TIDMRPT
RNS Number : 2334Z
Enwell Energy PLC
17 September 2020
17 September 2020
ENWELL ENERGY PLC
2020 INTERIM RESULTS
Enwell Energy plc (the "Company", and with its subsidiaries, the
"Group"), the AIM-quoted (ENW) oil and gas exploration and
production group with assets in Ukraine, today announces its
unaudited results for the six month period ended 30 June 2020.
Highlights
Operations
-- Record aggregate average daily production from the MEX-GOL,
SV and VAS fields of 4,545 boepd, which compares with 4,192
boepd during the first half of 2019, an increase of approximately
8%
-- Completion and hook-up of SV-54 development well in the SV field,
with strong production rates
-- Commencement of drilling of SV-25 appraisal well in the SV field
Finance
-- Revenue of $24.7 million (1H 2019: $31.3 million), down 21%
as a result of weakened gas prices in the period
-- Gross profit of $7.5 million (1H 2019: $13.9 million)
-- Operating profit of $5.2 million (1H 2019: $13.7 million)
-- Net profit for the first half of 2020 of $1.2 million (1H 2019:
$9.9 million)
-- Average realised gas, condensate and LPG prices in Ukraine were
all lower, particularly gas prices, at $139/Mm(3) (UAH3,514/Mm(3)
), $42/bbl and $40/bbl respectively (1H 2019: $256/Mm(3) (UAH6,921/Mm(3)
) gas, $54/bbl condensate and $52/bbl LPG)
-- Cash and cash equivalents of $54.2 million at 30 June 2020,
and at 13 September 2020 of $55.5 million (31 December 2019:
$62.5 million)
Outlook
-- Development work for the remainder of 2020 at MEX-GOL and SV
fields includes: continuing drilling operations of the SV-25
well; planning for a further new well or sidetracking of an
existing well in the SV field; investigating workover opportunities
for existing wells; installation of further compression equipment;
and continued investment in gas processing facilities, intra-field
flowline network and other infrastructure
-- Development work for the remainder of 2020 at VAS field includes:
planning for a new well to explore the VED prospect within the
VAS licence area; installation of compression equipment; and
continued investment in gas processing facilities, flowlines
and other infrastructure
-- Commencement of planning for development of the SC field operated
by Arkona, subject to resolution of legal dispute relating to
the SC licence
-- Development programme for the remainder of 2020 expected to
be funded from existing cash resources and operational cash
flow
-- As of the date of this report, the global economy, and global
social dynamics, are in a state of disruption and uncertainty
as a result of the COVID-19 pandemic. The Board and management
continue to monitor the evolving situation and take any steps
necessary to protect our staff, stakeholders and business alike.
The Group has taken steps to continually monitor the health
of operational staff, including temperature checks for such
staff at the commencement of each shift, as well as investing
in technology to enable many staff to work from remote locations.
As of the date hereof, there has been no operational disruption
linked to the COVID-19 pandemic, and no material impact is currently
envisaged on the Group's prospects. However, the Board and management
remain acutely aware of the risks, and are taking action to
mitigate them where possible, with the safety of individuals
and communities continuing to be the priority.
Sergii Glazunov, CEO, commented: "2020 has been a good
operational year so far, with record production from the MEX-GOL,
SV and VAS fields helping to offset the continued impact of lower
gas prices. We are looking forward to further progressing our
development programme and continuing to improve production rates.
Our solid operational base in tandem with our robust cash resources
positions us well as we continue our value delivery initiatives,
despite current reduced commodity prices. We are closely monitoring
the unprecedented developments of the ongoing COVID-19 pandemic,
and although we have experienced no material impact so far, we have
taken and will continue to take action to ensure the safety of our
employees and local communities."
This announcement contains inside information for the purposes
of Article 7 of EU Regulation 596/2014.
For further information, please contact:
Enwell Energy plc Tel: 020 3427 3550
Chris Hopkinson, Chairman
Sergii Glazunov, Chief Executive Officer
Bruce Burrows, Finance Director
Strand Hanson Limited Tel: 020 7409 3494
Rory Murphy / Richard Tulloch
Arden Partners plc Tel: 020 7614 5900
Ruari McGirr / Dan Gee-Summons (Corporate
Finance)
Simon Johnson (Corporate Broking)
Citigate Dewe Rogerson Tel: 020 7638 9571
Louise Mason-Rutherford / Elizabeth
Kittle
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 press
release in his capacity as a qualified person, as required under
the AIM Rules.
Definitions
AAPG American Association of Petroleum Geologists
Arkona LLC Arkona Gas-Energy
bbl barrel
bbl/d barrels per day
Bm(3) thousands of millions cubic metres
boe barrels of oil equivalent
boepd barrels of oil equivalent per day
C(1) reserves in deposits that were not put into
commercial development and that may be the
subject matter of production testing or
individual well production testing
C(2) reserves in deposits that were not put into
commercial development and that are developed
based on a production testing plan or individual
well production testing plan, matured with
seismic exploration or other methods, and
the availability of which is supported by
geological and geophysical study data as
well as testing data obtained from individual
wells whilst drilling
Company Enwell Energy plc
EUR Euro
Group Enwell Energy plc and its subsidiaries
km kilometre
km(2) square kilometre
LPG liquefied petroleum gas
MEX-GOL Mekhediviska-Golotvshinska
m(3) cubic metres
MMboe million barrels of oil equivalent
MMm(3) million cubic metres
MMscf million scf
MMscf/d million scf per day
Mtonnes thousand tonnes
% per cent
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
$ United States Dollar
UAH Ukrainian Hryvnia
Ukrnaftinvest PJSC Science and Production Concern Ukrnaftinvest
VAS Vasyschevskoye
VED Vvdenska
WPC World Petroleum Council
Chairman's Statement
During the first half of 2020, the Group continued with the
development of the MEX-GOL, SV and VAS gas and condensate fields in
north-eastern Ukraine, with a good operational performance during
the period. Drilling of the SV-54 development well was successfully
completed and brought on production in May 2020, with strong flow
rates.
At the MEX-GOL and SV fields, production was stable during the
first half of 2020, with higher production volumes compared with
the same period last year. At the VAS field production was also
steady, but lower than during the first half of 2019 after a
decline in production from the VAS-10 well in late 2019.
Aggregate average daily production from the MEX-GOL, SV and VAS
fields during the first half of 2020 was a record 4,545 boepd,
which compares with an aggregate daily production rate of 4,192
boepd during the first half of 2019, an increase of approximately
8%, and average daily production of 4,263 boepd for the 2019
year.
During the first half of 2020, the Group's operating profit was
$5.2 million (1H 2019: $13.7 million), with the decrease from the
same period last year predominantly as a result of weakened
European gas prices, despite higher production rates. Cash
generated from operations during the period was also lower at $11.0
million (1H 2019: $17.6 million) for the same reasons.
The fiscal and economic environment in Ukraine remains positive
despite the effects of the COVID-19 outbreak, resulting in lower
GDP growth, declining inflation and weakening Ukrainian Hryvnia
exchange rates. Nevertheless, fiscal and economic challenges in
Ukraine remain and we continue to be vigilant.
The deregulation of the gas supply market, supported by
electronic gas trading platforms and improved pricing transparency,
has meant that the market gas prices in Ukraine broadly correlate
with the imported gas prices. During the first half of 2020, gas
prices trended lower, reflecting a similar trend in European gas
prices, and were significantly lower than in the same period in
2019. Similarly, condensate and LPG prices were also lower by
comparison with the first half of 2019.
Arkona Acquisition
As announced on 24 March 2020, the Group has acquired the entire
issued share capital of LLC Arkona Gas-Energy ("Arkona") for total
consideration of up to $8.63 million, subject to satisfaction of
certain conditions. Arkona holds a 100% interest in the
Svystunivsko-Chervonolutskyi ("SC") exploration licence in
north-eastern Ukraine, some 15 km east of the SV field. The SC
licence was granted in May 2017, with a duration of 20 years, and
is prospective for gas and condensate. As with the productive
reservoirs in the SV field, the prospective reservoirs in this
licence are Visean, at depths between 4,600 - 6,000 metres.
However, NJSC Ukrnafta has issued legal proceedings against
Arkona, in which NJSC Ukrnafta has made claims about the procedure
involved in the grant of the SC licence to Arkona in May 2017 (see
announcements dated 3 July and 31 July 2020). In early July 2020,
the First Instance Court in Ukraine announced a ruling in favour of
NJSC Ukrnafta, which found that the grant of the SC licence was
irregular, which would mean the licence is invalid. Arkona disputes
these claims and is defending such legal proceedings, and
consequently has filed an appeal in the Appellate Administrative
Court in Kyiv. Pending the outcome of the appeal process, the SC
licence remains valid.
COVID-19
We continue to closely monitor the current volatility in global
financial markets, and the implications on the operational,
economic and social environment within which we work caused by the
COVID-19 pandemic, coupled with the recent sharp decline in
hydrocarbon prices. As of the date hereof, there has been no
operational disruption linked to the COVID-19 pandemic, and no
material impact is currently envisaged on the Group's prospects.
However, the Board and management remain acutely aware of the
risks, and continue to take action to mitigate them where possible,
not only to protect our staff and stakeholders but also to minimise
disruption to our business. We have taken steps to continually
monitor the health of our operational staff, including temperature
checks for such staff at the commencement of each shift, as well as
investing in technology to enable many staff to work from remote
locations. We continue to reassess our medium-term forecasts based
on current pricing and are confident we have the resources to
continue to deliver on our plans. Of course, we cannot be certain
of the duration of the pandemic's impact but will remain focussed
on monitoring and protecting our business through the period of
uncertainty. In protecting our stakeholders' interests, we are
conscious of our wider obligations to the communities, and country,
in which we operate. Accordingly, as previously announced, we have
acted, alongside other corporate entities in Ukraine, to directly
acquire critical equipment and supplies from Chinese suppliers to
donate to the Ukrainian State to assist its efforts to manage the
pandemic in Ukraine. Our monetary contribution of $2 million to
this initiative is reflected in the results for the period.
Outlook
Whilst there are still challenges in the business environment in
Ukraine, the situation is relatively stable despite the COVID-19
outbreak. After the steady operational performance during the first
half of 2020, and the increased production output during the
period, we are looking forward to the results of the SV-25
appraisal well, which are expected in the first half of 2021. We
are also looking forward to achieving further success in the
development activities planned for the remainder of 2020 and
delivering a steadily increasing production and revenue stream in
the future.
In conclusion, on behalf of the Board, I would like to thank all
of our staff for the continued dedication and support they have
shown during the year and especially in the midst of the COVID-19
pandemic.
Chris Hopkinson
Chairman
16 September 2020
Chief Executive Officer's Statement
Introduction
The Group continued its good progress at its Ukrainian fields
during 2020 with development activity at the MEX-GOL and SV fields,
including the successful drilling of the SV-54 development well,
which came on production in May, the commencement of the SV-25 well
and work to upgrade the gas processing facilities and flow-line
network and undertake remedial work on existing wells.
At the VAS field, planning for the proposed new well to explore
the VED prospect within the VAS licence area has continued, and
upgrades to the gas processing facilities, flow-line network and
other infrastructure are underway.
Overall production continued its upward trend during the period,
achieving record levels for the Group and being 8% higher than in
the first half of 2019, with a substantial boost in the second
quarter, once the SV-54 well came on production.
Production
The average daily production of gas, condensate and LPG from the
MEX-GOL, SV and VAS fields for the six month period ended 30 June
2020 was as follows:-
Field Gas Condensate LPG Aggregate
(MMscf/d) (bbl/d) (bbl/d) boepd
1H 2020 1H 2019 1H 2020 1H 2019 1H 2020 1 2019 1H 2020 1H 2019
-------- -------- -------- -------- -------- ------- -------- --------
MEX-GOL
& SV 17.4 14.0 654 542 292 273 3,941 3,203
-------- -------- -------- -------- -------- ------- -------- --------
VAS 3.1 4.9 34 81 - - 604 989
-------- -------- -------- -------- -------- ------- -------- --------
Total 20.5 18.9 688 623 292 273 4,545 4,192
-------- -------- -------- -------- -------- ------- -------- --------
Production rates were higher when compared with the
corresponding period in 2019, predominantly due to the
contributions of the MEX-119 well, which commenced production in
October 2019, and the SV-54 well, which commenced production in May
2020.
The Group's average daily production for the period from 1 July
2020 to 31 August 2020 from the MEX-GOL and SV field was 18.3
MMscf/d of gas, 640 bbl/d of condensate and 292 bbl/d of LPG (4,079
boepd in aggregate) and from the VAS field was 2.9 MMscf/d of gas
and 30 bbl/d of condensate (577 boepd in aggregate).
Operations
The relatively stable fiscal and economic conditions in Ukraine
, coupled with reductions in the subsoil tax rates and improvements
in the regulatory procedures in the oil and gas sector in Ukraine
over recent periods, have given the Board confidence to continue
the Group's development programme at its Ukrainian fields during
2020. However, lower realised gas prices significantly impacted
revenues, following a general decline in gas prices in Europe.
The Group continued to refine its geological subsurface models
of the MEX-GOL, SV and VAS fields, in order to enhance its
strategies for the further development of the 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-54
development well was completed to a final depth of 5,322 metres.
One interval, at a drilled depth of 5,303 - 5,308 metres in the
B-23 Visean formation, was perforated, and after successful
testing, the well was hooked-up to the gas processing facilities.
The well has demonstrated good production rates and is currently
producing at approximately 2.0 MMscf/d of gas and 9.3 bbl/d of
condensate (355 boepd in aggregate).
In July 2020, the SV-25 well was spudded. This well has a target
depth of 5,320 metres, with drilling operations scheduled to be
completed by the end of the first quarter of 2021, and, subject to
successful testing, production hook-up during the second quarter of
2021. The well is an appraisal well, with its primary targets being
the B-20, B-22 and B-23 horizons in the Visean formation.
The Group continues 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.
Both of these wells have proven to be strong producers since being
brought back on production.
At the VAS field, planning has continued for a new well to
explore the VED prospect within the VAS licence area. However, a
decline in production rates from the VAS-10 well impacted overall
production at the VAS field during the fourth quarter of 2019, and
as a result, compression equipment was installed to increase
production from this well, with a longer term plan to undertake a
workover of the well to access an alternative reservoir
horizon.
In March 2019 (see 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.
New Acquisitions
As announced on 24 March 2020, the Group has acquired the entire
issued share capital of LLC Arkona Gas-Energy ("Arkona") for total
consideration of up to $8.63 million, with $4.3 million subject to
the satisfaction of certain conditions as set out therein. 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 has an area of 97 km(2) , 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 are Visean, at depths
between 4,600 - 6,000 metres.
According to the recorded information on the Ukrainian State
Balance of Natural Resources as at 1 January 2020, the licence has
hydrocarbon reserves, in the category of C(1) and C(2) under the
Ukrainian classification, DKZ, of approximately 38.0 MMboe (4.9
Bm(3) of gas and 0.86 Mtonnes of condensate). It should be noted,
however, that whilst the Group's review of existing technical data
for the licence is considered supportive of such assessment of
hydrocarbon reserves, such hydrocarbon reserves have not been
verified by an independent reserves assessor and do not correspond
to the SPE/WPC/AAPG/SPEE Petroleum Resources Management System
("PRMS") standard for classification and reporting.
However, NJSC Ukrnafta, as claimant, has issued legal
proceedings against Arkona, as defendant, in which NJSC Ukrnafta
has made claims about the procedure involved in the grant of the SC
licence to Arkona in May 2017 (see announcements dated 3 July and
31 July 2020). NJSC Ukrnafta was the holder of a previous licence
over this area which expired prior to the grant of the SC licence.
In early July 2020, the First Instance Court in Ukraine announced a
ruling in favour of NJSC Ukrnafta, which found that the grant of
the SC licence was irregular, which would mean the licence is
invalid. Arkona disputes these claims and is defending such legal
proceedings, and consequently has filed an appeal in the Appellate
Administrative Court in Kyiv. Pending the outcome of the appeal
process, the SC licence remains valid. The Group considers Arkona
has strong grounds for a successful appeal since the subject matter
of these legal proceedings, including the validity of the SC
licence, has already been ruled upon by the Supreme Court of
Ukraine in similar proceedings in October 2019 involving, inter
alia, NJSC Ukrnafta and Arkona, in which the SC licence was held to
be valid. As a result, the Group is confident that the challenge to
the SC licence will be resolved in favour of Arkona.
Under the terms of the acquisition agreement for Arkona, half of
the consideration payable (split into two equal tranches) was
deferred and only payable on satisfaction of certain conditions
including the favourable resolution of these legal proceedings, as
well as certain other conditions, with the further proviso that if
the conditions for payment of these deferred tranches are not
satisfied, then neither of these tranches shall become payable. In
addition, the acquisition agreement contains customary warranties
and indemnities allowing the Group to seek recovery of
consideration previously paid in the event of a breach of such
warranties and indemnities, which include an adverse outcome of
these legal proceedings.
As announced on 1 April 2020, the Memorandum of Understanding
(the "Memorandum") for the potential acquisition of PJSC Science
and Production Concern Ukrnaftinvest ("Ukrnaftinvest") , announced
on 26 November 2019, expired and was consequently terminated as a
result of the parties to the Memorandum, being (1) the Company and
(2) Ms Lidiia Chernysh and Bolaso Investments Limited, being unable
to reach a final agreement for such potential acquisition on the
contemplated terms at the time. As a result, the provisions
relating to such termination set out in the Memorandum became
applicable, which included the refund of the deposit of $0.5
million previously paid to the sellers under the Memorandum. This
remains to be paid. In addition, the Group made a series of
advances, now totalling UAH47.3 million (approximately $1.8
million) to Ukrnaftinvest over the period from October 2019 to
March 2020 in conjunction with the MOU. The payments were to fund
certain operational works in preparation for a well which is
scheduled under the work commitments for the licences held by
Ukrnaftinvest, and these advances are also now repayable.
Notwithstanding these provisions and the terminated Memorandum, the
parties to it continue to be engaged in discussions in relation to
the acquisition of Ukrnaftinvest, and the Group believes revised
terms will be agreed, albeit there can be no certainty.
Accordingly, these amounts are regarded as recoverable at the date
of this announcement.
Outlook
During the remainder of 2020, the Group will continue to develop
the MEX-GOL, SV and VAS fields. At the MEX-GOL and SV fields, the
development programme includes continuing drilling operations of
the SV-25 appraisal well, planning for a further well or
sidetracking of an existing well in the SV field, investigating
workover opportunities for other existing wells, installation of
further compression equipment, further upgrading of the gas
processing facilities and flow-line network, and remedial and
upgrade work on existing wells, pipelines and other
infrastructure.
At the VAS field, planning for the proposed new well to explore
the VED prospect within the VAS licence area is continuing, and
upgrades to the gas processing facilities, pipeline network and
other infrastructure are planned.
Ongoing legislative reforms and the general stability in the
business climate in Ukraine, are encouraging and supportive of the
independent oil and gas producers in Ukraine.
Finally, I would like to add my thanks to all of our staff for
the continued hard work and dedication they have shown during this
year, and to especially recognise their continuing efforts and
professionalism during the current COVID-19 pandemic.
Sergii Glazunov
Chief Executive Officer
Finance Review
The Group's financial performance in the first half of 2020 was
shaped largely by two factors, the significant drop in average gas
realisations materially affecting revenue but partly mitigated by
the record level of gas production, and sale of gas from storage.
Despite the challenges during the period, the Group was delighted
to make a net profit of $1.2 million (1H 2019: $9.9 million).
Average gas realisations in the period were down 46% at
$139/Mm(3) compared to $256/Mm(3) in 1H 2019, with condensate and
LPG sales also down by 22% and 23% at $42/bbl and $40/bbl
respectively (1H 2019: $256/Mm(3) (UAH6,921/Mm(3) ), $54/bbl and
$52/bbl respectively).
Since the deregulation of the gas supply market in Ukraine in
October 2015, the market price for gas has broadly correlated to
the price of imported gas, which generally reflects trends in
European gas prices. Gas prices are also subject to seasonal
variation. During the first half of 2020, gas prices were
depressed, as a combined result of lower international prices
reducing the price of imported gas, and the unseasonally warm
2019/20 winter.
During the period from 1 July 2020 to 14 September 2020, the
average realised gas, condensate and LPG prices were $159/Mm(3)
(UAH4,352/Mm(3) ), $54/bbl and $65/bbl respectively.
Over and above the record level of production in the period, the
Company also sold 24 MMm(3) of gas held in inventory at 31 December
2019. The inventory was valued at its cost of $3.0 million, all of
which was recognised in the period as costs of sales, along with
the associated revenue.
Revenue for the period, derived from the sale of the Group's
Ukrainian gas, condensate and LPG production, was $24.7 million (1H
2019: $31.3 million). The gas price-driven fall in revenue also
impacted cash generated from operations during the period, which
was 59% lower at $7.2 million (1H 2019: $17.4 million).
Gross profit for the six months period to 30 June 2020 was $7.5
million (2019: $13.9 million).
Cost of sales for the period ended 30 June 2020 was marginally
lower at $17.2 million (1H 2019: $17.3 million). Whilst broadly
consistent with the same period in 2019, there were some
significant intra-total movements: production taxes declined by 27%
as a result of reduced gas revenues, in turn a function of the
reduced gas prices as noted above; a 35% decrease in rent expense,
a function of decreased gas prices; and the transmission tariff for
use of the Ukrainian gas transit system of UAH101.93/Mm(3) of gas
was applicable to the Group (1H 2019: UAH91.87/Mm(3) ), resulting
in a $0.4 million (1H 2019: $0.4 million) charge in the period.
The subsoil tax rates applicable to gas production were stable
during the period 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.
Administrative expenses for the period were higher at $3.9
million (1H 2019: $2.9 million), primarily as a result of: a 173%
increase in consultancy fees mainly due to legal and advisory costs
associated with the acquisition activity in the period; and a 61%
increase in other expenses primarily in relation to increased costs
for managing gas transportation and storage, and marketing.
Other expenses in the period significantly increased due to
charitable donations of $2.1 million (1H 2019: nil) for the supply
of COVID-19-related medical equipment for Ukrainian authorities and
charitable foundations .
The tax charge for the six month period ended 30 June 2020 of
$1.4 million (1H 2019: $3.4 million charge) comprises a current tax
charge of $1.4 million (1H 2019: $1.7 million charge) and a
deferred tax charge of $10,000 (1H 2019: $1.7 million charge).
Capital investment of $8.8 million reflects investment in the
Group's oil and gas development and production assets during the
period (1H 2019: $6.7 million), primarily relating to the
expenditure associated with the drilling of the SV-54 well.
Cash and cash equivalents held at 30 June 2020 were $54.2
million (31 December 2019: $62.5 million cash and cash
equivalents). The Group's cash and cash equivalents balance at 13
September 2020 was $55.5 million, held as to $15.5 million
equivalent in Ukrainian Hryvnia, and the balance of $40.0 million
equivalent predominantly in US Dollars, Euros and Pounds
Sterling.
Between early 2014 and 2018, the Ukrainian Hryvnia devalued
significantly against the US Dollar, falling from UAH8.3/$1.00 on 1
January 2014 to UAH27.7/$1.00 on 31 December 2018, which resulted
in substantial foreign exchange translation losses for the Group
over that period, and in turn adversely impacted the carrying value
of the MEX-GOL and SV asset due to the translation of two of the
Group's subsidiaries from their functional currency of Ukrainian
Hryvnia to the Group's presentation currency of US Dollars. In the
first half of 2020, global financial markets have become extremely
volatile as a combined function of a significant fall in oil prices
and the effects of the COVID-19 pandemic, and the Ukrainian Hryvnia
has weakened against the US Dollar with the exchange rate at 30
June 2020 being UAH26.69/$1.00. The impact of this devaluation was
$10.8 million of foreign exchange losses (1H 2019: $4.9 million of
foreign exchange gain). Further devaluation of the Ukrainian
Hryvnia against the US Dollar may affect the carrying value of the
Group's assets in the future.
Cash from operations has funded the capital investment during
the period, 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 the remainder of
2020 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 the 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 cash resources at the end of the period in excess of
$54 million, and annual running costs (both operating, and general
and administrative) of less than $16 million, the Group remains in
a very strong position should any local or global shocks occur to
the industry and/or the Group.
Bruce Burrows
Finance Director
Principal Risks and Uncertainties
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
-----------------------------------------------
Risk relating to Ukraine
-----------------------------------------------
Ukraine is an emerging market and The Group minimises this risk by
as such, the Group is exposed to continuously monitoring the market
greater regulatory, economic and in Ukraine and by maintaining a
political risks than it would be strong working relationship with
in other jurisdictions. Emerging the Ukrainian regulatory authorities.
economies are generally subject The Group also maintains a significant
to a volatile political and economic proportion of its cash holdings
environment, which makes them vulnerable in international banks outside Ukraine.
to market downturns elsewhere in
the world, and could adversely
impact the Group's ability to operate
in the market.
-----------------------------------------------
Regional conflict
-----------------------------------------------
Ukraine continues to have a strained As the Group has no assets in Crimea
relationship with Russia, following or the areas of conflict in the
Ukraine's agreement to join a free east of Ukraine, nor do its operations
trade area with the European Union, rely on sales or costs incurred
which resulted in the implementation there, the Group has not been directly
of mutual trade restrictions between affected by the conflict. However,
Russia and Ukraine on many key the Group continues to monitor the
products. Further, the conflict situation and endeavours to procure
in parts of eastern Ukraine has its equipment from sources in other
not been resolved to date, and markets. The disputes and interruption
Russia continues to occupy Crimea. to the supply of gas from Russia
This conflict has put further pressure has indirectly encouraged Ukrainian
on relations between Ukraine and Government support for the development
Russia, and the political tensions of the domestic production of hydrocarbons
have had an adverse effect on the since Ukraine imports a significant
Ukrainian financial markets, hampering proportion of its gas, which has
the ability of Ukrainian companies resulted in legislative measures
and banks to obtain funding from to improve the regulatory requirements
the international capital and debt for hydrocarbon extraction in Ukraine.
markets. This strained relationship
between Russia and Ukraine has
also resulted in disputes and interruptions
in the supply of gas from Russia.
-----------------------------------------------
Banking system in Ukraine
-----------------------------------------------
The banking system in Ukraine has The creditworthiness and potential
been under great strain in recent risks relating to the banks in Ukraine
years due to the weak level of are regularly reviewed by the Group,
capital, low asset quality caused but the geopolitical and economic
by the economic situation, currency events since 2013 in Ukraine have
depreciation, changing regulations significantly weakened the Ukrainian
and other economic pressures generally, banking sector. In light of this,
and so the risks associated with the Group has taken and continues
the banks in Ukraine have been to take steps to diversify its banking
significant, including in relation arrangements between a number of
to the banks with which the Group banks in Ukraine. These measures
has operated bank accounts. However, are designed to spread the risks
following remedial action imposed associated with each bank's creditworthiness,
by the National Bank of Ukraine, and the Group endeavours to use
Ukraine's banking system has improved banks that have the best available
moderately. Nevertheless, Ukraine creditworthiness. Nevertheless,
continues to be supported by funding and despite some recent improvements,
from the International Monetary the Ukrainian banking sector remains
Fund. 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 have been some improvements The Group continually monitors the
in recent years, there has not market and business environment
been a final resolution of the in Ukraine and endeavours to recognise
political, fiscal and economic approaching risks and factors that
situation in Ukraine and its ongoing may affect its business. In addition,
effects are difficult to predict the involvement of Lovitia Investments
and likely to continue to affect Limited, as the indirect majority
the Ukrainian economy and potentially shareholder with extensive experience
the Group's business. Whilst not in Ukraine, is considered helpful
materially affecting the Group's to mitigate such risks.
production operations, the instability
has disrupted the Group's development
and operational planning for its
assets.
-----------------------------------------------
Climate change
-----------------------------------------------
Any near and medium-term continued The Group's plans and actions include:
warming of the Planet can have assessing, reducing and/or mitigating
potentially increasing negative its emissions in its operations;
social, economic and environmental and identifying climate change-related
consequences, generally globally risks and assessing the degree to
and regionally, and specifically which they can affect its business,
in relation to the Group. The potential including financial implications.
impacts include: loss of market;
and increased costs of operation
through increasing regulatory oversight
and controls, including potential
effective or actual loss of licence
to operate. As a diligent operator
aware 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.
-----------------------------------------------
Operational and technical risks
-----------------------------------------------
Quality, Health, Safety and Environment
("QHSE")
-----------------------------------------------
The oil and gas industry, by its The Group maintains QHSE policies
nature, conducts activities which and requires that management, staff
can cause health, safety, environmental and contractors adhere to these
and security incidents. Serious policies. The policies ensure that
incidents can not only have a financial the Group meets Ukraine legislative
impact but can also damage the standards in full and achieves international
Group's reputation and the opportunity standards to the maximum extent
to undertake further projects. possible. As a consequence of the
As evidenced by events to date COVID-19 pandemic, including the
in 2020, pandemics also pose a threat of any resurgences in the
risk to operations, by potential scale and impact of the virus, or
illness and threat to life of employees new viruses, the Group is re-visiting
and contractors, and the associated processes and controls intended
disruptions in staffing levels, to ensure protection of all our
operations and supply chain. stakeholders and minimise any disruption
to our business. Whilst possible
to only a limited extent in field
operations, we have invested in
technology that will allow many
staff to work just as effectively
from remote locations.
-----------------------------------------------
Industry risks
-----------------------------------------------
The Group is exposed to risks which The Group has well qualified and
are generally associated with the experienced technical management
oil and gas industry. For example, staff to plan and supervise operational
the Group's ability to pursue and activities. In addition, the Group
develop its projects and development engages with suitably qualified
programmes depends on a number local and international geological,
of uncertainties, including the geophysical and engineering experts
availability of capital, seasonal and contractors to supplement and
conditions, regulatory approvals, broaden the pool of expertise available
gas, oil, condensate and LPG prices, to the Group. Detailed planning
development costs and drilling of development activities is undertaken
success. As a result of these uncertainties, with the aim of managing the inherent
it is unknown whether potential risks associated with oil and gas
drilling locations identified on exploration and production, as well
proposed projects will ever be as ensuring that appropriate equipment
drilled or whether these or any and personnel are available for
other potential drilling locations the operations, and that local contractors
will be able to produce gas, oil are appropriately supervised.
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.
-----------------------------------------------
Production of hydrocarbons
-----------------------------------------------
Producing gas and condensate reservoirs In 2016, the Group engaged external
are generally characterised by technical consultants to undertake
declining production rates which a comprehensive review and re-evaluation
vary depending upon reservoir characteristics study of the MEX-GOL and SV fields
and other factors. Future production in order to gain an improved understanding
of the Group's gas and condensate of the geological aspects of the
reserves, and therefore the Group's fields and reservoir engineering,
cash flow and income, are highly drilling and completion techniques,
dependent on the Group's success and the results of this study and
in operating existing producing further planned technical work is
wells, drilling new production being used by the Group in the future
wells and efficiently developing development of these fields. In
and exploiting any reserves, and addition, an evaluation study was
finding or acquiring additional undertaken on the VAS field prior
reserves. The Group may not be to its acquisition in 2016 and this
able to develop, find or acquire was updated in 2019. The Group has
reserves at acceptable costs. The established an ongoing relationship
experience gained from drilling with such external technical consultants
undertaken to date highlights such to ensure that technical management
risks as the Group targets the and planning is of a high quality
appraisal and production of these in respect of all development activities
hydrocarbons. on the Group's fields.
-----------------------------------------------
Risks relating to further development
and operation of the Group's gas
and condensate fields in Ukraine
-----------------------------------------------
The planned development and operation The Group's technical management
of the Group's gas and condensate staff, in consultation with its
fields in Ukraine is susceptible external technical consultants,
to appraisal, development and operational carefully plan and supervise development
risk. This could include, but is and operational activities with
not restricted to, delays in delivery the aim of managing the risks associated
of equipment in Ukraine, failure with the further development of
of key equipment, lower than expected the Group's fields in Ukraine. This
production from wells that are includes detailed review and consideration
currently producing, or new wells of available subsurface data, utilisation
that are brought on-stream, problematic of modern geological software, and
wells and complex geology which utilisation of engineering and completion
is difficult to drill or interpret. techniques developed for the fields.
The generation of significant operational With operational activities, the
cash is dependent on the successful Group ensures that appropriate equipment
delivery and completion of the and personnel is available for the
development and operation of the operations, and that operational
fields. contractors are appropriately supervised.
In addition, the Group performs
a review of its oil and gas assets
for impairment 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 utilisation of detailed sub-surface
the reservoirs in the Group's fields, analysis, careful well planning
the technical difficulty of drilling and engineering design in designing
or re-entering wells in the Group's work programmes, along with appropriate
fields is high, and this and the procurement procedures and competent
equipment limitations within Ukraine, on-site management, aims to minimise
can result in unsuccessful or lower these risks.
than expected outcomes for wells.
-----------------------------------------------
Maintenance of facilities
-----------------------------------------------
There is a risk that production The Group's facilities are operated
or transportation facilities can and maintained at standards above
fail due to non-adequate maintenance, the Ukraine minimum legal requirements.
control or poor performance of Operations staff are experienced
the Group's suppliers. 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 The Group maintains adequate cash
funds are available to meet the reserves and closely monitors forecasted
Group's development obligations and actual cash flow, as well as
to commercialise the Group's oil short and longer-term funding requirements.
and gas assets. Since a significant The Group does not currently have
proportion of the future capital any loans outstanding, internal
requirements of the Group is expected financial projections are regularly
to be derived from operational made based on the latest estimates
cash generated from production, available, and various scenarios
including from wells yet to be are run to assess the robustness
drilled, there is a risk that in of the liquidity of the Group. However,
the longer term, insufficient operational as the risk to future capital funding
cash is generated, or that additional is inherent in the oil and gas exploration
funding, should the need arise, and development industry and reliant
cannot be secured. 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, The Group maintains anti-bribery
an emerging market, where certain and corruption policies in relation
inappropriate business practices to all aspects of its business,
may, from time to time occur, such and ensures that clear authority
as corrupt business practices, levels and robust approval processes
bribery, appropriation of property are in place, with stringent controls
and fraud, all of which can lead over cash management and the tendering
to financial loss. 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 The Group sells a proportion of
from the sale of its Ukrainian its hydrocarbon production through
gas, condensate and LPG production. long-term offtake arrangements,
These revenues are subject to commodity which include pricing formulae so
price volatility and political as to ensure that it achieves market
influence. A prolonged period of prices for its products, as well
low gas, condensate and LPG prices utilising the electronic market
may impact the Group's ability platforms in Ukraine to achieve
to maintain its long-term investment market prices for its remaining
programme with a consequent effect products. However, hydrocarbon prices
on growth rate, which in turn may in Ukraine are implicitly linked
impact the share price or any shareholder to world hydrocarbon prices and
returns. Lower gas, condensate so the Group is subject to external
and LPG prices may not only decrease price trends.
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.
-----------------------------------------------
Currency risk
-----------------------------------------------
Since the beginning of 2014 , the The Group's sales proceeds are received
Ukrainian Hryvnia significantly in Ukrainian Hryvnia, and the majority
devalued against major world currencies, of the capital expenditure costs
including the US Dollar, where for the current investment programme
it has fallen from UAH8.3/$1.00 will be incurred in Ukrainian Hryvnia,
on 1 January 2014 to UAH26.7/$1.00 thus the currency of revenue and
on 30 June 2020 This devaluation costs are largely matched. In light
has been a significant contributor of the previous devaluation and
to the imposition of the banking volatility of the Ukrainian Hryvnia
restrictions by the National Bank against major world currencies,
of Ukraine over recent years. In and since the Ukrainian Hryvnia
addition, the geopolitical events does not benefit from the range
in Ukraine over recent years, are of currency hedging instruments
likely to continue to impact the which are available in more developed
valuation of the Ukrainian Hryvnia economies, the Group has adopted
against major world currencies. a policy that, where possible, funds
Further devaluation, and volutility, not required for use in Ukraine
of the Ukrainian Hryvnia against be retained on deposit in the United
the US Dollar will affect the carrying Kingdom and Europe, principally
value of the Group's assets. in US Dollars.
-----------------------------------------------
Counterparty and credit risk
-----------------------------------------------
The challenging political and economic The Group monitors the financial
environment in Ukraine means that position and credit quality of its
businesses can be subject to significant contractual counterparties and seeks
financial strain, which can mean to manage the risk associated with
that the Group is exposed to increased counterparties by contracting with
counterparty risk if counterparties creditworthy contractors and customers.
fail or default in their contractual Hydrocarbon production is sold on
obligations to the Group, including terms that limit supply credit and/or
in relation to the sale of its title transfer until payment is
hydrocarbon production, resulting received .
in financial loss to the Group.
-----------------------------------------------
Financial markets and economic
outlook
-----------------------------------------------
The performance of the Group is The Group's sales proceeds are received
influenced by global economic conditions in Ukrainian Hryvnia and a significant
and, in particular, the conditions proportion of investment expenditure
prevailing in the United Kingdom is made in Ukrainian Hryvnia, which
and Ukraine. The economies in these minimises risks related to foreign
regions have been subject to volatile exchange volatility. However, hydrocarbon
pressures in recent periods, with prices in Ukraine are implicitly
the global economy having experienced linked to world hydrocarbon prices
a long period of difficulties, and so the Group is subject to external
and more particularly the events price movements. The Group holds
that have occurred in Ukraine over a significant proportion of its
recent years. This has led to extreme cash reserves in the United Kingdom
foreign exchange movements in the and Europe, mostly in US Dollars,
Ukrainian Hryvnia , high inflation with reputable financial institutions.
and interest rates, and increased The financial status of counterparties
credit risk relating to the Group's is carefully monitored to manage
key counterparties. counterparty risks. Nevertheless,
the risks 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
-----------------------------------------------
Ukraine production licences
-----------------------------------------------
The Group operates in a region The Group ensures compliance with
where the right to production can commitments and regulations relating
be challenged by State and non-State to its production licences through
parties. In 2010, this manifested Group procedures and controls or,
itself in the form of a Ministry where this is not immediately feasible
Order instructing the Group to for practical or logistical considerations,
suspend all operations and production seeks to enter into dialogue with
from its MEX-GOL and SV production the relevant Government bodies with
licences, which was not resolved a view to agreeing a reasonable
until mid-2011. In 2013, new rules time frame for achieving compliance
relating to the updating of production or an alternative, mutually agreeable
licences led to further challenges course of action. Work programmes
being raised by the Ukrainian authorities are designed to ensure that all
to the production licences held licence obligations are met and
by independent oil and gas producers continual interaction with Government
in Ukraine, including the Group, bodies is maintained in relation
which may result in requirements to licence obligations and commitments.
for remediation work, financial
penalties and/or the suspension
of such licences, which, in turn,
may adversely affect the Group's
operations and financial position.
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 continuing, but this matter
remains unresolved. 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, these licences carry
ongoing compliance obligations,
which if not met, may lead to the
loss of a licence.
-----------------------------------------------
Extension of MEX-GOL and SV licences
-----------------------------------------------
The Group's production licences The Group monitors legislation in
for the MEX-GOL and SV fields currently Ukraine which is likely to affect
expire in 2024. However, in the its licences and the obligations
estimation of its reserves, it associated therewith, and ensures
is assumed that licence extensions that its licence compliance obligations
will be granted in accordance with are monitored and maintained as
current Ukrainian legislation and such compliance is a likely to be
that consequently the fields' development a factor in the extension of the
will continue until the end of licences in 2024.
the fields' economic life in 2038
for the MEX-GOL field and 2042
for the SV field. Despite such
legislation, it is possible that
licence extensions will not be
granted, which would affect the
achievement of full economic field
development and consequently the
carrying value of the Group's MEX-GOL
and SV asset in the future .
-----------------------------------------------
Risks relating to key personnel
-----------------------------------------------
The Group's success depends upon The Group periodically reviews the
skilled management as well as technical compensation and contractual terms
expertise and administrative staff. of its staff. In addition, the Group
The loss of service of critical has developed relationships with
members from the Group's team could a number of technical and other
have an adverse effect on the business. professional experts and advisers,
who are used to provided specialist
services as required.
-----------------------------------------------
Directors Responsibility Statement
The Directors confirm that, to the best of their knowledge:-
a) the unaudited condensed interim consolidated financial statements have
been prepared in accordance with IAS 34 as adopted by the European Union;
and
b) these unaudited interim results include:
(i) a fair review of the information required (i.e. an indication
of important events and their impact and a description of
the principal risks and uncertainties for the remaining
six months of the financial year); and
(ii) a fair review of the information required on related party
transactions.
A list of current Directors is maintained on the Group's website, www.enwell-energy.com.
Condensed Interim Consolidated Income Statement
6 months
6 months ended ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
Note $000 $000
Revenue 3 24,708 31,273
Cost of sales 4 (17,203) (17,347)
---------------------------------- ----- --------------- ------------
Gross profit 7,505 13,926
Administrative expenses (3,852) (2,857)
Other operating income, (net) 5 1,500 2,619
Operating profit 5,153 13,688
Net impairment (losses)/gains on
financial assets (29) 11
Loss on disposal of subsidiary - (115)
Other expenses, (net) 6 (1,925) (625)
Finance income - 516
Finance costs (604) (220)
Profit before taxation 2595 13,255
Income tax expense 7 (1,366) (3,368)
---------------------------------- ----- --------------- ------------
Profit for the period 1,229 9,887
---------------------------------- ----- --------------- ------------
Earnings per share (cents)
Basic and diluted 8 0.4c 3.1c
---------------------------------- ----- --------------- ------------
The Notes set out below are an integral part of these unaudited
condensed interim consolidated financial statements.
Condensed Interim Consolidated Statement of Comprehensive
Income
6 months ended 6 months
ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
Profit for the period 1,229 9,887
Other comprehensive income:
Items that may be subsequently reclassified
to profit or loss:
Equity - foreign currency translation (10,841) 4,919
Total other comprehensive income (10,841) 4,919
Total comprehensive (loss)/income for
the period (9,612) 14,806
--------------------------------------------- --------------- ------------
The Notes set out below are an integral part of these unaudited
condensed interim consolidated financial statements.
Condensed Interim Consolidated Balance Sheet
30 Jun 20 31 Dec 19
(unaudited) (audited)
Note $000 $000
Assets
Non-current assets
Property, plant and equipment 9 64,254 70,052
Intangible assets 10 12,680 5,197
Right-of-use assets 677 940
Prepayment for shares 11 500 500
Corporation tax receivable 29 10
Deferred tax asset 7 25 -
78,165 76,699
Current assets
Inventories 1,939 4,813
Trade and other receivables 11 10,199 10,937
Cash and cash equivalents 14 54,228 62,474
------------------------------- ----- ------------ ----------
66,366 78,224
Total assets 144,531 154,923
------------------------------- ----- ------------ ----------
Liabilities
Current liabilities
Trade and other payables (4,922) (3,968)
Lease liabilities (389) (454)
Corporation tax payable (450) (2,221)
------------------------------- ----- ------------ ----------
(5,761) (6,643)
------------------------------- ----- ------------ ----------
Net current assets 60,605 71,581
------------------------------- ----- ------------ ----------
Non-current liabilities
Provision for decommissioning 12 (5,849) (7,447)
Lease liabilities (375) (515)
Defined benefit liability (418) (480)
Deferred tax liability 7 (2,196) (2,288)
Other non-current liabilities 13 (1,994) -
(10,832) (10,730)
Total liabilities (16,593) (17,373)
------------------------------- ----- ------------ ----------
Net assets 127,938 137,550
------------------------------- ----- ------------ ----------
Equity
Called up share capital 28,115 28,115
Share premium account 555,090 555,090
Foreign exchange reserve (101,013) (90,172)
Other reserves 4,273 4,273
Accumulated losses (358,527) (359,756)
------------------------------- ----- ------------ ----------
Total equity 127,938 137,550
------------------------------- ----- ------------ ----------
The Notes set out below are an integral part of these unaudited
condensed interim consolidated financial statements.
Condensed Interim Consolidated Statement of Changes in
Equity
Called Share Merger Capital Foreign
up share premium reserve contributions exchange Accumulated Total
capital account reserve reserve* losses equity
$000 $000 $000 $000 $000 $000 $000
As at 1 January 2020
(audited) 28,115 555,090 (3,204) 7,477 (90,172) (359,756) 137,550
Profit for the period - - - - - 1,229 1,229
Other comprehensive
income
- exchange differences - - - - (10,841) - (10,841)
-------------------------- ----------- ----------- --------- -------------- ---------- ------------ ---------
Total comprehensive loss - - - - (10,841) 1,229 (9,612)
-------------------------- ----------- ----------- --------- -------------- ---------- ------------ ---------
As at 30 June 2020
(unaudited) 28,115 555,090 (3,204) 7,477 (101,013) (358,527) 127,938
-------------------------- ----------- ----------- --------- -------------- ---------- ------------ ---------
Called Share Merger Capital Foreign Accumulated Total
up share premium reserve contributions exchange losses equity
capital account reserve reserve*
$000 $000 $000 $000 $000 $000 $000
As at 1 January 2019
(audited) 28,115 555,090 (3,204) 7,477 (102,261) (372,120) 113,097
Profit for the period - - - - - 9,887 9,887
Other comprehensive
income
- exchange differences - - - - 4,919 - 4,919
-------------------------- ----------- ----------- --------- -------------- ---------- ------------ ---------
Total comprehensive
income - - - - 4,919 9,887 14,806
-------------------------- ----------- ----------- --------- -------------- ---------- ------------ ---------
As at 30 June 2019
(unaudited) 28,115 555,090 (3,204) 7,477 (97,342) (362,233) 127,903
-------------------------- ----------- ----------- --------- -------------- ---------- ------------ ---------
* Predominantly as result of exchange differences on
retranslation, where the subsidiaries ' functional currency is not
US Dollar
The Notes set out below are an integral part of these unaudited
condensed interim consolidated financial statements.
Condensed Interim Consolidated Statement of Cash Flows
6 months 6 months
ended ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
Note $000 $000
Operating activities
Cash generated from operations 15 11,036 17,596
Charitable donations 6 (2,057) -
Equipment rental income 17 15
Income tax paid (2,856) (2,811)
Interest received 1,066 2,636
-------------------------------------------- ----- ------------ ------------
Net cash inflow from operating activities 7,206 17,436
-------------------------------------------- ----- ------------ ------------
Investing activities
Disposal of subsidiary - (7)
Purchase of property, plant and equipment (8,096) (4,105)
Purchase of intangible assets (4,428) (19)
Proceeds from sale of property, plant
and equipment 1 16
Net cash outflow from investing activities (12,523) (4,115)
-------------------------------------------- ----- ------------ ------------
Financing activities
Principal elements of lease payments (282) (197)
Net cash outflow from financing activities (282) (197)
Net increase in cash and cash equivalents (5,599) 13,124
Cash and cash equivalents at beginning
of the period 14 62,474 53,222
ECL* of cash and cash equivalents (6) (31)
Effect of foreign exchange rate changes (2,641) 1,494
Cash and cash equivalents at end of
the period 14 54,228 67,809
-------------------------------------------- ----- ------------ ------------
* Expected credit losses
The Notes set out below are an integral part of these unaudited
condensed interim consolidated financial statements.
Notes to the U naudited Condensed Interim Consolidated Financial
Statements
1. General Information and Operational Environment
Enwell Energy plc (formerly Regal Petroleum plc) (the "Company")
and its subsidiaries (together the "Group") is a gas, condensate
and LPG production group.
Enwell Energy plc is a company quoted on the AIM Market of the
London Stock Exchange 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.
As at 30 June 2020, the Company's immediate parent company was
Pelidona Services Limited, which is 100% owned by Lovitia
Investments Limited, which is 100% owned by Mr Vadym Novynskyi.
Accordingly, the Company is ultimately controlled by Mr Vadym
Novynskyi.
The Group's gas, condensate and LPG extraction and production
facilities are located in Ukraine. The ongoing political and
economic instability in Ukraine, which commenced in late 2013, has
led to a deterioration of Ukrainian State finances, volatility of
financial markets, illiquidity in capital markets, higher inflation
and a depreciation of the national currency against major foreign
currencies, although there have been some gradual improvements
lately.
In recent years, the Ukrainian economy demonstrated growth amid
overall macroeconomics stabilisation supported by structural
reforms, a rise in domestic investment, revival in household
consumption, increase in industrial production, construction
activity and improved environment on external markets.
Starting from the first quarter of 2020, the Ukrainian economy
has been contracting following a decrease in industrial output and
the COVID-19 outbreak, which started in March 2020. The National
Bank of Ukraine ("NBU") follows an interest rate policy consistent
with inflation targets and keeps the Ukrainian Hryvnia floating.
The annualised inflation rate in Ukraine slowed to 2.0% in the
first half of 2020 (compared with 3.6% in the first half of 2019
and 4.1% over the 2019 year), which allowed the NBU to continue key
policy rate cuts after a lengthy period of rate increases - from
18.0% effective 7 September 2018 to 6.0% effective 12 June 2020,
which is historically the lowest ever rate in Ukraine. At the same
time, the NBU has madke appropriate market interventions in order
to contain abnormal fluctuations of the exchange rate.
As at the date of this report, the official NBU exchange rate of
the Ukrainian Hryvnia against the US Dollar was UAH28.06/$1.00,
compared with UAH26.69/$1.00 as at 30 June 2020 and UAH23.69/$1.00
as at 31 December 2019. In 2019, the NBU cancelled some of the
currency control restrictions, such as the required share of
foreign currency proceeds subject to mandatory sale and the amount
of dividend payments allowed to non-residents, which were
implemented in 2014 - 2015.
In order to manage external debt repayments and secure access to
external financing, Ukraine continues cooperation with
international financial institutions, which are major creditors of
its economy. In June 2020, the Executive Board of the International
Monetary Fund approved a new 18-month Stand-by Arrangement ("SBA")
for Ukraine with the total access of approximately $5 billion. The
approval of the SBA enabled the immediate disbursement of
approximately $2.1 billion, with the remainder being phased over
four reviews. In July 2020, Ukraine and the European Union signed
an agreement granting Ukraine EUR1.2 billion in macro-financial
assistance funds. Ukraine has remained active on international debt
capital markets to manage external debt maturity profile.
Further details of risks relating to Ukraine can be found within
the Principal Risks and Uncertainties section earlier in this
announcement.
As a consequence of the COVID-19 pandemic, the Group is
re-visiting processes and controls intended to ensure protection of
all our stakeholders and minimise any disruption to our business.
The Group is closely monitoring the current volatility in global
financial markets, and the implications on the operational,
economic and social environment within which the Group works caused
by the COVID-19 pandemic, coupled with the recent sharp decline in
hydrocarbon prices. As of the date hereof, there has been no
operational disruption linked to the COVID-19 pandemic, and no
material impact is currently envisaged on the Group's prospects.
However, the Board and management remain acutely aware of the
risks, and continue to take action to mitigate them where possible,
not only protect the Group's staff and stakeholders but to minimise
disruption to the Group's business. The Group has taken steps to
continually monitor the health of its operational staff, including
temperature checks for such staff at the commencement of each
shift, as well as investing in technology to enable many staff to
work from remote locations. The Group continues to reassess the
medium-term forecasts based on current pricing and is confident
that it has the resources to continue to deliver on its plans. Of
course, it is not possible to forecast the duration of the
pandemic's impact but the Group will remain focussed on monitoring
and protecting its business through the period of uncertainty, as
further explained below in the Going Concern section.
The unaudited condensed interim consolidated financial
statements for the six month period ended 30 June 2020 have been
prepared in accordance with International Accounting Standard 34
'Interim Financial Reporting' as adopted by the European Union. The
unaudited condensed interim consolidated financial statements do
not include all the notes of the type normally included in annual
financial statements. Accordingly, this report should be read in
conjunction with the annual consolidated financial statements for
the year ended 31 December 2019, which have been prepared in
accordance with International Financial Reporting Standards
(hereinafter "IFRSs") as adopted by the European Union.
These unaudited condensed interim consolidated financial
statements do not comprise statutory accounts within the meaning of
section 434 of the Companies Act 2006. Statutory accounts for the
year ended 31 December 2019 were approved by the Board of Directors
on 8 April 2020 and subsequently filed with the Registrar of
Companies. The Auditor's Report on those accounts was not qualified
and did not contain any statement under section 498 of the
Companies Act 2006.
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 Officer's
Statement and Finance Review above. The financial position of the
Group, its cash flows and liquidity position are set out in these
unaudited condensed interim consolidated financial statements .
The Directors have performed a robust assessment, including a
review of the budget and forecast for the year ending 31 December
2020 and longer-term strategic forecasts, plans, and models
including consideration of the principal risks faced by the Group
and taking into account the ongoing impact of the global COVID-19
pandemic on the macroeconomic situation and any potential impact to
operations and plans. In particular, the Directors considered a
number of sensitivities on key assumptions which included downside
(reverse stress) sensitivities in relation to production rates, gas
price, fixed operating and administration costs and foreign
exchange rates, which estimated the extent to which the key
assumptions would need to be adversely impacted in order to
eliminate the forecast headroom. Following this review, the
Directors are satisfied that, taking into consideration reasonably
possible downside sensitivities, the Group has adequate resources
to continue to operate and meet its liabilities as they fall due
for the foreseeable future, a period considered to be twelve months
from the date of signing these unaudited condensed interim
consolidated financial statements . The Directors noted that with
cash resources at the end of the period in excess of $54 million,
and annual running costs (both operating, and general and
administrative) of less than $16 million, the Group remains in a
very strong position should any local or global shocks occur to the
industry and/or the Group. For these reasons, the Directors
continue to adopt the Going Concern Basis for preparing the
unaudited condensed interim consolidated financial statements .
2. Accounting Judgements and Estimates
The accounting policies and methods of computation and
presentation used are consistent with those used in the Group's
Annual Report and Financial Statements for the year ended 31
December 2019, with the exception of the following new or revised
standards and interpretations:
New and amended standards adopted by the Group
A number of new or amended standards became applicable for the
current reporting period. The following amendments to standard,
which is relevant to the Group's condensed consolidated interim
financial statement, have been issued:
Definition of a business - Amendments to IFRS 3 (issued on 22
October 2018 and effective for acquisitions from the beginning of
annual reporting period that starts on or after 1 January 2020).The
amendments revise definition of a business. A business must have
inputs and a substantive process that together significantly
contribute to the ability to create outputs. The new guidance
provides a framework to evaluate when an input and a substantive
process are present, including for early stage companies that have
not generated outputs. An organised workforce should be present as
a condition for classification as a business if there are no
outputs. The definition of the term 'outputs' is narrowed to focus
on goods and services provided to customers, generating investment
income and other income, and it excludes returns in the form of
lower costs and other economic benefits. It is also no longer
necessary to assess whether market participants are capable of
replacing missing elements or integrating the acquired activities
and assets. An entity can apply a 'concentration test'. The assets
acquired would not represent a business if substantially all of the
fair value of gross assets acquired is concentrated in a single
asset (or a group of similar assets).
The Group had to changed its accounting policies as a result of
the adoption of amendments to IFRS 3, however this change had no
impact on the reporting period.
Amendments to IFRS 7, IFRS 9 and IAS 39 regarding interest rate
benchmark reform>> and amendments to IAS 1 and IAS 8
regarding definition of material did not have a material impact on
this unaudited condensed consolidated interim financial
statements.
Significant accounting judgements and estimates
The preparation of the unaudited condensed interim consolidated
financial statements requires management to make judgements,
estimates and assumptions that affect the application of accounting
policies and the reported amounts of assets and liabilities, income
and expenses. Actual results may differ from these estimates.
In preparing these unaudited condensed interim consolidated
financial statements, the significant judgements made by management
in applying the Group's accounting policies and the key sources of
estimation uncertainty were consistent with those that applied to
the consolidated financial statements for the year ended 31
December 2019 with certain updates described below.
Significant judgement
Acquisition of LLC Arkona Gas-Energy
The Group gained control over LLC Arkona Gas-Energy ("Arkona")
on 24 March 2020. The transaction is treated as an asset
acquisition as there were no employees and processes acquired,
which could be used to produce outputs. The same treatment is
achieved by applying the concentration test under amended IFRS 3
Business Combinations. The test revealed that the fair value
acquired, being the Svystunivsko-Chervonolutske licence ("SC
Licence"), comprises the vast amount (more than 90%) of the
consideration. The SC Licence is classified as the exploration and
evaluation intangible asset at the acquisition date. Management
believes there are no impairment indicators which exist at the
reporting date due to the following:
- the SC Licence is valid until 18 May 2037;
- further exploration and evaluation plans are included in the
Group's Budgets.
However, NJSC Ukrnafta, as claimant, has issued legal
proceedings against Arkona, as defendant, in which NJSC Ukrnafta
has made claims about the procedure involved in the grant of the SC
Licence to Arkona in May 2017 (see announcements dated 3 July and
31 July 2020). NJSC Ukrnafta was the holder of a previous licence
over this area which expired prior to the grant of the SC Licence.
In early July 2020, the First Instance Court in Ukraine announced a
ruling in favour of NJSC Ukrnafta, which found that the grant of
the SC Licence was irregular, which would mean the SC Licence is
invalid. Arkona disputes these claims and is defending such legal
proceedings, and consequently has filed an appeal in the Appellate
Administrative Court in Kyiv. The Group considers Arkona has strong
grounds for a successful appeal since the subject matter of these
legal proceedings, including the validity of the SC Licence, has
already been ruled upon by the Supreme Court of Ukraine in similar
proceedings in October 2019 involving, inter alia, NJSC Ukrnafta
and Arkona, and in which the SC Licence was held to be valid.
Pending the outcome of the appeal process, the SC Licence remains
valid. The current legal proceedings are not an indicator of
impairment of the SC Licence as the risk is assessed to be remote
as at 30 June 2020.
Under the terms of the sale and purchase agreement (the "SPA")
for Arkona, half of the consideration payable (split into two equal
tranches) was deferred and only payable on satisfaction of certain
conditions including the favourable resolution of these legal
proceedings, as well as certain other conditions, with the further
proviso that if the conditions for payment of these deferred
tranches are not satisfied, then neither of these tranches shall
become payable. In addition, the SPA contains customary warranties
and indemnities allowing the Group to seek recovery of
consideration paid in the event of a breach of such warranties and
indemnities.
The following items comprise Arkona's assets and liabilities at
their fair value at the date of acquisition:
$000
Property, plant and equipment 88
Trade and other receivables 35
Trade and other payables (291)
--------------------------------------------------------- ------
Net assets at the acquisition date (168)
--------------------------------------------------------- ------
Fair value of consideration (1st, 2nd and 3rd tranches) 8,163
--------------------------------------------------------- ------
Fair value of licence at the acquisition date 8,331
Under the SPA, the total consideration payable is $8,630,000,
with payment divided into three tranches. The first tranche of
$4,153,000 was paid on 24 March 2020 upon completion of the
acquisition of 100% of the issued share capital of Arkona.
The second and third tranches of $2,157,500 respectively are
contingent on satisfaction of the certain conditions, including the
favourable resolution of the abovementioned legal proceedings
brought by NJSC Ukrnafta against Arkona relating to the SC Licence
(the "Licence Case"), the absence of any contractual, warranty or
indemnity claims, and the delivery of certain documentation by the
sellers of Arkona, with proviso that if such conditions are not
satisfied, then neither the second tranche nor the third tranche
shall become payable.
The second tranche equals the fair value at the date of
acquisition and the estimated date of the relevant Court's decision
in the Licence Case is assumed to be before 31 December 2020.
The third tranche is payable in twelve months from the date of
payment of the second tranche. At the date of acquisition, the fair
value of the third tranche amounts to the discounted value at the
effective interest rate, being the Company's effective borrowing
rate of 9%. The Group recognised $306,000 of discounting effect
calculated against the value of the acquired assets.
The total consideration comprising the three tranches estimated
at the date of acquisition amounts to $8,163,000. The outstanding
balance as at 30 June 2020, consists of the non-current portion of
the liability of $1,852,000 (see Note 13) and the current portion
of $2,158,000 reflected in trade and other payables. Provided the
date of payment of the second tranche occurs 6 months later than
the abovementioned date (31 December 2020), the additional
discounting effect will amount to $301,000.
The second and third tranches are contingent on the outcome of
the Licence Case and thus constitute a contingent consideration.
Management made an accounting policy choice to use the cost
accumulation approach to account for the contingent consideration
based on the estimated payment amount at the acquisition date.
Subsequent to the acquisition date, the liability is not remeasured
until the change becomes at least highly probable. Any further
remeasurement of the liability would be recognised in the Income
Statement to the extent of unwinding of the discount and would
adjust the carrying value of the acquired asset or the
remeasurement of expected payment amount. The payment would not be
probable if the Licence Case is expected to be lost, in which case
the full amount of the SC Licence is likely to be impaired.
At the acquisition date and as at 30 June 2020, Management
assumes that all three tranches will be payable as there are
sufficient legal grounds for challenging and successfully appealing
the First Instance Court Decision in the Licence Case (see Note
16).
Estimates
Recoverability of Development and Production Assets in
Ukraine
According to the Group's accounting policies, costs capitalised
as assets are assessed for impairment at each balance sheet date if
impairment indicators exist. In assessing whether an impairment
loss has occurred, the carrying value of the asset or
cash-generating unit ("CGU") is compared to its recoverable amount.
The recoverable amount is the greater of fair value less costs to
dispose and value in use and is determined for an individual asset,
unless the asset does not generate cash inflows that are largely
independent of those from other assets or groups of assets. 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 and the respective impairment loss is recognised
as an expense immediately. A previously recognised impairment loss
is reversed only if there has been a change in the estimates used
to determine the asset's recoverable amount since the last
impairment loss was recognised. If that is the case, the carrying
amount of the asset is increased to its recoverable amount, but so
that the increased carrying amount does not exceed the carrying
amount that would have been determined, net of depreciation, had no
impairment loss been recognised for the asset in prior years. Such
reversals are recognised as income immediately.
MEX-GOL, SV and VAS gas and condensate fields
The impairment assessment carried out at 30 June 2020 has not
resulted in an impairment loss. Further details of this assessment,
including the sensitivity to the above assumptions, are set out in
Note 7.
Depreciation of 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 proven 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 assumptions
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. Additionally, the latest development plan and
therefore the inputs used to determine the depreciation charge,
assume that the current licences for the MEX-GOL and SV fields,
which are due to expire in July 2024, can be extended until the end
of the economic life of the fields , which is assessed to be 2038
and 2042 respectively, based on the assessment contained in the
DeGolyer & MacNaughton reserves report for these fields.
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 at 30 June 2020 was 4.67% (31
December 2019: 3.68%). 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.
The change in estimate applied to calculate the provision as at
30 June 2020 resulted from the revision of the estimated costs of
decommissioning (increase of $75,000 in provision) and the increase
in the discount rate applied (decrease of $978,000 in provision).
The increase in discount rate at 30 June 2020 resulted from the
increase in Ukrainian Eurobonds yield and the respective increase
of country risk premium. 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. If the costs on the MEX-GOL and SV fields
were to be incurred at the current expiry of the production
licences in 2024, the provision for decommissioning at 30 June 2020
would be $10,128,000 (31 December 2019: $11,564,000).
Recognition of Deferred Tax Asset
The recognition of deferred tax assets is based upon whether it
is more likely than not that sufficient and suitable taxable
profits will be available in the future against which the reversal
of temporary differences can be deducted. This requires judgement
for forecasting future profits. Further details of the deferred tax
assets recognised can be found in Note 7.
3. 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, budgets 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 and amortisation.
6 months ended 30 June 2020 (unaudited)
United
Ukraine Kingdom Total
$000 $000 $000
Revenue
Gas sales 17,974 - 17,974
Condensate sales 5,232 - 5,232
Liquefied Petroleum Gas sales 1,502 - 1,502
------------------------------- -------- --------- --------
Total revenue 24,708 - 24,708
Segment result 11,109 827 11,936
Depreciation and amortisation (6,783) - (6,783)
Operating profit 5,153
------------------------------- -------- --------- --------
Segment assets 106,494 38,037 144,531
Capital additions* 17,102 - 17,102
6 months ended 30 June 2019 (unaudited)
United
Ukraine Kingdom Total
$000 $000 $000
Revenue
Gas sales 23,347 - 23,347
Condensate sales 6,127 - 6,127
Liquefied Petroleum Gas sales 1,799 - 1,799
------------------------------- -------- --------- --------
Total revenue 31,273 - 31,273
Segment result 19,723 (1,107) 18,616
Depreciation and amortisation (4,928) - (4,928)
------------------------------- -------- --------- --------
Operating profit 13,688
------------------------------- -------- --------- --------
Segment assets 114,564 24,203 138,767
Capital additions* 6,722 - 6,722
*Comprises additions to property, plant and equipment and
intangible assets (Notes 7 and 8).
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.
4. Cost of Sales
6 months 6 months
ended ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
Production taxes 4,875 6,660
Depreciation of property, plant and equipment 6,176 4,297
Rent expenses 2,121 3,256
Staff costs 1,837 1,161
Cost of inventories recognised as an expense 624 688
Transmission tariff for Ukrainian gas system 421 336
Amortisation of mineral reserves 253 244
Other expenses 896 705
17,203 17,347
5. Other operating income/(expenses), (net)
6 months 6 months
ended ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
Interest income on cash and cash equivalents 1,023 2,792
Reversal of accruals 263 48
Contractor penalties applied 15 15
Other operating income/(losses), net 199 (236)
1,500 2,619
6. Other income/(expenses), (net)
6 months ended 6 months
30 Jun 20 ended
30 Jun 19
(unaudited) (unaudited)
$000 $000
Charitable donations (2,057) (51)
Net foreign exchange gains/(losses) 194 (443)
Other income/(expenses), (net) (62) (131)
(1,925) (625)
Charitable donations for the 6 month period ended 30 June 2020
comprise the supply of medical equipment and COVID-19 tests to
Ukrainian authorities and charitable foundations. Charitable
donations are disclosed in line with the accounting policy of the
Group as other expenses.
7. Taxation
The income tax charge of $1,366,000 for the six month period
ended 30 June 2020 relates to a urrent tax charge of $1,356,000 and
a deferred tax charge of $10,000 (1H 2019: current tax charge of
$1,684,000 and deferred tax charge of $1,684,000).
The movement in the period was as follows:
6 months ended 6 months
ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
Deferred tax asset recognised on tax losses
At beginning of the period - 2,134
Charged to Income Statement - current
year - (2,134)
At end of the period - -
--------------------------------------------- --------------- ------------
Deferred tax (liability)/asset recognised
relating to development and production
assets at MEX-GOL-SV fields and provision
for decommissioning
At beginning of the period (2,141) 1,149
(Charged)/credited to Income Statement
- current period (170) 209
Effect of exchange difference 115 6
--------------------------------------------
At end of the period (2,196) 1,364
-------------------------------------------- -------- ------
Deferred tax asset/( liability ) recognised
relating to development and production
assets at VAS field and provision for
decommissioning
At beginning of the period (147) (504)
Credited to Income Statement - current
period 160 241
Effect of exchange difference 12 (21)
---------------------------------------------
At end of the period 25 (284)
--------------------------------------------- ------ ------
Taxes on income in the interim periods are accrued using the tax
rate that would be applicable to the expected total annual profit
or loss.
The deferred tax asset relating to the Group's provision for
decommissioning at 30 June 2020 of $190,000 (31 December 2019:
$326,000) 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 at 30 June 2020 of $2,386,000 (31 December
2019: $2,467,000) 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 asset relating to the Group's provision for
decommissioning at 30 June 2020 of $280,000 (31 December 2019:
$329,000) 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 liability relating to the
Group's development and production assets at the VAS field at 30
June 2020 of $255,000 (31 December 2019: $476,000) 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.
UK Corporation tax change
In the Spring Budget 2020, the UK Government announced that from
1 April 2020 the corporation tax rate would remain at 19% (rather
than reducing to 17% as previously enacted) and the effect of these
change is included in these unaudited condensed interim
consolidated financial statements.
Double tax treaty
On 30 October 2019, the Parliament of Ukraine ratified a new
Protocol amending the Double Tax Treaties between Ukraine and the
United Kingdom. This Protocol increased withholding tax rates from
0% to 5% with effect from 1 January 2020. The Group accounts for
and pays withholding tax on current amounts of interests at the
moment the interest is paid.
8. Earnings per Share
The calculation of basic and diluted earnings per ordinary share
has been based on the profit for the six month period ended 30 June
2020 and 30 June 2019 and 320,637,836 ordinary shares, being the
average number of shares in issue for the period. There are no
dilutive instruments.
9. Property, Plant and Equipment
6 months ended 30 Jun 20 6 months ended 30 Jun 19
(unaudited) (unaudited)
----------------------------------------------- ------------------------------------------------
Oil and Oil and Other Total Oil and Oil and Other Total
gas gas fixed gas gas fixed
development exploration assets development exploration assets
and and and and
production evaluation production evaluation
assets assets assets assets
Ukraine Ukraine
$000 $000 $000 $000 $000 $000 $000 $000
Cost
At beginning of
the
period 143,127 2,571 2,103 147,801 104,809 1,259 1,293 107,361
Additions 8,199 172 386 8,757 5,791 796 68 6,655
Change in
decommissioning
provision (903) - - (903) 1,058 - - 1,058
Disposals (117) - - (117) (51) - - (51)
Exchange
differences (16, 216) (279) (377) (16,872) 6,292 117 45 6,454
----------------- ------------ ------------ -------- --------- ------------- ------------- -------- --------
At end of the
period 134,090 2,464 2,112 138, 666 117,899 2,172 1,406 121,477
Accumulated
depreciation
and impairment
At beginning of
the
period 76,802 - 947 77,749 56,567 - 602 57,169
Charge for the
period 5,268 - 201 5,469 4,388 - 103 4,491
Disposals (31) - (2) (33) (17) - (4) (21)
Exchange
differences (8,590) - (183) (8,773) 3,409 - 39 3,448
----------------- ------------ ------------ -------- --------- ------------- ------------- -------- --------
At end of the
period 73,449 - 963 74,412 64,347 - 740 65,087
----------------- ------------ ------------ -------- --------- ------------- ------------- -------- --------
Net book value
at
the beginning
of
the period 66,325 2,571 1,156 70,052 48,242 1,259 691 50,192
----------------- ------------ ------------ -------- --------- ------------- ------------- -------- --------
Net book value
at
end of the
period 60,641 2,464 1,149 64, 254 53,552 2,172 666 56,390
----------------- ------------ ------------ -------- --------- ------------- ------------- -------- --------
In accordance with the Group's accounting policies, oil and gas
development and production assets are tested for impairment at each
balance sheet date. The Group determines the recoverable amount of
its oil and gas development and production assets based on a Fair
Value Less Costs of Disposal ("FVLCD") approach using a discounted
cash flow methodology, where the cash flows are derived based on
estimates that a typical market participant would use in valuing
such assets.
The impairment assessment carried out at 30 June 2020 has not
resulted in an impairment loss.
The key assumptions on which the Group has based its
determination of FVLCD for its oil and gas development and
production assets and to which these CGU's recoverable amounts are
most sensitive are described below:
(i) Commodity prices - the model assumes gas prices of $129/Mm(3)
(UAH3.443/Mm(3) ) in 2020 increasing to $279/Mm(3) (UAH7,448/Mm(3)
) during 2021 - 2042 for the MEX-GOL and SV gas and condensate
fields and to $259/Mm(3) (UAH6,909Mm(3) ) during 2021 - 2028
for the VAS gas and condensate field. The prices were estimated
based on the price of recent Group transactions, Central European
hub futures and the forecast of natural gas price dynamics
for Europe published by the World Bank.
(ii) Discount rate - reflects the current market assessment of
the time value of money and risks specific to the assets.
The discount rate has been determined as the post-tax weighted
average cost of capital based on observable inputs and inputs
from third party financial analysts. For 2020 and onwards,
the discount rate applied is 11.7% (11.3% during previous
measurement of the recoverable amount as at 31 December 2019).
The discount rate and future cash flows are determined in
real terms, i.e. they do not take into account the impact
of the estimated commodity price index during the period of
projection.
(iii) Production levels and Reserves, MEX-GOL and SV fields - production
levels at the MEX-GOL and SV fields are derived from the estimate
of remaining proven plus probable reserves of 50.0 MMboe assessed
in the report prepared by DeGolyer & MacNaughton as at 31
December 2017. This report includes estimated production volumes,
including from new wells, over the remaining economic life
of the MEX-GOL and SV fields. The estimated production is
based on the Group's revised field development plan, which
includes the drilling of 24 new wells. Estimating oil and
gas reserves is a complex process requiring the knowledge
and experience of reservoir engineers. The quality of the
estimate of proved plus probable reserves depends on the availability,
completeness, and accuracy of data needed to develop the estimate,
including production history available, and on the experience
and judgement of the reservoir engineer. Estimates of proved
plus probable reserves inevitably change over time as additional
data become available and are taken into account. The magnitude
of changes in these estimates can be substantial.
(iv) Production levels and Reserves, VAS field - production levels
at the VAS field are derived from the estimate of remaining
proven plus probable reserves of 3.1 MMboe assessed in the
report prepared by DeGolyer & MacNaughton as at 31 December
2018. The estimated production is based on the Group's revised
field development plan, which includes the drilling of three
new wells. The quality of the estimate of proved plus probable
reserves depends on the availability, completeness, and accuracy
of data needed to develop the estimate, including production
history available, and on the experience and judgement of
the reservoir engineer. Estimates of proved plus probable
reserves inevitably change over time as additional data become
available and are taken into account. The magnitude of changes
in these estimates can be substantial.
(v) Production taxes - for existing wells, the Group assumed
production tax rates of 29% for gas and 45% for condensate
extracted from deposits up to depths of 5,000 metres and 14%
for gas and 21% for condensate extracted from deposits deeper
than 5,000 metres. From 1 January 2019, production tax rates
for condensate produced from all wells was 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. For new wells drilled after
1 January 2018, production tax rates were reduced to 12% for
gas produced from deposits at depths shallower than 5,000
metres and to 6% for gas produced from deposits deeper than
5,000 metres, effective for the period 2018 - 2022.
(vi) Capital expenditures, MEX-GOL and SV gas and condensate fields
- management assumed that most capital expenditures are to
be incurred during 2020 - 2026. A capital expenditure allowance
of $746,000 per year is assumed for maintenance of the development
and producing assets of the MEX-GOL and SV gas and condensate
fields.
(vii) Capital expenditures, VAS gas and condensate fields - management
assumed that most capital expenditures are to be incurred
during 2020-2023. A capital expenditure allowance of $290,000
per year is assumed for maintenance of the development and
producing assets of the VAS gas and condensate field.
(viii) Life of field, MEX-GOL and SV fields - the current licences,
which are due to expire in 2024, can be extended under applicable
legislation in Ukraine until the end of the economic life
of the field, which is assessed to be 2038 for the MEX-GOL
field and 2042 for the SV field, based on the assessment contained
in the DeGolyer & MacNaughton reserves report. No application
for such an extension has been made at the date of this report,
but the Group considers the assumption to be reasonable based
on its intention to seek such extensions in due course and
that the Group is legally entitled to request such extensions.
However, if the extensions were not granted, it would result
in a further reduction of $291,430,000 in the recoverable
amount.
(ix) Life of field, VAS field - according to the DeGolyer & MacNaughton
reserves report, the economic life of the VAS field is limited
to 2028. However, after additional drilling on the VED area
of the licence, management plans to undertake a further reserves
assessment.
The Group's discounted cash flow model for the VAS field in US
Dollars, flexed for sensitivities, produced the following
results:
Recoverable Net book Headroom
amount value* / (Shortfall)
$000 $000 $000
------------------------------------------ ------------ --------- ---------------
30 June 2020 14,200 11,400 2,800
Sensitivities:
10% reduction in gas price 11,350 11,400 (50)
10% increase in gas price 17,100 11,400 5,700
Breakeven gas price $117/Mm(3) 11,550 11,400 150
Breakeven flow rates 71 thsm(3)/day
for all wells 11,620 11,400 220
Breakeven discount rate 15,8% 11,420 11,400 20
*Net book value of the VAS asset is derived from property, plant
and equipment, mineral reserve rights and other intangible assets
(Note 8).
The Group's discounted cash flow model for the MEX-GOL and SV
fields in Ukrainian Hryvnia is not sensitive.
10. Intangible Assets
6 months ended 30 Jun 20 6 months ended 30
Jun 19
(unaudited) (unaudited)
Exploration
Mineral and evaluation Other Mineral Other
reserve intangible intangible reserve intangible
rights assets assets Total rights assets Total
$000 $000 $000 $000 $000 $000 $000
Cost
At beginning of the period 7,843 - 572 8,415 6,709 330 7,039
Additions - 8,331 101 8,432 - 67 67
Disposals - - (53) (53)
Exchange differences (884) 16 (52) (920) 390 21 411
----------------------------- --------- ---------------- ------------ ------- --------- ------------ --------
At end of the period 6,959 8,347 568 15,874 7,099 418 7,517
----------------------------- --------- ---------------- ------------ ------- --------- ------------ --------
Accumulated amortisation
and impairment
At beginning of the period 2,851 - 367 3,218 1,965 194 2,159
Amortisation charge for
the period 253 - 78 331 244 57 301
Disposals - (53) (53)
Exchange differences (274) - (28) (302) 121 6 127
----------------------------- --------- ---------------- ------------ ------- --------- ------------ --------
At end of the period 2,830 - 364 3,194 2,330 257 2,587
----------------------------- --------- ---------------- ------------ ------- --------- ------------ --------
Net book value at beginning
of the period 4,992 - 205 5,197 4,744 136 4,880
----------------------------- --------- ---------------- ------------ ------- --------- ------------ --------
Net book value at end
of the period 4,129 8,347 204 12,680 4,769 161 4,930
----------------------------- --------- ---------------- ------------ ------- --------- ------------ --------
Intangible assets consist mainly of the hydrocarbon production
licence relating to the VAS gas and condensate field which is held
by one of the Group's subsidiaries LLC Prom-Enerho Produkt and a
new hydrocarbon production licence relating to the
Svystunivsko-Chervonolutske ("SC") gas and condensate field which
is held by LLC Arkona Gas-Energy. The Group amortises the
hydrocarbon production licence relating to the VAS gas and
condensate field using the straight-line method over the term of
the economic life of the VAS field until 2028. The hydrocarbon
production licence relating to the SC gas and condensate field is
not amortised due to 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. Pursuant to the results of the impairment
tests performed, there is no impairment of the Group's intangible
assets as at 30 June 2020 (Note 9).
11. Trade and Other Receivables
30 Jun 20 31 Dec 19
(unaudited) (audited)
$000 $000
Trade receivables 1,631 2,881
Other financial receivables 1,816 1,718
Less credit loss allowance (150) (155)
----------------------------------- ------------- -----------
Total financial receivables 3,297 4,444
Prepayments and accrued income 5,330 5,959
VAT receivable 1 , 156 96
Other receivables 416 438
Total trade and other receivables 10,199 10,937
Due to the short-term nature of the current trade and other
financial 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.
The majority of the trade receivables are from a related party,
LLC Smart Energy, that purchases all of the Group's gas production.
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 period.
Prepayments and accrued income mainly consist of prepayment of
$4,249,000 relating to the development of the SV field (31 December
2019: $3,987,000 relating to the development of the SV field and
$1,094,000 relating to development of the VAS field).
The deposit of $500,000 paid under the Memorandum of
Understanding dated 21 November 2019 for the acquisition of the
entire share capital of PJSC Science and Production Concern
Ukrnaftinvest remains a receivable as at the date of this
announcement, as do the funds of UAH47.3 million (approximately
$1.8 million) advanced to PJSC Science and Production Concern
Ukrnaftinvest by the Group.
12. Provision for Decommissioning
6 months ended 6 months ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
At beginning of the period 7,447 3,137
Amounts provided - 141
Unwinding of discount 94 128
Change in estimate (903) 917
Effect of exchange difference (789) 219
------------------------------- --------------- ---------------
At end of the period 5,849 4,542
The provision for decommissioning is based on the net present
value of the Group's estimated liability for the removal of the
Ukraine production facilities and well site restoration at the end
of production life.
The non-current provision of $5,849,000 (31 December 2019:
$7,447,000) represents a provision for the decommissioning of the
Group's MEX-GOL, SV and VAS production facilities, including site
restoration. None of the provision was utilised during the
reporting period.
As described in Note 2, the change in estimates applied to
calculate the provision as at 30 June 2020 resulted from the
revision of the estimated costs of decommissioning (increase of
$75,000 in provision) and the increase in the discount rate applied
(decrease of $978,000 in provision).
13. Other non-current liabilities
Other non-current liabilities as at 30 June 2020, consist of the
long-term portion of the deferred consideration for the acquisition
of LLC Arkona Gas-Energy of $1,851,861 (Note 2) and the long-term
obligations for the State special purpose fund of $142,000 measured
at amortised cost using an interest rate of 20%.
14. Financial Instruments
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 borrowings. The main future
risks arising from the Group's financial instruments are currency
risk, interest rate risk, liquidity risk and credit risk.
The Group's financial assets and financial liabilities, measured
at amortised cost, which approximates their fair value, comprise
the following:
30 Jun 20 31 Dec 19
(unaudited) (audited)
$000 $000
Financial assets
Cash and cash equivalents 54,228 62,474
Trade and other receivables 3,297 4,444
Prepayment for shares 500 500
---------------
58,025 67,418
Financial Liabilities
Lease liabilities 764 969
Trade payables 175 277
Accruals 4, 748 1,018
---------------
5 ,687 2,264
All assets and liabilities of the Group where fair value is
disclosed are of level 2 value hierarchy and valued using current
cost accounting techniques.
At 30 June 2020, the Group held cash and cash equivalents in the
following currencies:
30 Jun 20 (unaudited) 31 Dec 19
(audited)
$000 $000
US Dollars 39,316 44,306
Ukrainian Hryvnia 14,686 17,881
British Pounds 222 257
Euros 4 30
54,228 62,474
------------------- ---------------------- ------------
All of the cash and cash equivalents held in Ukrainian Hryvnia
are held in banks within Ukraine, and all other cash and cash
equivalents are held in banks within Europe, Ukraine and the United
Kingdom.
15. Reconciliation of Operating Profit to Operating Cash
Flow
6 months ended 6 months ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
Operating profit 5,153 13,688
Depreciation and amortisation 6,783 4,928
Less interest income recorded within
operating profit (1,023) (2,792)
Provision for VAT repayment - 405
Fines and penalties received (1) (15)
Loss from credit loss allowance - 41
Loss from write off of non-current assets 81 -
Reversal of loss allowance on other
financial assets - (11)
Gain on sales of current assets, net (5) (18)
Decrease in provisions (169) (9)
Decrease/(increase) in inventory 2,106 (742)
Decrease/(increase) in receivables (1,032) 3,251
(Decrease)/increase in payables (857) (1,130)
------------------------------------------- --------------- ---------------
Cash generated from operations 11,036 17,596
------------------------------------------- --------------- ---------------
16. Contingencies and Commitments
Amounts related to works contracted but not yet undertaken in
relation to the Group's 2019 investment programme at the MEX-GOL,
SV and VAS gas and condensate fields in Ukraine, but not recorded
in the unaudited condensed interim consolidated financial
statements at 30 June 2020, were $5,207,000 (31 December 2019:
$2,306,000).
During 2010 - 2020, 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 UAH8,487,000
($324,000) 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 ourts 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, the
Group received positive decisions in the first and second instance
courts, but further legal proceedings may arise. Since the Group
had been successful in previous court cases in respect of this
dispute in ourts of different levels, the date of the next legal
proceedings has not been set and as the Group believes that
adequate defences exist to the claim, no liability has been
recognised in these unaudited condensed interim consolidated
financial statements for the six months ended 30 June 2020 (31
December 2019: nil).
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.
There are current legal proceedings between NJSC Ukrnafta as
claimant and Arkona as defendant, relating to claims made by NJSC
Ukrnafta about the procedure involved in the grant of the SC
Licence to Arkona in May 2017. NJSC Ukrnafta was the holder of a
previous licence over this area which expired prior to the grant of
the SC Licence. Arkona is defending the claims in such legal
proceedings and asserts that the claims are unwarranted and without
merit. In early July 2020, the First Instance Court in Ukraine made
a ruling in favour of NJSC Ukrnafta that the grant of the SC
Licence was irregular, which would mean the SC Licence is invalid.
The Company and Arkona have carefully reviewed this decision and
written judgement with their legal advisers in Ukraine, and
consider there are strong grounds for a successful appeal. This
view is supported by the fact that the subject matter of these
legal proceedings, including the validity of the SC Licence, has
already been ruled upon by the Supreme Court of Ukraine in similar
proceedings in October 2019 involving, inter alia, NJSC Ukrnafta
and Arkona, and in which the SC Licence was held to be valid.
Accordingly, an appeal has been filed by Arkona in the Appellate
Administrative Court in Kyiv. Pending the outcome of the appeal
process, the SC Licence remains valid. Under the terms of the
acquisition agreement for Arkona, half of the consideration payable
(split into two equal tranches) was deferred and only payable on
satisfaction of certain conditions including the favourable
resolution of these legal proceedings, as well as certain other
conditions, with the further provision that if the conditions for
payment of these deferred tranches are not satisfied, then neither
of these tranches shall become payable and the full amount of the
SC Licence is likely to be impaired.
17. Related Party Disclosures
Key management personnel of the Group are considered to comprise
only the Directors. Remuneration of the Directors for the six month
period ended 30 June 2020 was $532,000 (six month period ended 30
June 2019: $369,000, and year ended 31 December 2019:
$977,000).
During the period, Group companies entered into the following
transactions with related parties which are not members of the
Group:
6 months ended 6 months ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
Sale of goods/services 17,752 23,185
Purchase of goods/services 461 502
Amounts owed by related parties 1,490 1,683
Amounts owed to related parties 347 670
All related party transactions were with subsidiaries of the
ultimate Parent Company, and primarily relate to the sale of gas to
LLC Smart Energy, the rental of office facilities and vehicles and
the sale of equipment. The amounts outstanding were unsecured and
have been or will be settled in cash.
As of 30 June 2020, the Company's immediate parent company was
Pelidona Services Limited, which is 100% owned by Lovitia
Investments Limited, which is 100% owned by Mr Vadym Novynskyi.
Accordingly, the Company was ultimately controlled by Mr Vadym
Novynskyi.
The Group operates bank accounts in Ukraine with a related party
bank, Unex Bank, which is ultimately controlled by Mr Vadym
Novynskyi. There were the following transactions and balances with
Unex Bank during the period:
6 months ended 6 months ended
30 Jun 20 30 Jun 19
(unaudited) (unaudited)
$000 $000
Bank charges 1 1
Closing cash balance 13 -
At the date of this announcement, none of the Company's
controlling parties prepares consolidated financial statements
available for public use.
18. Events occurring after the Reporting Period
In early July 2020, the First Instance Court in Ukraine made a
ruling in favour of NJSC Ukrnafta that the grant of the SC Licence
held by Arkona was irregular, which would mean the SC Licence is
invalid. The Company and Arkona have carefully reviewed this
decision with their legal advisers in Ukraine, and consider there
are strong grounds for a successful appeal. This view is supported
by the fact that the subject matter of these legal proceedings,
including the validity of the Licence, has already been ruled upon
by the Supreme Court of Ukraine in similar proceedings in October
2019 involving, inter alia, NJSC Ukrnafta and Arkona, and in which
the SC Licence was held to be valid. Accordingly, an appeal has
been filed by Arkona in the Appellate Administrative Court in Kyiv.
Pending the outcome of the appeal process, the SC Licence remains
valid.
Negotiations are continuing between the Group and the
shareholders of PJSC Science and Production Concern Ukrnaftinvest
in relation to the acquisition of the entire share capital of PJSC
Science and Production Concern Ukrnaftinvest, and the Group
believes revised terms will be mutually agreed for the Group to
acquire PJSC Science and Production Concern Ukrnaftinvest, albeit
there can be no certainty.
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END
IR ZZGMLLVZGGZM
(END) Dow Jones Newswires
September 17, 2020 02:00 ET (06:00 GMT)
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