2021 Audited Results

RNS Number : 5533Q

Enwell Energy PLC

29 June 2022

 

29 June 2022

ENWELL ENERGY PLC

2021 AUDITED RESULTS

Enwell Energy plc ("Enwell Energy" or the "Company", and together with its subsidiaries, the "Group"), the AIM-quoted (AIM: ENW) oil and gas exploration and production group, today announces its audited results for the year ended 31 December 2021.

2021 Highlights

Operational

●	Aggregate average daily production of 4,730 boepd (2020: 4,541 boepd), an increase of approximately 4.2%
●	SV-25 appraisal well successfully completed and brought on production in February 2021
●	SV-31 development well successfully completed and brought on production in May 2022
●	No significant disruption to the Group's operations arising from the COVID-19 pandemic to date

Financial

●	Revenue of $121.4 million (2020: $47.3 million), up 157% as a result of significantly higher gas prices and increased production rates
●	Gross profit of $73.9 million (2020: $15.7 million), up 371%
●	Operating profit of $66.2 million (2020: $9.8 million), up 576%
●	Cash generated from operations of $77.6 million (2020: $23.8 million), up 226% as a result of significantly higher gas prices and increased production rates
●	Net profit of $51.1 million (2020: $3.2 million), up 1,497%
●	Cash, cash equivalents and short-term investments of $92.5 million as at 31 December 2021 (2020: $61.0 million), and of $76.5 million as at 24 June 2022
●	Average realised gas, condensate and LPG prices in Ukraine were much higher, particularly gas prices, at $432/Mm3 (UAH11,677/Mm3), $69/bbl and $80/bbl respectively (2020: $136/Mm3 (UAH3,618/Mm3) gas, $46/bbl condensate and $46/bbl LPG)
●	Reduction of capital completed through the cancellation of the Company's entire share premium account which has created distributable reserves, thereby enabling the possibility of the Company making distributions to shareholders in the future

Outlook

●		The Russian invasion of Ukraine in February 2022 has had a significant impact on all aspects of life in Ukraine, including the Group's business and operations, with all field operations being suspended from 24 February to 15 March 2022, after which production operations and some field activities resumed at the MEX-GOL and SV fields, while all operations remain suspended at the VAS field and SC licence area. The scale and duration of disruption to the Group's business is currently unknown, and there remains significant uncertainty about the outcome of the conflict in Ukraine.
●		The Russian invasion of Ukraine in February 2022 has had a significant impact on all aspects of life in Ukraine, including the Group's business and operations, with all field operations being suspended from 24 February to 15 March 2022, after which production operations and some field activities resumed at the MEX-GOL and SV fields, while all operations remain suspended at the VAS field and SC licence area. The scale and duration of disruption to the Group's business is currently unknown, and there remains significant uncertainty about the outcome of the conflict in Ukraine.
●		The Group retains the majority (77% as at 24 June 2022) of its cash outside Ukraine, which enhances the Group's ability to navigate the current risk environment for the foreseeable future, and provides a material buffer to any further disruptions to the Group's operations.
●		Subject to the Group's ability to operate safely, development work planned for 2022:
		◦		at the MEX-GOL and SV fields includes: a workover of the SV-29 well to test alternative horizons; and drilling of two new wells at the MEX-GOL field
		◦			at the SC licence includes: completing the drilling of the SC-4 well; processing and interpretation of the recently acquired 150 km2 of 3D seismic; and planning for the development of the licence area
		◦	at the VAS field includes: planning for a new well to explore the VED prospect within the VAS licence area; and maintenance of the gas processing facilities, flow-line network and other field infrastructure
●	2022 development programme expected to be funded from existing cash resources and operational cash flow

Sergii Glazunov, CEO, commented : "While 2021 was an extremely strong operational year for Enwell Energy, these achievements are entirely overshadowed by the ongoing military conflict in Ukraine. The conflict is having a huge impact on all aspects of life in Ukraine. Although operations at our VAS field are currently suspended, we were able to restart production at our MEX-GOL and SV fields, and this is testament to the diligence and fortitude of our operational team. We are also hoping to complete the drilling of the SC-4 well on our SC licence area in the near future.

Continuing to operate in the current environment is extremely challenging, and the safety and well-being of our staff is paramount, but, subject to that, we will endeavour to continue our operations and make our best contribution to the economy in Ukraine."

The Annual Report and Financial Statements for 2021 will be posted to shareholders and published on the Company's website by 30 June 2022, and a formal Notice of Annual General Meeting will follow later during July 2022.

This announcement contains inside information for the purposes of Article 7 of EU Regulation No. 596/2014, which forms part of United Kingdom domestic law by virtue of the European Union (Withdrawal) Act 2018, as amended.

For further information, please contact:

Enwell Energy plc	Tel: [phone]
Chris Hopkinson, Chairman
Sergii Glazunov, Chief Executive Officer
Bruce Burrows, Finance Director
Strand Hanson Limited	Tel: [phone]
Rory Murphy / Matthew Chandler
Arden Partners plc	Tel: [phone]
Ruari McGirr / Elliot Mustoe (Corporate Finance)
Simon Johnson (Corporate Broking)
Citigate Dewe Rogerson	Tel: [phone]
Ellen Wilton

Dmitry Sazonenko, MSc Geology, MSc Petroleum Engineering, Member of AAPG, SPE and EAGE, Director of the Company, has reviewed and approved the technical information contained within this announcement in his capacity as a qualified person, as required under the AIM Rules for Companies.

Glossary
AAPG	American Association of Petroleum Geologists
Arkona	LLC Arkona Gas-Energy
bbl	barrel
bbl/d	barrels per day
Bm3	thousands of millions of cubic metres
boe	barrels of oil equivalent
boepd	barrels of oil equivalent per day
Bscf	thousands of millions of scf
Company	Enwell Energy plc
D&M	DeGolyer and MacNaughton
€	Euro
Group	Enwell Energy plc and its subsidiaries
km	kilometre
km2	square kilometre
LPG	liquefied petroleum gas
MEX-GOL	Mekhediviska-Golotvshinska
m3	cubic metres
m³/d	cubic metres per day
Mboe	thousand barrels of oil equivalent
Mm³	thousand cubic metres
MMbbl	million barrels
MMboe	million barrels of oil equivalent
MMm3	million cubic metres
MMscf	million scf
MMscf/d	million scf per day
Mtonnes	thousand tonnes
%	per cent.
QCA Code	Quoted Companies Alliance Corporate Governance Code 2018
QHSE	quality, health, safety and environment
SC	Svystunivsko-Chervonolutskyi
scf	standard cubic feet measured at 20 degrees Celsius and one atmosphere
SPE	Society of Petroleum Engineers
SPEE	Society of Petroleum Evaluation Engineers
SV	Svyrydivske
Tscf	trillion scf
$	United States Dollar
UAH	Ukrainian Hryvnia
VAS	Vasyschevskoye
VED	Vvdenska
WPC	World Petroleum Council

Chairman's Statement

I present the 2021 Annual Report and Financial Statements with very mixed emotions this year. While the Group achieved an excellent performance during 2021, and avoided any significant operational disruption as a result of the COVID-19 pandemic, the invasion of Ukraine by Russia in February 2022 has created a very different and worrying outlook in respect of both the current and future situation in Ukraine, and I am greatly saddened to observe the terrible events occurring there.

The invasion has had a significant impact on all aspects of life in Ukraine, including the Group's business and operations, with all field operations being suspended from 24 February to 15 March 2022, after which production operations and some limited field activities resumed at the MEX-GOL and SV fields, while all operations remain suspended at the VAS field and SC licence area. The scale and duration of disruption to the Group's business is currently unknown, and there remains significant uncertainty about the outcome of the ongoing conflict in Ukraine.

During 2021, the Group continued to make good progress in the development of the MEX-GOL, SV and VAS gas and condensate fields and SC licence in north-eastern Ukraine, and has delivered an exceptional financial performance. The SV-25 appraisal well was completed and brought on production in February 2021, and the SV-31 development well was completed and brought on production in May 2022. Drilling of the SV-29 development well was completed and two horizons in the V-22 Visean formation were perforated and tested, but while there were intermittent gas flows, stabilised production was not achieved and so alternative horizons will be perforated and tested when possible. The SC-4 appraisal well was nearing its target depth when operations were suspended.

Aggregate average daily production from the MEX-GOL, SV and VAS fields during 2021 was 4,730 boepd, which compares favourably with an aggregate daily production rate of 4,541 boepd during 2020, an increase of approximately 4.2%. However, issues with water ingress at the MEX-109 and SV-2 wells in Q4 2021, meant that these wells were taken offline and workover operations were underway when field operations were suspended due to the invasion. The loss of production from these wells had a material impact on production rates in Q4 2021. At the VAS field production was steady, but lower than during 2020, after a decline in production from the VAS-10 well. 

Largely as a result of the dramatic rise in gas prices during the year, the Group's net profit increased hugely to $51.1 million (2020: $3.2 million) as did operating profit to $66.2 million (2020: $9.8 million) and cash generated from operations to $77.6 million (2020: $23.8 million). 

This significant level of cash generation enabled the Group to progress its multiple work programmes across its broadened asset portfolio, with approximately $43.0 million invested during the year (2020: $17.1 million).

During 2021, the fiscal and economic environment in Ukraine largely remained stable, despite the effects of the COVID-19 pandemic resulting in a contraction in GDP and an increase in the rate of inflation, and Ukrainian Hryvnia exchange rates also remained steady. However, the invasion of Ukraine has naturally had a huge impact on the fiscal and economic situation in Ukraine, and future fiscal and economic uncertainties will continue until an acceptable resolution of the conflict occurs.

The Ukrainian Government has implemented a number of reforms in the oil and gas sector in recent years, which include the deregulation of the gas supply market in late 2015, and subsequently, reductions in the subsoil tax rates relating to oil and gas production and a simplification of the regulatory procedures applicable to oil and gas exploration and production activities in Ukraine. 

The deregulation of the gas supply market, supported by electronic gas trading platforms and improved pricing transparency, has meant that Ukrainian market gas prices broadly correlated with imported gas prices. During 2021, gas prices recovered significantly, reflecting a similar trend in European gas prices.  Similarly, condensate and LPG prices were also much higher by comparison with last year.

However, in Q1 2022, the Ukrainian Government imposed two material measures on oil and gas producers. Firstly, in January 2022 temporary partial gas price regulations were imposed until 30 April 2022, designed to support the production of certain designated food products, further details of which were set out in the Company's announcement dated 17 January 2022. Secondly, changes to the subsoil production tax rates applicable to gas production were introduced with effect from 1 March 2022, pursuant to which the tax rates were linked to gas prices, the incentive rates for new wells were extended for a further 10 years and improvements were made to the regulatory environment. In addition, an excise tax applicable to LPG sales was cancelled in February 2022, and the VAT rate applicable to condensate and LPG sales was reduced in March 2022. Further details were set out in the Company's announcement dated 13 April 2022.

Outlook

The invasion of Ukraine by Russia means that there is a catastrophic humanitarian situation in Ukraine, as well as extreme challenges to the fiscal, economic and business environment. These circumstances mean that it is extremely difficult to plan future investment and operational activities at the Group's fields, but subject to it being safe to do so, the Group is hoping to undertake further development activities during 2022 and beyond in order to continue the development of its fields. However, in doing so, the Group is taking and will take all measures available to protect and safeguard its personnel and business, with the safety and wellbeing of its personnel and contractors being paramount. The Group retains the majority (77% as at 24 June 2022) of its cash outside Ukraine, which enhances the Group's ability to navigate the current risk environment for the foreseeable future, and provides a material buffer to any further disruptions to the Group's operations. This has enabled the Board to reach the opinion that the Group has sufficient resources to navigate the current risk environment for the foreseeable future.

In conclusion, on behalf of the Board, I would like to thank all of our staff for the continued dedication and support they showed during the 2021 year, especially in the midst of the COVID-19 pandemic, and even more so, for their remarkable fortitude since the invasion of Ukraine in February 2022.

Chris Hopkinson

Chairman

Chief Executive's Statement

Introduction

The Group continued to make good progress at its Ukrainian fields during 2021, with development activity at the MEX-GOL and SV fields including successes with the SV-25 appraisal well, which came on production in February 2021, and the SV-31 development well, which came on production in May 2022. Drilling of the SV-29 development well was also completed, and, although the well produced gas flows on test, a stabilised flow rate was not established and so it is planned to test alternative horizons when possible. In addition, upgrades to the gas processing facilities, flow-line network and remedial activity on existing wells were undertaken. 

At the VAS field, planning for a proposed new well to explore the VED prospect within the VAS licence area has continued, and upgrades to the flow-line network and other infrastructure were undertaken.

The Group also commenced work on the SC licence, with the spudding of the SC-4 appraisal well in August 2021, although the drilling operations were subsequently suspended due to the Russian invasion of Ukraine. However, the acquisition of 150 km² of 3D seismic over the 2021-2022 winter period was completed and the acquired seismic data is now being processed and interpreted. 

Overall production continued its upward trend during the year, being approximately 4.2% higher than in 2020, although production rates declined in Q4 2021 following water ingress at the MEX-109 and SV-2 wells, causing these wells to be shut in pending workover operations designed to remedy the water ingress issues.

Quality, Health, Safety and Environment ("QHSE")

The Group is committed to maintaining the highest QHSE standards and the effective management of these areas is an intrinsic element of its overall business ethos. The Group's QHSE policies and performance are overseen by the Health, Safety and Environment Committee. Through strict enforcement of the Group's QHSE policies, together with regular management meetings, training and the appointment of dedicated safety professionals, the Group strives to ensure that the impact of its business activities on its staff, contractors and the environment is as low as is reasonably practicable. The Group reports safety and environmental performance in accordance with industry practice and guidelines.

I am pleased to report that during 2021, a total of 840,807 man-hours of staff and contractor time were recorded without a Lost Time Incident occurring. The total number of safe man-hours now stands at over 4,292,623 man-hours without a Lost Time Incident.  No environmental incidents were recorded during the year. 

Production

The average daily production of gas, condensate and LPG from the MEX-GOL, SV and VAS fields for the year ended 31 December 2021 is shown below.

Field	Gas (MMscf/d)		Condensate (bbl/d)		LPG (bbl/d)		Aggregate boepd
	2021	2020	2021	2020	2021	2020	2021	2020
MEX-GOL & SV	18.9	17.6	681	641	295	295	4,237	3,960
VAS	2.6	2.9	26	32	-	-	493	581
Total	21.5	20.5	707	673	295	295	4,730	4,541

Production rates were higher in 2021 when compared with 2020, predominantly due to the contribution of the SV-25 well, which commenced production in February 2021.

The Russian invasion of Ukraine in February 2022 meant that the Group suspended all field operations for the period from 24 February to 15 March 2022, after which production operations and some field activities resumed at the MEX-GOL and SV fields, while all operations remain suspended at the VAS field and SC licence. The VAS field is located near Kharkiv in north-eastern Ukraine, which has experienced significant military activity, and so resumption of production at this field is not anticipated in the immediate future. However, plans are being made to complete the drilling of the SC-4 well at the SC licence in the near future. As a result of the disruptions to operations caused by the invasion, the Group's average daily production for the 2022 year to date has been materially affected. However, production is currently continuing at the MEX-GOL and SV fields at a rate of approximately 2,500 boepd.  

Operations

Notwithstanding the impact of the COVID-19 pandemic during 2020 and 2021, over those periods, there had been relatively stable fiscal and economic conditions in Ukraine, as well as reductions in the subsoil tax rates and improvements in the regulatory procedures in the oil and gas sector in Ukraine. However, the Russian invasion of Ukraine in February 2022 has caused huge disruption to the fiscal and economic conditions in Ukraine since then.  During 2021, the strong recovery in gas prices in Europe fed through to the Group's realised prices in Ukraine, and provided a significant boost to the Group's revenues and profitability during the year.

During 2021, the Group continued to refine its geological subsurface models of the MEX-GOL, SV and VAS fields, in order to enhance its strategy for the further development of such fields, including the timing and level of future capital investment required to exploit the hydrocarbon resources. 

At the MEX-GOL and SV fields, the drilling of the SV-25 appraisal well was completed in February 2021, having been drilled to a final depth of 5,320 metres. One interval, at a drilled depth of 5,184 - 5,190 metres, within the V-22 Visean formation was perforated, and after successful testing, the well was hooked-up to the gas processing facilities.

In August 2021, the drilling of the SV-29 development well was completed, having been drilled to a final depth of 5,450 metres. Two intervals, at drilled depths of 5,246 - 5,249 metres and 5,228 - 5,232 metres respectively, within the V-22 Visean formation, were perforated, and, while intermittent gas flows were achieved, a stabilised flow from these intervals was not established. It is therefore planned to perforate and test two alternative intervals in the V-19 and V-20 Visean formations when possible.

In May 2022, the SV-31 development well was completed, with the well having reached a final depth of 5,240 metres. One interval, at a drilled depth of 5,210 - 5,219 metres, within the V-22 Visean formation was perforated, and, after initial testing, the well was hooked up to the gas processing facilities. The well is currently producing at approximately 2.54 MMscf/d of gas and 117 bbl/d of condensate (563 boepd in aggregate). 

The Group continued to operate each of the SV-2 and SV-12 wells under joint venture agreements with NJSC Ukrnafta, the majority State-owned oil and gas producer. Under the agreements, the gas and condensate produced from the respective wells is sold under an equal net profit sharing arrangement between the Group and NJSC Ukrnafta, with the Group accounting for the hydrocarbons produced and sold from the wells as revenue, and the net profit share due to NJSC Ukrnafta being treated as a lease expense in cost of sales. However, during Q4 2021, the SV-2 well experienced water ingress and consequently had to be taken off production. A workover of this well was commenced to remove and replace the production string, but this work was suspended as a result of the Russian invasion of Ukraine.

In addition, in Q4 2021, the MEX-109 well also experienced water ingress and as a result was taken off production. A workover of the well was commenced, and steps were taken to seal the source of the water ingress, but again the work was suspended as a result of the Russian invasion, and the well is currently under observation. 

The shut-ins of the SV-2 and MEX-109 wells impacted overall production rates and, depending on the duration and outcome of the requisite remedial works, could potentially have a material impact on the Group's future overall production volumes.

Finally, at the MEX-GOL and SV fields, the upgrades to the gas processing facilities have been completed. These works involved an upgrade of the LPG extraction circuit, an increase to the flow capacity of the facilities, and a significant increase to the liquids tank storage capacity, which are designed to improve overall plant efficiencies, improve the quality of liquids produced and boost recoveries of LPG, while reducing environmental emissions.

At the VAS field, a successful workover of the VAS-10 well was undertaken to access an alternative production horizon, which improved production rates from the VAS field.

In March 2019 (as set out in the Company's announcement made on 12 March 2019), a regulatory issue arose when the State Service of Geology and Subsoil of Ukraine issued an order for suspension (the "Order") of the production licence for the VAS field. Under the applicable legislation, the Order would lead to a shut-down of production operations at the VAS field, but the Group has issued legal proceedings to challenge the Order, and has obtained a ruling suspending operation of the Order pending a hearing of the substantive issues. The Group does not believe that there are any grounds for the Order, and intends to pursue its challenge to the Order through the Ukrainian Courts.

Arkona Acquisition and SC Exploration Licence

As announced on 24 March 2020, the Group acquired the entire issued share capital of LLC Arkona Gas-Energy ("Arkona") for a total consideration of up to $8.63 million, of which $4.32 million was subject to the satisfaction of certain conditions. Following satisfaction of the requisite conditions, and by agreement between the parties to the acquisition agreement, further payments totalling $2.6 million (net of an indemnity liability) have been paid, and the balance of the consideration of $1.6 million is subject to the remaining conditions and contractual provisions. Arkona holds a 100% interest in the Svystunivsko-Chervonolutskyi ("SC") exploration licence, which is located in the Poltava region in north-eastern Ukraine. The SC licence covers an area of 97 km², and is approximately 15 km east of the SV field. The licence was granted in May 2017 with a duration of 20 years. The licence is prospective for gas and condensate, and has been the subject of exploration since the 1980s, with 5 wells having been drilled on the licence since then, although none of these wells are currently on production. As with the productive reservoirs in the SV field, the prospective reservoirs in the licence area are Visean, at depths between 4,600 - 6,000 metres. 

However, PJSC Ukrnafta, the majority State-owned oil and gas producer, issued legal proceedings against Arkona, in which PJSC Ukrnafta made claims of irregularities in the procedures involved in the grant of the SC licence to Arkona in May 2017. In early July 2020, the First Instance Court in Ukraine made a ruling in favour of PJSC Ukrnafta, which found that the grant of the SC licence was irregular, but this ruling was overturned by the Appellate Administrative Court in September 2020, and a final appeal to the Supreme Court of Ukraine was determined in favour of Arkona in February 2021. Further information is set out in the Company's announcements dated 3 July 2020, 31 July 2020, 30 September 2020, 23 November 2020 and 11 February 2021.

During early 2021, the Group engaged independent petroleum consultants, DeGolyer and MacNaughton, to prepare an assessment of the remaining reserves and contingent resources attributable to the SC licence as at 1 January 2021, in accordance with the March 2007 (as revised in June 2018) SPE/WPC/AAPG/SPEE Petroleum Resources Management System standard for classification and reporting. Their assessment estimated the proved and probable (2P) reserves attributable to the SC licence at 12.1 MMboe. The assessment is consistent with the Group's proposed field development plan for the SC licence, which includes the drilling of the SC-4 well and the acquisition of 150 km² of 3D seismic, and the construction of a gas processing plant. Development is then planned to continue with the drilling of a further six wells to recover the reserves and resources in the SC licence. Due to their targeted depths, the wells are each likely to take up to 12 months to complete, and are planned to be drilled consecutively over the next eight years. Further information on DeGolyer and MacNaughton's assessment can be found in the Company's announcement dated 2 June 2021.

At the SC licence, the SC-4 well had nearly reached its target depth of 5,565 metres, when drilling was suspended as a result of the Russian invasion of Ukraine. The well is primarily an appraisal well, targeting production from the V-22 horizon, as well as exploring the V-16 and V-21 horizons, in the Visean formation. In addition , the acquisition of 1 50 km² of 3D seismic has been completed, and processing and interpretation of the acquired seismic data is now being undertaken.

Outlook

The Russian invasion of Ukraine in February 2022 has caused significant disruption to Ukraine as a whole and to the Group's business activities, and until there is a satisfactory resolution to the conflict, the disruption and uncertainty are likely to continue. However, and subject to it being safe to do so, during 2022, the Group plans to continue to develop the MEX-GOL, SV and VAS fields, as well as moving forward with the appraisal and development of the SC licence area . At the MEX-GOL and SV fields, the development programme includes a workover of the SV-29 development well, to access alternative horizons in the Visean formation, drilling of two further wells in the MEX-GOL field, installation of further compression equipment, and remedial and upgrade work on existing wells, the flow-line network and pipelines and other infrastructure. 

At the VAS field, planning for the proposed new well to explore the VED prospect within the VAS licence area will continue, and upgrades to the gas processing facilities, pipeline network and other infrastructure are planned. 

At the SC licence, drilling of the SC-4 well is planned to be completed, the recently acquired 3D seismic will be processed and interpreted and planning for the construction of gas processing facilities will continue.

Finally, I would like to add my thanks to all of our staff for the continued hard work and dedication they have shown over the course of 2021, and to especially recognise their continuing efforts and professionalism in the face of the extremely challenging current situation in Ukraine.

Sergii Glazunov

Chief Executive Officer

Overview of Assets

We operate four fields in the Dnieper-Donets basin in north-eastern Ukraine. Our fields have high potential for growth and longevity for future production - a strong foundation for success.

MEX-GOL and SV fields

The MEX-GOL and SV fields are held under two adjacent production licences, but are operated as one integrated asset, and have significant gas and condensate reserves and potential resources of unconventional gas.

Production Licences

We hold a 100% working interest in, and are the operator of, the MEX-GOL and SV fields. The production licences for the fields were granted to the Group in July 2004 with an initial duration of 20 years, and the duration of these licences have recently been extended to 2044 in order to fully develop the remaining reserves. The economic life of these fields extend to 2038 and 2042 respectively pursuant to the most recent reserves and resources assessment by DeGolyer and MacNaughton ("D&M") as at 31 December 2017.

The two licences, located in Ukraine's Poltava region, are adjacent and extend over a combined area of 253 km², approximately 200 km east of Kyiv.

Geology

Geologically, the fields are located towards the middle of the Dnieper-Donets sedimentary basin which extends across the major part of north-eastern Ukraine. The vast majority of Ukrainian gas and condensate production comes from this basin. The reservoirs comprise a series of gently dipping Carboniferous sandstones of Visean age inter-bedded with shales at around 4,700 metres below the surface, with a gross thickness of between 800 and 1,000 metres.

Analysis suggests that the origin of these deposits ranges from fluvial to deltaic, and much of the trapping at these fields is stratigraphic. Below these reservoirs is a thick sequence of shale above deeper, similar, sandstones at a depth of around 5,800 metres. These sands are of Tournasian age and offer additional gas potential. Deeper sandstones of Devonian age have also been penetrated in the fields.

Reserves

The development of the fields began in 1995 by the Ukrainian State company Chernihivnaftogasgeologiya ("CNGG"), and shortly after this time, the Group entered a joint venture with CNGG in respect of the exploration and development of these fields.

The fields have been mapped with 3D seismic, and a geological subsurface model has been developed and refined using data derived from high-level reprocessing of such 3D seismic and new wells drilled on the fields.

The assessment undertaken by D&M as at 31 December 2017 estimated proved plus probable (2P) reserves attributable to the fields of 50.0 MMboe, with 3C contingent resources of 25.3 MMboe.

VAS field

The VAS field is a smaller field with interesting potential. The field has assessed proved plus probable reserves in excess of 3 MMboe and substantial contingent and prospective resources, as well as potential resources of unconventional gas.

Production Licence

We hold a 100% working interest in, and are the operator of, the VAS field. The production licence for the field was granted in August 2012 with a duration of 20 years. The economic life of the field extends to 2032 pursuant to the most recent reserves and resources assessment by D&M as at 31 December 2018.

The licence extends over an area of 33.2 km² and is located 17 km south-east of Kharkiv, in the Kharkiv region of Ukraine. The field was discovered in 1981, and the first well on the licence area was drilled in 2004.

Geology

Geologically, the field is located towards the middle of the Dnieper-Donets sedimentary basin in north-east Ukraine. The field is trapped in an anticlinal structure broken into several faulted blocks, which are gently dipping to the north, stretching from the north-east to south-west along a main bounding fault. The gas is located in Carboniferous sandstones of Bashkirian, Serpukhovian and Visean age.

The productive reservoirs are at depths between 3,370 and 3,700 metres.

Reserves

The field has been mapped with 3D seismic, and a geological subsurface model has been developed and refined using data derived from such 3D seismic and new wells drilled on the field.

The assessment undertaken by D&M as at 31 December 2018 estimated proved plus probable (2P) reserves of 3.1 MMboe, with 3C contingent resources of 0.6 MMboe, and prospective resources of 7.7 MMboe in the VED area of the field.  The next well planned on the field is designed to explore the VED area of the field.  

SC Licence

The SC licence area is located near to and has similar characteristics to the SV field, and is prospective for gas and condensate.

Exploration Licence

We hold a 100% working interest in, and are the operator of, the SC licence. The licence was granted in May 2017 with a duration of 20 years.

The licence extends over an area of 97 km² , and is located in the Poltava region in north-eastern Ukraine, approximately 15 km east of the SV field.

Geology

Geologically, the field is located towards the middle of the Dnieper-Donets sedimentary basin which extends across the major part of north-eastern Ukraine. The vast majority of Ukrainian gas and condensate production comes from this basin. The reservoirs comprise a series of gently dipping Carboniferous sandstones of Visean age inter-bedded with shales at depth between 4,600 and 6,000 metres.

Resources

The licence is prospective for gas and condensate, and has been the subject of exploration since the 1980s, with five wells having been drilled on the licence since then, although none of these wells are currently on production. 

The assessment undertaken by D&M as at 1 January 2021 estimated proved plus probable (2P) reserves of 12.1 MMboe, with 3C contingent resources of 15.0 MMboe.  

Overview of Reserves

1.  MEX-GOL and SV fields

The Group's estimates of the remaining Reserves and Resources at the MEX-GOL and SV fields are derived from an assessment undertaken by D&M, as at 31 December 2017 (the "MEX-GOL-SV Report"), which was announced on 31 July 2018. During the period from 1 January 2018 to 31 December 2021, the Group has produced 5.2 MMboe from these fields.

The MEX-GOL-SV Report estimated the remaining Reserves as at 31 December 2017 in the MEX-GOL and SV fields as follows:

	Proved (1P)	Proved + Probable (2P)	Proved + Probable + Possible (3P)
Gas	121.9 Bscf / 3.5 Bm3	218.3 Bscf / 6.2 Bm3	256.5 Bscf / 7.3 Bm3
Condensate	4.3 MMbbl / 514 Mtonne	7.9 MMbbl / 943 Mtonne	9.2 MMbbl / 1,098 Mtonne
LPG	2.8 MMbbl / 233 Mtonne	5.0 MMbbl / 418 Mtonne	5.8 MMbbl / 491 Mtonne
Total	27.8 MMboe	50.0 MMboe	58.6 MMboe

The MEX-GOL-SV Report estimated the Contingent Resources as at 31 December 2017 in the MEX-GOL and SV fields as follows:

	Contingent Resources (1C)	Contingent Resources (2C)	Contingent Resources (3C)
Gas	14.7 Bscf / 0.42 Bm3	38.3 Bscf / 1.08 Bm3	105.9 Bscf / 3.00 Bm3
Condensate	1.17 MMbbl / 144 Mtonne	2.8 MMbbl / 343 Mtonne	6.6 MMbbl / 812 Mtonne
Total	3.8 MMboe	9.6 MMboe	25.3 MMboe

2.  VAS field

The Group's estimates of the remaining Reserves and Resources at the VAS field and the Prospective Resources at the VED prospect are derived from an assessment undertaken by D&M as at 31 December 2018 (the "VAS Report"), which was announced on 21 August 2019.   During the period from 1 January 2019 to 31 December 2021, 0.7 MMboe were produced from the field.

The VAS Report estimated the remaining Reserves as at 31 December 2018 in the VAS field as follows:

	Proved (1P)	Proved + Probable (2P)	Proved + Probable + Possible (3P)
Gas	9,114 MMscf / 258 MMm3	15,098 MMscf / 427 MMm3	18,816 MMscf / 533 MMm3
Condensate	205 Mbbl / 25 Mtonne	346 Mbbl / 42 Mtonne	401 Mbbl / 48 Mtonne
Total	1.895 MMboe	3.145 MMboe	3.890 MMboe

The VAS Report estimated the Contingent Resources as at 31 December 2018 in the VAS field as follows:

	Contingent Resources (1C)	Contingent Resources (2C)	Contingent Resources (3C)
Gas	-	-	2,912 MMscf / 83 MMm3
Condensate	-	-	74 Mbbl / 9 Mtonne

The VAS Report estimated the Prospective Resources as at 31 December 2018 in the VED prospect as follows:

	Low (1U)	Best (2U)	High (3U)	Mean
Gas	23,721 MMscf / 672 MMm3	38,079 MMscf / 1,078 MMm3	62,293 MMscf / 1,764 MMm3	41,291 MMscf / 1,169 MMm3

3 .  SC Licence

The Group's estimates of the remaining Reserves and Contingent R esources at the SC Licence are derived from an assessment undertaken by D&M as at 1 January 2021 (the "SC Report"), which was announced on 2 June 2021.

The SC Report estimated the remaining Reserves as at 1 January 2021 in the SC licence area as follows:

	Proved (1P)	Proved + Probable (2P)	Proved + Probable + Possible (3P)
Gas	17.20 Bscf / 0.49 Bm3	65.16 Bscf / 1.85 Bm3	85.03 Bscf / 2.41 Bm3
Condensate	145 Mbbl / 16 Mtonne	548 Mbbl / 61 Mtonne	716 Mbbl / 80 Mtonne
Total	3.2 MMboe	12.1 MMboe	15.7 MMboe

The SC Report estimated the Contingent Resources as at 1 January 2021 in the SC licence area as follows:

	Contingent Resources (1C)	Contingent Resources (2C)	Contingent Resources (3C)
Gas	8.56 Bscf / 0.24 Bm3	14.18 Bscf / 0.40 Bm3	81.16 Bscf / 2.30 Bm3
Condensate	72 Mbbl / 8 Mtonne	119 Mbbl / 13 Mtonne	682 Mbbl / 75 Mtonne
Total	1.6 MMboe	2.6 MMboe	15.0 MMboe

Finance Review

The Group's financial performance in 2021 was exceptional when compared to previous periods, with the net profit for the year of $51.1 million being an approximate 15-fold increase on 2020 (2020: $3.2 million). The dramatic improvement is primarily a result of the Group's achievement of record levels of production coinciding with the very significant increase during the period in pricing of the Group's primary product, natural gas.

Aggregate production for the year was up approximately 4% at 4,730 boepd (2020: 4,541 boepd).

Rarely has natural gas, and its pricing, been more of a focus of public attention, with the sizeable global rise in the commodity's pricing being well documented throughout the latter part of 2021. These global and European price increases were also experienced in Ukraine, and underpinned the 218% rise in average gas price realisations in the period at $432/Mm³ (UAH11,677/Mm³), with condensate and LPG average sales prices also up by 50% and 74% at $69/bbl and $80/bbl respectively (2020: $136/Mm³ (UAH3,618/Mm³), $46/bbl and $46/bbl respectively). 

Revenue for the year, derived from the sale of the Group's Ukrainian gas, condensate and LPG production, was up at $121.4 million (2020: $47.3 million). Most notably, within this total, the revenue from gas sales alone was up approximately 197% at $95.8 million (2020: $32.3 million). 

During the period from 1 January 2022 to 31 May 2022, the average realised gas, condensate and LPG prices were $1,201/Mm³ (UAH34,613/Mm³), $105/bbl and $151/bbl respectively.

Cost of sales for the year was up approximately 5 0 % at $47. 4 million (2020: $31.5 million). The major contributor to this increase is the material rise in the revenue-related costs of taxes and well rental (with their direct link to commodity prices), up approximately 130% at a combined $28.7 million (2020: $12.5 million). Excluding these tax expenses directly related to commodity prices, the residual cost of sales is consistent at $18. 7 million (2020: $1 9 . 0 million). The impact of the above noted increase in well rental costs is also evidenced in the increase in operating expenditure per boe, which also increased as a direct result of such well rental costs increase, from $9.50/boe in 2020 to $13.60/boe in 2021.

Gross profit for the year was dramatically higher at $7 3 . 9 million (2020: $15.7 million).

The subsoil tax rates applicable to gas production were stable during the 2021 year at 29% for gas produced from deposits at depths shallower than 5,000 metres and 14% for gas produced from deposits deeper than 5,000 metres, but reductions in the subsoil rates applicable to new wells and to condensate production were applicable, under which (i) for new wells drilled after 1 January 2018, the subsoil tax rates were reduced from 29% to 12% for gas produced from deposits at depths shallower than 5,000 metres and from 14% to 6% for gas produced from deposits deeper than 5,000 metres for the period between 2018 and 2022, and (ii) with effect from 1 January 2019 and applicable to all wells, the subsoil tax rates for condensate were reduced from 45% to 31% for condensate produced from deposits shallower than 5,000 metres and from 21% to 16% for condensate produced from deposits deeper than 5,000 metres.

However, with effect from 1 March 2022, changes to the subsoil production tax rates applicable to gas production were introduced. These changes modified the applicable tax rates based on gas prices, extended the incentive rates for new wells for a further 10 years and made improvements to the regulatory environment. The legislation which introduced these changes also included provisions that these rates will not be increased for 10 years.

The new subsoil production tax rates applicable to gas production are as follows:

(i)  when gas prices are up to $150/Mm³, the rate for wells drilled prior to 1 January 2018 ("old wells") is 14.5% for gas produced from deposits at depths shallower than 5,000 metres and 7% for gas produced from deposits deeper than 5,000 metres, and for wells drilled after 1 January 2018 ("new wells") is 6% for gas produced from deposits at depths shallower than 5,000 metres and 3% for gas produced from deposits deeper than 5,000 metres;

(ii)  when gas prices are between $150/Mm³ and $400/Mm³, the rate for old wells is 29% for gas produced from deposits at depths shallower than 5,000 metres and 14% for gas produced from deposits deeper than 5,000 metres, and for new wells is 12% for gas produced from deposits at depths shallower than 5,000 metres and 6% for gas produced from deposits deeper than 5,000 metres;

(iii)  when gas prices are more than $400/Mm³, for the first $400/Mm³, the rate for old wells is 29% for gas produced from deposits at depths shallower than 5,000 metres and 14% for gas produced from deposits deeper than 5,000 metres, and for new wells is 12% for gas produced from deposits at depths shallower than 5,000 metres and 6% for gas produced from deposits deeper than 5,000 metres, and for the difference between $400/Mm³ and the actual price, the rate for old wells is 65% for gas produced from deposits at depths shallower than 5,000 metres and 31% for gas produced from deposits deeper than 5,000 metres, and for new wells is 36% for gas produced from deposits at depths shallower than 5,000 metres and 18% for gas produced from deposits deeper than 5,000 metres.

The tax rates applicable to condensate production were unchanged and so remain at 31% for condensate produced from deposits shallower than 5,000 metres and 16% for condensate produced from deposits deeper than 5,000 metres, for both old and new wells.

In addition, the excise tax of €52 ($59) per thousand litres applicable to LPG sales was cancelled entirely with effect from 24 February 2022, and the VAT rate applicable to condensate and LPG sales was reduced to 7% (from 20%) with effect from 18 March 2022.

Finally, in early 2022, the Ukrainian Government imposed temporary and partial gas price regulation to support the production of certain food products through the supply of gas at regulated prices to the producers of such products. Under this scheme, all independent gas producers in Ukraine were required to sell up to 20% of their natural gas production for the period until 30 April 2022 at a price set as the cost of sales of the relevant gas producer (based on established accounting rules) for such gas, plus a margin of 24%, plus existing subsoil production taxes (the "Regulated Price"). This gas was then sold to specified producers of designated socially important food products at the Regulated Price, so as to reduce the energy costs of such producers during the period through to 30 April 2022. The designated products were certain types of flour, milk (with up to 2.5% fat), bread, eggs, chicken and sunflower oil, for sale in the Ukrainian domestic market. This temporary scheme has now concluded. Further details are set out in the Company's announcement dated 17 January 2022.

Administrative expenses for the year were 7. 7 % higher at $8.4 million (2020: $7.8 million), primarily as a net result of: a 2 7 % decrease in consultancy fees mainly due to the level of legal and advisory costs associated with the acquisition activity in 2020 not having been repeated; and an 11% increase in payroll and related taxes, consistent with further increases in staff levels and salary inflation.

Finance costs for the year were approximately 43 % lower at $0.8 million (2020: $1.4 million), mainly due to realised net foreign exchange gains during 2021, as opposed to the net losses incurred in 2020.

Other losses in the year reduced by 95% in the period, a result of the non-recurring nature of the charitable donation in 2020 of $2.0 million for the supply of COVID-19-related medical equipment for Ukrainian authorities .

The tax charge for the year increased by a significant 370% to $15.5 million (2020: $3.3 million charge) mainly due to the material increase in profit before tax, and comprised a current tax charge of $13.3 million (2020: $3.0 million charge) and a deferred tax charge of $1 million (2020: $0.3 million charge). 

A deferred tax asset relating to the Group's provision for decommissioning as at 31 December 2021 of $ 0.5 million (2020: $0.2 million) was recognised on the tax effect of the temporary differences of the Group's provision for decommissioning at the MEX-GOL and SV fields, and its tax base. A deferred tax liability relating to the Group's development and production assets at the MEX-GOL and SV fields as at 31 December 2021 of $5.7 million (2020: $2.9 million) was recognised on the tax effect of the temporary differences between the carrying value of the Group's development and production asset at the MEX-GOL and SV fields, and its tax base.

A deferred tax asset relating to the Group's provision for decommissioning as at 31 December 2021 of $ 0.3 million (2020: $0.3 million) was recognised on the tax effect of the temporary differences on the Group's provision on decommissioning at the VAS field, and its tax base. A deferred tax liability relating to the Group's development and production assets at the VAS field as at 31 December 2021 of $0.5 million (2020: $0.2 million) was recognised on the tax effect of the temporary differences between the carrying value of the Group's development and production asset at the VAS field, and its tax base.

Capital investment of $ 32.2 million reflects the investment in the Group's oil and gas development and production assets during the year (2020: $18.2 million), primarily relating to the drilling of the SV-25, SV-29, SV-31 and SC-4 wells. A review of any indicators of impairment of the carrying value of the Group's assets was undertaken at the year end but this review did not reveal any such indicators.

With the material increase in commodity prices during the period, and Q4 2021 in particular, trade and other receivables were up 173% to $13.1 million (2020: $4.8 million). The $5.2 million of trade receivables included in the year-end balance have been paid in full in 2022.

Cash, cash equivalents and short-term investments held as at 31 December 2021 were 52% higher at $92.5 million (2020: $61.0 million), the increase being a result of the significant increase in sales receipts in the period for the reasons noted above. The Group's cash and cash equivalents balance as at 24 June 2022 was $76.5 million, held as to $17.4 million equivalent in Ukrainian Hryvnia and the balance of $59.1 million equivalent predominantly in US Dollars, Euros and Pounds Sterling.

During 2021, the Ukrainian Hryvnia was stable against the US Dollar, strengthening modestly from UAH28.3/$1.00 on 31 December 2020 to UAH27.3/$1.00 on 31 December 2021. The impact of this was $1.6 million of foreign exchange gain (2020: $15 million of foreign exchange loss). Increases and decreases in the value of the Ukrainian Hryvnia against the US Dollar affect the carrying value of the Group's assets.

Cash from operations has funded the capital investment during the year, and the Group's current cash position and positive operating cash flow are the sources from which the Group plans to fund the development programmes for its assets in 2022 and beyond. This is coupled with the fact that the Group is currently debt-free, and therefore has no debt covenants that may otherwise impede its ability to implement contingency plans if domestic and/or global circumstances dictate. This flexibility and ability to monitor and manage development plans and liquidity is a cornerstone of our planning, and underpins our assessments of the future. With monetary resources at the end of the year of $92.5 million ($63.5 million of which was held outside Ukraine), and annual running costs of less than $ 8 million, the Group remains in a very strong position, notwithstanding the impact of the current conflict in Ukraine, as well as any local or global shocks that may occur to the industry and/or the Group.

On 25 February 2021, the Company completed a reduction of its share capital through the cancellation of its entire share premium account. This reduction of capital creates distributable reserves of the Company, which potentially enables the Company to make distributions to its shareholders in the future, subject to the Company's financial performance. However, the Company is not indicating any commitment, and does not have any current intention, to make any distributions to shareholders.

Bruce Burrows

Finance Director

Principal Risks and How We Manage Them

The Group has a risk evaluation methodology in place to assist in the review of the risks across all material aspects of its business. This methodology highlights external, operational and technical, financial and corporate risks and assesses the level of risk and potential consequences. It is periodically presented to the Audit Committee and the Board for review, to bring to their attention potential risks and, where possible, propose mitigating actions. Key risks recognised and mitigation factors are detailed below:-

Risk	Mitigation
External risks
Military conflict in Ukraine
On 24 February 2022, Russia invaded Ukraine and there is currently a serious and ongoing military conflict within Ukraine. This conflict is having a huge impact on Ukraine and its population, with significant destruction of infrastructure and buildings in the areas of conflict, as well as damage in other areas of Ukraine. The conflict is resulting in significant casualties and has caused a huge humanitarian catastrophe and refugee influx into neighbouring countries. The conflict is also impacting the fiscal and economic environment in Ukraine, as well as the financial stability and banking system in Ukraine, including restrictions on the transfer of funds outside Ukraine. The conflict is an escalation of the previous Regional Conflict risk faced by the business, a dispute that has been going on since 2014 in parts of eastern Ukraine, and since that time Russia has continued to occupy Crimea. The current conflict is also having a significant adverse effect on the Ukrainian financial markets, hampering the ability of Ukrainian companies and banks to obtain funding from the international capital and debt markets. The conflict has disrupted the Group's business and operations, causing the suspension of field operations, albeit recommenced in March 2022 at the MEX-GOL and SV fields, and has also impacted the supply of materials and equipment and the availability of contractors to undertake field operations. At present, the conflict is ongoing and the scope and duration of the conflict is uncertain.	Although the Group has no assets in Crimea, it does have assets in the areas of conflict in the east of Ukraine, and the conflict has disrupted its operations in those areas. The Group has suspended all field operations at the VAS field and SC licence area, and is only undertaking limited field and production operations at the MEX-GOL and SV fields. At the MEX-GOL and SV fields, inventories of hydrocarbons are being maintained at minimum levels. At the sites where operations are suspended, there are no staff on site, except for necessary security staff. Where possible, all other staff work remotely and have been supplied with all necessary devices and software to facilitate remote working. Additionally, the Group aims to maintain the significant majority of its cash resources outside Ukraine (being 77% as at 24 June 2022). The Group continues to monitor the situation and endeavours to protect its assets and safeguard its staff and contractors.
Risk relating to Ukraine
Ukraine is an emerging market and as such the Group is exposed to greater regulatory, economic and political risks than it would be in other jurisdictions. Emerging economies are generally subject to a volatile political and economic environment, which makes them vulnerable to market downturns elsewhere in the world and could adversely impact the Group's ability to operate in the market. Furthermore, the military conflict in Ukraine is impacting the fiscal and economic environment, the financial and banking system, and the economic stability of Ukraine. As a result, Ukraine will require financial assistance and/or aid from international financial agencies to provide economic support and assist with the reconstruction of infrastructure and buildings damaged in the conflict.	The Group minimises this risk by continuously monitoring the market in Ukraine and by maintaining a strong working relationship with the Ukrainian regulatory authorities. The Group also maintains a significant proportion of its cash holdings in international banks outside Ukraine.
Banking system in Ukraine
The banking system in Ukraine has been under great strain in recent years due to the weak level of capital, low asset quality caused by the economic situation, currency depreciation, changing regulations and other economic pressures generally, and so the risks associated with the banks in Ukraine have been significant, including in relation to the banks with which the Group has operated bank accounts. This situation was improving moderately following remedial action by the National Bank of Ukraine, but the current military conflict has significantly affected such improvements, and the National Bank of Ukraine has imposed a number of restrictive measures designed to protect the banking system, including restrictions of the transfer of funds outside Ukraine (albeit that the Group aims to maintain the significant majority of its cash resources outside Ukraine (being 77% as at 24 June 2022). In addition, Ukraine continues to be supported by funding from the International Monetary Fund, and has requested further funding support from the International Monetary Fund.	The creditworthiness and potential risks relating to the banks in Ukraine are regularly reviewed by the Group, but the geopolitical and economic events in Ukraine over recent years have significantly weakened the Ukrainian banking sector. This has been exacerbated by the current military conflict in Ukraine. In light of this, the Group has taken and continues to take steps to diversify its banking arrangements between a number of banks in Ukraine. These measures are designed to spread the risks associated with each bank's creditworthiness, and the Group endeavours to use banks that have the best available creditworthiness.  Nevertheless, and despite the recent improvements, the Ukrainian banking sector remains weakly capitalised and so the risks associated with the banks in Ukraine remain significant, including in relation to the banks with which the Group operates bank accounts. As a consequence, the Group also maintains a significant proportion of its cash holdings in international banks outside Ukraine.
Geopolitical environment in Ukraine
Although there were some improvements in recent years, there has not been a final resolution of the political, fiscal and economic situation in Ukraine, and the current military conflict has had a severe detrimental effect on the economic situation in Ukraine. The ongoing effects of this are difficult to predict and likely to continue to affect the Ukrainian economy and potentially the Group's business. This situation is currently affecting the Group's production and field operations, and the ongoing instability is disrupting the Group's development and operational planning for its assets.	The Group continually monitors the market and business environment in Ukraine and endeavours to recognise approaching risks and factors that may affect its business. In addition, the involvement of Smart Holding (Cyprus) Limited, as an indirect major shareholder with extensive experience in Ukraine, is considered helpful to mitigate such risks. However, the invasion of Ukraine creates material challenges in planning future investment and operations. The Group is limiting its operational activities to minimise risk to its staff and contractors, and to limit its financial exposure.
Climate change
Any near and medium-term continued warming of the Planet can have potentially increasing negative social, economic and environmental consequences, generally, globally and regionally, and specifically in relation to the Group. The potential impacts include: loss of market; and increased costs of operations through increasing regulatory oversight and controls, including potential effective or actual loss of licences to operate. As a diligent operator aware of and responsive to its good stewardship responsibilities, the Group not only needs to monitor and modify its business plans and operations to react to changes, but also to ensure its environmental footprint is as minimal as it can practicably be in managing the hydrocarbon resources the Group produces.	The Group's plans include: assessing, reducing and/or mitigating its emissions in its operations ; and identifying climate change-related risks and assessing the degree to which they can affect its business, including financial implications. The HSE Committee, which was established in 2020, is specifically tasked with overseeing measuring, benchmarking and mitigating the Group's environmental and climate impact, which will be reported on in future periods. At this stage, the Group does not consider climate change to have any material implications on the Group's financial statements, including accounting estimates.
Operational and technical risks
Quality, Health, Safety and Environment ("QHSE")
The oil and gas industry, by its nature, conducts activities which can cause health, safety, environmental and security incidents. Serious incidents can not only have a financial impact but can also damage the Group's reputation and the opportunity to undertake further projects. The military conflict in Ukraine poses significant risks to field operations, by way of potential threat to the lives of employees and contractors, and damage to equipment and infrastructure.	The Group maintains QHSE policies and requires that management, staff and contractors adhere to these policies. The policies ensure that the Group meets Ukrainian legislative standards in full and achieves international standards to the maximum extent possible. As a consequence of the COVID-19 pandemic the Group has implemented processes and controls intended to ensure protection of all our stakeholders and minimise any disruption to our business. As a consequence of the current military conflict in Ukraine, operations at the VAS field and SC licence area are currently suspended entirely, and only limited field and production operations are continuing at the MEX-GOL and SV fields. Only essential staff are located at site, and all other staff are working remotely, either from areas away from the conflict areas or outside Ukraine. The Group has invested in technology that allows many staff to work just as effectively from remote locations.
Industry risks
The Group is exposed to risks which are generally associated with the oil and gas industry. For example, the Group's ability to pursue and develop its projects and undertake development programmes depends on a number of uncertainties, including  the  availability of capital, seasonal  conditions, regulatory approvals, gas, oil, condensate and LPG prices, development costs and drilling success. As a result of these uncertainties, it is unknown whether potential drilling locations identified on proposed projects will ever be drilled or whether these or any other potential drilling locations will be able to produce gas, oil or condensate. In addition, drilling activities are subject to many risks, including the risk that commercially productive reservoirs will not be discovered. Drilling for hydrocarbons can be unprofitable, not only due to dry holes, but also as a result of productive wells that do not produce sufficiently to be economic. In addition, drilling and production operations are highly technical and complex activities and may be curtailed, delayed or cancelled as a result of a variety of factors.	The Group has well qualified and experienced technical management staff to plan and supervise operational activities. In addition, the Group engages with suitably qualified local and international geological, geophysical and engineering experts and contractors to supplement and broaden the pool of expertise available to the Group. Detailed planning of development activities is undertaken with the aim of managing the inherent risks associated with oil and gas exploration and production, as well as ensuring that appropriate equipment and personnel are available for the operations, and that local contractors are appropriately supervised.
Production of hydrocarbons
Producing gas and condensate reservoirs are generally characterised by declining production rates which vary depending upon reservoir characteristics and other factors. Future production of the Group's gas and condensate reserves, and therefore the Group's cash flow and income, are highly dependent on the Group's success in operating existing producing wells, drilling new production wells and efficiently developing and exploiting any reserves, and finding or acquiring additional reserves. The Group may not be able to develop, find or acquire reserves at acceptable costs. The experience gained from drilling undertaken to date highlights such risks as the Group targets the appraisal and production of these hydrocarbons.	In recent years, the Group has engaged external technical consultants to undertake a comprehensive review and re-evaluation study of the MEX-GOL and SV fields in order to gain an improved understanding of the geological aspects of the fields and reservoir engineering, drilling and completion techniques, and the results of this study and further planned technical work are being used by the Group in the future development of these fields. The Group has established an ongoing relationship with such external technical consultants to ensure that technical management and planning is of a high quality in respect of all development activities on the Group's fields.
Risks relating to the further development and operation of the Group's gas and condensate fields in Ukraine
The planned development and operation of the Group's gas and condensate fields in Ukraine is susceptible to appraisal, development and operational risk. This could include, but is not restricted to, delays in the delivery of equipment in Ukraine, failure of key equipment, lower than expected production from wells that are currently producing, or new wells that are brought on-stream, problematic wells and complex geology which is difficult to drill or interpret. The generation of significant operational cash is dependent on the successful delivery and completion of the development and operation of the fields. The military conflict in Ukraine is impacting planning and implementation of development and operations at the Group's fields.	The Group's technical management staff, in consultation with its external technical consultants, carefully plan and supervise development and operational activities with the aim of managing the risks associated with the further development of the Group's fields in Ukraine. This includes detailed review and consideration of available subsurface data, utilisation of modern geological software, and utilisation of engineering and completion techniques developed for the fields. With regards to operational activities, the Group ensures that appropriate equipment and personnel are available for the operations, and that operational contractors are appropriately supervised. In addition, the Group performs a review of indicators of impairment of its oil and gas assets on an annual basis, and considers whether an assessment of its oil and gas assets by a suitably qualified independent assessor is appropriate or required.
Drilling and workover operations
Due to the depth and nature of the reservoirs in the Group's fields, the technical difficulty of drilling or re-entering wells in the Group's fields is high, and this and the equipment limitations within Ukraine, can result in unsuccessful or lower than expected outcomes for wells.	The utilisation of detailed sub-surface analysis, careful well planning and engineering design in designing work programmes, along with appropriate procurement procedures and competent on-site management, aims to minimise these risks.
Maintenance of facilities
There is a risk that production or transportation facilities can fail due to non-adequate maintenance, control or poor performance of the Group's suppliers.	The Group's facilities are operated and maintained at standards above the Ukrainian minimum legal requirements. Operations staff are experienced and receive supplemental training to ensure that facilities are properly operated and maintained. Service providers are rigorously reviewed at the tender stage and are monitored during the contract period.
Financial risks
Exposure to cash flow and liquidity risk
There is a risk that insufficient funds are available to meet the Group's development obligations to commercialise the Group's oil and gas assets. Since a significant proportion of the future capital requirements of the Group is expected to be derived from operational cash generated from production, including from wells yet to be drilled, there is a risk that in the longer term insufficient operational cash is generated, or that additional funding, should the need arise, cannot be secured. The military conflict in Ukraine has disrupted production operations at the Group's fields, and consequently reduced anticipated cash flows from those fields, and this has increased the risk regarding sufficiency of capital for development. In addition, the conflict may disrupt the sales market for hydrocarbons that are produced. Currently, however, hydrocarbon prices are very high, which is ameliorating the potential reduction in cash flows, and the Group's sales counterparties are meeting their financial obligations.	The Group maintains adequate cash reserves and closely monitors forecasted and actual cash flow, as well as short and longer-term funding requirements. T he Group aims to maintain the significant majority of its cash resources outside Ukraine (being 77% as at 24 June 2022). The Group does not currently have any loans outstanding, internal financial projections are regularly made based on the latest estimates available, and various scenarios are run to assess the robustness of the Group's liquidity. However, as the risk to future capital funding is inherent in the oil and gas exploration and development industry and reliant in part on future development success, it is difficult for the Group to take any other measures to further mitigate this risk, other than tailoring its development activities to its available capital funding from time to time.
Ensuring appropriate business practices
The Group operates in Ukraine, an emerging market, where certain inappropriate business practices may, from time to time occur, such as corrupt business practices, bribery, appropriation of property and fraud, all of which can lead to financial loss.	The Group maintains anti-bribery and corruption policies in relation to all aspects of its business, and ensures that clear authority levels and robust approval processes are in place, with stringent controls over cash management and the tendering and procurement processes. In addition, office and site protection is maintained to protect the Group's assets.
Hydrocarbon price risk
The Group derives its revenue principally from the sale of its Ukrainian gas, condensate and LPG production. These revenues are subject to commodity price volatility and political influence. A prolonged period of low gas, condensate and LPG prices may impact the Group's ability to maintain its long-term investment programme with a consequent effect on its growth rate, which in turn may impact the Company's share price or any shareholder returns. Lower gas, condensate and LPG prices may not only decrease the Group's revenues per unit, but may also reduce the amount of gas, condensate and LPG which the Group can produce economically, as would increases in costs associated with hydrocarbon production, such as subsoil taxes and royalties. The overall economics of the Group's key assets (being the net present value of the future cash flows from its Ukrainian projects) are far more sensitive to long term gas, condensate and LPG prices than short-term price volatility. However, short-term volatility does affect liquidity risk, as, in the early stage of the projects, income from production revenues is offset by capital investment. In addition, t he military conflict in Ukraine may disrupt the sales market for hydrocarbons, although, currently, hydrocarbon prices are very high, and the Group's sales counterparties are meeting their financial obligations.	The Group sells a proportion of Its hydrocarbon production through offtake arrangements, which include pricing formulae so as to ensure that it achieves market prices for its products, as well utilising the electronic market platforms in Ukraine to achieve market prices for its remaining products.  However, hydrocarbon prices in Ukraine are implicitly linked to world hydrocarbon prices and so the Group is subject to external price trends. In January 2022, the Ukrainian Government imposed temporary partial gas price regulations until 30 April 2022, designed to support the production of certain designated food products. Whilst an unhelpful interference in the functioning of the deregulated gas supply market in Ukraine, in its stated form and duration, this temporary scheme is not a material risk to the Company and its cash generation, and has now expired.
Currency risk
Since the beginning of 2014 , the Ukrainian Hryvnia significantly devalued against major world currencies, including the US Dollar, where it has fallen from UAH8.3/$1.00 on 1 January 2014 to UAH27.3/$1.00 on 31 December 2021. This devaluation has been a significant contributor to the imposition of banking restrictions by the National Bank of Ukraine over recent years. In addition, the geopolitical events in Ukraine over recent years and the current military conflict in Ukraine are likely to continue to impact the valuation of the Ukrainian Hryvnia against major world currencies. Further devaluation of the Ukrainian Hryvnia against the US Dollar will affect the carrying value of the Group's assets.	The Group's sales proceeds are received in Ukrainian Hryvnia, and the majority of the capital expenditure costs for the current investment programme will be incurred in Ukrainian Hryvnia, thus the currency of revenue and costs are largely matched. In light of the previous devaluation and volatility of the Ukrainian Hryvnia against major world currencies, and since the Ukrainian Hryvnia does not benefit from the range of currency hedging instruments which are available in more developed economies, the Group has adopted a policy that, where possible, funds not required for use in Ukraine be retained on deposit in the United Kingdom and Europe, principally in US Dollars.
Counterparty and credit risk
The challenging political and economic environment in Ukraine and current military conflict means that businesses can be subject to significant financial strain, which can mean that the Group is exposed to increased counterparty risk if counterparties fail or default in their contractual obligations to the Group, including in relation to the sale of its hydrocarbon production, resulting in financial loss to the Group.	The Group monitors the financial position and credit quality of its contractual counterparties and seeks to manage the risk associated with counterparties by contracting with creditworthy contractors and customers. Hydrocarbon production is sold on terms that limit supply credit and/or title transfer until payment is received .
Financial markets and economic outlook
The performance of the Group is influenced by global economic conditions and, in particular, the conditions prevailing in the United Kingdom and Ukraine. The economies in these regions have been subject to volatile pressures in recent periods, with the global economy having experienced a long period of difficulty, the COVID pandemic, and more particularly the current military conflict in Ukraine.  This has led to extreme foreign exchange movements in the Ukrainian Hryvnia , high inflation and interest rates, and increased credit risk relating to the Group's key counterparties.	The Group's sales proceeds are received in Ukrainian Hryvnia and a significant proportion of investment expenditure is made in Ukrainian Hryvnia , which minimises risks related to foreign exchange volatility. However, hydrocarbon prices in Ukraine are implicitly linked to world hydrocarbon prices and so the Group is subject to external price movements. The Group holds a significant proportion of its cash reserves in the United Kingdom and Europe, mostly in US Dollars, with reputable financial institutions. The financial status of counterparties is carefully monitored to manage counterparty risks. Nevertheless, the overall exposure that the Group faces as a result of these risks cannot be predicted and many of these are outside of the Group's control.
Corporate risks
Ukrainian production licences
The Group operates in a region where the right to production can be challenged by State and non-State parties. During 2010, this manifested itself in the form of a Ministry Order instructing the Group to suspend all operations and production from its MEX-GOL and SV production licences, which was not resolved until mid-2011. In 2013, new rules relating to the updating of production licences led to further challenges being raised by the Ukrainian authorities to the production licences held by independent oil and gas producers in Ukraine, including the Group. In March 2019, a Ministry Order was issued instructing the Group to suspend all operations and production from its VAS production licence. The Group is challenging this Order through legal proceedings, during which production from the licence is able to continue (although the Russian invasion has currently caused production to be suspended), but this matter remains unresolved. In 2020, LLC Arkona Gas-Energy ("Arkona") faced a challenge from PJSC Ukrnafta concerning the validity of its SC production licence , which was ultimately resolved in Arkona's favour by a decision of the Supreme Court of Ukraine in February 2021. All such challenges affecting the Group have thus far been successfully defended through the Ukrainian legal system. However, the business environment is such that these types of challenges may arise at any time in relation to the Group's operations, licence history, compliance with licence commitments and/or local regulations. In addition, production licences in Ukraine are issued with and/or carry ongoing compliance obligations, which if not met, may lead to the loss of a licence.	The Group ensures compliance with commitments and regulations relating to its production licences through Group procedures and controls or, where this is not immediately feasible for practical or logistical considerations, seeks to enter into dialogue with the relevant Government bodies with a view to agreeing a reasonable time frame for achieving compliance or an alternative, mutually agreeable course of action. Work programmes are designed to ensure that all licence obligations are met and continual interaction with Government bodies is maintained in relation to licence obligations and commitments.
Risks relating to key personnel
The Group's success depends upon skilled management as well as technical expertise and administrative staff. The loss of service of critical members from the Group's team could have an adverse effect on the business. The current military conflict in Ukraine has meant that, as far as possible, the Group's staff have needed to move away from areas of conflict and work remotely.	The Group periodically reviews the compensation and contractual terms of its staff. In addition, the Group has developed relationships with a number of technical and other professional experts and advisers, who are used to provide specialist services as required. As a result of the military conflict, o nly essential staff are located at site, and all other staff are working remotely, either from areas away from the conflict areas or outside Ukraine. The Group has invested in technology that allows many staff to work just as effectively from remote locations.

Consolidated Income Statement

for the year ended 31 December 2021

		202 1	2020
	Note	$000	$000
Revenue	5	121,353	47,251
Cost of sales	6	(47,422)	(31, 511 )
Gross profit		73,931	15, 740
Administrative expenses	7	(8,350)	(7,791)
Other operating gains, (net)	10	654	1, 821
Operating profit		66,235	9, 770
Finance income	11	1,394	-
Finance costs	12	(752)	(1,418)
Net impairment (losses)/gains on financial assets		(177)	24
Other losses, (net)	13	(108)	(1,856)
Profit before taxation		66,592	6, 520
Income tax expense	14	(15,473)	(3,332)
Profit for the year		51,119	3, 188
Earnings per share (cents)
Basic and diluted	16	15.9c	1.0c

The Notes set out below are an integral part of these consolidated financial statements.

Consolidated Statement of Comprehensive Income

for the year ended 31 December 2021

		202 1	2020
		$000	$000
Profit for the year		51,119	3, 188
Other comprehensive income/(expense):
Items that may be subsequently reclassified to profit or loss:
Equity - foreign currency translation		1,611	(15,050)
Items that will not be subsequently reclassified to profit or loss:
Re-measurements of post-employment benefit obligations		172	(73)
Total other comprehensive income/(expense)		1,783	(15,123)
Total comprehensive income/(expense) for the year		52,902	(11 , 935)

The Notes set out below are an integral part of these consolidated financial statements.

Consolidated Balance Sheet

as at 31 December 2021

		202 1	20 20
	Note	$000	$000
Assets
Non-current assets
Property, plant and equipment	18	87,418	65, 662
Intangible assets	1 9	12,340	12,232
Right-of-use assets	20	1,008	512
Corporation tax receivable		-	9
Deferred tax asset	2 5	361	167
		101,127	78, 582
Current assets
Inventories	22	1,862	1,541
Trade and other receivables	23	13,059	4,847
Cash and cash equivalents	24	87,780	60,993
Other short-term investments	24	4,762	-
		107,463	67,381
Total assets		208,590	145, 963
Liabilities
Current liabilities
Trade and other payables	25	(12,306)	(6,641)
Lease liabilities	20	(455)	(245)
Corporation tax payable		(5,445)	(1,062)
		(18,206)	(7,948)
Net current assets		89,257	59,433
Non-current liabilities
Provision for decommissioning	26	(5,467)	(6,819)
Lease liabilities	20	(648)	(371)
Defined benefit liability		(427)	(530)
Deferred tax liability	27	(5,197)	(2,705)
Other non-current liabilities		(128)	(1,975)
		(11,867)	(12,400)
Total liabilities		(30,073)	(20,348)
Net assets		178,517	125, 615
Equity
Called up share capital	28	28,115	28,115
Share premium account	17	-	555,090
Foreign exchange reserve	29	(103,611)	(105,222)
Merger reserve	29	(3,204)	(3,204)
Capital contributions reserve	29	7,477	7,477
Retained earnings/(Accumulated losses)		249,740	(356, 641 )
Total equity		178,517	125, 615

The Notes set out below are an integral part of these consolidated financial statements.

Consolidated Statement of Changes in Equity

for the year ended 31 December 2021

	Called up share capital	Share premium account	Merger reserve	Capital contributions reserve	Foreign exchange reserve*	Retained earnings/(Accumulated losses)	Total equity
	$000	$000	$000	$000	$000	$000	$000
As at 1 January 2020	28,115	555,090	(3,204)	7,477	(90,172)	(359,756)	137,550
Profit for the year	-	-	-	-	-	3, 188	3, 188
Other comprehensive expense   - exchange differences	-	-	-	-	(15,050)	-	(15,050)
- re-measurements of post-employment benefit obligations	-	-	-	-	-	(73)	(73)
Total comprehensive income/( expense)	-	-	-	-	(15,050)	3, 115	(1 1 , 935 )
As at 31 December 2020	28,115	555,090	(3,204)	7,477	(105,222)	(356, 641 )	125, 615
	Called up share capital	Share premium account	Merger reserve	Capital contributions reserve	Foreign exchange reserve*	Retained earnings/(Accumulated losses)	Total equity
	$000	$000	$000	$000	$000	$000	$000
As at 1 January 202 1	28,115	555,090	(3,204)	7,477	( 105 , 22 2)	(35 6 , 641 )	1 25 , 615
Profit for the year	-	-	-	-	-	51,119	51,119
Other comprehensive income   - exchange differences	-	-	-	-	1,611	-	1,611
- re-measurements of post-employment benefit obligations	-	-	-	-	-	172	172
Total comprehensive income/( expense)	-	-	-	-	1,611	51,291	52,902
Cancellation of share premium account (Note 17)	-	(555,090)	-	-	-	555,090	-
As at 31 December 202 1	28,115	-	(3,204)	7,477	(103,611)	249,740	178,517
* Predominantly as a result of exchange differences on non-monetary assets and liabilities where the subsidiaries' functional currency is not the US Dollar.

The Notes set out below are an integral part of these consolidated financial statements.

Consolidated Cash Flow Statement

for the year ended 31 December 2021

		202 1	20 20
	Note	$000	$000
Operating activities
Cash generated from operations	30	77,646	2 3 ,7 64
Charitable donations	13	(76)	(2,077)
Income tax paid		(8,959)	(3,850)
Interest received		763	1,487
Net cash inflow from operating activities		69,374	19,324
Investing activities
Purchase of oil and gas development, production and other property, plant and equipment		(26,292)	(12,749)
Purchase of oil and gas exploration and evaluation assets		(11,387)	(4,154)
Purchase of financial instruments	24	(4,762)	-
Purchase of oil and gas development, production and other intangible assets		(5 39 )	(194)
Proceeds from return of prepayments for shares		250	250
Proceeds from sale of property, plant and equipment		10	4
Net cash outflow from investing activities		(42,720)	(16,843)
Financing activities
Payment of principal portion of lease liabilities		(555)	(543)
Net cash outflow from financing activities		(555)	(543)
Net increase in cash and cash equivalents		26,099	1,938
Cash and cash equivalents at the beginning of the year		60,993	62,474
ECL* of cash and cash equivalents		(6)	(6)
Effect of foreign exchange rate changes		694	(3,413)
Cash and cash equivalents at the end of the year	24	87,780	60,993

*ECL - Expected credit losses

The Notes set out below are an integral part of these consolidated financial statements.

Notes forming part of the financial statements

1. Statutory Accounts

The financial information set out above does not constitute the Company's statutory accounts for the year ended 31 December 2021 or 2020, but is derived from those accounts. The Auditor has reported on those accounts, and its reports were unqualified and did not contain statements under sections 498(2) or (3) of the Companies Act 2006. The auditors' report on the Group financial statements included a material uncertainty in respect of the Group's ability to continue as a going concern as explained in the section "Going Concern" in Note 3 below.

The statutory accounts for 2021 will be delivered to the Registrar of Companies following publication.

While the financial information included in this preliminary announcement has been prepared in accordance with UK-adopted International Accounting Standards ("framework"), this announcement does not itself contain sufficient information to comply with the framework. The Company expects to distribute the full financial statements that comply with UK-adopted International Accounting Standards by 30 June 2022.

2.  General Information and Operational Environment

Enwell Energy plc (the "Company") and its subsidiaries (the "Group") is a gas, condensate and LPG production group.

The Company is a public limited company quoted on the AIM Market operated by London Stock Exchange plc and incorporated in England and Wales under the Companies Act 2006. The Company's registered office is at 16 Old Queen Street, London, SW1H 9HP, United Kingdom and its registered number is 4462555. The principal activities of the Group and the nature of the Group's operations are set out above.

As at 31 December 2021 and 2020, the Company's immediate parent company was Smart Energy (CY) Limited, which is 100% owned by Smart Holding (Cyprus) Limited, which is 100% owned by Mr Vadym Novynskyi. Accordingly, the Company was ultimately controlled by Mr Vadym Novynskyi.

The Group's gas, condensate and LPG extraction and production facilities are located in Ukraine. Since 2013, there has been ongoing political and economic instability in Ukraine, which has led to a deterioration of Ukrainian State finances, volatility of financial markets, illiquidity on capital markets, higher inflation and a depreciation of the national currency against major foreign currencies, although there had been some recent gradual improvements.

Impact of the ongoing war in Ukraine

On 24 February 2022, Russia commenced a military invasion of Ukraine. This was quickly followed by the enactment of martial law by the Ukrainian President's Decree, approved by the Parliament of Ukraine, and the corresponding introduction of related temporary restrictions that impact, amongst other areas, the economic environment and business operations in Ukraine.

Currently, four months after the initial military attack, fighting continues in and around several major Ukrainian cities, causing very significant numbers of reported military and civilian casualties and significant dislocation of the Ukrainian population. As of the date hereof, the Russian army has occupied territories in the east and south of Ukraine, including the majority of the Kherson, Zaporizhzhia, Luhansk and Donetsk regions. Russian attacks have targeted and destroyed civilian infrastructure over wide areas of Ukraine, including hospitals and residential complexes. The invasion caused, and continues to cause, significant turbulence and disruption to the social and economic environment in Ukraine, with many businesses being forced to suspend their operations. According to a projection published by the International Monetary Fund ("IMF") in April 2022, Ukrainian GDP may fall 35% in 2022.

On 3 June 2022, the National Bank of Ukraine ("NBU") increased the key policy interest rate to 25%, which was aimed at suspending price increases and strengthening the Ukrainian Hryvnia exchange rate. The NBU has also introduced temporary restrictions on foreign currency trades and limited the ability to perform cross-border payments for non-critical imports and repayment of debt to foreign creditors, apart from international institutions. The Ukrainian Hryvnia exchange rate with the US Dollar was effectively fixed at UAH29.25:$1.00 on the foreign exchange market to ensure the stable operation of Ukraine's financial system. As a result, commercial interbank quotes remain close to the officially imposed NBU exchange rate. Despite the uncertainty and instability in the general situation within Ukraine, the banking system remains relatively stable, with sufficient liquidity even as martial law continues, and banking services are available to both legal entities and individual bank customers .

The Ukrainian Government is taking action to limit the negative effects of the war on the Ukrainian economic environment during the period of martial law and beyond, including but not limited to:

●	the Parliament of Ukraine has adopted a temporary easing of the tax regime until the end of martial law, including the suspension of tax audits and has cancelled penalties for violating the tax law;
●	gasoline, heavy distillates, liquefied gas, oil and petroleum are subject to VAT at a reduced rate of 7%, and the excise tax rate for the imported fuel group of products' is set at zero;
●	a number of measures were taken to limit prices for energy resources, including prohibiting export of gas, setting a level of electricity price on transactions a day ahead and intraday markets; and
●	the Parliament of Ukraine passed a law (№ 7038-d) to increase the subsoil tax rate on natural gas production during martial law. This law introduced a differentiated subsoil tax rate on the production of natural gas depending on sale prices for natural gas.

Additional financial support was received from a number of international institutions, including from the IMF and European Bank for Reconstruction and Development ("EBRD"), to support the economy and the population. Such financial support is critical for Ukraine to continue to service its debts in the foreseeable future, including record high State debt repayments in 2022.

Given the fast-moving nature of the situation in Ukraine and the unpredictability of the outcome, it is impracticable to assess the full impact of the war on the economic environment.

Gas market developments

On 30 December 2021, the Cabinet of Ministers adopted Resolution № 1433 and Resolution № 1435, according to which all independent gas producers in Ukraine (as identified by a Committee set up by the Ukrainian Government (the "Committee")) were required to sell up to 20% of their natural gas production for the period until 30 April 2022 at a price set at the cost of sales of the relevant gas producer (based on established accounting rules) for such gas, plus a margin of 24%, plus existing production taxes (the "Regulated Price"). This gas was then to be sold to specified producers of designated socially important food products (as identified by the Committee) at the Regulated Price to reduce the energy costs of such producers during the period through to 30 April 2022. Although the introduction of these measures pre-dated the military conflict in Ukraine, their impact has coincided with the military conflict, but nevertheless, the measures have not had a material financial impact on the Group, given the modest volume of gas sold at Regulated Prices and the reduced production during the applicable period.

On 15 March 2022, the Ukrainian Parliament adopted the Law of Ukraine № 2139-IX "On amendments to the Tax Code of Ukraine and certain legislative acts of Ukraine on the introduction of differentiated rent (subsoil tax) for natural gas production", which introduced changes to the subsoil production tax rates applicable to natural gas production by modifying the applicable rates based on gas prices, extending the incentive rates for new wells for a further 10 years and making improvements to the regulatory environment. These changes took effect on 1 March 2022, and the legislation includes provisions that these rates will not be increased for 10 years.

The new subsoil production tax rates are as follows:

(a)  when gas prices are up to $150/Mm³, the rate for wells drilled prior to 1 January 2018 ("old wells") is 14.5% for gas produced from deposits at depths shallower than 5,000 metres and 7% for gas produced from deposits deeper than 5,000 metres, and for wells drilled after 1 January 2018 ("new wells") is 6% for gas produced from deposits at depths shallower than 5,000 metres and 3% for gas produced from deposits deeper than 5,000 metres;

(b)  when gas prices are between $150/Mm³ and $400/Mm³, the rate for old wells is 29% for gas produced from deposits at depths shallower than 5,000 metres and 14% for gas produced from deposits deeper than 5,000 metres, and for new wells is 12% for gas produced from deposits at depths shallower than 5,000 metres and 6% for gas produced from deposits deeper than 5,000 metres;

(c)  when gas prices are more than $400/Mm³, for the first $400/Mm³, the rate for old wells is 29% for gas produced from deposits at depths shallower than 5,000 metres and 14% for gas produced from deposits deeper than 5,000 metres, and for new wells is 12% for gas produced from deposits at depths shallower than 5,000 metres and 6% for gas produced from deposits deeper than 5,000 metres, and for the difference between $400/Mm³ and the actual price, the rate for old wells is 65% for gas produced from deposits at depths shallower than 5,000 metres and 31% for gas produced from deposits deeper than 5,000 metres, and for new wells is 36% for gas produced from deposits at depths shallower than 5,000 metres and 18% for gas produced from deposits deeper than 5,000 metres.

Prior to the changes, the tax rate for old wells was 29% for gas produced from deposits at depths shallower than 5,000 metres and 14% for gas produced from deposits deeper than 5,000 metres, and for new wells was 12% for gas produced from deposits at depths shallower than 5,000 metres and 6% for gas produced from deposits deeper than 5,000 metres. The tax rates applicable to condensate production were unchanged and remain at 31% for condensate produced from deposits shallower than 5,000 metres and 16% for condensate produced from deposits deeper than 5,000 metres, for both old and new wells.

COVID-19 impact

The COVID-19 pandemic had a significant impact on the economic environment in Ukraine and throughout the world. The rapid spread of the COVID-19 coronavirus pandemic, and the restrictions introduced to counteract the pandemic significantly impacted global commodity and financial markets. The overall impact of COVID-19 will largely depend on the duration and extent of the effects of the pandemic on the global and Ukrainian economies. Businesses in Ukraine adapted to operating in new realities, arranging remote work, supply and sale modes of operation. At the date hereof, based on the available information, management believes that the uncertainties attributable to COVID-19 do not represent a key risk factor that may materially affect the liquidity and continuity of the Group's operations.

Overall, the final resolution and the ongoing effects of the military conflict and political and economic situation in Ukraine are difficult to predict, but they may have further severe effects on the Ukrainian economy and the Group's business.

As at 24 June 2022, the official NBU exchange rate of the Ukrainian Hryvnia against the US Dollar was UAH29.25/$1.00, compared with UAH27.23/$1.00 as at 31 December 2021.

Further details of risks relating to Ukraine can be found within the Principal Risks section above.

3.  Accounting Policies

The principal accounting policies applied in the preparation of these consolidated financial statements are set out below. These policies have been consistently applied to all the years presented, unless otherwise stated.

Basis of Preparation

On 31 December 2020, IFRS as adopted by the European Union at that date was brought into UK law and became UK-adopted International Accounting Standards, with future changes being subject to endorsement by the UK Endorsement Board. The Group and Company transitioned to UK-adopted International Accounting Standards on 1 January 2021. This change constitutes a change in accounting framework. However, there is no impact on recognition, measurement or disclosure in the period reported as a result of the change in framework. The consolidated financial statements of the Group and the financial statements of the Company have been prepared in accordance with UK-adopted International Accounting Standards and with the requirements of the Companies Act 2006 as applicable to companies reporting under those standards.

These consolidated financial statements have been prepared in accordance with UK-adopted International Accounting Standards under the historical cost convention, as modified by the initial recognition of financial instruments based on fair value, and by the revaluation of financial instruments categorised at fair value through profit or loss ("FVTPL") and at fair value through other comprehensive income ("FVOCI"). The principal accounting policies applied in the preparation of these consolidated financial statements are set out below. Apart from the accounting policy changes effective from 1 January 2021 these policies have been consistently applied to all the periods presented, unless otherwise stated.

The preparation of financial statements in conformity with UK-adopted International Accounting Standards requires the use of certain critical accounting estimates. It also requires management to exercise its judgement in the process of applying the Group's accounting policies. The areas involving a higher degree of judgement or complexity, or areas where assumptions and estimates are significant to the consolidated financial statements are disclosed in Note 4.

Going Concern

The Group's business activities, together with the factors likely to affect its future operations, performance and position are set out in the Chairman's Statement, Chief Executive's Statement and Finance Review. The financial position of the Group, its cash flows and liquidity position are set out in these consolidated financial statements.

On 24 February 2022, Russia commenced a military invasion of Ukraine. This was quickly followed by the enactment of martial law by the Ukrainian President's Decree, approved by the Parliament of Ukraine, and the corresponding introduction of related temporary restrictions that impact the economic environment and business operations in Ukraine.

The production assets of the Group are located in the central and eastern part of the country (Poltava and Kharkiv regions) which are controlled by the Ukrainian Government. Following a brief period of suspension, production and field operations, as well as construction work on upgrades to the gas processing facilities, at the MEX-GOL and SV fields have recommenced. As of the date of approval of these financial statements, no assets of the Group have been damaged, and the Group continues to operate its MEX-GOL, SV and SC assets in the Poltava region, while all production and field operations at the VAS asset located in the Kharkiv region are suspended. At the SC licence area, completion of the drilling of the SC-4 well is planned shortly. No military activities have occurred at the Group's field locations. The Gas Transmission System Operator of Ukraine has maintained complete operational and technological control over the operations of the Ukrainian Gas Transmission System. However, as of the date of approval of these financial statements, the military conflict has had, and continues to have, a material impact on the production and sales levels of the business and execution of the Group's 2022 budget.

The Group has no debt and funds its operations from its own cash resources. Cash and cash equivalents were $76.5 million as at 24 June 2022, of which $58.8 million were held outside of Ukraine, in currencies other than the Ukrainian Hryvnia. The Directors maintain a significant level of flexibility to modify the Group's development plans as may be required to preserve cash resources for liquidity management. Absent the potential impact of the military conflict in Ukraine, the Directors are satisfied that the Group and the Company are a going concern and will continue their operations for the foreseeable future.

In assessing the impact of the military conflict on the ability of the Group and the Company to continue as a going concern, the Directors have analysed a number of possible scenarios of economic and military developments and the impact on the expected cash flows of the Group and Company for 2022 and 2023. This includes considering a possible (but in the view of the Directors, highly unlikely) worst case scenario in which the Group has zero production as a result of possible future military conflict dictating field operations being completely shut-in, and all other non-production related costs being maintained at current levels with no reduction or mitigating actions as would otherwise be possible. Even in this worst-case scenario, the Directors are satisfied that the Group and the Company have sufficient liquid resources to be able to meet their liabilities as they fall due and to be able to continue as a going concern for the foreseeable future.

In respect of the Group's operations, staff and assets in Ukraine, the potential short and long-term impact of the future development of the military conflict is inherently uncertain. Accordingly, this creates a material uncertainty related to events or conditions that may cast significant doubt on the Group's ability to continue as a going concern because of the potential impact on its ability to continue its operations for the foreseeable future and realise its assets in the normal course of business. The financial statements do not include the adjustments that would result if the Group were unable to continue as a going concern.

The Company is a UK-based investment holding company. The Company had cash and cash equivalents of $58.8 million as at 24 June 2022, all of which are held outside of Ukraine, in US Dollars, Pounds Sterling and Euros. The Directors are satisfied that the Company is a going concern and will be able to continue its operations for the foreseeable future, and there is no material uncertainty in respect of its ability to do so.

New and amended standards adopted by the Group

The following amended standards became effective from 1 January 2021, but did not have a material impact on the Group's c onsolidated or Company's financial statements :

●	Interest rate benchmark (IBOR) reform - phase 2 amendments to IFRS 9, IAS 39, IFRS 7, IFRS 4 and IFRS 16 (issued on 27 August 2020 and effective for annual periods beginning on or after 1 January 2021);
●	COVID-19-Related Rent Concessions Amendment to IFRS 16 issued on 28 May 2020 and effective for annual periods beginning on or after 1 April 2021.

Impact of standards issued but not yet applied by the Group

Certain new standards and interpretations have been issued that are mandatory for the annual periods beginning on or after 1 January 2022 or later, and which the Group has not early adopted.

(a)  Sale or Contribution of Assets between an Investor and its Associate or Joint Venture - Amendments to IFRS 10 and IAS 28 (issued on 11 September 2014 and effective for annual periods beginning on or after a date to be determined by the UK Endorsement Board )

(b)  IFRS 17 "Insurance Contracts" (issued on 18 May 2017 and effective for annual periods beginning on or after 1 January 202 3 )

(c)  Amendments to IFRS 17 and an amendment to IFRS 4 (issued on 25 June 2020 and effective for annual periods beginning on or after 1 January 2023)

(d)  Classification of liabilities as current or non-current - Amendments to IAS 1 (issued on 23 January 2020 and effective for annual periods beginning on or after 1 January 2022)

(e)  Classification of liabilities as current or non-current, deferral of effective date - Amendments to IAS 1 (issued on 15 July 2020 and effective for annual periods beginning on or after 1 January 2023) 

(f)  Proceeds before intended use, Onerous contracts - cost of fulfilling a contract, Reference to the Conceptual Framework - narrow scope amendments to IAS 16, IAS 37 and IFRS 3, and Annual Improvements to IFRSs 2018-2020 - amendments to IFRS 1, IFRS 9,  IFRS 16 and IAS 41 (issued on 14 May 2020 and effective for annual periods beginning on or after 1 January 2022)

(g)  Amendments to IAS 1 and IFRS Practice Statement 2: Disclosure of Accounting policies (issued on 12 February 2021 and effective for annual periods beginning on or after 1 January 2023)

(h)  Amendments to IAS 8: Definition of Accounting Estimates (issued on 12 February 2021 and effective for annual periods beginning on or after 1 January 2023)

(i)  Covid-19-Related Rent Concessions - Amendments to IFRS 16 (issued on 31 March 2021 and effective for annual periods beginning on or after 1 April 2021)

(j)  Deferred tax related to assets and liabilities arising from a single transaction - Amendments to IAS 12 (issued on 7 May 2021 and effective for annual periods beginning on or after 1 January 2023)

These new standards and interpretations are not expected to affect significantly the Group's consolidated financial statements.

Exchange differences on intra-group balances with foreign operation

The Group has certain inter-company monetary balances of which the Company is the beneficial owner. These monetary balances are payable by a subsidiary that is a foreign operation and are eliminated on consolidation.

In the consolidated financial statements, exchange differences arising on such payables because the transaction currency differs from the subsidiary's functional currency are recognised initially in other comprehensive income if the settlement of such payables is continuously deferred and is neither planned nor likely to occur in the foreseeable future.

In such cases, the respective receivables of the Company are regarded as an extension of the Company's net investment in that foreign operation, and the cumulative amount of the abovementioned exchange differences recognised in other comprehensive income is carried forward within the foreign exchange reserve in equity and is reclassified to profit or loss only upon disposal of the foreign operation.

When the subsidiary that is a foreign operation settles its quasi-equity liability due to the Company, but the Company continues to possess the same percentage of the subsidiary, i.e. there has been no change in its proportionate ownership interest, such settlement is not regarded as a disposal or a partial disposal, and therefore cumulative exchange differences are not reclassified.

The designation of inter-company monetary balances as part of the net investment in a foreign operation is re-assessed when management's expectations and intentions on settlement change due to a change in circumstances.

Where, because of a change in circumstances, a receivable balance, or part thereof, previously designated as a net investment into a foreign operation is intended to be settled, the receivable is de-designated and is no longer regarded as part of the net investment.

In such cases, the exchange differences arising on the subsidiary's payable following de-designation are recognised within finance costs / income in profit or loss, similar to foreign exchange differences arising from financing.

Foreign exchange gains and losses not related to intra-group balances are recognised on a net basis as other gains or losses.

Basis of Consolidation

The consolidated financial statements incorporate the financial information of the Company and entities controlled by the Company (and its subsidiaries) made up to 31 December each year.

Subsidiaries

Subsidiaries are all entities (including structured entities) over which the Group has control. The Group controls an entity when the Group is exposed to, or has rights to variable returns from its involvement with the entity and has the ability to affect those returns through its power over the entity. Subsidiaries are fully consolidated from the date on which control is transferred to the Group. They are deconsolidated from the date that control ceases.

The Group applies the acquisition method to account for business combinations. The consideration transferred for the acquisition of a subsidiary is the fair value of the assets transferred, the liabilities incurred to the former owners of the acquiree and the equity interests issued by the Group. The consideration transferred includes the fair value of any asset or liability resulting from a contingent consideration arrangement. Identifiable assets acquired and liabilities and contingent liabilities assumed in a business combination are measured initially at their fair values at the acquisition date. The Group recognises any non-controlling interest in the acquiree on an acquisition-by-acquisition basis at the non-controlling interest's proportionate share of the recognised amounts of the acquiree's identifiable net assets.

Acquisition-related costs are expensed as incurred.

If the business combination is achieved in stages, the acquisition date carrying value of the acquirer's previously held equity interest in the acquiree is re-measured to fair value at the acquisition date; any gains or losses arising from such re-measurement are recognised in profit or loss.

Any contingent consideration to be transferred by the Group is recognised at fair value at the acquisition date. Subsequent changes to the fair value of the contingent consideration that is deemed to be an asset or liability is recognised in accordance with IFRS 9 in profit or loss.

Inter-company transactions, balances and unrealised gains on transactions between Group companies are eliminated. Unrealised losses are also eliminated. When necessary, amounts reported by subsidiaries have been adjusted to conform with the Group's accounting policies.

Segment reporting

The Group's only class of business activity is oil and gas exploration, development and production. The Group's primary operations are located in Ukraine, with its head office in the United Kingdom. The geographical segments are the basis on which the Group reports its segment information to management. Operating segments are reported in a manner consistent with the internal reporting provided to the Board of Directors.

Commercial Reserves

Proved and probable oil and gas reserves are estimated quantities of commercially producible hydrocarbons which the existing geological, geophysical and engineering data show to be recoverable in future years from known reservoirs. Proved reserves are those quantities of petroleum that, by analysis of geoscience and engineering data, can be estimated with reasonable certainty to be commercially recoverable from known reservoirs and under defined technical and commercial conditions. Probable reserves are those additional reserves which analysis of geoscience and engineering data indicate are less likely to be recovered than proved reserves but more certain to be recovered than possible reserves. The proved and probable reserves conform to the definition approved by the Petroleum Resources Management System.

Oil and Gas Exploration/Evaluation and Development/Production Assets

The Group applies the successful efforts method of accounting for oil and gas assets, having regard to the requirements of IFRS 6 Exploration for and Evaluation of Mineral Resources.

Exploration costs are incurred to discover hydrocarbon resources. Evaluation costs are incurred to assess the technical feasibility and commercial viability of the resources found. Exploration, as defined in IFRS 6 Exploration and evaluation of mineral resources, starts when the legal rights to explore have been obtained. Expenditure incurred before obtaining the legal right to explore is generally expensed; an exception to this would be separately acquired intangible assets such as payment for an option to obtain legal rights.

Expenditures incurred in the exploration activities are expensed unless they meet the definition of an asset. The Group recognises an asset when it is probable that economic benefits will flow to the Group as a result of the expenditure. The economic benefits might be available through commercial exploitation of hydrocarbon reserves or sales of exploration findings or further development rights. Exploration and evaluation ("E&E") assets are recognised as either property, plant and equipment or intangible assets, according to their nature, in single field cost centres.

The capitalisation point is the earlier of:

(a)   the point at which the fair value less costs to sell the property can be reliably determined as being higher than the total of the expenses incurred and costs already capitalised (such as licence acquisition costs); and

(b)   an assessment of the property demonstrates that commercially viable reserves are present and hence there are probable future economic benefits from the continued development and production of the resource.

E&E assets are reclassified from Exploration and Evaluation when evaluation procedures have been completed. E&E assets that are not commercially viable are written down. E&E assets for which commercially viable reserves have been identified are reclassified to Development and Production assets. E&E assets are tested for impairment immediately prior to reclassification out of E&E.

Once an E&E asset has been reclassified from E&E, it is subject to the normal IFRS requirements. This includes impairment testing at the cash-generating unit ("CGU") level and depreciation.

Abandonment and Retirement of Individual Items of Property, Plant and Equipment

Normally, no gains or losses shall be recognised if only an individual item of equipment is abandoned or retired or if only a single lease or other part of a group of proved properties constituting the amortisation base is abandoned or retired as long as the remainder of the property or group of properties constituting the amortisation base continues to produce oil or gas. Instead, the asset being abandoned or retired shall be deemed to be fully amortised, and its costs shall be charged to accumulated depreciation, depletion or amortisation. When the last well on an individual property (if that is the amortisation base) or group of properties (if amortisation is determined on the basis of an aggregation of properties with a common geological structure) ceases to produce and the entire property or group of properties is abandoned, a gain or loss shall be recognised. Occasionally, the partial abandonment or retirement of a proved property or group of proved properties or the abandonment or retirement of wells or related equipment or facilities may result from a catastrophic event or other major abnormality. In those cases, a loss shall be recognised at the time of abandonment or retirement.

Intangible Assets other than Oil and Gas Assets

Intangible assets other than oil and gas assets are stated at cost less accumulated amortisation and any provision for impairment. These assets represent exploration licences. Amortisation is charged so as to write off the cost, less estimated residual value on a straight-line basis of 20-25% per annum.

Depreciation, Depletion and Amortisation

All expenditure carried within each field is amortised from the commencement of commercial production on a unit of production basis, which is the ratio of gas production in the period to the estimated quantities of commercial reserves at the end of the period plus the production in the period, generally on a field by field basis. In certain circumstances, fields within a single development area may be combined for depletion purposes. Costs used in the unit of production calculation comprise the net book value of capitalised costs plus the estimated future field development costs necessary to bring the reserves into production.

Impairment

At each balance sheet date, the Group reviews the carrying amount of oil and gas development and production assets to determine whether there is any indication that those assets have suffered an impairment loss. This includes exploration and appraisal costs capitalised which are assessed for impairment in accordance with IFRS 6. If any such indication exists, the recoverable amount of the asset is estimated in order to determine the extent of the impairment loss.

For oil and gas development and production assets, the recoverable amount is the greater of fair value less costs to dispose and value in use. In assessing value in use, the estimated future cash flows are discounted to their present value using an expected weighted average cost of capital. If the recoverable amount of an asset is estimated to be less than its carrying amount, the carrying amount of the asset is reduced to its recoverable amount. Impairment losses are recognised as an expense immediately. The valuation method used for determination of fair value less cost of disposal is based on unobservable market data, which is within Level 3 of the fair value hierarchy.

Should an impairment loss subsequently reverse, the carrying amount of the asset is increased to the revised estimate of its recoverable amount, but so that the increased carrying amount does not exceed the carrying amount that would have been determined had no impairment loss been recognised for the asset in prior years. A reversal of an impairment loss is recognised as income immediately.

Decommissioning Provision

Where a material liability for the removal of existing production facilities and site restoration at the end of the productive life of a field exists, a provision for decommissioning is recognised. The amount recognised is the present value of estimated future expenditure determined in accordance with local conditions and requirements. The cost of the relevant property, plant and equipment is increased with an amount equivalent to the provision and depreciated on a unit of production basis. Changes in estimates are recognised prospectively, with corresponding adjustments to the provision and the associated fixed asset. The unwinding of the discount on the decommissioning provision is included within finance costs.

Property, Plant and Equipment other than Oil and Gas Assets

Property, plant and equipment other than oil and gas assets (included in Other fixed assets in Note 18 are stated at cost less accumulated depreciation and any provision for impairment. Depreciation is charged so as to write off the cost of assets on a straight-line basis over their useful lives as follows:

  Useful lives in years

Buildings and constructions	10 to 20 years
Machinery and equipment	2 to 5 years
Vehicles	5 years
Office and other equipment	4 to 12 years

Spare parts and equipment purchased with the intention to be used in future capital investment projects are recognised as oil and gas development and production assets within property, plant and equipment.

Right-of-use assets

The Group leases various offices, equipment, wells and land. Contracts may contain both lease and non-lease components. The Group allocates the consideration in the contract to the lease and non-lease components based on their relative stand-alone prices.

Assets arising from a lease are initially measured on a present value basis.

Right-of-use assets are measured at cost comprising the following:

●	the amount of the initial measurement of lease liability,
●	any lease payments made at or before the commencement date less any lease incentives received,
●	any initial direct costs, and
●	costs to restore the asset to the conditions required by lease agreements.

Right-of-use assets are generally depreciated over the shorter of the asset's useful life and the lease term on a straight-line basis. If the Group is reasonably certain to exercise a purchase option, the right-of-use asset is depreciated over the underlying assets' useful lives. Depreciation on the items of the right-of-use assets is calculated using the straight-line method over their estimated useful lives as follows:

  Useful lives in years

Land	40 to 50 years
Wells	10 to 20 years
Properties:
Buildings and constructions	10 to 20 years
Machinery and equipment	2 to 5 years
Vehicles	5 years
Office and other equipment	4 to 12 years

Inventories

Inventories typically consist of materials, spare parts and hydrocarbons, and are stated at the lower of cost and net realisable value. Cost of finished goods is determined on the weighted average bases. Cost of other than finished goods inventory is determined on the first in first out basis. Net realisable value represents the estimated selling price less all estimated costs of completion and costs to be incurred in marketing, selling and distribution.

Revenue Recognition

Revenue is income arising in the course of the Group's ordinary activities. Revenue is recognised by the amount of the transaction price. Transaction price is the amount of consideration to which the Group expects to be entitled in exchange for transferring control over promised goods or services to a customer, excluding the amounts collected on behalf of third parties.

Revenue is recognised net of indirect taxes and excise duties.

Sales of gas, condensate and LPG are recognised when control of the good has transferred, being when the goods are delivered to the customer, the customer has full discretion over the goods, and there is no unfulfilled obligation that could affect the customer's acceptance of the goods. Delivery occurs when the goods have been shipped to the specific location, the risks of obsolescence and loss have been transferred to the customer, and either the customer has accepted the goods in accordance with the contract, the acceptance provisions have lapsed, or the Group has objective evidence that all criteria for acceptance have been satisfied.

A receivable is recognised when the goods are delivered as this is the point in time that the consideration is unconditional because only the passage of time is required before the payment is due.

The Group normally uses standardised contracts for the sale of gas, condensate and LPG, which define the point of control transfer. The price and quantity of each sale transaction are indicated in the specifications to the sales contracts.

The control over gas is transferred to a customer when the respective act of acceptance is signed by the parties to a contract upon delivery of gas to the point of sale specified in the contract, normally being a certain point in the Ukrainian gas transportation system. Acts of acceptance of gas are signed and the respective revenues are recognised on a monthly basis.

The control over condensate and LPG is transferred to a customer when the respective waybill is signed by the parties to a contract upon shipment of goods at the point of sale specified in the contract, which is normally the Group's production site.

Foreign Currencies

The Group's consolidated financial statements and those of the Company are presented in US Dollars. The functional currency of the subsidiaries which operate in Ukraine is Ukrainian Hryvnia. The remaining entities have US Dollars as their functional currency.

The functional currency of individual companies is determined by the primary economic environment in which the entity operates, normally the one in which it primarily generates and expends cash. In preparing the financial statements of the individual companies, transactions in currencies other than the entity's functional currency ("foreign currencies") are recorded at the rates of exchange prevailing on the dates of the transactions. At each balance sheet date, monetary assets and liabilities that are denominated in foreign currencies are retranslated at the rates prevailing on the balance sheet date. Foreign exchange gains and losses resulting from the settlement of such transactions and from the translation at year-end exchange rates of monetary assets and liabilities denominated in foreign currencies are recognised in the Income Statement. Non-monetary assets and liabilities carried at fair value that are denominated in foreign currencies are translated at the rates prevailing at the date when the fair value was determined. Non-monetary items which are measured in terms of historical cost in a foreign currency are not retranslated. Gains and losses arising on retranslation are included in net profit or loss for the period, except for exchange differences arising on balances which are considered long term investments where the changes in fair value are recognised directly in other comprehensive income.

On consolidation, the assets and liabilities of the Group's subsidiaries which do not use US Dollars as their functional currency are translated into US Dollars as follows:

(a)  assets and liabilities for each Balance Sheet presented are translated at the closing rate at the date of that Balance Sheet;

(b)  income and expenses for each Income Statement are translated at average monthly exchange rates (unless this average is not a reasonable approximation of the cumulative effect of the rates prevailing on the transaction dates, in which case income and expenses are translated at the rate on the dates of the transactions); and

(c)  all resulting exchange differences are recognised in other comprehensive income.

The principal rates of exchange used for translating foreign currency balances as at 31 December 202 1 were $1:UAH2 7 . 3 (20 20 : $1:UAH28.3), $1:£0. 74 1 (20 20 : $1:£ 0.736), $1:€0.8 8 3 (20 20 : $1:€0.81 4 ), and the average rates for the year were $1:UAH27.3 (2020: $1:UAH27.0), $1:£0.727 (2020: $1:£ 0.779), $1:€0.845 (2020: $1:€0.876)

None of the Group's operations are considered to use the currency of a hyperinflationary economy, however this is kept under review.

Pensions

The Group contributes to a local government pension scheme in Ukraine and defined benefit plans. The Group has no further payment obligations towards the local government pension scheme once the contributions have been paid.

Defined benefit plans define an amount of pension benefit that an employee will receive on retirement, usually dependent on one or more factors such as age, years of service and compensation.

The Group companies participate in a mandatory Ukrainian State-defined retirement benefit plan, which provides for early pension benefits for employees working in certain workplaces with hazardous and unhealthy working conditions. The Group also provides lump sum benefits upon retirement subject to certain conditions. The early pension benefit (in the form of a monthly annuity) is payable by employers only until the employee has reached the statutory retirement age. The pension scheme is based on a benefit formula which depends on each individual member's average salary, his/her total length of past service and total length of past service at specific types of workplaces ("list II" category).

The liability recognised in the Balance Sheet in respect of defined benefit pension plans is the present value of the defined benefit obligation at the end of the reporting period less the fair value of plan assets. The defined benefit obligation is calculated annually by independent actuaries using the projected unit credit method. The present value of the defined benefit obligation is determined by discounting the estimated future cash outflows using interest rates of high-quality corporate bonds that are denominated in the currency in which the benefits will be paid, and that have terms to maturity approximating to the terms of the related pension obligation. Since Ukraine has no deep market in such bonds, the market rates on government bonds are used.

The current service cost of the defined benefit plan, recognised in the Income Statement within the Cost of Sales in employee benefit expense, except where included in the cost of an asset, reflects the increase in the defined benefit obligation resulting from employee service in the current year, benefit changes curtailments and settlements. Past-service costs are recognised immediately in the Income Statement.

The net interest cost is calculated by applying the discount rate to the net balance of the defined benefit obligation and the fair value of plan assets. This cost is included in employee benefit expense in the Income Statement within the Cost of Sales.

Actuarial gains and losses arising from experience adjustments and changes in actuarial assumptions are charged or credited to equity in other comprehensive income in the period in which they arise.

Taxation

The tax expense represents the sum of the current tax and deferred tax.

Current tax, including UK corporation and overseas tax, is provided at amounts expected to be paid (or recovered) using the tax rates and laws that have been enacted or substantively enacted by the balance sheet date.

Deferred tax is the tax expected to be payable or recoverable on differences between the carrying amounts of assets and liabilities in the financial statements and the corresponding tax bases used in the computation of taxable profit, and is accounted for using the balance sheet liability method. Deferred tax liabilities are generally recognised for all taxable temporary differences and deferred tax assets are recognised to the extent that it is probable that taxable profits will be available against which deductible temporary differences can be utilised. Such assets and liabilities are not recognised if the temporary difference arises from goodwill or from the initial recognition (other than in a business combination) of other assets and liabilities in a transaction that affects neither the tax profit nor the accounting profit.

Deferred tax liabilities are recognised for taxable temporary differences arising on investments in subsidiaries and associates, and interests in joint ventures, except where the Group is able to control the reversal of the temporary difference and it is probable that the temporary difference will not reverse in the foreseeable future.

Deferred tax is calculated at the tax rates which are expected to apply in the period when the liability is settled or the asset is realised. Deferred tax is charged or credited in the Income Statement, except when it relates to items charged or credited directly to equity, in which case the deferred tax is also dealt with in equity.

Other taxes which include recoverable value added tax, excise tax and custom duties represent the amounts receivable or payable to local tax authorities in the countries where the Group operates.

Value added tax

Output value added tax related to sales is payable to tax authorities on the earlier of (a) collection of receivables from customers or (b) delivery of goods or services to customers. Input VAT is generally recoverable against output VAT upon receipt of the VAT invoice. The tax authorities permit the settlement of VAT on a net basis. VAT related to sales and purchases is recognised in the consolidated statement of financial position on a gross basis for different entities of the Group and disclosed separately as an asset and a liability. Where provision has been made for expected credit losses ("ECL") of receivables, the impairment loss is recorded for the gross amount of the debtor, including VAT.

Financial Instruments

Financial instruments - key measurement terms . Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The best evidence of fair value is the price in an active market. An active market is one in which transactions for the asset or liability take place with sufficient frequency and volume to provide pricing information on an ongoing basis.

Fair value of financial instruments traded in an active market is measured as the product of the quoted price for the individual asset or liability and the number of instruments held by the entity. This is the case even if a market's normal daily trading volume is not sufficient to absorb the quantity held and placing orders to sell the position in a single transaction might affect the quoted price.

A portfolio of financial derivatives or other financial assets and liabilities that are not traded in an active market is measured at the fair value of a group of financial assets and financial liabilities on the basis of the price that would be received to sell a net long position (i.e. an asset) for a particular risk exposure or paid to transfer a net short position (i.e. a liability) for a particular risk exposure in an orderly transaction between market participants at the measurement date. This is applicable for assets carried at fair value on a recurring basis if the Group: (a) manages the group of financial assets and financial liabilities on the basis of the Group's net exposure to a particular market risk (or risks) or to the credit risk of a particular counterparty in accordance with the Group's documented risk management or investment strategy; (b) it provides information on that basis about the group of assets and liabilities to the Group's key management personnel; and (c) the market risks, including duration of the Group's exposure to a particular market risk (or risks) arising from the financial assets and financial liabilities are substantially the same.

Valuation techniques such as discounted cash flow models or models based on recent arm's length transactions or consideration of financial data of the investees are used to measure fair value of certain financial instruments for which external market pricing information is not available. Fair value measurements are analysed by level in the fair value hierarchy as follows: (i) level one are measurements at quoted prices (unadjusted) in active markets for identical assets or liabilities, (ii) level two measurements are valuations techniques with all material inputs observable for the asset or liability, either directly (that is, as prices) or indirectly (that is, derived from prices), and (iii) level three measurements are valuations not based on solely observable market data (that is, the measurement requires significant unobservable inputs).

Transaction costs are incremental costs that are directly attributable to the acquisition, issue or disposal of a financial instrument. An incremental cost is one that would not have been incurred if the transaction had not taken place. Transaction costs include fees and commissions paid to agents (including employees acting as selling agents), advisers, brokers and dealers, levies by regulatory agencies and securities exchanges, and transfer taxes and duties. Transaction costs do not include debt premiums or discounts, financing costs or internal administrative or holding costs.

Fair value is the amount at which the financial instrument was recognised at initial recognition, while amortised cost ("AC") is the amount at which the financial instrument was subsequently measured after the initial recognition less any principal repayments, plus accrued interest, and for financial assets less any allowance for ECL. Accrued interest includes amortisation of transaction costs deferred at initial recognition and of any premium or discount to the maturity amount using the effective interest method. Accrued interest income and accrued interest expense, including both accrued coupon and amortised discount or premium (including fees deferred at origination, if any), are not presented separately and are included in the carrying values of the related items in the consolidated statement of financial position.

The effective interest method is a method of allocating interest income or interest expense over the relevant period, so as to achieve a constant periodic rate of interest (effective interest rate) on the carrying amount. The effective interest rate is the rate that exactly discounts estimated future cash payments or receipts (excluding future credit losses) through the expected life of the financial instrument or a shorter period, if appropriate, to the gross carrying amount of the financial instrument. The effective interest rate discounts cash flows of variable interest instruments to the next interest repricing date, except for the premium or discount which reflects the credit spread over the floating rate specified in the instrument, or other variables that are not reset to market rates. Such premiums or discounts are amortised over the whole expected life of the instrument. The present value calculation includes all fees paid or received between parties to the contract that are an integral part of the effective interest rate. For assets that are purchased or originated credit impaired ("POCI") at initial recognition, the effective interest rate is adjusted for credit risk, i.e. it is calculated based on the expected cash flows on initial recognition instead of contractual payments.

Financial instruments - initial recognition . Financial instruments at fair value through profit or loss ("FVTPL") are initially recorded at fair value. All other financial instruments are initially recorded at fair value adjusted for transaction costs. Fair value at initial recognition is best evidenced by the transaction price. A gain or loss on initial recognition is only recorded if there is a difference between fair value and transaction price which can be evidenced by other observable current market transactions in the same instrument or by a valuation technique whose inputs include only data from observable markets. After the initial recognition, an ECL allowance is recognised for financial assets measured at AC and investments in debt instruments measured at fair value through other comprehensive income ("FVOCI"), resulting in an immediate accounting loss.

All purchases and sales of financial assets that require delivery within the time frame established by regulation or market convention ("regular way" purchases and sales) are recorded at trade date, which is the date on which the Group commits to deliver a financial asset. All other purchases are recognised when the entity becomes a party to the contractual provisions of the instrument.

Financial assets - classification and subsequent measurement - measurement categories. The Group classifies financial assets in the following measurement categories: FVTPL, FVOCI and AC. The classification and subsequent measurement of debt financial assets depends on: (i) the Group's business model for managing the related assets portfolio and (ii) the cash flow characteristics of the asset.  The Group's financial assets include cash and cash equivalents, trade and other receivables, loans to subsidiary undertakings, all of which are classified as AC in accordance with IFRS 9.

Financial assets - classification and subsequent measurement - business model. The business model reflects how the Group manages the assets in order to generate cash flows - whether the Group's objective is: (i) solely to collect the contractual cash flows from the assets ("hold to collect contractual cash flows"), or (ii) to collect both the contractual cash flows and the cash flows arising from the sale of assets ("hold to collect contractual cash flows and sell") or, if neither of (i) and (ii) is applicable, the financial assets are classified as part of "other" business model and measured at FVTPL.

Business model is determined for a group of assets (on a portfolio level) based on all relevant evidence about the activities that the Group undertakes to achieve the objective set out for the portfolio available at the date of the assessment. Factors considered by the Group in determining the business model include past experience on how the cash flows for the respective assets were collected.

The Group's business model for financial assets is to collect the contractual cash flows from the assets ("hold to collect contractual cash flows").

Financial assets - classification and subsequent measurement - cash flow characteristics. Where the business model is to hold assets to collect contractual cash flows or to hold contractual cash flows and sell, the Group assesses whether the cash flows represent solely payments of principal and interest ("SPPI"). Financial assets with embedded derivatives are considered in their entirety when determining whether their cash flows are consistent with the SPPI feature. In making this assessment, the Group considers whether the contractual cash flows are consistent with a basic lending arrangement, i.e. interest includes only consideration for credit risk, time value of money, other basic lending risks and profit margin.

Where the contractual terms introduce exposure to risk or volatility that is inconsistent with a basic lending arrangement, the financial asset is classified and measured at FVTPL. The SPPI assessment is performed on initial recognition of an asset and it is not subsequently reassessed.

Financial assets - reclassification. Financial instruments are reclassified only when the business model for managing the portfolio as a whole changes. The reclassification has a prospective effect and takes place from the beginning of the first reporting period that follows after the change in the business model. The Group did not change its business model during the current and comparative period and did not make any reclassifications.

Financial assets impairment - credit loss allowance for ECL. The Group assesses, on a forward-looking basis, the ECL for debt instruments measured at AC and FVOCI and for the exposures arising for contractual assets. The Group measures ECL and recognises Net impairment losses on financial and contractual assets at each reporting date. The measurement of ECL reflects: (i) an unbiased and probability weighted amount that is determined by evaluating a range of possible outcomes, (ii) time value of money and (iii) all reasonable and supportable information that is available without undue cost and effort at the end of each reporting period about past events, current conditions and forecasts of future conditions.

Debt instruments measured at AC and contractual assets are presented in the consolidated statement of financial position net of the allowance for ECL. For loan commitments and financial guarantees, a separate provision for ECL is recognised as a liability in the consolidated statement of financial position.

The Group applies a simplified approach for impairment of cash and cash equivalents, other short-term investments and trade and other receivables, by recognising lifetime expected credit losses based on past default experience and credit profiles, adjusted as appropriate for current observable data. For other financial assets the Group applies a three stage model for impairment, based on changes in credit quality since initial recognition. A financial instrument that is not credit-impaired on initial recognition is classified in Stage 1. Financial assets in Stage 1 have their ECL measured at an amount equal to the portion of lifetime ECL that results from default events possible within the next 12 months or until contractual maturity, if shorter ("12 Months ECL"). If the Group identifies a significant increase in credit risk ("SICR") since initial recognition, the asset is transferred to Stage 2 and its ECL is measured based on ECL on a lifetime basis, that is, up until contractual maturity but considering expected prepayments, if any ("Lifetime ECL"). If the Group determines that a financial asset is credit-impaired, the asset is transferred to Stage 3 and its ECL is measured as a Lifetime ECL. For financial assets that are purchased or originated credit-impaired ("POCI Assets"), the ECL is always measured as a Lifetime ECL.

Financial assets - write-off. Financial assets are written-off, in whole or in part, when the Group has exhausted all practical recovery efforts and has concluded that there is no reasonable expectation of recovery. The write-off represents a derecognition event. The Group may write-off financial assets that are still subject to enforcement activity when the Group seeks to recover amounts that are contractually due, however, there is no reasonable expectation of recovery.

Financial assets - derecognition. The Group derecognises financial assets when (a) the assets are redeemed or the rights to cash flows from the assets otherwise expire or (b) the Group has transferred the rights to the cash flows from the financial assets or entered into a qualifying pass-through arrangement whilst (i) also transferring substantially all the risks and rewards of ownership of the assets or (ii) neither transferring nor retaining substantially all the risks and rewards of ownership but not retaining control.

Financial assets - modification. If the modified terms are substantially different, the rights to cash flows from the original asset expire and the Company derecognises the original financial asset and recognises a new asset at its fair value. The date of renegotiation is considered to be the date of initial recognition for subsequent impairment calculation purposes, including determining whether a SICR has occurred. Any difference between the carrying amount of the original asset derecognised and fair value of the new substantially modified asset is recognised in profit or loss, unless the substance of the difference is attributed to a capital transaction with owners. If the modified asset is not substantially different from the original asset and the modification does not result in derecognition. The Group recalculates the gross carrying amount by discounting the modified contractual cash flows by the original effective interest rate (or credit-adjusted effective interest rate for POCI financial assets), and recognises a modification gain or loss in profit or loss. 

Financial liabilities - measurement categories. Financial liabilities are classified as subsequently measured at AC, except for (i) financial liabilities at FVTPL: this classification is applied to derivatives, financial liabilities held for trading (e.g. short positions in securities), contingent consideration recognised by an acquirer in a business combination and other financial liabilities designated as such at initial recognition and (ii) financial guarantee contracts and loan commitments. The Group's financial liabilities include trade and other payables , lease liabilities , all of which are classified as AC in accordance with IFRS 9.

Financial liabilities - derecognition. Financial liabilities are derecognised when they are extinguished (i.e. when the obligation specified in the contract is discharged, cancelled or expires).

Trade Receivables

Trade receivables are amounts due from customers for goods sold in the ordinary course of business. If collection is expected in one year or less, they are classified as current assets. If not, they are presented as non-current assets.

Trade receivables are recognised initially at fair value and subsequently measured at amortised cost using the effective interest method, less expected credit losses.

Prepayments

Prepayments are carried at cost less provision for impairment. A prepayment is classified as non-current when the goods or services relating to the prepayment are expected to be obtained after one year, or when the prepayment relates to an asset which will itself be classified as non-current upon initial recognition. Prepayments to acquire assets are transferred to the carrying amount of the asset once the Group has obtained control of the asset and it is probable that future economic benefits associated with the asset will flow to the Group. Other prepayments are written off to profit or loss when the services relating to the prepayments are received. If there is an indication that the assets, goods or services relating to a prepayment will not be received, the carrying value of the prepayment is written down accordingly and a corresponding impairment loss is recognised in profit or loss for the year.

Investments in subsidiaries

Investments made by the Company in its subsidiaries are stated at cost in the Company's financial statements and reviewed for impairment if there are indications that the carrying value may not be recoverable.

Loans issued to subsidiaries

Loans issued by the Company to its subsidiaries are initially recognised in the Company's financial statements at fair value and are subsequently carried at amortised cost using the effective interest method, less credit loss allowance. Net change in credit losses and foreign exchange differences on loans issued are recognised in the Company's statement of profit or loss in the period when incurred.

Trade and Other Payables

Trade payables are obligations to pay for goods or services that have been acquired in the ordinary course of business from suppliers. Accounts payable are classified as current liabilities if payment is due within one year or less. If not, they are presented as non-current liabilities.

Trade payables are recognised initially at fair value and subsequently measured at amortised cost using the effective interest method.

Lease liabilities

Liabilities arising from a lease are initially measured on a present value basis. Lease liabilities include the net present value of the following lease payments:

●	fixed payments (including in-substance fixed payments), less any lease incentives receivable,
●	variable lease payments that are based on an index or a rate, initially measured using the index or rate as at the commencement date,
●	the exercise price of a purchase option if the Group is reasonably certain to exercise that option, and
●	payments of penalties for terminating the lease, if the lease term reflects the Group exercising that option.

Extension and termination options are included in a number of property and equipment leases across the Group. These terms are used to maximise operational flexibility in terms of managing contracts. Extension options (or period after termination options) are only included in the lease term if the lease is reasonably certain to be extended (or not terminated). Lease payments to be made under reasonably certain extension options are also included in the measurement of the liability.

The lease payments are discounted using the interest rate implicit in the lease. If that rate cannot be readily determined, which is generally the case for leases of the Group, the Group's incremental borrowing rate is used, being the rate that the Group would have to pay to borrow the funds necessary to obtain an asset of similar value in a similar economic environment with similar terms and conditions.

To determine the incremental borrowing rate, the Group:

●	where possible, uses recent third-party financing received by the individual lessee as a starting point, adjusted to reflect changes in financing conditions since third party financing was received,
●	uses a build-up approach that starts with a risk-free interest rate adjusted for credit risk, and
●	makes adjustments specific to the lease, e.g. term, country, currency and collateral.

The Group is exposed to potential future increases in variable lease payments based on an index or rate, which are not included in the lease liability until they take effect. When adjustments to lease payments based on an index or rate take effect, the lease liability is reassessed and adjusted against the right-of-use asset.

Lease payments are allocated between principal and finance costs. The finance costs are charged to profit or loss over the lease period so as to produce a constant periodic rate of interest on the remaining balance of the liability for each period.

Payments associated with short-term leases and all leases of low-value assets are recognised on a straight-line basis as an expense in profit or loss. Short-term leases are leases with a lease term of 12 months or less.

Equity Instruments

Ordinary shares are classified as equity. Equity instruments issued by the Company and the Group are recorded at the proceeds received, net of direct issue costs. Any excess of the fair value of consideration received over the par value of shares issued is recorded as share premium in equity.

Cash and Cash Equivalents

Cash and cash equivalents comprise cash on hand and deposits held at call with banks and other short-term highly liquid investments which are readily convertible to a known amount of cash with insignificant risk of change in value. Cash and cash equivalents are carried at amortised cost. Interest income that relates to cash and cash equivalents on current and deposit accounts is disclosed within operating cash flow.

Other short-term investments

Other short-term investments include current accounts and deposits held at banks, which do not meet the cash and cash equivalents definition. Current accounts and deposits held at banks, which do not meet the cash and cash equivalents definition are measured initially at fair value and subsequently carried at amortised cost using the effective interest method. Interest received on other short-term investments is disclosed within operating cash flow.

Interest income

Interest income is recognised as it accrues, taking into account the effective yield on the asset. Interest income on current bank accounts and on demand deposits or term deposits with the maturity less than three months recognised as part of cash and cash equivalents is recognised as other operating income. Interest income on term deposits other than those classified as cash and cash equivalents is recognised as finance income.

4.  Significant Accounting Judgements and Estimates

The Group makes estimates and judgements concerning the future. The resulting accounting estimates will, by definition, seldom equal the related actual results. The estimates and judgements which have a risk of causing material adjustment to the carrying amounts of assets and liabilities within the next financial year are discussed below.

Judgements

Acquisition of LLC Arkona Gas-Energy

The Group acquired control of LLC Arkona Gas-Energy ("Arkona") on 24 March 2020. This acquisition required a determination to be made as to whether the acquisition should be treated as a business or asset acquisition. Following such determination, the transaction has been treated as an asset acquisition as there were no employees or production operations acquired. In applying the concentration test under amended IFRS 3 Business Combinations, the fair value of the acquired Svystunivsko-Chervonolutskyi licence ("SC Licence") comprises the majority amount (more than 90%) of the consideration. The SC Licence is classified as an exploration and evaluation intangible asset at the acquisition date. The Group believes no impairment indicators exist at the reporting date, and note the following:

· the SC Licence is valid until 18 May 2037; and

· further exploration and evaluation plans are included in the Group's Budgets.

The following table provides the allocation of the fair value of the consideration to Arkona's assets and liabilities at their relative fair values at the date of acquisition:

	$000
Property, plant and equipment	88
Trade and other receivables	35
Trade and other payables	(291)
Net liabilities - at the acquisition date, excluding licence	(168)
Gross value of consideration (1st, 2nd and 3rd tranches)	8,469
Discounting effect	(306)
Fair value of consideration (1st, 2nd and 3rd tranches)	8,163
Fair value of licence at the acquisition date	8,331

Under the terms of the sale and purchase agreement for Arkona, the total consideration payable is $8,630,000 with payment divided into three tranches. The first tranche of $4,315,000 was paid on 24 March 2020 upon completion of the acquisition of 100% of the issued share capital of Arkona.

In March 2021, the Group paid the second tranche of the consideration (net of an indemnity liability owned to the Group ) of $2,078,000.

In September 2021, the Group made an early payment of 25% of the third tranche of the consideration totalling $539,000.

The remaining balance of the third tranche of the consideration totalling $1,618,125 is subject to satisfaction of certain conditions, including the favourable resolution of legal proceedings brought by NJSC Ukrnafta against Arkona relating to the SC Licence, the absence of any further legal claims or contractual, warranty or indemnity claims, and the expiration of a further period of time. The total consideration comprising the three tranches estimated at the date of acquisition amounts to $8,163,000. The outstanding amount is reflected in trade and other payables.

Estimates

Depreciation of Oil and Gas Development and Production Assets

Development and production assets held in property, plant and equipment are depreciated on a unit of production basis at a rate calculated by reference to proved and probable reserves at the end of the period plus the production in the period, and incorporating the estimated future cost of developing and extracting those reserves. Future development costs are estimated using estimates about the number of wells required to produce those reserves, the cost of the wells, future production facilities and operating costs, together with assumptions on oil and gas realisations, and are revised annually. The reserves estimates used are determined using estimates of gas in place, recovery factors, future hydrocarbon prices and also take into consideration the Group's latest development plan for the associated development and production asset. The latest development plan and therefore the inputs used to determine the depreciation charge for the MEX-GOL, SV and VAS fields continue until the end of the economic life of the fields, which is assessed to be 2038, 2042 and 2028 respectively, based on the assessment contained in the DeGolyer & MacNaughton reserves report for these fields. The licences for the MEX-GOL and SV fields have recently been extended until 2044. Were the estimated reserves at the beginning of the year to differ by 10% from previous assumptions, the impact on depreciation for the year ended 31 December 2021 would be to increase it by $1,195,000 or decrease it by $975,000 (2020: increase by $1,165,000 or decrease by $953,000).

Provision for Decommissioning

The Group has decommissioning obligations in respect of its Ukrainian assets. The full extent to which the provision is required depends on the legal requirements at the time of decommissioning, the costs and timing of any decommissioning works and the discount rate applied to such costs.

A detailed assessment of gross decommissioning cost was undertaken on a well-by-well basis using local data on day rates and equipment costs. The discount rate applied on the decommissioning cost provision as at 31 December 2021 was 6.29 % (31 December 2020: 3.70%). The discount rate is calculated in real terms based on the yield to maturity of Ukrainian Government bonds denominated in the currency in which the liability is expected to be settled and with the settlement date that approximates the timing of settlement of decommissioning obligations. Increase of the discount rate applied is caused by the growth of the Ukrainian risk-free rate.

The change in estimate applied to calculate the provision as at 31 December 2021 resulted from the revision of the estimated costs of decommissioning (increase of $398,000 in provision), an increase in the discount rate applied (decrease of $2,188,000 in provision) and change of the estimated economic life of the SV-10 well (decrease of $259,000 in provision). The costs are expected to be incurred by 2038 on the MEX-GOL field, by 2042 on the SV field, and by 2028 on the VAS field, which is the end of the estimated economic life of the respective fields (Note 26).

Net Carrying Amount of Inter-Company Loans Receivable and Investments by the Company into a Subsidiary

The Company has certain inter-company loans receivable from a subsidiary, which are eliminated on consolidation. For the purpose of the Company's financial statements, these receivable balances are carried at amortised cost using the effective interest method, less credit loss allowance. Measurement of lifetime expected credit losses on inter-company loans is a significant judgment that involves models and data inputs including forward-looking information, current conditions and forecasts of future conditions impacting the estimated future cash flows that are expected to be recovered, time value of money, etc. In previous years, significant impairment charges were recorded against the carrying amount of the loans issued to subsidiaries as the present value of estimated future cash flows discounted at the original effective interest rate was less than the carrying amount of the loans, and the resulting impairment losses were recognised in profit or loss in the Company's financial statements.

For the purpose of assessment of the credit loss allowance as at 31 December 2021, the Company considered all reasonable and supportable forward-looking information available as at that date without undue cost and effort, which includes a range of factors, such as estimated future net cash flows to be generated by the subsidiaries operating in Ukraine and cash flow management. All these factors have a significant impact on the amounts subject to repayment on the loans and investments. The estimated future discounted cash flows generated by the subsidiaries operating in Ukraine are considered as a primary source of repayment on the loans and investments. As at 31 December 2021, the present value of future net cash flows to be generated by the subsidiaries operating in Ukraine during 2022 - 2026, adjusted for the subsidiaries' working capital as at 31 December 2021 and estimated amounts reserved by the Group for investment projects in the time horizon was calculated.

The key assumptions used in the discounted cash flow model are:

●	commodity prices - the model assumes gas prices of $725/Mm3 in 2022, decreasing to $514/Mm3 in 2023, $370/Mm3 in 2024 and $250/Mm3 in subsequent years;
●	discount rate applied is 12.6%, determined in real terms:
●	production levels and reserves at the beginning of year 2022 at the MEX-GOL and SV fields of 44.7 MMboe, at the VAS field of 2.4 MMboe and at the SC licence area of 12.6 MMboe;
●	production taxes applicable to gas production at variable rates under relevant legislation;
●	capital expenditure allowance for maintenance and development of: MEX-GOL and SV fields at the level of $750,000 per year, VAS field at the level of $250,000 per year and SC licence area at the level of $100,000 per year;
●	future capital expenditures for a period of five years assumed to be: for the MEX-GOL and SV fields at the level of $181,700,000, VAS field at the level of $15,500,000 and SC licence area at the level of $65,900,000;
●	future capital expenditures until the end of field life assumed to be: for the MEX-GOL and SV fields at the level of $253,200,000, VAS field at the level of $16,500,000 and SC licence area at the level of $97,500,000;
●	life of field for the purpose of the assessment of loans - cash flows were taken for a period of five years as management believes there is no reasonably available information to build reliable expectations and demonstrate the ability to settle the loans over a longer perspective;
●	life of field for the purpose of the assessment of investments - cash flows were taken for a period of the full economic life of the respective CGUs.

The increase in the net present value of future net cash flows as at 31 December 2021 in comparison with 31 December 2020 was affected by the increase in gas prices forecast.

The resulting amount, net of the carrying value of the Company's investments in subsidiaries and loans, was compared to the discounted cash flows and net financial assets of the subsidiaries as at 31 December 2021. As such, the Company has recorded $ 1 0,912,000 of income, being the net change in the expected credit losses for loans issued to and investments in subsidiaries in the Company's statement of profit or loss for the year ended 31 December 2021. The set off of the accumulated impairment of $3,322,000 was due to the disposal of the fully impaired investment in Regal Petroleum (Jersey) Limited (Note 21). 

As with any economic forecast, the projections and likelihoods of occurrence are subject to a high degree of inherent uncertainty, and therefore the actual outcomes may be significantly different to those projected. The Company considers these forecasts to represent its best estimate of the possible outcomes.

5.  Segmental Information

In line with the Group's internal reporting framework and management structure, the key strategic and operating decisions are made by the Board of Directors, who review internal monthly management reports, budget and forecast information as part of this process. Accordingly, the Board of Directors is deemed to be the Chief Operating Decision Maker within the Group.

The Group's only class of business activity is oil and gas exploration, development and production. The Group's operations are located in Ukraine, with its head office in the United Kingdom. These geographical regions are the basis on which the Group reports its segment information. The segment results as presented represent operating profit before depreciation, amortisation and impairment of non-current assets.

	Ukraine	United Kingdom	Total
	2021	2021	2021
	$000	$000	$000
Revenue
Gas sales	95,813	-	95,813
Condensate sales	19,260	-	19,260
Liquefied Petroleum Gas sales	6,280	-	6,280
Total revenue	121,353	-	121,353
Segment result	81,025	(2,832)	78,193
Depreciation and amortisation of non-current assets	(11,958)	-	(11,958)
Operating profit			66,235
Segment assets	144,941	63,649	208,590
Capital additions*	32,577	-	32,577

*Comprises additions to property, plant and equipment (Note 18)

There are no inter-segment sales within the Group and all products are sold in the geographical region in which they are produced. The Group is not significantly impacted by seasonality. Revenue is recognised at a point in time.

During 2021, the Group was selling all of its gas production to its related party, LLC Smart Energy ("Smart Energy"). Smart Energy has oil and gas operations in Ukraine and is part of the PJSC Smart-Holding Group, which is ultimately controlled by Mr Vadym Novynskyi, who through an indirect 82.65% majority shareholding, ultimately controls the Group. This arrangement came about in 2017 as a consequence of the Ukrainian Government introducing a number of new provisions into the Ukrainian Tax Code over the previous two years, including transfer pricing regulations for companies operating in Ukraine. The introduction of the new regulations has meant that there is an increased regulatory burden on affected companies in Ukraine who must prepare and submit reporting information to the Ukrainian Tax Authorities. Due to the corporate structure of the Group, a substantial proportion of its gas production is produced by a non-Ukrainian subsidiary of the Group, which operates in Ukraine as a branch, or representative office as it Is classified in Ukraine. Under the current tax regulations, this places additional regulatory obligations on each of the Group's potential customers who may be less inclined to purchase the Group's gas and/or may seek discounts on sales prices. As a result of discussions between the Company and Smart Energy, Smart Energy agreed to purchase all of the Group's gas production and to assume responsibility for the regulatory obligations under the Ukrainian tax regulations. Furthermore, Smart Energy has agreed to combine the Group's gas production with its own gas production, and to sell such gas as combined volumes, which is intended to result in higher sales prices due to the larger sales volumes. At the commencement of this sales arrangement, in order to cover Smart Energy's sales, administration and regulatory compliance costs, the Group sold its gas to Smart Energy at a discount of 0.5% to the gas sales prices achieved by Smart Energy, who sold the combined volumes in line with market prices. Due to changes in the regulatory regime in Ukraine, which has increased the burden of administration and regulatory compliance obligations involved in the sale of gas, and in order to ensure that the Group is compliant with current transfer pricing regulations in Ukraine, the Group and Smart Energy agreed in 2019 to increase the discount on the price at which the Group sells its gas to Smart Energy from 0.5% to 2%. The terms of sale for the Group's gas to Smart Energy are (i) for 35% of the monthly volume of gas by the 15th of the month following the month of delivery, and (ii) payment of the remaining balance by the end of that month.

	Ukraine	United Kingdom	Total
	2020	2020	2020
	$000	$000	$000
Revenue
Gas sales	32,309	-	32,309
Condensate sales	11,418	-	11,418
Liquefied Petroleum Gas sales	3,524	-	3,524
Total revenue	47,251	-	47,251
Segment result	25,473	(3,053)	22,420
Depreciation and amortisation of non-current assets	(12,650)	-	(12,650)
Operating profit			9,770
Segment assets	106,587	39,376	145, 963
Capital additions*	18,167	-	18,167

*Comprises additions to property, plant and equipment (Note 18)

6.  Cost of Sales

	2021	2020
	$000	$000
Production taxes	19,926	9,361
Depreciation of property, plant and equipment	10,669	11,546
Rent expenses	8,811	3,151
Staff costs (Note 9)	2,886	3,202
Cost of inventories recognised as an expense	1,708	1,227
Transmission tariff for Ukrainian gas system	880	824
Amortisation of mineral reserves	482	488
Other expenses	2,060	1,712
	47,422	31, 511

The increase in production taxes and rent expenses in 2021 is a function of those charges being price-linked, with hydrocarbon prices having risen significantly during the year. A transmission tariff for use of the Ukrainian gas transit system of UAH101.93/Mm³ of gas was applicable to the Group (2020:   UAH101.93/Mm³).  

7.  Administrative Expenses

	2021	2020
	$000	$000
Staff costs (Note 9)	5,019	4,521
Consultancy fees	923	1,271
Depreciation of other fixed assets	572	456
Auditors' remuneration	352	394
Amortisation of other intangible assets	235	160
Rent expenses	160	154
Other expenses	1,089	835
	8,350	7,791
	2021	2020
	$000	$000
Audit of the Company and subsidiaries	141	176
Audit of subsidiaries in Ukraine	124	123
Audit related assurances services - interim review	48	47
Total assurance services	313	346
Tax compliance services	26	3
Tax advisory services	13	45
Total non-audit services	39	48
Total audit and other services	352	394

The amounts disclosed above were paid to PricewaterhouseCoopers LLP in the UK and Ukraine, with the exception of $7,000 paid to another audit firm in respect of the audit of a subsidiary in Ukraine (2020: $47,000 in respect of the audit of a subsidiary in Ukraine and tax advisory services).  

8.  Remuneration of Directors

	2021	2020
	$000	$000
Directors' emoluments	1,115	1,026

The emoluments of the individual Directors were as follows:

	Total Emoluments	Total emoluments
	2021	2020
	$000	$000
Executive Directors:
Sergii Glazunov	307	370
Bruce Burrows	484	354
Non-executive Directors:
Chris Hopkinson	138	128
Alexey Pertin	62	58
Yuliia Kirianova	62	58
Dmitry Sazonenko	62	58
	1,115	1,026

The emoluments include base salary, bonuses and fees. According to the Register of Directors' Interests, no rights to subscribe for shares in or debentures of any Group companies were granted to any of the Directors or their immediate families during the financial year, and there were no outstanding options to Directors.

9.  Staff Numbers and Costs

The average monthly number of employees during the year (including Executive Directors) and the aggregate staff costs of such employees were as follows:

	Number of employees
	2021	2020
Group
Management / operational	171	166
Administrative support	92	93
	263	259

The prior year comparative numbers of employees were amended to conform to the current year presentation. The number of employees includes full-time and part-time employees.

	2021	2020
	$000	$000
Wages and salaries	6,785	6,664
Other pension costs	1,007	953
Social security costs	113	106
	7,905	7,723

10.  Other Operating Gains, (net)

	2021	2020
	$000	$000
Interest income on cash and cash equivalents	763	1,421
Contractor penalties applied	81	-
Gain on sales of current assets	16	26
Other operating (loss)/income, net	( 206 )	374
	654	1, 821

The prior year comparative costs were amended to conform to the current year presentation.

11.  Finance Income

During 2021, the Group recognised foreign exchange gains less losses of $1,394,000 (2020: $nil). The net exposure in the previous year was recognised as finance costs (Note 12).

12.  Finance Costs

	2021	2020
	$000	$000
Unwinding of discount on financial liabilities	333	27
Unwinding of discount on provision for decommissioning (Note 26)	250	234
Interest expense on lease liabilities	169	126
Foreign exchange losses less gains	-	1,031
	752	1,418

13.  Other Losses, (net)

	2021	2020
	$000	$000
Charitable donations	76	2,077
Foreign exchange gains/(losses)	53	(340)
Other (gains)/losses, net	(21)	1 19
	108	1,85 6

Charitable donations for the year ended 31 December 2021 comprise contributions to the development of social infrastructure of local communities (2020: charitable donations comprised the supply of medical equipment and COVID-19 testing equipment to Ukrainian authorities and charitable foundations).

14.  Income Tax Expense

a)  Income tax expense and (benefit):

			2021	2020
			$000	$000
Current tax
UK - current year			165	227
UK - prior year			10	328
Overseas - current year			13,130	2,770
Overseas - prior year			-	(329)
Deferred tax (Note 27)
UK - current year			2,367	640
Overseas - current year			(199)	(304)
Income tax expense			15,473	3,332

b)  Factors affecting tax charge for the year:

The tax assessed for the year is different from the corporation tax in the UK of 19.00%. The expense for the year can be reconciled to the profit as per the Income Statement as follows:

	2021	2020
	$000	$000
Profit before taxation	66, 592	6,520
Tax charge at UK tax rate of 19.00% (2020: 19.00%)	12,6 5 2	1,239
Tax effects of:
Lower foreign corporate tax rates in Ukraine (18.00%) (2020: 18.00%)	(685)	(95)
Change in UK tax rate from 19% to 25% starting from 1 April 2023	1,168	-
Disallowed expenses and non-taxable income	1 2 , 038	22,648
Previously unrecognised tax losses used to reduce income tax expense	( 9 ,875)	(21,015)
Adjustments in respect of prior periods	175	555
Total tax expense for the year	15,473	3,332

The tax effect of disallowed expenses and non-taxable income are mainly represented by foreign exchange differences of Regal Petroleum Corporation (Ukraine) Limited and the net change in credit loss allowance for loans issued to subsidiaries and shares in subsidiary undertakings.

The tax effect of losses not recognised as deferred tax assets are mainly represented by accumulated losses of Regal Petroleum Corporation (Ukraine) Limited.

15.  Profit for the Year

The Company has taken advantage of the exemption allowed under section 408 of the Companies Act 2006 and has not presented its own Income Statement in these financial statements. The Parent Company profit after tax was $ 16 , 330, 000 for the year ended 31 December 2021 (2020: profit after tax $59,454,000).

16.  Earnings per Share

The calculation of basic earnings per ordinary share has been based on the profit for the year and 320,637,836 (2020: 320,637,836) ordinary shares, being the weighted average number of shares in issue for the year. There are no dilutive instruments.

17.  Reduction of Capital

On 25 February 2021, the Company completed a reduction of its share capital through the cancellation of its entire share premium account, thereby creating distributable reserves, which potentially enables the Company to make distributions to its shareholders in the future, subject to the Company's financial performance. However, the Company is not indicating any commitment, and does not have any current intention, to make any distributions to shareholders.

18.  Property, Plant and Equipment

	2021					2020
	Oil and Gas Development and Production assets Ukraine	Oil and Gas Exploration and Evaluation Assets	Other fixed assets	Total	Oil and Gas Development and Production assets Ukraine	Oil and Gas Exploration and Evaluation Assets	Other fixed assets	Total
Group	$000	$000	$000	$000	$000	$000	$000	$000
Cost
At the beginning of the year	135,966	2,362	2,21 7	140,54 5	143,127	2,571	2,103	147,801
Additions	24,289	7,763	524	32,576	17,241	213	713	18,167
Change in decommissioning provision	(1,921)	70	-	(1,851)	372	-	-	372
Disposals	(62)	-	(187)	(249)	(443)	-	(73)	(516)
Exchange differences	4,898	(85)	77	4,890	(24,331)	(422)	(52 6 )	(25,2 79 )
At the end of the year	163,170	10,110	2,631	175,911	135,966	2,362	2,21 7	140,54 5
Accumulated depreciation and impairment
At the beginning of the year	73,816	-	1,06 7	74,88 3	76,802	-	947	77,749
Charge for year	10,544	-	343	10,887	10, 450	-	319	10, 769
Disposals	(25)	-	(28)	(53)	(327)	-	(30)	(357)
Exchange differences	2,735	-	41	2,776	(13,10 9 )	-	(169)	(13,278)
At the end of the year	87,070	-	1,423	88,493	73,816	-	1,06 7	74,88 3
Net book value at the beginning of the year	62, 150	2,362	1,150	65, 662	66,325	2,571	1,156	70,052
Net book value at the end of the year	76,100	10,110	1,208	87,418	62, 150	2,362	1,150	65, 662

MEX-GOL, SV and VAS gas and condensate fields

In accordance with the Group's accounting policies, the oil and gas development and producing assets are tested for impairment at each balance sheet date if impairment indicators exist. As at 31 December 2021, no impairment indicators were identified by the Group, and therefore no impairment test was performed for the MEX-GOL, SV and VAS gas and condensate fields.

19. Intangible Assets

		2021					2020
	Mineral reserve rights		Exploration and evaluation intangible assets	Other intangible assets	Total	Mineral reserve rights		Exploration and evaluation intangible assets	Other intangible assets	Total
Group	$000		$000	$000	$000	$000		$000	$000	$000
Cost
At the beginning of the year	6,570		8,286	616	15,472	7,843		-	572	8,415
Additions	-		143	324	467	-		8,331	224	8,555
Disposals	-		(80)	(212)	(292)	-		-	(85)	(85)
Exchange differences	240		302	24	566	(1,273)		(45)	(95)	(1,413)
At the end of the year	6,810		8,651	752	16,213	6,570		8,286	616	15,472
Accumulated amortisation
At the beginning of the year	2,855		-	385	3,240	2,851		-	367	3,218
Charge for year	482		-	239	721	488		-	166	654
Disposals	-		-	(212)	(212)	-		-	(85)	(85)
Exchange differences	102		-	22	124	(484)		-	(63)	(547)
At the end of the year	3,439		-	434	3,873	2,855		-	385	3,240
Net book value at the beginning of the year	3,715		8,286	231	12,232	4,992		-	205	5,197
Net book value at the end of the year	3,371		8,651	318	12,340	3,715		8,286	231	12,232

Intangible assets consist mainly of the hydrocarbon production licence relating to the VAS field which is held by one of the Group's subsidiaries, LLC Prom-Enerho Produkt, and a hydrocarbon exploration licence relating to the Svystunivsko-Chervonolutskyi ("SC") area which is held by LLC Arkona Gas-Energy. The Group amortises the hydrocarbon production licence relating to the VAS field using the straight-line method over the term of the economic life of the VAS field until 2028. The hydrocarbon exploration licence relating to the SC area is not amortised due to it being in an exploration and evaluation stage.

In accordance with the Group's accounting policies, intangible assets are tested for impairment at each balance sheet date as part of the impairment testing of the Group's oil and gas development and production assets if impairment indicators exist. As at 31 December 2021, no impairment indicators were identified.

20. Leases

This note provides information for leases where the Group is a lessee.

Amount recognised in the balance sheet:

	2021	2020
	$000	$000
Right-of-use assets
Properties	627	108
Land	242	236
Wells	139	16 8
	1,008	512

	2021	2020
	$000	$000
Lease liabilities
Current	455	245
Non-current	648	371
	1,103	616

After modification additions to the right-of-use assets during the 2021 financial year were $820,000 (2020: $56,000).

Amounts recognised in the statement of profit or loss:

	2021	2020
	$000	$000
Depreciation charge
Properties	(311)	(308)
Land	(15)	(15)
Wells	(34)	(35)
	(360)	(35 8 )
Interest expense (included in finance cost)	(169)	(126)
Expense relating to short-term leases (included in cost of sales and administrative expenses)	(142)	(139)
Expense relating to variable lease payments not included in lease liabilities (included in cost of sales)	(8,765)	(3,101)
Expense relating to lease payments for land under wells not included in lease liabilities (included in cost of sales)	(64)	(71)

The comparative expense relating to lease payments for land under wells not included in lease liabilities was amended to conform to the current year presentation.

The total cash outflow for leases in 2021 was $10,217,000 (2020: $3,456,000).

21. Investments and Loans to Subsidiary Undertakings

	Shares in subsidiary undertakings	Loans to subsidiary undertakings	Total
	$000	$000	$000
Company
As at 1 January 2020	17,279	14,181	31,460
Additions including accrued interest	8,163	4,336	12,499
Transfers	39,987	(39,987)	-
Repayment of interest and loans	-	(4,318)	(4,318)
(Impairment)/reversal of impairment	(30,142)	87,264	57,122
Exchange differences	-	1,352	1,352
As at 31 December 2020	35,287	62,828	98,115
Additions including accrued interest	-	15,447	15,447
Disposal of shares in subsidiary	(3,322)	-	(3,322)
Accumulated impairment on disposal of shares in subsidiary	3,322	-	3,322
Repayment of interest and loans	-	(32,132)	(32,132)
Reversal of impairment	3,240	7,672	10,912
Exchange differences	-	(4,916)	(4,916)
As at 31 December 2021	38,527	48,899	87,426

The Company has recorded a credit of $7,672,000, being the net change in expected credit losses for loans issued to subsidiaries in the Company's statement of profit or loss for the year ended 31 December 2021 (Note 4). As at 31 December 2021, following a review of the underlying cash flow forecasts of the subsidiaries and a significant increase in gas prices forecast, management reassessed the method of measurement of expected credit losses and use of the downside scenario, calculating the ECL based on the sovereign rating of Ukraine defined by Fitch as "B" as at 31 December 2021. The cash flow forecast would be sensitive to a breakeven discount rate of 26.00%, and a breakeven gas price of $348/Mm³.

The Company also recorded a credit of $3,240,000, being the net change in credit loss allowance for shares in subsidiary undertakings. The set off of the accumulated impairment of $3,322,000 was due to the disposal of the fully impaired investment in Regal Petroleum (Jersey) Limited.

The Company's discounted cash flow model used for the assessment of the investments recoverability, flexed for sensitivities, produced the following results:

	31 December 2021	31 December 2020
	$000	$000
Discount rate (increase)/decrease by 1%	(641)/676	( 810 )/ 867
Change in gas price increase/(decrease) by 10%	3,388 /( 3,411 )	2,879 /( 2,880 )

The table presented below discloses the changes in the gross carrying amount and credit loss allowance between the beginning and the end of the reporting period for loans to subsidiary undertakings carried at amortised cost and classified within a three-stage model for impairment assessment as at 31 December 2021:

	Credit loss allowance				Gross carrying amount
	Stage 1	Stage 2	Stage 3	Total	Stage 1	Stage 2	Stage 3	Total
	(12-months ECL)	(lifetime ECL for SICR)	(lifetime ECL for credit impaired)		(12-months ECL)	(lifetime ECL for SICR)	(lifetime ECL for credit impaired)
	$000	$000	$000	$000	$000	$000	$000	$000
As at 1 January 2021	-	-	(20,375)	(20,375)	-	-	83,203	83,203
Movements with impact on credit loss allowance charge for the year:
Modification of loans	-	-	(5,378)	(5,378)	-	-	5,378	5,378
Additions including accrued interest	-	-	-	-	12,276	-	3,171	15,447
Payment of interest	-	-	-	-	-	-	(3,134)	(3,134)
Repayment of loans	-	-	-	-	-	-	(28,998)	(28,998)
Exchange difference	-	-	1,400	1,400	-	-	(6,316)	(6,316)
Changes to ECL measurement model assumptions	(637)	-	8,309	7,672	-	-	-	-
Total movements with impact on credit loss allowance charge for the year	(637)	-	4,331	3,694	12,276	-	(29,899)	(17,623)
As at 31 December 2021	(637)	-	(16,044)	(16,681)	12,276	-	53,304	65,580

ECL - Expected credit losses

SICR - Significant increase in credit risk

The table presented below discloses the changes in the gross carrying amount and credit loss allowance between the beginning and the end of the reporting period for loans to subsidiary undertakings carried at amortised cost and classified within a three-stage model for impairment assessment as at 31 December 2020:

	Credit loss allowance				Gross carrying amount
	Stage 1	Stage 2	Stage 3	Total	Stage 1	Stage 2	Stage 3	Totall
	(12-months ECL)	(lifetime ECL for SICR)	(lifetime ECL for credit impaired)		(12-months ECL)	(lifetime ECL for SICR)	(lifetime ECL for credit impaired)
	$000	$000	$000	$000	$000	$000	$000	$000
As at 1 January 2020	-	-	(167,072)	(167,072)	-	-	181,253	181,253
Movements with impact on credit loss allowance charge for the year:
Modification of loans	-	-	72,412	72,412	-	-	(72,412)	(72,412)
Additions including accrued interest	-	-	-	-	-	-	4,336	4,336
Transfers	-	-	-	-	-	-	(39,987)	(39,987)
Payment of interest	-	-	-	-	-	-	(4,318)	(4,318)
Repayment of loans	-	-	-	-	-	-	-	-
Exchange difference	-	-	(12,979)	(12,979)	-	-	14,331	14,331
Changes to ECL measurement model assumptions	-	-	87,264	87,264	-	-	-	-
Total movements with impact on credit loss allowance charge for the year	-	-	146,697	146,697	-	-	(98,050)	(98,050)
As at 31 December 2020	-	-	(20,375)	(20,375)	-	-	83,203	83,203

ECL - Expected credit losses

SICR - Significant increase in credit risk

Subsidiary undertakings

As at 31 December 2021 and 2020, the Company's subsidiary undertakings, all of which are included in the consolidated financial statements, were:

	Registered address	Country of incorporation	Country of operation	Principal activity	% of shares held
Regal Petroleum Corporation Limited	3rd Floor, Charter Place, 23-27 Seaton Place, St Helier, Jersey, JE4 0WH	Jersey	Ukraine	Oil & Natural Gas Extraction	100%
Regal Group Services Limited	16 Old Queen Street, London, SW1H 9HP	United Kingdom	United Kingdom	Service Company	100%
Regal Petroleum (Jersey) Limited	3rd Floor, Charter Place, 23-27 Seaton Place, St Helier, Jersey, JE4 0WH	Jersey	United Kingdom	Holding Company	100%
Regal Petroleum Corporation (Ukraine) Limited	162 Shevchenko Str., Yakhnyky Village, Lokhvytsya District, Poltava Region, 37212	Ukraine	Ukraine	Service Company	100%
LLC Prom-Enerho Produkt	3 Klemanska Str., Kiev, 02081	Ukraine	Ukraine	Oil & Natural Gas Extraction	100%
LLC Arkona Gas-Energy	162 Shevchenko Str., Yakhnyky Village, Lokhvytsya District, Poltava Region, 37212	Ukraine	Ukraine	Exploration and Evaluation for Oil and Natural Gas	100%

The Parent Company, Enwell Energy plc, holds direct interests in 100% of the share capital of Regal Petroleum Corporation Limited, Regal Group Services Limited, Regal Petroleum (Jersey) Limited, Regal Petroleum Corporation (Ukraine) Limited and LLC Arkona Gas-Energy, and a 100% indirect interest in  LLC Prom-Enerho Produkt through its 100% shareholding in Regal Petroleum Corporation (Ukraine) Limited, which owns all of the share capital of LLC Prom-Enerho Produkt. 

Regal Group Services Limited, company number 5252958, has taken advantage of the subsidiary audit exemption allowed under section 479A of the Companies Act 2006 for the year ended 31 December 2021.

22. Inventories

	Group
	2021	2020
	$000	$000
Current
Materials and spare parts	1,705	1,445
Finished goods	157	96
	1,862	1,541

Inventories consist of materials, spare parts and finished goods. Materials and spare parts are represented by spare parts that were not assigned to any new wells, production raw materials and fuel at the storage facility. Finished goods consist of produced gas held in underground gas storage facilities and condensate and LPG held at the processing facility prior to sale.

As at 31 December 2021 allowances for impairment of materials and spare parts amounted to $965,000 (31 December 2020: $974,000).

All inventories are measured at the lower of cost or net realisable value. There was no write down of inventory as at 31 December 2021 or 2020.

23. Trade and Other Receivables

	Group		Company
	2021	2020	2021	2020
	$000	$000	$000	$000
Trade receivables	5,308	1,936	-	-
Other financial receivables	200	1,053	196	304
Less credit loss allowance	(140)	(133)	-	-
Total financial receivables	5,368	2,856	196	304
Prepayments and accrued income	5,231	1,387	28	55
Other receivables	2,460	604	75	76
Total trade and other receivables	13,059	4,847	299	435

Due to the short-term nature of the trade and other receivables, their carrying amount is assumed to be the same as their fair value. All trade and other financial receivables, except those provided for, are considered to be of high credit quality.

As at 31 December 2021, the Group's total trade receivables, net of expected credit losses amounted to $5,169,000 and 100% were denominated in Ukrainian Hryvnia (31 December 2020: $1,806,000 and 100% were denominated in Ukrainian Hryvnia). Further description of financial receivables is disclosed in Note 31.

The majority of the trade receivables are from a related party, LLC Smart Energy, that purchases all of the Group's gas production (see Note 4). The applicable payment terms, which were revised in the period, are payment for 35% of the monthly volume of gas by the 15^th of the month following the month of delivery, and payment of the remaining balance by the end of that month (2020: the applicable payment terms are payment for one third of the estimated monthly volume of gas by the 20^th of the month of delivery, and payment of the remaining balance by the 10^th of the month following the month of delivery). The trade receivables were paid in full after the end of the year.

Prepayments and accrued income mainly consist of prepayments of $1,366,000 relating to the development of the SV field, $1,210,000 relating to the development of the MEX-GOL field and $2,284,000 relating to the development of the SC licence (31 December 2020: of $926,000 relating to the development of the SV licence).

Analysis by credit quality of financial trade and other receivables and expected credit loss allowance as at 31 December 2021 is as follows:

	Loss rate	Gross carrying amount	Life-time ECL	Carrying amount	Basis
		$000	$000	$000
Trade receivables from related parties	5%	5,015	(7)	5,008	financial position of related party
Trade receivables - credit impaired	100%	132	(132)	-	number of days the asset past due
Trade receivables - other	0.21%	161	-	161	historical credit losses experienced
Other financial receivables	0.48%	200	(1)	199	individual default rates
Total trade and other receivables for which individual approach for ECL is used		5,508	(140)	5,368

Analysis by credit quality of financial trade and other receivables and expected credit loss allowance as at 31 December 2020 is as follows:

	Loss rate	Gross carrying amount	Life-time ECL	Carrying amount	Basis
		$000	$000	$000
Trade receivables from related parties	5%	1,804	(3)	1,801	financial position of related party
Trade receivables - credit impaired	100%	127	(127)	-	number of days the asset past due
Trade receivables - other	0.21%	5	-	5	historical credit losses experienced
Other financial receivables	0.42%	1,053	(3)	1,050	individual default rates
Total trade and other receivables for which individual approach for ECL is used		2,989	(133)	2,856

ECL - Expected credit losses

The following table explains the changes in the credit loss allowance for trade and other receivables under the simplified ECL model between the beginning and the end of the year:

	2021	2020
	$000	$000
Trade and other receivables
Balance as at 1 January	133	155
New originated or purchased	24	-
Financial assets derecognised during the year	(19)	-
Changes in estimates and assumptions	(3)	3
Foreign exchange movements	5	(25)
Balance as at 31 December	140	13 3

24. Cash and Cash Equivalents and Other short-term investments

	Group		Company
	2021	2020	2021	2020
	$000	$000	$000	$000
Cash and Cash Equivalents
Cash at bank	75,457	53,710	63,299	38,619
Demand deposits and term deposits with maturity of less than 3 months	12,323	7,283	-	-
	87,780	60,993	63,299	38,619
Other short-term investments
Demand deposits and term deposits with maturity of more than 3 months but less than a year	4,762	-	-	-
	4,762	-	-	-

Cash at bank earns interest at fluctuating rates based on daily bank deposit rates. Demand deposits are made for varying periods depending on the immediate cash requirements of the Group and earn interest at the respective short-term deposit rates. The terms and conditions upon which the Group's demand deposits are made allow immediate access to all cash deposits, with no significant loss of interest.

The credit quality of cash and cash equivalents balances and other short-term investments may be summarised based on Moody's ratings as follows as at 31 December:

	Cash at bank and on hand	Demand deposits and term deposits with maturity less than 3 months	Demand deposits and term deposits with maturity more than 3 months	Total cash and cash equivalents and other short-term investments
	2021	2021	2021	2021
	$000	$000		$000
A- to A+ rated	63,290	-	-	63,290
B- to B+ rated	900	8,660	4,762	14,322
Unrated	11,267	3,663	-	14,930
	75,457	12,323	4,762	92,542

	Cash at bank and on hand	Demand deposits and term deposits with maturity less than 3 months	Demand deposits and term deposits with maturity more than 3 months	Total cash and cash equivalents and other short-term investments
	2020	2020	2020	2020
	$000	$000	$000	$000
A- to A+ rated	38,615	-	-	38,615
B- to B+ rated	1	5,477	-	5,478
Unrated	15,094	1,806	-	16,900
	53,710	7,283	-	60,993

For cash and cash equivalents and other short-term investments, the Group assessed ECL based on the Moody's rating for rated banks and based on the sovereign rating of Ukraine defined by Fitch as "B" as at 31 December 2021 for non-rated banks. Based on this assessment, the Group concluded that the identified impairment loss was immaterial.

25. Trade and Other Payables

	2021		2020
	$000		$000
Taxation and social security	5 , 031		1,396
Trade payables	3,404		843
Accruals and other payables	3,354		4,037
Advances received	517		365
		12,306	6,641

The carrying amounts of trade and other payables are assumed to be the same as their fair values, due to their short-term nature. Financial payables are disclosed in Note 31.

26. Provision for Decommissioning

	2021	2020
	$000	$000
Group
At the beginning of the year	6,819	7,447
Amounts provided	198	146
Unwinding of discount	250	234
Change in estimate	(2,049)	226
Effect of exchange difference	249	(1,234)
At the end of the year	5,467	6,819

The provision for decommissioning is based on the net present value of the Group's estimated liability for the removal of the Ukrainian production facilities and well site restoration at the end of production life.

The non-current provision of $5,467,000 (31 December 2020: $6,819,000) represents a provision for the decommissioning of the Group's MEX-GOL, SV, VAS and SC production and exploration facilities, including site restoration.

The change in estimates applied to calculate the provision as at 31 December 2021 is explained in Note 4.

The principal assumptions used are as follows:

	31 December 2021	31 December 2020
Discount rate	6.29%	3.70%
Average cost of restoration per well ($000)	348	342

The sensitivity of the restoration provision to changes in the principal assumptions to the provision balance and related asset is presented below:

	31 December 2021	31 December 2020
	$000	$000
Discount rate (increase)/decrease by 1%	(723)/860	(948)/1,143
Change in average cost of well restoration increase/ (decrease) by 10%	353 /( 353 )	469/(469)

27. Deferred Tax

	2021	2020
	$000	$000
Deferred tax (liability)/asset recognised relating to oil and gas development and production assets at the MEX-GOL-SV fields and provision for decommissioning
At the beginning of the year	(2,705)	(2,141)
Charged to Income Statement - UK current year	(2,367)	(640)
Charged to Income Statement - UK prior year	-	-
Effect of exchange difference	(125)	76
At the end of the year	(5,197)	(2,705)
	2021	2020
	$000	$000
Deferred tax asset/(liability) recognised relating to development and production assets at the VAS field and provision for decommissioning
At the beginning of the year	167	(147)
Credited to Income Statement - overseas current year	199	304
Effect of exchange difference	(5)	10
At the end of the year	361	167

There was a further $76,433,000 (31 December 2020: $73,661,000) of unrecognised UK tax losses carried forward for which no deferred tax asset has been recognised. This amount includes $4, 065 , 000 of previous losses added during the period as a result of finalisation of the tax return. These losses can be carried forward indefinitely, subject to certain rules regarding capital transactions and changes in the trade of the Company.

The deferred tax asset relating to the Group's provision for decommissioning as at 31 December 2021 of $457,000 (31 December 2020: $170 , 000 ) was recognised on the tax effect of the temporary differences of the Group's provision for decommissioning at the MEX-GOL and SV fields, and its tax base. The deferred tax liability relating to the Group's development and production assets at the MEX-GOL and SV fields as at 31 December 2021 of $5,654,000 (31 December 2020: $2,875,000) was recognised on the tax effect of the temporary differences between the carrying value of the Group's development and production asset at the MEX-GOL and SV fields, and its tax base. The deferred tax liability will be settled more than twelve months after the reporting period.

The deferred tax asset relating to the Group's provision for decommissioning as at 31 December 2021 of $315,000 (31 December 2020: $323,000) was recognised on the tax effect of the temporary differences on the Group's provision on decommissioning at the VAS field, and its tax base. The deferred tax asset relating to the Group's development and production assets at the VAS field as at 31 December 2021 of $46,000 (31 December 2020: deferred tax liability of $156,000) was recognised on the tax effect of the temporary differences between the carrying value of the Group's development and production asset at the VAS field, and its tax base. The deferred tax assets are expected to be recovered more than twelve months after the reporting period.

Losses accumulated in a Ukrainian subsidiary service company of UAH 835,298,000 ($30,621,000) as at 31 December 2021 and UAH 1,763,494,000 ($62,370,000) as at 31   December 2020 mainly originated as foreign exchange differences on inter-company loans and for which no deferred tax asset was recognised as this subsidiary is not expected to have taxable profits to utilise these losses in the future.

As at 31 December 2021 and 2020, the Group has not recorded a deferred tax liability in respect of taxable temporary differences associated with investments in subsidiaries as the Group is able to control the timing of the reversal of those temporary differences and does not intend to reverse them in the foreseeable future.

UK Corporation tax change

The current Corporation tax rate of 19% generally applies to all companies whatever their size. From 1 April 2023, this rate will cease to apply and will be replaced by variable rates ranging from 19% to 25%. A small profits rate of 19% will apply to companies whose profits are equal to or less than £50,000. The main Corporation Tax rate is increased to 25% and will apply to companies with profits in excess of £250,000. This had an impact on the deferred tax liability and the income tax expense in the amount of $1,168,000 (Note 14).

Double tax treaty

On 30 October 2019, the Parliament of Ukraine voted for ratification of a Protocol changing the Double Tax Treaties between Ukraine and the United Kingdom. The Protocol and the new Treaty will enter into force upon completion of ratification formalities, and for the purposes of withholding tax, commence applying from 1 January 2020. The Group accrues and pays withholding tax on current amounts of interest at the moment when such interest accrues and is paid.

28.  Called Up Share Capital

	2021		2020
	Number	$000	Number	$000
Allotted, called up and fully paid
Opening balance as at 1 January	320,637,836	28,115	320,637,836	28,115
Issued during the year	-	-	-	-
Closing balance as at 31 December	320,637,836	28,115	320,637,836	28,115

There are no restrictions over ordinary shares issued. The Company is a public company limited by shares.

29.  Other Reserves

The holders of ordinary shares are entitled to receive dividends as declared and are entitled to one vote per share at any general meeting of shareholders.

Other reserves, the movements in which are shown in the statements of changes in equity, comprise the following:

Capital contributions reserve

The capital contributions reserve is non-distributable and represents the value of equity invested in subsidiary entities prior to the Company listing.

Merger reserve

The merger reserve represents the difference between the nominal value of shares acquired by the Company and those issued to acquire subsidiary undertakings. This balance relates wholly to the acquisition of Regal Petroleum (Jersey) Limited and that company's acquisition of Regal Petroleum Corporation Limited during 2002.

Foreign exchange reserve

Exchange reserve movement for the year attributable to currency fluctuations. This balance predominantly represents the result of exchange differences on non-monetary assets and liabilities where the subsidiaries' functional currency is not the US Dollar.

30.  Reconciliation of Operating Profit to Operating Cash Flow

	2021	2020
	$000	$000
Group
Operating profit	66,235	9, 770
Depreciation and amortisation	11,958	12, 679
Less interest income recorded within operating profit	(763)	(1,421)
Fines and penalties received	(81)	(18)
Gain on sales of current assets, net	( 16 )	(31)
Net (gain)/loss on sale of non-current assets	(16)	159
Change in working capital:
Increase in provisions	(6)	(55)
(Increase)/decrease in inventory	(104)	2,499
(Increase)/decrease in receivables	(4,4 63 )	359
Increase/(decrease) in payables	4,902	(177)
Cash generated from operations	77,646	23,764

	2021	2020
	$000	$000
Company
Operating profit	11,591	58,018
Interest received	(3,447)	(4,336)
Change in working capital:
Movement in provisions (including impairment of subsidiary loans)	(10,912)	(57,122)
Decrease/(increase) in receivables	136	(101)
(Decrease)/increase in payables	(188)	13
Cash used in operations	(2,820)	(3,528)

31.  Financial Instruments

Capital Risk Management

The Group defines its capital as equity. As at 31 December 2021, net assets were $178,517,000 (31 December 2020: $125,615,000). The primary source of the Group's liquidity has been cash generated from operations. The Group's objectives when managing capital are to safeguard the Group's and the Company's ability to continue as a going concern in order to provide returns for shareholders and benefits for other stakeholders and to maintain an optimal capital structure to reduce the cost of capital.

In order to maintain or adjust the capital structure, the Group may adjust the amount of dividends paid to shareholders, return capital to shareholders, issue new shares or sell assets.

On 25 February 2021, the Company completed a reduction of its share capital through the cancellation of its entire share premium account, thereby creating distributable reserves, which enables the Company to make distributions to its shareholders in the future, subject to the Company's financial performance. However, the Company is not indicating any commitment, and does not have any current intention, to make any distributions to shareholders.

The capital structure of the Group consists of equity attributable to the equity holders of the parent, comprising issued share capital, share premium, reserves and retained earnings.

There are no capital requirements imposed on the Group.

Financial Risk Management

The Group's financial instruments comprise cash and cash equivalents and various items such as debtors and creditors that arise directly from its operations. The Group has bank accounts denominated in British Pounds, US Dollars, Euros and Ukrainian Hryvnia. The Group does not have any external borrowings. The main future risks arising from the Group's financial instruments are currently currency risk, interest rate risk, liquidity risk and credit risk.

The Group's financial assets and financial liabilities comprise the following:

Financial Assets
	2021	2020
	$000	$000
Group
Cash and cash equivalents	87,780	60,993
Other short-term investments	4,762	-
Trade and other receivables	5,368	2,856
	9 7 , 910	63,849

	2021	2020
	$000	$000
Company
Cash and cash equivalents	63,299	38,619
Loans to subsidiary undertakings	48,899	62,828
	112,198	101,447

Financial Liabilities
	2021	2020
	$000	$000
Group
Lease liabilities	1,103	616
Trade and other payables	3,404	843
Other financial liabilities	2,244	4,336
	6,751	5,795
	2021	2020
	$000	$000
Company
Trade and other payables	1,767	4,247
	1,767	4,247

Financial assets and financial liabilities are measured at amortised cost, which approximates their fair value as the instruments are mostly short-term. Assets and liabilities of the Group where fair value is disclosed are level 2 in the fair value hierarchy and valued using the current cost accounting technique.

Financial instruments that potentially subject the Group to concentrations of credit risk consist primarily of cash and cash equivalents and accounts receivable, and financial instruments that potentially subject the Company to concentrations of credit risk consist primarily of cash and cash equivalents and loans to subsidiary undertakings. 

Currency Risk

The functional currencies of the Group's entities are US Dollars and Ukrainian Hryvnia. The following analysis of net monetary assets and liabilities shows the Group's currency exposures. Exposures comprise the monetary assets and liabilities of the Group that are not denominated in the functional currency of the relevant entity.

	2021	2020
Currency	$000	$000
British Pounds	275	232
US Dollars	234	1,806
Euros	9	5
Net monetary assets less liabilities	518	2,043

The Group's exposure to currency risk at the end of the reporting period is not significant due to immaterial balances of monetary assets and liabilities denominated in foreign currencies.

The sensitivity of the exchange rate of US Dollars is presented below:

	31 December 2021	31 December 2020
	$000	$000
Increase/(decrease) by 10%	2 3 /( 2 3 )	189/(189)

The prior year comparative figures were amended to conform to the current year presentation.

Interest Rate Risk Management

The Group is not exposed to interest rate risk on financial liabilities as none of the entities in the Group have any external borrowings. The Group does not use interest rate forward contracts and interest rate swap contracts as part of its strategy.

The Group is exposed to interest rate risk on financial assets as entities in the Group hold money market deposits at floating interest rates. The risk is managed by fixing interest rates for a period of time when indications exist that interest rates may move adversely.

The Group's exposure to interest rates on financial assets and financial liabilities are detailed in the liquidity risk section below.

Interest Rate Sensitivity Analysis

The sensitivity analysis below has been determined based on exposure to interest rates for non-derivative instruments at the balance sheet date. A 0.5% increase or decrease is used when reporting interest rate risk internally to key management personnel and represents management's assessment of a reasonably possible change in interest rates.

If interest rates earned on money market deposits had been 0.5% higher / lower and all other variables were held constant, the Group's:

●

profit for the year ended 31 December 2021 would increase by $136,000 in the event of 0.5% higher interest rates and decrease by $136,000 in the event of 0.5% lower interest rates (profit for the year ended 31 December 2020 would increase by $97,000 in the event of 0.5% higher interest rates and decrease by $97,000 in the event of 0.5% lower interest rates). This is mainly attributable to the Group's exposure to interest rates on its money market deposits; and

●

other equity reserves would not be affected (2020: not affected)

Interest payable on the Group's liabilities would have an immaterial effect on the profit or loss for the year.

Liquidity Risk

The Group's objective throughout the year has been to ensure continuity of funding. Operations have primarily been financed through revenue from Ukrainian operations.

The table below shows liabilities by their remaining contractual maturity. The amounts disclosed in the maturity table are the contractual undiscounted cash flows including future interest. Such undiscounted cash flows differ from the amount included in the statement of financial position because the statement of financial position amount is based on discounted cash flows and does not include the interest that will be accrued in future periods.

When the amount payable is not fixed, the amount disclosed is determined by reference to the conditions existing at the reporting date. Foreign currency payments are translated using the spot exchange rate at the end of the reporting period. The maturity analysis of financial liabilities as at 31 December 2021 is as follows:

As at 31 December 202 1	On demand and less than 1 month	From 1 to 3 months	From 3 to 12 months	From 12   months to 5 years	More than 5 years	Total
	$000	$000	$000	$000	$000	$000
Liabilities
Trade and other payables	4,030	1,618	-	-	-	5,648
Lease liabilities	39	80	381	661	492	1,653
Other non-current liabilities	-	-	-	142	256	398
Total future payments, including future principal and interest payments	4,069	1,698	381	803	748	7,699

The maturity analysis of financial liabilities as at 31 December 2020 is as follows:

As at 31 December 20 20	On demand and less than 1 month	From 1 to 3 months	From 3 to 12 months	From 12 months to 5 years	More than 5 years	Total
	$000	$000	$000	$000	$000	$000
Liabilities
Trade and other payables	1,137	2,158	33	-	-	3,328
Lease liabilities	40	80	101	291	539	1,051
Other non-current liabilities	-	27	-	2,569	-	2,596
Total future payments, including future principal and interest payments	1 , 1 7 7	2 ,26 5	1 3 4	2 ,860	539	6, 9 75

Details of the Group's cash management policy are explained in Note 24.

Liquidity risk for the Group is further detailed under the Principal Risks section above.

Credit Risk

Credit risk principally arises in respect of the Group's cash balance. For balances held outside Ukraine, where $63,299,000 of the overall cash and cash equivalents is held (31 December 2020: $38,619,000), the Group only deposits cash surpluses with major banks of high quality credit standing (Note 24). As at 31 December 2021, the remaining balance of $29,243,000 of cash and cash equivalents and other short-term investments was held in Ukraine (31 December 2020: $22,374,000). As at 31 December 2021, Standard & Poor's affirmed Ukraine's sovereign credit rating of 'B', Outlook Stable. There is no international credit rating information available for the specific banks in Ukraine where the Group currently holds its cash and cash equivalents. 

The Group has taken steps to diversify its banking arrangements between a number of banks in Ukraine and increased the quality of cash placed with UK and European banking institutions. These measures are designed to spread the risks associated with each bank's creditworthiness. Management considers the credit risk to be immaterial.

Interest Rate Risk Profile of Financial Assets

The Group had the following cash and cash equivalent and other short-term investments balances which are included in financial assets as at 31 December with an exposure to interest rate risk:

Currency		Total	Floating rate financial assets	Fixed rate financial assets	Total	Floating rate financial assets	Fixed rate financial assets
		202 1	202 1	202 1	20 20	20 20	20 20
		$000	$000	$000	$000	$000	$000
Euros		9	9	-	5	5	-
British Pounds		275	275	-	232	232	-
Ukrainian Hryvnia		29,011	-	29,011	20,569	-	20,569
US Dollars		63,247	63,247	-	40,187	40,187	-
		92,542	63,531	29,011	60,993	40,424	20,569

Cash deposits included in the above balances comprise term deposits with maturity less than 3 months of $12,323,000 and term deposits with maturity more than 3 months but less than a year of $4,762,000 (2020: term deposits with maturity less than 3 months of $7,283,000).

As at 31 December 2021, cash and cash equivalents of the Company of $63,015,000 were held in US Dollars at a floating rate (2020: $38,382,000).

Interest Rate Risk Profile of Financial Liabilities

As at 31 December 2021 and 2020, the Group had no interest bearing financial liabilities at the year end.

Maturity of Financial Liabilities

The maturity profile of financial liabilities, on an undiscounted basis, is as follows:

		202 1	20 20
		$000	$000
Group
In one year or less		6,148	3,576
		6,148	3, 576
		202 1	20 20
		$000	$000
Company
In one year or less		1,767	2,395
		1,767	2,395

Borrowing Facilities

As at 31 December 2021 and 2020, the Group did not have any borrowing facilities available to it.

Fair Value of Financial Assets and Liabilities

The fair value of all financial instruments is not materially different from the book value.

32.  Contingencies and Commitments

Amounts contracted in relation to the Group's 2021 investment programme in the MEX-GOL, SV, VAS and SC fields in Ukraine, but not provided for in the financial statements at 31 December 2021, were $3 , 101,000 related to Oil and Gas Exploration and Evaluation assets and $2,674,000 related to Oil and Gas Development and Production assets (2020: $9,052,000 for Oil and Gas Development and Production assets).

Since 2010, the Group has been in dispute with the Ukrainian tax authorities in respect of VAT receivables on imported leased equipment, with a disputed liability of up to UAH 8,487,000 ($302,000) inclusive of penalties and other associated costs. There is a level of ambiguity in the interpretation of the relevant tax legislation, and the position adopted by the Group has been challenged by the Ukrainian tax authorities, which has led to legal proceedings to resolve the issue. The Group had been successful in three court cases in respect of this dispute in courts of different levels. On 20 September 2016, a hearing was held in the Supreme Court of Ukraine of an appeal of the Ukrainian tax authorities against the decision of the Higher Administrative Court of Ukraine, in which the appeal of the Ukrainian tax authorities was upheld. As a result of this appeal decision, all decisions of the lower courts were cancelled, and the case was remitted to the first instance court for a new trial. On 1 December 2016 and 7 March 2017 respectively, the Group received positive decisions in the first and second instance courts, but no appointment of hearings has been settled yet. No liability has been recognised in these consolidated financial statements for the year ended 31 December 2021 (31 December 2020: nil), as the Group has been successful in previous court cases in respect of this dispute in courts of different levels, the date of the next legal proceedings has not been set and as management believes that adequate defences exist to the claim.

On 12 March 2019, the Group announced the publication of an Order for suspension (the "Order") by the State Service of Geology and Subsoil of Ukraine affecting the production licence for its VAS gas and condensate field. The Group is confident there are no violations of the terms of the licence or in relation to the operational activities of the Group that would justify the Order or the suspension of the licence. The Group has issued legal proceedings in the Ukrainian Courts to challenge the validity of the Order, and in these proceedings, on 18 March 2019, the Court made a ruling on interim measures to suspend the Order pending hearings of the substantive issues of the case to be held subsequently. The effect of this ruling is that the suspension of operational activities at the VAS licence is deferred until the result of the legal proceedings is determined. These legal proceedings are continuing through the Ukrainian Court system and the ultimate outcome is not yet known. However, the Group considers that the Order is groundless and that the outcome of the legal proceedings challenging the Order will ultimately be in favour of the Group, and consequently, the Group does not expect any negative effect on its operations in respect of this matter.

On 24 March 2020, the Company completed the acquisition of the entire share capital of LLC Arkona Gas-Energy. In July 2020, legal proceedings issued by NJSC Ukrnafta ("Ukrnafta"), as claimant, against Arkona, as defendant, relating to a claim by Ukrnafta that irregular procedures were followed in the grant of the Svystunivsko-Chervonolutskyi exploration licence (the "Licence") to Arkona in May 2017, were considered by the First Instance Court in Ukraine. Ukrnafta also brought these proceedings against the State Service of Geology and Subsoil of Ukraine ("SGS"). Ukrnafta was the holder of a previous licence over a part of this area which expired prior to the grant of the Licence. Both Arkona and SGS disputed these claims. In the legal proceedings, the First Instance Court made a ruling in favour of Ukrnafta which determined that the grant of the Licence was irregular, and accordingly, the Licence would be invalid. In August 2020, Arkona filed an appeal of this decision in the Appellate Administrative Court in Kyiv, and on 29   September 2020, the Appellate Administrative Court ruled in favour of Arkona, overturning the earlier decision of the First Instance Court. In November 2020, Ukrnafta filed a further appeal in the Supreme Court in Kyiv, appealing the ruling made by the Appellate Administrative Court on 29 September 2020. In February 2021, the Supreme Court delivered its decision and written judgement on this appeal, in which the Supreme Court ruled that the arguments raised by Ukrnafta in the appeal were not substantiated, and that the proceedings against Arkona should be dismissed. The decision of the Supreme Court represents the final appeal procedure in the Ukrainian Courts, and accordingly, these legal proceedings against Arkona have now been exhausted. Prior to the Company's acquisition of Arkona, Ukrnafta had previously issued legal proceedings in 2018, raising substantially the same claims, which proceeded through the First Instance Court and Appellate Administrative Court, before a final appeal was determined by the Supreme Court in October 2019, in which Ukrnafta's claims were denied. In April 2021, an entity named JV Boryslav Oil Company, which is 25.0999% owned by Ukrnafta, issued a further legal claim, also claiming that irregular procedures were followed in the grant of the Licence, which claim was denied by the First Instance Court in July 2021 and by the Appellate Administrative Court in October 2021. There was no further appeal in this case and so the decision of the Appellate Administrative Court is final.  In September 2021, JV Boryslav Oil Company issued a further legal claim, again claiming that irregular procedures were followed in the grant of the Licence, against the SGS and the State Commission of Ukraine for Mineral Resources ("SCP"), as defendants, with Arkona and Ukrnafta named as third parties. In this claim, the First Instance Court made a ruling in January 2022 in favour of JV Boryslav Oil Company, which has been appealed to the Appellate Administrative Court, and this appeal is expected to be determined in the near future. Pending the hearing of this appeal, the ruling of the First Instance Court did not come into force, and consequently, the Licence remains valid.

33.  Related Party Disclosures

Key management personnel of the Group are considered to comprise only the Directors. Details of Directors' remuneration are disclosed in Note 8.

During the year, Group companies entered into the following transactions with related parties who are not members of the Group:

	202 1	20 20
	$000	$000
Sale of goods/services	95,342	32,074
Purchase of goods/services	1,099	890
Amounts owed by related parties	5,008	1,805
Amounts owed to related parties	912	202

All related party transactions were with subsidiaries of the ultimate Parent Company, and primarily relate to the sale of gas (see Note 4 for more details), the rental of office facilities and a vehicle and the sale of equipment. The amounts outstanding were unsecured and will be settled in cash.

As at the date of this announcement, none of the Company's controlling parties prepares consolidated financial statements available for public use. 

34.  Post Balance Sheet Events

On 21 February 2022, the President of Russia announced the recognition of independence of two regions of Ukraine: the self-proclaimed Donetsk People's Republic and the Luhansk People's Republic and ordered the deployment of troops to the two rebel-held eastern regions. On 23 February 2022, the National Security and Defence Council of Ukraine declared a state of emergency. On 24 February 2022, the President of Russia announced a "special military operation" in Ukraine, which de facto represented a declaration of war by the Russian Federation against Ukraine. Russian troops immediately launched a military attack and invasion of Ukraine, with missile strikes on major Ukrainian cities and deployment of troops onto the territory of Ukraine, with the consequent defence by Ukraine, and a wide range of military engagements and activity. The President of Ukraine signed Decree No. 64/2022 "On the imposition of martial law in Ukraine", which was approved by the Ukrainian Parliament. Currently, the Ukrainian army continues to actively resist, and in part push back the invasion. At the same time, a very broad range of countries across the world, imposed sanctions on Russia as a result of its invasion of Ukraine, targeting the Russian economy, financial institutions and a wide range of individuals. Moreover, various international companies are suspending or terminating their activities in Russia.

The final resolution and consequences of these events are hard to predict, but they may have a further serious impact on the Ukrainian economy and business of the Group. Management continues to identify and mitigate, where possible, the impact on the Group, but the majority of these factors are beyond their control, including the duration and severity of conflict, as well as the further actions of various governments and diplomacy.

In light of the Russian military action in Ukraine, on 24 February 2022, the Group shut-in and made safe its production and drilling operations at all of its fields. Subsequently, on 11 March 2022, having taken a number of measures to ensure safe operations, the Group commenced the partial restart of production operations at its MEX-GOL and SV fields, and subsequently field operations have been undertaken at those fields, including the completion of the SV-31 well. More recently, plans have been made to complete the drilling of the SC-4 well at the SC licence area. However, all operations remain suspended at the VAS gas and condensate field.

In January 2022, the Government of Ukraine imposed temporary and partial gas price regulation to sustain production of certain food products. Under this scheme, all independent gas producers in Ukraine were required to sell up to 20% of their natural gas production for the period until 30 April 2022 at a price set as the cost of sales of the relevant gas producer (based on established accounting rules) for such gas, plus a margin of 24%, plus existing subsoil production taxes.

In March 2022, the Ukrainian Government enacted changes to the subsoil production tax rates applicable to natural gas production by modifying the applicable rates based on gas sales prices, extending the incentive rates for new wells for a further 10 years and making improvements to the regulatory environment. These changes took effect on 1 March 2022, and the legislation includes provisions that these rates will not be increased for 10 years. In addition, the excise tax applicable to LPG sales was cancelled entirely with effect from 24 February 2022, and the VAT rate applicable to condensate and LPG sales was reduced to 7% (from 20%) with effect from 18 March 2022.

The events described above constitute non-adjusting post balance sheet events, and therefore they had no effect on the carrying value of the assets and liabilities as at 31 December 2021. Any impact on the carrying value of assets and liabilities will be considered in the results for the six months ended 30 June 2022.

 

END

 

 

FR FZGZVZRGGZZZ