 December 10,694 10,000
Charge for the year 318 694
At 31 December 11,012 10,694
Carrying amount at 30 June 2025 and 31 December 2024 7,370 1,144
30.06.2025 31.12.2024
(unaudited) (audited)
10. Trade and other receivables £ £
Non-Current
Security deposit (US$1,500,000) (i) 1,093,425 1,195,377
Current
Prepayments and other receivables (ii) 355,206 213,327
1,448,631 1,408,704
(iii) A security deposit of USD1,500,000
(2024: USD1,500,000) is held by Barclays Bank in respect of a guarantee
provided to Office National des Hydrocarbures et des Mines (ONHYM) as a
condition of being granted the Guercif exploration licence. These funds are
refundable on the completion of the Minimum Work Programme set out in the
terms of the Guercif Petroleum Agreement and Association Contract.
Following ratification by a Joint Ministerial Order, the Bank Guarantee has
been rolled over into the First Extension Period of the Guercif Licence.
(iv) 4,441,641 shares were issued to
Challenger Energy Group Plc to satisfy the terms of a cash equivalent
US$250,000 (£198,082) deposit to secure a period of exclusivity to acquire
the Challenger Energy Group's Plc's business and operations in Trinidad and
Tobago.
30.06.2025 31.12.2024
(unaudited) (audited)
11. Cash and cash equivalents £ £
Barclays Bank Plc 2,302,808 3,776,453
Scotia Bank 6,438 21,650
Republic Bank 138,437 6,360
Société Générale 126,996 8,908
Bank of St Lucia 3,411 -
2,578,090 3,813,371
12. Share capital Number of shares Nominal value
Issued and fully paid
Opening Balance 01/01/2025 611,874,754 35,509,502
Share issue 05/02/2025 25,000,000 1,000,000
Share issue 05/02/2025 25,000,000 1,000,000
Share issue 18/02/2025 4,441,641 198,082
666,316,395 37,707,584
30.06.2025 31.12.2024
(unaudited) (audited)
13. Trade and other payables £ £
Current
Trade payables (i) 1,441,736 1,267,116
Accruals (ii) 2,658,437 3,070,163
Provisions - 174,097
4,100,173 4,511,376
Non-current
Provisions (iii) 667,772 -
4,767,945 4,511,376
(i) Trade payables as at 30 June 2025
includes an amount of GBP 826,499 in respect of Moroccan withholding tax and
an amount of GBP 323,785 in respect of performance bonuses due to the
Executive Chairman.
(ii) Accruals as at 30 June 2025 includes an
amount of GBP 2,521,436 (TTD23.4 million) in relation to amounts payable to
the Trinidadian Ministry of Energy and Energy Industries in respect of past
dues on the Cory Moruga licence.
(iii) Provisions relate to the estimated cost
of decommissioning at the end of the economic producing lives of the wells
acquired as part of the recent Trinidad company acquisitions.
14. Other reserves
30.06.2025 31.12.2024
Warrants (unaudited) (audited)
issuance cost reserve
No of warrants £ £
Balance brought forward 65,748,976 (1,374,041) (1,711,756)
Issue of warrants 10,000,000 - -
Exercised warrants at fair value - - 337,715
Cancelled and/or expired warrants - - -
Balance carried forward 75,748,976 (1,374,041) (1,374,041)
Share based payments reserve 30.06.2025 31.12.2024
No of share options (unaudited) (audited)
£ £
Balance brought forward 34,355,486 2,473,910 2,844,770
Fair value of share options 45,000,000 1,176,935 480,748
Cancelled options - - (513,893)
Warrants exercised - - (337,715)
Balance carried forward 79,355,486 3,650,845 2,473,910
15. Share based payments
Share options
On 20 February 2025, the Company issued 45,000,000 share options at an
exercise price of 5.5p. The vesting conditions were as follows:
- 25% will be awarded on commencement of MOU-5 Drilling
- 25% after 9 months or announcement of the completion of the acquisition of
Challenger Energy Group Plc's Trinidad
and Tobago companies, whichever comes first
- 25% after 6 months or announcement of positive MOU-3 testing results,
whichever occurs first
- 25% on announcement of achieving 500boe/pd net to Predator in Trinidad
Paul Griffiths
Share options issued during the period:
On the 20 February 2025, the company issued 18,500,000 share options at an
exercise price of 5.5p (see above vesting conditions).
Share options exercised during the period:
No share options were exercised during the period.
Share options held as at period end:
Share options agreement dated 9 November 2022 - 4,171,881 share options at an
exercise price of 10.0p.
Share options agreement dated 12 May 2023 -3,328,119 share options at an
exercise price of 10.0p.
Share options agreement dated 12 May 2023 - 7,855,486 share options at an
exercise price of 8.0p.
Share options agreement dated 20 February 2025 - 18,500,000 share options at
an exercise price of 5.5p.
Steve Boldy
Share options issued during the period:
On the 20 February 2025, the company issued 7,500,000 share options at an
exercise price of 5.5p (see above vesting conditions).
Share options exercised during the period:
No share options were exercised during the period.
Share options held as at period end:
Share options agreement dated 1 October 2024 - 3,000,000 share options at an
exercise price of 10.5p.
Share options agreement dated 20 February 2025 - 7,500,000 share options at an
exercise price of 5.5p.
Alistair Jury
Share options issued during the period:
On the 20 February 2025, the company issued 7,500,000 share options at an
exercise price of 5.5p (see above vesting conditions).
Share options exercised during the period:
No share options were exercised during the period.
Share options held as at period end:
Share options agreement dated 5 July 2022 - 2,000,000 share options at an
exercise price of 8.125p.
Share options agreement dated 11 October 2023 - 3,000,00 share options at an
exercise price of 12.5p.
Share options agreement dated 20 February 2025 - 7,500,000 share options at an
exercise price of 5.5p.
Carl Kindinger
Share options issued during the period:
On the 20 February 2025, the company issued 7,500,000 share options at an
exercise price of 5.5p (see above vesting conditions).
Share options exercised during the period:
No share options were exercised during the period.
Share options held as at period end:
Share options agreement dated 9 November 2022 - 2,000,000 share options at an
exercise price of 7.75p.
Share options agreement dated 11 October 2023 - 3,000,000 share options at an
exercise price of 12.5p.
Share options agreement dated 20 February 2025 - 7,500,000 share options at an
exercise price of 5.5p.
Moyra Scott
Share options issued during the period:
There was no share options issued during the period.
Share options exercised during the period:
No share options were exercised during the period.
Share options held as at period end:
Share options agreement dated 29 March 2023 - 3,000,000 share options at an
exercise price of 10.0p.
Geoffrey Leid
Share options issued during the period:
On the 20 February 2025, the company issued 4,000,000 share options at an
exercise price of 5.5p (see above vesting conditions).
Share options exercised during the period:
No share options were exercised during the period.
Share options held as at period end:
Share options agreement dated 18 April 2024 - 3,000,000 share options at an
exercise price of 12.5p.
Share options agreement dated 20 February 2025 - 4,000,000 share options at an
exercise price of 5.5p.
Warrants
During the period ending 30 June 2025, the Company issued the following
warrants.
1. On 4 February 2025, 5,000,000 warrants were issued to Eva
Pacific Pty Ltd exercisable at 6.0p with an initial and current expiry date of
4 February 2028.
2. On 4 February 2025, 5,000,000 warrants were issued to
Cynosure Capital Pty Ltd exercisable at 6.0p with an initial and current
expiry date of 4 February 2028.
During the period ended 30 June 2025 no warrants were exercised.
16. Investment in subsidiaries Principal activity Country of Ownership
incorporation interest
Predator Oil and Gas Ventures Limited Licence options in offshore Ireland Jersey 100%
Predator Oil and Gas Trinidad Limited Profit rights for production revenues from a CO2 enhanced oil recovery project Jersey 100%
T-Rex Resources (Trinidad) Limited ("T-Rex") - See note 7 Exploration licence onshore Trinidad Trinidad 100%
Caribbean Rex Limited (CRex) - see note 7 Exploration licence onshore Trinidad Trinidad 51%
CEG Bonasse Limited - see note 7 Exploration licence onshore Trinidad Trinidad 51%
Predator Gas Ventures Limited Exploration licence onshore Morocco Jersey 100%
Mag Mell Energy Ireland Ltd Licence application to import liquified natural gas Jersey 100%
17. Financial instruments
The Group's financial instruments comprise cash and items arising directly
from its operations such as trade receivables and trade payables.
30.06.2025 31.12.2024
Categorisation of financial instruments (unaudited) (unaudited)
£ £
Financial assets measured at amortised cost
Trade and other receivables 1,448,631 1,408,704
Financial assets that are debt instruments measured at amortised cost:
Cash and cash equivalents 2,578,090 3,813,371
4,026,721 5,222,075
Financial liabilities measured at amortised cost:
Trade and other payables (excluding short term loans) (4,100,173) (4,511,376)
(4,100,173) (4,511,376)
18. Related party transactions
Transactions with key management personnel
Key management of the Group are the executive members of the Company board of
directors. Key management personnel remuneration includes the following
expenses:
30.06.2025 30.06.2024 31.12.2024
(unaudited) (unaudited) (audited)
£ £ £
Short-term employee benefits
Executive and non-executive directors 257,351 298,267 433,708
Share option scheme 1,176,935 - 480,748
1,434,286 298,267 914,456
The average number of personnel (including directors) during the period was:
Management - (Executive directors) 1 2 2
Non-management - (Non-executive directors) 3 2 2
4 4 4
Four Directors at the end of the period have share options receivable under
long-term incentive schemes. The highest paid Director received an amount of
£156,768 (2024: £120,084). The Group does not have employees. All personnel
are engaged as service providers.
On the 20 February 2025, share options were issued to the following directors.
No. of Shares
Paul Griffiths 18,500,000
Carl Kindinger 7,500,000
Alistar Jury 7,500,000
Stephen Boldy 7,500,000
Total number of directors shares issued in year 41,000,000
19. Subsequent events
1 July 2025
The Company announced that a revised longstop date of 30 August 2025 for the
agreement concluded by the Group's 51% owned subsidiary, Caribbean Rex
Limited, in February 2025 for the acquisition of the entirety of the
Challenger Energy Group's operations in Trinidad and Tobago. Substantial
progress in terms of satisfying requirements for the grant of the necessary
regulatory approval has been made. The parties have agreed to extend the date
for completion of the transaction to 7 days after the granting of regulatory
approval, subject to the aforesaid longstop date.
22 July 2025
The Company announced that it has conditionally placed 20 million new ordinary
shares of no par value at a placing price of 5 pence each to raise £1.0
million.
Use of funds:
1. Trinidad - £550,000
1.1 Deferred consideration due on the completion of the acquisition of
Challenger Energy Group Plc's business interests and operations onshore
Trinidad.
1.2 Rig inspection and maintenance work for the Snowcap-3 selected rig and
negotiate a rig contract.
2. Morocco - £ 350,000
2.1 EIA and front end engineering design for gas processing and
distribution facilities for a potential gas development at MOU-3 well site.
2.2 Place a purchase order for the import of large perforating guns for
MOU-1 and MOU-4 rigless testing programmes.
3. Corporate overheads- £100,000
31 July 2025
The Company announced that following the £1.0million placing the Ordinary
share capital and Voting rights increased to 686,286,395 Ordinary Shares.
1 August 2025
The Company announced that in the course of the MOU-3 well intervention and
rigless testing operations the "A" Sand was successfully perforated using, for
the first time, the larger 2 7/8" power jet NOVA perforating guns. Whilst the
perforating has been successful, thus far it has not been able to completely
overcome the formation damage to allow the well to flow. Pressure builds up in
the well is being monitored to see if, with time, the damage can be overcome.
A new well, MOU-6, is being designed to mitigate for formation damage and is
crucial for evaluating potential well productivity and reservoir performance
at several levels. Execution of the MOU-6 drilling programme will take place
at the earliest opportunity this year in order to maintain momentum.
1 September 2025
The Company announced that the previously announced transaction for the
purchase of the entirety of Challenger Energy Group Plc's St. Lucia-domiciled
subsidiary company, Columbus Energy (St. Lucia) Limited ("CEG Trinidad") and
its business and operations in Trinidad and Tobago has been completed, with an
effective date of 29 August 2025, following the receipt of all regulatory
consents:
a) as at completion, Challenger Energy Group Plc ("Challenger")
has been paid US$0.5 million in cash from uncommitted funds in the Company's
working capital forecast; and
b) Challenger will be paid a further US$0.5 million in deferred
consideration on 31 August 2026, US$0.25 million on 31 December 2026; and
US$0.25 million on 31 December 2027.
c) Seller's Warranties under the SPA remain applicable for a
period of 12 months from 29 August 2025.
d) Following Completion, the West Indian Energy Group Limited
has assumed all liabilities, provisions and potential exposures of CEG
Trinidad's business, assets and operations in Trinidad and Tobago (which for
the purposes of the transaction were agreed to be US$4.25 million), with the
effect that the Company has no residual exposure to CEG Trinidad's business
and operations.
5 September 2025
The Company changed its Company Secretary and Administrative Service Provider
from Oak Group (Jerey) Limited to Equiom (Jersey) Limited.
20. Ultimate controlling party
In the opinion of the Directors there is no ultimate controlling party as no
one individual is deemed to satisfy this definition.
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