Predator Oil Regulatory News (PRD)

FOR IMMEDIATE RELEASE

10 April 2024

Predator Oil & Gas Holdings Plc / Index: LSE / Epic: PRD / Sector: Oil & Gas

LEI 213800L7QXFURBFLDS54

Predator Oil & Gas Holdings Plc

("Predator" or the "Company" and together with its subsidiaries the "Group")

Financial Statements for the Year Ended 31 December 2023

Predator Oil & Gas Holdings Plc (LSE: PRD), the Jersey based Oil and Gas Company with near-term hydrocarbon operations focussed on Morocco and Trinidad, is pleased to announce its audited financial statements for the year ended 31 December 2023, extracts of which are set out below.

The Company's Annual Report is available to shareholders to download from the Company's website at www.predatoroilandgas.com.  In line with ESG best practice no hard copies of the Annual Report will be printed.

In addition, a copy of the 2023 Annual Report will be uploaded to the National Storage Mechanism and will be available for viewing at

https://data.fca.org.uk/#/nsm/nationalstoragemechanism.

The financial information set out below does not constitute the Company's statutory accounts for the year ending 31 December 2023.

 Highlights of Financial Results for 2023

· Loss from operations of GBP 4,815,984 (GBP 2,558,844 for the period to 31 December 2022).

The increase in operating loss is primarily due to increased drilling activity in Morocco (MOU-2, MOU-3 and MOU-4 wells)

· Administrative expenses of GBP 3,224,721 (GBP 2,545,789 for the period to 31 December 2022).

Excluding share based payments for options and warrants corporate administrative expenses were GBP 1,540,481 (GBP 1,248,084 for the period to 31 December 2022).

Corporate administrative expenses have been prudently managed despite inflationary pressures during 2023 despite the significant increase in corporate activities which included Project Allosaurus costs of GBP 217,241 related to progressing a Secondary Prospectus with the FCA.

· Executive directors' fees have increased to GBP 604,506 (GBP414,709 for the period to 31 December 2022) as a result of the significant increase in the Company's corporate and operational activities in the period to 31 December 2023 to maintain business growth potential. This increase is mainly attributable to technical services consulting fees charged by the executive directors in providing technical support and reports that would otherwise would have been out-sourced to third parties at competitive market rates. 

· Increased cash balance at period end of 2023 GBP 6,484,034 (GBP 3,323,161 for the period to 31 December 2022).

· Additional, restricted cash of USD1,500,000 (USD 1,500,000 for the period ended 31 December 2022).

· The Company has no debt.

Directors' loans of £507,999 were capitalised and linked to a repayment in full upon the Company flowing a minimum of 1 million cubic feet/day from the rigless testing programme to be executed in the Guercif Licence or from the flow of a minimum of 100 bopd from the well workovers planned for the Cory Moruga Exploration and Production Licence.

· Balance outstanding of the loan made by the Company to FRAM Exploration Trinidad Ltd. ("FRAM") for the investment in the Inniss-Trinity Pilot CO2 EOR Project was GBP NIL (GBP 659,504 the period to 31 December 2022) at the end of the period.

In 2023 the Company announced that it had completed the acquisition (the "Acquisition") of the entire issued share capital of T-Rex, a wholly owned subsidiary of Challenger Energy Group Plc ("CEG"). FRAM is also a wholly owned subsidiary of CEG. T-Rex holds an 83.8% in the Cory Moruga Exploration and Production Licence containing the Snowcap-1 oil discovery. The Acquisition was for a gross consideration ("Gross Consideration") that included USD1,000,000 payable to CEG in cash and allowed for the offset of the outstanding FRAM Loan balance against the agreed Gross Consideration. The Cory Moruga Independent Technical Report and resource potential of the Snowcap-1 discovery by Scorpion Geoscience Limited gives 2C and 3C Contingent Resources of 1.40 and 1.84 million barrels respectively and 2C and 3C Prospective Resources of 12.91 and 19.57 million barrels respectively net to the Company. The Company through the Acquisition has acquired TT $323,652,447 (US $ 47,948,510 @ a forex rate of 6.75) of T-Rex tax losses as of 2022 that can be offset against 50% Petroleum Profit Tax on future net operating profits from oil production in the Cory Moruga Exploration and Production License.

· Placed 97,231,500 new ordinary shares of no par value in the Company to raise GBP10,360,377 (before expenses).

· Exercise of broker warrants resulted in the issue of 2,035,714 new ordinary shares of no par value in the Company to raise GBP 79,500.

· Exercise of share options by directors and former directors resulted in the issue of 20,112,049 new ordinary shares of no par value in the Company to raise GBP 1,646,986.

· 6,401,077, 15,710,972 and 6,000,000 share options have been issued exercisable at £0.10, £0.08 and £0.125 respectively.

· 8,318,182, 1,080,000, 2,181,818 and 1.780,412 broker warrants have been issued exercisable at £0.11, £0.055 and £0.057 respectively.

· 2,659,574 new ordinary shares were issued to the executive directors for no Consideration in accordance with the Executive Directors' Bonus arrangements established by the independent Remuneration Committee.

· Following the admission of the above exercised share options and warrants, bonus shares, returned Loan Shares and the Placing Shares the issued share capital increased to 565,161,662 by the end of the period to 31 December 2023 (383,759,189 for the period ended 31 December 2022).

Highlights of key Operational Activities in 2023

· MOU-2 was drilled to 1,260 metres Measured Depth before being suspended for operational reasons for a possible later re-entry.

Three gas samples collected whilst drilling.

100 metres of variable quality sand in primary target.

· MOU-3 was drilled to 1,509 metres Measured Depth and completed for rigless testing.

Seven gas samples collected whilst drilling.

50.5 metres of gross sand interval in primary target.

Secondary targets Ma and TGB-6 sand intervals confirmed to be present and gas-bearing based on NuTech petrophysics and gas samples collected whilst drilling.

Ma and TGB-6 intervals correlated with MOU-1 drilled in 2021 to potentially define a single structure covering up to 21 km2.

11 metres of unexpected sand encountered at shallow depth with over-pressured gas.

Formation damage predicted due to necessity to drill with heavy drilling mud - to be potentially penetrated using Sandjet rigless testing technology.

· MOU-4 was drilled to 1,199 metres Measured Depth and completed for rigless testing.

Unexpected 58 metres of gross M1 Sand potential reservoir interval, interpreted by NuTech as gas-bearing.

21 metres of gross sand in primary target with improved reservoir characteristics compared to MOU-3 and interpreted as gas-bearing by NuTech petrophysics.

MOU-3 and MOU-4 confirmed potential for stratigraphic trap covering 68km2 for the primary Moulouya Fan target.

MOU-4 achieved its secondary objective by defining the edge of the Jurassic carbonate prospect located to the east of the MOU-4.

The new post-drill well tie to the seismic data validated the pre-drill Jurassic prospect and increased the area of structural closure from 126 to 177 km².

Formation damage also predicted due to necessity to drill with heavy drilling mud - to be potentially penetrated using Sandjet.

· Successful completion of the drilling programme allowed the Company to enter into the signing of a Memorandum of Understanding in relation to gas sales and collaboration for up to 50 million cubic feet of gas per day (50 mm cf/d) with Afriquia Gaz.

· 29 additional prospects and leads have been identified during 2023.

· On 7 November 2023 the acquisition of T-Rex and an 83.8% interest in and operatorship of the Cory Moruga Exploration and Production Licence was completed following receipt of agreements from the Trinidadian Ministry of Energy and Energy Industries ("MEEI").

· Work Programme agreed by the Company with the MEEI will be conducted over the next three years with the initial focus will on a low-cost re-entry of the Snowcap-1 discovery well to restore production and a re-entry of the Snowcap-2ST1 and Jacobin-1 wells to establish potential production.

ESG

· In 2023 the Company spent 25,855,427 Dirhams in Morocco on local services in relation to drilling of three wells 10 kilometers northwest of Guercif city.

Beneficiaries included civil engineering contractors; field support activities including provision and mobilisation of cabins; provision of Guercif warehouse staff (renting of warehouse in Guercif city); provision

of water and waste disposal; fuel supplies; transport and drivers; local hotel accommodation for rig and well services crews; heavy lifting equipment; internet services and provision of office equipment; and accounting and customs administration services. This was a significant boost for the local economy.

Highlights of Directorate Changes

· There were no directorate changes during 2023.

Post Period End:

· The Company published an Independent Technical Report ("ITR") by Scorpion Geoscience Ltd. for the Cory Moruga block and resource potential of the Snowcap Discovery.

· The Company provided an update on the Phase 1 and Phase 2 rigless testing programmes for the Guercif Licence.

· The Company published an Independent Technical Report ("ITR") by Scorpion Geoscience Ltd. for the Guercif block and resource potential of the Moulouya Sub-Area following an evaluation of the 2023 drilling programme results.

· The Company announced that it had received a communication from the GeoScience Regulation Office ("GSRO") at the Department of the Environment, Climate and Communications informing the Company that consideration of its application for a successor authorisation to Licensing Option 16/26 Corrib South was hoped to be concluded during Q1 2024.

· The Company indicated that the commencement of the Phase 1 rigless testing programme was expected to occur on or about 29 January 2024.

· The Company extended its 2022 rig contract for the use of the Star Valley Rig 101 to facilitate the drilling of MOU-5 subject to regulatory approvals.

· The Company announced the results of the Phase 1 rigless testing programme and confirmed potential formation damage.

The results of the Phase 1 rigless testing programme allows the design parameters for the Sandjet testing programme to be set with a higher degree of confidence in relation to achieving key objectives of reservoir penetration.

Seven gas samples collected in isotubes in MOU-3 whilst drilling were analysed by Applied Petroleum Technology (UK) Ltd. ("APT") in Oslo. Gas composition is in the range 98.04 to 99.57% methane, making it ideal for a Compressed Natural Gas development with minimum processing. Isotope analysis indicates the gas is biogenic in origin.

The Company also announced that it would continue to progress planning activities for the drilling of the MOU-5 well to test a large Jurassic structure updip from MOU-4.

 Paul Griffiths, Executive Chairman of Predator Oil & Gas Holdings Plc commented:

"We are pleased to have completed successfully and within budget a transformational 3-well drilling programme in Morocco.

We have identified a significant potential gas structure linking the MOU-1 and MOU-3 wells that will be evaluated by a rigless testing programme using Sandjet perforating technology to reach beyond potential formation damage.

We have also encountered shallow higher pressure gas that was better protected from formation damage whilst drilling by the setting of a shallow casing string. This can also be perforated and tested now using Sandjet, even though it sits behind two casing strings.

The shallow and intermediate reservoir sands combined with the analysis of the gas samples collected whilst drilling, confirming very high purity methane gas composition at all reservoir levels, are ideal for an easily scalable CNG development project.

We are confident that potential gas flow rates using Sandjet will fulfil the potential 50 million cubic feet of gas per day profile facilitated by the Collaboration Agreement with Afriquia Gaz.

Additionally we have increased the areal extent through drilling of the pre-drill primary target, the Moulouya Fan, to 68 km2 and that of the Jurassic target tested at its extremity by MOU-4, to 177 km2. Further appraisal of these large traps may facilitate a later gas-to-power project. The potential for significant condensate resources in the Jurassic target may also exist and will be tested by the MOU-5 well in 2024.

We are excited by the biogenic gas potential at Guercif and the areal scale of the individual tested structures, which is unique for Northern Morocco, but not in terms of the large biogenic gas finds in the area of the Mediterranean region.

We have completed the acquisition of a large equity interest in the onshore Cory Moruga Exploration and Production Licence in Trinidad. This is a unique opportunity to develop an onshore oil field that has not been developed previously and hence has none of the historical issues linked to low well productivity for mature oil fields. Combined with the substantial legacy tax losses this potentially drives a brand new and most probably unique economic model for onshore Trinidad driven by higher well deliverability, lower operating costs, organically-funded modest and manageable capital investments out of production and the application of new technologies such as Sandjet and NuTech.

The Company is a prudent and experienced operator, as we have shown in 2023 and will continue to deliver in 2024. We manage costs carefully, even during times when inflationary pressures and "shrinkflation" have become a normal modus operandi for some suppliers and services.

Like many listed companies of our size we are extremely disappointed with the over-regulated London public markets and their poor appreciation of the value of businesses and opportunities that several companies have created and further developed. Many of our shareholders, including the executive directors, seek to re-set the valuation of our assets through means other than the intra-day share price. This will be the top priority for 2024 and will focus on entities that understand the true value of natural resources in oil and gas commodity sector, as has been proven cyclically time and time again and which continues to support the global economy and is the catalyst for promoting viable economic growth.

We thank our shareholders for their continued support along our journey towards achieving our ultimate goal. It is not an easy path when wedded to a public market that is contracting in relation to its global peers through an inability to reform and refresh in a timely manner to become more attractive and competitive. You might surmise that it would be "in the public interest" so to do, but there again perhaps it's not. 2024 should be an interesting year."

For further information visit www.predatoroilandgas.com

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: 

Enquiries:

Notes to Editors:

Predator is operator of the Guercif Petroleum Agreement onshore Morocco which is prospective for Tertiary and Jurassic gas. The current focus of the exploration and appraisal drilling programme is located less than 10 kilometres from the Maghreb gas pipeline. The MOU-1 well drilled in 2021 and the MOU-3 and MOU-4 wells drilled in 2023 have been completed for rigless testing in early 2024. Near-term focus is on supplying compressed natural gas ("CNG") to the Moroccan industrial market. A Collaboration Agreement for potential CNG gas sales of up to 50 mm cfgpd has been executed with Afriquia Gaz. Further drilling activity is anticipated in 2024 to further evaluate the MOU-4 Jurassic prospect.

Predator is seeking in the medium term to apply CO2 EOR techniques onshore Trinidad which have the advantage of sequestrating anthropogenic carbon dioxide. The acquisition of T-Rex Resources (Trinidad) Ltd. ("T-Rex") is a first step to realising this objective. T-Rex holds the Cory Moruga Production Licence. Cory Moruga is a largely undeveloped near-virgin oil field of similar potential size to the nearby Moruga West and Inniss-Trinity mature oil fields. The Cory Moruga Production Licence is a potentially significant asset for the Company with the capability of generating positive operating profits in the near-term. Capital required for staged field development can be implemented potentially utilising operating profits generated from an increasing level of gross production revenues.

Predator owns and operates exploration and appraisal assets in licensing options offshore Ireland, for which successor authorisations have been applied for, adjoining Vermilion's Corrib gas field in the Slyne Basin on the Atlantic Margin and east of the decommissioned Kinsale gas field in the Celtic Sea. The applications for successor authorisations remain "under consideration" by the DECC.

Predator has developed a Floating Storage and Regasification Project ("FSRUP") for the import of LNG and its regassification for Ireland and is also developing gas storage concepts to address security of gas supply and volatility in gas prices during times of peak gas demand.

Further progress for the Mag Mell FSRUP will be dependent on government policy in relation to security of energy supply. A generalised FSRUP concept has now been recognised by the government as an option for security of energy supply.

The Company has a small but highly experienced management team with a proven track record in successfully executing drilling operations in the oil and gas sector and in acquiring assets where there is a potential to generate multiple returns for relatively low and manageable levels of investment.

The accompanying accounting policies and notes on pages 94 to 121 form an integral part of these financial statements.

All items in the above statement derive from continuing operations.

The Company has adopted the exemption under Companies (Jersey) Law 1991 Article 105 (11) not to prepare separate accounts. The Group reported a loss after taxation for the year of £4.8 million (2022: £2.6 million loss). The financial statements were approved and authorised for issue by the Board of Directors on 9 April 2024 and were signed on its behalf by:

Paul Griffiths

Director

Statement of accounting policies

For the year ended 31 December 2023

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 or preparation and going concern assessment

The principal accounting policies adopted in the preparation of the financial information are set out below. The policies have been consistently applied throughout the current year and prior year, unless otherwise stated. These financial statements have been prepared in accordance with International Financial Reporting Standards (IFRSs and IFRIC interpretations) issued by the International Accounting Standards Board (IASB) as adopted by the European Union and with those parts of the Companies (Jersey) Law, 1991 applicable to companies preparing their accounts under IFRS. The Company has adopted the exemption under Companies (Jersey) Law 1991 Article 105 (11) not to prepare separate accounts.

The consolidated financial statements incorporate the results of Predator Oil & Gas Holdings Plc and its subsidiary undertakings as at 31 December 2023. In prior years, the financial statements notes were rounded to the nearest thousands and did not follow the same treatment as the prime statements, therefore, the Directors have amended the presentation of the notes to be rounded to the nearest pound.

The financial statements are prepared under the historical cost convention on a going concern basis. The financial statements of the subsidiaries are prepared for the same reporting period as the parent company, using consistent accounting policies. All intra-group balances, transactions, income and expenses and profits and losses resulting from intra-group transactions that are recognised in assets, are eliminated in full. Subsidiaries are fully consolidated from the date of acquisition, being the date on which the Group obtains control, and continue to be consolidated until the date that such control ceases.

The preparation of financial statements requires an assessment on the validity of the going concern assumption. 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, Irish licence interests, Moroccan licence and the Trinidad licence. Pursuant to a Prospectus in August 2023 total capital of £10 million before expenses, was raised. At 31 December 2023 the Group held £6.5 million in cash. In 2024 a minor quantum of these funds will be required for general working capital for corporate overheads and for overheads in Morocco, Ireland and Trinidad. The Group has committed to a programme of testing wells following a successful drilling campaign in Morocco and following the acquisition of TRex Resources, to well workovers in Trinidad. Expenditures on these activities will be comfortably met through the course of 2024 and into 2025 without resorting to raising fresh funding. The Group also has announced an intention to pursue various incremental activities in Morocco and Trinidad. Progressing these discretionary activities will be dependent partly, on further equity and or debt fund raises and in the case of Trinidad will be supported by the proceeds of oil production following the aforesaid workovers. Directors are confident that the Group will be able to meet requirements over the course of the next 24 months.

 Change in Accounting Policies

At the date of approval of these financial statements, certain new standards, amendments and interpretations have been published by the International Accounting Standards Board but are not as yet effective and have not been adopted early by the Group. All relevant standards, amendments and interpretations will be adopted in the Group's accounting policies in the first period beginning on or after the effective date of the relevant pronouncement.

At the date of authorisation of these financial statements, a number of Standards and Interpretations were in issue but were not yet effective. The Directors do not anticipate that the adoption of these standards and interpretations, or any of the amendments made to existing standards as a result of the annual improvements cycle, will have a material effect on the financial statements in the year of initial application.

Standards and amendments to existing standards effective 1 January 2023

- Amendment to IAS 37 - Provisions, Contingent Liabilities and Contingent Assets - Onerous contracts.

- Amendments to IFRS 3 - Business Combinations - Reference to Conceptual Framework

- Amendments to IAS 16 - Property, Plant and Equipment - Proceeds before Intended Use

New Standards, amendments and interpretations effective after 1 January 2023 and have not been early adopted

The Group does not believe that the standards not yet effective, will have a material impact on the consolidated financial statements.

Areas of estimates and judgement

The preparation of the group financial statements in conformity with generally accepted accounting principles requires the use of estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Although these estimates are based on management's best knowledge of current events and actions, actual results may ultimately differ from those estimates. The Group commenced operations in 2018 and did not enter into material operational transactions requiring significant estimates and assumptions to be effected in preparation of financial statements for the reporting period. The critical accounting estimates and judgements made are in line with those made in the audited financial statements for the year ended 31 December 2022 with the exception of estimates used in the relation to the valuation of the acquisition of T-Rex Resources (Trinidad) Limited as detailed in note 12.

Provisions

Provisions are recognised when the Group has a present obligation (legal or constructive) as a result of a past event and it is probable that an outflow of resources embodying economic benefits will be required to settle the obligation and a reliable estimate can be made of the amount of the obligation. Where the Group expects some or all of a provision to be reimbursed, the reimbursement is recognised as a separate asset but only when the reimbursement is virtually certain. The expense relating to any provision is presented in the statement of comprehensive income net of any reimbursement. If the effect of the time value of money is material, provisions are discounted using a current pre-tax rate that reflects, where appropriate, the risks specific to the liability. Where discounting is used, the increase in the provision due to the passage of time is recognised as a borrowing cost.

a) Going concern

The Group's cash flow projections indicate that the Group should have sufficient resources to continue as a going concern. As at 31 December 2023 the Group had cash of £6.5 million, no debt 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. In addition, the Group is fully funded for all firm operational commitments for 2024.

Heretofore the Group has not generated revenues from operations. Going forward the Group will depend on raising equity, debt finance and licence and or joint venture partnerships to finance the Group's projects to maturity and revenue generation.

The Group's subsidiaries are funded by inter-company loans advanced by Predator Oil & Gas Holdings plc ('the Company'). The recoverability of the inter-company loans advanced depends also on the subsidiaries realising their cash flow projections.

The Board have reviewed a range of potential cash flow forecasts for the period to 31 December 2025, including reasonable possible downside scenarios. This has included 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 in the latter part of 2024 following a program of well workovers in early 2024. The workovers will be funded out of existing cash resources. Leading into 2025 production revenues are forecast from the near-term well workovers of the Snowcap field wells to re-establish production and the medium implementation of a Field Development Plan, where project economics have been stress-tested at lower oil prices. Accumulated material tax losses in T-Rex significantly improve the near-term positive cash flow projections even at a lower oil price. The Licence provides the Group with the potential to generate strongly positive cashflows so as possibly to contribute organically towards further development of the Group's assets. Capital required for a staged field development in 2025 could be funded from operating profits generated from an increasing level of gross production revenues following the well workovers. The Group may resort to the option of raising equity funding to accelerate this development if need be.

The Initial Work Programme agreed by TRex with the MEEI will be conducted over the next three years without any fixed commitments to be met in the first two years.

2. Morocco - Guercif licence

In the case of Predator Gas Ventures Ltd., recovery of inter-company loans is dependent upon the two phases of the Guercif rigless testing programme successfully recovering commercial quantities of gas that can be developed and brought to market. Following significant gas discoveries in 2023 a programme of rigless testing is underway in H1 2024. Phase1 of this programme is fully funded. The Company may drill two appraisal or development wells to potentially, if successful, add incremental gas resources to support and extend the production profiles of a CNG project. Funding and timing of the discretionary drilling programme will be dictated by the availability and quantum of production revenues generated by Cory Moruga and the opportunity for partial monetisation of gas assets in Guercif. The Moroccan gas market is commercially attractive and even relatively low volumes of discovered gas are likely to be economic. The Collaboration Agreement with Afriquia Gaz for negotiating a Gas Sales Agreement de-risks the marketing of even small volumes of gas. Funding for a CNG project likely will be secured by project finance which may include a leasing arrangement for CNG trailers and equipment and or a partial sale of equity in the project. The Company also is seeking to drill in H1 2024 the Jurassic target, the extreme edge of which was penetrated in the MOU-4 downdip. Funding for this well be either through an equity placing and or the Group's internal cash resources.

3. 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 in 2024. The Group is awaiting the outcome of applications for successor authorisations to Licensing Options 16/26 (Corrib South) and 16/30 (Ram Head) which remain under consideration by the Department of the Environment, Climate and Communications. There are not likely to be any significant funding implications emerging from this process in 2024. In the future, the potential exists for the Company, as promoters of an LNG project to receive introduction and service providers' fees and a free minority equity position in a joint venture vehicle to move to the project development stage. Alternatively, should an award of a successor authorisation occur in 2024 our Corrib South asset may attract interest from a Corrib gas field participant possibly resulting in a monetisation event. During 2023 the Company had an unsolicited approach from a partner in the Corrib gas field to potentially acquire some or all of its interest in Corrib South in the event a successor authorisation is awarded in 2024. Under these circumstances the inter-company loan would constitute past costs contributing to the level of free equity. The commercial terms of any future potential transaction may or may not be capable of satisfying the quantum of the inter-company loan.

Management have also assessed that the carrying value and recoverability of the investment, including intercompany receivables is ultimately dependent on the value of the underlying assets of the Group. Further evidence of its realisable value can also be noted by reference the market capitalisation of the Group on the

London Stock exchange at the date of this report which can be used as a guide and to provide further assurance of its carrying value subsequent to the year end.

b) Share based payments

The Group has applied the requirements of IFRS 2 Share-based Payment for all grants of equity instruments.

The Group operates an equity settled share option scheme for directors. The increase in equity is measured by reference to the fair value of equity instruments at the date of grant. The liabilities incurred under these arrangements are assumed to be converted into shares in the parent company, under an option arrangement. The fair value of the service received in exchange for the grant of options and warrants is recognised as an expense. Equity-settled share-based payments are measured at fair value (excluding the effect of non-market based vesting conditions) at the date of grant. The fair value determined at the grant date of equity-settled share-based payment is expensed over the vesting period, based on the Group's estimate of shares that will eventually vest and adjusted for the effect of non-market based vesting conditions.

During the year, the Company issued warrants in lieu of fees to stockbrokers. The warrant agreements do not contain vesting conditions and therefore the full share-based payment charge, being the fair value of the warrants using the Black-Scholes model, has been recorded immediately. The charge is recognised within the statement of changes in equity. The valuation of these warrants involves making a number of estimates relating to price volatility, future dividend yields and continuous growth rates (see Note 19).

The fair value of the share options is estimated by using the Black Scholes model on the date of grant based on certain assumptions. Those assumptions are described in note 19 and include, among others, the expected volatility and expected life of the options. The expected life used in the model has been adjusted, based on management's best estimate, for the effects of non-transferability exercise restrictions and behavioural considerations. The market price used in the model is the market price at the date of the issue of the options. Where the terms and conditions of options are modified before they vest, the increase in the fair value of the warrants, measured immediately before and after the modification, is also charged to profit or loss over the remaining vesting period.

Where equity instruments are granted to persons or entities other than staff, the fair value of goods and services received is charged to profit or loss, except where it is in respect to costs associated with the issue of shares, in which case, it is charged to the share premium account.

The fair values calculated are inherently subjective and uncertain due to the assumptions made and the limitation of the calculations used. Further details of the specific amounts concerned are given in note 19.

c) Intangible assets - Project Guercif

All expenditure relating to oil and gas activities is capitalised in accordance with the "successful efforts" method of accounting, as described in IFRS 6 - "Exploration for and Evaluation of Mineral Resources". Under this standard, the Group's exploration and appraisal activities are capitalised as intangible assets.

The direct costs of exploration and appraisal are initially capitalised as intangible assets, pending determination of the existence of commercial reserves in the licence area. Such costs are classified as intangible assets based on the nature of the underlying asset, which does not yet have any proven physical substance. Exploration and appraisal costs are held, un-depreciated, until such a time as the exploration phase on the licence area is complete or commercial reserves have been discovered.

If no commercial reserves exist, then that particular exploration/appraisal effort was "unsuccessful" and the costs are written off to the income statement in the period in which the evaluation is made. The success or failure of each exploration/appraisal effort is judged on a field by field basis.

Net proceeds from any disposal of an exploration asset are initially credited against the previously capitalised costs. Any surplus proceeds are credited to the income statement. Net proceeds from any disposal of exploration assets are credited against the previously capitalised cost. A gain or loss on disposal of an exploration asset is recognised in the income statement to the extent that the net proceeds exceed or are less than the appropriate portion of the net capitalised costs of the asset.

Upon commencement of production, capitalised costs will be amortised on a unit of production basis which is calculated to write off the expected cost of each asset over its life in line with the depletion of proved and probable reserves.

For more information, please refer to note 10.

Business combinations

Business combinations are accounted for using the acquisition method. The cost of an acquisition is measured as the fair value of the assets given, equity instruments issued, and liabilities incurred or assumed at the acquisition date.

Identifiable assets acquired and liabilities assumed are measured and recognized at their fair value at the date of the acquisition, with the exception of income taxes, and lease liabilities. Any deferred tax asset or liability arising from a business combination is recognized at the acquisition date. Transaction costs associated with a business combination are expensed as incurred. Results of acquisitions are included in the financial statements from the closing date of the acquisition. If the consideration of the acquisition is less than the fair value of the net assets received, the difference is recognized immediately in the statements of comprehensive income. If the consideration of the acquisition is greater than the fair value of the net assets received, the difference is recognised as goodwill on the consolidated balance sheet.

The directors have included provisional fair values within the business combination note as presented above, which represent their best estimates using information available at the year end. Under IFRS 3, there is a measurement period which shall not exceed one year from the acquisition date, during which the company can, if necessary, retrospectively adjust the provisional amounts recognised at the acquisition date to reflect new information obtained about facts and circumstances that existed as of the acquisition date.

Basis of consolidation

Where the Group has control over an investee, it is classified as a subsidiary. The Group controls an investee if all three of the following elements are present: power over the investee, exposure to variable returns from the investee, and the ability of the investor to use its power to affect those variable returns. Control is reassessed whenever facts and circumstances indicate that there may be a change in any of these elements of control.

The consolidated financial statements present the results of the Company and its subsidiaries ("the Group") as if they formed a single entity. Inter-company transactions and balances between Group companies are therefore eliminated in full. Uniform accounting policies are applied across the Group.

The consolidated financial statements incorporate the results of business combinations using the acquisition method. In the statement of financial position, the acquirer's identifiable assets, liabilities and contingent liabilities are initially recognised at their fair values at the acquisition date. The results of acquired operations are included in the consolidated statement of comprehensive income from the date on which control is obtained. They are deconsolidated from the date on which control ceases.

Intangible assets

Mineral exploration and evaluation expenditure relates to costs incurred in the exploration and evaluation of potential mineral resources and includes exploration and mineral licences, researching and analysing historical exploration data, exploratory drilling, trenching, sampling and the costs of pre-feasibility studies.

Exploration and evaluation expenditure for each area of interest, other than that acquired from another entity, is charged to the consolidated statement of income as incurred except when the expenditure is expected to be recouped from future exploitation or sale of the area of interest and it is planned to continue with active and significant operations in relation to the area, or at the reporting period end, the activity has not reached a stage which permits a reasonable assessment of the existence of commercially recoverable reserves, in which case the expenditure is capitalised. Purchased exploration and evaluation assets are recognised at their fair value at acquisition. As the capitalised exploration and evaluation expenditure asset is not available for use, it is not depreciated.

Exploration and evaluation assets have an indefinite useful life and are assessed for impairment annually or when facts and circumstances suggest that the carrying amount of an asset may exceed its recoverable amount. The assessment is carried out by allocating exploration and evaluation assets to cash generating units, which are based on specific projects or geographical areas. IFRS 6 permits impairments of exploration and evaluation expenditure to be reversed should the conditions which led to the impairment improve. The Group continually monitors the position of the projects capitalised and impaired.

Whenever the exploration for and evaluation of mineral resources in cash generating units does not lead to the discovery of commercially viable quantities of mineral resources and the Group has decided to discontinue such activities of that unit, the associated expenditures are written off to the Statement of comprehensive income.

Financial assets

The Financial assets currently held by the Group and Company are classified as loans and receivables and cash and cash equivalents. These assets are non-derivative financial assets with fixed or determinable payments that are not quoted in an active market. They are initially recognised at fair value plus transaction costs that are directly attributable to their acquisition or issue and are subsequently carried at amortised cost using the effective interest rate method less provision for impairment.

Impairment provisions are recognised when there is objective evidence (such as significant financial difficulties on the part of the counterparty or default or significant delay in payment) that the Group will be unable to collect all of the amounts due under the terms receivable, the amount of such a provision being the difference between the net carrying amount and the present value of the future expected cash flows associated with the impaired receivable. For receivables, which are reported net, such provisions are recorded in a separate allowance account with the loss being recognised within administrative expenses in the statement of comprehensive income. On confirmation that the receivable will not be collectable, the gross carrying value of the asset is written off against the associated provision.

Cash and cash equivalents

These amounts comprise cash on hand and balances with banks. Cash equivalents are short term, highly liquid accounts that are readily converted to known amounts of cash. They include short-term bank deposits and short-term investments.

Any cash or bank balances that are subject to any restrictive conditions, such as cash held in escrow pending the conclusion of conditions precedent to completion of a contract, are disclosed separately as "Restricted cash". The security deposit is recognised within trade and other receivables in note 14.

There is no significant difference between the carrying value and fair value of receivables.

Derecognition

The Group derecognises a financial asset when the contractual rights to the cash flow from the asset expire, or it transfers the asset and substantially all the risk and rewards of ownership of the asset to another entity.

Financial liabilities

The Group's financial liabilities consist of trade and other payables (including short terms loans) and long term secured borrowings. These are initially recognised at fair value and subsequently carried at amortised cost, using the effective interest method. All interest and other borrowing costs incurred in connection with the above are expensed as incurred and reported as part of financing costs in profit or loss. Where any liability carries a right to convertibility into shares in the Group, the fair value of the equity and liability portions of the liability is determined at the date that the convertible instrument is issued, by use of appropriate discount factors.

Derecognition

The Group derecognises a financial liability when the obligations are discharged, cancelled or they expire.

Foreign currency

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.

The exchange rates applied at each reporting date were as follows:

31 December 2023 - £1: £1 : US$1.2731, £1 : Euro1.1505 , £1 : MAD12.5947 and £1: TT$ 8.34

31 December 2022 - £1: US$1.2041, £1: Euro1.1313 and £1: MAD12.5824

Investments in subsidiaries

The Group's investment in its subsidiaries are recorded at cost.

Plant and equipment

Plant and equipment owned by the Group relates solely to computer equipment.

Depreciation is provided on equipment so as to write off the carrying value of items over their expected useful economic lives. It is applied at the following rates:

Computer equipment - 20% per annum, straight line

Share options and Equity Instruments

Where the terms and conditions of options are modified before they vest, the increase in the fair value of the options, measured immediately before and after the modification, is also charged to profit or loss over the remaining vesting period. Where equity instruments are granted to persons other than consultants, the fair value of goods and services received is charged to profit or loss, except where it is in respect to costs associated with the issue of shares, in which case, it is charged to the share capital or share premium account.

Equity instruments

Share capital represents the amount subscribed for shares at each of the placings.

The reconstruction reserve account represents premiums received on the share capital of subsidiaries and also includes directly related share issue costs.

Warrants issuance cost reserve includes any costs relating to warrants issued for services rendered accounted for in accordance with IFRS 2 - Equity-settled instruments.

The share-based payments reserve represents equity-settled shared-based employee remuneration for the fair value of the options issued.

Retained earnings include all current and prior period results as disclosed in the Statement of comprehensive income, less dividends paid to the owners of the Company.

Taxation

The Company and all subsidiaries ('the Group') are registered in Jersey, Channel Islands and are taxed at the Jersey company standard rate of 0%. However, the Group's projects are situated in jurisdictions where taxation may become applicable to local operations.

The major components of income tax on the profit or loss include current and deferred tax.

Current tax

Current tax is based on the profit or loss adjusted for items that are non-assessable or disallowed and is calculated using tax rates that have been enacted or substantively enacted by the reporting date.

Tax is charged or credited to the statement of comprehensive income, except when the tax relates to items credited or charged directly to equity, in which case the tax is also dealt with in equity.

Deferred tax

Deferred tax assets and liabilities are recognised where the carrying amount of an asset or liability in the statement of financial position differs to its tax base, except for differences arising on:

• The initial recognition of an asset or liability in a transaction which is not a business combination and at the time of the transaction affects neither accounting or taxable profit; and

• Investments in subsidiaries and jointly controlled entities where the Group is able to control the timing of the reversal of the difference and it is probable that the differences will not reverse in the foreseeable future.

Recognition of deferred tax assets is restricted to those instances where it is probable that taxable profit will be available against which the difference can be utilised.

The amount of the asset or liability is determined using tax rates that have been enacted or substantively enacted by the reporting date and are expected to apply when deferred tax liabilities/ (assets) are settled/ (recovered). Deferred tax balances are not discounted.

Predator Gas Ventures Limited has a Withholdings Tax Liability in Morocco for all services that are carried out in in relation to wells. The Withholdings Tax is charged at 10% on all services (excluding material) (see note 4).

1. 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.

Exploration and development are reported to the CODM only on the basis of those costs incurred directly on projects.

Administration and corporate costs are further reviewed on the basis of spend across the Group.

Decisions are made about where to allocate cash resources based on the status of each project and according to the Group's strategy to develop the projects. Each project, if taken into commercial development, has the potential to be a separate operating segment. Operating segments are disclosed below on the basis of the split between exploration and development and administration and corporate.

No charge to taxation arises due to the losses incurred.

Predator Gas Ventures Limited is subject to tax in its operating jurisdiction of Morocco; however, the Company is loss making and has no taxable profits to date.

No deferred tax asset has been recognised on accumulated tax losses because of uncertainty over the timing of future taxable profits against which the losses may be offset.

No deferred tax asset or liability has been recognised as the Standard Jersey corporate tax rate is 0%.

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 £321,622 (2022: £236,575). The Group does not have employees. All personnel are engaged as service providers.

Dilutive loss per Ordinary Share equals basic loss per Ordinary Share as, due to the losses incurred in 2023 and 2022, there is no dilutive effect from the subsisting share options.

9 Loss for the financial year

The Group has adopted the exemption in terms of Companies (Jersey) law 1991 and has not presented its own income statement in these financial statements.

Project Guercif

The total carrying amount of Project Guercif as at 31 December 2023 of £12,335,992 (2022: £5,275,000) relates to costs incurred with wells MOU-1, MOU-2, MOU-3 and MOU-4.

MOU-1, MOU-3 and MOU-4

In conformance with the current Moroccan regulatory procedures for rigless well testing, the Company has expressed in writing to the Office National des Hydrocarbures et des Mines ("ONHYM") the intention to test MOU-1, MOU-3 and MOU-4. Planning for these activities was carried out in Q4 2023.

The Company will begin Phase 1 rigless well testing for MOU-1 and MOU-3 at the very earliest opportunity once the regulatory process has been fully complied with all approvals and consents are given.

MOU-2:

On 25 January 2023, the Company announced that MOU-2 well had been suspended with an option to re-enter after reaching a depth of 1,260 metres Measured Depth.

Wireline logs were acquired from the 95/8" casing point at 677 metres to 1,010 metres Measured Depth. The wireline logging tools were not able to log deeper than this depth due the presence of extremely sticky clays in a geological formation overlying the Moulouya Fan primary objective.

The debris flow potentially forms a highly effective seal on the underlying Moulouya Fan. The thickness of the Moulouya Fan reservoir interval is expected to increase between MOU-1 and MOU-2 based on the sand content of the debris-flow penetrated in MOU-2 allowed an extrapolation across to MOU-1 to be made. A re-entry and deepening of MOU-2 will be fully evaluated once a solution to optimising the drilling mud programme and mud properties has been completed.

Isotube gas samples were recovered from the shallow section above 700 metres measured depth.

All costs relating to Project Guercif have been capitalised and will only be depreciated once gas discovery is declared commercial and a Plan of Development has been approved.

In accordance with IFRS 6, the Directors undertook an assessment of the following areas and circumstances which 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