CASP Caspian Sunrise Plc

                               

Caspian Sunrise PLC

("Caspian Sunrise" or the "Company")

Annual Report and Financial Statements for the Year Ended 31 December 2023

Caspian Sunrise, the Central Asian oil and gas company with a focus on Kazakhstan, is pleased to announce its audited final results for the year ended 31 December 2023. The Company anticipates that the suspension of the Company's shares will be lifted today.

 

2023 Financial highlights

·      Total revenues $36.7 million  (Restated 2022: $40.9 million)

o  Oil sales revenues $21.6 million  (2022: $39.2 million)

o  Oil trading revenues $10.3 million (2022: nil)

o  Oil services revenues $4.1 million. (Restated 2022: $1.6 million)

·      EBITDA $18.1 million (Restated 2022;  $15.7 million)

·      Operating profit $15.5 million (Restated 2022:  $12.9 million)

·      Profit before tax $14.8 million (2022:  $12.3 million)

·      Profit after tax $11.1 million (Restated 2022:  $10.0 million)

·      Gross assets $134.9 million (2022:  $117.7 million)

 

2023 Operational highlights

·      Production volumes 665,114 barrels (bbls) (2022: 792,284 bbls) 

·      Commencement of oil trading

·      Continuing workover programme at MJF structure

·      Horizontal drilling approach at Soviet era South Yelemes wells

·      Deep Well 803 spudded - the third deep well on the Yelemes Deep structure

·      Two new deep wells completed at Block 8

·      First commercial drilling contract signed for the Caspian Explorer

·      BNG shallow structure reserves at 31 December 2023:

o  P1 13.6 million barrels (mmbls); (2022 14.3 mmbls)

o  P2 24.8 mmbls (2022:  25.5 mmbls)

2024 Highlights to date

·      Independent shareholder approval of the acquisition of the West Shalva Contract Area

·      Shallow Well 155 spudded in February 2024 and drilled to 2,400 meters now testing a 16 meter interval

·      Deep Well 803 drilled to a depth of 3,420 meters now testing a 15 meter interval

·      Conditional agreement to sell the MJF and South Yelemes structures for $83 million

·      Reserves in the immediate vicinity of the drainage areas around Deep Wells A5, A6 & A7 independently assessed at approximately

o  C1    49.0 million barrels

o  C2    28.9 million barrels

·      Commencement of the Caspian Explorer ENI charter

Expected future events

 

Q3 2024

·      Licence renewal at Block 8

·      Caspian Explorer charter completed

·      Confirmation of C1 style reserves for the Yelemes Deep structure at BNG

·      Award of licence extension for BNG's Airshagyl & Yelemes Deep structures

·      Production commences from Block 8 from existing wells

·      Testing new well at Block 8

·      First well drilled at West Shalva

·      Acquisition of a G70 rig

Q4 2024

·      First mining acquisition

·      Completion of the West Shalva acquisition

·      Completion of the Block 8 acquisition

 

CHAIRMAN'S STATEMENT

Introduction

Over the past few years, Caspian Sunrise has evolved from essentially one commercial asset with just a single producing structure, to now being a diversified and profitable natural resources group, with significant income flowing from a range of activities and with additional near term opportunities for further successful growth and diversification. The Group also has strong asset backing.

This transformation has been achieved in the face of some significant hurdles, including the oil price falling to $6 per barrel during the Covid-19 pandemic, assessed historic costs of $32 million to be repaid over a 10 year period, and the financial and operational impact of Russian sanctions, which for much of the past two years has ruled out international sales and significantly added to operational complexity. Notably, this transition was achieved against the backdrop of the financial constraints of a demanding work programme at our flagship BNG asset. It has also been implemented without undue dilution to shareholders.

Funding for the transition came principally from the sale of oil produced at BNG's MJF structure, from loans from our largest shareholding group and by running creditors and short term debt at higher levels than usual.

The Group now:

·     owns (or is in the process of acquiring) three active oilfields with production expected from all three before the end of the year;

·      is building a significant reserve base with further additions expected in the next 3 months;

·     owns sufficient equipment and rigs to drill four wells at the same time and is also able to drill for third parties to farm into new oilfields;

·      owns the only drilling vessel of its type capable of exploring the shallow reaches of the highly prospective northern Caspian Sea, which the Directors estimate would have a replacement cost of approximately $300 million and would take up to 3 years to become operational; and

·      holds a coveted oil trading licence under the new rules introduced in 2023.

 

The financial rewards of these achievements are expected to become more apparent during the second half of the current financial year following:

·      increasing production from BNG, Block 8 & West Shalva;

·    if completed on the terms set out in the exclusivity agreement the proposed sale of the MJF and South Yelemes structures at the BNG Contract Area would result in $83 million gross proceeds;

·      reduced operational expenditure following the completion of the current work programme commitments at BNG;

·      the start of production revenues from Block 8 and West Shalva;

·      continued oil trading profit; and

·      receipt of income from the first commercial drilling charter for the Caspian Explorer under the Group's ownership.

 

Operational overview

BNG

At BNG our prime focus was to complete the work programme obligations required to renew the licence for the Airshagyl & Yelemes Deep structures from July 2024, being principally Well 155 on the MJF structure and Deep Well 803 on the Yelemes Deep structure.

We currently have a combined licence for the Airshagyl and Yelemes Deep structures which we intend to extend for a two year period before applying for separate 25 year licences for both structures. We already have separate production licences at both the MJF and South Yelemes structures running until 2043 and 2046 respectively.

The licence upgrade process requires independent assessments of the reserves under the former Soviet classification system operated by the Geological Committee of the Republic of Kazakhstan as required under the Kazakh reserve reporting rules at both the Airshagyl and Yelemes Deep structures based on the information gathered from the wells drilled on each.

In June 2024 we announced that SciRes, an independent Kazakh consultancy, had assessed the C1 reserves in the immediate vicinity of the Deep Wells A5, A6 & A7 on the Airshagyl structure as 6.809 million tonnes or approximately 49.0 million barrels and C2 reserves on the same basis as 4.009 million tonnes or approximately 28.9 million barrels.

A similar exercise is underway on the Yelemes Deep structure, the second deep structure on the BNG Contract Area, where to date three wells have been drilled. The reserve estimate requires the completion of the current work at Deep Well 803 and is therefore expected to be available in Q3 2024.

To maximise the revenues from the MJF structure to fund the development of the Group we pushed the original wells hard over prolonged periods with the result that they are no longer as productive as they could have been if our priority had been to maximise their useful lives.

The MJF structure is clearly a maturing structure with higher levels of water content than ideal and it is inevitable that we will find it harder to maintain production levels from the earlier wells drilled on the structure. Drilling to date to return the previously best performing Wells 141 and 142 to meaningful production has yet to work.

On the positive side, we are becoming more comfortable with the use of horizontal drilling techniques which can significantly increase production volumes. However, it is clear that horizontal drilling is far more effective in new wells, such as Well 155, rather than older wells such as 141 & 142. At South Yelemes we completed horizontal side-tracks at Wells 805 and 806 from depths between approximately 2,200 and 2,300 meters.

Production levels from the BNG shallow structures fluctuated during the period under review and subsequently to a greater degree than in previous years as wells came in and out of production.  Total production for 2023 was 665,114 bbls which equates to 1,822 bopd (2022: 792,284 bbls & 2,171bopd).

Well 155 on the MJF structure was spudded in Q1 2024 and drilled to a depth of 2,400 meters. Testing of a 16 meter interval commenced in June 2024 with initial flow rates between 900 and 1,000 bopd. Production rates at Well 155 have since been reduced to approximately 700 bopd to optimise the life of the well.

Deep Well 803 was spudded in Q4 2023 with a planned total depth of 4,200 meters with a primary target at a depth of 3,950 meters and a secondary target at a depth of 4,200 meters. Oil has been detected over a 60 meter interval between 3,360 meters and 3,420 meters, above the expected targets and also above the main salt layer. Testing of a 15 meter interval commenced in July 2024.

Total production at the date of this report, before any contribution from Well 803, is approximately 2,300 bopd.

Block 8

In 2023 in anticipation of the completion of the acquisition of the Block 8 Contract Area, details of which are set out under the Corporate Events section below, we drilled two new deep wells to depths of 3,922 and 3,408 meters. These wells cannot be tested until the licence at Block 8 is renewed.

Once the licence is renewed our intention is now to use our G20 workover rig to test these two new wells.

3A Best

There was no operational activity at 3A Best during the period under review or subsequently.

Further information on the BNG, Block 8, and 3A Best Contract Areas together with the West Shalva Contract Area is set out below under the section entitled Our Assets.

 

 

 

Caspian Technical Services (CTS)

All the Group's onshore drilling is conducted via our 100% owned drilling subsidiary CTS, which also drills for third parties and currently has the capacity to drill four wells simultaneously using its own rigs and approximately 150 specialist contractors.

CTS owns 4 rigs, being one G50, two G40s, and a G20 workover rig, with the number indicating the maximum drill string weight the rig can support. Negotiations to acquire a G70 rig, which will allow future faster drilling of deep wells, are at an advanced stage.

Caspian Explorer

During the period under review and subsequently, significant effort has been expended on preparing the Caspian Explorer for its first commercial drilling contract under the Group's ownership.

In February 2023 we announced a two well charter for a consortium in which  Eni S.p,A, the Italian multinational energy company (ENI) is the leading member. Contracts for the first of the two wells are in place and the first charter commenced in July 2024. As the contract specifies day rates rather than a fixed amount for the use of the Caspian Explorer it will not be until drilling is completed that the total revenue will be known.  However, we expect to receive at least a further $10 million in the next few months in addition to the upfront payments already received.

We are also in discussions to charter the Caspian Explorer in 2025 to a different consortium, with 2026 identified should the ENI led consortium exercise their option for a second well.

Oil Trading

Being principally a financial function our introduction into oil trading is covered under the Financial Review below.

Corporate activities

BNG

In March 2024 we reported early stage discussions with a number of parties, which could result in a partial or complete sale of our interest in the BNG Contract Area. Our belief is that this heightened level of corporate interest in the BNG Contract Area reflects a combination of the relative scarcity of such assets and also the changes to the Kazakh oil trading regulations, which now require production to qualify for a trading licence.

In May 2024 we granted Absolute Resources LLP, a Kazakh registered entity, a 90 day exclusivity period to complete their due diligence on a proposed $83 million acquisition of the MJF and South Yelemes shallow structures on the BNG Contract Area.

We remain proud owners of the BNG Contract Area and have not initiated these discussions. However, accepting that there is a price for any of our assets at which shareholders would be better served by selling, we have a duty to listen and if appropriate act. We believe that realising $83 million to use on other Group assets would enhance shareholder value over the medium / longer term.

If progressed the sale of the MJF and South Yelemes structures would require the approval of Caspian Sunrise shareholders and the customary regulatory approvals in Kazakhstan and the UAE.

To date, in aggregate, approaching $200 million has been spent on the BNG Contract Area of which the Group has spent approximately $120 million, most of which was spent on the deep structures. Any corporate activity in respect of the deep structures at the BNG Contract Area would need to reflect both the gross investment made to date and the Contract Area's future prospects as evidenced by expected future production levels and reserves.

Block 8

In September 2023 we exercised the option to acquire the Block 8 Contract Area, which was first announced in September 2022.

On renewal of the licence, which is a condition of the acquisition, completion of the acquisition will be dependent on the customary approvals from the Kazakh authorities and the re-registration of ownership in the UAE.

Under the terms of the Block 8 Acquisition Agreement there is no significant up-front cash payment or issue of shares. Virtually all the purchase consideration is to be satisfied in cash via a royalty of $5 per barrel from oil produced from Block 8 once owned by the Group. The maximum purchase price is capped at $60 million.

The resumption of production at Block 8 will trigger the commencement of the repayment of the $3.1 million loan advanced to allow the 2023 drilling work at Block 8 to be completed. For further details see Note 16.

We believe Block 8 represents, in addition to the deep structures at BNG,  a second potentially transformative asset in that either or both could enjoy the same geological characteristics of the nearby world class Tengiz and Kashagan assets.

West Shalva

In April 2024 independent shareholders approved the acquisition of the West Shalva Contract Area for an initial consideration of $5 million to be satisfied by the issue of 99,206,349 shares to be issued at 4p per share.  On first oil an additional $5 million becomes payable by the issue of a further 99,206,349 shares, again to be issued at 4p per share. Additionally, the first $5 million of revenue derived from the sale of West Shalva oil once under the Group's ownership is payable in cash to the vendor in which case the maximum total consideration would be $15 million.

West Shalva is expected to be a far easier oilfield from which to produce oil than either BNG or Block 8.  It does not have the salt layer present at both BNG and Block 8, beneath which the exceptional temperatures and pressures have made drilling difficult. Conversely, it does not have the same potential to become a world class asset.

It is better located for access and to deliver oil being much closer to refineries than either BNG or Block 8. It is also approximately 600 km further south than BNG and Block 8 thereby enjoying a better climate, which should result in fewer weather related delays than we encounter at BNG and are likely to encounter at Block 8.

More strategically, owning West Shalva makes it easier to consider selling all or part of BNG without the need to have rigs idle.

3A Best

The 3A Best licence expired some years ago and there are overdue social obligations to pay to be in a position to apply to renew the licence. However, we believe the complexity of the situation set out below is the reason why the Kazakh authorities have not sought to put the licence back into a tender process and that in time it will be renewed.

The 3A Best Contract Area surrounds and goes beneath the established shallow Dunga Contract Area, which is believed to have produced at rates up to 15,000 bopd. When we acquired our interest in 3A Best Dunga was owned by Maersk, the Danish conglomerate, who then sold it to Total Energies, the French energy company. KazMunaiGas, the Kazakh state oil company is now the owner.

Our interest in the 3A Best Contract Area was for accounting purposes fully written down several years ago. In 2021 we entered into an agreement to sell the majority of our interest in 3A Best conditional on the licence renewal but the delays involved resulted in that agreement falling away. Now the ownership of Dunga has been resolved we cpcan decide how best to proceed at 3A Best.

Caspian Explorer

Given its unique nature and the resurrection of exploration activity in the shallow northern Caspian Sea, it was not a surprise to receive interest from potential buyers at sums vastly greater than the $1.7 million that the Caspian Explorer is carried at in these financial statements.

In June 2023 we announced the proposed sale of a 50% interest in the UAE registered company that holds a 100% interest in the Kazakh entity that in turn owns the Caspian Explorer at a sum that valued our 100% interest at $45 million. That proposed transaction did not complete as the prospective purchasers did not make the agreed payments citing a failure to obtain the required Kazakh exchange control approvals.

As with BNG, the Group is not looking to sell the Caspian Explorer as we recognise its true potential. However, as noted above, we are duty bound to consider meaningful offers. Our preference would be to use our ownership of the Caspian Explorer as an entry point to join consortia to develop the hugely prospective offshore blocks in the shallow northern Caspian Sea now being prepared for exploration.

CTS

Our investment in CTS with its ability to drill several deep wells at the same time has led to early stage discussions for the Group to farm into an existing asset in return for CTS drilling wells to help that third party meet existing work programme obligations that may otherwise be missed.

Mining

For some time, it has been our stated intention to add mining investments to the Group's portfolio in recognition that a key strength of the Group is the identification, assessment and negotiation of asset acquisitions in Kazakhstan, which in addition to being a leading world producer of oil is also home to vast mineral resources.

An asset has been identified and we are in the evaluation stage with the intention, if what we believe is confirmed under an internal and external due diligence process, to seek to conclude its acquisition later this financial year.

Unlike early stage oil exploration similar mining ventures typically require far less investment and in the case of the project we are reviewing could produce income from day one. An investment in a mining project could also provide an opportunity for an expansion of our commodity trading activities, which to date have been limited to oil.

Kazakhstan

While in recent times Kazakhstan has been out of favour with some international investors, others - notably Chinese investors - have increased their interest in the country and its assets.

Kazakhstan is home to vast oil, gas and mineral reserves which will continue to attract international investment. The Kazakh economy is the strongest in Central Asia and is thriving principally based on high levels of demand for its natural resources.

Further details on the country and its assets are contained in the Kazakhstan section set out later in these financial statements.

Dilution and related party transactions

This Chairman's Statement provides an opportunity to set out some facts, which I believe to be relevant but seem not to be universally understood or appreciated.

Dilution

The Group has only issued shares specifically to raise cash on two occasions. The first being at the IPO in 2007 when we raised approximately $78 million and again in 2020 when we raised approximately $1.3 million in response to the impact of the domestic oil price falling to a Covid induced $6 per barrel.

At times over the past 18 years the Group has run short of cash and turned to the only realistic lender, being the Oraziman family. From time to time these amounts have been converted to shares but always with the prior approval of the independent directors as advised by the Group's Nominated Adviser and under the rules of the UK Takeover Panel and most importantly also approved in advance by independent shareholders. These share issues once approved have also always been at a premium to the prevailing share price. 

Without this funding we would not have been able to develop the Group's activities and in all likelihood would not have survived. Other shares have been issued to buy assets (principally rigs) and companies (BNG / Caspian Explorer / 3A Best) or to satisfy specific debts where cash was not available.

Independent shareholders have also recently approved the issue of new shares at a premium to the then prevailing market price on completion of the West Shalva acquisition.

 

Related party transactions

Here again there seems to be a misinformed view that we have favoured the sellers when the opposite is very clearly the case. 

In particular:

·      Shareholders with longer memories will recall that in 2015 we sold Galaz, which was acquired as part of the Eragon acquisition in 2008 including BNG, for $100 million.

·      In 2020 the Caspian Explorer drilling vessel was acquired for $3.2 million where it's resale value today is many times greater and the replacement cost is believed to be some $300 million.

·      At Block 8 we will only pay for an asset with the potential to be world class from future production at the rate of $5 per barrel and with the price capped at $60 million.

·      With West Shalva it is only the first $5 million that would be payable should there be no oil

 

It is therefore only at 3A Best that we have yet to come out on the right side of the deal and as set out above that remains a work in progress.

The advantage of related party transactions is that we fully understand and can check what we are buying.  Given their existing shareholding in the Group there is no commercial purpose for the sellers seeking poor terms, even if under the regulatory framework it were possible.

For us related party transactions have worked very well and we should not be afraid to do others where the situation merits it.

Dividends

In November 2022 we initiated monthly dividend payments at the rate of approximately $1.25 million per month but after only four instalments we were forced to suspend payments for lack of available cash.

The immediate cause for the suspension in dividend payments was the operational impact of Russian sanctions, which meant instead of buying the bulk of our international drilling supplies and consumables from Russia on decent credit terms and two week delivery times, we had to order mainly from China with six month lead times and the need to pre-fund all payments.

This not only took all our available free cash but also delayed planned workovers, which in turn meant production related income was much lower than we expected at the time we set the dividend policy.

The decision to suspend dividend payments was not taken lightly and inevitably had a dramatic impact on the share price. When we suspended the dividend payments we undertook to review the position later in the year and again with these financial statements.

Opinion among shareholders who have expressed a view is divided. While some want the dividends to resume others would rather see available cash invested in new projects.

Separately, and as a consequence of both the 2022 UK High Court approved capital reduction and the UK Takeover Panel Rule 9 waiver granted in connection with the recent West Shalva acquisition, we now have both distributable reserves and, with the re-constituted concert party now cleared to hold more than 50% of the Group's shares, share buy-backs are possible without the need each time for a formal and expensive UK Takeover Panel approved whitewash.

In the circumstances therefore, the Board has decided not to resume regular dividend payments but to consider special dividends or share buy backs when funding permits.

 

Board composition

We are aware the current board composition is not ideal both in terms of the total number of directors and also where relevant the number of independent directors, which gives problems in:

·      fully populating the various board committees;

·      when it comes to the consideration of related party transactions; and

·      more generally as the extent of the Group's operations expands.

 

The main reason we have yet to appoint new non-executive directors is the ongoing up to 75% pay cut taken by all board members, which has been in place since early 2020 and was instigated to help the Group fund its survival and development. These restrictions are expected to be partially eased in the second half of the current financial year as the Group's cash position improves. At that time, we expect to be in a position to strengthen the board and have already identified individuals we believe would add value.

Further information relating to the board is set out in the Directors Report and the Remuneration Committee Report in these financial statements.

Outlook

We have always been optimistic about the prospects for the Group's assets. The issue though for the past decade at least has been funding and the need to both safeguard existing assets via compliance with the demanding work programme commitments including the need to pay down the assessed historic costs, while at the same time seeking to take advantage of as many of the opportunities available to us as could then be funded.

The current BNG work programme commitments are now largely satisfied.  Block 8 is expected to start contributing in the near future and significant income is expected from the Caspian Explorer in the coming months. Accordingly, we expect soon to enter a prolonged period where cash receipts far exceed mandated cash payments. In the event we complete the proposed sale of the BNG shallow structures for the proposed $83 million we would have large cash balances to invest or to return to shareholders via special dividends or share buy backs.

This, together with an expectation of the true commercial value of our assets emerging for all to see through increased production, further corporate transactions and / or reserve upgrades, plus the other opportunities we have in front of us, leads the Board to be now more confident of the Group's future success than at any time in the past decade.

 

Clive Carver

Chairman

15 July 2024

 

OPERATIONAL REVIEW

Oil production

Volumes

In 2023 a total of 665,114 barrels of oil were produced from the two shallow structures at the BNG Contract Area (2022: 792,284 barrels).

Of this production 576,368 barrels, representing approximately 87% of the total, were produced from the MJF structure (2022: approximately 767,284 barrels representing approximately 97% of the total) with 88,746 barrels representing approximately 13% of the total being produced from the South Yelemes structure (2022: approximately 25,000 barrels representing approximately 3% of the total).

Production in 2023 was adversely affected as for most of the year wells 141, 142 and 145 were shut in for workovers necessitated by increasing water content.

Current production from the shallow structures at the BNG Contract Area before any contribution from Well 803 is approximately 2,300 bopd.

Pricing

Oil produced in Kazakhstan and transported via the Russian pipeline network is not subject to sanctions. Nevertheless, in reality such oil continued to suffer significant discounts to the international price, which throughout 2023 meant it was uneconomic to sell any of the oil produced on the international markets.

In 2023 therefore 53% of oil produced was sold to the Kazakh domestic market (2022: 72%) with 47% sold to the Kazakh domestic mini refinery market (2022: 29%).

The average price achieved for oil sold in 2023 was approximately $32 per barrel (2022: $49.5 per barrel - which included several months of international sales before the imposition of the full impact of Russian sanction related "Urals discount").

On a positive note, the discount for oil produced in Kazakhstan and transported via the Russian pipeline network narrowed towards the end of 2023, to the point where international sales in 2024 seem far more likely.

Oil exploration

BNG Shallow structures

During the year workovers were undertaken at Wells 142 and 145 on the MJF structure.

At Well 142, which was the best performing of the original wells on the MJF structure before the water content rose to a level requiring a workover, a 2,300 meter side-track was drilled from a depth of approximately 1,860 meters with three intervals identified for testing. The first two intervals did not prove commercial. We are waiting on the outcome of the discussions to sell the MJF structure before testing the third interval.

The workover at Well 145 was not successful. The intention at Well 141 is to resume work to remove approximately 27 meters of stuck pipes, before drilling a horizontal side-track.

In February 2024 we spudded new Well 155 with a planned total depth of 2,400 meters. As noted above a 16 meter interval is currently under test with initial flow rates of between 900 and 1,000 bopd. Production levels at Well 155 have been reduced to approximately 700 bopd to optimise the life of the well. Accordingly, production from the MJF structure is currently approximately 2,050 bopd.

At the shallow South Yelemes structure we commenced the long planned use of horizontal drilling techniques at four Soviet era shallow wells. Work there has been completed on Wells 805 and 806. Production from the South Yelemes wells is currently approximately 250 bopd.

We are now drilling a new well on the South Yelemes structure being Well 815 with a planned depth of 1,900 meters targeting oil in the dolomites.

 

BNG Deep Structures

During 2023 we concluded that Deep Well A8 was not commercial and decided to abandon the well and since the period end we have made the same assessment at Deep Well 801.

At Deep Well A5, which flowed at rates in excess of 3,000 bopd when first drilled, work was undertaken in 2023 continuing in 2024 to attempt to remove a stuck pipe as a cheaper alternative to drilling a further side track. While a portion of the stuck pipe was removed the majority remains and a decision has been taken that, in due course, we will drill the new side track.  In the meantime, the rig previously in use at Deep Well A5 has moved to drill Well 815 as noted above.

At Deep Well A6 no work was undertaken in the period under review or subsequently. We plan to use a chemical treatment to seek to get the well to flow at commercial rates and have identified the rig currently in use at Deep Well 803 to be used in the attempt.

At Deep Well A7 we plan to use the G70 rig we expect soon to acquire to resume drilling from a depth of approximately 2,150 meters where drilling was paused to allow other wells to be drilled. The Planned Total Depth of the well is 5,300 meters with an interval of interest identified at approximately 4,000 meters.

At Deep Well 802, which was spudded in 2022 and drilled to a depth of 3,800 meters, our work in 2023 to bring the well into commercial production was not successful and we are now looking for a partner with technical expertise to develop the well together.

In Q4 2023 we spudded Deep Well 803.  As noted above the well had a planned total depth of 4,200 meters with a primary target at a depth of 3,950 meters and a secondary target at a depth of 4,200 meters. Oil has been detected over a 60 meter interval between 3,360 meters and 3,420 meters, above the expected targets and also above the main salt layer. A 15 meter interval is now being tested.

In June 2024 SciRes, an independent Kazakh consultancy, assessed C1 reserves in the immediate vicinity of wells A5, A6 & A7 at 49 mmbls. For further details please see the Licences & Work programmes and Reserves section of these financial statements.

Block 8

In 2023 two deep wells were drilled at Block 8. The first was drilled to a depth of 3,922 meters and the second was drilled to a depth of 3,408 meters. Both wells are now ready for testing once the Block 8 licence is renewed.

On renewal of the licence the two previously producing wells at Block 8, which before they were shut in produced at the rate of 110 bopd, would resume production.

West Shalva

In anticipation of the completion of the acquisition of the West Shalva Contract Area we plan to drill a 3,200 meter well, which is expected to spud in Q3 2024.

 

Clive Carver

Chairman

15 July 2024

 

FINANCIAL REVIEW

Revenue

Total revenue in 2023 fell by approximately 10 per cent to $36.7 million (Restated 2022: $40.9 million).

Oil prices

The impact of Russian sanctions made any international sales during 2023 uneconomic. By comparison, in the first four months of 2022 we sold 237,144 barrels on the international markets at an average price of $85 per barrel.

In 2023 the average price per barrel was approximately $32.5 compared to $49.5 in 2022.

Production volumes

Production in 2023 at 665,114 barrels was some 16% lower than in 2022 (792,284 barrels) principally as a consequence of wells 141 and 142 being out of production for much of the period and to date in 2024.

Income from oil sales

The net impact of lower prices and lower volumes was to reduce revenues from oil sales by approximately 45% to $21.6 million (2022: $39.2 million)

CTS

CTS LLP is the Group's wholly owned drilling company, which in 2023 undertook further work at the Block 8 Contract Area, which is in the process of being acquired with completion now expected later this year. Such work before the formal completion of the acquisition is recognised as third party revenue, as would income for drilling on other assets not then owned by the Group.

In 2023 the revenue from work at Block 8 was $4.1 million (Restated 2022: $1.6 million).

Prior Year Restatements

In preparing the financial statements for 2022, including the comparative numbers for 2021, the Directors were unable to obtain reliable information relating to drilling contracts held by its subsidiary CTS LLP in respect of the timing of the drilling costs incurred and their allocation between different contracts with EPC Munai LLP, an external party, and as well as contracts with another subsidiary of the Group, BNG LLP.

This information was necessary to determine revenues, cost of sales, advances received / receivable, provisions for losses on contracts, property plant & equipment, oil & gas assets, related tax balances and related party disclosures. As a result, the 2022 audit report included an audit qualification in this regard for the years ended 31 December 2021 and 2022, with revenue recognition not recorded in accordance with IFRS 15 under the input method.

Extensive work undertaken over the past 12 months has allowed the amounts spend by CTS to be properly allocated for 2023. As a result, the 2022 financial statements are subject to a prior year adjustment with the comparative numbers for the year ended 31 December 2022 being restated. The audit qualification in respect of the position at 2022 remains, and there is also a resultant impact on the 2023 revenue recognition and cost of sales.

The audit report for the year ended 31 December 2023, includes a qualification relating to these matters as was the case in the 2022 financial statements.

Further information relating to the prior year adjustment is set out in note 3.

The contracts with EPC Munai were all either completed or terminated during 2023 and therefore management do not believe there will be further ongoing issues in allocating the costs of CTS LLP.

 

 

 

Oil trading

Revenue from oil trading in 2023 was $10.3 million (2022: nil).

Under this heading we purchase crude oil and fund its refining, selling the resultant oil products to third parties.

 

Changes in Kazakh regulations, which came into effect at the start of 2023 and which require an element of oil production to qualify for an oil trading licence, allowed our entry into the market. Oil trading is only allowed on oil sold to the domestic market (53% in 2023) rather than for domestic mini-refinery sales (47% in 2023) or international sales (0% in 2023). To date we have adopted a relatively low risk approach to oil trading having formed a 70:30 partnership with an established trader with ourselves being the larger party and with our 30% partner providing the required funding.

 

Our entry into oil trading has proved extremely successful and we plan to continue to trade oil whether or not we sell the shallow MJF and South Yelemes structures. As our oil output from the BNG Contract Area increases and with Block 8 and West Shalva expected to come on stream we look forward to growing our oil trading income in the coming years.

Caspian Explorer

There was no revenue from the Caspian Explorer in 2023.

Gross profit

Gross profit fell by approximately 36 per cent to approximately $20.7 million principally as a result of the lower revenue from oil sales (Restated 2022: $32.2 million having in 2022 increased by 69%).

Selling expenses

Selling expenses fell by approximately 69% to $3.0 million (2022: $9.8 million having increased in 2022 by 29%) mainly as the result of lower export and customs duties, which are typically based on achieved oil prices with export sales attracting a much higher charge.

Administrative expenses

General and Administrative expenses were approximately $4.0 million lower at $5.8 million compared with $9.8 million in 2022, which included significant non-recurring local staff payments.

Other income

Following the write back of long standing but no longer required provisions we recorded a gain of $3.8 million.

EBITDA

EBITDA was $18.1 million (Restated 2022: $15.7 million.)

Operating profit

Despite the large decrease in gross profit the operating profit was $15.5 million (Restated 2022: $12.9 million) principally as the result of a $2.2 million contribution from oil trading, which commenced in 2023 together with the reversal of £3.8 million long standing provisions that are no longer required.

Profit for the year before tax

Profit before tax was $14.8 million (Restated 2022: $12.3 million).

Tax charge

The tax charge was $3.7 million (2022: $2.4 million). This tax is payable in Kazakhstan where historic losses have now been fully utilised.

Profit for the year after tax

The profit for the year after tax was $11.1 million (Restated 2022: $9.9 million).

Oil and gas assets

Unproven oil & gas assets

The carrying value of unproven oil and gas assets increased by approximately $7.4 million to approximately $52.0 million (Restated 2022: $44.6 million) as the result of additional work at the BNG deep structures.

Proven oil & gas assets

The value of proven oil & gas assets increased by approximately $6.5 million to approximately $60.6 million (2022:  $54.1 million).

Other receivables

Other receivables due within 12 months increased from approximately $6.1 million to approximately $12.1 million. Of this, trade receivables increased by $3.1 million to $3.7 million (Restated 2022: $0.6 million); prepayments increased by $3.0 million to $4.3 million (Restated 2022: $1.3 million); recoverable VAT increased by $0.9 million to $2.9 million (Restated 2022: $2.0 million); with other receivables falling by $0.9 million to $1.3 million (restated 2022 $ 2.2 million).

Cash position

At the year-end we had cash balances of approximately $0.4 million (2022: $3.7 million).

Liabilities

Trade and other payables under 12 months (excluding historic costs and provisions)

Trade and other payables increased to $16.1 million (Restated 2022: $14.8 million).

The provisions for payments in less than 12 months were approximately $4.5 million (2022: $6.0 million), which are mainly social obligations.

BNG historic costs

We have continued to pay down the historic costs assessed against the BNG Contract Area. At 31 December 2023, of the original $32 million levied in 2019 approximately $16.9 million remains to be paid over the next six years, of which approximately $3.2 million is to be paid within 12 months.

Cashflows

During the period under review approximately $39.6 million was received from customers and approximately $33.9 million paid out to suppliers, creditors and staff with a further $4.9 million spent on unproven oil and gas assets and $7.3 million spent on property plant and equipment. A further $1.5 million was paid to related parties in connection with the Block 8 loan, and approximately $3.0 million was paid in dividends.

The above plus new loans of $8.0 million resulted in cash balances at the year-end decreasing from $3.7 million to $0.4 million.

Going Concern

As set out in the Chairman's statement and throughout these financial statements the financial strategy of the Group in recent years has been to fund compliance with work programme commitments and to expand the Group's activities without unduly diluting shareholders longer term interests.

This has inevitably stretched the short and longer term creditor position to levels at the period end and today which in a more established Group might appear excessive. However, the Board believes the expected significant cash inflows from oil production, offshore chartering and if appropriate asset sales means that the current position is set to reverse during the remainder of the current financial year to the point that the Group will significantly improve its cash position.

Nevertheless, with net current liabilities of approximately $14.3 million as at 31 December 2023, the assessment of going concern needs careful consideration. The Board has therefore assessed cash flow forecasts prepared for the period to 31 December 2025 and assessed the risks and uncertainties associated with the operations and funding position, including Block 8 and West Shalva.

These cash flows are dependent on a number of key factors including:

·      The Group's cashflow is sensitive to oil price and volume sold. We have assumed all sales will be either domestic sales or sales to the domestic mini refineries. Should sales to domestic mini refineries cease and the surplus oil not be picked up on the domestic market additional funding would be required.

·      The Group continues to forward sell its domestic production and receives advances from oil traders. With approximately $3.9 million advanced at the reporting date the continued availability of such arrangements is important to working capital. Whilst the Board anticipate such facilities remaining available given its trader relationships, should they be withdrawn or reduced more quickly than forecast cash flows allow then additional funding would be required.

·      The Group has $4.0 million of tax liabilities and $4.3 million due on demand under social development programmes and $3.2 million BNG licence payments due within the next 12 months to the Kazakh government. The Board has forecasted the payment of the outstanding tax liabilities and the BNG licence payments but only a portion of the social obligations and development programmes due within the forecast period as the Board expects some social obligation and development programme payment deferrals to be approved. Should these deferrals not occur additional funding would be required.

·      Should the charter for the Caspian Explorer be materially delayed from its July 2024 start date and / or payment not be made in accordance with the contract terms additional funding would be required.

These circumstances continue to indicate the existence of a material uncertainty which may cast significant doubt about the Group and the Company's ability to continue as a going concern and it therefore may be unable to realise its assets and discharge its liabilities in the normal course of business. The financial statements do not include the adjustments that would result if the Group and the Company was unable to continue as a going concern.

While none of the following can be relied upon until cash is received there are a number of expected events, which could provide significant additional working capital in the short term:

·      operational expenditure savings at BNG where the mandated work programme obligations will end with Wells 155 and 803, both of which have been drilled and are now testing, together with new Well 815

·      revenues of at least $10 million expected in H2 2024 from the Caspian Explorer contract

·      commencement of repayment of the $3.1 million loan advanced to enable the 2023 work programme at Block 8 to be completed

·      production commencing from Block 8 less the $5 per barrel royalty once the licence is renewed and the re registration formalities in the UAE are finalised

·      if progressed, completion of the proposed $83 million sale of the MJF and South Yelemes structures would on its own eliminate any funding issues

Should it be necessary, the Board has the following actions to mitigate any short-term funding issues

·      To seek additional funding from advance oil sales

·      To sell all or part of one or more of the Group's assets - including either the BNG Contract Area where we have already received expressions of interest or the Caspian Explorer

·      To seek additional short term funding from the Group's largest shareholder group

·      To seek additional equity capital

Notwithstanding the material uncertainty described above, after making enquiries and assessing the progress against the forecast, projections and the status of the mitigating actions referred to above, the Directors have a reasonable expectation that the Group and the Company will continue in operation and meet its commitments as they fall due over the going concern period. Accordingly, the Directors continue to adopt the going concern basis in preparing the financial statements.

 

Clive Carver

Chairman

15 July 2024

 

 

OUR OIL & GAS ASSETS

BNG Contract Area

The Group holds a 99% interest in the BNG Contract Area, having first taken a stake in 2008, as part of the acquisition of 58.41% of a portfolio of assets owned by Eragon Petroleum Limited. In 2017, we increased our stake to 99% upon the completion of the merger with Baverstock GmbH. Since 2008, more than $100 million has been spent at BNG.

The BNG Contract Area is located in the west of Kazakhstan 40 km southeast of Tengiz on the edge of the Mangistau Oblast, covering an area of 1,561 square km of which 1,376 square km has 3D seismic coverage acquired in 2009 and 2010. We became operators at BNG in 2011, since when we have identified and developed both shallow and deep structures.

Shallow structures

The shallow structures at the BNG Contract Area (MJF & South Yelemes) produced 665,114 barrels of oil in 2023 (2022: 792,284).

MJF structure

The first wells were drilled on the MJF structure in 2016, since when it has produced in aggregate in excess of 4 million barrels. We have embarked on a programme of redrilling the older wells using horizontal drilling techniques to increase production.

The productive Jurassic aged reservoir consists of stacked pay intervals with most ranging in thickness from two meters to 17 meters. The current mapped lateral extent of the MJF field is now approximately 13 km2. The producing wells range in depth from 2,192 meters to 2,450 meters.

In December 2018, we applied to move the MJF structure, which was part of the overall BNG licence, from an appraisal licence to a full production licence, under which the majority of the oil produced from the MJF wells may be sold by reference to world rather than domestic Kazakh prices. The full production licence became effective in July 2019 and runs to 2043, with the first revenues based on international prices received in August 2019.

Following the award of the MJF export licence the Kazakh regulatory authorities assessed historic costs of $32 million against the MJF structure, repayable quarterly over a 10-year period, of which approximately $17 million remained payable at 31 December 2023.

In 2023 we produced 576,368 barrels of oil from the MJF structure at an average of 1,579 bopd (2022: 767,284 barrels at an average of 2,102 bopd). 

At the date of this report production from the MJF structure is approximately 2,050 bopd.

South Yelemes structure

The first wells were drilled on the South Yelemes structure during the Soviet era, with test production commencing in 1994. In 2023 the four Soviet era wells (54, 805, 806 & 807) produced approximately 88,746 barrels, (2022: approximately 25,000 barrels) at an average of 243 bopd. The structure has a full production licence to 2046 under which international sales are permitted.

Work has commenced to drill horizontally from each of the existing Soviet era wells at depths between approximately 2,200 and 2,300 meters targeting potential horizons in the Dolomites, with drilling on the first two wells completed. At the date of this report production from the South Yelemes structure is approximately 250 bopd.

Well 815 is a new well which is being drilled to a depth of 1,900 meters on the South Yelemes structure targeting oil in the Dolomites, using the rig previously used at Deep Well A5.

Deep structures

We have identified two deep structures at the BNG Contract Area. The first is the Airshagyl structure, which extends to 58 km2. The second is the Yelemes Deep structure, which extends over an area of 36 km2.

Airshagyl structure

Four deep wells have been drilled on the Airshagyl structure.

·      Deep Well A5 was spudded in July 2013 and drilled to a total depth of 4,442 meters. Attempts to remove a stuck pipe have to date not proved successful and a new side track is planned

·      Deep Well A6 was spudded in 2015 and drilled to a depth of 4,528 meters. A chemical treatment is planned.

·      Deep Well A7 was spudded in December 2021, with a planned Total Depth of 5,300 meters but primarily targeting an interval at a depth of 4,000 meters. In March 2022 drilling at A7 was paused at a depth of 2,150 meters to allow the rig to be used to drill a horizontal well on the shallow South Yelemes structure.

·      Deep Well A8 was spudded in 2018 with a planned Total Depth of 5,300 meters, initially targeting the same pre-salt carbonates that were successfully identified in Deep Well A5 at depths of 4,342 meters but with a prime target being the deeper carbonate of the Devonian to Mississippian ages towards the planned Total Depth of 5,300 meters. The well is now to be abandoned.

 

Yelemes Deep structure

·      Deep Well 801 was drilled in 2014 / 2015 to a depth of 5,050 meters. The well has been assessed as non-commercial and has been marked for abandonment.

·      Deep Well 802 was spudded in June 2022, with a planned Total Depth of 5,300 meters. To date the well has not flowed at commercial rates and we are seeking to conclude a joint venture agreement with an identified technical partner to continue work on this well.

·      Deep Well 803 was spudded in December 2023 with a planned total depth of 4,500 meters. Oil was encountered over a 60 meter interval between depths of 3,360 and 3,420 meters and a 15 meter interval is being tested.

 

Deep well drilling issues

Sub-surface conditions at the two discovered deep structures at BNG present significant technical challenges in drilling and completing the wells. These are the extreme high temperature and pressure that exist below the salt layer. At the Airshagyl structure the salt layer is typically found at depths between 3,700 and 4,000 meters whereas at the Yelemes Deep structure the salt layer is typically found at depths between 3,000 and 3,500 meters.

The extreme pressure below the salt layer requires the use of high-density drilling fluid to maintain control of the well during drilling. The high-density drilling fluid's principal role is to help prevent dangerous blow-outs. The attributes of the high-density barite weighted drilling fluid, which allow the wells to be controlled during the drilling phase, act against us when we attempt to clear the well for production.

To the extent that drilling fluids, which include solid particles added to increase density, are not fully recovered they can form a barrier between the wellbore and the reservoir impeding the flow of hydrocarbons into the well.

Block 8

The Block 8 Contract Area is 2,823 sq km with three identified structures and is approximately 160 km from the BNG Contract Area.

The Block 8 licence was previously held by LG International the Korean conglomerate, who in 2006 started to acquire 3D seismic data over approximately 456 sq km. In recent years two deep wells have been drilled to depths of 4,203 meters and 3,449 meters respectively, from which oil has flowed at rates of up to 800 bopd but at the time they were shut in, as required as part of the licence renewal process, produced at the rate of 110 bopd.

Two other wells were drilled in 2022 and 2023 to depths of 3,922 and 3,408 meters respectively and on receipt of the new Block 8 licence will be tested.

West Shalva

The West Shalva contract area is rectangular in shape and extends over approximately 25 km².  It is located in the oil producing Zhetybay Steppe Area in the Mangyshlak region of Western Kazakhstan approximately 90 km east of Actau and approximately 20 km north from the Zhetybay field, where an oil processing plant is located and oil enters the Actau / Atyrau main pipeline.

The West Shalva prospect is partially located in Block XXXVII-12 but straddles the boundary with adjacent blocks. The source rock for the West Shalva prospect is considered to be Triassic marine shale as is understood to be the case in the nearby Shalva and Zhalganoy fields.

The West Shalva prospect has potential reservoirs of Jurassic and Triassic age. The Jurassic - IX and Jurassic - XI and Triassic reservoirs are oil bearing in the nearby Shalva field and oil has been reported (but not tested) from core in the Triassic reservoir in the WSH-4 well. Based on interpretation of the available information the main reservoir targets are Jurassic IX and Jurassic -XI reservoirs, with secondary targets in the Triassic.

West Shalva was first identified as a potential oil producing location in the mid 1970's. In 1977 and based on 2D seismic data, Well no. 4 (Wsh-4) was drilled to the north and outside the structural closure of the West Shalva prospect to a depth of 3,500 meters with a prime potential oil bearing interval detected at a depth of 1,033 meters in the lower Triassic. After open hole testing lasting only a few minutes the well was deemed not to have found any commercial volumes of oil or gas despite oil being detected at three other intervals. The well was then abandoned without running a production string.

In 2008 a 3D seismic survey was undertaken on the contract area, which identified the West Shalva structure. In June 2022 oil was detected spilling to the surface.

West Shalva is an early stage oilfield but with strong indicators from both the adjacent Shalva field and from the available seismic information that it is likely to produce oil in decent quantities.  Additionally, it is expected to be easier to drill than either BNG and Block 8 as the high pressure and high temperature encountered in those fields are not present at West Shalva.  There is also no salt layer to penetrate and the field is closer to local refineries with a history of higher prices than the refineries nearer BNG and Block 8. In summary,  West Shalva is expected to be a much easier field to work than either BNG or Block 8 and a good addition to the portfolio. As at Block 8 the acquisition has been structured to avoid any up-front cash payments.

3A Best

In January 2019, we acquired 100% of the 3A Best Group JSC, a Kazakh corporation owning an existing Contract Area of some 1,347 sq. km located near the Caspian port city of Aktau.

The Contract Area, which has been designated by the Kazakh authorities as a strategic national asset, surrounds and goes below the established shallow field at Dunga, which we believe to be producing at the rate of approximately 15,000 bopd.

No development work has been undertaken since 2019.

 

 

 

 

LICENCES & WORK PROGRAMMES AND RESERVES

LICENCES

BNG

BNG LLP Ltd holds three contracts for subsoil use. The first is the appraisal contract, covering the full extent of the BNG Contract Area (except the MJF and South Yelemes structures), originally issued in 2007 and successively extended until August 2024.

The second is the export contract covering just the MJF structure, which runs to 2043 and the third is the export contract covering the South Yelemes structure, which runs to 2046. Under the MJF and South Yelemes licences the majority of oil produced may be sold by reference to international rather than domestic prices.

The process to extend the existing Airshagyl and Yelemes Deep appraisal licence for a further two years before then upgrading to separate 25 year production licences is underway under a new streamlined process which is expected to be completed during Q3 2024.

Block 8

The Block 8 licence renewal is expected imminently.

West Shalva

The licence at the West Shalva Contract Area is a six-year appraisal licence running until 2029.

3A Best

The licence renewal at 3A Best was delayed as the result of outstanding social payments due from the assets previous owners. As noted more fully in the Chairman's statement we continue to work with the Kazakh authorities to renew the 3A Best licence at the appropriate time.

WORK PROGRAMMES

BNG

The current work programme commitments end with Well 155, Deep Well 803 and new Well 815, for which we estimate the outstanding costs to be approximately $3 million.

Block 8

The extent of the work programme commitments under the new licence have yet to be determined.

West Shalva

On completion of the acquisition of West Shalva there will be an obligation to drill one well to a depth of approximately 2,600 meters.

RESERVES

BNG

Shallow structures

In 2011 Gaffney, Cline & Associates ("GCA") undertook a technical audit of the BNG licence area and subsequently Petroleum Geology Services ("PGS") undertook depth migration work, based on the 3D seismic work carried out in 2009 and 2010.

The work of GCA resulted in confirming total unrisked resources of 900 million barrels from 37 prospects and leads mapped from the 3D seismic work undertaken in 2009 and 2010. The report of GCA also confirmed risked resources of 202 million barrels as well as Most-Likely Contingent Resources of 13 million barrels on South Yelemes.

In September 2016 GCA assessed the reserves attributable to the BNG shallow structures (MJF & South Yelemes). Between then and the end of 2023, approximately 4.0 mmbls of oil were produced, which under financial reporting rules are deducted from the assessment of reserves as at 31 December 2023.

BNG	As at 31 December 2023	As at 31 December 2022
	mmbls	mmbls
Shallow P1	13.6	14.3
Shallow P2	24.8	25.5

 

Despite the last external review of the Group's reserves being in 2016, the Board considers their assessment as set out in the above table to be valid. In the event the proposed sale of the MJF and South Yelemes structures does not complete the Board's intention is to revisit the external assessment of the BNG Contract Area's shallow reserves.

Deep structures

In conjunction with the licence extension in respect of the Airshagyl and Yelemes Deep structures and referred to above under licences, we are also making submissions for formal recognition under the former Soviet classification system used in Kazakhstan of reserves at both deep structures based on information gained from the  four deep wells drilled to date at the Airshagyl structure and the three deep wells drilled to date on the Yelemes Deep structure.

In June 2024 reserves under the former Soviet classification system were independently assessed by SciRes, a Kazakh consultancy, based solely on the vicinity of the immediate drainage area around Deep Wells A5, A6 & A7 as being C1 49.0 million barrels & C2 as 28.9 million barrels.

At Yelemes Deep we first need to complete the testing at Deep Well 803 before a similar assessment can be finalised.

In due course, following the completion of the reserves estimate underway at the Yelemes Deep structures under the former Soviet classification system, we plan to seek a reserves update under the international Society of Petroleum Engineers (SPE) classification system, for all of the BNG Contract Area, which would also include the shallow MJF and South Yelemes shallow structures, provided they are then still part of the Group.

Block 8

An estimate of the reserves at Block 8 is planned following completion.

West Shalva

To date there are no certified reserves in respect of the West Shalva Contract Area. Again, we intend to commission an independent assessment of the West Shalva reserves after completing the planned 3,200 meter well.

3A Best

There are no certified reserves in respect of the 3A Best Contract Area.

 

 

QUALIFIED PERSON & GLOSSARY

Qualified Person

Mr. Assylbek Umbetov, a member of the Association of Petroleum Engineers, has reviewed and approved the technical disclosures in these financial statements.

Glossary

SPE - the Society of Petroleum Engineers

Bbl - barrels of oil

Bopd - barrels of oil per day mmbls - million barrels

Proven reserves

Proven reserves (P1) are those quantities of petroleum which, by analysis of geosciences and engineering data, can be estimated with reasonable certainty to be commercially recoverable, from a given date forward, from known reservoirs and under defined economic conditions, operating methods, and government regulations.

If deterministic methods are used, the term reasonable certainty is intended to express a high degree of confidence that the quantities will be recovered. If probabilistic methods are used, there should be at least a 90% probability that the quantities actually recovered will equal or exceed the estimate.

Probable reserves

Probable reserves are those additional reserves which analysis of geosciences and engineering data indicate are less likely to be recovered than proved reserves but more certain to be recovered than possible reserves. It is equally likely that actual remaining quantities recovered will be greater than or less than the sum of the estimated proved plus probable reserves (2P).

In this context, when probabilistic methods are used, there should be at least a 50% probability that the actual quantities recovered will equal or exceed the 2P estimate.

Possible reserves

Possible reserves are those additional reserves which analysis of geosciences and engineering data indicate are less likely to be recovered than probable reserves.

The total quantities ultimately recovered from the project have a low probability to exceed the sum of proved plus probable plus possible (3P), which is equivalent to the high estimate scenario. In this context, when probabilistic methods are used, there should be at least a 10% probability that the actual quantities recovered will equal or exceed the 3P estimate.

Contingent resources

Contingent resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations, but the applied project(s) are not yet considered mature enough for commercial development due to one or more contingencies.

Contingent resources may include, for example, projects for which there are currently no viable markets, or where commercial recovery is dependent on technology under development, or where evaluation of the accumulation is insufficient to clearly assess commerciality.

Contingent resources are further categorised in accordance with the level of certainty associated with the estimates and may be sub-classified based on project maturity and/or characterized by their economic status.

Prospective resources

Prospective resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from undiscovered accumulations.

Potential accumulations are evaluated according to their chance of discovery and, assuming a discovery, the estimated quantities that would be recoverable under defined development projects.

CASPIAN EXPLORER

Introduction

The Caspian Explorer is a drilling vessel designed specifically for use in the shallow northern Caspian Sea where traditional deep water rigs cannot be used.

The principal ways of exploring in such shallow waters are either from a land base or using a specialist shallow drilling vessel such as the Caspian Explorer, which we believe to be the only one of its type operational in the Caspian Sea.

Land based options typically involve either the creation of man-made islands from which to drill as if onshore or less commonly drilling out from an onshore location. Both are typically expensive compared to the use of a specialist drilling platform such as the Caspian Explorer.

The Caspian Explorer was conceived of by a consortium of leading Korean companies including KNOC, Samsung and Daewoo Shipbuilding.  The vessel was assembled in the Ersay shipyard in Kazakhstan between 2010 and 2011 for a construction cost believed to be approximately $170 million. The Caspian Explorer became operational in 2012 at a time of relatively low oil prices and reduced exploration activity in the northern Caspian Sea.

The total costs after fit-out are believed to have been approximately $200 million. We believe a replacement would today cost in the region of $300 million and take several years from a decision to commission it for such a new vessel to become operational.

Operational characteristics

The Caspian Explorer:

·      operates principally between May and November as the Northern Caspian Sea is subject to winter ice

·      operates in depths between 2.5 meters and 7.5 meters

·      can drill to depths of 6,000 meters

·      typically has a crew to operate the drilling vessel of 20

·      has accommodation for approximately 100

·      costs approximately $60,000 per month while moored in port 

·      is generally able to pass on other costs incurred while operational to the clients hiring the vessel

 

Safety contract

In June 2021 we announced the first charter for the Caspian Explorer since it has been a part of the Group. The charter was with the North Caspian Operating Company ("NCOC"), which is the principal operator in the region, comprising the Republic of Kazakhstan working through KazMunaiGas (KMG), and international oil companies including Shell, ExxonMobil, ENI, Total Energies and CNPC, the consortium operating the Kashagan field.

Daily rates for safety related work are much lower than for conventional commercial drilling contracts but the income from the charter covered the Caspian Explorer's costs for that year.

Drilling contract

In March 2023 we announced that the first commercial drilling contract for the Caspian Explorer under the Group's ownership had been signed.

An offshore well is scheduled to be drilled in the summer of 2024 to a planned depth of 2,500 meters. It will be drilled for the Isatay Operating Company LLP ("IOC"), a Kazakh registered explorer, in which Italy's ENI is a leading participant. The Caspian Explorer left the port of Aktau in July 2024 to commence drilling as planned with the drill programme expected to take approximately two months.

Daily rates have been agreed for both drilling days and days when no drilling occurs.  On the basis of these rates and the Group's assessment of the likely total number of days required to complete the assignment the Group expects further revenue in 2024 of approximately $10 million.

The contract also provides for a second well in the event the first is deemed successful.  In the event the option for the second well was exercised it would most likely be drilled in 2026 on terms similar to the first assignment and is again expected to produce revenue of in excess of $10 million.

We are finalising the preparatory work for the ENI led consortium charter, which we expect to start on time in July 2024.

Other charters

We believe the drilling contract due to commence in Q3 2024 will be the first of a number as exploration of the shallow northern Caspian Sea increases. Discussions continue with a number of parties interested in chartering the Caspian Explorer, either on normal commercial terms or where the involvement of the Caspian Explorer allows Caspian Sunrise to take an interest in the project.

Accounting valuation

The Caspian Explorer has been written down in previous financial statements so that its carrying value at 31 December 2023 is only $1.7 million (2022: $1.7 million). 

Lapsed conditional sale

In June 2023 we announced the conditional sale of 50% of Prosperity Petroleum, the UAE registered holding company for the Caspian Explorer for $22.5 million. The sale did not complete as a result of the prospective buyer failing to make the agreed payments.

Other corporate interest

Given its unique nature other expressions of interest in acquiring the Caspian Explorer have been received at indicated sums vastly greater than its accounting valuation. While it is not the Group's intention to sell the drilling vessel we are, as set out more fully in the Chairman's statement, obliged to consider all meaningful offers.

 

KAZAKHSTAN

Introduction

The Republic of Kazakhstan is mostly in Central Asia, with a part in Eastern Europe. It borders Russia to the north and west, China to the east, Kyrgyzstan to the southeast, Uzbekistan to the south and Turkmenistan to the southwest, with a coastline along the Caspian Sea.

Kazakhstan is the ninth largest country by land area and the largest landlocked country. Its population is 20 million with one of the world's lowest population densities.

Kazakhstan dominates Central Asia economically accounting for 60 per cent of the regions GDP, primarily through its oil & gas industry and its vast mineral resources.

Natural resources

Kazakhstan has an enormous supply of accessible mineral and fossil fuel resources.

Petroleum

The United States International Trade Administration lists Kazakhstan as having the 12^th largest proven reserves which they estimate at 30 billion barrels.

The major oil and gas fields and recoverable oil reserves are Tengiz (which is approximately 40 km from BNG), Karachaganak and Kashagan.

The Tengiz field was jointly developed in 1993 as a 40-year Tengizchevroil venture between Chevron Texaco Exxonmobil, KazMunayGas, and LukArco. The Karachaganak natural gas and gas condensate field was developed by  BG, Agip, ChevronTexaco, and Lukoil.

Chinese oil companies are now also heavily involved in Kazakhstan's oil industry.

Minerals

The United States International Trade Administration also lists Kazakhstan as having the world's largest reserves of uranium and extensive coal, gold and manganese reserves.

 

THE KAZAKH OIL AND GAS LICENCING AND TAXATION ENVIRONMENT

Introduction

Oil & gas is a heavily regulated industry throughout the world, with strict rules on licencing and taxation. Set out below is a summary of the position in Kazakhstan.

Licensing

Exploration licences

The initial licence to develop a field is typically an exploration licence where the focus is on completing agreed work programmes. Exploration licences are typically two years in duration and it is usual for there to be several consecutive two-year exploration licence extensions agreed during the exploration phase.

Appraisal licences

In the event the project appears commercial, the exploration licence is typically upgraded to an appraisal licence.

Under an appraisal licence, oil produced incidentally while exploring and assessing may be sold but only at domestic prices. Taxation under an appraisal licence is limited with only modest deductions. Changes to the legislation in the last few years have reduced the length of appraisal licences from six to five years, with a concession of reduced social obligation payments.

Full production licences

To sell oil by reference to world prices requires that either the Contract Area as a whole or a particular structure has to be upgraded to a full production licence. Under a full production licence there is only limited scope to develop areas not already drilled. Additionally, a significant minority portion of production typically remains at domestic prices although the majority can be sold by reference to world prices.

Taxes

There are five different taxes that apply to Kazakh oil & gas producers. Each has its own basis of calculation with some being related to profits, others by reference to world oil prices and yet others by reference to the volume of oil sold. The overall impact is that as world prices increase so typically does the percentage taken by the Kazakh state.

 

 

 

 

STRATEGIC REPORT

Introduction

This strategic report comprises: the Group's objectives; the strategy; the business model; and a review of the Group's business using key performance indicators. The Chairman's statement, which together with the operational and financial reviews also form the main part of the strategic review, contain a review of the development and performance of the Group's business during the financial year, and the position of the Group's business at the end of that year. Additionally, a summary of the principal risks and uncertainties facing the business is set out immediately after the Directors' report.

Objectives

The Group's objective is to create shareholder value from the development of oil & gas and mining projects and associated activities.

The Group has a number of secondary objectives, including promoting the highest level of health and safety standards, developing our staff to their highest potential and being a good corporate citizen in our chosen countries of operations.

Strategy

The Group's long-term strategy is to increase shareholder value by building an attractive portfolio of oil & gas and mineral assets, initially in Central Asia, and in particular Kazakhstan where the board has the greatest experience.

The Group's principal asset is its 99% interest in BNG, a 100% interest in the Caspian Explorer, a shallow water drilling vessel designed for the northern parts of the Caspian Sea. The Group also owns a 100 per cent interest in the 3A Best Contract Area, which would require a licence renewal before having any commercial value.

The Group has also conditionally agreed to acquire:

·      a 100% interest in the Block 8 Contract Area for a maximum consideration of $60 million, payable via royalties on future Block 8 oil production at the rate of $5 per barrel; and

·      a 100% interest in the West Shalva Contract Area for a maximum consideration of $15 million, of which a maximum of $10 million is payable by the issue of Caspian Sunrise shares to be issued at 4p per share and up to a further $5 million in cash from future West Shalva production

 

Business model

The business model is straightforward. To take assets at any stage of the development cycle and to improve them to the point they contribute to the Group's profitability or that they may be sold on at a profit to provide funding for additional development.

Our BNG asset has been developed over the past 18 years with approaching $200 million spent on it of which approximately $120 million has been spent by the Group since 2008. We believe it is set to be a very substantial asset for many years to come.  We have received a conditional offer of $83 million for the shallow structures and believe the deep structures have a far greater value.

We also believe Block 8 has the potential to at least match BNG. West Shalva adds a third oil & gas asset, but without the high temperature and pressures present at BNG and Block 8.

While we seek to grow our asset portfolio with appropriately timed acquisitions we are also prepared and able to sell assets when their value to others exceeds the value we can see. This was the case in 2015, when in poor market conditions, we sold our then second asset Galaz for a headline price of $100 million, which represented a profit of $15 million on our interest in the asset, and which provided $33 million to re-invest into BNG.

Further growth by acquisition

The Group will consider acquiring additional assets or related businesses where the Board believes they would increase shareholder value, including by providing funding or infrastructure to develop the Group's other assets.

The Directors believe the Group is exceptionally well placed through its strong local Kazakh presence to identify and buy undervalued oil & gas assets and mining and other assets on an opportunistic basis.

Climate Change

The Group's purpose is to supply energy in an environmentally conscious manner to the benefit of all stakeholders. As a natural resources exploration and production company, we recognise our environmental responsibilities to all our stakeholders and in particular to the local communities in which we operate.

However, other than a longer term general move away from fossil fuels once renewable alternatives are available in sufficient quantities and at comparable prices, the Board is not aware of any indications that the impact of climate change is likely to have a material impact on the Group's business over the short and medium terms.  We believe the current need for oil will continue for many decades to come.

The Group's size means it is not required to report further on climate change.

Key performance indicators

The Non-Financial Key Performance Indicators are:

·      Operational (wells drilled and not identified for abandonment at end of year) 2023: 20 (2022: 20)

·      Aggregate production for 2023 was 665,114 barrels (2022: 792,284) a fall of approximately 16%

·      Reserves at 31 December 2023 13.6 P1 mmbls & 24.8 P2 mmbls (2022: P1 14.3 mmbls & P2 25.5 mmbls)

 

The Financial Key Performance Indicators are:

·      Revenue: down 10% at $36.7 million (Restated 2022: $40.9 million)

·      EBITDA $18.1 million (Restated 2022: $15.7 million)

·      Profit before tax $14.8 million (Restated 2022: $12.3 million)

·      Profit after tax for the year $11.1 million (Restated 2022: $10.0 million)

·      Cash at bank: $0.4 million (2022: $3.7 million)

·      Total assets: $134.9 million (Restated 2022: $117.7 million)

·      Exploration assets $52.0 million (Restated 2022: $44.6 million)

·      Proved oil & gas assets $60.6 million (Restated 2022: $54.1 million)

 

Production at the date of this report

·      Approximately 2.300 bopd excluding any production from Well 803.   (30 June 2023: approximately 2,000 bopd)

 

Assets & Reserves

Further details of the Group's assets and reserves are set out in the Chairman's statement and throughout this Annual Report.

Financial

At current domestic and domestic mini refinery prices and with current levels of production the income from current production is sufficient to cover day-to-day Group operations and G&A costs.

The bulk of the payments for the Caspian Sunrise drilling contract for the consortium headed by ENI are expected to be received during the remainder of 2024.

Should the proposed conditional $83 million sale of the shallow structures at the BNG Contract Area complete we would expect the net proceeds to be received in Q4 2024. In the event any of the deep wells drilled start to produce oil in commercial quantities the associated revenues should transform the Group's cash flows.

Drilling wells at a rate faster than could be funded from oil sales, would require additional funding, as would any acquisitions to be funded by cash. Potential sources of such funding would include further advances from local oil traders for the sale of oil yet to be produced; industry funding in the form of partnerships with larger industry players; further support from existing shareholders; and equity funding from financial institutions. Additionally, funding may be available from selected asset sales.

Dividends

The Company's first dividend was declared in November 2022 and was followed by 3 further monthly dividends. In March 2023 the Company announced that future dividends would be declared on a quarterly rather than monthly basis. In July 2023 we announced the suspension of future dividend payments following sanctions related working capital pressure. 

As set out more fully in the Chairman's statement the Board has decided against the resumption of regular dividend payments in favour of special dividends and / or share buy backs when funding permits.

S. 172 Statement

The Board is mindful of the duties of directors under S.172 of the Companies Act 2006.

Directors act in a way they consider, in good faith, to be most likely to promote the success of the Company for the benefit of its members. In doing so, they each have regard to a range of matters when making decisions for the long term success of the Company.

Our culture is that of treating everyone fairly and with respect and this extends to all our principal stakeholders. Through engaging formally and informally with our key stakeholders, we have been able to develop an understanding of their needs, assess their perspectives and monitor their impact on our strategic ambition.

As part of the Board's decision-making process, the Board and its committees consider the potential impact of decisions on relevant stakeholders whilst also having regard to a number of broader factors, including the impact of the Company's operations on the community and environment, responsible business practices and the likely consequences of decisions in the long term.

Our objective is to act in a way that meets the long term needs of all our main stakeholder groups. However, in so doing we pay particular regard to the longer term needs of shareholders. We engage with investors on our financial performance, strategy and business model. Our Annual General Meeting provides an opportunity for investors to meet and engage with members of the Board. The Board also continues to encourage senior management to engage with staff, suppliers, customers and the community in order to assist the Board in discharging its obligations.

Further details of how the Directors have had regard to the issues, factors and stakeholders considered relevant in complying with S 172 (1) (a)-(f), the methods used to engage with stakeholders and the effect on the Group's decisions during the year can be found throughout this report and in particular at page 29 (where the Group's strategy, objectives and business model are addressed), page 32 (in relation to employees) the ESG report on page 37 (in relation to social and environmental matters).

We seek to attract and retain staff by acting as a responsible employer. The health and safety of our employees is important to the Company and an area we have to regularly report on to the Kazakh regulatory authorities.

We continue to provide support to communities and governments through the provision of employment, the payment of taxes and supporting social and economic development in the surrounding areas, both through social investment and local procurement. We have contributed to a range of social programmes for well over a decade.

We have established long-term partnerships that complement our in-house expertise and have built a network of specialised partners within the industry and beyond.

 

Clive Carver

Chairman

15 July 2024

 

 

 

DIRECTORS' REPORT

The Directors present their annual report on the operations of the Company and the Group, together with the audited financial statements for the year ended 31 December 2023.

The Strategic Report forms part of the business review for this year.

Principal activities

The principal activities of the Group are

·      the  exploration and production of oil & gas

·      onshore and offshore oil field services

·      oil trading

 

Results and dividends

The consolidated statement of profit or loss is set out on page 56 and shows a $11.1 million profit for the year after tax (Restated 2022: US$10.0 million).

The Company declared its first monthly dividend of £1 million (approximately $1.13 million) in November 2022 and has subsequently declared a further 3 monthly dividends before suspending dividend payments in July 2023. As set out more fully in the Chairman's statement the Board has decided not to resume regular dividend payments but rather to look to declare special dividends and / or share buy backs when funding permits.

Review of the year

The review of the year and the Directors' strategy are set out in the Chairman's Statement, the Strategic Report and throughout these financial statements.

Events after the reporting period

Other than the operational and financial matters set out in these financial statements there have been no material events between 31 December 2023, and the date of this report, which are required to be brought to the attention of shareholders. Please refer to note 31 of these financial statements for further details.

Board changes

In July 2023 Edmund Limerick left the board after 13 year's service as a non-executive director. Otherwise, there have been no board changes during the year under review or subsequently.

Employees

Staff employed by the Group are based primarily in Kazakhstan.

The recruitment and retention of staff, especially at management level, is increasingly important as the Group continues to build its portfolio of oil & gas and mining assets. As well as providing employees with appropriate remuneration and other benefits together with a safe and enjoyable working environment, the Board recognises the importance of communicating with employees to motivate them and involve them fully in the business.

For the most part, this communication takes place at a local level and staff are kept informed of major developments through email updates. They also have access to the Group's website.

The Group has taken out full indemnity insurance on behalf of the Directors and officers.

Health, safety and environment

It is the Group's policy and practice to comply with health, safety and environmental regulations and the requirements of the countries in which it operates, to protect its employees, assets and the environment.

 

Environmental reporting

The Group is exempt from the Streamlined Energy and Carbon Reporting (SECR) requirements since its energy consumption is less than 40,000 kWh per annum in the UK.

Charitable and Political donations

During the year the Group made no charitable or political donations.

Directors and Directors' interests

The Directors of the Group and the Company who held office during the period under review and up to the date of these financial statements are as follows:

Directors' interests

Director	Number of Ordinary Shares
	As at 31 December 2023	As at 31 December 2022
Clive Carver	2,245,000	2,245,000
Kuat Oraziman*	nil	nil
Aibek Oraziman*	1,046,909,031	946,887,599
Seokwoo Shin	nil	nil

 

* taken together on 31 December 2023 the Oraziman Family, comprising Kuat Oraziman, Aibek Oraziman, Altynbek Bolatzhan and Bolatzhan Kerimbayev held 1,089,544,791 shares representing approximately 48.41% of the issued share capital. Together with Daulet Beisenov they formed a Concert Party then holding 1,091,189,529 shares representing 48.49%

Biographical details of the Directors are set out on the Company's website www.caspiansunrise.com.

Details of the Directors' individual remuneration, service contracts and interests in share options are shown in the Remuneration Committee Report.

Other shareholders over 3% at the date of this report

Shareholder	Shares held	%
Dae Han New Pharm Co Limited	224,830,964	9.97
Midiel Engineering AG	110,812,501	4.91
Al Marri Family	110,812,500	4.91
Abai Kalmyrzayev	79,058,642	3.51

 

Financial instruments

Details of the use of financial instruments by the Group and its subsidiary undertakings are contained in note 27 of the financial statements.

Statement of disclosure of information to auditor

The Directors have taken all the steps that they ought to have taken to make themselves aware of any information needed by the Group's auditor for the purposes of their audit and to establish that the auditors are aware of that information.

The Directors are not aware of any relevant audit information of which the auditor is unaware.

Auditors PKF Littlejohn LLP, who were appointed in the year, have indicated their willingness to continue in office and a resolution concerning their reappointment was passed at the Annual General Meeting held on 27 June 2024.

Directors' responsibilities statement 

The Directors are responsible for preparing the annual report and the financial statements in accordance with applicable law and regulations.

Company law requires the Directors to prepare financial statements for each financial year. Under that law the Directors have elected to prepare the Group and Company financial statements in accordance with UK adopted international accounting standards. 

Under Company law the Directors must not approve the financial statements unless they are satisfied that they give a true and fair view of the state of affairs of the Group and Company and of the profit or loss of the Group for that period.

The Directors are also required to prepare financial statements in accordance with the rules of the London Stock Exchange for companies trading securities on the London Stock Exchange AIM Market.

In preparing these financial statements, the Directors are required to:

·      select suitable accounting policies and then apply them consistently;

·      make judgements and accounting estimates that are reasonable and prudent;

·      state whether they have been prepared in accordance with UK adopted international accounting standards subject to any material departures disclosed and explained in the financial statements; and

·      prepare the financial statements on the going concern basis unless it is inappropriate to presume that the Company and the Group will continue in business.

 

The Directors are responsible for keeping adequate accounting records that are sufficient to show and explain the Group's and the Company's transactions and disclose with reasonable accuracy at any time the financial position of the Group and the Company and enable them to ensure that the financial statements comply with the requirements of the Companies Act 2006.

They are also responsible for safeguarding the assets of the Group and the Company and hence for taking reasonable steps for the prevention and detection of fraud and other irregularities.

Website publication

The maintenance and integrity of the Group's website is the responsibility of the Directors.

The Directors are responsible for ensuring the annual report and the financial statements are made available on a website.  www.caspiansunrise.com/investors/reports

Financial statements are published on the Group's website in accordance with legislation in the United Kingdom governing the preparation and dissemination of financial statements, which may vary from legislation in other jurisdictions.

The Directors' responsibility also extends to the ongoing integrity of the financial statements contained therein.

Responsibility statement

The Directors confirm that to the best of their knowledge

·      the financial statements, prepared in accordance with the relevant financial reporting framework, give a true and fair view of the assets, financial position and profit or loss of the Company and the undertakings included in the consolidation taken as a whole

·      the Strategic Report includes a fair review of the development and performance of the business and the position of the Company and the undertakings included in the consolidation taken as a whole, together with a description of the principal risks and uncertainties

·      the Annual Report and the financial statements taken as a whole, are fair balanced and understandable and provide the information necessary for shareholders to assess the Company's position, performance, business model and strategy.

 

Clive Carver

Chairman

15 July 2024

PRINCIPAL AND OTHER RISKS AND UNCERTAINTIES FACING THE BUSINESS

Introduction

Risk assessment and evaluation is an essential part of the Group's planning and an important aspect of the Group's internal control system.

Oil & gas exploration and production and mining are dangerous activities and as such are necessarily subject to an extremely rigorous health and safety regime. The Board aims to identify and evaluate the risks the Group faces or is likely to face in future both from its immediate activities and from the wider environment. This helps to inform and shape the Group's strategy and to quantify its tolerance to risk.

Operational success generally helps to mitigate financial risks. Increases in production as new wells or mines come on stream generates cash and improves the Group's financial position, which can then lead to further operational success.

As the Group develops, its approach to risk management and mitigation will be refined. In due course we plan to include a formal risk register including all the principal operational and non-operational risks to the business.  Such a risk register would be reviewed and assessed at least once a year.

The Group is subject to various risks relating to political, economic, legal, social, industry, business and financial conditions. The following risk factors, which are not exhaustive, are particularly relevant to the Group's business activities and are listed in the Board assessment in the order of greatest potential impact.

Risk	Description	Mitigation
Operating risk	Oil & gas exploration and production and mining are dangerous activities. The Group is exposed to risks such as well blowouts, fire, pollution, bad weather and equipment failure.	The Group seeks to adopt best in class industry operating standards and complies with rigorous health & safety regulations.   The Group also seeks to work with contractors who can demonstrate similar high standards of safety.
Exploration risk	Despite the success of the BNG shallow structures, there can be no assurance the Group's exploration activities in the BNG deep structures or anywhere else will be successful.	The Group seeks to reduce this risk by acquiring and evaluating 3D seismic information before committing to drill exploration and appraisal wells.   The Group also seeks to engage suitably skilled personnel either as employees or contractors to undertake detailed assessments of the areas under exploration.
Political Risk	Political division which leads to civil disorder is likely to have an adverse impact on the Group's operations.	Widespread disorder in Kazakhstan had been absent since the Group's formation until the beginning of 2022, when the Group together with other operators was forced to suspend operations due to civil unrest.   The importance of the oil & gas and mining industries to the Kazakh economy makes a prolonged suspension of operations unlikely, as was the case in 2022.
Russian sanctions	The sanctions imposed on Russia may affect both the Group's ability to transport its oil and the price at which the oil may be sold.   It may also affect the Group's ability to source equipment and other consumables required to produce oil.	For international sales and like most oil produced in Kazakhstan for the international market the Company's oil is transported to international buyers via the Russian oil pipeline network.   While there are and were no UK or EU sanction on Kazakh oil transported through the Russian pipeline system in practice for much of the past two years such oil was subject to a hefty unofficial "Urals Oil" discount. This made selling the Group's oil on the international market uneconomic.   In recent months the discount on "Urals Oil" to international oil prices has narrowed to the point it is no longer an issue for volumes greater than those currently produced by the Group. However, for our levels of production and given our sales trading income we are not to date at the point where international sales are yet commercial.   We therefore currently sell all our oil either on the traditional domestic market or the relatively new domestic mini refinery market where taxes and other deductions are much lower. Equipment and consumables previously sourced from Russia are now found elsewhere, typically China, adding  time and expense.
Permitting risks	Every stage of the Group's operations requires the approval of the industry regulators.   While the Group enjoys good working relationships with the Kazakh regulatory authorities there can be no assurances that the laws and regulations and their reinterpretation will not change in future periods and that, as a result, the Group's activities would be affected.	Regulatory delays are inevitable and common place.   Our experienced Kazakh workforce has both a thorough knowledge of the complex rules and a detailed practical understanding of the workings of each of the regulatory bodies with whom we need to deal. Accordingly, we believe we are well placed to minimise the financial impact of regulatory delays.
Pricing risk	We operate in an industry where the international price is set by world markets and the domestic price is set by the Kazakh regulatory authorities.	We have no influence on the price at which we can sell our oil or any minerals produced from mining.   Greater storage and or financial hedging would provide some protection against adverse oil price movements but would be expensive and short lived.
Environmental risk	There would be serious consequences in the event of a polluting event.	The Group seeks to maintain compliance with all applicable regulatory standards and practices.   Further information is set out in the Environmental, Social and Governance Report.
Climate change	That climate change might impact the prospects for the Group	The board does not believe in the short to medium term climate change will have a material impact on the Group's revenues or operations. In particular the board believes the demand for oil will continue for at least the next decade and that climate change is unlikely to materially impact the Group's ability to produce that oil.
Exchange rate risk	Movements in exchange rates may result in actual losses or in the results reported in the Group financial statements.	The Group's income is denominated in US$ and Kazakh Tenge its expenditure is denominated principally in US$, Kazakh Tenge and UK £.  In the year under review and subsequently the Tenge broadly maintained its exchange rate against the US$.   Any decline in the Kazakh Tenge against the US$ affects the US$ reported income for domestic sales which transacted in Tenge. However, in such circumstances the Group generally benefits as international income is unaffected but approximately 50% of the Group's costs are  incurred in Tenge reducing the US$ reported operating costs.   Given the relative strengths of the US$ and the Kazakh Tenge, the Group has decided not to seek to hedge this foreign currency exposure.
Loss of major shareholder support	In previous periods the Group has relied on the financial support of the Oraziman family, which currently holds 48.3% of the Company's shares.	The Group is now producing significant volumes of oil with additional income from oil services and oil trading and is on a day to day operating basis financially a self-supporting enterprise.   However, in the event further support was required it would clearly be in the interests of the Oraziman family as the major shareholding  group to provide it.
Supplier risk	Continued operations depend on regular deliveries to site of consumables, such as water, food, heating oil and replacement parts for our drilling equipment. Delays in such deliveries to site could impact production volumes. The war in Ukraine has resulted in supplies no longer being sourced from Russia.  Replacement supplies from China are taking much longer to arrive.	We have been operating the BNG Contract Area for more than a decade during which we have encountered numerous supply issues, all of which have been overcome.   Managing supplies has become one of the most important aspects of the business.   With the majority of supplies now coming from China, whose border is approximately 3,000 kilometers from the BNG Contract Area, lead times are now much greater. In addition, the working capital investment is also much greater as supplies need to be paid for much earlier than before.

 

ENVIRONMENTAL, SOCIAL AND GOVERNANCE (ESG) REPORT

This report covers our ESG approach and performance for the year ended 31 December 2023.

ENVIRONMENTAL

Introduction

Oil and gas exploration and production is a long-term activity requiring effective environmental stewardship. We have operated in Kazakhstan now for more than 18 years and have only been able to do so by complying with applicable environmental standards.

We recognise that society is transitioning towards a low-carbon future, and we support this goal. However, we believe that oil will continue to play an important role in the global economy for many decades to come, and new sources of oil supply will be required for a sustainable energy transition.

Climate change

Assessing the risks

We look to the Kazakh regulatory authorities to set the standards to which we work.

Compliance with the standards

We seek to comply with all relevant Kazakh environmental requirements, including environmental laws & regulations and industry guidelines.

Specific initiatives

·      We seek to recycle gas produced as a by-product at BNG to power the Contract Area's day-to-day operations.

·      We seek wherever possible to avoid flaring, which in any event is a regulated activity.

·      Our workers at the BNG Contract Area are drawn from the local community, lessening the transportation carbon footprint.

·      We make use of existing oil pipelines to move our oil.

 

Health and safety

Our daily operations prioritise health and safety and protecting the environment and we seek to comply with all applicable health and safety related regulations.

SOCIAL

Since the Group's formation in 2006, the social obligations payments made principally to the authorities in the regions in which the group operates have funded a range of projects for the benefit of the local communities concerned.

GOVERNANCE

Introduction

Overall responsibility over the Group's corporate governance, risk management, market disclosure and related obligations rests with the Board.

Recently, as noted elsewhere in these financial statements, the Group has struggled to operate the board committee system set out below because of the small size of the board. Accordingly, in recent times the board as a whole has considered many of the issues typically previously dealt with by board committees.

Committee composition

The Governance & Risk Committee now comprises Clive Carver and Aibek Oraziman with Clive Carver acting as chairman. The committee typically meets at least once a year to review the Group's governance procedures compared to accepted industry best practice.

At the appropriate time the Board plans to include a formal risk register including all the principal operational and non-operational risks to the business to be considered by the Governance & Risk Committee.

Share dealing policy

The Group has adopted and operates a share dealing code for Directors and employees in accordance with the AIM Rules.

Internal controls

The Board acknowledges responsibility for maintaining appropriate internal control systems and procedures to safeguard the shareholders' investments and assets, employees and the business of the Group. The Board also intends to periodically review the Group's financial controls and operating procedures.

Internal audit

The Board does not consider it appropriate for the current size of the Group to establish an internal audit function. However, this will be kept under review.

Bribery and corruption

The UK Bribery Act 2010 came into force on 1 July 2011.

The Company is committed to acting ethically, fairly and with integrity in all its endeavours and compliance with legislation is monitored. The principal terms of the UK Bribery Act have been translated into Russian and circulated to our Kazakh based staff. Consideration of the UK Bribery Act is a standing item at board meetings.

The Company's culture

Our culture might best be described as one where we strive for commercial success while treating others fairly and with respect. The Board firmly believes that sustained success will best be achieved by following this simple philosophy. Accordingly, in dealing with each of the Group's principal stakeholders, we encourage our staff to operate in an honest and respectful manner. We also believe in getting proper value for money spent and believe this goes hand in hand with being a low-cost operator.

Kazakhstan plays an important part in the Group's culture. It is where we operate; where almost all staff are based; it is the nationality of most staff and of the majority of shareholders.

The Group is committed to promoting a culture based on ethical values and behaviours across the business. Policies are in place covering key matters such as equality, protection of sensitive information, conflicts of interest, whistleblowing and health and safety as well as environmental concerns.

QCA Code

Caspian Sunrise, in line with most AIM companies, elected to apply the rules of the Quoted Companies Alliance (QCA) Corporate Governance Code ("QCA Code"), which is based around 10 broad principles.

Principle 1   Establish a strategy and business model which promotes long term value for shareholders	Objective Caspian Sunrise's objective is to create shareholder value from the development of oil and gas projects and associated activities.   The Group has a number of secondary objectives, including promoting the highest level of health and safety standards, developing our staff to their highest potential and being a good corporate citizen in our chosen countries of operations.   Strategy The Group's long-term strategy is to build shareholder value by assembling an attractive portfolio of oil & gas and mineral exploration and production assets in Central Asia, and more particularly in Kazakhstan where the board has the greatest experience. The Group is also exploiting associated opportunities, such as oilfield services and commodity trading, where the board believes it can add significant value and contribute towards the success of the Group as a whole.   Our business model Our business model is to invest in and develop promising oil & gas, mineral and other projects. Success in the long term will be measured by a sustainable appreciation in the Group's profitability and the Company's share price.   Principal assets The Group's principal asset is its 99% interest in the BNG Contract Area, which is in the west of Kazakhstan, 40 kilometres southeast of Tengiz on the edge of the Mangistau Oblast.   The Group is in the process of acquiring Block 8, an oilfield with many of the characteristics of BNG and is 160 km away. The Group has also agreed to acquire the West Shalva Contract Area, an oilfield expected to be easier to develop than either BNG or Block 8 and nearer road and refinery infrastructure but without the deep prospects of BNG and Block 8.   The Group owns the Caspian Explorer, a purpose built drilling vessel designed to explore the shallow reaches of the Caspian Sea. The Caspian Explorer has a construction cost of approximately $200 million in 2012 and a replacement cost believed to be approximately $300 million today.   The Group also has a 100% interest in the 3A Best Contract Area, although the licence there has expired.   Further acquisitions are expected.
Principle 2   Seek to understand and meet shareholder needs and expectations	Shareholder communications   The Company communicates with its shareholders via RNS announcements, its website, formal company meetings and periodic investor presentations. However, the need to avoid selectively releasing price sensitive information often limits our ability to provide the answers many investors seek.   The Company's management meets prospective institutional investors from time to time to assess the availability of large-scale institutional funding to advance the Group's plans.   Our shareholders A large proportion of the Company's shares are held by a relatively small group, namely: The Oraziman family (48.3%); Korean shareholders (9.97%); shareholders in Switzerland (4.91%); shareholders in the UAE (4.91)%; with the remaining (31.91)% being principally other Kazakh or UK based investors.   There is a contact form available for investors to use on the website: https://www.caspiansunrise.com/contact/contact-form/
Principle 3   Take into account wider stakeholder and social responsibilities and their implications for long term success	Our stakeholders   In addition to our shareholders the Company regards its employees and their families, local and national government, suppliers and customers to be the core of the wider stakeholder group.   Employees Almost all staff employed by the Group are based in Kazakhstan. The Group draws most of its field workers from the Mangistau region where alternative employment opportunities are limited. At our head office in Almaty we employ further staff, some of whom hold highly skilled positions.   As well as providing employees with appropriate remuneration and other benefits together with a safe and enjoyable working environment, the Board recognises the importance of communication with employees to motivate them and involve them fully in the business. For the most part, this communication takes place at a local level, but staff are kept informed of major developments through email updates and staff meetings.   Local communities The Group has provided significant financial support to the Mangistau region for over a decade by way of social payments sometimes delivered in the form of medical or educational facilities for the local population.    Part of our work programme obligations are paid in the form of contributions to local social programmes. We are pleased to have assisted in the development of these projects and look forward to contributing to others in the coming years.     Kazakh Government agencies and regulators The Kazakh authorities are responsible for granting licences to explore for and produce oil. Licences are awarded subject to agreed work programmes being adhered to over the period of each licence renewal. This includes compliance with rules designed to preserve the environment.   Caspian Sunrise has an extremely high proportion of Kazakh nationals in our workforce and among our core shareholder group. The Board believes that this helps create a positive relationship with the Kazakh authorities and has assisted in the Group's day-to-day dealings with regulators.   External stakeholders Many additional jobs have been funded in the Company's suppliers, partners and professional advisers.   Feedback The Company considers feedback from its stakeholders in its decisions and actions.
Principle 4   Embed effective risk management, considering both opportunities and threats, throughout the organisation	Risk assessment   Oil & gas and mining exploration and production are dangerous activities and as such are necessarily subject to an extreme health and safety regime.  Risk assessment and evaluation is an essential part of the Company's planning and an important aspect of the Company's internal control system.   It is planned to introduce a formal risk register, including all the principal operational and non-operational risks to the business. Such a risk register would be reviewed and assessed at least once a year by the Audit Committee.   A summary of the principal risks facing the Group are set out in the Principal Risks section on page 35 of these Financial Statements.   As stated elsewhere in these financial statements, the relatively small size of the board and the lack of independent non-executive directors makes the operation of the board committee systems envisaged under the QCA code very difficult to follow.  The board intends to address this with the appointment of additional and independent non-executive directors
Principle 5   Maintain the board as a well-functioning, balanced team led by the chair	Board composition   The board currently comprises three executive directors and one non-executive director. All are male with two Kazakh nationals, one South Korean national and a national from the United Kingdom.   Executive directors At the executive level Kuat Oraziman, Chief Executive Officer, and Seokwoo Shin Chief Operating Officer run the Company's operations in Kazakhstan with Clive Carver, Chairman and Chief Financial Officer, taking the lead on financial and non-operational matters including all aspects related to the listing of the Company's shares on AIM, Corporate Governance compliance and Investor Relations.   Kuat Oraziman is a trained geologist and member of the Academy of Sciences. He has nearly 30 years oil and gas experience in Kazakhstan.   Seokwoo Shin worked for the Korean National Oil Corporation from 1987 until 2018 with spells in Korea, the United Kingdom, Russia and most recently Kazakhstan, where he was responsible for KNOC's Kazakh oil fields. He joined Caspian Sunrise in 2018.   Clive Carver is a fellow of the Institute of Chartered Accountants in England and Wales (FCA) and a Fellow of the Association of Corporate Treasurers (FCT). While working in the UK broking industry Clive gained more than 15 years' experience as a Qualified Executive under the AIM Rules having led the Corporate Finance departments of several of the larger and more active Nominated Adviser firms.   Non-executive director Aibek Oraziman, is the Company's largest shareholder with 46.4% of the Company's shares. He has more than 14 years oil and gas experience in Kazakhstan, including 3 years in the field at Aktobe working for a local oil company.   The board believes it possesses the skills required to build a successful and durable oil and gas business focused on Kazakhstan.   The board meets a minimum of four times each year supported by periodic telephone meetings. At such meetings the board receives a report from Kuat Oraziman on all matters operational and from Clive Carver on non-operational matters.   The board also has a list of standing items, including compliance with the UK Bribery Act, litigation, and existence of open and closed periods for director dealings, which are considered at each meeting.   The number of board meetings attended each year by the directors is set out in the Directors' report which forms part of the Annual Report and Financial Statements.   Board committees   While the Audit, Remuneration and Governance committees remain in place, but with only four directors and only one non-executive director much of the work typically undertaken in the board committees has been handled by the board as a whole.   We expect to make additional appointments to board as funding improves later in the year that would help move back to a more traditional board committee set up.   Departures from the Code   Executive Chairman The principal reason advanced by proponents of the Code that the Chairman be non-executive is to split the roles of Chairman and Chief Executive Officer as combining them puts too much control in one pair of hands. This is not the case with our Company where the Chief Executive Officer's family is the largest shareholding group, with some 48.3%.   Clive Carver was appointed Non-Executive Chairman of the Company in 2006 in the lead-up to the IPO the following year. In 2012 he was appointed Executive Chairman at the same time as Kuat Oraziman moved from Non-Executive Director to Chief Executive Officer.   Clive Carver has served as non-executive chairman of eight AIM listed companies. In addition, his 15 years as a Qualified Executive and head of active corporate finance departments make him a very suitable candidate to be Chairman, notwithstanding his executive status.   Non-Executive Directors' participation in Option Schemes In common with many AIM listed companies we actively encourage non-executive directors to participate in the Company's option schemes, although it is not currently the case. Proponents of the Code believe this affects the independence of the non-executive directors concerned.   We believe that independence is a matter of independence of mind, judgement, and integrity. We consider our non-executives' ability to act independently to be unaffected by the level of participation in the Company's option scheme.
Principle 6   Ensure that between them the directors have the necessary up-to-date experience, skills, and capabilities.	Experience   The experience of the directors and the operational board is set out in the response to Principle 5 above and in the Annual Report and Financial Statements.   Operational skills are maintained through an active day to day interaction with leading international consultancies and contractors engaged to assist in the development of the Company's assets.   Non-operational skills are maintained principally via the Company's interaction with its professional advisers plus the experience gained from sitting on the boards of other commercial enterprises.   As the Company develops and moves from predominantly an oil exploration company to a balanced production and exploration company with both oil & gas and mining projects, the board will periodically re-assess the adequacy of the skills on both the main board and the operational board. Where gaps are found, new appointments will be sought.
Principle 7   Evaluate board performance based on clear and relevant objectives, seeking continuous improvement	Performance   The Company currently does not evaluate board performance on a formal basis. However, it will in due course seek to formalise the assessment of both executive and non-executive board members.   The Company is aware of its need to facilitate succession planning and the board evaluation process will form part of this going forward.
Principle 8   Promote a corporate culture that is based on ethical values and behaviours.	Culture   Our culture can best be described as one where we strive for commercial success while treating others fairly and with respect. The board firmly believes that sustained success will best be achieved by following this simple philosophy.   Accordingly, in dealing with each of the Company's principal stakeholders, we encourage our staff to operate in an honest and respectful manner.   Operating with integrity is clearly good business and forms an important part of the annual assessment of staff and in setting their pay for future periods.
Principle 9   Maintain governance structures and processes that are fit for purpose and support good decision-making by the board	Governance   The Company believes that its stated governance structures and processes are consistent with its current size and complexity, while acknowledging the size of the board as currently constituted makes adherence to such a governance regime difficult in practice.   The Board is aware that it must continue to review its practices as the Company evolves and grows and intends to make further appointments to the board as circumstances permit.   The executive members of the Board have overall responsibility for managing the day-to-day operations of the Company and the Board as a whole is responsible for implementing the Company's strategy.   The Audit Committee typically meets before each set of results (interim and final) are published  and the Remuneration Committee typically meets at least once a year, when the Financial Statements for the Full year results are approved. All Committee members attend these meetings.   Our Report and Accounts contain reports from the Chairman of the Remuneration. and the Audit Committee.   The appropriateness of the Company's governance structures will be reviewed annually in light of further developments of accepted best practice and the development of the Company.
Principle 10   Communicate how the company is governed and is performing by maintaining a dialogue with shareholders and other relevant stakeholders	Communications   The Company reports formally to its shareholders and the market twice each year with the release of its interim and full year results.   The Annual Report and Financial Statements set out how the corporate governance of the Company has been applied in the period under review including the work undertaken by the Audit Committee and the Remuneration Committee.   The Annual Report and Financial Statements contain full details of the principal events of the relevant period together with an assessment of current trading and prospects. They are sent to shareholders and made available on the Company's website to anyone who wishes to review them.   The Board already discloses the result of general meetings by way of RNS announcements, disclosing the voting numbers. The Company's website also contains all the information prescribed for an AIM Company under Rule 26.   Further details of the Company's dialogue with its shareholders are set out under Principle 2 above.   Employee stakeholders are regularly updated with the development of the Company and its performance.   We are in almost constant communication with our Governmental and regulatory stakeholders via their involvement in our day-to-day operational activities.

 

Board composition, skills and capabilities

From 1 January 2023 to 7 July 2023 the Board comprised three executive directors and two non-executive directors. From 8 July 2023 following the resignation of Edmund Limerick until 31 December 2023, the Board comprised three executive directors and one non-executive director, which remains the position at the date of this report.

Clive Carver, Executive Chairman and Chief Financial Officer

Clive is a fellow of the Institute of Chartered Accountants in England and Wales (FCA) and a Fellow of the Association of Corporate Treasurers (FCT). He is an experienced public company director having been chairman of a number of AIM companies in recent years.

Kuat Oraziman, Chief Executive Officer

Kuat Oraziman runs the Company's operations in Kazakhstan. Kuat Oraziman is a trained geologist and member of the Academy of Sciences. He has nearly 30 years oil and gas experience in Kazakhstan.

Seokwoo Shin, Chief Operating Officer

Seokwoo Shin was educated at Sungkyunkwan University in Korea.  He worked for the Korean National Oil Corporation from 1987 until 2019 with spells in Korea, the United Kingdom, Russia and most recently Kazakhstan, where he was responsible for KNOC's Kazakh oil fields. He joined Caspian Sunrise in 2018 and on 4 March 2021 was appointed to the board as Chief Operating Officer.

Aibek Oraziman, Non-executive director

Aibek Oraziman was educated in Kazakhstan and in the United Kingdom. He has more than 14 years oil and gas experience in Kazakhstan, including 3 years in the field at Aktobe working for a local oil company. He was appointed to the Caspian Sunrise board on 21 August 2020.

The Board believes it possesses the skills required to build a successful and durable oil and gas business focused on Kazakhstan but recognises the need for the appointment of additional non-executive directors.

Board and committee meetings

Attendances of Directors at board and committee meetings convened in the year, and which they were eligible to attend in person or by telephone, are set out below:

Director	Board meetings attended	Remuneration Committees attended	Audit Committee attended
Clive Carver	5 of 5	1 of 1	2 of 2
Kuat Oraziman	5 of 5	N/A	N/A
Edmund Limerick	3 of 3	1 of 1	2 of 2
Seokwoo Shin	5 of 5	N/A	N/A
Aibek Oraziman	5 of 5	1 of 1	2 of 2

 

The Board has established the following committees:

Audit Committee

The Audit Committee which comprises Aibek Oraziman and Clive Carver, with Clive Carver as acting Chairman, determines and examines any matters relating to the financial affairs of the Group including the terms of engagement of the Group's auditors and, in consultation with the auditor, the scope of the audit.

The Audit Committee receives and reviews reports from the management and the external auditor of the Group relating to the annual and interim amounts and the accounting and internal control systems of the Group. In addition, it considers the financial performance, position and prospects of the Group and the Company and ensures they are properly monitored and reported on.

Remuneration Committee

The Remuneration Committee, which comprises Aibek Oraziman and Clive Carver, with Aibek Oraziman as Chairman, reviews the performance of the senior management, sets and reviews their remuneration and the terms of their service contracts and considers the Group's bonus and option schemes.

 

 

Board committee membership in 2023

Director	Audit Committee		Remuneration Committee		Corporate Governance Committee
	Served from	Served to	Served from	Served to	Served from	Served to
Clive Carver	1 January	31 December	1 January	31 December	1 January	31 December
Kuat Oraziman	N/A	N/A	N/A	N/A	N/A	N/A
Edmund Limerick	1 January	7 July	1 January	7 July	1 January	7 July
Seokwoo Shin	N/A	N/A	N/A	N/A	N/A	N/A
Aibek Oraziman	1 January	31 December	1 January	31 December	1 January	31 December

 

Clive Carver

Chairman

15 July 2024

 

 

REMUNERATION COMMITTEE REPORT

Remuneration Committee

Between 1 January 2023 and 7 July 2023, the Remuneration Committee comprises Edmund Limerick, Aibek Oraziman and Clive Carver and was chaired by Edmund Limerick. From 8 July 2023 the Remuneration Committee comprised Aibek Oraziman and Clive Carver, with Aibek Oraziman as Chairman.

Remuneration policy

The Remuneration Committee determines the contract term, basic salary, and other remuneration for the members of the Board and the senior management team.

The Group's and the Company's policy is to provide remuneration packages that will attract, retain and motivate its executive Directors and senior management. This consists of a basic salary, ancillary benefits and other performance-related remuneration appropriate to their individual responsibilities and having regard to the remuneration levels of comparable posts. However, starting in 2020 the Covid-19 impact on the Group's finances required the Directors to accept reductions of up to 75% of contracted salary which continues to be the case.

Agreement has been reached to begin to relax the salary reductions as the Group's funding position improves with the first relaxation expected in Q3 2024.

Service contracts

Details of the current Directors' service contracts are as follows:

Executive		Date of service agreement / appointment letter	Date of last renewal of appointment
Clive Carver		20 March 2019	27 June 2024
Kuat Oraziman		6 December 2019	30 June 2023
Aibek Oraziman		21 August 2020	30 June 2023
Seokwoo Shin		4 March 2021	30 June 2023

 

Notwithstanding their service agreements or letters of appointment the directors who served throughout the period under review have agreed until further notice to restrict their remuneration to approximately 25% of previous amounts without any accrual for the up to 75% sacrificed.

Basic salary and benefits

The basic salaries of the Directors who served during the financial year are established by reference to their responsibilities and individual performance.

Directors	Role	2023 Salary / fees US$	Terminated benefits US$		2023 Benefits US$	2023 Total US$	2022 Total US$
Clive Carver	Chairman	152,698		-	9,805	162,503	152,698
Kuat Oraziman	CEO	145,484		-	-	145,484	156,753
Seokwoo Shin	COO	55,000		-	-	55,000	54,000
Edmund Limerick #	Non-executive	5,882		66,500	-	72,382	16,319
Aibek Oraziman	Non-executive	10,000		-	-	10,000	-
Total		369,064		66,500	9,805	445,369	379,770

# Edmund Limerick resigned as a director effective from 7 July 2023.

There were no company pension contributions in respect of any director.

Bonus schemes

All Executive Directors are eligible for consideration of participation in the Company bonus scheme.  However, as in previous years no bonuses are payable in respect of the year ended 31 December 2023 (2022: nil).

Long term incentives

Share options

The current interests as at approval of accounts of the current Directors in share options agreements are as follows:

Directors	Granted	Exercise price (p)	Expiry Date
Clive Carver	2,400,000	4	30 April 2025
Clive Carver	3,000,000	20	21 August 2024
Kuat Oraziman	3,000,000	20	21 August 2024
Seokwoo Shin	2,500,000	4	24 April 2034

 

The position as set out in the 2022 financial statements was as follows:

Directors		Granted	Exercise price (p)		Grant date	Expiry Date
Clive Carver	2,400,000		4.0	15 December 2013			14 December 2023
Clive Carver	3,000,000		20.0	22 August 2014			21 August 2024
Kuat Oraziman	3,000,000		20.0	22 August 2014			21 August 2024
Edmund Limerick	750,000		20.0	22 August 2014			21 August 2024
Edmund Limerick	1,000,000		20.0	6 June 2019			5 June 2029
Edmund Limerick	1,000,000		5.5	10 January 2022			9 January 2032
Seokwoo Shin	2,500,000		5.5	10 January 2022			9 January 2032

 

The exercise date of 2,400,000 options held by Clive Carver, which were not capable of exercise before the expiry date of 14 December 2023 as the Company was in an extended close period, have been extended until 30 April 2025.

There were no options exercised in 2023. To date in 2024, 4,500,000 options have been granted including on 24 April 2024, 2,500,000 options granted to Seokwoo Shin at an exercise price of 4.0p. At that time 2,500,000 options then held by Seokwoo Shin, exercisable before 9 January 2032 were cancelled.

The total number of options at the date of this report is 16,850,000 representing approximately 0.75% of the total number of issued shares.

Cash based incentives

In May 2019, we introduced cash based long term incentive arrangements for the senior management team since 2012, Kuat Oraziman and Clive Carver.

Under these arrangements, provided the share price growth exceeds pre-set targets starting at 17.23p, then for every $500 million increase in the Group's market capitalisation above $300 million, as adjusted to take account of dividends paid, both Kuat Oraziman and Clive Carver, would receive payments of $3 million each.

The principal hurdles under these arrangements are set out in the table below.

Market cap threshold	Share price target	Pay-out rate (each)	Pay-out amount (each)
$' billion	Pence per share	%	$' million
0.8	17.23	0.6	3.0
1.3	20.67	0.6	3.0
1.8	24.81	0.6	3.0
2.3	29.77	0.6	3.0
2.8	35.72	0.6	3.0

 

The scheme continues beyond the numbers in the table such that with the threshold for market capitalisation increasing at the rate of $0.5 billion and the corresponding share price threshold increasing from the earlier threshold by a constant factor of 1.2.

Each threshold must be sustained for at least 30 consecutive days for the awards to be triggered. There may be only one pay-out for each market capitalisation threshold crossed no matter how many times it is crossed.

Whilst the Incentive Scheme is in place neither of the recipients will be granted any further options.

On behalf of the Directors of Caspian Sunrise plc

 

Aibek Oraziman

Chairman of Remuneration Committee

15 July 2024

AUDIT COMMITTEE REPORT

The Audit Committee

The Audit Committee, which between 1 January and 7 July 2023 comprised Edmund Limerick, Clive Carver and Aibek Oraziman, with Edmund Limerick acting as Chairman, and from 8  July 2023 comprised Clive Carver and Aibek Oraziman with Clive Carver as Acting Chairman, determines and examines any matters relating to the financial affairs of the Group including the terms of engagement of the Group's auditors and, in consultation with the auditor, the scope of the audit.

Role and responsibilities

The Audit Committee is responsible for monitoring the integrity of the Company's financial statements, reviewing significant financial reporting issues, reviewing the effectiveness of the Group's internal control and risk management systems.

In addition, it considers the financial performance, position and prospects of the Group and the Company and ensures they are properly monitored and reported on. It oversees the relationship with the Auditor (including advising on their appointment, agreeing the scope of the audit and reviewing the audit findings).

Meetings

The committee met on two occasions during the year under review.

Internal audit

The Board and the Audit Committee do not consider it appropriate for the current size of the Group to establish an internal audit function. However, this will be kept under review.

Attendance at Audit Committee meetings

Please see the table in the preceding Corporate Governance Report for attendance by the members of the Audit Committee.

Group auditors

In October 2023 PKF Littlejohn LLP were appointed Group auditors, replacing BDO LLP.

 

On behalf of the Directors of Caspian Sunrise plc

 

Clive Carver

Acting Chairman of Audit Committee

15 July 2024

 

 

 

 

 

 

 

 

 

 

 

 

 

INDEPENDENT AUDITORS REPORT TO THE MEMBERS OF CASPIAN SUNRISE PLC

Qualified opinion on the Group financial statements and unmodified opinion on the Parent Company financial statements

We have audited the financial statements of Caspian Sunrise plc (the 'Parent Company') and its subsidiaries (the 'Group') for the year ended 31 December 2023 which comprise the Consolidated Statement of Profit or Loss, the Consolidated Statement of Comprehensive Income, the Consolidated and Parent Company Statements of Changes in Equity, the Consolidated and Parent Company Statements of Financial Position, the Consolidated and Parent Company Statements of Cash Flows and the notes to the financial statements, including a summary of significant accounting policies. The financial reporting framework that has been applied in their preparation is applicable law and UK adopted international accounting standards and as regards the Parent Company financial statements, as applied in accordance with the provisions of the Companies Act 2006.

In our opinion, except for the effects of the matter described in the Basis for qualified opinion section on the Group financial statements and unmodified opinion on the Parent Company financial statements section of our report:

·      the financial statements give a true and fair view of the state of the Group's and of the Parent Company's affairs as at 31 December 2023 and of the Group's profit for the year then ended;

·      the Group financial statements have been properly prepared in accordance with UK adopted international accounting standards;

·      the Parent Company financial statements have been properly prepared in accordance with UK adopted international accounting standards and as applied in accordance with the provisions of the Companies Act 2006; and

·      the financial statements have been prepared in accordance with the requirements of the Companies Act 2006.

 

Basis for qualified opinion on the Group financial statements and unmodified opinion on the Parent Company financial statements

In 2023, 2022 and 2021, the Group's subsidiary, CTS LLP, provided drilling services to both an external related party, EPC Munai LLP, and within the Group to fellow subsidiary BNG Ltd LLP. 

For drilling services provided to external entities, costs should be recognised in cost of sales, which impacts the amount of revenue recognised under the input method as detailed in notes 1.5 and 1.6. Drilling costs provided to other entities in the Group may be capitalised, subject to compliance with relevant accounting standards as detailed in notes 1.9 and 1.10. 

The prior year audit report, which was issued by the predecessor auditor, contained a qualified opinion in respect of the Directors being unable to obtain reliable information for CTS LLP in respect of the timing of the related direct costs being incurred, their allocation between different contracts with EPC Munai LLP, and whether the costs should have been allocated to cost of sales (which impacts external revenue recognised), or capitalised in the Group's Property Plant and Equipment or Unproven oil and gas assets. In addition, the Directors were unable to provide updated budgets for estimated costs to complete. This information is necessary to determine revenue, costs of sales, advances received/ receivable, provisions for losses on contracts, property, plant and equipment, unproven oil and gas assets, related tax balances and related party disclosures and as a result the predecessor auditor concluded that these balances may be materially higher or lower than those reported in the signed 2022 financial statements.

Following the issue of the 2022 financial statements, and as explained in note 3, management performed a detailed review of CTS LLP's books and records relating to its drilling contracts. As a result, a number of adjustments to previously reported balances were required, and restatements made to relevant line items in relation to the 2022 and 2021 financial years, as shown and explained further in note 3.

Following this review by management, included in the Group's revenue in 2023 is USD 4,126,000 (2022 restated: USD 1,590,000) of drilling revenue related to contracts with EPC Munai LLP and USD 4,735,000 (2022 restated: USD 1,834, 000) of related cost of sales.

We have reviewed the exercise performed by management relating to the adjustments to the 2022 and 2021 financial statements and, based on the information provided, have been unable to gain sufficient assurance surrounding the basis for cost allocation between the various contracts with EPC Munai LLP, or the timing of these costs being incurred, both of which drive the revenue recognition for each year. As a result, we are unable to conclude whether or not the impacted line items in the 2022 financial statements, as restated (see note 3) are materially misstated. We have therefore also been unable to obtain sufficient appropriate audit evidence over the accuracy of the Group's external drilling revenues or the completeness and validity of its cost of sales allocation for the 2023 financial year. Our opinion is therefore qualified in respect of these matters. The contracts with EPC Munai LLP were concluded before the 2023 year end and therefore we are satisfied based on work performed that the closing Group statement of financial position is materially correct.

We conducted our audit in accordance with International Standards on Auditing (UK) (ISAs (UK)) and applicable law. Our responsibilities under those standards are further described in the Auditor's responsibilities for the audit of the financial statements section of our report. We are independent of the company in accordance with the ethical requirements that are relevant to our audit of the financial statements in the UK, including the FRC's Ethical Standard as applied to listed entities, and we have fulfilled our other ethical responsibilities in accordance with these requirements. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our qualified opinion.

Material uncertainty in relation to going concern

We draw attention to note 1.1 in the financial statements concerning the Group's and the Parent Company's ability to continue as a going concern. Note 1.1 highlights that the Group has significant net current liabilities of approximately USD 14,300,000 as at the year end, and that the forecast cashflows are dependent on key factors including ,oil price and volume sold, continued availability of oil trader advances, deferral of financial obligations and the receipt of funds from the charter of the Caspian Explorer. As stated in note 1.1, these events or conditions, along with other matters as set out in note 1.1, indicate that a material uncertainty exists that may cast significant doubt on the Group's and the Parent Company's ability to continue as a going concern. Our opinion is not modified in respect of this matter.

In auditing the financial statements, we have concluded that the Directors' use of the going concern basis of accounting in the preparation of the financial statements is appropriate. Our evaluation of the Directors' assessment of the Group's and the Parent Company's ability to continue to adopt the going concern basis of accounting included:  

·       Obtaining the directors' going concern assessment and evaluating the appropriateness of this assessment;

·       Obtaining cashflow forecasts for the period to 31 December 2025 used to support this assessment, ascertaining the key assumptions and inputs used in the preparation of the forecasts, and assessing the reasonableness of such assumptions and inputs. This included, where possible, agreeing the inputs to underlying supporting documentation, and sensitising key assumptions;

·       Comparing oil prices to available market data and production levels to historic operating information;

·       Comparing forecast income and expenses with recent historical financial information to consider the accuracy of management's forecasting; 

·       Agreeing cash balances to the opening working capital position and testing the mathematical accuracy of the forecasts;

·       Considering external market factors affecting the Group and its future economic viability, such as oil prices and the ongoing lack of viability of international sales as a result of the sanctions imposed against Russia;

·       Evaluating the completeness of forecast licence related expenditure included in the forecasts. We held discussions with the Directors and those charged with governance regarding the intention to seek a 2 year extension to the appraisal licence covering the Airshagyl an Yelemes Deep structures before then applying for separate 25 year production licences;

·       Comparing the forecast cash payments in respect of the BNG production licence award against the USD 32,000,000 assessment received from the Government payable in instalments over 10 years.  We ensured that the relevant instalments are included in the forecast;

·       Assessing the reasonableness of cash inflows included in the forecasts including those relating to oil production and the Group's maiden offshore drilling chartering contract for the Caspian Explorer, including agreement to the underlying contract for the latter;

·       Evaluating the possibility of obtaining cash through sale of key assets, and examined available documentation as well as publicly available announcements in respect of these matters;

·       Assessing the validity of any mitigating actions identified by the Directors; and

·       Reviewing the adequacy and completeness of the disclosures included within the financial statements in respect of going concern based on our understanding of the business and the Group's current financial position, and the uncertainties surrounding the going concern position.

 

Our responsibilities and the responsibilities of the Directors with respect to going concern are described in the relevant sections of this report.

Our application of materiality

We apply the concept of materiality in both planning and performing the audit and evaluating the effect of misstatements. Based on our professional judgement, we determined materiality for the financial statements as follows:

	Group financial statements	Parent Company financial statements
Materiality	USD 1,960,000	USD 1,170,000
Basis for determining materiality	1.5% of gross assets	3% of net assets, capped below group Performance materiality
Rationale for the benchmark applied	We have determined an asset based measure is appropriate as the Group continues to focus on the development of its key oil and gas exploration and production activities, which require significant capital expenditure.	The Parent Company is a holding company; therefore, materiality was set on the net assets basis.

 

Performance materiality

We set performance materiality at a level lower than materiality to reduce the probability that, in aggregate, uncorrected and undetected misstatements exceed the materiality for the financial statements as a whole.

	Group financial statements	Parent Company financial statements
Performance materiality	USD 1,176,000	USD 702,000
Basis for determining materiality	60% of materiality	60% of materiality
Rationale for the benchmark applied	Performance materiality for the current year was set based our assessment of the control environment including identified control deficiencies.

 

Our audit procedures were performed to materiality levels applicable to each component, which were lower than the Group materiality level and ranged from USD 290,000 to USD 1,170,000.

In the audit of each component, we further applied performance materiality levels of 60%  of the component materiality to our testing to ensure that the risk of errors exceeding component materiality was appropriately mitigated.

We agreed with those charged with governance that we would report to them all audit differences identified during the course of our audit in excess of USD 98,000. We also agreed to report any other audit misstatements below that threshold that we believe warranted reporting on qualitative grounds.

Our approach to the audit

Our audit approach was developed by obtaining an understanding of the Group's and Parent Company's activities, the key subjective judgments made by the directors, for example in respect of the significant accounting estimates regarding the valuation of unproven oil and gas assets and the accounting treatment of CTS LLP drilling contracts, considering future events that are inherently uncertain, and the overall control environment. Based on this understanding we assessed those aspects of the Group's and Parent Company's transactions and balances which were most likely to give rise to a material misstatement and were most susceptible to irregularities including fraud or error. Specifically, we identified what we considered to be key audit matters and planned our audit approach accordingly.

The Group's operations principally comprise oil and gas exploration and production in Kazakhstan. We assessed there to be five significant components comprising BNG Ltd LLP, CTS LLP, KC Caspian Explorer LLP, Roxi Petroleum Kazakhstan LLP, and the Parent Company. These components, which were subject to full scope audit procedures, represent the principal business units. 

A non-PKF member firm performed a full scope audit of BNG Ltd LLP, CTS LLP, KC Caspian Explorer LLP and Roxi Petroleum Kazakhstan LLP in Kazakhstan, under our direction and supervision as Group auditors. The audit of the Parent Company and the Group consolidation were performed in the United Kingdom by us.

The remaining components of the Group were considered non-significant and these components were subject to either specified audit procedures by the component auditor, to address risks assessed at the Group level or to gain comfort over material items, or analytical review procedures by the Group audit team.  The Group audit team performed additional procedures in respect of certain significant risk areas that represented Key Audit Matters.

Our involvement with component auditors included the following:

•    Detailed Group reporting instructions were sent to the component auditors, which included the significant areas to be covered by the audit. 

•    We reviewed the component auditor's working papers, both in Kazakhstan and remotely from the UK.  In addition, we  reviewed the Group reporting submissions received from the component audit teams and held regular calls with the component audit teams during the planning, fieldwork and completion phases of their audit to discuss significant findings from their audit. 

•    We performed additional procedures in respect of the significant risk areas where deemed necessary.

Key audit matters

Key audit matters are those matters that, in our professional judgment, were of most significance in our audit of the financial statements of the current period and include the most significant assessed risks of material misstatement (whether or not due to fraud) we identified, including those which had the greatest effect on the overall audit strategy, the allocation of resources in the audit; and directing the efforts of the engagement team. These matters were addressed in the context of our audit of the financial statements as a whole, and in forming our opinion thereon, and we do not provide a separate opinion on these matters.  In addition to the matter described in the Material uncertainty related to going concern section, and the matter disclosed in the Basis for qualified opinion section, we have determined the matters described below to be the key audit matters to be communicated in our report.

Key Audit Matter - Valuation of unproven oil and gas assets [Note 12] The carrying value of Group's unproven oil and gas assets as at 31 December 2023 was USD 51,963,000. In accordance with IFRS 6 Exploration for and Evaluation of Mineral Resources, assets should be held at cost and an annual assessment of impairment indicators performed and, where such indicators exist, perform an impairment assessment in accordance with IAS 36 Impairment. Given the level of management estimates and judgement required in determining the recoverability of these assets, there is a risk that management may not adequately identify all impairment indicators.  As such, there is a risk that the carrying value of these assets is impaired and that exploration and development costs capitalised during the year have not been capitalised in accordance with IFRS 6. As a result of the significant estimates and judgement required to be exercised by management, as well as the quantum of this balance, we consider this to be a key audit matter.  How our scope addressed this matter Our work in this area included: ·      Reviewing the work of the component auditor's testing of additions in the year, as well as performing additional work in this area, such as vouching costs to supporting documentation to ensure that costs have been appropriately capitalised in accordance with IFRS 6 and the Group's accounting policies; ·      Obtaining confirmation that the Group has good title to the applicable exploration licences, and assessing compliance with terms of the licences through making enquiries of management and the legal consultant; ·      Obtaining management's review of indicators of impairment and considering the reasonableness of this assessment in accordance with the requirements of IFRS 6. ·      Performing an independent assessment as to whether any of the impairment indicators as per IFRS 6 have been met and if so, whether any impairment is necessary. ·      Inspecting cash flow forecasts to confirm that further drilling and exploration is planned for the licenced areas, as well as reviewing internal and external information available during the year and post-year end such as Board minutes and Regulatory News Service announcements for evidence of potential impairment; ·      Evaluation of the results of exploration activity in the year for indications that the licences would be abandoned or that the recoverable value would be below carrying value; and ·      Reviewing disclosures in the financial statements to ensure compliance with the requirements of IFRS.   Key observations We draw attention to the disclosure within Notes 12 Unproven oil and gas assets and 2.2.2 within the Critical Accounting Estimates and Judgements, which state that the Group's existing appraisal licence will expire in August 2024 and that the Group has in July 2024 submitted an application to extend the licence for a further 2 years. Should the application to extend the licence not be successful, this could result in impairment to valuation of the unproven oil and gas assets.

 

Key audit matter - Accounting treatment of CTS LLP drilling services [Notes 3 and 4; Accounting policies 1.5 and 2.1.2] The accounting treatment of contracts to provide drilling services held within entity CTS LLP with external related party EPC Munai LLP is dependent on the existence of reliable information in respect of the timing of the costs being incurred, their allocation between different contracts and whether costs should have been allocated to cost of sales or capitalised as property plant and equipment. As such, there is a risk that the accounting treatment is not in accordance with IFRS. How the scope of our audit responded to the key audit matter Our work in this area included: •     Obtaining management's schedules relating to the analysis of the accounting treatment of the contracts on a contract-by-contract basis and providing challenge to, and corroborating, key inputs and assumptions being used, including: o  vouching revenue amounts to underlying contracts; o  testing a sample of costs to supporting documentation including confirmation of well number, on which the allocation to contract is based, to confirm accuracy of costs; o  assessing the appropriateness of allocation between contracts, and o  evaluating the reasonableness of allocation between cost of sales (external contracts) and capitalised assets (BNG contracts); •     Considering the appropriateness of revenue recognition in accordance with the requirements of IFRS 15 Revenue from Contracts with Customers for each contract, including reference to the relevant sales agreements and the key terms and conditions within the contracts; •     Performing testing in accordance with IAS 37 Provisions, Contingent Liabilities and Contingent Assets to determine whether any provisions for losses for onerous contracts should be recognised as at 31 December 2023; and •     Reviewing the disclosures in the financial statements to ensure compliance with the requirements of IFRS.   Key observations As explained in the Basis for qualified opinion, we have been unable to conclude as to whether material misstatements are present in the opening balances, nor whether revenue and cost of sales related to external drilling contracts during 2023 are accurate. However, on the basis of the audit procedures performed, we are satisfied that given that all contracts with EPC Munai LLP were concluded before 31 December 2023, the closing statement of financial position is not materially misstated in respect of the CTS LLP drilling contracts.

 

Other information

The other information comprises the information included in the annual report, other than the financial statements and our auditor's report thereon. The Directors are responsible for the other information contained within the annual report. Our opinion on the Group and Parent Company financial statements does not cover the other information and, except to the extent otherwise explicitly stated in our report, we do not express any form of assurance conclusion thereon. Our responsibility is to read the other information and, in doing so, consider whether the other information is materially inconsistent with the financial statements or our knowledge obtained in the course of the audit, or otherwise appears to be materially misstated. If we identify such material inconsistencies or apparent material misstatements, we are required to determine whether this gives rise to a material misstatement in the financial statements themselves. If, based on the work we have performed, we conclude that there is a material misstatement of this other information, we are required to report that fact.

As described in the basis for qualified opinion section of our report, we have concluded that other information may be materially misstated.

Opinion on other matters prescribed by the Companies Act 2006

Except for the matter described in the Basis for qualified opinion on other matters prescribed by the Companies Act 2006 section of our report, in our opinion, based on the work undertaken in the course of the audit:

·      the information given in the Directors' report for the financial year for which the financial statements are prepared is consistent with the financial statements; and

·      the Directors' report have been prepared in accordance with applicable legal requirements.

Based on the responsibilities described below and our work performed during the course of the audit, we are required by the Companies Act 2006 and ISAs (UK) to report on certain opinions and matters as described below.  

Matters on which we are required to report by exception

Notwithstanding our Basis for qualified opinion, in the light of the knowledge and understanding of the company and its environment obtained in the course of the audit, we have not identified material misstatements in the Directors' report.

Arising from the limitation of our work performed in the Basis of qualified opinion section:

·      we were unable to determine whether adequate accounting records have been kept; and

·      we have not received all the information and explanations we require for our audit.

We have nothing to report in respect of the following matters in relation to which the Companies Act 2006 requires us to report to you if, in our opinion:

·      returns adequate for our audit have not been received from branches not visited by us; or

·      certain disclosures of directors' remuneration specified by law are not made.

Responsibilities of Directors

As explained more fully in the Directors' responsibilities statement, the Directors are responsible for the preparation of the financial statements and for being satisfied that they give a true and fair view, and for such internal control as the Directors determine is necessary to enable the preparation of financial statements that are free from material misstatement, whether due to fraud or error.

In preparing the financial statements, the Directors are responsible for assessing the company's ability to continue as a going concern, disclosing, as applicable, matters related to going concern and using the going concern basis of accounting unless the Directors either intend to liquidate the company or to cease operations, or have no realistic alternative but to do so.

Auditor's responsibilities for the audit of the financial statements

Our objectives are to obtain reasonable assurance about whether the financial statements as a whole are free from material misstatement, whether due to fraud or error, and to issue an auditor's report that includes our opinion.  Reasonable assurance is a high level of assurance, but is not a guarantee that an audit conducted in accordance with ISAs (UK) will always detect a material misstatement when it exists. Misstatements can arise from fraud or error and are considered material if, individually or in the aggregate, they could reasonably be expected to influence the economic decisions of users taken on the basis of these financial statements.

Irregularities, including fraud, are instances of non-compliance with laws and regulations. We design procedures in line with our responsibilities, outlined above, to detect material misstatements in respect of irregularities, including fraud. The extent to which our procedures are capable of detecting irregularities, including fraud is detailed below:

·      We obtained an understanding of the company and the sector in which it operates to identify laws and regulations that could reasonably be expected to have a direct effect on the financial statements. We obtained our understanding in this regard through:

o  Discussing with management, those charged with governance and those responsible for legal and compliance procedures, to understand how the Group is complying with those legal and regulatory frameworks; and

o  Conducting and applying industry research and application of cumulative audit knowledge.

·      We determined the principal laws and regulations relevant to the company in this regard to be those arising from:

o  UK-adopted international accounting standards;

o  Companies Act 2006;

o  AIM Rules and the Quoted Companies Alliance Corporate Governance Code;

o  Relevant industry laws and regulations in Kazakhstan, including relevant environmental regulations associated with oil and gas exploration and production activities;

o  UK and Kazakh taxation and employment laws; and

o  Terms of compliance included in the Group's production and exploration licences.

·      We designed our audit procedures to ensure the audit team considered whether there were any indications of non-compliance by the company with those laws and regulations. These procedures included, but were not limited to:

o  Reviewing minutes of meetings of those charged with governance for any instances of non-compliance with laws and regulations;

o  Reviewing of Regulatory News Service announcements;

o  Directing the auditors of the significant components to ensure an assessment was performed on the extent of the components' compliance with the relevant local and regulatory environment and a review of correspondence with regulatory and tax authorities was performed for any instances of non-compliance with laws and regulations;

o  Reviewing the terms of the licences to assess the extent to which the Group was in compliance with the conditions of the licence and considering management's assessment of the impact of instances of non-compliance where applicable; and

o  Review of legal expenditure accounts to understand the nature of expenditure incurred.

·      We also identified the risks of material misstatement of the financial statements due to fraud. We considered, in addition to the non-rebuttable presumption of a risk of fraud arising from management override of controls, that the areas most susceptible to fraud were revenue recognition, valuation of unproven oil and gas assets and the accounting treatment of CTS LLP drilling services, on the basis that there is potential for management bias as a result of judgement being exercised, and we addressed this by challenging the assumptions and judgements made by management when auditing these areas. See Key audit matters section above.

·      As in all of our audits, we addressed the risk of fraud arising from management override of controls by performing audit procedures which included, but were not limited to: the testing of journals; reviewing accounting estimates for evidence of bias; and evaluating the business rationale of any significant transactions that are unusual or outside the normal course of business. 

Because of the inherent limitations of an audit, there is a risk that we will not detect all irregularities, including those leading to a material misstatement in the financial statements or non-compliance with regulation.  This risk increases the more that compliance with a law or regulation is removed from the events and transactions reflected in the financial statements, as we will be less likely to become aware of instances of non-compliance. The risk is also greater regarding irregularities occurring due to fraud rather than error, as fraud involves intentional concealment, forgery, collusion, omission or misrepresentation.

A further description of our responsibilities for the audit of the financial statements is located on the Financial Reporting Council's website at: www.frc.org.uk/auditorsresponsibilitieshttp://www.frc.org.uk/auditorsresponsibilitieshttp://www.frc.org.uk/auditors/audit-assurance/auditor-s-responsibilities-for-the-audit-of-the-fi/description-of-the-auditor's-responsibilities-forhttps://www.frc.org.uk/auditors/audit-assurance/standards-and-guidance/2010-ethical-standards-for-auditors-(1). This description forms part of our auditor's report.

Use of our report

This report is made solely to the company's members, as a body, in accordance with Chapter 3 of Part 16 of the Companies Act 2006.  Our audit work has been undertaken so that we might state to the company's members those matters we are required to state to them in an auditor's report and for no other purpose.  To the fullest extent permitted by law, we do not accept or assume responsibility to anyone, other than the company and the company's members as a body, for our audit work, for this report, or for the opinions we have formed.

 

 

 

 

 

Imogen Massey (Senior Statutory Auditor)                                                                                        15 Westferry Circus

For and on behalf of PKF Littlejohn LLP                                                                                          Canary Wharf

Statutory Auditor                                                                                                                                   London E14 4HD

 

15 July 2024

 

Consolidated Statement of Profit or Loss
	Notes	Year ended 31 December 2023	*Restated Year ended 31 December 2022
		US$'000	US$'000
Revenue	4	36,651	40,893
Cost of sales		(15,926)	(8,718)
Gross profit		20,725	32,175
Selling expense		(2,993)	(9,751)
Administrative costs		(6,031)	(9,767)
Other operating income	5	3,774	211
Operating profit	5	15,475	12,868
Finance cost	8	(920)	(585)
Finance income	9	231	59
Profit before taxation		14,786	12,342
Tax charge	10	(3,681)	(2,371)
Profit after taxation from continuing operations		11,105	9,971
Profit attributable to owners of the parent		10,590	9,837
Profit attributable to non-controlling interest		515	134
Profit for the year		11,105	9,971
Earnings per ordinary share
Basic (US cents)	11	0.47	0.44
Diluted (US cents)	11	0.47	0.44

*See note 3 for details of prior year restatement.

 

 

                                                                                                                                             

 

 

 

Consolidated Statement of Comprehensive Income

 

 

	Year ended 31 December 2023	*Restated Year ended 31 December 2022
	US$'000	US$'000
Profit after taxation	11,105	9,971
Other comprehensive income, net of tax:
Items that may be subsequently reclassified to profit or loss:
Exchange differences on translating foreign operations	676	(4,407)
Total comprehensive income for the year	11,781	5,564
Total comprehensive profit attributable to:
Owners of parent	11,266	5,430
Non-controlling interest	515	134
Total comprehensive income for the year	11,781	5,564

   * See note 3 for details of prior year restatement.