| Genel Energy PLC (GENL) 26 March 2024 Genel Energy plc Audited results for the year ended 31 December 2023
Genel Energy plc (‘Genel’ or ‘the Company’) announces its audited results for the year ended 31 December 2023.
Paul Weir, Chief Executive of Genel, said: “We have continued the journey that we commenced in 2022 to, firstly, refocus the business on areas where it can be profitable and deliver shareholder value and, secondly, optimise the organisation to create a reshaped and resilient business with the potential for transformational value accretion through several catalysts.
We are a leaner, simplified company that retains clear objectives – generating resilient and sustainable cash flows, diversifying our income through the addition of new assets, and maintaining a strong balance sheet.
We have reduced our workforce and cut costs significantly, exited the Sarta and Qara Dagh licences, worked with our operating partner to develop a new income stream from local sales, and spent considerable time defending our contractual rights under the Bina Bawi and Miran PSCs, where we invested over $1.4 billion before their termination in December 2021.
These actions mean that we are now well positioned in 2024, with a reshaped and resilient business and a strong balance sheet. In the absence of value accretive M&A, we expect to maintain net cash of more than $100 million even if the suspension of exports continues to the end of the year.
Genel has established a sound platform from which to spring forward. The re-opening of the pipeline has the potential to more than double cash generation. We expect to recover the $107 million of overdue receivables, and we have the capacity and intent to acquire new assets. On the Miran and Bina Bawi oil and gas assets arbitration, having now completed the evidential hearing, our views on the merits of our case are unchanged since the arbitration was launched in December 2021.”
Results summary ($ million unless stated)
Highlights
Potential catalysts for significant shareholder value creation in 2024
Enquiries:
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This announcement includes inside information.
Disclaimer This announcement contains certain forward-looking statements that are subject to the usual risk factors and uncertainties associated with the oil & gas exploration and production business. Whilst the Company believes the expectations reflected herein to be reasonable in light of the information available to them at this time, the actual outcome may be materially different owing to factors beyond the Company’s control or within the Company’s control where, for example, the Company decides on a change of plan or strategy. Accordingly, no reliance may be placed on the figures contained in such forward looking statements.
CEO STATEMENT It is difficult to look at 2023 without it being dominated by the closure of the Iraq-Türkiye pipeline. The suspension of our route to export resulted in a material reduction in production and cash flow. In a year in which we were buffeted by factors beyond our control, it was a reminder of the inherent resilience of our business model, a resilience that means we retain a strong position from which we view the future with confidence.
Going in to 2023, one of our key aims was to continue the simplification of the business, focusing on optimisation and cost control and investment in business improvement. With the ITP suspended, we accelerated this journey, significantly changing the size and shape of the organisation, materially reducing our cost base. We are now in a position where our income from strong local sales in January and February 2024 has covered our outflows, we have over $100 million in net cash, and significant opportunities lie ahead.
A reshaped business The closure of the pipeline prompted us to move quickly to reduce our capital expenditure, with $50 million cut from our original budget. We have more than halved our workforce, and we have shed non-profitable assets. We allowed the Qara Dagh licence to lapse, and Sarta has been terminated. We are a significantly leaner vehicle than we were even six months ago, having efficiently closed out our activity at Sarta and having minimised our footprint and cost base in Kurdistan. And we are getting leaner still, encouraging a constant state of awareness in the business about how we can drive further cost efficiencies.
As we have cut costs we have ensured that we have kept the right personnel to grow the business in the better times that certainly lie ahead. It is important that a reshaped business does not mean a business that lacks skills, and we must ensure that we have the correct balance between being right sized in the current environment and having the right people to drive Genel forward and take advantage of upcoming opportunities.
All of the changes that we have made to the business have been done with our shareholders in mind, protecting shareholder funds and ensuring that we remain resilient with a robust balance sheet, with a business that is set up to maximise shareholder value going forward.
Robustly positioned Our focus on resilience is bolstered by income from the Tawke licence, which remains the engine room of the business. Working with the operator, DNO, a great job has been done to build a new income stream from local sales, while cutting operational costs by 65%. Production ramped up through the second half of the year, and local sales have been material and robust so far this year.
Going forward we expect cash generation from these local sales to match our total business expenditure, should income remain at levels seen in Q1 2024. Should the ITP reopen, our cash generation has the potential to more than double overnight. Along with our industry peers, we continue to work hard to facilitate the resumption of exports with appropriate commercial terms. Positive comments are regularly being made by politicians from both the Federal Government of Iraq and the KRG, although these are not being supported by movement on key issues so far. The timing of export resumption is therefore not something that we can suggest with any certainty.
Opportunities ahead The reopening of the export route, with a stable and predictable payment environment, is one of the numerous catalysts that we can see ahead in 2024. We are reviewing all options relating to the $107 million that is still owed for past exports, the repayment of which would help to further strengthen our balance sheet and boost cash generation.
As we work to unlock the significant value from Kurdistan, we continue our search to add new income streams elsewhere. Our criteria for new assets have not changed – we are focused on cash generation, seeking a value accretive deal in a stable jurisdiction. We remain laser focused and disciplined as we seek the right deal for our shareholders, and are comfortable looking beyond the MENA region to get a deal that ticks all of our boxes. As we reshaped our business in 2023, we have continued our search for the right opportunity to integrate within Genel. There remain opportunities out there that fit our criteria, and we are confident that we will find the correct deal.
Miran and Bina Bawi arbitration progressing The Company has committed significant senior management time to the arbitration relating to the Miran and Bina Bawi PSCs. As a reminder, our position is that the KRG’s termination of the Bina Bawi and Miran licences in December 2021 was repudiatory and caused us significant losses. By way of reference, we have spent over $1.4 billion acquiring and attempting development of these assets, both as operator and non-operator up to the termination of both PSCs in December 2021.
The two-week hearing (including factual and expert evidence) was held in London as scheduled and ended on 1 March 2024. The timing of the result is uncertain, but is expected by the end of 2024 following the Parties making closing written submissions in April 2024 and reply written submissions in May 2024. Our views on the merits of the case are unchanged since the dispute process under the PSCs was commenced in Q3 2021.
Outlook Genel retains a robust cash position, a resilient business model, and a focus on taking advantage of the material catalysts ahead.
OPERATING REVIEW Reserves and resources development Genel's proven plus probable (2P) net working interest reserves totalled 89 MMbbls (31 December 2022: 92 MMbbls) at the end of 2023. A positive 4 MMbbls revision of 2P reserves at the Tawke PSC offset the removal of 2.7 MMbbls of 2P reserves from the terminated Sarta PSC, with 4.5 MMbbls of production in 2023.
Production Net production in 2023 averaged 12,410 bopd, significantly down on the prior year (2022: 30,150 bopd) due to the suspension of the ITP. This caused there to be minimal sales in the second quarter of the year, before the local sales market was established in Q3 and production was then ramped up in Q4. Production was dominated by the Tawke PSC, which produced 11,570 bopd.
All Genel production in H2 2023 came from the Tawke PSC. Gross production from the Tawke licence increased to 65,780 bopd in Q4 2023, up from 25,980 bopd in Q3, with the field partners selling their entitlement share into the local market.
PRODUCING ASSETS Tawke PSC (25% working interest) Gross production from the Tawke licence averaged 46,280 bopd in 2023, impacted by the closure of the ITP. Following the start of local sales in H2, production increased to 65,780 bopd in Q4 2023.
At the end of 2023, gross production from the Tawke licence was averaging 80,000 bopd, with entitlement barrels sold at prices in the low-to-mid $30s per barrel. The operator, DNO, expects gross production at the licence to continue to average 80,000 bopd. That figure could change depending on the outcome of ongoing discussions related to recovery of arrears for past deliveries to the KRG and payment terms and conditions for any future oil exports, which in turn will drive investments in wells.
With operational spend having been reduced by 65%, the Tawke PSC is currently generating over $3 million a month in net cash flow for Genel from strong local sales, which if retained at current levels is able to cover total organisational spend away from the licence.
Taq Taq (44% working interest, joint operator) Prior to the closure of the ITP, field partners were planning a resumption of drilling at Taq Taq. In line with Genel’s focus on reducing costs, and lack of clarity regarding the resumption of exports and payments, this plan was dropped. Costs were reduced to below $1 million per month at the start of 2024, and further cuts are expected to reduce this to around half a million dollars per month. Given the lack of meaningful cash flows expected to come from Taq Taq going forward, its place in the Genel portfolio is under review.
Sarta (30% working interest, operator) Genel’s focus at the start of 2023 was on making ongoing production from Sarta profitable, and capital investment was contingent on both licence profitability and the extent to which there could be confidence that such investment would add cash generative production. Given the investment required, and the lack of certainty over a resumption of payments, Genel and its joint venture partner, Chevron, informed the Ministry of Natural Resources of its intention to surrender the asset and thereby terminate the Sarta PSC on 1 December 2023.
Remediation work was completed in Q1 2024, at a net cost of $1 million, and there will be no further material expenditure at Sarta going forward.
PRE-PRODUCTION ASSETS Somaliland Work continued in 2023 on readiness towards the potential drilling of a well at the Toosan-1 well site on the SL10B13 block (51% working interest and operator). The Environmental, Social and Health Impact Assessment was finished, and required civil work at the well site at this stage of the project is now complete.
Genel continues to believe that there is a tremendous opportunity in Somaliland, and is assessing the timing of further investment. There is no significant expenditure expected in 2024, and a licence extension has been granted which allows for drilling to be undertaken in due course.
Morocco (Lagzira block - 75% working interest and operator) The farm-out programme on the Lagzira block is ongoing.
FINANCIAL REVIEW
1 Net cash interest is bond interest payable less bank interest income (see note 5)
2023 financial priorities With the export pipeline suspended from March, 2023 did not generate the financial performance that we had planned for, but we have taken decisions that mean we have ended the year in a resilient position, with an outlook where we can see a clear route to delivery of material shareholder value. While the closure of the ITP accelerated and deepened some of our planned cost cutting, we were already well on the way to reshaping the business and ensuring that it has the financial strength to endure challenges and maintain our exposure to the significantly value accretive potential events that we hope to see materialise in 2024.
The table below summarises our progress against the 2023 financial priorities of the Company as set out in our 2022 results.
Outlook and financial priorities for 2024 The key principles of our financial focus remain largely unchanged. We have a resilient business model that will continue to mitigate negative events and maximise potential upside, all with a firm focus on maximising cash generation. Ultimately, successful strategic delivery will lead to a resumption of shareholder returns, through delivering robust, resilient, diverse, and predictable cash flows.
Maintain business resilience and balance sheet strength Running a resilient business with a strong balance sheet is a key component of our business model. It is particularly relevant at the current time, with the lack of access to export prices and volumes and the delayed receipt of amounts owed. While the ITP remains closed, we protect the balance sheet and resilience of the business by balancing the sources and uses of our cash flows. Actions taken to reduce costs and restructure the organisation in 2023 have prepared us well for this, with monthly organisation spend excluding the cash-generative Tawke PSC reduced to under $3 million per month at the time of writing.
Local market sales since November 2023 have seen relatively consistent volumes, which has required constant attention from the operator. We believe the Tawke PSC is well positioned to continue to deliver stable and meaningful cash flows that will be sufficient to cover our costs, and as a consequence we expect to retain a net cash position of over $100 million in 2024. Should the pipeline open, which we expect, then the subsequent establishment of regular payments would materially boost our cash generation, with the receipt of our outstanding receivable of $107 million offering further significant upside.
Ensure capital availability for funding of key strategic objectives Our capital allocation priorities remain maintenance of a strong balance sheet and funding of the Company’s strategic objectives in order to generate long-term value for shareholders.
We are currently retaining a significant cash balance in excess of the cash required to fund the organic business in order to fund the acquisition of new assets, as we seek to diversify our income streams. This balance is partly funded by our bond debt of $248 million, which matures in October 2025. We retain strict discipline as we seek new opportunities, with appropriate economic analysis and downside planning key considerations.
With a coupon that is low relative to prevailing market rates, the net cost of retaining this optionality is low.
Ensure appropriate capital allocation In pursuit of our strategic objectives, robust assessment of the expected benefit to be obtained from invested capital underpins our processes to ensure appropriate allocation of capital, making sure that each dollar spent is done so in the knowledge that we are custodians of shareholder funds.
In 2023, as well as cutting our capital allocation appropriately in the face of the ongoing ITP closure, with Tawke drilling suspended, we ensured that any investment was necessary and effective towards improving the profitability of our business and achieving our objectives.
At the start of the year, we took the decision to exit the Qara Dagh licence, due to the extent of certainty that redrilling on the licence would have a positive outcome. For similar reasons, it was decided not to pursue other drilling opportunities at Sarta, and to reduce costs appropriately at Taq Taq. This focus has meant that our future activity at that licence is under review. Finally, we agreed with the government and our partner to extend the exploration period on the Toosan-1 well in Somaliland. There is the opportunity for significant value creation in Somaliland, where we remain excited about the potential of the subsurface.
In addition, we invested in the Miran and Bina Bawi arbitration process, where we are seeking to protect our contractual position under the PSCs which are governed by English law. We have invested over $1.4 billion in the acquisition and attempted development of these assets, and we will continue to ensure that funds are available to pursue collection in the event of an Award in Genel’s favour.
Finally, we reduced our debt by nominal $26 million of our debt at a cost of below 95 cents in the dollar, which provided an attractive level of return without significantly impacting our capital availability for other strategic objectives.
Financial results for the year Income statement
Production of 12,410 bopd was significantly lower than last year (2022: 30,150 bopd) as a result of the suspension of exports through the ITP. This resulted in very limited production between April and July, with production from Tawke only restarting from July at lower levels, selling into the domestic market. This decrease in production, together with the significantly lower realised price per barrel for local sales, resulted in a reduction in revenue from $402 million to $85 million, with $38 million generated from local sales in H2 2023 and the remainder of $47 million generated from export sales between January and March inclusive.
Production costs of $21 million decreased from the prior year (2022: $34 million), with cost per barrel $4.8/bbl in 2023 (2022: $3.3/bbl), with the higher cost per barrel being the result of a combination of lower production and some fixed costs.
Other operating costs of $4 million were related to Taq Taq which were incurred after production cease.
Corporate cash costs were $12 million (2022: $14 million).
The decrease in revenue resulted in a similar decrease to EBITDAX, which was $33 million (2022: $349 million). EBITDAX is presented in order to illustrate the cash operating profitability of the Company and excludes the impact of costs attributable to exploration activity, which tend to be one-off in nature, and the non-cash costs relating to depreciation, amortisation, impairments and write-offs.
Depreciation of $40 million (2022: $95 million) and Tawke intangibles amortisation of $4 million (2022: $39 million) decreased due to lower production and pipeline closure.
While Genel expects to recover its overdue receivables of $107 million in full, given there is currently no repayment plan, a net expense of $10 million has been recognised relating to the expected credit loss on overdue receivables. Further explanation is provided in note 1 to the financial statements.
Interest income of $21 million (2022: $7 million) has significantly increased as a result of the increase in interest rates, in turn reducing our net cost of debt. Bond interest expense of $25 million (2022: $26 million) was in line with the previous year. Other finance expense of $5 million (2022: $5 million) related to non-cash discount unwinding on provisions and bond which is partly offset by gain on buyback of bonds in the year.
In relation to taxation, under the terms of KRI production sharing contracts, corporate income tax due is paid on behalf of the Company by the KRG from the KRG's own share of revenues, resulting in no corporate income tax payment required or expected to be made by the Company. Tax presented in the income statement was related to taxation of the service companies (2023: $0.2 million, 2022: $0.2 million).
Following the termination of Sarta PSC in the year, income statement figures of Sarta PSC have been disclosed as discontinued operation. Further details are provided in note 7 to the financial statements.
Capital expenditure Capital expenditure was reduced to $68 million (2023: $143 million), a reduction of around $50 million reduced from our initial guidance. Spend on production assets was $59 million, and pre-production assets $9 million, with $20 million spent in H2 as expenditure cuts were made following the ITP closure.
Cash flow, cash, net cash and debt Gross proceeds received totalled $102 million (2022: $473 million).
Free cash flow is presented in order to illustrate the free cash generated for equity. Free cash outflow was $71 million (2022: $235 million inflow) with an overall decrease due to pipeline closure and delay in proceeds.
The bonds maturing in 2025 have two financial covenant maintenance tests:
Net assets Net assets at 31 December 2023 were $434 million (31 December 2022: $528 million) and consist primarily of oil and gas assets of $331 million (31 December 2022: $327 million), net trade receivables of $93 million (31 December 2022: $117 million) and net cash of $120 million (31 December 2022: $228 million).
Liquidity / cash counterparty risk management The Company monitors its cash position, cash forecasts and liquidity on a regular basis. The Company holds surplus cash in treasury bills, time deposits or liquidity funds with a number of major financial institutions. Suitability of banks is assessed using a combination of sovereign risk, credit default swap pricing and credit rating.
Going concern The Directors have assessed that the Company’s forecast liquidity provides adequate headroom over forecast expenditure for the 12 months following the signing of the annual report for the year ended 31 December 2023 and consequently that the Company is considered a going concern. Further explanation is provided in note 1 to the financial statements.
The Company is in a net cash position with no near-term maturity of liabilities.
Consolidated statement of comprehensive income For the year ended 31 December 2023
1Basic (LPS) / EPS excluding impairment is loss and total comprehensive expense adjusted for the add back of net impairment/write-off of oil and gas assets and net ECL/reversal of ECL of receivables divided by weighted average number of ordinary shares
Previous year’s figures have been restated for discontinued operation disclosure in relation to Sarta PSC (see note 7). Consolidated balance sheet At 31 December 2023
Consolidated statement of changes in equity For the year ended 31 December 2023
1 The Companies (Jersey) Law 1991 does not define the expression “dividend” but refers instead to “distributions”. Distributions may be debited to any account or reserve of the Company (including share premium account)
Consolidated cash flow statement For the year ended 31 December 2023
Notes to the consolidated financial statements
1. Summary of material accounting policies
Genel Energy Plc – registration number: 107897 (the Company), is a public limited company incorporated and domiciled in Jersey with a listing on the London Stock Exchange. The address of its registered office is 26 New Street, St Helier, Jersey, JE2 3RA.
The consolidated financial statements of the Company have been prepared in accordance with International Financial Reporting Standards as adopted by the European Union and interpretations issued by the IFRS Interpretations Committee (together ’IFRS’); are prepared under the historical cost convention except as where stated; and comply with Company (Jersey) Law 1991. The significant accounting policies are set out below and have been applied consistently throughout the period.
The Company prepares its financial statements on a historical cost basis, unless accounting standards require an alternate measurement basis. Where there are assets and liabilities calculated on a different basis, this fact is disclosed either in the relevant accounting policy or in the notes to the financial statements.
Items included in the financial information of each of the Company's entities are measured using the currency of the primary economic environment in which the entity operates (the functional currency). The consolidated financial statements are presented in US dollars to the nearest million ($ million) rounded to one decimal place, except where otherwise indicated.
For explanation of the key judgements and estimates made by the Company in applying the Company’s accounting policies, refer to significant accounting judgements and estimates on pages 17 to 19.
Going concern The Company regularly evaluates its financial position, cash flow forecasts and its compliance with financial covenants by considering multiple combinations of oil price, discount rates, production volumes, payments, capital and operational spend scenarios.
The Company has reported cash of $363 million, with its debt of $248 million maturing in the second half of 2025 and significant headroom on both the equity ratio and minimum liquidity financial covenants.
The Federal Iraq Supreme Court majority decision in February 2022 regarding the Kurdistan Oil and Gas Law (2007) and the subsequent actions taken by the Federal Minister of Oil in Baghdad Commercial Court did not have a significant impact on the Company’s cash generation. However, since then, the International Chamber of Commerce in Paris ruling in favour of Iraq in the long running arbitration case against Türkiye concerning the Iraqi-Turkish pipeline agreement signed in 1973, resulted in exports through the pipeline being suspended from 25 March 2023.
The Company is currently selling in the domestic market at lower prices and lower volumes than are available from exports, with significantly reduced cash generation.
The Company forecasts that, even with continued suspension of exports, it will have a significant net cash balance for the foreseeable future.
As a result, the Directors have assessed that the Company’s forecast liquidity provides adequate headroom over its forecast expenditure for the 12 months following the signing of the annual report for the period ended 31 December 2023 and consequently that the Company is considered a going concern.
Consolidation The consolidated financial statements consolidate the Company and its subsidiaries. These accounting policies have been adopted by all companies.
Subsidiaries Subsidiaries are all entities over which the Company has control. The Company controls an entity when it is exposed to, or has rights to, variable returns from its involvement with the entity and has the ability to affect those returns through its power over the entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Company. They are deconsolidated from the date that control ceases. Transactions, balances and unrealised gains on transactions between companies are eliminated.
Joint arrangements and associates Arrangements under which the Company has contractually agreed to share control with another party, or parties, are joint ventures where the parties have rights to the net assets of the arrangement, or joint operations where the parties have rights to the assets and obligations for the liabilities relating to the arrangement. Investments in entities over which the Company has the right to exercise significant influence but has neither control nor joint control are classified as associates and accounted for under the equity method.
The Company recognises its assets, liabilities, income and expenses relating to its interests in joint operations, including its share of assets and income held jointly and liabilities and expenses incurred jointly with other partners.
Farm-in/farm-out Farm-in/farm-out transactions undertaken in the exploration phase of an oil and gas asset are accounted for on a no gain/no loss basis due to inherent uncertainties in the exploration phase and associated difficulties in determining fair values reliably prior to the determination of commercially recoverable proved reserves. The resulting exploration and evaluation asset is then assessed for impairment indicators under IFRS 6. Any cash payment or proceeds are presented as an increase or reduction to additions respectively.
The preparation of the financial statements in accordance with IFRS requires the Company to make judgements and estimates that affect the reported results, assets and liabilities. Where judgements and estimates are made, there is a risk that the actual outcome could differ from the judgement or estimate made.
Significant judgements The following are the significant judgements that the directors have made in the process of applying the Group and Company’s accounting policies and that have the most significant effect on the amounts recognised in the financial statements.
Sarta PSC (note 10 and 7) At 31 December 2022, the Company’s assessment on the recoverable value of the Sarta PSC had resulted with an impairment expense of $125.5 million following the disappointing results of the two appraisal wells and pilot production.
In 2023, the Company has informed the KRG of its intention to exit the Sarta licence and the remaining recoverable value of the Sarta PSC have been reduced to nil and a write-off expense of $18.7 million has been booked. Following the termination of the PSC on 1 December 2023, decommissioning provisions have been derecognised.
Significant estimates The following are the critical estimates that the directors have made in the process of applying the Group and Company’s accounting policies and that have the most significant effect on the amounts recognised in the financial statements.
Estimation of hydrocarbon reserves and resources and associated production profiles and costs Estimates of hydrocarbon reserves and resources are inherently imprecise and are subject to future revision. The Company’s estimation of the quantum of oil and gas reserves and resources and the timing of its production, cost and monetisation impact the Company’s financial statements in a number of ways, including: testing recoverable values for impairment; the calculation of depreciation, amortisation and assessing the cost and likely timing of decommissioning activity and associated costs. This estimation also impacts the assessment of going concern and the viability statement.
Proved and probable reserves are estimates of the amount of hydrocarbons that can be economically extracted from the Company’s assets. The Company estimates its reserves using standard recognised evaluation techniques which are based on Petroleum Resources Management System 2018. Assets assessed as having proven and probable reserves are generally classified as property, plant and equipment as development or producing assets and depreciated using the units of production methodology. The Company considers its best estimate for future production and quantity of oil within an asset based on a combination of internal and external evaluations and uses this as the basis of calculating depreciation and amortisation of oil and gas assets and testing for impairment under IAS 36.
Hydrocarbons that are not assessed as reserves are considered to be resources and the related assets are classified as exploration and evaluation assets. These assets are expenditures incurred before technical feasibility and commercial viability is demonstrable. Estimates of resources for undeveloped or partially developed fields are subject to greater uncertainty over their future life than estimates of reserves for fields that are substantially developed and being depleted and are likely to contain estimates and judgements with a wide range of possibilities. These assets are considered for impairment under IFRS 6.
Once a field commences production, the amount of proved reserves will be subject to future revision once additional information becomes available through, for example, the drilling of additional wells or the observation of long-term reservoir performance under producing conditions. As those fields are further developed, new information may lead to revisions.
Assessment of reserves and resources are determined using estimates of oil and gas in place, recovery factors and future commodity prices, the latter having an impact on the total amount of recoverable reserves.
Where the Company has updated its estimated reserves and resources any required disclosure of the impact on the financial statements is provided in the following sections.
Estimation of oil and gas asset values (note 9 and 10)Estimation of the asset value of oil and gas assets is calculated from a number of inputs that require varying degrees of estimation. Principally oil and gas assets are valued by estimating the future cash flows based on a combination of reserves and resources, costs of appraisal, development and production, production profile, climate-related risks, pipeline reopening and future sales price and discounting those cash flows at an appropriate discount rate.
Future costs of appraisal, development and production are estimated taking into account the level of development required to produce those reserves and are based on past costs, experience and data from similar assets in the region, future petroleum prices and the planned development of the asset. However, actual costs may be different from those estimated.
Discount rate is assessed by the Company using various inputs from market data, external advisers and internal calculations. A post tax nominal discount rate of 14% (2022: 14%) derived from the Company’s weighted average cost of capital (WACC) is used when assessing the impairment testing of the Company’s oil assets at year-end. Risking factors are also used alongside the discount rate when the Company is assessing exploration and appraisal assets.
Estimation of future oil price and netback price The estimation of future oil price has a significant impact throughout the financial statements, primarily in relation to the estimation of the recoverable value of property, plant and equipment and intangible assets. It is also relevant to the assessment of ECL, going concern and the viability statement.
The Company’s estimate of average Brent oil price for future years is based on a range of publicly available market estimates and is summarised in the table below.
The netback price is used to value the Company’s revenue, trade receivables and its forecast cash flows used for impairment testing and viability. It is the aggregation of reference oil price average less transportation costs, handling costs and quality adjustments.
Effective from 1 September 2022, sales have been priced by the MNR under a new pricing formula based on the realised sales price for Kurdistan blend crude (‘KBT’) during the delivery month, rather than on dated Brent. The Company has not agreed on this new pricing formula and continued to invoice on Brent. The Company does not have direct visibility on the components of the netback price realised for its oil because sales are managed by the KRG, but the latest payments were based on the netback price provided by the KRG. Therefore, the export revenue from 1 September 2022 was recognised in accordance with IFRS15 using KBT pricing, resulting in the recognition of $13 million less of revenue.
The export pipeline closure in March 2023 has resulted in volumes sold in the local market starting in June 2023 on a cash and carry basis at lower realised oil prices than previously achieved through export.
A sensitivity analysis of netback price on producing asset values has been provided in note 10.
The Company has also taken the change into account in its assessment of impairment reversal and considered it appropriate not to reverse any previous impairments.
Estimation of the recoverable value of deferred receivables and trade receivables (note 11) As of 31 December 2023, the Company is owed six months of payments. Management has compared the carrying value of trade receivables with the present value of the estimated future cash flows based on the prevailing discount rate at the time sales made (14%) and a number of collection scenarios. The ECL is the weighted average of these scenarios and is recognised in the income statement. The weighting is applied based on expected repayment timing by considering the recovery of previous deferred receivables. The result of this assessment is an ECL provision of $14.5 million. Each 1% increase in discount rate would increase the ECL by $0.9 million. Sensitivity of the calculation to different scenarios has been provided in note 11.
Other estimates The following are the other estimates that the directors have made in the process of applying the Group and Company’s accounting policies and that have effect on the amounts recognised in the financial statements.
Decommissioning provision (note 15) Decommissioning provisions are calculated from a number of inputs such as costs to be incurred in removing production facilities and site restoration at the end of the producing life of each field which is considered as the mid-point of a range of cost estimation. These inputs are based on the Company’s best estimate of the expenditure required to settle the present obligation at the end of the period inflated at 2% (2022: 2%) and discounted at 4% (2022: 4%). 10% increase in cost estimates would increase the existing provision by c.$4 million and 1% increase in discount rate would decrease the existing provision by c.$3 million, the combined impact would be c.$1 million. The cash flows relating to the decommissioning and abandonment provisions are expected to occur between 2028 and 2036.
Taxation Under the terms of KRI PSC's, corporate income tax due is paid on behalf of the Company by the KRG from the KRG's own share of revenues, resulting in no corporate income tax payment required or expected to be made by the Company. It is not known at what rate tax is paid, but it is estimated that the current tax rate would be between 15% and 40%. If this was known it would result in a gross up of revenue with a corresponding debit entry to taxation expense with no net impact on the income statement or on cash. In addition, it would be necessary to assess whether any deferred tax asset or liability was required to be recognised.
The accounting policies adopted in preparation of these financial statements are consistent with those used in preparation of the annual financial statements for the year ended 31 December 2022, adjusted for transitional requirements where necessary, further explained under revenue and changes in accounting policies headings.
Revenue Revenue from contracts with customers is earned based on the entitlement mechanism under the terms of the relevant PSC and, overriding royalty income (‘ORRI’), which was earned on 4.5% of gross field revenue from the Tawke licence up until July 2022.
Under IFRS 15, entitlement revenue and ORRI is recognised when the control of the product is deemed to have passed to the customer, in exchange for the consideration amount determined by the terms of the contract. For exports the control passes to the customer when the oil enters the export pipe. For local sales, the control passes to the customer when the oil is delivered to the trucks.
Entitlement has two components: cost oil, which is the mechanism by which the Company recovers its costs incurred on an asset, and profit oil, which is the mechanism through which profits are shared between the Company, its partners and the KRG. The Company pays capacity building payments on profit oil entitlement earned on the Sarta and Taq Taq licences, which become due for payment once the Company has received the relevant proceeds. Profit oil revenue is always reported net of any capacity building payments that will become due.
The Company’s export oil sales made to the KRG are valued at a netback price which is explained further in significant accounting estimates and judgements. The Company’s local sales are valued at the price agreed with the local buyers.
The Company is not able to measure the tax that has been paid on its behalf and consequently has not been able to assess where revenue should be reported gross of implied income tax paid.
The Company’s revenue from other sources includes a non-cash royalty income which is recognised in the statement of comprehensive income in a manner consistent with entitlement mechanism.
Intangible assets Exploration and evaluation assets Oil and gas assets classified as exploration and evaluation assets are explained under Oil and Gas assets below.
Tawke RSA Intangible assets include the Receivable Settlement Agreement (‘RSA’) effective from 1 August 2017, which was entered into in exchange for trade receivables due from KRG for Taq Taq and Tawke past sales. The RSA was recognised at cost and is amortised on a units of production basis in line with the economic lives of the rights acquired.
Property, plant and equipment Producing and Development assets Oil and gas assets classified as producing and development assets are explained under Oil and Gas assets below.
Oil and gas assets Costs incurred prior to obtaining legal rights to explore are expensed to the statement of comprehensive income. Exploration, appraisal and development expenditure is accounted for under the successful efforts method. Under the successful efforts method only costs that relate directly to the discovery and development of specific oil and gas reserves are capitalised as exploration and evaluation assets within intangible assets so long as the activity is assessed to be de-risking the asset and the Company expects continued activity on the asset into the foreseeable future. Costs of activity that do not identify oil and gas reserves are expensed.
All licence acquisition costs, geological and geophysical costs, inventories and other direct costs of exploration, evaluation and development are capitalised as intangible assets or property, plant and equipment according to their nature. Intangible assets comprise costs relating to the exploration and evaluation of properties which the directors consider to be unevaluated until assessed as being 2P reserves and commercially viable.
Once assessed as being 2P reserves they are tested for impairment and transferred to property, plant and equipment as development assets. Where properties are appraised to have no commercial value, the associated costs are expensed as an impairment loss in the period in which the determination is made. Development assets are classified under producing assets following the commercial production commencement.
Development expenditure is accounted for in accordance with IAS 16 – Property, plant and equipment. Producing assets are depreciated once they are available for use and are depleted on a field-by-field basis using the unit of production method. The sum of carrying value and the estimated future development costs are divided by total barrels to provide a $/barrel unit depreciation cost. Changes to depreciation rates as a result of changes in forecast production and estimates of future development expenditure are reflected prospectively.
The estimated useful lives of property, plant and equipment and their residual values are reviewed on an annual basis and changes in useful lives are accounted for prospectively. The gain or loss arising on the disposal or retirement of an asset is determined as the difference between the sales proceeds and the carrying amount of the asset and is recognised in the statement of comprehensive income for the relevant period.
Where exploration licences are relinquished or exited for no consideration or costs incurred are neither de-risking nor adding value to the asset, the associated costs are expensed to the income statement.
Impairment testing of oil and gas assets is considered in the context of each cash generating unit. A cash generating unit is generally a licence, with the discounted value of the future cash flows of the CGU compared to the book value of the relevant assets and liabilities.
Subsequent costs The cost of replacing part of an item of property and equipment is recognised in the carrying amount of the item if it is probable that the future economic benefits embodied within the part will flow to the Company, and its cost can be measured reliably. The net book value of the replaced part is expensed. The costs of the day-to-day servicing and maintenance of property, plant and equipment are recognised in the statement of comprehensive income.
Discontinued operations A part of the Company’s operations is classified as a discontinued operation if the component has either been disposed of or is classified as held for sale and represents a separate major line of business or geographic area of operations, is part of a single coordinated plan to dispose of a separate major line of business or geographic area of operations, or is a subsidiary acquired exclusively with a view to resale. Discontinued operations are excluded from the net income/loss from continuing operations and are presented as a single amount as gain/loss from discontinued operations, in the consolidated statement of comprehensive income. When an operation is classified as a discontinued operation, the comparative consolidated statement of comprehensive income is restated and presented as if the operation had been classified as such from the start of the comparative year.
Right of use (RoU) assets / Lease liabilities The Company recognises a right to use asset and lease liability, depreciate the associated asset, re-measure and reduce the liability through lease payments unless the underlying leased asset is of low value and/or short term in nature. The Company uses the following judgements permitted by the standard: applying a single discount rate to a portfolio of leases with reasonably similar characteristics, exemption from recognition of right of use assets with a lease term of less than 12 months at the inception and using hindsight in determining the lease term where the contract contains options to extend or terminate the lease. Right-of-use assets are depreciated over the lifetime of the related lease contract. Lease liabilities were measured at the present value of the remaining lease payments, discounted using the lessee’s incremental borrowing rate and included within trade and other payables.
Drill rig contracts are service contracts where contractors provide the rig together with the services and the contracted personnel on a day-rate basis for the purpose of drilling exploration or development wells. The Company has no right of use of the rigs. The aggregate payments under drilling contracts are determined by the number of days required to drill each well and are capitalised as exploration or development assets as appropriate.
Financial assets and liabilities Classification The Company assesses the classification of its financial assets on initial recognition at amortised cost, fair value through other comprehensive income or fair value through profit and loss. The Company assesses the classification of its financial liabilities on initial recognition at either fair value through profit and loss or amortised cost.
Recognition and measurement Regular purchases and sales of financial assets are recognised at fair value on the trade-date – the date on which the Company commits to purchase or sell the asset. Trade and other receivables, trade and other payables, borrowings and deferred contingent consideration are subsequently carried at amortised cost using the effective interest method.
Trade and other receivables Trade receivables are amounts due from crude oil sales, sales of gas or services performed in the ordinary course of business. If payment is expected within one year or less, trade receivables are classified as current assets otherwise they are presented as non-current assets. Trade receivables are recognised initially at fair value and subsequently measured at amortised cost using the effective interest method, less provision for expected credit loss.
The Company’s assessment of expected credit loss model is explained below under financial assets.
Cash and cash equivalents In the consolidated balance sheet and consolidated statement of cash flows, cash and cash equivalents includes cash in hand, deposits held on call with banks, other short-term highly liquid investments which are assessed as cash and cash equivalents under IAS 7 and includes the Company’s share of cash held in joint operations.
Interest-bearing borrowings Borrowings are recognised initially at fair value, net of any discount in issuance and transaction costs incurred. Borrowings are subsequently carried at amortised cost; any difference between the proceeds (net of transaction costs) and the redemption value is recognised in the statement of comprehensive income over the period of the borrowings using the effective interest method.
Fees paid on the establishment of loan facilities are recognised as transaction costs of the loan.
Borrowings are presented as long or short-term based on the maturity of the respective borrowings in accordance with the loan or other agreement. Borrowings with maturities of less than twelve months are classified as short-term. Amounts are classified as long-term where maturity is greater than twelve months. Where no objective evidence of maturity exists, related amounts are classified as short-term.
Trade and other payables Trade and other payables are recognised initially at fair value. Subsequent to initial recognition they are measured at amortised cost using the effective interest method.
Offsetting Financial assets and liabilities are offset and the net amount reported in the balance sheet when there is a legally enforceable right to offset the recognised amounts and there is an intention to settle on a net basis or realise the asset and settle the liability simultaneously.
Provisions Provisions are recognised when the Company has a present obligation as a result of a past event, and it is probable that the Company will be required to settle that obligation. Provisions are measured at the Company’s best estimate of the expenditure required to settle the obligation at the balance sheet date and are discounted to present value where the effect is material. The unwinding of any discount is recognised as finance costs in the statement of comprehensive income.
Decommissioning Provision is made for the cost of decommissioning assets at the time when the obligation to decommission arises. Such provision represents the estimated discounted liability for costs which are expected to be incurred in removing production facilities and site restoration at the end of the producing life of each field. A corresponding cost is capitalised to property, plant and equipment and subsequently depreciated as part of the capital costs of the production facilities. Any change in the present value of the estimated expenditure attributable to changes in the estimates of the cash flow or the current estimate of the discount rate used are reflected as an adjustment to the provision and capitalised as part of the cost of the assets.
Impairment Exploration and evaluation assets Spend on exploration and evaluation assets is capitalised in accordance with IFRS 6. The carrying amounts of the Company’s exploration and evaluation assets are reviewed at each reporting date to determine whether there is any indication of impairment under IFRS 6. Impairment assessment of exploration and evaluation assets is considered in the context of each cash generating unit, which is generally represented by relevant the licence.
Producing and Development assets The carrying amounts of the Company’s producing and development assets are reviewed at each reporting date to determine whether there is any indication of impairment or reversal of impairment. If any such indication exists, then the asset’s recoverable amount is estimated. The recoverable amount of an asset or cash generating unit is the greater of its value in use and its fair value less costs of disposal. For value in use, the estimated future cash flows arising from the Company’s future plans for the asset are discounted to their present value using a nominal post tax discount rate that reflects market assessments of the time value of money and the risks specific to the asset. For fair value less costs of disposal, an estimation is made of the fair value of consideration that would be received to sell an asset less associated selling costs (which are assumed to be immaterial). Assets are grouped together into the smallest group of assets that generates cash inflows from continuing use that are largely independent of the cash inflows of other assets or groups of assets (cash generating unit).
The estimated recoverable amount is then compared to the carrying value of the asset. Where the estimated recoverable amount is materially lower than the carrying value of the asset an impairment loss is recognised. Non-financial assets that suffered impairment are reviewed for possible reversal of the impairment at each reporting date.
Property, plant and equipment and intangible assets Impairment testing of oil and gas assets is explained above. When impairment indicators exist for other non-financial assets, impairment testing is performed based on the higher of value in use and fair value less costs of disposal. The Company assets' recoverable amount is determined by fair value less costs of disposal.
Financial assets Impairment of financial assets is assessed under IFRS 9 with a forward-looking expected credit loss (‘ECL’) model. The standard requires the Company to book an allowance for ECL for its financial assets. The Company has assessed its trade receivables as at 31 December 2023 for ECL. Further explanation is provided in significant accounting judgements and estimates.
Equity Share capital Amounts subscribed for share capital at nominal value. Ordinary shares are classified as equity.
When share capital recognised as equity is repurchased, the amount of the consideration paid, which includes directly attributable costs, is net of any tax effects and is recognised as a deduction in equity. Repurchased shares are classified as treasury shares and are presented as a deduction from total equity. When treasury shares are subsequently sold or reissued, the amount received is recognised as an increase in equity and the resulting surplus or deficit of the transaction is transferred to/from retained earnings.
Share premium Amounts subscribed for share capital in excess of nominal value.
Accumulated loss Cumulative net losses recognised in the statement of comprehensive income net of amounts recognised directly in equity.
Dividend Liability to pay a dividend is recognised based on the declared timetable. A corresponding amount is recognised directly in equity.
Employee benefits Short-term benefits Short-term employee benefit obligations are expensed to the statement of comprehensive income as the related service is provided. A liability is recognised for the amount expected to be paid under short-term cash bonus or profit-sharing plans if the Company has a present legal or constructive obligation to pay this amount as a result of past service provided by the employee and the obligation can be estimated reliably.
Share-based payments The Company operates equity-settled share-based compensation plans. The expense required in accordance with IFRS 2 is recognised in the statement of comprehensive income over the vesting period of the award and partially capitalised as oil and gas assets in line with the hours incurred by the employees. The expense is determined by reference to option pricing models, principally Monte Carlo and adjusted Black-Scholes models.
At each balance sheet date, the Company revises its estimate of the number of options that are expected to become exercisable. Any revision to the original estimates is reflected in the statement of comprehensive income with a corresponding adjustment to equity immediately to the extent it relates to past service and the remainder over the rest of the vesting period.
Finance income and finance costs Finance income comprises interest income on cash invested, foreign currency gains and the unwind of discount on any assets held at amortised cost. Interest income is recognised as it accrues, using the effective interest method.
Finance expense comprises interest expense on borrowings, foreign currency losses and discount unwind on any liabilities held at amortised cost. Borrowing costs directly attributable to the acquisition of a qualifying asset as part of the cost of that asset are capitalised over the respective assets.
Taxation Under the terms of the KRI PSCs, the Company is not required to pay any cash corporate income taxes as explained in significant accounting judgements and estimates. Current tax expense is incurred on profits of service companies.
Segmental reporting IFRS 8 requires the Company to disclose information about its business segments and the geographic areas in which it operates. It requires identification of business segments on the basis of internal reports that are regularly reviewed by the CEO, the chief operating decision maker, in order to allocate resources to the segment and assess its performance.
Related parties Parties are related if one party has the ability, directly or indirectly, to control the other party or exercise significant influence over the party in making financial or operational decisions. Parties are also related if they are subject to common control. Transactions between related parties are transfers of resources, services or obligations, regardless of whether a price is charged and are disclosed separately within the notes to the consolidated financial information.
New standards The following new accounting standards, amendments to existing standards and interpretations are effective on 1 January 2023. Amendments to IAS 12 Income taxes: International Tax Reform – Pillar Two Model Rules (issued on 23 May 2023), Amendments to IFRS 17 Insurance contracts: Initial Application of IFRS 17 and IFRS 9 – Comparative Information (issued on 9 December 2021), Amendments to IAS 12 Income Taxes: Deferred Tax related to Assets and Liabilities arising from a Single Transaction (issued on 7 May 2021), Amendments to IAS 1 Presentation of Financial Statements and IFRS Practice Statement 2: Disclosure of Accounting policies (issued on 12 February 2021), Amendments to IAS 8 Accounting policies, Changes in Accounting Estimates and Errors: Definition of Accounting Estimates (issued on 12 February 2021), IFRS 17 Insurance Contracts (issued on 18 May 2017). These standards did not have a material impact on the Company’s results or financial statements disclosures in the current reporting period except Amendments to IAS 1 Presentation of Financial Statements and IFRS Practice Statement 2: Disclosure of Accounting policies (issued on 12 February 2021). The Company has adopted the amendments to IAS 1 for the first time in the current year as to disclose material accounting policies.
The following new accounting standards, amendments to existing standards and interpretations have been issued but are not yet effective and/or have not yet been endorsed by the EU: Amendments to IAS 21 The Effects of Changes in Foreign Exchange Rates: Lack of Exchangeability (issued on 15 August 2023), Amendments to IAS 7 Statement of Cash Flows and IFRS 7 Financial Instruments: Disclosures: Supplier Finance Arrangements (issued on 25 May 2023), Amendments to IAS 1 Presentation of Financial Statements: Classification of Liabilities as Current or Noncurrent (issued on 23 January 2020); Classification of Liabilities as Current or Noncurrent - Deferral of Effective Date (issued on 15 July 2020); and Non-current Liabilities with Covenants (issued on 31 October 2022), Amendments to IFRS 16 Leases: Lease Liability in a Sale and Leaseback (issued on 22 September 2022). Nothing has been early adopted, and these standards are not expected to have a material impact on the Company’s results or financials statement disclosures in the periods they become effective.
2. Segmental information
The Company has two reportable business segments: Production and Pre-production. Capital allocation decisions for the production segment are considered in the context of the cash flows expected from the production and sale of crude oil. The production segment is comprised of the producing fields on the Tawke PSC (Tawke and Peshkabir fields) and the Taq Taq PSC which are located in the KRI and make export sales to the KRG and local sales to the local buyers. The pre-production segment is comprised of exploration activity, principally located in Somaliland and Morocco. ‘Other’ includes corporate assets, liabilities and costs, elimination of intercompany receivables and intercompany payables, which are non-segment items.
For the year ended 31 December 2023
Sarta PSC figures have been disclosed as discontinued operation following the PSC termination in the year (see note 7).
Total assets and liabilities in the other segment are predominantly cash and debt balances.
For the year ended 31 December 2022
Revenue from contracts with customers includes $94.5 million arising from the ORRI and $34.7 million in relation to the suspended ORRI.
Total assets and liabilities in the other segment are predominantly cash and debt balances.
5. Finance expense and income
Bond interest payable is the cash interest cost of the Company’s bond debt. Other finance expense (non-cash) primarily relates to the discount unwind on the bond and the asset retirement obligation provision.
6. Income tax expense
Current tax expense is incurred on profits of service companies. Under the terms of the KRI PSCs, the Company is not required to pay any cash corporate income taxes as explained in note 1.
7. Discontinued operations
Sarta PSC was terminated on 1 December 2023. The results of the discontinued operations, which have been included in the loss for the year, were as follows:
1 Other operating costs relate to costs incurred after production ceased in March 2023, following the pipeline closure and costs incurred in relation to exiting the PSC.
8. (Loss) / Earnings per share
Basic Basic loss per share is calculated by dividing the loss attributable to owners of the parent by the weighted average number of shares in issue during the year.
1 Excluding shares held as treasury shares
Diluted The Company purchases shares in the market to satisfy share plan requirements so diluted earnings per share is adjusted for performance shares, restricted shares, share options and deferred bonus plans not included in the calculation of basic earnings per share. Because the Company reported a loss for the year ended 31 December 2023 and 31 December 2022, the performance shares, restricted shares and share options are anti-dilutive and therefore diluted LPS is the same as basic LPS:
1 Excluding shares held as treasury shares
Basic (LPS) / EPS excluding impairments Basic (LPS) / EPS excluding impairment is loss and total comprehensive expense adjusted for the add back of net impairment/write-off of oil and gas assets and net ECL/reversal of ECL of receivables divided by weighted average number of ordinary shares.
1 Excluding shares held as treasury shares
9. Intangible assets
10. Property, plant and equipment
1 Other line includes non-cash asset retirement obligation provision and share-based payment costs.
Sarta PSC was terminated on 1 December 2023 and this resulted in a reduction in the carrying value to nil and write-off of assets of $18.7 million as of 31 December 2023. Further explanation is provided in note 1.
The sensitivities below provide an indicative impact on net asset value of a change in netback price, discount rate or production, assuming no change to any other inputs.
11. Trade and other receivables
At 31 December 2023, the Company is owed six months of payments (31 December 2022: five months).
Recovery of the carrying value of the receivable All trade receivables relate to export sales as the local sales are on a cash and carry basis. As explained in note 1, the booked nominal receivable value of $107.4 million has been recognised based on KBT due to IFRS 15 requirements and it would be $13 million higher under Brent pricing mechanism. The Company expects to recover the full value of receivables owed from the KRG under Brent pricing mechanism, but the terms of recovery are not determined yet. An explanation of the assumptions and estimates in assessing the net present value of the deferred receivables are provided in note 1.
Sensitivities/Scenarios The table below shows the sensitivity of the net present value of the overdue trade receivables to start and timing of repayment that the company has used during its ECL assessment. Each scenario has been weighted in accordance with the management’s expected outcome.
Cash is primarily invested with major international financial institutions, in US Treasury bills or liquidity funds. $0.6 million (2022: $0.1 million) of cash is restricted.
13. Trade and other payables
Current payables are predominantly short-term in nature and there is minimal difference between contractual cash flows related to the financial liabilities and their carrying amount. For non-current payables, liabilities are recognised at discounted fair value using the effective interest rate. Lease liabilities are included in other payables, further explanation is provided in note 20.
14. Deferred income
15. Provisions
Provisions cover expected decommissioning, abandonment and exit costs arising from the Company’s assets which are further explained in note 1. Reversals are related to Sarta and Qara Dagh licences as a result of the termination of the PSCs.
16. Interest bearing loans and net cash
1 Net other changes are free cash flow plus purchase of own shares
At 31 December 2023, the fair value of the $248 million (2022: $274 million) of bonds held by third parties is $236.5 million (2022: $257.6 million).
The Company repurchased $26 million of its existing $274 million senior unsecured bond at a price equal to 93.5% of the nominal amount.
The bonds maturing in 2025 have two financial covenant maintenance tests:
17. Financial Risk Management
Credit risk Credit risk arises from cash and cash equivalents, trade and other receivables and other assets. The carrying amount of financial assets represents the maximum credit exposure. The maximum credit exposure to credit risk at 31 December was:
All trade receivables are owed by the KRG. Cash is deposited with major international financial institutions and the US treasury that are assessed as appropriate based on, among other things, sovereign risk, CDS pricing and credit rating.
Liquidity risk The Company is committed to ensuring it has sufficient liquidity to meet its payables as they fall due. At 31 December 2023 the Company had cash and cash equivalents of $363.4 million (2022: $494.6 million).
Oil price risk The Company’s export revenues are calculated from netback price and local sales revenues are from a price established on an arms length basis as further explained in note 1, and a $5/bbl change in average price across local and export sales would result in a (loss) / profit before tax change of circa $10 million.
Currency risk Other than head office costs, substantially all of the Company’s transactions are denominated and/or reported in US dollars. The exposure to currency risk is therefore immaterial and accordingly no sensitivity analysis has been presented.
Interest rate risk The Company reported borrowings of $243.7 million (2022: $266.6 million) in the form of a bond maturing in October 2025, with fixed coupon interest payable of 9.25% on the nominal value of $248.0 million (2022: $274 million). Although interest is fixed on existing debts, whenever the Company wishes to borrow new debt or refinance existing debt, it will be exposed to interest rate risk. A 1% increase in interest rate payable on a balance similar to the existing debts of the Company would result in an additional cost of circa $2.5 million per annum.
Capital management The Company manages its capital to ensure that it remains sufficiently funded to support its business strategy and maximise shareholder value. The Company’s short-term funding needs are met principally from the cash flows generated from its operations and available cash of $363.4 million (2022: $494.6 million).
Financial instruments All financial assets and liabilities are measured at amortised cost. Due to their short-term nature except interest bearing loans and non-current portion of trade receivables, the carrying value of these financial instruments approximates their fair value. Their carrying values are as follows:
18. Share capital
1 Ordinary shares include 845,335 (2022: 845,335) treasury shares. Share capital includes 2,224,090 (2022: 629,769) of trust shares.
There have been no changes to the authorised share capital since it was determined to be 10,000,000,000 ordinary shares of £0.10 per share.
19. Dividends
20. Right-of-use assets / Lease liabilities
The Company’s right-of-use assets are related to the offices and included within property, plant and equipment.
The weighted average lessee’s incremental borrowing rate applied to the lease liabilities. The lease terms vary from one to five years.
Included within lease liabilities of $1.1 million (2022: $4.1 million) are non-current lease liabilities of $0.5 million (2022: $1.2 million). The identified leases have no significant impact on the Company`s financing, bond covenants or dividend policy. The Company does not have any residual value guarantees. The contractual maturities of the Company’s lease liabilities are as follows:
21. Share based payments
The Company has five share-based payment plans under which awards are currently outstanding: performance share plan (2011), performance share plan (2021), restricted share plan (2011), share option plan (2011), and deferred bonus plan (2021). The main features of these share plans are set out below.
In 2023, awards were made under the performance share plan only. The numbers of outstanding shares as at 31 December 2023 are set out below:
The exercise price for share options outstanding at the end of the period is 1,046.00p.
Fair value of awards granted during the year has been measured by use of the Monte-Carlo pricing model. The model takes into account assumptions regarding expected volatility, expected dividends and expected time to exercise. Expected volatility was also analysed with the historical volatility of FTSE-listed oil and gas producers over the three years prior to the date of grant. The expected dividend assumption was set at 0%. The risk-free interest rate incorporated into the model is based on the term structure of UK Government zero coupon bonds. The inputs into the fair value calculation for PSP awards granted in 2023 and fair values per share using the model were as follows:
The weighted average fair value for PSP awards (without condition) granted in 2023 is 121p and for PSP awards granted in 2023 is 80p.
The inputs into the fair value calculation for PSP awards granted in 2022 and fair values per share using the model were as follows:
The weighted average fair value for PSP awards (without condition) granted in 2022 is 164p and for PSP awards granted in 2022 is 124p.
Total share-based payment charge for the year was $3.7 million (2022: $4.1 million). 22. Capital commitments
Under the terms of its production sharing contracts (‘PSC’s) and joint operating agreements (‘JOA’s), the Company has certain commitments that are generally defined by activity rather than spend. The Company’s capital programme for the next few years is explained in the operating review and is in excess of the activity required by its PSCs and JOAs.
23. Related parties
The directors have identified related parties of the Company under IAS 24 as being: the shareholders; members of the Board; and members of the executive committee, together with the families and companies, associates, investments and associates controlled by or affiliated with each of them. The compensation of key management personnel including the directors of the Company is as follows:
There have been no changes in related parties since last year and no related party transactions that had a material effect on financial position or performance in the year.
24. Events occurring after the reporting period
The London-seated international arbitration hearing (factual and expert evidence) which includes Genel’s claim for substantial compensation from the KRG following the termination of the Miran and Bina Bawi PSCs ended on 1 March 2024. The timing of the result is uncertain but is expected by the end of 2024 following the Parties making closing written submissions in April 2024 and reply written submissions in May 2024.
25. Subsidiaries and joint arrangements
The Company has four joint arrangements in relation to its producing assets Taq Taq, Tawke, Sarta and pre-production asset Qara Dagh PSC. The Company holds 44% working interest in Taq Taq PSC and owns 55% of Taq Taq Operating Company Limited. The Company holds 25% working interest in Tawke PSC which is operated by DNO ASA.
For the period ended 31 December 2023 the principal subsidiaries of the Company were the following:
1 Registered office is 7 Boulevard Latrille Cocody, 25 B.P. 945 Abidjan 25, Cote d'Ivoire 2 Registered office is 6 Hope Street, Castletown, IM9 1AS, Isle of Man 3 Registered office is Fifth Floor, 36 Broadway, Victoria, London, SW1H 0BH, United Kingdom 4 Registered office is 26 New Street, St Helier, JE2 3RA, Jersey 5 Registered office is PO Box 1338, Maico Building, The Valley, Anguilla 6 Registered office is Vadi Istanbul 1 B Block, Ayazaga Mahallesi, Azerbaycan Caddesi, No:3 Floor: 18, 34396, Sariyer, Istanbul, Turkey 7 Registered office is Kingston Chambers, P.O. Box 173, Road Town, Tortola, VG1110, British Virgin Islands
26. Annual report
Copies of the 2023 annual report will be despatched to shareholders in April 2024 and will also be available from the Company’s registered office at 26 New Street, St Helier, Jersey, JE2 3RA and at the Company’s website – www.genelenergy.com.
27. Statutory financial statements
The financial information for the year ended 31 December 2023 contained in this preliminary announcement has been audited and was approved by the Board on 25 March 2024. The financial information in this statement does not constitute the Company's statutory financial statements for the years ended 31 December 2023 or 2022. The financial information for 2023 and 2022 is derived from the statutory financial statements for 2022, which have been delivered to the Registrar of Companies, and 2023, which will be delivered to the Registrar of Companies and issued to shareholders in April 2024. The auditors have reported on the 2023 and 2022 financial statements; their report was unqualified and did not include a reference to any matters to which the auditors drew attention by way of emphasis without qualifying their report. The statutory financial statements for 2023 are prepared in accordance with International Financial Reporting Standards (IFRS) as adopted for use in the European Union. The accounting policies (that comply with IFRS) used by Genel Energy plc are consistent with those set out in the 2022 annual report.
Dissemination of a Regulatory Announcement that contains inside information in accordance with the Market Abuse Regulation (MAR), transmitted by EQS Group. The issuer is solely responsible for the content of this announcement. | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ISIN: | JE00B55Q3P39, NO0010894330 |
| Category Code: | FR |
| TIDM: | GENL |
| LEI Code: | 549300IVCJDWC3LR8F94 |
| Sequence No.: | 311832 |
| EQS News ID: | 1866825 |
| End of Announcement | EQS News Service |
| |
