REG - Kistos PLC - Final results for the period to 31/12/21
07/04/2022 07:00
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RNS Number : 5573H Kistos PLC 07 April 2022
7 April 2022
Kistos plc
("Kistos", the "Company" or the "Group")
Final results for the period from incorporation to 31 December 2021
Kistos (LSE: KIST), the low carbon intensity gas producer pursuing a strategy
to acquire assets with a role in energy transition, is pleased to provide its
audited results for the period to 31 December 2021. A copy of the Company's
annual report and accounts will be made available shortly on the Company's
website at www.kistosplc.com.
The numbers referred to as "actual" in this announcement include the results
of Kistos plc from incorporation on 14(th) October 2020 to 31 December 2021
and the results of Kistos NL1 and Kistos NL2 from acquisition on 20 May 2021
to 31 December 2021. The "pro forma" numbers include the results of Kistos plc
and the results of Kistos NL1 and Kistos NL2 from 1 January 2021, which was
the effective date of the acquisition and so the date from which Kistos
economically benefitted from the assets to 31 December 2021.
Highlights
Strategic & operational
§ Completed the acquisition of Tulip Oil Netherlands B.V. and Tulip Oil
Netherlands Offshore B.V. (subsequently renamed Kistos NL1 B.V. and Kistos NL2
B.V. respectively) in May 2021.
§ Year-end 2P reserves of 18.1 MMboe in the Q10-A gas field (Kistos 60% and
operator).
§ Q10-A gas field produced at an average gross rate of 1.31 MM Nm(3) per day
on a pro forma basis in the year to 31 December 2021.
§ Average gross production since completion of the Tulip acquisition of 1.17
MM Nm(3) per day.
§ Successful drilling campaign commenced in July 2021 and completed in
February 2022:
o Appraisal of the Orion oil field tested 3,200 b/d. Development studies are
underway.
o Appraisal of the Q11-B discovery successfully flowed at a combined rate of
over 0.27 MM Nm(3) per day from the Bunter and Zechstein reservoirs.
Development studies are underway.
o Sidetrack of the A-04 well at Q10-B increased production by >0.8 MM
Nm(3) per day.
§ The wind turbines on the renewably powered Q10-A platform were upgraded in
2021 to help minimise CO(2).emissions.
§ In January 2022, Kistos announced that it had reached agreement with
TotalEnergies to acquire a 20% interest in the Greater Laggan Area (GLA) West
of Shetland. This transaction is expected to complete in the second quarter of
2022, subject to customary regulatory and partner consents.
§ On a pro forma basis, this transaction is expected to add 6.2 MMboe of 2P
reserves and 2.5 MMboe of 2C resources plus net production in 2022 of
approximately 6,000 boe/d. This will increase Group production in 2022 to
approximately 12,000 boe/d (net).
Financial
§ Pro forma adjusted EBITDA of €102.9MM in the 12 months to 31 December
2021
§ Loss after tax of €40.1MM reflects total impairments of €121.0MM.
§ Impairments of €121.0MM include €119.8MM related to the result of the
Q11-B appraisal well, which did not encounter gas in the Slochteren formation.
§ Issued €150MM of Nordic Bonds (€60M of new bonds and €90M of
refinancing) in conjunction with the €223MM Tulip Oil acquisition.
§ Raised over €100MM from equity investors between incorporation (October
2020) and the end of 2021.
§ Capital expenditure in 2021 was €23.8MM on an accruals basis, 95% of
which occurred in the second half of the year when the drilling campaign was
underway.
§ Cash balances on 31 December 2021 were €77.3MM (30 June 2021, €59.1MM).
§ The Group is unhedged as of 1 April 2022.
§ Given its financial strength and in line with its strategy, the Group
continues to evaluate several business development opportunities in the energy
transition space.
Audited results for the period ending 31 December 2021
31 December 2021 (actual) 31 December 2021
(pro forma)(4)
Production million nm(3) 157 288
Production '000 MWh 1,892 3,460
Revenue €'000 89,628 116,731
Unit Opex(1) €/MWh 3.25 2.83
Adjusted EBITDA(2) €'000 78,861 102,862
(Loss)/profit before tax €'000 (73,857) (65,940)
Average realised gas price(3) €/MWh 47.31 33.58
Total cash €'000 77,288 77,288
Note: The financial results are prepared in accordance with IFRS, unless
otherwise noted below:
1. Non-IFRS measures. Refer to the alternative performance measures
definition within the glossary.
2. Adjusted EBITDA is calculated on a business performance basis.
Refer to the alternative performance measures definition within the glossary.
3. Includes the impact of effective realised gain on cash flow
hedges.
4. Pro forma information in respect of the enlarged Group is based
on Kistos NL1, Kistos NL2, and Kistos PLC from 1 January 2021 to 31 December
2021.
Chairman's comment
After listing on AIM in the final quarter of 2020, the first half of 2021 saw
Kistos commence the execution of its strategy to acquire assets with a role to
play in the energy transition. We did so by purchasing Tulip Oil Netherlands
(renamed Kistos NL1) and its subsidiary, Tulip Oil Netherlands Offshore
(renamed Kistos NL2), from Tulip Oil Holding B.V. (the "Acquisition"). This
transaction brought with it 60% interests in and operatorship of the producing
Q10-A gas field as well as the Orion oil discovery and the Q11-B gas discovery
exploration and evaluation assets in the Dutch sector of the North Sea.
In the six months to the end of June 2021, production from Q10-A averaged 1.43
MM Nm(3) per day. Two months after the completion of the acquisition, Kistos
announced the commencement of a six-month drilling campaign, which resulted in
Q10-A exiting the year with output significantly higher at 1.8 MM Nm(3) per
day. In addition, an appraisal of the Orion oil discovery tested at a rate of
3,200 b/d and an appraisal of the Q11-B gas discovery flowed gas from the
Bunter and Zechstein formations, although it failed to encounter gas in the
primary Slochteren target, leading to an impairment of €119.8MM. Studies are
now underway to establish the optimum way of developing both fields.
As detailed in the independent Competent Persons Report (CPR) published in
conjunction with the Acquisition, the 2P reserves associated with the acquired
assets were 20.0 MMboe as of 31 December 2020. After taking account of
production from Q10-A during the course of last year, the figure was 18.1
MMboe on 31 December 2021. Kistos expects this to increase as we progress
towards a Final Investment Decision (FID) with the Orion and Q11-B projects,
enabling us to convert 2C resources to 2P reserves.
Crucially, Kistos achieved this increase in reserves and production while
abiding by its founding principle of being part of the energy transition.
Natural gas will be critical to Europe's transition to a low carbon economy,
which is demonstrated by the European Commission's decision to categorise
investments in natural gas production as 'transitional economic activities'.
Our Q10-A platform has an extremely low carbon footprint thanks to the
integration of wind turbines and solar panels into its design. We will take a
similar approach to any future development projects.
Reported adjusted EBITDA for 2021 was €78.9MM (see Financial Review) while
adjusted pro forma EBITDA, which includes a full 12 months contribution from
Kistos NL1 and Kistos NL2, was €102.9MM. This was weighted towards the
second half of the year, when gas prices were significantly higher and
production responded to our drilling and workover campaign. Hence, we ended
the year with cash balances of €77.3MM, which was achieved after capital
expenditure of €20.0MM on a cash basis. With high gas prices carrying over
into 2022 and production from the Q10-A gas field significantly higher than
when we acquired it, the current year has started strongly.
Central to our operations is our health, safety, and environmental (HSE)
performance. I am pleased to report that we did not suffer any Lost Time
Injuries in 2021 despite undertaking more than five months of drilling and
testing operations. Neither did we suffer any disruption to our operations
from COVID-19 thanks to the rigorous procedures we have in place to combat
and, if necessary, contain the virus. Meanwhile, the wind turbines, which were
upgraded in 2021, and the solar panels on the Q10-A platform continue to
minimise our CO2 emissions.
We expect to drive further operational progress across our portfolio in 2022.
Currently, our plans to construct a new gas export pipeline from Q10-A to
IJmuiden, are on hold while we review alternatives that have been proposed by
other stakeholders, thus ensuring that we pursue the option that adds most
value for shareholders. Similarly, with the help of Rockflow Resources, our
technical team in the Netherlands is taking a rigorous approach to the Concept
Assess and Concept Select phases of the Q-10 Orion oil field development
project.
In January 2022, we announced that we had reached agreement with TotalEnergies
to acquire a 20% interest in the Greater Laggan Area ('GLA') offshore the UK.
Once this transaction completes, which we expect to occur during the second
quarter of 2022, Kistos' output is expected to increase by approximately 6,000
boe/d. Importantly, with an effective economic date of 1 January 2022, the
Company secured exposure to the high commodity prices that have prevailed
since the beginning of the year has been for our account and will be reflected
in the amount payable to the vendor at completion.
Although we do not set explicit long-term targets for reserves or production,
believing instead that shareholder value is a more important metric, we remain
committed to growing the business. From a standing start in the fourth quarter
of 2020, we have built an excellent platform from which to do so, and we will
seek to deploy further capital for the right opportunities. With that in mind,
we continue to evaluate potential acquisitions. However, it is critical that
we maintain capital discipline and we must be prepared to walk away from
transactions if we do not believe they will be accretive to shareholder value.
The Remuneration Committee seeks to ensure that all employees are
appropriately incentivised to deliver results for the Company. The Company
announced on 15 and 16 February 2022 an intention to establish a Value
Creation Plan ("VCP") to maintain alignment of the Company's executive
directors with shareholders, to achieve exceptional levels of performance, and
to deliver further returns. Since these announcements, the Board confirms that
it has commenced a consultation process with its major shareholders. No
decision has yet been made as to the terms, structure, or timing of
implementing any incentive plan and a further announcement will be made at the
appropriate time.
Finally, I would like to thank all our stakeholders for their work and
commitment to the Company and to thank staff, contractors, co-venturers and
others for their continued support. I believe we are well- placed to continue
generating substantial returns for investors and look forward to reporting
further progress during 2022.
Andrew Austin, Executive Chairman
Enquiries:
Kistos plc
Andrew Austin c/o Camarco Tel: 0203 757 4983
Panmure Gordon
John Prior / James Sinclair-Ford / Hugh Rich Tel: 0207 886 2500
Berenberg Tel: 0203 207 7800
Emily Morris / Jack Botros
Camarco
Billy Clegg / James Crothers Tel: 0203 757 4983
Notes to editors
Kistos plc was established to acquire and manage companies in the energy
sector engaging in the energy transition trend. The Company has acquired Tulip
Oil Netherlands B.V., which has a portfolio of assets, including profitable,
highly cash generative natural gas production, plus appraisal and exploration
opportunities. The Company has 18.1 MMboe of 2P reserves and an additional
99.1 MMboe of contingent resources.
Kistos is a low carbon intensity gas producer. The Q10-A gas field in the
Dutch North Sea (60% operated working interest) has recorded a Scope 1 carbon
emissions intensity of 13g CO(2)e/boe since inception. This compares to an
industry average of 22kg CO(2)/boe for gas extracted from the UK continental
shelf. The Q10-A normally unmanned installation is located approximately 20
km from the Dutch shore. It is powered sustainably via wind and solar power
and is remotely operated, limiting offshore visits, which are conducted by
boat.
https://kistosplc.com/ (https://kistosplc.com/)
Operating Review
2021 was a critical year for Kistos, as we transitioned from being an
investing company to an operating business with significant reserves,
production, and technical expertise. Our newly purchased Dutch assets
contributed over 7 months of production to the Group and exited the year with
output of 1.8 MM Nm(3) per day versus 1.2 MM Nm(3) per day at acquisition.
Average daily production post-acquisition was lower than pre-acquisition owing
to planned and unplanned shutdowns on the P15-D platform in the third quarter
of the year. Nevertheless, on a pro forma basis for the whole of 2021, output
was 1.31 MM Nm(3) per day and is anticipated to be higher in 2022.
An important part of the acquisition in the Netherlands was gaining access to
a highly skilled workforce and an operating capability. It is a tribute to the
team that they managed a drilling campaign lasting almost 7 months without any
lost time injuries. It also led to the uplift in production referred to above,
a successful flow test from the Q10-A Orion oil discovery, and a successful
flow test from the secondary targets at the Q11-B gas discovery.
Drilling Campaign
Our drilling campaign commenced with the arrival of Borr Drilling's
Prospector-1 jack-up drilling rig at the Q10-A field in mid-July 2021. By the
time the rig went off contract in February 2022, we had successfully
completed:
§ A flow test of the Q10-A Orion oil discovery, which is located in a
naturally fractured reservoir overlying the producing Q10-A gas field.
§ A sidetrack of the Q10-A-04 well, which was not producing, to a new
location in the Slochteren formation. This is the field's primary producing
reservoir.
§ A series of workovers on existing producing wells at the Q10-A gas field.
§ An appraisal well on the Q11-B gas discovery, which failed to encounter gas
in the primary Slochteren target but tested over 0.27 MMcm/d from secondary
targets.
After the target formation at Q10-A Orion was encountered on prognosis at a
depth of 1,562 metres TVDSS, an 825 metres horizontal section was drilled by
the Prospector-1. The well was flow tested for 5 days and, during this time, a
maximum stable rate of 3,200 barrels of oil per day (bopd) was achieved. This
was higher than anticipated and the good quality oil (33° API) was sold to a
local refinery. We are now evaluating development options for the field.
Although the Q11-B appraisal did not encounter gas in its primary target, it
did successfully test gas from the Bunter and Zechstein formations, both of
which are also productive at Q10-A. Although this means the volume of gas at
Q11-B is materially less than we would have hoped, which resulted in an
impairment of €119.8MM, we are working to establish the viability of a
smaller development tied back to Q10-A.
Gas Producing Assets
Q10-A (Kistos 60% and operator)
As Kistos' only producing asset in 2021, the Q10-A gas field was responsible
for 100% of the Company's gas production. It straddles the Q07 and Q10-a
production licences approximately 20km offshore the Netherlands and received
development approval in January 2018. This followed the drilling of a
successful appraisal/development well in 2015. Little more than a year after
the project was sanctioned, commercial gas production was achieved in February
2019.
The facilities comprise a remotely operated, unmanned platform with six
well-slots, located in relatively shallow water of approximately 21 metres.
The platform was designed to have as small a carbon footprint as possible,
with on-board wind turbines and solar panels providing most of its power.
Furthermore, any visits to the platform are carried out by boat rather than
helicopter. Produced gas is exported through a dedicated 42km pipeline to the
TAQA-operated P15-D platform, where it is processed for onward transportation
to shore.
Development Projects
Q10-A Orion (Kistos 60% and operator)
The Q10-A Orion oil field is located directly above the Q10-A gas field in the
relatively shallow (<1,600 metres) Vlieland sandstone formation. This is a
proven play in the area, with the P09 Horizon field and the P15 Rijn field
both producing from this zone. Although the Vlieland has low porosity and
permeability, it also contains natural fractures that can significantly
enhance productivity. This was shown to be the case at Q10-A Orion in the
third quarter of 2021, when we drilled a sidetrack from the Q10-A-04 well and
flow tested an 825 metres horizontal section at a rate of 3,200 b/d.
This result led to a decision to commence the Concept Assess phase of
development planning for the field. This involves building new static and
dynamic reservoir models before evaluating several development concepts with a
view to creating a shortlist of options to take forward into a more detailed
Concept Select phase of work. This is expected to complete in the second
quarter of 2022, potentially enabling an investment decision to be taken by
the end of the year.
Q11-B (Kistos 60% and operator)
An appraisal of the Q11-B discovery failed to produce gas from its primary
target. However, this disappointment was tempered by successful tests from the
Zechstein and Bunter formations. Work is now underway to establish that these
reservoirs contain sufficient volumes to justify a tieback of the Q11-B field
to the Q10-A facilities. This work is expected to complete 2022.
Proposed Acquisition
After the period end, on 31 January 2022, Kistos entered into an agreement
with TotalEnergies S.E. ("TotalEnergies") to acquire:
§ 20% working interests in the producing Laggan, Tormore, Edradour, and
Glenlivet gas fields, located offshore the UK West of Shetland.
§ A 20% interest in the undeveloped Glendronach gas field.
§ A 25% interest in block 206/4a, which contains the 638 Bcf (operator's P50
resource estimate) Benriach prospect.
§ A 20% interest in the Shetland Gas Plant.
The consideration payable in respect of the acquisition comprises:
§ Initial cash consideration of US$125 million (subject to customary closing
adjustments), payable on completion.
§ In the event the average day-ahead gas price at the National Balancing
Point exceeds 150p/therm in 2022, up to US$40 million will be payable in
January 2023.
§ Should Benriach be developed, Kistos will pay US$0.25 per MMBtu of net 2P
reserves after first gas.
Kistos expects production from the assets to be acquired to average
approximately 6,000 boe/d (net) during 2022, which will approximately double
full year Group output on a pro forma basis. Importantly, emissions from GLA
production operations are forecast by Kistos to be approximately 13 kg
CO(2)e/boe in 2022, which is significantly below the North Sea average of 22
kg CO2e/boe (as estimated in the OGA's "UKCS natural gas carbon footprint
analysis" of 26th May 2020). Proved and probable reserves as at 1(st) January
2022, which is the effective date of the acquisition, were 6.2 MMboe
(operator's estimate).
The producing GLA gas fields are in water depths of approximately 300 metres
to 625 metres and are located up to 125km north-west of the Shetland Islands.
Development approval was originally granted in 2010 and first gas was achieved
at the Laggan and Tormore fields during 2016. The Glenlivet and Edradour
fields received development approval in 2015 and subsequently came on-stream
in 2017. Meanwhile, the Glendronach field was discovered in 2018 and it is
anticipated that the development will utilise existing infrastructure. This
includes the Shetland Gas Plant, where the gas is processed prior to export to
the St. Fergus Gas Terminal in Scotland.
Completion is expected to occur in the second quarter of 2022 subject to
customary regulatory and partner consents.
Financial Review
Production and Revenue
Actual production on a working interest basis totalled 157 MM Nm(3) (2.4
kboe/d) in the 63 weeks to 31 December 2021. This reflects the acquisition of
Tulip Oil Netherlands ('TON') on 20 May 2021. Had Kistos acquired TON on 1
January 2021, average production in 2021 would have been 288 MM Nm3 or 0.79 MM
Nm3/d (5.3 kboe/d).
The Group's average realised gas price during the period was €47.31/MWh and
total revenue from gas sales was €89.5MM. On a pro forma basis, these
figures were €33.58/MWh and €116.2MM. Revenue from condensate sales was
€0.1MM or €0.6MM on a pro forma basis.
Costs
Production costs for the period following the acquisition of TON was €6.1MM
or €3.25 per MWh. The latter figure would have been 13% lower or €2.83 per
MWh if the acquisition of TON had completed on 1 January 2021. During 2021,
Kistos NL2 incurred pre-FID development expenses of €4.5MM on potential
alternative evacuation routes for the Q10-A platform. As FID was not taken on
the project these costs have been expensed in the profit and loss account.
Further studies are being undertaken in 2022 with other partners.
EBITDA
The Group reported adjusted EBITDA of €78.9MM or €41.68 per MWh in the 63
weeks to 31 December 2021. On a pro forma basis, adjusted EBITDA was
€102.9MM or €29.73 per MWh in the period. The impairment of €121.0MM
relates primarily to the failure of the Q11-B appraisal well to encounter gas
in the Slochteren formation. It also included a total of €1.2MM for the
restimulation of the Q10-A06 well (€1.4MM), the abandonment of Donkerbroek
Hemrik (€0.4MM) and a reversal of the impairment of the partial abandonment
of the Q10-A04 well (€0.6MM).
€'000 31 December 2021 (actual) 31 December 2021 (pro forma)
Adjusted EBITDA 78,861 102,862
Depreciation and amortisation (13,277) (20,247)
Impairments (121,036) (128,507)
Pre-FID expenses (4,456) (4,535)
Transaction costs (2,864) (2,172)
Operating loss (62,772) (52,599)
Capital Expenditure
Consistent with our growth plans and to ensure we maximise the value of our
asset portfolio, capital expenditure in 2021 was €23.8MM on an accruals
basis. The bulk of this - €23.7MM - related to our drilling campaign, while
expenditure on an alternative export route was expensed given the project is
pre-FID. Given we are now investigating possible alternatives to a new
pipeline to IJmuiden, capital expenditure in 2022 will not ramp up as much as
we originally expected.
Profit/loss before tax
There was an actual operating loss of €62.8MM during the period and a loss
before tax of €73.9MM. This figure was after impairments of €121.0MM, and
finance costs of €11.1MM, including interest charges of €9.0MM associated
with the €150MM of Nordic Bonds (€60MM of new bonds and €90MM of
refinancing) issued by Kistos NL2 during the period. There was also a loss on
redemption of €0.8MM relating to an €87MM Nordic Bond refinancing. On a
pro forma basis, there was a €65.9MM pre-tax loss for the period. As well as
the items referred to above, this figure also reflects interest charges
relating to the €87MM bond prior to its redemption.
Before expenses, Kistos raised €102.4MM from equity investors and issued
€150MM of Nordic Bonds (€60M of new bonds and €90M of refinancing)
during the period. After acquiring Tulip Oil Netherlands and other expenses,
this led to the Company holding cash and cash equivalents of €77.3MM on 31
December 2021.
In May 2021, Kistos hedged 100,000 MWh per month at a price of €25/MWh for
the 9-month period from July 2021 to March 2022 to cover anticipated capital
expenditure over the period. Based on the prevailing gas price of
€64.85/MWh, this resulted in the creation of a €5.9MM hedge reserve at
year end. As of 1 April 2022, Kistos is unhedged and, given capital
expenditure is not expected to ramp up as much as originally expected in 2022,
has no current plans to enter into any new hedging agreements.
Financial position
€'000 31 December 2021 (actual)
Cash and cash equivalents at beginning of period -
Net cash generated from operating activities 47,956
Net cash used in investing activities (120,654)
Net cash from financing activities 149,986
Net increase/(decrease) in cash and cash equivalents 77,288
Exchange (losses)/gains -
Cash and cash equivalents on 31 December 2021 77,288
Proposed Acquisition
After the period ending 31 January 2022, Kistos entered into an acquisition
agreement with TotalEnergies (see page 9 for further details). Completion is
subject to partner and OGA approval. The consideration payable in respect of
this transaction comprises cash of US$125MM (subject to customary closing
adjustments and less the deposit paid of $6.25m), and further contingent cash
payments as follows:
§ In the event the average day ahead gas price at the National Balancing
Point exceeds 150p/therm in 2022, up to US$40MM will be payable in January
2023.
§ Should Benriach be developed, Kistos will pay US$0.25 per MMBtu of net 2P
reserves after first gas.
Principal Risks and Uncertainties
Kistos identifies, assesses, and manages the risks critical to its success.
Overseeing these risks benefits the Group and protects its business, people,
and reputation. We use the risk management process to provide reasonable
assurance that the risks we face are recognised and controlled. This approach
enables the organisation to achieve its strategic objectives and create value.
The principal risks and uncertainties of the Group relate to the following:
Growth of Reserve Base
The Group needs to identify new reserves and resources to ensure continued
future growth and does so through development and acquisition. The Group may
fail to identify attractive acquisition opportunities or may select
inappropriate drilling targets.
The long-term commodity price forecast and other assumptions used when
assessing potential projects and other investment opportunities have a
significant influence on the forecast return on investment and, if incorrectly
estimated, could result in poor decisions.
The Group's investment strategy prioritises investment in the North-West
Europe and across a mix of producing, development, and appraisal projects. A
rigorous assessment process evaluates and determines the risks associated with
all potential business acquisitions and strategic alliances, including
conducting stress-test scenarios for sensitivity analysis. Each assessment
includes an analysis of the Group's ability to operate in a new jurisdiction.
Operational Performance
The Group's production volumes (and therefore revenue) are dependent on the
performance of its producing assets. The Group's producing assets are subject
to operational risks including no critical spare equipment or plant
availability during the required plant maintenance or shutdowns; asset
integrity and health, safety, security, and environment incidents; and low
reserves recovery from the field and exposure to natural hazards such as
extreme weather events.
Reputation
The reputational and commercial exposures to a major offshore incident,
including those related to an environmental incident, or
non-compliance with applicable law and regulation are significant. All
activities are conducted in accordance with approved policies, standards, and
procedures. The Group requires adherence to its Code of Conduct and runs
compliance programmes to provide assurance on conformity with relevant legal
and ethical requirements.
Commodity Prices
The Group's results are heavily dependent on natural gas prices, which are
dependent on several factors including the impact of climate change concerns,
COVID-19, and regulatory developments. The Group will regularly review and
implement suitable policies to hedge against the possible negative impact of
changes in gas prices to protect its investment strategy.
Decommissioning Cost Estimates and Timing
The estimated future costs and timing of decommissioning is a significant
estimate; any adverse movement in price, operational issues and changes in
reserves and resource estimates could have a significant impact on the cost
and timing of decommissioning. The Group mitigates this risk through the
specialist decommissioning experience in its team, coupled with a continued
focus on delivering asset value to maximise field life.
Cyber Security
Breaches in, or failures of, the Group's information security management could
adversely impact its business activities. The Group's information security
management model is designed with defensive structural controls to prevent and
mitigate the effects of computer risks. It employs a set of rules and
procedures, including a Disaster Recovery Plan, to restore critical IT
functions.
COVID-19
Operational restrictions placed on the Group and its supply chain because of
the spread of COVID-19 could lead to shutdowns and/ or delays in obtaining
critical equipment for capital projects. To date, the Company has not
experienced any material adverse impact on its operations because of COVID-19.
The precautionary and contingency measures that have been put in place,
particularly in relation to our 2021/2022 drilling campaign have worked well.
Environmental, Social and Governance
In the second half of 2021, we engaged Flag Communications to undertake our inaugural materiality assessment, to identify and prioritise the issues related to sustainability and responsible business that are most important to Kistos. The process involved:
§ A desk-based research and media scan;
§ A review of Kistos' corporate approach and policies;
§ A review of material issues reported by a benchmark group of peers and best practice companies; and
§ Interviews with a variety of internal and external subject matter experts, to score potential material issues in terms of impact on the business and influence over stakeholders
The results of this exercise have formed the foundation for our ESG strategy, grouped under three pillars covering environmental, social and governance issues:
1. Caring for the environment
We will continue to put sustainability first with every decision we make:
w Action on Climate Change
w Global Energy Transition
w Operational Energy Use
w Spill Performance
w Air Quality, Emissions and Waste
w Decommissioning
w Ecological Impacts and Biodiversity
2. Operating ethically and responsibly
We will act with integrity to ensure we're always doing the right thing.
w Risk Management
w Business Ethics and Governance
w Operations in Sensitive or Complex Locations g Sustainable Procurement
w Financial Risks of Climate Change g Funding and Investment
w Economic Performance
3. Putting People First
We will create safe, inclusive workplaces, promote human rights and strengthen
our communities.
w Health and Safety
w Access to Energy
w Engagement with Communities and Stakeholders
w Employment, Training and Education
w Diversity, Equality and Inclusion
w Human Rights
In particular, our new strategy will broaden the scope of our stewardship approach to the environment. By fully embracing the European Union's aim to reach net zero GHG emissions by 2050 and working with suppliers to promote good practice, we are confident that we can contribute to a more sustainable future without compromising our growth ambitions
Cautionary statement about forward-looking statements
This results announcement contains certain forward-looking statements. All
statements other than historical facts are forward-looking statements.
Examples of forward-looking statements include those regarding the Group's
strategy, plans, objectives or future operating or financial performance,
reserve and resource estimates, commodity demand and trends in commodity
prices, growth opportunities, and any assumptions underlying or relating to
any of the foregoing. Words such as "intend", "aim", "project", "anticipate",
"estimate", "plan", "believe", "expect", "may", "should", "will", "continue"
and similar expressions identify forward-looking statements. Forward-looking
statements involve known and unknown risks, uncertainties, assumptions and
other factors that are beyond the Group's control. Given these risks,
uncertainties and assumptions, actual results could differ materially from any
future results expressed or implied by these forward-looking statements, which
speak only as at the date of this report. Important factors that could cause
actual results to differ from those in the forward-looking statements include:
global economic conditions, demand, supply and prices for oil, gas and other
long-term commodity price assumptions (as they materially affect the timing
and feasibility of future projects and developments), trends in the oil and
gas sector and conditions of the international markets, the effect of currency
exchange rates on commodity prices and operating costs, the availability and
costs associated with production inputs and labour, operating or technical
difficulties in connection with production or development activities, employee
relations, litigation, and actions and activities of governmental authorities,
including changes in laws, regulations or taxation. Except as required by
applicable law, rule or regulation, the Group does not undertake any
obligation to publicly update or revise any forward-looking statements,
whether as a result of new information, future events or otherwise. Past
performance cannot be relied on as a guide to future performance.
Financial Statements
Consolidated profit and loss account
€'000 Note 14 October 2020 to 31 December 2021
Revenue 3 89,628
Other income 61
Exploration expenses (123)
Production costs 4 (6,143)
Development expenses 5 (4,456)
Other operating expenses 6 (7,426)
Depreciation and amortisation 15,16 (13,277)
Impairments 16 (121,036)
Total operating expenses (152,461)
Operating loss (62,772)
Interest expenses 10 (8,993)
Finance income and expenses 10 (2,092)
Net finance costs (11,085)
Loss before taxes (73,857)
Tax (charge)/credit 12 33,749
Loss for the period attributable to owners of the Group (40,108)
Basic and diluted (loss)/earnings per share (cents) 11 (0.68)
Consolidated statement of comprehensive income
€'000 Note 14 October 2020 to 31 December 2021
Profit/(loss) for the period attributable to owners of the Group (40,108)
Items that may be reclassified to profit or loss
Costs of cash flow hedge deferred and recognised in OCI 21 (38,624)
Cash flow hedge - reclassified to profit or loss 21 26,843
Tax impact on hedge reserve in OCI 21 5,891
Foreign currency translation differences 382
Total comprehensive income attributable to owners of the Group (45,616)
Consolidated balance sheet
€'000 Note 31 December 2021
Goodwill 14,15 -
Exploration and evaluation assets 15 43,500
Property, plant and equipment 16 189,600
Deferred tax assets 12 13,496
Total non-current assets 246,596
Inventories 902
Unbilled receivables 29 40,299
Other receivables 17 8,439
Cash and cash equivalents 18 77,288
Total current assets 126,928
Total assets 357,422
Share capital 19 9,627
Share premium 20a 94,181
Merger reserve 20b 14,734
Hedge reserve 21 (5,890)
Translation reserve 22 382
Retained earnings (42,463)
Total equity 70,571
Abandonment provision 24 15,904
Bond payable 25 145,074
Deferred tax liability 26 57,288
Other non-current liabilities 31 31
Total non-current liabilities 218,297
Trade payables and accrued expenses 27 23,479
Tax payable 14,980
Abandonment provision 24 1,272
Other liabilities 28 28,823
Total current liabilities 68,554
Total liabilities 286,851
TOTAL EQUITY & LIABILITIES 357,422
Consolidated statement of changes in equity for the period from 14 October 2020 to 31 December 2021
€'000 Share capital Share premium Merger reserve Hedge reserve Translation Retained earnings Total equity
reserve
Opening balance - - - - - - -
Loss for the period - - - - - (40,108) (40,108)
Movement in the period - - - (5,890) 382 - (5,508)
Total comprehensive income for the year - - - (5,890) 382 (40,108) (45,616)
Transactions with owners
Shares issued in the period 9,627 94,181 14,734 - - - 118,542
Shares issue costs - - - - - (2,355) (2,355)
Total transactions with owners 9,627 94,181 14,734 - - (2,355) 116,187
Equity at 31/12/21 9,627 94,181 14,734 (5,890) 382 (42,463) 70,571
Consolidated statement of cash flows
€'000 Note 14 October 2020 to 31 December 2021
Cash flow from operating activities
Loss for the period (40,108)
Tax charge/(credit) 12 (33,749)
Net finance costs 10 11,085
Depreciation and amortisation 16 13,277
Impairment losses 15,16 121,036
Taxes paid (890)
(Increase)/decrease in trade and other receivables (40,990)
Increase/(decrease) in trade, other payables and provisions 18,582
Increase)/decrease in inventories (287)
Net cash flow from operating activities 47,956
Cash flow from investing activities
Payments to acquire tangible fixed assets 32 (19,958)
Payments for acquisition of Kistos NL1 and NL2 14,32 (100,696)
Net cash flow from investing activities (120,654)
Cash flow from financing activities
Proceeds from share issue 102,441
Costs incurred for share issue (2,355)
Repayment of long-term payables (79)
Interest paid (7,461)
Bond refinancing 25 3,000
Bond issue costs (2,933)
Bond redemption costs (2,627)
Proceeds from bond issue 25 60,000
Net cash flow from financing activities 149,986
Increase/(decrease) in cash and cash equivalents 77,288
Cash and cash equivalents opening -
Cash and cash equivalents at 31 December 2021 17 77,288
Notes to the Consolidated Financial Statements
Note 1: Accounting policies
General information
Kistos plc (hereinafter "the Group") is a public limited liability Group
incorporated on 14 October 2020 in England and Wales whose shares are publicly
traded on the Alternative Investment Market in London. The address of its
registered office and principal place of business is 9th Floor 107 Cheapside,
London, United Kingdom, EC2V 6DN. The Group is registered in the Trade
Register at the Companies House under number 12949154.
The main focus of the Group is creating value for its investors through the
acquisition and management of companies or businesses in the energy sector. On
20 May 2021 Kistos NL1 B.V. ("'Kistos NL1") was acquired by Kistos plc. Kistos
NL2 B.V. ("'Kistos NL2") is a wholly owned subsidiary of Kistos NL1 B.V. The
main focus of these subsidiaries is the upstream development and production
with a focus on the exploitation opportunities in undiscovered and undeveloped
(offshore) oil and gas fields in The Netherlands. Together with the wholly
owned subsidiary Kistos Energy Ltd., these subsidiaries form the Kistos Group
(hereinafter referred to as "the Group").
The Group holds the exploration licenses for Q8, Q10-B, Q11, M10-A + M11A and
Terschelling- Noord and holds the production licenses for Q7, Q10-A,
Akkrum-11, Donkerbroek and Donkerbroek-West. Together with Energie Beheer
Netherlands ('EBN') as partner, Kistos NL2 acts as the operator in the joint
operation agreements of the abovementioned offshore licenses.
Financial reporting period
These consolidated financial statements cover the first extended financial
period of the Group, which runs from 14 October 2020 to 31 December 2021.
Going concern
The total available liquidity at 31 December 2021 for the Kistos Group was
€77.3m in cash and cash equivalents, and from May 2021, when the Group
acquired Tulip Oil Netherlands Offshore B.V., the Group has generated €48m
of cash from operating activities. Directors' Report.
To assess the Group's and the Parent Company's ability to continue as a going
concern, management has prepared base case and downside cash flow forecasts to
31 December 2023. These forecasts have considered the recently announced 20%
acquisition of TotalEnergies interest in the Greater Laggan Area (GLA) West of
Shetland for US$125m (with additional contingent considerations that may be
payable in January 2023). This is planned to be funded through internally
generated cash resources. This transaction, which is subject to customary
regulatory and partner consents, is envisaged to complete in Q2 2022. The
effective date of the transaction is 1 January 2022.
Management's base case cash flow forecast assumes:
§ Production between 1 January 2022 and the acquisition date is offset
against the acquisition price.
§ Q10-A and TotalEnergies future production is in line with forecast, and
future sales are priced at the ICIS forward gas curve.
§ Gross acquisition consideration of US$125MM is paid in June 2022 and Debt
Service Obligations of €16.5MM in respect of asset retirement obligations
are paid into Escrow.
This forecast shows that minimum covenant liquidity and leverage covenants
under the bond are complied with in all periods.
Management has also prepared downside cash flow forecasts. This has focused on
the pinch point for cash, which is when the consideration for the
TotalEnergies acquisition is paid in Q2 2022. This shows if no further cash
was generated or costs incurred for TotalEnergies or Q10-A after March 2022,
there would be no breach of the liquidity or leverage covenants.
Management has also performed a reverse stress test, which showed that either
a reduction in sales volumes or price of greater than 67% for the remainder of
the forecast period, with all other factors held constant, would result in the
liquidity covenant being breached in June 2023.
Accordingly, the Directors have concluded that these circumstances form a
reasonable expectation that the Group has adequate resources to continue in
operational existence, for the foreseeable future. For these reasons, the
Directors continue to adopt the going concern basis in preparing the Annual
Report and Accounts.
Note 2: Basis of preparation
Statement of compliance
The consolidated financial statements for the extended period from 14 October
2020 to
31 December 2021 have been prepared in accordance with international
accounting standards in conformity with the requirements of the Companies Act
2006.
Details of the Group's significant accounting policies are set out in note 2.
The Group's financial statements were authorised for issue by the Board on 6
April 2022.
Basis of measurement
The financial statements have been prepared on the historical cost basis
except for the following items, which are measured on an alternative basis on
each reporting date:
§ derivative financial instruments are measured at fair value (see note 29);
§ non-derivative financial instruments are measured at fair value through
profit and loss account (FVTPL) (see Note 29); and
§ contingent consideration assumed in a business combination at fair value
(see note 29).
Functional and presentation currency
Items included in the financial statements of each of the Group's entities are
measured using the currency of the primary economic environment in which each
entity operates ('the functional currency').
Transactions in foreign currencies are translated to the entity's functional
currency at the foreign exchange rates at the date of the transactions.
Foreign exchange gains and losses resulting from the settlement of monetary
assets and liabilities denominated in foreign currencies are recognised in the
income statement, except when deferred in other comprehensive income as
qualifying cash flow hedges and qualifying net investment hedges. All UK
entities in the Group have a functional currency of GBP. All Dutch entities
have a functional currency of EUR.
The presentation currency for the financial statements is EUR as the
significant subsidiaries have most of their transactions in this currency. All
amounts have been rounded to the nearest €1 thousands, unless otherwise
stated.
The results and balance sheet of all of the Group entities that have a
functional currency different from the presentation currency are translated
into the presentation currency as follows:
§ assets and liabilities for each balance sheet presented are translated at
the closing rate at the date of that balance sheet (long term assets and
liabilities translated at the historic rate);
§ income and expenses for each income statement are translated at average
exchange rates (unless this average is not a reasonable approximation of the
cumulative effect of the rates prevailing on the transaction dates, in which
case income and expenses are translated at the rate on the dates of each
transaction); and
§ all resulting exchange differences are recognised in other comprehensive
income.
On consolidation, exchange differences arising from the translation of any net
investment in foreign entities, and of borrowings and other financial
instruments designated as hedges of such investments, are recognised in other
comprehensive income. When a foreign operation is sold or any borrowings
forming part of the net investment are repaid, the associated exchange
differences are reclassified to profit or loss, as part of the gain or loss on
sale.
Goodwill and fair value adjustments arising on the acquisition of a foreign
operation are treated as assets and liabilities of the foreign operation and
translated at the closing rate.
Business combinations
The Group accounts for business combinations using the acquisition method when
the acquired set of activities and assets meets the definition of a business
and control is transferred to the Group. In determining whether a particular
set of activities and assets is a business, the Group assesses whether the set
of assets and activities acquired includes, at a minimum, an input and
substantive process and whether the acquired set has the ability to produce
outputs.
The consideration transferred in the acquisition is generally measured at fair
value, as are the identifiable net assets acquired. Any goodwill that arises
is tested annually for impairment. Any gain on a bargain purchase is
recognised in profit or loss immediately. Transaction costs are expensed as
incurred, except if related to the issue of debt or equity securities.
The consideration transferred does not include amounts related to the
settlement of pre-existing relationships. Such amounts are generally
recognised in profit or loss.
Any contingent consideration is measured at fair value at the date of
acquisition. If an obligation to pay contingent consideration that meets the
definition of a financial instrument is classified as equity, then it is not
remeasured and settlement is accounted for within equity. Otherwise, other
contingent consideration is remeasured at fair value at each reporting date
and subsequent changes in the fair value of the contingent consideration are
recognised in profit or loss.
Use of judgements and estimates
In preparing these consolidated financial statements, management has made
judgements and estimates that affect the application of the Group's accounting
policies and the reported amounts of assets, liabilities, income and expenses.
Actual results may differ from these estimates.
Estimates and underlying assumptions are reviewed on an ongoing basis.
Revisions to estimates are recognised prospectively.
Judgements
The significant judgements made in applying the accounting policies to the
Group's consolidated financial statements are set out below.
§ Acquisition accounting
The standard on acquisition accounting requires an assessment of whether an
acquisition meets the criteria of a business. The acquisition of the Dutch
North Sea assets of Kistos NL1 and NL2
in the view of management does meet this definition and hence the appropriate
accounting implications have been followed.
§ Abandonment provisions
The abandonment provisions for Kistos NL2 assume that the pipelines between
Q10-A and P15D can remain in place and do not need to be removed. This is
based on recent updates in legislative changes.
§ Assumptions and estimation uncertainties
Information about assumptions and estimation uncertainties at 31 December 2021
that have a significant risk of resulting in a material adjustment to the
carrying amounts of assets and liabilities in the next financial year are
included below.
o Acquisition accounting (note 14)
During 2021, Kistos plc undertook acquisition accounting of its newly acquired
subsidiaries: Kistos NL1 and Kistos NL2. As part of the purchase price
accounting and following the use of an external consultant, a step up has been
recorded on the valuation of the tangible and intangible fixed assets.
Management has determined that the fair value of the current assets and
current liabilities, including financial liabilities, are equal to book value.
Carrying value of goodwill, intangible assets and property, plant and
equipment (note 15 and 16): Management performs annual impairment testing on
the goodwill balance to assess recoverability. The principles of this
assessment are similar to that adopted for tangible and intangible assets
where an impairment trigger exists.
Management performs impairment reviews on the Group's intangible assets and
property, plant and equipment assets at least annually with reference to
indicators in IAS 36 Impairment of Assets. Where indicators are present and an
impairment test is required, the calculation of the recoverable amount
requires estimation of future cash flows within complex impairment models.
Key assumptions and estimates in the impairment models relate to: commodity
prices and the long-term corporate economic assumptions thereafter, operating
expenses, capital expenditures, pre-tax discount rates that are adjusted to
reflect risks specific to individual assets, commercial resources and the
related cost profiles.
Impairment tests are carried out on the following basis:
§ By comparing the sum of any amounts carried in the books as compared to the
recoverable amounts;
§ The recoverable amount is the higher of an asset's fair value less costs to
sell and its value in use. The Group generally assesses the value in use using
the estimated future cash flows which are discounted to their present value
using a pre-tax discount rate that reflects current market assessments of the
time value of money and the risks specific to the asset or CGU; and
§ Where there has been a charge for impairment in an earlier period that
charge will be reversed in a later period where there has been a change in
circumstances to the extent that the recoverable amount is higher than the net
book value at the time. In reversing impairment losses, the carrying amount of
the asset will be increased to the lower of its original carrying value and
the carrying value that would have been determined (net of depletion) had no
impairment loss been recognised in prior periods.
¨ Commercial reserves (oil and gas) estimates used in the calculation of
depreciation and impairment of property, plant and equipment (note 16):
P1 proven and P2 probable reserves are estimates of the amount of oil and gas
that can be economically extracted from the Group's oil and gas assets. The
Group estimates its resources using standard recognised evaluation techniques.
The estimate is reviewed at least annually by management and is reviewed as
required by independent consultants.
Proven and probable reserves are determined using estimates of oil and gas in
place, recovery factors and future commodity prices; these having an impact on
the total amount of recoverable reserves. Depreciation is calculated using the
net book value of the asset multiplied by the ratio of production divided by
2P reserves remaining.
¨ Abandonment provision (note 24):
Decommissioning costs are uncertain and cost estimates can vary in response to
many factors, including changes to the relevant legal requirements, the
emergence of new technology or experience at other assets. The expected
timing, work scope, amount of expenditure and risk weighting may also change.
Therefore, significant estimates and assumptions are made in determining the
provision for decommissioning.
The estimated decommissioning costs are reviewed annually by an internal
expert and the results of this review are then assessed alongside estimates
from Operators. Provision for environmental clean-up and remediation costs is
based on current legal and contractual requirements, technology and price
levels.
¨ Current tax charge and deferred tax assets (note 12):
Deferred tax assets are recognised only to the extent it is considered
probable that those assetswill be recoverable. This involves an assessment of
when those assets are likely to reverse, and a judgement as to whether or not
there will be sufficient taxable profits available to offset the assets when
they do reverse. This requires assumptions regarding future profitability and
is therefore inherently uncertain. To the extent assumptions regarding future
profitability change, there can be an increase or decrease in the amounts
recognised in respect of deferred tax assets as well as in the amounts
recognised in income in the period in which the change occurs.
Current tax is calculated based on the best available information. Changes
between the tax charge included in the consolidated financial statements and
the subsequent tax filings are recognised prospectively as a prior year tax
charge.
¨ Measurement of fair values (note 29):
A number of the Group's accounting policies and disclosures require the
measurement of fair values, for both financial and non-financial assets and
liabilities. When measuring the fair value of an asset or a liability, the
Group uses observable market data as far as possible. Fair values are
categorised into different levels in a fair value hierarchy based on the
inputs used in the valuation techniques as follows:
§ Level 1: quoted prices (unadjusted) in active markets for identical assets
or liabilities.
§ Level 2: inputs other than quoted prices included in Level 1 that are
observable for the asset or liability, either directly (ie as prices) or
indirectly (ie derived from prices).
§ Level 3: inputs for the asset or liability that are not based on observable
market data (unobservable inputs).
If the inputs used to measure the fair value of an asset or a liability fall
into different levels of the fair value hierarchy, then the fair value
measurement is categorised in its entirety in the same level of the fair value
hierarchy as the lowest level input that is significant to the entire
measurement.
Statement of cash flows
The statement of cash flows is prepared in accordance with indirect method and
constitutes an explanation of the change in net cash, defined as cash and cash
equivalents. In the statement of cash flows, a differentiation is made between
cash flows from operating, investing and financing activities.
Cash flows in currencies other than the euro are translated at the exchange
rates prevailing at the date of the transaction. The Group uses periodically
fixed average exchange rates that effectively approximate the exchange rates
on transaction dates.
Note 3: Revenue
Revenue is measured based on the consideration specified in a contract with a
customer. The Group recognises revenue when it transfers control over the oil
or gas sold to a customer.
€'000 14 October 2020 to
31 December 2021
Recognised income liquids 108
Recognised income gas 89,520
Total petroleum revenues 89,628
Breakdown of produced volumes (thousand barrels of oil equivalent)
Liquids 6
Gas 1,055
Total produced volumes 1,061
Gas (million Nm3) 157
Gas ('000 MWh) 1,892
Note 4: Production costs
Production costs include the costs related to:
§ the export of the gas produced from the Q10-A platform to a third-party
platform, P15-D, including treatment tariff, compression tariff and fixed
fees;
§ well maintenance expenditures; g GTS capacity fees; and
§ structural and facility-related surveys.
Note 5: Development expenses
These are mainly pre final investment decision expenses incurred on front end
engineering and design related to potential alternative commercial evacuation
routes.
Note 6: Other operating expenses
€'000 14 October 2020 to 31 December 2021
Salaries and contractors 3,114
Travel and travel-related costs 129
IT and communication 105
Professional services 4,238
Cost recharges 820
Other (including recovery of cost and capitalisation of costs) (980)
Total other operating expenses 7,426
Other includes IT and communication costs, occupancy costs and other costs
offset by joint operator recovery of €1.0MM and capitalisations of €670
thousand of costs related to the drilling programme executed
Note 7: Employee benefit expenses
€'000 14 October 2020 to 31 December 2021
Wages and salaries 2,585
Social security costs 272
Total employee benefit expenses 2,857
At the end of the year there were 17 employees of the Group in 2021 (excluding
non-executive directors), 12 of them working in The Netherlands and five of
them working in the United Kingdom.
During the period of 14 October 2020 to 31 December 2021, the average number
of staff employed by the Group, amounted to 10 people. This staffing level
(average number of staff) can be divided into the following staff categories,
including Executive Directors, in the year:
14 October 2020 to 31 December 2021
Technical 4
Support 6
Total staff 10
Note 8: Directors' remuneration
The following table details remuneration of Executive Directors of the Group.
Key management personnel are the Executive and Non-Executive Directors of the
Group.
€'000 14 October 2020 to 31 December 2021
Short-term employee benefits 935
Post-employment benefits 30
Total Directors' remuneration 965
The highest paid Director has a total remuneration of €490 thousand.
An interest-free loan of €238,214 (£200,000) has been granted by the Group
to one of its Executive Directors during the period. This loan remains
outstanding at the balance sheet date. No other loans, advances or guarantees
have been granted by the Group to its Executive or Non- Executive Directors
during the period 14 October 2020 to 31 December 2021.
Note 9: Reconciliation of adjusted EBITDA to operating profit
€'000 14 October 2020 to 31 December 2021 Pro forma EBITDA for the year 2021
Adjusted EBITDA 78,861 102,862
Depreciation and amortisation expense (13,277) (20,247)
Impairment (121,036) (128,057)
Pre-FID expenses (4,456) (4,535)
Transaction costs (2,864) (2,172)
Operating loss (62,772) (52,599)
Adjusted EBITDA is calculated on a business performance basis. Refer to the
alternative performance measures definition within the glossary. Transaction
costs represents professional advisor costs incurred in the listing of Kistos
plc.
Note 10: Net finance costs
€'000 14 October 2020 to 31 December 2021
Other interest expenses 93
Interest expenses 8,900
Total interest expenses 8,993
Accretion expenses 45
Amortised loan costs 700
Hedge ineffectiveness (see note 29) 625
Loss on bond redemption (see note 25) 781
Foreign exchange gains (59)
Total other financial expenses 2,092
Net finance costs 11,085
During 2021, €940 thousand of interest expenses have been capitalised under
property, plant and equipment. The Group ceased capitalising interest from
October 2021 following the completion of the remaining drilling programme
related to the initial financing secured by Kistos NL2 and the initial plans
drawn up for the Q10-A asset.
Note 11: (Loss)/earnings per share
Basic (loss)/earnings per share
The calculation of basic earnings per share (EPS) has been based on the
following consolidated profit attributable to ordinary shareholders and a
number of ordinary shares outstanding.
Consolidated profit/(loss) for the period, attributable to shareholders of the (40,108)
Group (€'000)
Average number of shares in the period 58,867,726
(Loss)/earnings per share (0.68)
Diluted (loss)/earnings per share (0.68)
Note 12 Tax (charge)/credit
€'000 14 October 2020 to 31 December 2021
Current tax expense
Current year (14,091)
Deferred tax expense
Deferred tax assets expense (11,872)
Deferred tax liability expense (see note 26) 59,712
Tax (charge)/credit 33,749
The income tax credit for the period can be reconciled to the accounting
profit as follows:
€'000 14 October 2020 to 31 December 2021
Loss before taxes (73,857)
Income tax (expense)/benefit calculated at 50% 36,929
Expense uplift on SPS 694
Marginal field incentive (investment allowance) 1,545
Difference in tax rates (2,712)
Other movements (1,045)
Parent company losses not recognised (1,662)
Tax (charge)/credit 33,749
Effective tax rate 45.7%
Temporary differences
€'000 Tax losses Provisions Other Total;
Opening balance - - - -
Acquired balances 14,802 2,765 1,910 19,477
Deferred tax on hedge reserve in OCI (see note 21) - - 5,891 5,891
Profit and loss account (7,787) 1,403 (5,488) (11,872)
At 31 December 2021 7,015 4,168 (2,313) 13,496
The tax losses are made up of Corporate Income Tax ("CIT") and State Profit
Share ("SPS") losses. Provisions relate to temporary differences on
abandonment provisions and Other relates to temporary differences on property,
plant and equipment, abandonment fixed assets and other
provisions/liabilities.
SPS losses can be carried forward indefinitely and are expected to be
recovered in the coming year for Kistos NL2 given the production levels and
high gas prices in 2022. The SPS losses in Kistos NL1 have been written off
given the uncertainty over the future development of M10a and M11 discoveries
(€15.4MM).
CIT losses can only be carried forward for a defined period of time. Some
losses in Kistos NL1 cannot be utilised and hence have been fully provided
for. This amounts to €1.9MM (2020: €3.0MM).
Kistos plc standalone losses have not been recognised due to the uncertainty
of future profits and where they may arise from.
During 2020, a new framework for fiscal union compensation was established
covering 2019 and future years. This results in an intercompany settlement of
tax charges/(credits) where an offset against other available losses/(profits)
within the fiscal union is possible. Kistos NL1
formed a fiscal unity with its subsidiary Kistos NL2 as of 1 April 2021. The
fiscal unity with Tulip Oil Holding B.V. ended on 31 March 2021.
Note 13 Subsidiaries and joint arrangements
Subsidiaries
Details of the Group's subsidiaries (both direct and indirect) at the end of the reporting year are as follows:
Name of subsidiary Principal activity Place of incorporation and operation Proportion of ownership interest and voting power held by the Group
Kistos NL1 B.V. Onshore and offshore exploration and production of hydrocarbon volumes The Hague, Netherlands 100%
Kistos NL2 B.V. Offshore exploration and production of hydrocarbon volumes The Hague, Netherlands 100%
Kistos Energy Ltd. Management consultancy activities other than financial management London, United Kingdom 100%
Joint arrangements
The Group has the following interest in joint arrangement that classifies as a joint operation:
Joint arrangement Licence owner Licence type Partner Status Period ended 31/12/21
M10a & M11 Kistos NL1 B.V. Exploration EBN Operated 60%
(offshore block)
Terschelling-Noord Kistos NL1 B.V. Exploration EBN Operated 60%
Donkerbroek Kistos NL1 B.V. Production EBN Operated 60%
Donkerbroek-West Kistos NL1 B.V. Production EBN Operated 60%
Akkrum-11 Kistos NL1 B.V. Production EBN Operated 60%
Q07 Kistos NL2 B.V. Production EBN Operated 60%
Q08 (offshore block) Kistos NL2 B.V. Exploration EBN Operated 60%
Q10-A (offshore block) Kistos NL2 B.V. Production EBN Operated 60%
Q10-B (offshore block) Kistos NL2 B.V. Exploration EBN Operated 60%
Q11 (offshore block) Kistos NL2 B.V. Exploration EBN Operated 60%
Note 14: Acquisition
In line with the mission statement of Kistos plc to create value for
shareholders through the acquisition and management of companies in the energy
sector, on 20 May 2021, Kistos plc completed the 100% acquisition of Tulip Oil
Netherlands B.V. (now called Kistos NL1) and Tulip Oil Netherlands Offshore
B.V. (now called Kistos NL2) for €155MM. The transaction assets constitute a
business and the acquisition has been accounted for using the acquisition
method, in accordance with IFRS3 business combinations. Control of the
businesses was acquired through the acquisition of 100% of the shares of
Kistos NL1, which also fully owns Kistos NL2. The consolidated financial
statements include the fair value of the identifiable assets and liabilities
as at the acquisition date and the results of Kistos NL1 and Kistos NL2 from
21 May 2021 till 31 December 2021. The next table shows management's
assessment of the calculated fair values.
Fair value acquisition
€'000 Fair value
Deferred tax assets 19,477
Cash and cash equivalents 23,529
Trade and other receivables 8,600
Inventory 615
Property, plant and equipment 81,725
Exploration and evaluation assets 144,856
Production assets 93,800
Trade and other payables (4,500)
Provisions (14,158)
Accrued expenses (3,552)
Deferred tax liability (117,000)
Borrowings (85,417)
Net assets acquired 147,975
Total consideration paid 154,975
Goodwill 7,000
An external valuation specialist has been used for determining the purchase
price accounting. The key assumptions used to arrive at the fair value are:
Assumption Value/range
Blended WACC 13.8%
Production CGU WACC 13.0%
Exploration CGU WACC 15.2%
Gas price €17.0 - 19.7/MWh
As part of the purchase price accounting two cash generating units have been
determined: production (covering Q10-A) and exploration (covering Q11-B, Q10
Gamma and Q10-B gas). A forecast period of 2041 has been applied to the
production CGU and 2032 to the exploration CGU. The forecast period is based
on the expected life of both the assets. A gas price in the range of 17.0-19.7
€/MWh has been used for the period to 2025. An inflation increase of 2% on
the gas price has been assumed after 2025. The deferred tax liability on the
intangibles has been recognised at a tax rate of 50%.
Cash flow overview acquisition
Cash Non-cash Total
Cash 60,000 - 60,000
Cash raised through additional borrowings 60,000 - 60,000
Surplus cash extraction 5,108 - 5,108
Other SPA adjustments (883) - (883)
Shares in Kistos plc - 15,750 15,750
Contingent consideration - 15,000 15,000
Total consideration paid 124,225 30,750 154,975
Cash held in Kistos NL2 (23,529)
Cash outflow on acquisition 100,696
The company may be required to pay contingent milestone consideration upon:
i) Intention to continue exploitation activities in respect of
Vlieland Oil (€7.5MM) and M10-M11 (€7.5MM) by Feb 2022. As management has
the intention to continue with these activities, this contingent consideration
has been recognised at the balance sheet date.
ii) Up to a maximum of €75MM payable at FID of Vlieland Oil
based on the recognition of estimated reserves recognised.
iii) Up to a maximum of €75MM payable at FID of M10-M11 based on the
recognition of estimated reserves recognised.
iv) Taking FID on the Q10-Gamma prospect by 2025 to the amount €10MM.
Payments related to ii)-iv) if crystallised would be incurred post the IFRS 3
measurement period of 12 months. As a result, these payments would be
accounted at fair value through the profit and loss account. Based on
management's best estimates no contingent consideration for items ii)-iv) have
been recognised as at balance sheet date.
Note 15: Intangible assets
€'000 Goodwill Exploration and evaluation assets Total
Opening balance - - -
Acquisitions (see note 14)* 7,000 144,856 151,856
Additions - 13,717 13,717
Acquisition cost 31.12.2021 7,000 158,573 165,573
Opening balance accumulated amortisation and impairments - - -
Amortisation - - -
Impairment (7,000) (112,802) (119,802)
Accumulated amortisation and impairments 31.12.2021 (7,000) (112,802) (119,802)
Book value 31.12.2021 - 45,771 45,771
* The exploration and evaluation assets include an amount of €140.2MM
arising on the purchase price accounting following the acquisition of Kistos
NL1 and Kistos NL2 (see note 14).
Kistos plc acquired Kistos NL1 and Kistos NL2 on 20 May 2021 for a total cash
and non-cash consideration of €155MM. As part of the purchase price
accounting based on the facts and circumstances at the date of acquisition,
Kistos plc recognised €7.0MM of goodwill, €140.2MM of exploration and
evaluation assets and €93.8MM of production licences. The goodwill is
allocated to the exploration and evaluation assets across the entire portfolio
of Kistos NL1 and Kistos NL2 assets. The production licences represents the
producing Q10-A asset. The exploration and evaluation intangible assets has
been recognised in respect of the Q11-B, Q10-B, Q10a oil,M10a, M11, and Q10-G
prospects.
During the period post acquisition, Kistos plc had success in the Q10-A oil
discovery with an initial production rate of 3,200 bbl/d, success in the side
track of the Q10-A04 well and limited success in the Q11-B drilling. The Q11-B
drilling targeted three reservoirs: Slochteren, Bunter and Zechstein. The
Slochteren completed drilling just before the end of the year, whilst Bunter
and Zechstein continued after the end of the year. The results of the drilling
showed that the Slochteren was water bearing. The Bunter and the Zechstein
were hydrocarbon bearing. As a result, the well was suspended pending further
development studies to formulate an economic development. Given this and the
fact that this information was not known at the time of the purchase price
accounting an impairment review over the goodwill and exploration and
evaluation assets has been performed. The impairment value has been determined
using the higher of fair value less costs to sell and value in use. The fair
value less costs to sell has been determined based on the nominal value of the
licenses when originally acquired. The value in use has been determined using
a set of discounted cashflows of future revenue and expenditure at a
weighted average cost of capital of 15% and forward gas prices at 31
December 2021 for the available years of 2022-2025 as published by ICIS with a
2% annual inflation rate thereafter. As the value in use was greater than the
determined fair value less costs to sell, the impairment value has been
determined based thereon. The assets valued have been the revised Q11-B target
(Bunter and Zechstein), Q10-B and Q10-G prospects, Q10-A oil discovery and the
M10a-M11 prospects. The total valuation of these assets was €45.8MM compared
to a total book value of €158.6MM. This has resulted in management recording
an impairment of €119.8MM comprised of a full write down of the goodwill of
€7.0MM and a €112.8MM impairment of the exploration and evaluation assets.
A sensitivity on the remaining valuation indicates that a 10% fall in the gas
price would result in a €7.9MM fall in the recoverable value.
Note 16: Property, plant and equipment
€'000 Assets under construction Production facilities including wells Other Total
Opening balance - - - -
Acquisition of Kistos NL2 (see note 14)* 1,227 174,156 142 175,525
Additions 9,187 692 183 10,062
Other - 151 - 151
Reclassification (10,414) 10,414 - -
Acquisition cost 31.12.2021 - 185,413 325 185,738
Opening balance depreciation and impairments
- - - -
Depreciation - (13,161) (116) (13,277)
Impairment - (1,234) - (1,234)
Reclassification - - - -
Accumulated depreciation and impairments 31.12.2021 - (14,395) (116) (14,511)
Book value 31.12.2021 - 171,018 209 171,227
* The fair value acquisition balance includes an amount of €93.8MM that
relates to the step-up on assets acquired of Kistos NL2, these assets
principally relate to the Q10 assets in production.
The reclassification in 2021 relates to the movement of assets to production
facilities including wells following the start of production.
Assets under construction
Assets under construction relate to wells drilled but not yet producing.
Production facilities, including wells
An amount of €93.8MM has been included relating to step up in fair value
following the acquisition of the Q10-A assets in production.
Impairment
Impairment tests of individual cash-generating units are performed when
impairment triggers are identified. Impairments identified are:
§ Adjustment to the abandonment cost of Donkerbroek Hemrik (€0.35MM) for
Kistos NL1 following a revision in cost estimates. As production from this
asset has ceased there are no management judgements applied in arriving at
this;
§ For Kistos NL2, following the unsuccessful restimulation of well Q10-A06
the amount spent has been impaired (€1.43MM); and
§ For Kistos NL2 the abandonment of the A04 drilling path (before drilling
the side track) has resulted in an impairment of the costs originally
capitalised of €6.92MM.
Note 17: Other receivables
€'000 31 December 2021
Joint operator receivable 3,920
Other receivables 2,014
Prepayments 163
VAT receivable 2,342
Total other receivables 8,439
Information about the company's exposure to credit risks, and impairment
losses for other short-term receivables is included in note 29.
Note 18: Cash and cash equivalents
Cash and cash equivalents consist of bank accounts and restricted cash
balances. The restricted funds at the end of 2021 relate to a bank guarantee
for the office lease in The Hague.
€'000 31 December 2021
Bank accounts 77,266
Restricted funds 22
Cash and cash equivalents 77,288
Note 19: Share capital
€'000 31 December 2021
Share capital 9,627
The Group's policy is to manage a strong capital base so as to manage
investor, creditor and market confidence and to sustain growth of the
business. Management monitors its return on capital. There are currently no
covenants related to the equity of the Group.
8,742,775 shares have been issued to Tulip Oil Holding B.V. in relation to the
acquisition of Kistos NL1 and NL2.
Share capital and premium analysis
No. of shares Issue price Ordinary shares (£'000) Share premium (£'000) Merger reserve (£'000) Ordinary shares (€'000) Share premium (€'000) Merger reserve (€'000)
10 Nov 2020 8,500,000 £0.50 850 3,400 - 987 3,949 -
25 Nov 2020 31,750,000 £1.00 3,175 28,575 - 3,689 33,192 -
20 May 2021 42,613,743 £1.55 4,261 49,113 12,677 4,951 57,040 14,734
Total 82,863,743 8,286 81,088 12,677 9,627 94,181 14,734
Note 20a: Share premium
€'000 31 December 2021
Share premium received in the period 94,181
Total share premium 94,181
Note 20b: Merger reserve
€'000 31 December 2021
Merger reserve arising on acquisition of Kistos NL1 and Kistos NL2 14,734
Total merger reserve 14,734
The merger reserve represents the difference between the value of shares
issued as part of the total consideration of the acquisition of Kistos NL1 and
the nominal value per share. Kistos plc has paid €15.75MM of the total
consideration by issuing 8,742,775 shares to Tulip Oil Holding at a price of
£1.55 per share. This created a merger reserve of €14.7MM.
Note 21: Hedge reserve
€'000 31 December 2021
Balance at the beginning of the year -
Cost of hedging deferred and recognised in OCI (11,781)
Deferred tax on hedge reserve in OCI 5,891
Total hedge reserve (5,890)
The hedging reserve represents the change in value of the hedged items
(production) discounted cash flows at the forward gas prices curve between
inception date, year end and fixed hedged instrument (100,000 MWh of
production) discounted cashflow. Amounts that are effective and realised have
been taken into the profit and loss account within gas sales (revenue). The
hedge ineffectiveness has been recorded in other financial expenses (see note
10). The hedge ineffectiveness has arisen from a greater level of production
downtime than initially forecast during a month resulting in a lower level of
production compared to the fixed hedge instrument. The hedge reserve has been
taxed at an effective rate of 50%.
Kistos NL2 held the following cash flow hedge at the balance sheet date:
Volume (MWh) Price Period of hedge
Cash flow hedge 300,000 €25 MWh Jan-Mar 22
The hedge is equally distributed over each month at 100,000 MWh.
Note 22: Translation reserve
€'000 31 December 2021
Translation reserve 382
The translation reserve comprises all foreign currency differences arising
from the translation of the financial statements of foreign operations, as
well as the effective portion of any foreign currency differences arising from
hedges of a net investment in a foreign operation.
Note 23: Proposed appropriation of result
The Group proposes to transfer the loss for the period of €40.1MM to
retained earnings in accordance with Article 137 of Articles of Association.
This article states that the profits are at the disposal of the shareholders.
Note 24: Abandonment provision
€'000 31 December 2021
Provisions at beginning of the period -
Acquisition of Kistos NL1 and NL2 14,158
Accretion expense 43
Additions 3,717
Utilisation (736)
Change in estimates and incurred liabilities (6)
Total abandonment provision at year end 17,176
Analysis of the abandonment provision:
Short term 1,272
Long term 15,904
Total abandonment provision 17,176
Abandonment provisions are determined using an inflation rate of 1.0% and a
discount rate of 0.5% in line with publicly available economic forecasts. The
additions in 2021 abandonment provision for Q11-B and well Q10-A04-S1 for
Kistos NL2 and Donkerbroek Hemrik for Kistos NL1. Utilisation relates to the
partial abandonment of the mainly relate an additional A04 drilling path. A
0.25% increase in the discount rate results in a €0.4MM decrease in the
abandonment provision.
Note 25: Bond payable
€'000 Bond €90MM Bond €60MM Bond costs Total
Opening balance - - - -
Acquisition of Kistos NL1 and NL2 (see note 14) 86,497 - (1,080) 85,417
Proceed from borrowings 3,000 60,000 - 63,000
Transaction cost modification - - (2,588) (2,588)
Amortisation of bond costs - - 700 700
Unwinding effective interest rate ('EIR') impact €87MM bond 502 - - 502
Unwinding EIR impact €90MM bond 391 - - 391
EIR impact non-substantial modification (2,348) - - (2,348)
Book value at 31.12.2021 88,042 60,000 (2,968) 145,074
During 2021, Kistos NL2 refinanced an existing €87MM bond with a new €90MM
bond which is denominated in € and runs from May 2021 to November 2024. The
bond modification calculation indicates that the modification is not
substantial and hence the difference between
the carrying value of the liability before the modification and the present
value of the cash flows after the modification has been recognised
(€2.35MM). The refinancing incurred a loss in the profit and loss account
(loss on redemption of €0.8MM) disclosed under net finance costs (see note
10). This loss arises from payments made on redeeming the bond loan of
€2.6MM, loss on release of the remaining discount carried on the bond prior
to redemption (€0.5MM) offset by non-cash movements related to the effective
interest rate (€2.3MM).
An additional €60MM bond that runs from May 2021 to May 2026, denominated in
€ with an interest rate of 9.15% per annum, was also issued in relation to
the acquisition of Kistos NL2 and Kistos NL1 by Kistos plc. The principal
falls due on May 2026 and interest is paid on a half yearly basis. Kistos NL1
and Kistos plc are Guarantors. Each guarantor irrevocably, unconditionally,
jointly and severally:
§ guarantees to the Bond Trustee the punctual performance by Kistos NL2 of
all obligations related to the Bonds;
§ agrees to make payment to the Bond Trustee on request in the event of
non-payment by Kistos NL2, together with any default interest; and
§ indemnifies the Bond Trustee against any cost, loss or liability incurred
in respect of the obligations of Kistos NL2.
Kistos NL2 has issued a security in favour of the Bond Trustee over its assets
for both the 2024 Bond and the 2026 Bond, including a pledge over all
intercompany receivables between Kistos NL2 and Kistos NL1 and Kistos plc. In
addition, a Netherlands Pledge has been provided to the Bond Trustee covering
all receivables of Kistos NL2 and Kistos plc.
The €87MM bond was originally issued at a 98% par value. The 2% discount on
the bond resulted in an unwinding of the bond discount to reach the par value
at maturity date. Interest on this bond was paid quarterly and funded in
advance in a restricted bank account.
Terms and repayment schedule
€'000 Currency Nominal interest rate Year of maturity Face value Carrying value
Secured bond € 8.75% 2024 90,000 88,042
Secured bond € 9.15% 2026 60,000 60,000
Total interest-bearing liabilities 150,000 148,042
Financial covenants
€90MM bond Value/range Unit
Issuer (Kistos NL2)
Minimum liquidity 10,000,000 At all times
Maximum leverage ratio 2.50 From and including 1 January 2022
Group (Kistos consolidated)
Minimum liquidity 20,000,000 At all times
Maximum leverage ratio 3.50 From and including 30 June 2021
€60MM bond Value/range Unit
Issuer (Kistos NL2)
Minimum liquidity 10,000,000 At all times
Maximum leverage ratio 2.50 From and including 1 January 2022
Group (Kistos consolidated)
Minimum liquidity 20,000,000 At all times
Maximum leverage ratio 3.50 From and including 30 June 2021
Kistos plc maximum leverage ratio 3.50:
On 31 December 2021, Kistos plc had a leverage ratio of 0.68 calculated as
follows:
Covenant calculation 2021
Kistos Group pro forma EBITDA for the year 2021 (see note 9) 102,862
Debt at 31 December 2021 (see note 25) 148,042
Cash and cash equivalents at 31 December 2021 (77,266)
Net debt at 31 December 2021 70,776
Leverage ratio (EBITDA/Net debt) 0.69
Note 26: Deferred tax liability
€'000 31 December 2021
Opening balance -
Acquisition balance (see note 14) 117,000
Profit and loss account (59,712)
At 31 December 2021 57,288
Following acquisition of Kistos NL1 and Kistos NL2, the fair value of the
deferred tax liability amounts to €117MM. The deferred tax liability is
calculated based on a 50% tax rate that is applied to the fair value uplift of
the intangibles assets. At 31 December 2021 the deferred tax liability has
been reduced by €59.7MM to account for the impairment booked on the
exploration and evaluation assets recorded within intangible assets.
Exploration licenses will be depreciated once classified as a producing asset.
Note 27: Trade payables and accrued expenses
€'000 31 December 2021
Trade payables 9,018
Other accrued expenses 14,461
Total trade payables and accrued expenses 23,479
Trade payables are unsecured and generally paid within 30 days. Accrued
expenses are also unsecured and represents estimates of expenses incurred but
where no invoice has yet been received. The carrying value of trade payables
and other accrued expenses are considered to be fair value given their
short-term nature.
Note 28: Other liabilities
€'000 31 December 2021
Bond interest payable 1,854
Hedge liability 11,781
Wage tax payable 76
Contingent consideration (see note 14) 15,000
Payroll liabilities 21
Right of use liability 91
Total other liabilities 28,823
Interest payable
The interest over the long-term bond is payable per half year. The balance of
€1.8MM presented as part of the other current liabilities relates to the
interest over the long-term bond payable as at year end.
Hedge liability
The hedge liability of €11,781 thousand represents the potential fair value
liability in respect of the cash flow hedge for the remaining period of the
contract. This is calculated by taking the delta in volumes between produced
and the fixed hedged item against future gas prices as determined using ICIS
forward gas prices and a discount factor based on remaining months.
Note 29: Financial instruments
Financial risk management objectives
The Group is exposed to a variety of risks including commodity price risk,
interest rate risk, credit risk, foreign currency risk and liquidity risk. The
use of derivative financial instruments (derivatives) is governed by the
Group's policies approved by the Kistos Board. Compliance with policies and
exposure limits are monitored and reviewed internally on a regular basis. The
Group does not enter into or trade financial instruments, including
derivatives, for speculative purposes.
Fair values of financial assets and liabilities
The Group considers the carrying value of all its financial assets and
liabilities to be materially the same as their fair value. The following table
shows the carrying amounts and fair values of financial assets and financial
liabilities, including their levels in the fair value hierarchy. It does not
include fair value information for financial assets and financial liabilities
not measured at fair value if the carrying amount is a reasonable
approximation of fair value:
€'000 Financial assets at amortised cost Other financial liabilities Fair value hierachy
Financial liabilities
Bond payable - 145,074 Level 3
Hedge liability - 11,781 Level 3
Total financial liabilities - 156,855
The Group has no material financial assets that are past due. No financial
assets are impaired at the balance sheet date.
Risk management framework
The Kistos Board has overall responsibility for the establishment and
oversight of the Group's risk management framework. The Kistos Board is
responsible for developing and monitoring the Group's risk management
policies.
The Group's risk management policies are established to identify and analyse
the risks faced by the Group, to set appropriate risk limits and controls but
also to monitor risks and adherence to limits. Risk management policies and
systems are reviewed when needed to reflect changes in market conditions and
the Group's activities. The Group aims to develop a disciplined and
constructive control environment in which all employees understand their roles
and obligations.
The Kistos Audit Committee oversees how management monitors compliance with
the Group's risk management policies and procedures and reviews the adequacy
of the risk management framework in relation to the risks faced by the Group.
Commodity price (market) risk
Market risk is the risk that changes in market prices (e.g. foreign exchange
rates, interest rates and equity prices) will affect the Company's profit and
loss account. The objective of material risk management is to manage and
control market risk exposures within acceptable parameters, while optimising
return.
During 2021 or 2020, the Company has not used derivatives to mitigate the
commodity price risk associated with its underlying oil and gas revenues.
Where such transactions are carried out, they are done based on the Company's
guidelines.
Cash flow hedge
During the first half of 2021, Kistos NL2 hedged its monthly production
(hedged item) at an amount of 100,000 MWh per month at a price of €25/MWh
(hedged instrument) for the nine- month period from July 2021 to March 2022.
Kistos NL2 engaged in this cash flow hedge to cover the potential volatility
of the gas price and the impact that this may have on its capital expenditure
programme. For one month during 2021, the hedge proved to be ineffective due
to a production shortfall greater than estimated at inception of the contract
and as a result a hedge ineffectiveness of €625 thousand has been recorded
under other finance costs (see note 10).
Cash flow and interest rate risk
The following table demonstrates the sensitivity of the Company's bond loan of
€90MM to reasonably possible movements in interest rates:
Effect on finance costs Effect on equity
€'000 Market movement 14 October 2020 to 31 December 2021 31 December 2021
Interest rate +10 basis points (90) 49
Interest rate -10 basis points 90 (49)
No sensitivity has been included on the €60MM loan as the arrangements put
in place are back-to-back and Kistos plc has no current intention of repaying
the loan.
Cash flow risk is the risk that the Group will encounter difficulty in meeting
the obligations associated with its financial liabilities that are settled by
delivering cash or another financial asset. The Group's approach to managing
cash flow is to currently utilise the funds residing as cash balances and the
cash generated from operations.
Expected credit loss assessment
The Group has a credit policy that governs the management of credit risk,
including the establishment of counterparty credit limits and specific
transaction approvals. The primary credit exposures for the Group are its
receivables generated by the marketing of gas and condensate and amounts due
from joint operators. These exposures are managed at the Group level. The
Group's oil and gas sales are predominantly made to international oil market
participants including the oil majors, trading houses and refineries. Joint
operators are predominantly international major oil and gas market
participants. Material counterparty evaluations are conducted utilising
international credit rating agency and financial assessments. Where considered
appropriate, security in the form of trade finance instruments from financial
institutions with appropriate credit ratings, such as letters of credit,
guarantees and credit insurance, are obtained to mitigate the risks.
Cash and cash equivalents
The Group held cash and cash equivalents of €77.3MM at 31 December 2021. The
cash and cash equivalents are held with bank and financial institution
counterparties which are rated at least A-.
Impairment on cash and cash equivalents has been measured on a 12-month
expected loss basis and reflects the short maturities of the exposures. The
Group considers that its cash and cash equivalents have low credit risk based
on external credit ratings of the counterparties.
The Group uses a similar approach for assessment of ECLs for cash and cash
equivalents to those used for debt securities.
The Group has not recognised an allowance for credit losses over cash and cash
equivalents in 2021.
Foreign currency risk
The Group conducts and manages its business predominately in euros, the
operating currency of the industry in which it operates. From time to time the
Group undertakes certain transactions denominated in other currencies. There
were no foreign currency financial derivatives in place at 31 December 2021.
As at 31 December 2021, there were no material monetary assets or liabilities
of the Group that were not denominated in the functional currency of the
respective subsidiaries.
The Group does not see material movements arising from foreign currency
fluctuations.
Liquidity risk
The Group manages its liquidity risk using both short- and long-term cash flow
projections, supplemented by debt financing plans and active portfolio
management. Ultimate responsibility for liquidity risk management rests with
the Kistos Board, which has established an appropriate liquidity risk
management framework covering the Group's short-, medium- and long-term
funding and liquidity management requirements.
Cash forecasts are regularly produced and sensitivities run for different
scenarios including, but not limited to, changes in commodity prices,
different production rates from the Group's producing assets and delays to
development projects. In addition to the Group's operating cash flows,
portfolio management opportunities are reviewed to potentially enhance the
financial capability and flexibility of the Group.
The Group's forecast, taking into account the risks described above, show that
the Group will be able to operate within its current debt facilities and have
sufficient financial headroom for the 12 months from the date of approval of
the 2021 Annual Report and Accounts.
The following table details the Group's remaining contractual maturity for its
non-derivative financial liabilities with agreed repayment periods. The tables
have been drawn up based on the undiscounted cash flows of financial
liabilities based on the earliest date on which the Group can be required to
pay.
€'000 Weighted average effective interest rate (%) 1-3 months 3 months to 1 year 1-5 years 5 years Total
31 December 2021
Bond €90MM 8.75 - - 88,042 - 88,042
Bond €60MM 9.15 - - 60,000 - 60,000
Other non-current liabilities - - - 31 - 31
Tax payable - - 14,980 - - 14,980
Other liabilities - 97 16,945 - - 17,042
Trade payables - 9,018 - - - 9,018
Total 9,115 31,925 148,073 - 189,113
Note 30: Related party transactions
Details of transactions between the Group and other related parties are
disclosed below.
Compensation of key management and key management personnel
The Directors of the Kistos Group and management personnel are the only key
management members as defined by IAS 24 - Related Party Disclosures. This
function of the Directors of Kistos NL1 and Kistos NL2 is provided by certain
management companies and staff employed by Kistos plc for which recharges to
the Group companies based on time spent are implemented.
The Group is wholly and directly controlled by Kistos plc. Transactions with
other related parties are set out below:
€'000 Transaction type 14 October 2020 to 31 December 2021
Key management Management fees 965
Directors of subsidiaries Management fees 42
Key management Loans 238
Outstanding balances receivable (payable) at end of year: Transaction type 31 December 2021
Directors of subsidiaries Management fees 7
Key management Loans 238
Note 31: Contingencies
As of 1 April 2021, Kistos NL1 and Kistos NL2 are part of a fiscal unity for
corporate income tax purposes where each entity is individually liable for the
tax payments. Kistos NL1 is the head of the fiscal unity. The fiscal unity
with Tulip Oil Holding B.V. ended on 31 March 2021.
At 31 December 2021, the drilling programme has not been completed. The
outstanding commitment at year end related to the drilling rig and associated
services amounts to €1.4MM.
Details of the contingent milestone considerations related to the acquisition
of Kistos NL1 can be found in note 13.
Note 32: Reconciliation of investing cash flows
€'000 Note 14 October 2020 to 31 December 2021
Additions and other movements to fixed assets 16 (23,930)
Non-cash abandonment (other movements)/additions 24 3,717
Capitalised interest 10 940
Movement in accruals and trade payables (685)
Acquisition of Kistos NL1 and Kistos NL2 14 (100,696)
Investing cash flow (120,654)
Note 33: Reconciliation of financing cash flows
€'000 Share capital Share premium & merger reserve Bond €90MM Bond €60MM Amortised bond costs Other non-current liabilities Other liabilities
Opening balance - - - - - - -
Acquisition balance - - 86,497 - (1,080) 110 2,438
Financing cash flows 9,627 92,815 3,000 60,000 (2,933) (79) (2,627)
Non-cash movements - 16,100 (1,455) - 1,045 - 28,634
At 31.12.2021 9,627 108,915 88,042 60,000 (2,968) 31 28,823
Cash outflow related to the bond redemption costs amounts to €2,627
thousand.
Note 34: Auditor's remuneration
During the year, the Group obtained the following services from the Group's
auditors:
€'000 31 December 2021
Audit fees
Audit of the consolidated and company financial statements (BDO LLP) 176
Audit of the financial statements of the subsidiaries (BDO Audit & 227
Assurance B.V.)
Non-audit fees
Due diligence services (BDO LLP) 240
Tax services (BDO LLP) 12
Tax services (KPMG Accountants N.V.) 10
Total 665
Note 35: Subsequent events
There are no adjusting events subsequent to the end of the year. The Q11-B
drilling campaign was completed post year end with the rig being safely moved
away from Q10-A in February 2022. The Q11-B drilling was targeting three main
reservoirs - Slochteren, Bunter and Zechstein. Prior to the end of the year,
the Slochteren was determined to be water bearing. After the year end
hydrocarbons were flowed from both the Bunter and the Zechstein resulting in
the well being suspended pending further development studies. Initial economic
analysis indicates that the book value at 31 December 2021 of Q11-B can be
recovered through a development.
The recent developments in Ukraine have no impact on the customer or supplier
base for Kistos NL2. The increase in the gas price has had a positive impact
on the revenue of the Company in 2022.
In March 2022, Kistos NL2 used the surplus cash on its balance sheet to
purchase €27.7MM of the €90MM bonds.
After the period end, on 31 January 2022, Kistos entered into an acquisition
agreement with TotalEnergies to acquire a 20% interest in the Greater Laggan
Area West of Shetland. Completion is subject to partner and OGA approval. The
consideration payable in respect of this transaction, which Kistos Group will
finance from internal resources, comprises cash of US$125MM (subject to
customary closing adjustments), and further contingent cash payments as
follows:
§ In the event the average day-ahead gas price at the National Balancing
Point exceeds 150p/ therm in 2022, up to US$40MM will be payable in January
2023.
§ Should Benriach be developed, Kistos will pay US$0.25 per MMBtu of net 2P
reserves after first gas.
Note 36: Significant accounting policies
The Group has consistently applied the following accounting policies to all
periods presented in these financial statements.
a) Basis of consolidation
(i) Subsidiaries
Subsidiaries are entities controlled by the Group. The Group 'controls' an
entity when it is exposed to, or has rights to, variable returns from its
involvement with the entity and has the ability to affect those returns
through its power over the entity. The financial statements of subsidiaries
are included in the consolidated financial statements from the date on which
control commences until the date on which control ceases.
(ii) Non-controlling interests
Non-controlling interests are measured initially at their proportionate share
of the acquiree's identifiable net assets at the date of acquisition.
Changes in the Group's interest in a subsidiary that do not result in a loss
of control are accounted for as equity transactions.
(iii) Transactions eliminated on consolidation
Intra-group balances and transactions, and any unrealised income and expenses
(except for foreign currency transaction gains or losses) arising from
intra-group transactions, are eliminated. Unrealised gains arising from
transactions with equity-accounted investees are eliminated against the
investment to the extent of the Group's interest in the investee.
Unrealised losses are eliminated in the same way as unrealised gains, but only
to the extent that there is no evidence of impairment.
b) Foreign currencies
Transactions in foreign currencies are translated into the respective
functional currencies of Group companies at the exchange rates on the dates of
the transactions.
Monetary assets and liabilities denominated in foreign currencies are
translated into the functional currency at the exchange rate at the reporting
date. Non-monetary assets and liabilities that are measured at fair value in a
foreign currency are translated into the functional currency at the exchange
rate when the fair value was determined. Non-monetary items that are measured
based on historical cost in a foreign currency are translated at the exchange
rate on the date of the transaction. Foreign currency differences are
generally recognised in profit or loss and presented within other operating
expenses or finance costs.
c) Revenue
Sales revenue represents the sales value, net of VAT, of the Group's share of
gas sales in the year. Revenue is recognised when goods are delivered and
title has passed.
Interest income is accrued on a time basis, by reference to the principal
outstanding and at the effective interest rate applicable, which is the rate
that exactly discounts estimated future cash receipts through the expected
life of the financial asset to that asset's net carrying amount.
d) Operating profit
Operating profit is the result generated from the continuing principal revenue
producing activities of the Group as well as other income and expenses related
to operating activities. Operating profit excludes net finance costs, share of
profit of equity accounted investees and income taxes.
e) Joint operations
The Group is engaged in oil and gas exploration, development and production
through unincorporated joint arrangements; these are classified as joint
operations in accordance with IFRS 11. The Group accounts for its share of the
assets, liabilities, revenue and expenses of these joint operations. In
addition, where Kistos acts as Operator to the joint operation, the gross
liabilities and receivables (including amounts due to or from non-operating
partners) of the joint operation are included in the Group's balance sheet.
f) Finance income and finance costs
Borrowing costs directly attributable to the acquisition, construction or
production of qualifying assets, which are assets that necessarily take a
substantial period of time to get ready for their intended use or sale, are
added to the cost of those assets, until such time as the assets are
substantially ready for their intended use or sale.
Finance costs of debt are allocated to periods over the term of the related
debt at a constant rate on the carrying amount. Arrangement fees and issue
costs are deducted from the debt proceeds on initial recognition of the
liability and are amortised and charged to the income statement as finance
costs over the term of the debt.
Interest income or expense is recognised using the effective interest method.
Dividend income is recognised in profit or loss on the date that the Group's
right to receive payment is established.
g) Taxation
Income tax expense represents the sum of the tax currently payable and
deferred tax. For purposes of corporate income tax, Kistos NL1 B.V. formed a
fiscal unity with its subsidiary Kistos NL2 B.V. as of 1 April 2021. The
companies are separately liable for tax and therefore account for their tax
charge/credit on a standalone basis after taking into account the effects of
horizontal compensation within the fiscal union that is applicable from 1
April 2021.
Current and deferred tax are provided at amounts expected to be paid using the
tax rates and laws that have been enacted or substantively enacted by the
balance sheet date.
Interest and penalties related to income taxes, including uncertain tax
treatments, are accounted for under IAS 37 Provisions, Contingent Liabilities
and Contingent Assets.
Current tax
Current tax comprises the expected tax payable or receivable on the taxable
income or loss for the year and any adjustment to tax payable or receivable in
respect of previous years. The
amount of current tax payable or receivable is the best estimate of the tax
amount expected to be paid or received that reflects uncertainty related to
income taxes, if any. It is measured using tax rates enacted or substantively
enacted at the reporting date. Current tax also includes any tax arising from
dividends.
Current tax assets and liabilities are offset only if certain criteria are
met.
Deferred tax
Deferred tax is recognised in respect of temporary differences between the
carrying amounts of assets and liabilities for financial reporting purposes
and the amounts used for taxation purposes. Deferred tax is not recognised
for:
§ Temporary differences on the initial recognition of assets or liabilities
in a transaction that is not a business combination and that affects neither
accounting nor taxable profit or loss;
§ Temporary differences related to investments in subsidiaries, associates
and joint arrangements to the extent that the Group is able to control the
timing of the reversal of the temporary differences and it is probable that
they will not reverse in the foreseeable future; and
§ Taxable temporary differences arising on the initial recognition of
goodwill.
Deferred tax assets are recognised for unused tax losses, unused tax credits
and deductible temporary differences to the extent that is probable that
future taxable profits will be available against which they can be used.
Future taxable profits are determined based on the reversal
of relevant taxable temporary differences. If the amount of taxable temporary
differences is insufficient to recognise a deferred tax asset in full, then
future taxable profits, adjusted for reversals of existing temporary
differences, are considered, based on business plans for
individual subsidiaries in the Group. Deferred tax assets are reviewed at each
reporting date and are reduced to the extent that it is no longer probable
that the related tax benefit will be realised; such reductions are reversed
when the probability of future taxable profits improves.
Unrecognised deferred tax assets are reassessed at each reporting date and
recognised to the extent that it has become probable that future taxable
profits will be available against which they can be used.
Deferred tax is measured at the tax rates that are expected to be applied to
temporary differences when they reverse, using tax rates enacted or
substantively enacted at the reporting date.
The measurement of deferred tax reflects the tax consequences that would
follow from the manner in which the Group expects, at the reporting date, to
recover or settle the carrying amount of its assets and liabilities.
Deferred tax assets and liabilities are offset only if certain criteria are
met.
h) Leases
At inception of a contract, the Group assesses whether a contract is, or
contains, a lease. A contract is, or contains, a lease if the contract conveys
the right to control the use of an identified asset for a period of time in
exchange for consideration.
As a lessee
At commencement or on modification of a contract that contains a lease
component, the Group allocates the consideration in the contract to each lease
component on the basis of its relative stand-alone prices. However, for the
leases of property the Group has elected not to separate non-lease components
and account for the lease and non-lease components as a single lease
component.
The Group recognises a right-of-use asset and a lease liability at the lease
commencement date. The right-of-use asset is initially measured at cost, which
comprises the initial amount of the lease liability adjusted for any lease
payments made at or before the commencement date, plus any initial direct
costs incurred and an estimate of costs to dismantle and remove
the underlying asset or to restore the underlying asset or the site on which
it is located, less any lease incentives received.
The right-of-use asset is subsequently depreciated using the straight-line
method from the commencement date to the end of the lease term, unless the
lease transfers ownership of the underlying asset to the Group by the end of
the lease term or the cost of the right-of-use asset reflects that the Group
will exercise a purchase option. In that case the right-of-use asset will be
depreciated over the useful life of the underlying asset, which is determined
on the same basis as those of property and equipment. In addition, the
right-of-use asset is periodically reduced by impairment losses, if any, and
adjusted for certain remeasurements of the lease liability.
The lease liability is initially measured at the present value of the lease
payments that are not paid at the commencement date, discounted using the
interest rate implicit in the lease or, if that rate cannot be readily
determined, the Group's incremental borrowing rate. Generally, the Group uses
its incremental borrowing rate as the discount rate.
The Group determines its incremental borrowing rate by obtaining interest
rates from various external financing sources and makes certain adjustments to
reflect the terms of the lease and type of the asset leased.
Lease payments included in the measurement of the lease liability comprise the
following: g fixed payments, including in-substance fixed payments;
§ variable lease payments that depend on an index or a rate, initially
measured using the index or rate as at the commencement date;
§ amounts expected to be payable under a residual value guarantee; and
§ the exercise price under a purchase option that the Group is reasonably
certain to exercise, lease payments in an optional renewal period if the Group
is reasonably certain to exercise an extension option, and penalties for early
termination of a lease unless the Group is reasonably certain not to terminate
early.
The lease liability is measured at amortised cost using the effective interest
method. It is remeasured when there is a change in future lease payments
arising from a change in an index or rate, if there is a change in the Group's
estimate of the amount expected to be payable under a residual value
guarantee, if the Group changes its assessment of whether it will exercise
a purchase, extension or termination option or if there is a revised
in-substance fixed lease payment.
When the lease liability is remeasured in this way, a corresponding adjustment
is made to the carrying amount of the right-of-use asset, or, is recorded in
profit or loss if the carrying amount of the right-of-use asset has been
reduced to zero.
The Group presents right-of-use assets that do not meet the definition of
investment property in 'property, plant and equipment' and lease liabilities
in 'loans and borrowings' in the balance sheet.
Short-term leases and leases of low-value assets
The Group has elected not to recognise right-of-use assets and lease
liabilities for leases of low- value assets (less than €5,000) and
short-term leases (period less than one year), including IT equipment. The
Group recognises the lease payments associated with these leases as an expense
on a straight-line basis over the lease term.
i) Inventory
Inventories, other than oil products, are stated at the lower of cost and net
realisable value. Cost is determined by the first in first-out method and
comprises direct purchase costs, costs of production and transportation and
manufacturing expenses. Net realisable value is determined by reference to
prices existing at the balance sheet date.
Oil product is stated at net realisable value and changes in net realisable
value are recognised in the income statement.
j) Intangible assets and goodwill
Recognition and measurement
Goodwill
Goodwill arising on the acquisition of subsidiaries is measured at cost less
accumulated impairment losses.
Other intangible assets
Other intangible assets, including customer relationships, patents and
trademarks, that are acquired by the Group and have finite useful lives are
measured at cost less accumulated amortisation and accumulated impairment
losses.
Amortisation is recognised on a straight-line basis over their estimated
useful lives. The estimated useful life and amortisation method are reviewed
at the end of each reporting period, with the effect of any changes in
estimate being accounted for on a prospective basis. Intangible assets with
indefinite useful lives that are acquired separately are carried at cost less
accumulated impairment losses.
Subsequent expenditure
Subsequent expenditure is capitalised only when it increases the future
economic benefits embodied in the specific asset to which it relates. All
other expenditure, including expenditure on internally generated goodwill and
brands, is recognised in profit or loss as incurred.
The Group allocates goodwill to cash-generating units (CGUs) or groups of CGUs
that represent the assets acquired as part of the business combination. The
fields (licences) within the Group are considered CGUs for the purposes of
impairment testing.
Goodwill is tested for impairment annually as at 31 December and when
circumstances indicate that the carrying value may be impaired.
Impairment is determined for goodwill by assessing the recoverable amount,
using the 'Value in Use' method, of each CGU (or group of CGUs) to which
goodwill relates. When the recoverable amount of the CGU is less than its
carrying amount, an impairment loss is recognised.
Impairment losses relating to goodwill cannot be reversed in future periods.
k) Exploration, evaluation and production assets
The Group adopts the successful efforts method of accounting for exploration
and evaluation costs. Pre-license costs are expensed in the period in which
they are incurred. All licence acquisition, exploration and evaluation costs
and directly attributable administration costs are initially capitalised by
well, field or exploration area, as appropriate. Interest payable is
capitalised insofar as it relates to specific project financing.
These costs are written off as exploration costs in the income statement
unless commercial reserves have been established or the determination process
has not been completed and there are no indications of impairment.
All field development costs are capitalised as property, plant and equipment.
Property, plant and equipment related to production activities are depreciated
in accordance with the Group's depreciation accounting policy.
Where the Company drills a sidetrack from an original well, the costs of the
original well are estimated and written off, if the well is not hydrocarbon
producing.
l) Commercial reserves
P1 developed producing and P2 reserves are estimates of the amount of oil and
gas that can be economically extracted from the Group's oil and gas assets.
The Group estimates its reserves using standard recognised evaluation
techniques. The estimate is reviewed at least annually by management and is
reviewed as required by independent consultants.
m) Depreciation based on depletion
All expenditure carried within each field is depreciated from the commencement
of production on a unit of production basis, which is the ratio of oil and gas
production in the period to the estimated quantities of commercial reserves at
the end of the period plus the production in the period, generally on a
field-by-field basis or by a Group of fields which are reliant on common
infrastructure. Costs used in the unit of production calculation comprise the
net book value of capitalised costs incurred to date. Changes in the estimates
of commercial reserves are dealt with prospectively.
Where there has been a change in economic conditions that indicates a possible
impairment in a discovery field, the recoverability of the net book value
relating to that field is assessed by comparison with the estimated discounted
future cash flows based on management's expectations of future oil and gas
prices and future costs.
In order to discount the future cash flows the Group calculates CGU-specific
discount rates. The discount rates are based on an assessment of the Group's
post-tax Weighted Average Cost of Capital (WACC). The post-tax WACC is
subsequently grossed up to a pre-tax rate.
Where there is evidence of economic interdependency between fields, such as
common infrastructure, the fields are grouped as a single CGU for impairment
purposes.
Where conditions giving rise to impairment subsequently reverse, the effect of
the impairment charge is also reversed as a credit to the income statement,
net of any amortisation that would have been charged since the impairment.
n) Provisions
Provisions are determined by discounting the expected future cash flows at a
pre-tax rate that reflects current market assessments of the time value of
money and the risks specific to the liability. The unwinding of the discount
is recognised as finance cost.
Onerous contracts
A provision for onerous contracts is measured at the present value of the
lower for the expected cost of terminating the contract and the expected net
cost of continuing with the contract which is determined based on incremental
costs necessary to fulfil the obligation under the contract. Before a
provision is established, the Group recognises any impairment loss on the
assets associated with that contract.
Abandonment provision
An abandonment provision for decommissioning is recognised in full when the
related facilities or wells are installed. A corresponding amount equivalent
to the provision is also recognised
as part of the cost of the related property, plant and equipment. The amount
recognised is the estimated cost of abandonment, discounted to its net present
value, and is reassessed each year in accordance with local conditions and
requirements.
Changes in the estimated timing of abandonment or abandonment cost estimates
are dealt with prospectively by recording an adjustment to the provision, and
a corresponding adjustment to property, plant and equipment. The unwinding of
the discount on the abandonment provision is included as a finance cost.
o) Property, plant and equipment
Recognition and measurement
Items of property, plant and equipment are measured at cost, which includes
capitalised borrowing costs less accumulated depreciation and any accumulated
impairment losses.
If significant parts of an item of property, plant and equipment have
different useful lives, then they are accounted for as separable items (major
components) of property, plant and equipment.
Any gain or loss on disposal of an item of property, plant and equipment is
recognised in the profit and loss account.
Subsequent expenditure
Subsequent expenditure is capitalised only when it is probable that the future
economic benefits associated with the expenditure will flow to the Group.
Depreciation
Depreciation is calculated to write-off the cost of items of property, plant
and equipment less their estimated residual values using the aforementioned
depreciation based on depletion accounting policy for all assets related to
oil and gas fields and straight-line method over the estimated useful lives
for all other property, plant and equipment. Depreciation is recognised in the
profit and loss account.
The estimated useful lives of property, plant and equipment depreciated using
the straight- line method is three to five years. Depreciation methods, useful
lives and residual values are reviewed at each reporting date and adjusted if
appropriate.
p) Employee benefits
Short-term employee benefits
Short-term employee benefits are expensed as the related service is provided.
A liability is recognised for the amount expected to be paid if the Group has
a present legal or constructive obligation to pay this amount as a result of
the past service provided by the employee and the obligation can be estimated
reliably.
Pension plans
The Group does not have any pension plans. Some employees are paid a pension
contribution as part of their remuneration and are responsible for organising
their pensions personally.
Termination benefits
Termination benefits are expensed at the earlier of when the Group can no
longer withdraw the offer of those benefits and when the Group recognises
costs for a restructuring. If benefits are not expected to be settled wholly
within 12 months of the end of the reporting period, then they are discounted.
q) Cash and cash equivalents
Cash and cash equivalents comprise cash at bank, demand deposits and other
short-term highly liquid investments that are readily convertible to a known
amount of cash and are subject to an insignificant risk of changes in value.
r) Effective interest method
The effective interest method is a method of calculating the amortised cost of
a financial asset and of allocating interest income over the relevant period.
The effective interest rate is the
rate that exactly discounts estimated future cash receipts (including all fees
on points paid or received that form an integral part of the effective
interest rate, transaction costs and other premiums or discounts) through the
expected life of the financial asset, or, where appropriate, a shorter period.
Income is recognised on an effective interest basis for debt instruments other
than those financial assets classified as at FVTPL.
s) Bond modification
When the Group exchanges with an existing lender one debt instrument into
another one with the substantially different terms, such exchange is accounted
for as an extinguishment of the original financial liability and the
recognition of a new financial liability. Similarly, the Group accounts for
substantial modification of terms of an existing liability or part of it as an
extinguishment of the original financial liability and the recognition of a
new liability. The terms are substantially different if the discounted present
fair value of the cash flows under the new terms, including any transaction
costs paid and discounted using the original
effective interest rate is at least 10 per cent different from the discounted
present value of the remaining cash flows of the original financial liability.
If the modification is not substantial, the difference between: (1) the
carrying amount of the liability including transaction costs before the
modification; and (2) the present value of the cash flows after modification
is recognised through the profit and loss account as a modification gain or
loss.
t) Financial Instruments
Recognition and Initial Measurement
Trade receivables, unbilled revenue and debt securities issued are initially
recognised when they are originated. All other financial assets and financial
liabilities are initially recognised when the Group becomes a party to the
contractual provisions of the instrument.
A financial asset (unless it is a trade receivable without a significant
financing component) or financial liability is initially measured at fair
value plus, for an item not at FVTPL, transaction costs that are directly
attributable to its acquisition or issue. A trade receivable without a
significant financing component is initially measured at the transaction
price.
Classification and Subsequent Measurement
Financial assets
On initial recognition, a financial asset is classified as measured at:
amortised cost; fair value through other comprehensive income (FVOCI) - debt
investment; FVOCI - equity investment; or FVTPL.
Financial assets are not reclassified subsequent to their initial recognition
unless the Group changes its business model for managing financial assets, in
which case all affected financial assets are reclassified on the first day of
the first reporting period following the change in the business model.
A financial asset is measured at amortised cost if it meets both of the
following conditions and is not designated as at FVTPL:
§ it is held within a business model whose objective is to hold assets to
collect contractual cash flows; and
§ its contractual terms give rise on specified dates to cash flows that are
solely payments of principal and interest on the principal amount outstanding.
A debt investment is measured at FVOCI if it meets both of the following
conditions and is not designated as at FVTPL:
§ it is held within a business model whose objective is achieved by both
collecting contractual cash flows and selling financial assets; and
§ its contractual terms give rise on specified dates to cash flows that are
solely payments of principal and interest on the principal amount outstanding.
On initial recognition of an equity investment that is not held for trading,
the Group may irrevocably elect to present subsequent changes in the
investment's fair value in OCI. This election is made on an
investment-by-investment basis.
All financial assets not classified as measured at amortised cost or FVOCI as
described above are measured at FVTPL. This includes all derivative financial
assets. On initial recognition, the Group may irrevocably designate a
financial asset that otherwise meets the requirements to be measured at
amortised cost or at FVOCI as at FVTPL if doing so eliminates or significantly
reduces an accounting mismatch that would otherwise arise.
Financial assets - Subsequent measurement and gains and losses:
§ Financial assets at FVTPL - These assets are subsequently measured at fair
value. Net gains and losses, including any interest or dividend income, are
recognised in profit or loss.
§ Financial assets at amortised cost - These assets are subsequently measured
at amortised cost using the effective interest method. The amortised cost is
reduced by impairment losses. Interest income, foreign exchange gains and
losses and impairment are recognised in profit or loss. Any gain or loss on
derecognition is recognised in profit or loss.
§ Debt investments at FVOCI - These assets are subsequently measured at fair
value. Interest income calculated using the effective interest method, foreign
exchange gains and losses and impairment are recognised in profit or loss.
Other net gains and losses are recognised in OCI. On derecognition, gains and
losses accumulated in OCI are reclassified to profit or loss.
§ Equity investments at FVOCI - These assets are subsequently measured at
fair value. Dividends are recognised as income in profit or loss unless the
dividend clearly represents a recovery of part of the cost of the investment.
Other net gains and losses are recognised in OCI and are never reclassified to
profit or loss.
Financial liabilities - Classification, subsequent measurement and gains and
losses
Financial liabilities are classified as measured at amortised cost or FVTPL. A
financial liability is classified as at FVTPL if it is classified as
held-for-trading, it is a derivative or it is designated as such on initial
recognition. Financial liabilities at FVTPL are measured at fair value and net
gains and losses, including any interest expense, are recognised in profit or
loss. Other financial liabilities are subsequently measured at amortised cost
using the effective interest method. Interest expense and foreign exchange
gains and losses are recognised in profit or loss. Any gain or loss on
derecognition is also recognised in profit or loss.
Derecognition
Financial assets
The Group derecognises a financial asset when:
§ the contractual rights to the cash flows from the financial asset expire;
or
§ it transfers the rights to receive the contractual cash flows in a
transaction in which either:
o substantially all of the risks and rewards of ownership of the financial
asset are transferred; or
o in which the Group neither transfers nor retains substantially all of the
risks and rewards of ownership and it does not retain control of the financial
asset.
The Group enters into transactions whereby it transfers assets recognised in
its balance sheet, but, retains either all of substantially all of the risks
and rewards of the transferred assets. In these cases, the transferred assets
are not derecognised.
Financial liabilities
The Group derecognises a financial liability when its contractual obligations
are discharged or cancelled or expire. The Group also derecognises a financial
liability when its terms are modified and the cash flows of the modified
liability are substantially different, in which case a new financial liability
based on the modified terms is recognised at fair value.
On derecognition of a financial liability, the difference between the carrying
amount extinguished and the consideration paid (including any non-cash assets
transferred or liabilities assumed) is recognised in the profit and loss
account.
Share capital - Ordinary shares
Incremental costs directly attributable to the issue of ordinary shares, net
of any tax effects, are recognised as a deduction from equity. Income tax
relating to transaction costs of an equity transaction is accounted for in
accordance with IAS12.
Derivative financial instruments and hedge accounting
The Group holds derivative financial instruments to hedge cash flow risk
exposures. Embedded derivatives are separated from the host contract and
accounted for separately if the host contract is not a financial asset and
certain criteria are met.
Derivatives are initially measured at fair value. Subsequent to initial
recognition, derivatives are measured at fair value, and changes therein are
generally recognised in profit or loss.
The Group designates certain derivatives as hedging instruments to hedge the
variability in cash flows associated with highly probable forecast
transactions arising from changes in commodity prices and certain derivatives
and non-derivative financial liabilities as hedges of foreign exchange risk on
a net investment in a foreign operation.
At inception of designated hedging relationships, the Group documents the risk
management objective and strategy for undertaking the hedge. The Group also
documents the economic relationship between the hedged item and the hedging
instrument, including whether the changes in cash flows of the hedged item and
hedging instrument are expected to offset each other.
The Group has adopted the Phase 2 amendments. When the basis for determining
the contractual cash flows of the hedged item or hedging instrument changes as
a result of interbank offered rate (IBOR) reform and therefore there is no
longer uncertainty arising about the cash flows of the hedged item or the
hedging instrument, the Group amends the hedge documentation of that hedging
relationship to reflect the change(s) required by IBOR reform. For this
purpose, the hedge designation is amended only to make one or more of the
following changes:
§ designating an alternative benchmark rate as the hedged risk;
§ updating the description of the hedged item, including the description of
the designated portion of the cash flows or fair value being hedged; or
§ updating the description of the hedging instrument.
The Group amends the description of the hedging instrument only if the
following conditions are met:
§ it makes a change required by IBOR reform by changing the basis for
determining the contractual cash flows of the hedging instrument or using
another approach that is economically equivalent to changing the basis for
determining the contractual cash flows of the original hedging instrument; and
§ the original hedging instrument is not derecognised.
The Group amends the formal hedge documentation by the end of the reporting
period during which a change required by IBOR reform is made to the hedged
risk, hedged item or hedging instrument. These amendments in the formal hedge
documentation do not constitute the discontinuation of the hedging
relationship or the designation of a new hedging relationship.
If changes are made in addition to those changes required by IBOR reform
described above, then the Group first considers whether those additional
changes result in the discontinuation of the hedge accounting relationship. If
the additional changes do not result in the discontinuation of the hedge
accounting relationship, then the Group amends the formal hedge documentation
for changes required by IBOR reform as mentioned above.
When the interest rate benchmark on which the hedged future cash flows had
been based is changed as required by IBOR reform, for the purpose of
determining whether the hedged future cash flows are expected to occur, the
Group deems that the hedging reserve recognised in OCI for that hedging
relationship is based on the alternative benchmark rate on which the hedged
future cash flows will be based.
Cash flow hedge
When a derivative is designated as a cash flow hedging instrument, the
effective portion of changes in the fair value of the derivative is recognised
in OCI and accumulated in the hedging reserve. The effective portion of
changes in the fair value of the derivative that is recognised in OCI is
limited to the cumulative change in fair value of the hedged item, determined
on a present value basis, from inception of the hedge. Any ineffective portion
of changes in the fair value of the derivative is recognised immediately in
profit or loss.
The Group designates only the change in fair value of the spot element of
forward exchange contracts as the hedging instrument in cash flow hedging
relationships. The change in fair value of the forward element of forward
exchange contracts (forward points) is separately accounted for as a cost of
hedging and recognised in a costs of hedging reserve within equity.
When the hedged forecast transaction subsequently results in the recognition
of a non-financial item such as inventory, the amount accumulated in the
hedging reserve and the cost of hedging reserve is included directly in the
initial cost of the non-financial item when it is recognised.
For all other hedged forecast transactions, the amount accumulated in the
hedging reserve and the cost of hedging reserve is reclassified to profit or
loss in the same period or periods during which the hedged expected future
cash flows affect profit or loss.
If the hedge no longer meets the criteria for hedge accounting or the hedging
instrument is sold, expires, is terminated or is exercised, then hedge
accounting is discontinued prospectively. When hedge accounting for cash flow
hedges is discontinued, the amount that has been accumulated in the hedging
reserve remains in equity until, for a hedge of a transaction resulting in the
recognition of a non-financial item, it is included in the non-financial
item's cost on its initial recognition or, for other cash flow hedges, it is
reclassified to profit or loss in the same period or periods as the hedged
expected future cash flows affect profit or loss.
If the hedged future cash flows are no longer expected to occur, then the
amounts that have been accumulated in the hedging reserve and the cost of
hedging reserve are immediately reclassified to profit or loss.
u) Impairment
Non-derivative financial assets
The Group recognises loss allowances for expected credit losses (ECLs) on:
§ financial assets measured at amortised cost; g debt investments measured at
FVOCI; and
§ contract assets.
The Group measures loss allowances at an amount equal to lifetime ECLs, except
for the following, which are measured at 12-month ECLs:
§ debt securities that are determined to have low credit risk at the
reporting date; and
§ other debt securities and bank balances for which credit risk (ie the risk
of default occurring over the expected life of the financial instrument) has
not increased significantly since initial recognition.
Loss allowances for trade receivables and contract assets are always measured
at an amount equal to lifetime ECLs.
When determining whether the credit risk of a financial asset has increased
significantly since initial recognition and when estimating ECLs, the Group
considers reasonable and supportable information that is relevant and
available without undue cost or effort. This includes both quantitative and
qualitative information and analysis, based on the Group's historical
experience and informed credit assessment and including forward-looking
information.
The Group assumes that the credit risk on a financial asset has increased
significantly if it is more than 30 days past due.
The Group considers a financial asset to be in default when:
§ the borrower is unlikely to pay its credit obligations to the Group in
full, without recourse by the Group to actions such as realising security (if
any is held); or
§ the financial asset is more than 90 days past due.
The Group considers a debt security to have low credit risk when its credit
risk rating is equivalent to the globally understood definition of 'investment
grade'.
Lifetime ECLs are the ECLs that result from all possible default events over
the expected life of a financial instrument. 12-month ECLs are the portion of
ECLs that result from default events that are possible within the 12 months
after the reporting date (or a shorter period if the expected life of the
instrument is less than 12 months).
The maximum period considered when estimating ECLs is the maximum contractual
period over which the Group is exposed to credit risk.
Measurement of ECLs
ECLs are a probability-weighted estimate of credit losses. Credit losses are
measured as the present value of all cash shortfalls (i.e. the difference
between the cash flows due to the entity in accordance with the contract and
the cash flows that the Group expects to receive). ECLs are discounted at the
effective interest rate of the financial asset.
Credit-impaired financial assets
At each reporting date, the Group assesses whether financial assets carried at
amortised cost and debt securities at FVOCI are credit-impaired. A financial
asset is 'credit-impaired' when one or more events that have a detrimental
impact on the estimated future cash flows of the financial asset have
occurred.
Evidence that a financial asset is credit-impaired includes the following
observable data: g Significant financial difficulty of the borrower or issuer;
§ A breach of contract such as a default or being more than 90 days past due;
§ The restructuring of a loan or advance by the Group on terms that the Group
would not consider otherwise;
§ It is probable that the borrower will enter bankruptcy or other financial
reorganisation; or g The disappearance of an active market for a security
because of financial difficulties.
Presentation of allowance for ECL in the balance sheet
Loss allowances for financial assets measured at amortised cost are deducted
from the gross carrying amount of the assets.
For debt securities at FVOCI, the loss allowance is charged to profit or loss
and is recognised in OCI.
Write-off
The gross carrying amount of a financial asset is written off when the Group
has no reasonable expectations of recovering a financial asset in its entirety
or a portion thereof. For individual customers, the Group has a policy of
writing off the gross carrying amount when the financial asset is 180 days
past due based on historical experience of recoveries of similar assets. For
corporate customers, the Group individually makes an assessment with respect
to the timing and amount of write-off based on whether there is a reasonable
expectation of recovery. The Group expects no significant recovery from the
amount written off. However, financial assets that are written off could still
be subject to enforcement activities in order to comply with the Group's
procedures for recovery of amounts due.
Non-financial assets
At each reporting date, the Group reviews the carrying amounts of its
non-financial assets to determine whether there is any indication of
impairment. If any such indication exists, then the asset's recoverable amount
is estimated. Goodwill is tested annually for impairment.
For impairment testing, assets are grouped together into the smallest group of
assets that generate cash inflows from continuing use that are largely
independent of the cash inflows of other assets or CGUs. Goodwill arising from
a business combination is allocated to CGUs or groups of CGUs that are
expected to benefit from the synergies of the combination.
The recoverable amount of an asset or CGU is the greater of its value in use
and its fair value less costs to sell. Value in use is based on the estimated
future cash flows, discounted to their present value using a pre-tax discount
rate that reflects current market assessments of the time value of money and
the risks specific to the asset or CGU.
An impairment loss is recognised if the carrying amount of an asset or CGU
exceeds its recoverable amount.
Impairment losses are recognised in profit or loss. They are allocated first
to reduce the carrying amount of any goodwill allocated to the CGU, and then
to reduce the carrying amounts of the other assets in the CGU on a pro rata
basis.
An impairment loss in respect of goodwill is not reversed. For other assets,
an impairment loss is reversed only to the extent that the asset's carrying
amount does not exceed the carrying amount that would have been determined,
net of depreciation or amortisation, if no impairment loss had been
recognised.
v) Fair value
'Fair value' is the price that would be received to sell an asset or paid to
transfer a liability in an orderly transaction between market participants at
the measurement date in the principal or, in its absence, the most
advantageous market to which the Group has access at that date. The fair value
of a liability reflects its non-performance risk.
A number of the Group's accounting policies and disclosures require the
measurement of fair values, for both financial and non-financial assets and
liabilities.
When one is available, the Group measures the fair value of an instrument
using the quoted price in an active market for that instrument. A market is
regarded as active if transactions for the asset or liability take place with
sufficient frequency and volume to provide pricing information on an ongoing
basis.
If there is no quoted price in an active market, then the Group uses valuation
techniques that maximise the use of relevant observable inputs and minimise
the use of unobservable inputs. The chosen valuation technique incorporates
all of the factors that market participants would take into account in pricing
a transaction.
If an asset or a liability measured at fair value has a bid price and an ask
price, then the Group measures assets and long positions at a bid price and
liabilities and short positions at an ask price.
The best evidence of the fair value of a financial instrument on initial
recognition is normally the transaction price - ie the fair value of the
consideration given or received. If the Group determines that the fair value
on initial recognition differs from the transaction price and the fair value
is evidenced neither by a quoted price in an active market for an identical
asset or liability nor based on a valuation technique for which any
unobservable inputs are judged to be insignificant in relation to the
measurement, then the financial instrument is initially measured
at fair value, adjusted to defer the difference between the fair value on
initial recognition and the transaction price. Subsequently, that difference
is recognised in profit or loss on an appropriate basis over the life of the
instrument but no later than when the valuation is wholly supported by
observable market data or the transaction is closed out.
w) Standards issued that are not effective
A number of new standards are effective for annual periods beginning after 1
January 2021 and earlier application is permitted; however, the Group has not
early adopted the new or amended standards in preparing these financial
statements.
A. Deferred Tax related to Assets and Liabilities arising from a Single
Transaction (Amendments to IAS 12). The amendments narrow the scope of the
initial recognition exemption to exclude transactions that give rise to equal
and offsetting temporary differences - e.g. leases and decommissioning
liabilities. The amendments apply for annual reporting periods beginning on or
after 1 January 2023. For leases and decommissioning liabilities, the
associated deferred tax asset and liabilities will need to be recognised from
the beginning of the earliest comparative period presented, with any
cumulative effect recognised as an adjustment to retained earnings or other
components of equity at that date. For all other transactions, the amendments
apply to transactions that occur after the beginning of the earliest period
presented.
The Group accounts for deferred tax on leases and decommissioning liabilities
applying the 'integrally linked' approach, resulting in a similar outcome to
the amendments, except that the deferred tax impacts are presented net in the
balance sheet. Under the amendments, the Group will recognise a separate
deferred tax asset and a deferred tax liability. There will be no impact on
retained earnings on adoption of the amendments.
B. Onerous contracts - Cost of Fulfilling a Contract (Amendments to IAS
37) .The amendments specify which costs an entity includes in determining the
cost of fulfilling a contract for the purpose of assessing whether the
contract is onerous. The amendments apply for annual reporting periods
beginning on or after 1 January 2022 to contracts existing at the date when
the amendments are first applied.
At the date of initial application, the cumulative effect of applying the
amendments is recognised as an opening balance adjustment to retained earnings
or other components of equity, as appropriate. The comparatives are not
restated. At 31 December 2021 the Group did not have any onerous contracts.
C. Other standards. The following new and amended standards are not
expected to have a significant impact on the Group's financial statements:
§ COVID-19-Related Rent Concessions beyond 30 June 2021 (Amendment to IFRS
16); g Annual improvements to IFRS Standards 2018-2020;
§ Property, Plant and Equipment: Proceeds before Intended Use (Amendments to
IAS 16); g Reference to Conceptual Framework (Amendments to IFRS 3);
§ Classification of Liabilities as Current or Non-current (Amendments to IAS
1); g IFRS 17 Insurance Contracts and amendments to IFRS 17 Insurance
Contracts;
§ Disclosure of Accounting Policies (Amendments to IAS 1 and IFRS Practice
Statement 2); and
§ Definition of Accounting Estimates (Amendments to IAS 8).
x) Operating segments
As the Group currently has only one revenue stream it does not recognise any
separate reportable segments.
Glossary
Adjusted EBITDA: The Board uses Adjusted EBITDA as a measure to assess the performance of the
Group. This measure excludes the effects of significant items of income and
expenditure which may have an impact on the quality of earnings such as
reversal of provisions and impairments when the impairment is the result of an
isolated non-recurring event.
Average realised oil/gas price Calculated as revenue divided by sales production for the period. Sales
production for the period may be different from production for the period.
Boe Barrels of oil equivalent.
Boepd Barrels of oil equivalent produced per day.
Company Kistos or Kistos plc.
Earnings per share Calculated as profit for the financial period divided by weighted average
number of shares for the period.
FID Final Investment Decision
Group Kistos plc and its subsidiaries.
NM(3) Normal cubic metres
ROU Right of use.
Unit opex Calculated as production costs divided by production.
Conversion factors
35.3 standard cubic feet (scf) in 1 normal cubic metre (Nm3)
5,560 scf in 1 barrel of oil equivalent (boe)
157.5 Nm3 in 1 boe
1.78 megawatt hours (MWh) in 1 boe
Independent auditor's report to the members of Kistos plc
Opinion on the financial statements
In our opinion:
• the financial statements give a true and fair view of the state of
the Group's and of the Parent Company's affairs as at 31 December 2021 and of
the Group's profit for the period from 14 October 2020 to 31 December 2021;
• the Group financial statements have been properly prepared in
accordance with international accounting standards in conformity with the
requirements of the Companies Act 2006;
• the Parent Company financial statements have been properly
prepared in accordance with international accounting standards in conformity
with the requirements of the Companies Act 2006 and as applied in accordance
with the provisions of the Companies Act 2006; and
• the financial statements have been prepared in accordance with the
requirements of the Companies Act 2006.
We have audited the financial statements of Kistos plc (the 'Parent Company')
and its subsidiaries (the 'Group') for the period ended 31 December 2021 which
comprise the Consolidated profit and loss account and Consolidated statement
of comprehensive income, the Consolidated balance sheet, the Consolidated
statement of changes in equity, the Consolidated statement of cash flow, notes
to the Consolidated financial statements, the Company balance sheet, the
Company changes in equity, the Company cash flow and notes to the company
financial statements, including a summary of significant accounting policies.
The financial reporting framework that has been applied in their preparation
is applicable law and international accounting standards in conformity with
the requirements of the Companies Act 2006 and, as regards the Parent Company
financial statements, as applied in accordance with the provisions of the
Companies Act 2006.
Basis for opinion
We conducted our audit in accordance with International Standards on Auditing
(UK) (ISAs
(UK)) and applicable law. Our responsibilities under those standards are
further described in the
Auditor's responsibilities for the audit of the financial statements section
of our report. We believe that the audit evidence we have obtained is
sufficient and appropriate to provide a basis for our opinion.
Independence
We remain independent of the Group and the Parent Company in accordance with
the ethical requirements that are relevant to our audit of the financial
statements in the UK, including the FRC's Ethical Standard as applied to
listed entities, and we have fulfilled our other ethical responsibilities in
accordance with these requirements.
Conclusions relating to going concern
In auditing the financial statements, we have concluded that the Directors'
use of the going concern basis of accounting in the preparation of the
financial statements is appropriate.
Our evaluation of the Directors' assessment of the Group and the Parent
Company's ability to continue to adopt the going concern basis of accounting
has been included in the key audit matters section below.
Based on the work we have performed, we have not identified any material
uncertainties relating to events or conditions that, individually or
collectively, may cast significant doubt on the Group and the Parent Company's
ability to continue as a going concern for a period of at least twelve months
from when the financial statements are authorised for issue.
Our responsibilities and the responsibilities of the Directors with respect to
going concern are described in the relevant sections of this report.
Overview
100% of Group profit before tax
Coverage 100% of Group revenue
100% of Group total assets
Period ended 31 December 2021
· Acquisition of Tulip Oil Netherlands
· Accounting for cashflow hedging contract
· Application of the Dutch Mining Act (Mijnbouwwet), state profit share
tax and marginal field investment allowance in the calculation of the tax
Key audit matters charge
· Carrying value of exploration and evaluation assets and related
goodwill
· Going concern
·
Group financial statements as a whole
Materiality
€4.6m based on 1.29% of Total Assets.
An overview of the scope of our audit
Our Group audit was scoped by obtaining an understanding of the Group and its
environment, including the Group's system of internal control, and assessing
the risks of material misstatement in the financial statements. We also
addressed the risk of Management override of internal controls, including
assessing whether there was evidence of bias by the Directors that may have
represented a risk of material misstatement.
In approaching the audit, we considered how the Group is organised and
managed.
We assessed there to be two significant components, being the Parent Company
(Kistos plc), and Kistos NL1 B.V., which is the Dutch sub-consolidation of the
Kistos NL1 B.V. and Kistos NL2 B.V. entities operating the Q10-A platform and
holding key exploration licenses including those pertaining to the Q11-B,
M10/M11 and Q10 Gamma fields. The remaining components were considered to be
non-significant and were subject to analytical review procedures by BDO UK.
The Parent Company was subject to a full scope audit by the Group auditor. A
full scope audit for Group reporting and statutory purposes was performed by a
BDO network firm in the Netherlands on the Kistos NL1 consolidated entity.
Our involvement with component auditors
For the work performed by component auditors, we determined the level of
involvement needed in order to be able to conclude whether sufficient
appropriate audit evidence has been obtained as a basis for our opinion on the
Group financial statements as a whole. Our involvement with component auditors
included the following:
· Planning meetings were held with the component auditor remotely,
following the distribution of detailed Group reporting instructions outlining
the minimum procedures to be performed over the significant areas of the
audit.
· An in-person meeting and site visit was held between BDO UK and the
component auditor in the early stages of the execution phase of the audit to
ensure appropriate oversight over the planning and execution work performed.
· A detailed review of the component audit file was undertaken, with
findings discussed with the component audit team, and component Management
where appropriate.
· Regular oversight meetings were held between senior members of the
Group and component audit teams to maintain appropriate levels of involvement
over all significant risk areas.
Key audit matters
Key audit matters are those matters that, in our professional judgement, were
of most significance in our audit of the financial statements of the current
period and include the most significant assessed risks of material
misstatement (whether or not due to fraud) that we identified, including those
which had the greatest effect on: the overall audit strategy, the allocation
of resources in the audit, and directing the efforts of the engagement team.
These matters were addressed in the context of our audit of the financial
statements as a whole, and in forming our opinion thereon, and we do not
provide a separate opinion on these matters. We in this case refers to the
Group audit team and BDO Netherlands.
Key audit matter How the scope of our audit addressed the key audit matter
Acquisition of Tulip Oil Netherlands. Note 2d, 2e and 13. The Group acquired Tulip Oil Netherlands B.V. (now Kistos NL1 B.V) as part of Our specific audit testing in this regard included:
a business combination, as the underlying transaction met the definition of
such a transaction under applicable accounting standards.
We reviewed the purchase agreement and associated legal documents, made
inquiries of Management and assessed the activities of Tulip Oil Netherlands
As part of the acquisition of Tulip Oil Netherlands B.V., the Group acquired B.V. to confirm the appropriateness of Management's accounting treatment for
100% of the underlying subsidiary, Tulip Oil Netherlands Offshore B.V. (now the transaction as
Kistos NL2 B.V.).
a business combination.
As part of the acquisition of the above entities, Kistos plc (Kistos) acquired
the entire issued and outstanding share capital of Tulip Oil Netherlands B.V., We assessed the validity of the date at which control passed to the Group
including a €90m bond issued by Kistos NL2 as part of the consideration paid based on the contractual terms and the status of conditions precedent for
in the transaction. completion.
The acquisition accounting involved making significant judgements and We assessed the independent expert's competence and capabilities and read
estimates including assessing the fair value of the consideration paid which their terms of engagement with the Group, to identify any matters that could
included contingent consideration and assigning fair values to the producing have affected their independence and objectivity or imposed scope limitations
and exploration assets acquired. Management used a third party independent upon them.
expert to assist in determining the fair value of the assets and liabilities
acquired, underpinning the enterprise valuation model. For these reasons we
considered it be a key audit matter.
We recalculated the fair value of consideration paid with support from our
internal valuations team. This included agreeing inputs to supporting
documents and challenging Management's assessment of the likelihood of the
linked developments impacting contingent consideration being pursued by
corroborating to Management's forecasts.
We evaluated Management's determination of the allocation of the consideration
to the assets and liabilities acquired in order to assess whether the fair
values were supportable by agreeing the Purchase Price Allocation (PPA) to
supporting calculations prepared by Management's expert.
We performed audit procedures over the opening balance sheet as at the date of
acquisition.
Key observations:
Based on the procedures performed, we found the judgments and estimates made
by Management in respect of the acquisition of Tulip Oil Netherlands to be
reasonable.
Accounting for cashflow hedging contract. Note 2e and 21. In order to ensure cashflows during the drilling campaign, Kistos entered into Our specific audit testing in this regard included:
an over-the-counter commodity forward contract, hedging monthly gas sales over
a nine month period from July 2021.
We inspected underlying hedging election documentation to ensure it was
appropriately maintained by the entity.
This hedge was designated as an accounting cashflow hedge at inception. We
consider hedging a relatively complex accounting treatment outside the normal
course of business of Kistos. The correct accounting treatment and valuation
is considered a key audit matter. We reviewed the underlying agreement to ensure that the accounting treatment
adopted reflects the nature and terms of the contract and is in accordance
with the applicable accounting standards.
We assessed management's valuation of derivatives and agreed inputs into the
calculation to quoted market prices.
Key observations:
Based on the procedures performed we concur with the calculated fair value of
the hedge liability and unrealised loss as at 31 December 2021.
Application of Dutch Oil & Gas taxation legislation. Note 2e, 12 and 36g. Income tax calculations are inherently more complex for upstream oil and gas Our specific audit testing in this regard included:
companies. due to the interaction of laws and regulations between 'corporate
income tax' and sector specific 'state profit share tax', as governed in the
Dutch Mining Act (Mijnbouwwet). The correct tax computations consequently
requires extensive and specialised knowledge. For this reason it was We added a BDO NL tax expert to our team (with significant experience of North
considered to be a key audit matter. Sea oil and gas clients) to review tax calculations and computations,
including the underlying application of the Dutch Mining Act. The audit team
agreed relevant items to tax computations and agreed that the calculations
were in line with IAS 12;
We obtained confirmations from management and the Company's tax adviser
regarding the completeness of the tax charge and related to deferred tax
assets and liabilities.
We reviewed available tax authority audit reports.
Key observations:
Based on the procedures performed, we found Managements applied tax treatment
to be reasonable in the context of the Dutch taxation legislation.
Carrying value of exploration and evaluation assets and related goodwill. Note Following the purchase price allocation performed on the acquisition of Tulip Our specific audit testing in this regard included:
2e, 15 and 36j. Oil Netherlands Offshore B.V, and Tulip Oil Netherlands B.V., the Group
reported exploration and evaluation ('E&E') assets of €144.9m and a
goodwill balance of €7.0m before impairment.
We considered the results of management's drilling activity and determined
that it was an impairment trigger as the results from drilling the Slochteren
reservoir were know in 2021.
In Q4 2021 and Q1 2022 the Group drilled and appraisal well of the Q11b
well. Although gas flowed from the Bunter and Zechstein formations, no gas
was encountered in the Slochteren reservoir, which was the primary target.
We obtained and agreed for mathematical accuracy the valuation model prepared
by Management for the E&E CGU and associated goodwill, as well as the
resultant impairment.
This result led to a €7.0m impairment of goodwill arising on the
acquisition, and a €112.8 million impairment of the underlying exploration
and evaluation assets.
We corroborated and challenged the assumptions used in the aforementioned
valuation model, including resource levels in the Bunter and Zechstein
reservoirs, production profile, capital and operating expenditures and forward
To determination the impairment required estimation and judgement of gas gas prices.
volumes, production profiles, gas prices, operating and capital costs. For
this reason it was considered to be a key audit matter.
We involved BDO's internal valuation experts to validate the discount rates
applied in the model.
We performed sensitivities on key inputs to the model where appropriate.
Key observations:
Based on the procedures performed, we found the judgments made by Management
to be reasonable in the context of the carrying value and impairment of
E&E assets and associated goodwill.
Going concern. Note 1b. We have highlighted going concern as a key audit matter as a result of the Our specific audit testing in this regard included:
estimates and judgements required by to be made by the Directors in their
going concern assessment and the effect on our audit strategy.
We obtained the Directors' base case cash flow forecast and agreed the
February 2022 cash position used in the cash flow forecast to bank statements.
The level of judgement and estimation uncertainty has arisen, because as
outlined in note 1b, the Group has announced plans to acquire a 20% interest
in the Greater Laggan Area, West of Shetland for initial consideration of
US$125 million (subject to customary closing adjustments) in Q2 2022, which We considered the reasonableness of key underlying assumptions of operations
Kistos plc will finance from cash flow from operations. based on 2021 and 2022 year to date actual results, external data, and market
commentary where applicable.
We considered the impact of the Group's planned post-year end cash acquisition
of an interest in the Greater Laggan Area operation. This included reading key
terms of the Sale and purchase agreement. As the effective transaction date is
1 January 2022, but the transaction, which is subject to regulatory and
partner consents, is not due to complete until Q2 2022 we also considered the
reasonableness of key underlying assumptions of the acquired operations from
the effective date based on 2021 and 2022 year to date actual results.
We tested the accuracy and the mechanics of the cash flow forecast model
prepared by the Directors and assessed their consistency with approved budgets
and Field Development Plans for existing assets and assets to be acquired, as
applicable.
We agreed and recalculated headroom on financial covenants linked to the
entity's outstanding bonds.
We obtained the Directors' reverse stress testing analysis which was performed
to determine the point at which liquidity breaks and considered whether such
scenarios, including significant reductions in commodity prices and production
were possible. This included assessing the Group's ability to walk away from
the acquisition of the Greater Laggan area.
Key observations:
Please refer to the conclusions relating to going concern section of our
report.
Our application of materiality
We apply the concept of materiality both in planning and performing our audit,
and in evaluating the effect of misstatements. We consider materiality to be
the magnitude by which misstatements, including omissions, could influence the
economic decisions of reasonable users that are taken on the basis of the
financial statements.
In order to reduce to an appropriately low level the probability that any
misstatements exceed materiality, we use a lower materiality level,
performance materiality, to determine the extent of testing needed.
Importantly, misstatements below these levels will not necessarily be
evaluated as immaterial as we also take account of the nature of identified
misstatements, and the particular circumstances of their occurrence, when
evaluating their effect on the financial statements as a whole.
Based on our professional judgement, we determined materiality for the
financial statements as a whole and performance materiality as follows:
Group financial statements Parent Company financial statements
2021 2021
Materiality €4,600,000 €1,600,000
Basis for determining materiality 1.29% of total assets 65% of Group materiality
Rationale for the benchmark applied The materiality has been based on total assets as the Group was not producing 65% of Group materiality given the assessment of the components' aggregation
for the full year. Furthermore, as the Group continues to expand and explore risk.
new gas fields, we consider total assets to be one of the principal
considerations for users of the financial statements.
Performance materiality €2,900,000 €1,040,000
Basis for determining performance materiality 65% of materiality. We considered a number of factors including the expected
total value of known and likely misstatements, and our knowledge of the
Group's internal controls.
Component materiality
We set materiality for the significant component of the Group based on a
percentage of 35% of Group materiality dependent on the size and our
assessment of the risk of material misstatement of that component. Component
materiality was €1,600,000. In the audit of the component, we further
applied performance materiality levels of 65% of the component materiality to
our testing to ensure that the risk of errors exceeding component materiality
was appropriately mitigated.
Reporting threshold
We agreed with the Audit Committee that we would report to them all individual
audit differences in excess of €92,000. We also agreed to report
differences below this threshold that, in our view, warranted reporting on
qualitative grounds.
Other information
The Directors are responsible for the other information. The other information
comprises the information included in the annual report and audited financial
statements other than the financial statements and our auditor's report
thereon. Our opinion on the financial statements does not cover the other
information and, except to the extent otherwise explicitly stated in our
report, we do not express any form of assurance conclusion thereon. Our
responsibility is to read the other information and, in doing so, consider
whether the other information is materially inconsistent with the financial
statements or our knowledge obtained in the course of the audit, or otherwise
appears to be materially misstated. If we identify such material
inconsistencies or apparent material misstatements, we are required to
determine whether this gives rise to a material misstatement in the financial
statements themselves. If, based on the work we have performed, we conclude
that there is a material misstatement of this other information, we are
required to report that fact.
We have nothing to report in this regard.
Other Companies Act 2006 reporting
Based on the responsibilities described below and our work performed during
the course of the audit, we are required by the Companies Act 2006 and ISAs
(UK) to report on certain opinions and matters as described below.
Strategic report and Directors' report In our opinion, based on the work undertaken in the course of the audit:
· the information given in the Strategic report and the Directors'
report for the financial year for which the financial statements are prepared
is consistent with the financial statements; and
· the Strategic report and the Directors' report have been prepared in
accordance with applicable legal requirements.
In the light of the knowledge and understanding of the Group and Parent
Company and its environment obtained in the course of the audit, we have not
identified material misstatements in the strategic report or the Directors'
report.
Matters on which we are required to report by exception We have nothing to report in respect of the following matters in relation to
which the Companies Act 2006 requires us to report to you if, in our opinion:
· adequate accounting records have not been kept by the Parent Company,
or returns adequate for our audit have not been received from branches not
visited by us; or
· the Parent Company financial statements are not in agreement with the
accounting records and returns; or
· certain disclosures of Directors' remuneration specified by law are
not made; or
· we have not received all the information and explanations we require
for our audit.
Responsibilities of Directors
As explained more fully in the Directors' responsibilities statement, the
Directors are responsible for the preparation of the financial statements and
for being satisfied that they give a true and fair view, and for such internal
control as the Directors determine is necessary to enable the preparation of
financial statements that are free from material misstatement, whether due to
fraud or error.
In preparing the financial statements, the Directors are responsible for
assessing the Group's and the Parent Company's ability to continue as a going
concern, disclosing, as applicable, matters related to going concern and using
the going concern basis of accounting unless the Directors either intend to
liquidate the Group or the Parent Company or to cease operations, or have no
realistic alternative but to do so.
Auditor's responsibilities for the audit of the financial statements
Our objectives are to obtain reasonable assurance about whether the financial
statements as a whole are free from material misstatement, whether due to
fraud or error, and to issue an auditor's report that includes our opinion.
Reasonable assurance is a high level of assurance, but is not a guarantee that
an audit conducted in accordance with ISAs (UK) will always detect a material
misstatement when it exists. Misstatements can arise from fraud or error and
are considered material if, individually or in the aggregate, they could
reasonably be expected to influence the economic decisions of users taken on
the basis of these financial statements.
Extent to which the audit was capable of detecting irregularities,
including fraud
Irregularities, including fraud, are instances of non-compliance with laws and
regulations. We design procedures in line with our responsibilities, outlined
above, to detect material misstatements in respect of irregularities,
including fraud. The extent to which our procedures are capable of detecting
irregularities, including fraud is detailed below:
· Holding discussions with Management, the Audit Committee, the
component auditor and component Management to understand the laws and
regulations relevant to the Group and the Parent Company. These include
elements of the financial reporting framework, tax legislation, Dutch Mining
Act, AIM listing rules, QCA corporate governance code and environmental
regulations;
· Holding discussions with Management and the audit committee to
consider any known or suspected instances of non-compliance with laws and
regulations, or fraud;
We assessed the susceptibility of the financial statements to material
misstatement, including fraud and considered the fraud risk areas to be
management override of controls, revenue recognition, accounting for business
combinations, asset retirement obligations (ARO), impairment of goodwill and
exploration and evaluation assets, and unauthorised payments.
Our procedures in addressing these risks at a Group, Parent Company and
component level included:
· Testing the appropriateness of journal entries made throughout the
period which met a specific risk-based criteria;
· Performing a detailed review of the Group's year end adjusting
entries and investigating any that appear unusual as to nature or amount;
· Assessing the judgements made by Management when making key
accounting estimates and judgements, and challenging Management on the
appropriateness of these judgments, specifically around key audit matters as
discussed above;
· Reviewing minutes from board meetings of those charged with
governance and RNS announcements to identify any instances of non-compliance
with laws and regulations;
· Performing a detailed review of the Group's consolidation entries,
and investigating any that appear unusual with regards to nature or amount to
corroborative evidence; and
We communicated relevant identified laws and regulations and potential fraud
risks to all engagement team members and remained alert to any indications of
fraud or non-compliance with laws and regulations throughout the audit.
We considered the engagement team's collective competence and capabilities to
identify or recognize non-compliance with the applicable laws and regulations
set out above.
We requested the component auditors communicate any instances of
non-compliance with laws and regulations that could give rise to a material
misstatement of the Group financial statements.
Our audit procedures were designed to respond to risks of material
misstatement in the financial statements, recognising that the risk of not
detecting a material misstatement due to fraud is higher than the risk of not
detecting one resulting from error, as fraud may involve deliberate
concealment by, for example, forgery, misrepresentations or through collusion.
There are inherent limitations in the audit procedures performed and the
further removed non-compliance with laws and regulations is from the events
and transactions reflected in the financial statements, the less likely we are
to become aware of it.
A further description of our responsibilities is available on the Financial
Reporting Council's website at: www.frc.org.uk/auditorsresponsibilities
(http://insite.bdo.co.uk/sites/audit/Documents/www.frc.org.uk/auditorsresponsibilities)
. This description forms part of our auditor's report.
Use of our report
This report is made solely to the Parent Company's members, as a body, in
accordance with Chapter 3 of Part 16 of the Companies Act 2006. Our audit
work has been undertaken so that we might state to the Parent Company's
members those matters we are required to state to them in an auditor's report
and for no other purpose. To the fullest extent permitted by law, we do not
accept or assume responsibility to anyone other than the Parent Company and
the Parent Company's members as a body, for our audit work, for this report,
or for the opinions we have formed.
Peter Acloque (Senior Statutory Auditor)
For and on behalf of BDO LLP, Statutory Auditor
United Kingdom
6 April 2022
BDO LLP is a limited liability partnership registered in England and Wales
(with registered number OC305127).
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