Caspian Sunrise Regulatory News (CASP)

Caspian Sunrise PLC

("Caspian Sunrise" or the "Company")

Annual Report and Financial Statements for the Year Ended 31 December 2021

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 2021.

Highlights for the year:

Operational:

· Aggregate production for 2021 was 533,857 barrels (2020: 545,667) a decrease of approximately 2.2%

· Reserves at 31 December 2021 P1 15.1 mmbls & P2 26.3 mmbls (2020: P1 15.6 mmbls & P2 26.8 mmbls)

Financial:

· Revenue: up 75% at $25 million (2020: $14.3 million)

· Loss after tax for the year $5.5 million (2020: $3.5 million)

· Cash at bank: $0.4 million (2020: $0.3 million)

· Total assets: $114.2 million (2020: $125.7 million)

· Exploration assets $46.1 million (2020: $61.6 million)

· Plant, property & equipment $57.1 million (2020: $52.8 million)

The Report and Accounts and Notice of a General Meeting to approve the Accounts will shortly be posted to shareholders and available from the Company's website at https://www.caspiansunrise.com/investors/reports

The information contained within this announcement is deemed to constitute inside information as stipulated under the retained EU law version of the Market Abuse Regulation (EU) No. 596/2014 (the "UK MAR") which is part of UK law by virtue of the European Union (Withdrawal) Act 2018. The information is disclosed in accordance with the Company's obligations under Article 17 of the UK MAR. Upon the publication of this announcement, this inside information is now considered to be in the public domain.

CHAIRMAN'S STATEMENT

Introduction

Our company has come through a difficult period in good shape and is set to prosper in the coming years.

We are producing record amounts of oil and selling it at prices greater than at any time since we commenced production. Debt has been paid down or converted to equity and we expect to declare our first dividend later this year. Further, by the end of 2022 we expect to have completed all the mandatory BNG work programme commitments.

With international oil prices well above $100 per barrel the position is a world away from 2020, when we faced $16 per barrel and limited interest in our oil. Over the same period the domestic price of oil has increased from approximately $6 per barrel to approximately $25 per barrel.

Russian sanctions

As with much of Kazakh oil production our oil is transported to international markets via the Russian pipeline network, emerging as "Urals Oil" as our oil was until very recently termed once mixed with Russian oil. While we have not experienced any significant issues in delivering our oil, recent prices for Urals Oil have been some $25 - $35 per barrel below Brent prices.

We firmly believe the Russian pipeline network will remain available to transport our Kazakh oil, however if that were not to be the case, or if the discount to Brent of our oil significantly widens, we would seek alternative distribution options avoiding Russia.

Other delivery destinations include China, Azerbaijan and Uzbekistan with each option involving additional transportation costs. An alternative would be to sell all oil produced on the domestic market. A better alternative would be to sell direct to one of the new mini refineries setting up in the region, which would eliminate a large part of the transportation and delivery costs.

Our expectation however, is that through natural market arbitrage led by those countries not signed up to Russian sanctions such as China, India and other Asian countries, the current discount will significantly reduce.

Also, with a new KEBCO designation for Kazakh oil and the EU confirming that Kazakh oil transported through the Russian pipeline systems is not subject to any sanctions we expect to be able to sell oil to our international oil trader partners in Kazakhstan at prices much closer to Brent.

We estimate the impact of the sanctions related Urals Oil discount to currently be of the order of $30 million per annum based on current production volumes and prevailing international prices. Any reversal of the impact of the Urals Oil discount would flow directly to revenues and a large portion to profits.

As Kazakh economy is closely linked to the Russian economy the value of the Kazakh Tenge could decline against the dollar. While this would affect the price at which we account in US$ for oil sold domestically it would also reduce the US$ reported operating costs incurred in Tenge, which account for approximately 50% of the Group's total costs.

Strategy

To date

Since our IPO in 2007, the Group's strategy has been to exploit oil & gas opportunities in Central Asia, focusing on Kazakhstan where the management team has the most experience.

During that period we have successfully brought into production shallow structures at our flagship asset BNG. During the same period we have completed four of the six deep wells required under the BNG Contract Area work programme commitment, with a fifth well part drilled and the sixth underway and expected to complete in Q4 2022.

Going forward

Our focus will remain on exploiting oil and gas assets in Kazakhstan, in particular at our flagship BNG asset, prioritising production from the shallow structures.

CHAIRMAN'S STATEMENT (CONTINUED)

While we will continue to look at early-stage projects, such as in 2008 when we acquired our interest in BNG, our concentration will be on cashflow positive producing assets and for the right projects we would look beyond Kazakhstan.

A decade ago we looked at alternative energy projects but concluded the returns then available did not match those at BNG. The economics of alternative energy are now markedly better. We are therefore looking over time to become a diversified energy group rather than one focused solely on oil. In particular we are looking at wind energy projects.

Operational Review

BNG

Horizontal drilling

A big positive in the period under review and subsequently has been the successful introduction of horizontal drilling techniques.

Horizontal drilling has been used to improve the production of existing wells and will in the coming months be used in new wells at both the MJF structure and at South Yelemes, where we believe significant volumes of oil may lie at depths as shallow as 2,500 meters.

Shallow structures

All of the oil produced in 2021 was from the MJF structure. The production capacity at the MJF structure has increased to 3,750 bopd, with seven wells producing and a further two wells planned before the year end, including Well 141 which is due to re-enter production shortly following a horizontal drilling workover.

Following the award of the export status at the South Yelemes structure we have been able to re-open wells there, which were shut in for the whole of 2021. The production capacity of these existing wells is approximately 300 bopd. As noted above we plan to drill a new well at a depth of 2,500 meters exploiting horizontal drilling targeting oil in the dolomite.

Our target with these new wells is as soon as possible to increase production capacity to 5,000 bopd solely from our shallow structures.

Deep structures

The three deep wells drilled in previous years on the Airshagyl structure are Wells A5, A6 & A8. The existing deep well on the Yelemes Deep Structure is Well 801.

Funding constraints in the period under review limited the work that we could undertake to bring these wells into production. Little was achieved at Wells A5, A6 and 801. At Well A8, however we drilled from a depth of 4,500 meters to 5,400 meters identifying three oil bearing intervals covering in aggregate 140 meters.

Since the period end we perforated two of the three intervals identified as potentially oil bearing but neither flowed oil at commercial quantities. The rig used at A8 has been reallocated to drill a shallow well on the MJF structure.

A7 is the fourth deep well to be drilled on the Airshagyl structure and the fifth in total. It was spudded in late December 2021 with a planned Total Depth of 5,300 meters targeting oil in the Carboniferous and the Devonian. Drilling reached a depth of 2,150 meters before pausing to allow the rig to be used elsewhere.

The final deep well required under the BNG Work Programme commitment is Deep Well 802, which spudded in June 2022, with a Total Depth of 5,300 meters and will target oil in the Carboniferous and the Devonian and an initial target at a depth of 4,300 meters. At the date of this report drilling had reached 650 meters without incident.

Our approach to BNG

At BNG we have two proven and commercially viable shallow structures, MJF and South Yelemes, and two deep structures Airshagyl and Yelemes Deep with huge potential but to date with no production.

As noted above our plan is to prioritise production from the shallow structures with a series of new wells and workovers of existing wells.

CHAIRMAN'S STATEMENT (CONTINUED)

This does not mean we are moving away from the hugely prospective deep structures at BNG. We already have four deep wells drilled to their total depths, a fifth part drilled and a sixth underway. This is the final deep well required under the BNG work programme commitments, which are expected to be complete before the end of the year.

We continue to believe that the geological conditions at the super giant fields of Kashagan and Tengiz extend to the BNG Contract Area. If this is the case the potential volume of oil in these deep structures is vast and the implications on the Company's fortunes of one or more commercial deep wells would be transformational. We remain committed to bring as many as possible of these six deep wells into production. However, until we are successful in bringing at least one of these six deep wells into production, it is unlikely we will drill any further deep wells at BNG.

Given the current high oil price and the relatively low risk opportunities on our shallow structures our focus is now to maximise cashflow from production.

Own equipment

The move to own the drilling rigs and much of the other equipment previously rented has significantly improved operational efficiency and reduced operating costs. The Covid-19 related prolonged closure of the Chinese / Kazakh border and the sanctions on Russia have also underlined the importance of being self-reliant for rigs and drilling consumables.

Since the period end we have acquired a further workover rig with the $750,000 consideration satisfied by the issue of approximately 19 million new shares.

The impact of Covid-19

Although there were several periods when the Almaty office was closed following staff testing positive for Covid-19, the impact on operations in the oilfields were far less pronounced than in 2020. More impactful was the Covid-19 related closure of the Chinese / Kazakh border and the resultant sharp rise in the price of equipment and consumables sourced from Russia. Happily, the Chinese / Kazakh border has reopened.

The impact of the drilling slow-down in 2020 became apparent in 2021 with no new wells coming on stream in the first half of 2021, resulting in a 2% fall in the volume of oil produced for the year as a whole.

3A Best

There was little progress at 3A Best in the period under review or subsequently. The farm-out announced in June 2021 was conditional on the renewal of the 3A Best Licence. We continue to work with the Kazakh authorities to renew the licence, following which we will assess its place within the Group. In the meantime, our investment in 3A Best has been fully provided for.

Caspian Explorer

During the period under review the Caspian Explorer was chartered for a safety related contract by the North Caspian Operating Company, the leading operator in the region. Daily rates for safety related work are much lower than for drilling contracts but the income from the charter covered the Caspian Explorer's costs for the year.

While we have serious interest in both safety related and drilling charters for 2023 no contracts have yet been signed, although a tender has been submitted for a 2023 drilling programme. We have also received several early-stage approaches to buy the Caspian Explorer.

Dividends

It has been our objective for some time to commence regular dividend payments. Not only will this reward shareholders for their continued support it should also signal to the wider investment community that the Group has moved to the next stage in its development.

We have worked to create sufficient distributable reserves to allow dividends to be paid. This required a formal Capital Reduction to cancel the share premium account and the deferred shares to boost distributable reserves. The Capital Reduction was approved by shareholders in April 2022 and approved by the UK High Court in June 2022.

In assessing the size and timing of any dividends the board will have regard to the matters disclosed in note 1.1, which include the Group's free cashflows and its existing and future financial commitments. The Board will also need to be satisfied there are no additional adverse impacts from Russian sanctions.

CHAIRMAN'S STATEMENT (CONTINUED)

Based on their current assessment and subject to the points noted above the Board anticipates declaring the first dividend later this year.

Board changes

On 4 March 2021 we were pleased to welcome Seokwoo Shin, Chief Operating Officer, to the Board as an executive director. He 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.

Employees

The Group currently employees 215 staff, including Directors, of whom 213 are based in Kazakhstan and split principally between the corporate offices in Almaty and in the field.

Outlook

We look forward to further increasing production from the shallow structures at BNG.

Even at current prices and despite the Urals Oil discount the company is doing well, however, as noted above, we do not expect the current discount for Urals Oil to apply to our oil for much longer. A drilling charter for the Caspian Explorer in 2023 would also make a material difference to the Group's trading. However, the greatest impact on the value of our Company would be success at our BNG deep structures.

Clive Carver

Chairman

24 June 2022

FINANCIAL REVIEW OF THE 12 MONTHS ENDED 31 DECEMBER 2021

Revenue

Revenue in 2021 increased by approximately 75 per cent to approximately $25 million (2020: $14.3 million).

Oil prices

International export prices rose steadily from approximately $50 per barrel at the start of 2021 to approximately $77 per barrel by the year end. Over the same period domestic prices rose from approximately $6 per barrel to approximately $25 per barrel.

Production volumes

Production volume in 2021 was at 533,857 barrels some 2.2% lower than in 2020, reflecting the limited investment in workovers and new wells during the height of the Covid-19 restrictions in 2020.

International vs Domestic sales

The proportion of oil sold on the international market in 2021 was similar to that in 2020 as the export status at South Yelemes was not received until late December 2021.

Gross profit

Gross profit increased by approximately 106 per cent to approximately $19.4 million (2020: $9.4 million), principally as the result of the increase in the oil price.

Selling expenses

Selling expenses increased by approximately 94% at $7.6 million (2020: $3.9 million) and are mainly export and customs duties, which are typically based on achieved oil prices.

Operating loss

The operating loss was $4.0 million (2020: $0.7 million) This includes a provision in respect of the carrying value of 3A Best of $12.5 million.

Other administrative expenses

The Board's pay reductions introduced in 2020 continued through 2021 and throughout H1 2022, with the result that in the period under review General and Administrative expenses fell a further 11% to $3.3 million (2020: $3.7 million).

Tax charge

The tax charge reduced to $0.7 million (2020: $1.8 million). and the reduction in the tax charge reflected lower provisions for Kazakh withholding tax on intercompany loans with taxes on trading being covered by past losses.

Loss for the year

The loss for the year after tax was $5.5 million, after the $12.5 million provision in respect of 3A Best. (2020: loss of $3.5 million).

Oil and gas assets

Unproven oil & gas assets

The carrying value of unproven oil and gas assets fell by approximately $15.3 million to approximately $46.2 million (2020: $61.4 million) largely as the result of the $12.5 million provision in respect of 3A Best and exchange rate differences of approximately $3.5 million.

The approval for export sales from the South Yelemes which was granted in December 2021 required further information to be supplied in the following 6 months for the formal export licence to be confirmed. Accordingly, at 31 December 2021 the South Yelemes asset has remained as part of unproven oil & gas assets and will be moved to proven oil and gas assets in the 2022 financial statements.

Plant, property and equipment

The value of plant property and equipment increased by approximately $4.3 million to approximately $57.1 million (2020: $52.8 million), reflecting the acquisition in the year of drilling rigs and equipment.

FINANCIAL REVIEW OF THE 12 MONTHS ENDED 31 DECEMBER 2021 (CONTINUED)

Other receivables

Other receivables fell from approximately $6.2 million to approximately $4.9 million principally as the result of lower pre-payments. Receivables due in more than one year were approximately $4.3 million (2020: $4.2 million) and are principally Kazakh VAT related.

Cash position

At the year-end we had cash balances of approximately $0.4 million (2020: $0.3 million). This reflects the continuing extremely tight working capital position following the impact of Covid-19.

Liabilities

Trade and other payables under 12 months

Trade and other payables increased to approximately $13.2 million (2020: 11.0 million), largely as the result of higher tax due on oil sales. Short term borrowings provided by the Oraziman family increased to $6.4 million (2020: $5.6 million) and the provisions for payments in less than 12 months stayed broadly similar at approximately $8.7 million (2020: $9.3 million) of which the provision for BNG licence payments was $3.2 million in both years.

On 9 March 2022, following the period end Independent Shareholders approved the conversion of approximately $6.2 million due to the Oraziman family into 139,729,446 new ordinary shares.

BNG historic costs

We have continued to pay down the historic costs assessed against BNG. At 31 December 2021, of the original $32 million levied in 2019 approximately $22.5 million remains to be paid over the next seven years.

Cashflows

During the period under review approximately $24.3 million was received from customers and approximately $16.6 million paid out to suppliers, creditors and staff with a further $0.7 million spent on unproven oil and gas assets and $7.1 million spent on property, plant and equipment, resulting in cash balances at the year increasing slightly from $0.3 million to $0.4 million.

Going Concern

The financial position of the Group and the Company has improved in the past year and as at 1 June 2022 the Group had cash of $1 million.

· At current oil prices, even with the Urals Oil price discount, the Company enjoys positive operational cash flows

· Deep Well 802 is the final well required under the BNG work programme. Any further deep wells drilled at BNG will be on a discretionary basis

· As is the case for the MJF structure, the South Yelemes structure with current production of approximately 300 bopd is now able to sell most of its oil at international prices

· $6.2 million of debt has been converted to equity

Nevertheless, with net current liabilities of approximately $22 million as at 31 December 2021, the assessment of going concern needs to be properly considered. The Board have assessed cash flow forecasts prepared for a period of at least 12 months from the of approval of the financial statements and assessed the risks and uncertainties associated with the operations and funding position, including the potential further effects of the COVID-19 pandemic. These cash flows, which include the payment of discretionary dividend, are dependent on a number of key factors including:

· The Group's cashflow is sensitive to oil price and volume sold. This is impacted by its current reliance on exporting a portion of its oil sales through the Russian pipeline network. If due to sanctions on Russia, this pipeline network is no longer available, or the discount on oil exported through this network increased over a prolonged period, to continue to generate positive cash the Group would either seek alternative distribution routes via Uzbekistan, Azerbaijan or China or alternatively sell all oil produced on the domestic market or to one of the new mini refineries opening in the region, where prices are typically better than the domestic price and buyers collect the oil from the wellhead. As none of these alternatives have yet been tested, if the oil price achieved or volume sold declined, these factors could result in the Group requiring additional funding.

FINANCIAL REVIEW OF THE 12 MONTHS ENDED 31 DECEMBER 2021 (CONTINUED)

· The Group continues to forward sell its domestic production and receive advances from oil traders with $1.8m currently advanced and the continued availability of such arrangements is important to working capital. Whilst the Board anticipate such facilities remaining available given its trader relationships and recent oil price increases, should they be withdrawn or reduced more quickly than forecast cash flows allow then additional funding would be required.

· The Group has $6.0m of liabilities due on demand under social development program and $0.4m of BNG licence payments due within the forecast period to the Kazakh government. Whilst the Board has forecasted the payment of BNG licence payments, there are no payments planned for social development program within the forecast period as the Board expects additional payment deferrals to be approved. Should the deferrals not occur 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 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.

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

24 June 2022

OUR OIL & GAS ASSETS

BNG CONTRACT AREA

Introduction

The Group's principal asset is its 99% interest in the BNG Contract Area. We first took a stake in the BNG Contract Area in 2008, as part of the acquisition of 58.41% of 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 kilometers southeast of Tengiz on the edge of the Mangistau Oblast, covering an area of 1,561 square kilometers of which 1,376 square kilometers 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

There are two confirmed and producing shallow structures at BNG.

MJF structure

The first wells were drilled on the MJF structure in 2016, since when it has produced in aggregate approximately 2.7 million barrels. We have embarked on a programme of redrilling the older wells using horizontal drilling techniques to increase production. At the date of this report work at three of the older wells has been completed.

In 2013, we announced the discovery of the MJF structure and have subsequently drilled eight wells of which seven are currently producing with an aggregate capacity of approximately 3,750 bopd.

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 13km2. 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, 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 $22 million remained payable at 31 December 2021.

Wells 154 and 153 were the first new wells drilled using horizontal techniques both targeting a Middle Jurassic reservoir. Recently Well 142 recommenced production following use of horizontal drilling and is producing at approximately 1,400 bopd.

All of the oil produced in 2021 was from the MJF structure. In 2021 we produced 533,857 barrels of oil at an average of 1,462 bopd (2020: 545,667 barrels at an average of 1,495 bopd).

South Yelemes structure

The first wells were drilled on the South Yelemes structure during the Soviet era, with test production commencing in 1994.

Well 54 was intermittently active between periods of being shut in to allow pressure to be restored. There are three other wells at South Yelemes (805, 806 & 807). Since 2010 the South Yelemes shallow structure has produced approximately 350,000 barrels.

No production was allowed at this structure between May 2020 when we submitted our application to upgrade the structure to export status in late December 2021. We are now able to sell most of the oil produced from the South Yelemes structure by reference to international rather than domestic prices.

OUR OIL & GAS ASSETS (CONTINUED)

South Yelemes structure (Continued)

Until recently these older wells were the only wells on the BNG Contract Area to use artificial lift to assist the oil to flow to the surface. We believe the structure may have untapped quantities of oil at higher levels than previously explored, which we intended to explore with horizontal drilling targeting a Dolomite reservoir.

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

Three deep wells have been drilled on the Airshagyl structure, A5, A6 & A8 a fourth A7 was spudded in December 2021.

A5

Well A5 was spudded in July 2013 and drilled to a total depth of 4,442 meters with casing set to a depth of 4,077 meters to allow open-hole testing. Core sampling revealed the existence of a gross oil-bearing interval of at least 105 meters from 4,332 meters to at least 4,437 meters. For 15 days the well produced at the rate of approximately 3,000 bopd before production fell to approximately 1,000 bopd, leading to the well being shut in for remedial treatment.

Limited rig availability resulted in little work on this well in 2021 or subsequently. We remain believers in the well and intend to drill a new side-track from a depth of 4,500 meters when a rig becomes available.

A6

Deep Well A6 was spudded in 2015 and drilled to a depth of 4,528 meters. Initially problems in perforating the well prevented it being put on test. Latterly the issue has been blockages from unrecovered drilling fluid. During the year the year under review there was no significant progress with the well. Further development work will depend on rig availability and a decision on which acid formulation to use.

A8

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 the 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.

During 2021 we decided to resume drilling towards the original objective in the Devonian. Drilling reached a final depth of 5,400 meters in early December. Neither of the two intervals of interest perforated resulted in commercial quantities of oil with pressures below the levels expected. Accordingly, work has stopped at A8 and the rig has been reassigned.

New wells

New 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 5,300 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.

Yelemes Deep structure

Deep Well 801 was drilled in 2014 / 2015 to a depth of 5,050 meters. During the year the year under review there was no progress with the well. As with Deep Well A6 on the Airshagyl structure further development work will depend on rig availability.

Deep Well 802 was spudded in June 2022, with a planned Total Depth of 5,300 meters. At the date of this report drilling had reached 650 meters without incident. This will be the final deep well required under the BNG work programme.

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 extremely high temperature and extreme 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 where at the Yelemes Deep structure the salt layer is typically found at depths between 3,000 and 3,500 meters.

OUR OIL & GAS ASSETS (CONTINUED)

Deep well drilling issues (Continued)

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.

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, currently owned by Total Energies, which we believe to be producing at the rate of approximately 15,000 bopd.

In June 2021, we announced a farm out of 15% of the 3A Best Contract Area in return for our new partners assuming responsibility for the current 3A Best work programme commitments. However, the farm out was conditional on the deferral of obligations under the licence and the extension of the license which are yet to be granted. We also granted our new partners an option to acquire the remaining 85%, exercisable after completion of the current work programme commitments, at a price to be determined by an independent expert.

We continue to work with the Kazakh authorities to renew the 3A Best licence. Until we are successful on this the farm-out will not proceed. Our investment in 3A Best has been fully provided for.

LICENCES & WORK PROGRAMMES AND RESERVES

LICENCES & WORK PROGRAMMES

BNG

BNG LLP Ltd holds three contracts for a 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 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.

Wells A7 and 802 are the final two deep wells required under the BNG work programme commitments. Well A7 was spudded in December 2021 and Well 802 was spudded in June 2022.

3A Best

The licence renewal at 3A Best was delayed as the result of outstanding social payments due from the assets previous owners. We continue to work with the Kazakh authorities to renew the 3A Best licence.

RESERVES

BNG

In 2011 Gaffney Cline & Associates ("GCA") undertook a technical audit of the BNG license area and subsequently Petroleum Geology Services ("PGS") to undertake 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 2021, approximately 3.0 mmbls of oil were produced, which under financial reporting rules are deducted from the assessment of reserves as at 31 December 2021.

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.

CASPIAN EXPLORER

Introduction

In 2020 we acquired the Caspian Explorer, a drilling vessel designed specifically for use in the shallow northern Caspian Sea where traditional deep water rigs cannot be used. We believe it to be the only vessel of its type operating in the Caspian Sea.

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 class 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 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 total costs after fit-out are believed to have been approximately $200 million. We understand a replacement would today cost in excess of $300 million and take several years to become operational.

The Caspian Explorer became operational in 2012 at a time of relatively low oil prices and reduced exploration activity in the Northern Caspian Sea.

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 and CNPC, the consortium operating the Kashagan field. The charter has been completed and payment received.

We have submitted a tender for a drilling charter in 2023.

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 $100,000 per month while moored in port 

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

Commercial activity

· In 2017, the Caspian Explorer was hired out to a KazMunaiGas / Indian state oil company joint venture for $28 million after costs and drilled one exploration well to a depth of 3.5 km.

· In 2018, the Caspian Explorer was hired out KazMunaiGas for up to $24 million drilling one exploration well to a depth of 1.8 km.

· The Caspian Explorer did not operate in 2019 or in 2020. In 2021 $1.2 million was received for a safety related charter

· A tender is outstanding for a 2023 drilling contract at prices broadly consistent with the rates achieved in 2017 and 2018

QUALIFIED PERSON & GLOSSARY

Qualified Person

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

Glossary

SPE - the Society of Petroleum Engineers

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.

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 licence 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 usually 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 has 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 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 is 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 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 also forms the main part of the strategic review, contains 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 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 an attractive portfolio of oil and gas exploration and production assets initially in Central Asia, and in particular Kazakhstan where the board has the greatest experience. Additionally, the Group will seek to exploit associated opportunities where the board believes it can add significant value and contribute towards the success of the Group as a whole.

This strategy has been refined during the year under review and subsequently to favour cash producing assets and to seek to exploit alternative energy project, specifically wind energy project.

The Group's principal asset is its 99 per cent interest in BNG. Additionally, the Group owns a 100 per cent interest in the 3A Best Contract Area, of which subject to licence renewal it has agreed to sell 15% to fund existing 3A Best work programme commitments and granted an option for the sale of the remaining 85% at a valuation to be assessed by an independent expert. The Group also owns a 100% interest in the Caspian Explorer, a shallow water drilling vessel designed for the Northern parts of the Caspian Sea.

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 main asset BNG has been developed over the past 14 years with more than $100 million spent and is set to be a very substantial asset for many years to come.

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

When appropriate 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.

In Kazakhstan the Directors believe the Group is exceptionally well placed through its local presence to identify and buy undervalued oil and gas assets on an opportunistic basis.

Climate Change

Other than a general move away from fossil fuels, 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 at least the next decade.

STRATEGIC REPORT (CONTINUED)

Key performance indicators

The Non-Financial Key Performance Indicators are:

· Operational (wells drilled at end of year) 2021: 18 (2020: 17)

· Aggregate production for 2021 was 533,857 barrels (2020: 545,667) a decrease of approximately 2.2%

· Reserves at 31 December 2021 P1 15.1 mmbls & P2 26.3 mmbls (2020: P1 15.6 mmbls & P2 26.8 mmbls)

The Financial Key Performance Indicators are:

· Revenue: up 75% at $25.0 million (2020: $14.3 million)

· Operating loss $4.0 million (2020: loss of $0.7 million) after a $12.5 million provision in respect of 3A Best

· Loss after tax for the year $5.5 million (2020: $3.5 million)

· Cash at bank: $0.4 million (2020: $0.3 million)

· Total assets: $114 million (2020: $125.6 million)

· Exploration assets $46.3 million (2020: $61.4 million)

· Plant, property & equipment $57.1 million (2020: $52.8 million)

Current production capacity

· 4,000 bopd

Assets & Reserves

Details of the Group's assets and reserves are set out in the Chairman's statement.

Financial

At current international prices and with current levels of production the income from export sales is sufficient to cover all day-to-day Group operations; and G&A costs; the costs of the two new deep wells A7 & 802; and to fund planned dividend payments.

In the event any of the six deep wells drilled or being drilled start to produce oil in commercial quantities the associated revenues should transform the Group's cash flows. The same would be the case in the event the Caspian Explorer is chartered for drilling projects at market rates.

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

For some years it has been the policy of the Board to work towards a position where meaningful dividends can be paid. This requires not only consistently profitable trading but also a corporate reorganisation to create distributable reserves. New corporate subsidiaries have been incorporated in the UAE, with a view improving and simplifying the Group structure and easing the future payment of dividends. The final step was the approval of shareholders and the UK Court of a Capital Reduction. Shareholder approved the Capital Reduction in April 2022, which was approved by the UK High Court in June 2022.

The Group's then expects to declare and pay dividends on a regular basis, subject to the comments set out in the Chairman's Statement.

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.

STRATEGIC REPORT (CONTINUED)

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 on 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 and until the Covid-19 virus struck our Annual General Meeting provided an opportunity for investors to meet and engage with members of the Board.

The Board continues to encourage senior management to engage with staff, suppliers, customers and the community in order to assist the Board in discharging its obligations.

During 2021 the Board was particularly mindful of the impact of the ongoing Covid-19 pandemic when making decisions. This has impacted all areas of decision making and is not limited to ensuring that its impact on employees, contractors, suppliers and the communities in which we operate is factored into any decision, but also to ensure that its reputational, financial and other impact is also considered.

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 4 (in relation to decision-making), page 18 (where the Group's strategy, objectives and business model are addressed), page 21 (in relation to employees) the ESG report on page 26 (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 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

24 June 2022

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 2021.

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

Principal activity

The principal activity of the Group is oil and gas exploration and production.

Results and dividends

The consolidated statement of profit or loss is set out on page 45 and shows a $5.5 million loss for the year after tax (2020: loss US$3.5 million).

Subject to the comments set out in the Chairman's Statement, the Directors expect to declare the Company's first dividend later this year.

Review of the year

The review of the year and the Directors' strategy are set out in the Chairman's Statement and the Strategic Report.

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 2021, and the date of this report, which are required to be brought to the attention of shareholders. Please refer to note 28 of these financial statements for further details.

Board changes

On 4 March 2021, Seokwoo Shin, Chief Operating Officer joined the Board as an executive director.

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 and gas 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 environment.

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 the Annual Report are as follows:

Directors' interests

* taken together on 31 December 2021 the Oraziman Family, comprising Kuat Oraziman, Aibek Oraziman, Aidana Urazimanova, the Estate of the late Rafik Oraziman, Altynbek Boltazhan and Boltazhan Kerimbayev held 949,815,346 shares representing 45% of the issued share capital shares.

Since the year end and following the $6.2 million Debt Conversion completed in March 2021 the Oraziman family hold 1,089,544,792 shares representing 48.41% of the issued share capital.

** comprises 492,836,151 shares held direct plus 100,021,432 shares held by Akku Investments in which Aibek Oraziman has a 50% interest. The entry as at 31 December 2020 was made on the basis that all shares held by Aibek Oraziman and Aidana Urazimanova were pooled in Akku Investments, in which Aibek Oraziman had a 50% interest.

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

*** comprises 396,682,324 shares held direct plus 100,021,432 shares held by Akku Investments in which Aidana Urazimanova has a 50% interest.

Financial instruments

Details of the use of financial instruments by the Group and its subsidiary undertakings are contained in note 25 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.

Auditor BDO LLP have indicated their willingness to continue in office and a resolution concerning their reappointment will be proposed at the next Annual General Meeting.

Directors' responsibilities

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 Group's website. www.caspiansunrise.com has recently been updated and readers of these financial statements are encouraged to visit the website. 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.

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

24 June 2022

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 is a dangerous activity and as such is 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 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 by our new Corporate Governance Committee.

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.

ENVIRONMENTAL, SOCIAL AND GOVERNANCE (ESG) REPORT

This report covers our ESG approach and performance for the year ended 31 December 2021.

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 15 years and have only been able to do so by complying with all 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 years to come, and new sources of oil supply will be required for a sustainable energy transition.

Climate change

Assessing the risks

We have no particular insights into assessing climate control risks beyond those underpinning the regulations in Kazakhstan. We therefore 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 and 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 extensive use of existing oil pipelines to move our oil.

· Largely as the result of Covid-19 restriction the use of international travel for management and board meetings has been severely restricted with no full face to face board meetings for more than 24 months.

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.

The Governance & Risk Committee comprises Clive Carver, Edmund Limerick and Aibek Oraziman with Clive Carver acting as chairman. The committee intends to meet 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 the 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 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 Bribery Act have been translated into Russian and circulated to our Kazakh based staff. Consideration of the 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 Groups 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.

Board composition, skills and capabilities

· Between 1 January 2021 and 4 March 2021 the Board comprised one executive director and three non-executive directors.

· Between 4 March 2021 and 31 December 2021, the Board comprised two executive directors and three non-executive directors.

· From 1 January 2022 the Board comprised three executive directors and two non-executive directors

Clive Carver, Executive Chairman

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 more than 27 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 the board as chief Operating Officer.

Edmund Limerick, Senior Non-Executive Director

Edmund is a Russian speaking former lawyer and investment banker who ran an institutional investment fund focused on Central Asia. Edmund was called to the Bar in 1987 and served as an officer in the Foreign & Commonwealth Office until 1992 with postings in Paris, Dakar and Amman. He was an international corporate lawyer at Clifford Chance, Freshfields and Milbank Tweed (where he headed the Moscow Office) before joining Deutsche Bank as a director in Moscow, London and Dubai. In 2006, he joined Altima Partners where he managed the Altima Central Asia Fund, focusing on Kazakhstan. Edmund has served as a director of Caspian Sunrise plc since 2010, and chairs the Audit and Remuneration Committees.

Aibek Oraziman, Non-executive director

Aibek Oraziman was educated in Kazakhstan and in the United Kingdom. He more than 12 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.

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 phone, are set out below:

Note: Seokwoo Shin joined the board on 4 March 2021

The Board has established the following committees:

Audit Committee

The Audit Committee which comprises Edmund Limerick, Aibek Oraziman and Clive Carver, with Edmund Limerick acting as 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 Edmund Limerick Aibek Oraziman and Clive Carver, with Edmund Limerick acting 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 2021

Clive Carver

24 June 2022

REMUNERATION COMMITTEE REPORT

Remuneration Committee

The Remuneration Committee comprises Edmund Limerick, Aibek Oraziman and Clive Carver and is chaired by Edmund Limerick.

Remuneration policy

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, the Covid-19 impact on the Group's finance required the Directors to accept very significant reductions in the amounts received which continued throughout 2021 and the first six months of 2022.

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

Service contracts

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

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 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.

Share option amounts refer to the IFRS 2 accounting charge.

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 2021 (2020: 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:

There were no options exercised in 2021. On 26 November 2021, the exercise date for the options held by Clive Carver were extended from 14 December 2021 to 14 December 2023.

Cash based incentives

In May 2019, we introduced a 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.

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

Edmund Limerick

Chairman of Remuneration Committee

24 June 2021

AUDIT COMMITTEE REPORT

The Audit Committee

The Audit Committee, which comprises Edmund Limerick, Clive Carver and Aibek Oraziman, with Edmund Limerick acting as 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 three 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.

On behalf of the Directors of Caspian Sunrise plc

Edmund Limerick

Chairman of Audit Committee

24 June 2022

Independent auditor's report to the members of Caspian Sunrise plc

Opinion on the financial statements

In our opinion:

• 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 2021 and of the Group's loss 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.

We have audited the financial statements of Caspian Sunrise plc (the 'Parent Company') and its subsidiaries (the 'Group') for the year ended 31 December 2021 which comprise the Consolidated Statement of Profit or Loss, the Consolidated Statement of Comprehensive Income, the Consolidated Statement of Changes in Equity, the Parent Company Statement of Changes in Equity, the Consolidated Statement of Financial Position, the Parent Company Statement of Financial Position, the Consolidated and Parent Company Statements of Cash Flows and 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.

Basis for opinion

We conducted our audit in accordance with International Standards on Auditing (UK) (ISAs (UK)) and applicable law. Our responsibilities under those standards are further described in the Auditor's responsibilities for the audit of the financial statements section of our report. We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our opinion.

Independence

We remain independent of the Group and the Parent 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.

Material uncertainty in relation to going concern

We draw attention to note 1.1 in the financial statements concerning the Group and the Parent Company's ability to continue as a going concern. Note 1.1 highlights that Group and Parent Company's ability to meet its liabilities and commitments as they fall due without additional funding is sensitive to the oil prices realised and volumes sold which is impacted by its ability to export a portion of its oil sales through the Russian pipeline network. Note 1.1 also highlights that the Group and Parent Company is dependent upon the deferral of financial obligations, the continued availability of oil trader advances and the continued support of certain creditors together with other matters set out therein. These factors are outside the control of the Group and the Parent Company and there is no certainty that any funding that may therefore be required can be secured within the necessary timescales. These events or conditions indicate that a material uncertainty exists that may cast significant doubt on the Group 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. We consider going concern to be a Key Audit Matter based on our assessment of the risk and the effect on our audit.

Our evaluation of the Directors' assessment of the Group and the Parent Company's ability to continue to adopt the going concern basis of accounting, and our response to this key audit matter included: 

· We obtained management's base case cash flow forecast and a reasonable plausible downside cash flow forecast and critically assessed the key inputs. In doing so, we compared oil prices to market data, production levels to recent performance trends and operating costs to historical data.

· We discussed the potential impact of sanctions against Russia on the Group's operations with management and the Audit Committee including their assessment of risks and uncertainties associated with areas such as production disruption, commodity price volatility and the impact on the availability of funding. This included considering the Group's reliance on selling oil through the Russian pipeline network, and should this no longer be a viable export route, the alternatives available to the Group. 

· We formed our own assessment of risks and uncertainties based on our understanding of the business and oil sector.

· We evaluated the completeness of forecast licence related expenditure against the licence work programs and payments due under the 3A Best licence. We held discussions with management and the Audit Committee regarding the status of such applications. 

· We compared the forecast cash payments in respect of the BNG production licence award against the $32m assessment received from the Government payable in instalments over 10 years. We ensured that the relevant instalments are included in the forecast.

· We considered the appropriateness of the Board's judgement regarding the availability of sufficient oil trader funding through the forecast period. In doing so, we considered factors such as the production profile, oil price trends, the terms of the arrangements and the history of transactions with the oil traders.

· We reviewed the agreement that converted the loans provided from the Group's largest shareholder and his connected companies to equity after the period end. 

· We assessed the validity of any mitigating actions identified by the Directors including drilling new wells.

· We reviewed the adequacy and completeness of the disclosure included within the financial statements in respect of going concern against the requirement of the accounting standards and the results of our audit testing.

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

Overview

An overview of the scope of our audit

Our Group audit was scoped by obtaining an understanding of the Group and its environment, including the Group's system of internal control, and assessing the risks of material misstatement in the financial statements. We also addressed the risk of management override of internal controls, including assessing whether there was evidence of bias by the Directors that may have represented a risk of material misstatement.

The Group's operations principally comprise oil and gas exploration and production in Kazakhstan. We assessed there to be four significant components comprising BNG, 3A Best, Caspian Explorer and the Parent Company. These components, which were subject to full scope audit procedures, represent the principal business units.

Non-BDO member firms performed a full scope audit of BNG, 3A Best and Caspian Explorer 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 the Group audit team.

The remaining components of the Group were considered non-significant and these components were principally subject to analytical review procedures by the Group audit team.

Our involvement with component auditors

For the work performed by component auditors, we determined the level of involvement needed in order to be able to conclude whether sufficient appropriate audit evidence has been obtained as a basis for our opinion on the Group financial statements as a whole. 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 work papers in Kazakhstan, reviewed Group reporting submissions received and held regular calls with the component audit teams during the planning and completion phases of their audit to discuss significant findings from their audit.

· We held calls and meetings with members of Group and component management to discuss accounting and audit matters arising.

· The Group audit team was actively involved in the direction of the audits performed by the component auditors, along with the consideration of findings and determination of conclusions drawn. We performed additional procedures in respect of the significant risk areas where considered necessary.

Key audit matters

Key audit matters are those matters that, in our professional judgement, were of most significance in our audit of the financial statements of the current period and include the most significant assessed risks of material misstatement (whether or not due to fraud) that 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, we do not provide a separate opinion on these matters. In addition to going concern, described in the Material uncertainty related to going concern section above, we determined the matters described below to be the key audit matters to be communicated in our report.

Our application of materiality

We apply the concept of materiality both in planning and performing our audit, and in evaluating the effect of misstatements. We consider materiality to be the magnitude by which misstatements, including omissions, could influence the economic decisions of reasonable users that are taken on the basis of the financial statements.

In order to reduce to an appropriately low level the probability that any misstatements exceed materiality, we use a lower materiality level, performance materiality, to determine the extent of testing needed. Importantly, misstatements below these levels will not necessarily be evaluated as immaterial as we also take account of the nature of identified misstatements, and the particular circumstances of their occurrence, when evaluating their effect on the financial statements as a whole.

Based on our professional judgement, we determined materiality for the financial statements as a whole and performance materiality as follows:

Component materiality

We set materiality for each significant component of the Group based on a percentage of between 26% and 68% of Group materiality dependent on the size and our assessment of the risk of material misstatement of that component. Component materiality ranged from US$500,000 to US$1,300,000. In the audit of each component, we further applied performance materiality levels of 65% of the component materiality to our testing to ensure that the risk of errors exceeding component materiality was appropriately mitigated.

Reporting threshold 

We agreed with the Audit Committee that we would report to them all individual audit differences in excess of US$38,000 (2020: US$95,000). We also agreed to report differences below this threshold that, in our view, warranted reporting on qualitative grounds.

Other information

The directors are responsible for the other information. The other information comprises the information included in the Annual Report and Financial Statements other than the financial statements and our auditor's report thereon. Our opinion on the financial statements does not cover the other information and, except to the extent otherwise explicitly stated in our report, we do not express any form of assurance conclusion thereon. 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.

We have nothing to report in this regard.

Other Companies Act 2006 reporting

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. 

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 Group's and the Parent 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 Group or the Parent 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.

Extent to which the audit was capable of detecting irregularities, including fraud

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

We obtained an understanding of the legal and regulatory frameworks that are applicable to the Group and the Parent company. We determined that the most significant which are directly relevant to specific assertions in the financial statements are those related to the reporting framework (UK adopted international accounting standards, the Companies Act 2006, the AIM rules and the QCA Corporate Governance Code), the significant laws and regulations of Kazakhstan relating to the oil and gas industry, local taxation legislation and environmental regulations, and the terms and requirements included in the Group's production and exploration licences.

Our procedures included the following:

· We gained an understanding of how the Group is complying with those legal and regulatory frameworks by making inquiries of Management and the Audit Committee, and those responsible for legal and compliance procedures. We corroborated our inquires through our review of board minutes and other supporting documentation;

· We directed the auditors of the significant components to ensure an assessment is performed on the extent of the component's compliance with the relevant local and regulatory framework; and

· We reviewed the financial statement disclosures and tested to supporting documentation to assess compliance with relevant laws and regulations noted above.

We assessed the susceptibility of the financial statements to material misstatement, including fraud and considered the fraud risk areas to be management override of controls and revenue recognition.

Our procedures included:

· Testing the appropriateness of journal entries made through the year by applying specific criteria to detect possible irregularities and fraud;

· Reviewing 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;

· Performing a detailed review of the Group's year end adjusting entries and investigating any that appear unusual as to nature or amount and agreeing to supporting documentation;

· For significant and unusual transactions, particularly those occurring at or near year-end, obtaining evidence for the rationale of these transactions and the sources of financial resources supporting the transactions;

· Assessing the judgements made by management when making key accounting estimates and judgements, and challenging management on the appropriateness of these judgements (refer to key audit matters above); and

· Communicating relevant potential fraud risks to all engagement team members and remaining alert to any indications of fraud throughout the audit.

Our audit procedures were designed to respond to risks of material misstatement in the financial statements, recognising that the risk of not detecting a material misstatement due to fraud is higher than the risk of not detecting one resulting from error, as fraud may involve deliberate concealment by, for example, forgery, misrepresentations or through collusion. There are inherent limitations in the audit procedures performed and the further removed non-compliance with laws and regulations is from the events and transactions reflected in the financial statements, the less likely we are to become aware of it.

A further description of our responsibilities is available on the Financial Reporting Council's website at: www.frc.org.uk/auditorsresponsibilities. This description forms part of our auditor's report.

Use of our report

This report is made solely to the Parent 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 Parent 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 Parent Company and the Parent Company's members as a body, for our audit work, for this report, or for the opinions we have formed.

Peter Acloque (Senior Statutory Auditor)

For and on behalf of BDO LLP, Statutory Auditor

London, 

United Kingdom 

24 June 2022

BDO LLP is a limited liability partnership registered in England and Wales (with registered number OC305127).

The notes on pages 52 to 82 are essential part of these financial statements

Consolidated Statement of Comprehensive Income

The notes on pages 52 to 82 are essential part of these financial statements

Consolidated Statement of Changes in Equity

Equity Description and purpose

Share capital The nominal value of shares issued

Share premium Amount subscribed for share capital in excess of nominal value

Deferred shares The nominal value of deferred shares issued

Cumulative translation reserve Gains/losses arising on retranslating the net assets of overseas operations into US Dollars, less amounts recycled on disposal of subsidiaries and joint ventures

Other reserves Fair value of warrants issued and capital contribution arising on discounted loans

Merger reserve The excess of the fair value of the issues share capital over the nominal value of these shares issued for acquisition of at least 90 percent equity holding in subsidiaries.

Retained deficit Cumulative losses recognised in the consolidated statement of profit or loss, adjustments on the acquisition of non-controlling interests and transfers in respect of share based payments

Non-controlling interest The interest of non-controlling parties in the net assets of the subsidiaries

The notes on pages 52 to 82 are essential part of these financial statements

Parent Company Statement of Changes in Equity

Equity Description and purpose

Share capital The nominal value of shares issued

Share premium Amount subscribed for share capital in excess of nominal value

Deferred shares The nominal value of deferred shares issued

Other reserves Capital contribution arising on discounted loans

Merger reserve The excess of the fair value of the issues share capital over the nominal value of these shares issued for acquisition of at least 90 percent equity holding in subsidiaries.

Retained deficit Cumulative losses recognised in the profit or loss

The notes on pages 52 to 82 are essential part of these financial statements

Consolidated Statement of Financial Position

Approved by the Board and authorized for issue:

Clive Carver,

Chairman,

24 June 2022

Company number: 5966431

The notes on pages 52 to 82 are essential part of these financial statements

Parent Company Statement of Financial Position