TIDMRKH
RNS Number : 7631U
Rockhopper Exploration plc
02 April 2019
2 April 2019
Rockhopper Exploration plc
("Rockhopper" or the "Company")
Full-year results for the year ended 31 December 2018
Rockhopper Exploration plc (AIM: RKH), the oil and gas
exploration and production company with key interests in the North
Falkland Basin and the Greater Mediterranean region, is pleased to
announce its audited results for the year ended 31 December
2018.
Highlights
Sea Lion Phase 1 development - securing senior debt funding
represents last major milestone to achievement of FID
-- Front End Engineering and Design completed in Q1 2019
-- Process to progress contractor LOIs to full agreements well advanced
-- Field Development Plan and Environmental Impact Statement
substantially agreed with the Falkland Islands Government - final
approval expected at sanction
-- Good progress made with the Falkland Islands Government on Sea Lion royalty and fiscal terms
-- Financing structure progressed - extensive due diligence and assurance process underway
-- Vendor financing - contractors have agreed to provide up to
US$400 million of funding for the project
-- Project momentum building with budget approved in Q3 2018 to
increase activity and expand the Operator's project development
team
Greater Mediterranean portfolio continues to deliver stable
production with exploration upside
-- Net working interest production averaged 1.1 kboepd in 2018
-- Multiple oil and gas discoveries as a result of the 2018
drilling campaign at Abu Sennan, Egypt
o Successful infill drilling and implementation of a water
injection programme at the Al Jahraa field to enhance production
and maximise recoverability
o Oil discovery in the Bahariya de-risks future exploration at
this level across the concession
Strong financial performance with continued focus on managing
costs
-- Revenue of US$10.6 million; operating costs US$4.6 million;
cash flow from operations US$5.4 million
-- Cash operating costs of US$11.7 per boe - maintaining a low cost base
-- Continued management of G&A costs - US$5.3 million - down over 50% since 2014
-- G&A costs covered by operating cash flows
-- Cash resources of US$40.4 million at 31 December 2018 and no debt
Corporate
-- International arbitration hearing in relation to Ombrina Mare took place in February 2019
-- Alison Baker appointed as Independent Non-Executive Director in September 2018
Outlook
-- Joint venture to submit formal senior debt funding
application on Sea Lion Phase 1 in Q2 2019
-- Outcome in relation to Ombrina Mare arbitration expected in
late Q3 or early Q4 2019 - seeking significant monetary damages
-- Active drilling campaign at Abu Sennan, Egypt with four wells planned during 2019
-- Appointment of Keith Lough as Non-Executive Chairman
following the retirement of David McManus at Company's forthcoming
AGM
-- Continued pursuit of new venture opportunities to supplement
production, enhance cash flow and strengthen balance sheet
Sam Moody, Chief Executive Officer of Rockhopper Exploration,
commented:
"Sea Lion has the potential to be transformational for
Rockhopper and the Falkland Islands as a whole. Securing funding is
the last remaining major milestone before Sea Lion can reach FID
and all efforts are focused on securing such financing to allow the
project to move into the development phase.
"The outcome of our international arbitration against the
Republic of Italy is expected later this year and following the
hearing in February we remain confident that we have strong
prospects of recovering very significant monetary damages.
"I would again like to thank David McManus for his efforts as
both a Director and latterly as Chairman, throughout a period in
which the Company undertook transactions in the Falklands and the
Mediterranean and continued to advance the world class Sea Lion
development."
Enquiries:
Rockhopper Exploration plc
Sam Moody - Chief Executive
Stewart MacDonald - Chief Financial Officer
Tel. +44 (0) 20 7390 0234 (via Vigo Communications)
Canaccord Genuity Limited (NOMAD and Joint Broker)
Henry Fitzgerald-O'Connor/James Asensio
Tel. +44 (0) 20 7523 8000
Peel Hunt LLP (Joint Broker)
Richard Crichton
Tel. +44 (0) 20 7418 8900
Vigo Communications
Patrick d'Ancona/Ben Simons
Tel. +44 (0) 20 7390 0234
Note regarding Rockhopper oil and gas disclosure
This announcement has been approved by Rockhopper's geological
staff which includes Lucy Williams (Geoscience Manager) who is a
Chartered Geologist, a Fellow of the Geological Society of London
and a Member of both the Petroleum Exploration Society of Great
Britain and American Association of Petroleum Geologists, with over
25 years of experience in petroleum exploration and management and
who is the qualified person as defined in the Guidance Note for
Mining, Oil and Gas Companies issued by the London Stock Exchange
in respect of AIM companies.
The information contained within this announcement is deemed by
the Company to constitute inside information as stipulated under
the Market Abuse Regulations (EU) No. 596/2014 ("MAR").
CHAIRMAN AND CHIEF EXECUTIVE OFFICER'S REPORT
Rockhopper's strategy is to build a well-funded, full-cycle,
exploration led E&P company.
Against a backdrop of volatile commodity prices, Rockhopper has
continued to balance the progression of its world-class Sea Lion
project in the North Falkland Basin with an ongoing focus on cost
control.
Sea Lion has the potential to be transformational for Rockhopper
and the Falkland Islands as a whole. Securing funding is the last
remaining major milestone before Sea Lion can reach FID and all
efforts are focused on securing such financing to allow the project
to move into the development phase.
In the Greater Mediterranean, our portfolio continues to meet
its primary objective, namely to provide a production and cash flow
base to fund our corporate and operating costs and support our
balance sheet.
We maintain ambitions to further expand our production base
thereby generating additional free cash flow to strengthen our
balance sheet and invest in future exploration or other
value-accretive growth opportunities both in the Falklands and
elsewhere.
Sea Lion Phase 1 - FEED completed; formal funding application to
be submitted Q2 2019
Material progress continues to be made across a range of
commercial, fiscal and funding matters as we work towards a final
investment decision on the Phase 1 development of the Sea Lion
field.
During 2018, FEED contracts were awarded for all the outstanding
elements of the project scope with a corresponding increase in
activity, expenditure and expansion of the Operator's project
development team. Although FEED concluded in March 2019 increased
activity levels are expected to be maintained throughout 2019 in
the lead up to project sanction. The process to agree fully termed
documentation for the provision of contractor services and vendor
finance is well advanced and letters of award will be issued as we
go through the sanction gate.
Engagement continues with the Falkland Islands Government
("FIG") on a range of environmental, fiscal and regulatory matters
with a view to obtaining the consents and agreements necessary to
be in a position to reach a final investment decision. Following
submission of a revised Field Development Plan ("FDP") to FIG in
March 2018, the FDP is considered substantially agreed. The
Environmental Impact Statement ("EIS") public consultation process
concluded in March 2018 with no material objections received. The
final EIS document has been submitted to FIG. Formal approval of
the EIS and FDP are expected at sanction.
Good progress has been made with FIG on the royalty and fiscal
terms which will apply to the first phase of development of the Sea
Lion field. A public consultation on a number of technical tax
matters associated with oil field development in the Falklands was
concluded in the third quarter of 2018 with a number of technical
amendments and clarifications being implemented. These amendments
and clarifications provided definition on a number of important
regulatory and tax matters which were critical to enabling the
project to progress.
The Sea Lion financing plan comprises funding elements including
senior project finance debt (likely involving a combination of
export credit financing and project bank funding), vendor financing
from contractors and equity from the joint venture. Rockhopper's
share of the joint venture equity is to be funded through the carry
arrangements with Premier. The joint venture continues to lead
engagement with a wide range of stakeholders to obtain the support
required to secure senior project finance debt, which represents
the core of the project's funding strategy. With initial debt
feasibility and structuring now progressed, the joint venture
expects to submit the Project Information Memorandum ("PIM") and
formal funding application during Q2 2019. On the vendor financing
side, the project contractors have undertaken an extensive due
diligence and assurance process and, subject to the finalisation of
documentation, have agreed to provide up to US$400 million of
funding for the project.
Greater Mediterranean portfolio continues to deliver stable
production with exploration upside
Our Greater Mediterranean portfolio continued to perform well
with production growth in Egypt broadly offsetting declining
production in Italy. Production during 2018 averaged 1.1 kboepd net
to Rockhopper, with operating cash flows again covering the Group's
G&A costs.
In June 2018, the Company announced the commencement of a
four-well drilling campaign across its Egyptian portfolio,
including three wells at Abu Sennan and one at El Qa'a Plain.
Whilst the Raya commitment well on the El Qa'a Plain concession
encountered good quality sands, no hydrocarbons were
encountered.
Within the Abu Sennan concession, successful infill oil
producers were drilled at Al Jahraa-6 and Al Jahraa-10 as well as a
successful exploration well at ASZ-1X. At Al Jahraa-6, success
occurred in both the primary objective, being the Abu Roach-C
reservoir, and with a new oil discovery in the deeper Bahariya
section. The Bahariya formation was subsequently put into
production and continues to make a meaningful contribution to
overall volumes from the concession.
During 2018 the Company continued to see a material improvement
in the payment situation in Egypt with a significant decline in
outstanding receivables owed by Egyptian General Petroleum
Corporation ("EGPC").
Corporate matters
Rockhopper commenced international arbitration proceedings
against the Republic of Italy in relation to the Ombrina Mare field
in March 2017. The hearing took place in early February 2019 in
Paris. Rockhopper continues to believe it has strong prospects of
recovering very significant monetary damages - on the basis of lost
profits - as a result of the Republic of Italy's breaches of the
Energy Charter Treaty. All costs associated with the arbitration
are funded on a non-recourse ("no win - no fee") basis from a
specialist arbitration funder.
As part of the Board's long-term succession planning, and having
served on the Board for nearly nine years, the past three as
Non-Executive Chairman, David McManus will be retiring as a
Director with effect from the Company's 2019 Annual General Meeting
("AGM"). David will be succeeded as Non-Executive Chairman by Keith
Lough, currently the Senior Independent Director and a
Non-Executive Director of the Company since January 2014.
In September 2018, Alison Baker was appointed as an Independent
Non-Executive Director. Alison has nearly 25 years' experience in
the provision of audit, capital markets and advisory services,
having led the UK and EMEA Oil and Gas practice at
PricewaterhouseCoopers and prior to that the Energy, Utilities and
Mining Assurance practice at Ernst & Young. Alison is currently
an Independent Non-Executive Director of KAZ Minerals PLC and
Centamin plc. Alison will replace Keith as Chairman of the Audit
and Risk Committee, also with effect from the 2019 AGM.
Accordingly, following the Company's 2019 AGM, the Board will
comprise six Directors - two Executive Directors and four
Non-Executive Directors, including the Chairman. However, as part
of the Board's long-term succession planning and given our
continued focus on corporate costs, the aim remains to further
reduce the size of the Board over time. In this regard, and as
previously announced, it is anticipated that Tim Bushell will step
down from the Board at or before the Company's AGM in 2020.
From 28 September 2018, all AIM companies are required to state
which recognised corporate governance code the Board has decided to
apply and to explain how the Company complies with that code.
Following a review of the alternative codes available, the Board
decided to adopt the Quoted Companies Alliance Corporate Governance
Code (the "QCA Code") and suitable disclosures will be made going
forward.
Following the conclusion of a formal tender process, the Board
has approved the proposed appointment of PricewaterhouseCoopers as
the Company's auditor for the financial year commencing 1 January
2019. This appointment is subject to approval by shareholders of
the Company at the 2019 AGM.
Outlook
Sea Lion has the potential to be transformational for Rockhopper
and all efforts remain focused on securing the requisite
stakeholder support and funding to allow sanction to occur.
With Brent oil prices currently above US$65 per barrel, the
economics for the Sea Lion project remain robust. It is in this
context that the Board remains confident that the requisite
stakeholder support and funding will be secured. Whilst PIM and
formal funding application submission represent a significant
milestone in the financing process, the timetable and process to
secure such funding remains outside our control.
The outcome of the international arbitration against the
Republic of Italy is expected later this year and following the
hearing in February we remain confident that we have strong
prospects of recovering very significant monetary damages.
Our Greater Mediterranean portfolio continues to provide the
necessary operating cash flow to fund corporate costs while
providing low-risk exploration upside opportunities. On a highly
selective basis, the Company will seek to further expand the
production base with the aim of generating additional free cash
flow to invest in future exploration and value-accretive growth
opportunities both in the Falklands and elsewhere.
David McManus Samuel Moody
Non-Executive Chairman Chief Executive Officer
1 April 2019
OPERATIONAL REVIEW
Sea Lion, North Falkland Basin
Rockhopper is the leading acreage holder in the North Falkland
Basin with a material working interest in all key licences.
The overall strategy to develop the North Falkland Basin remains
a phased development solution, starting with Sea Lion Phase 1,
which will develop approximately 220 mmbbls in PL032 (in which
Rockhopper has a 40% working interest). A subsequent Phase 2
development will develop a further 300 mmbbls from the remaining
resources in PL032 and the satellite accumulations in the north of
PL004 (in which Rockhopper has a 64% working interest). In
addition, there is a further 200 mmbbls of low risk, near field
exploration potential which could be included in either the Phase 1
or Phase 2 developments. Phase 3 will entail the development of the
Isobel/Elaine fan complex in the south of PL004, subject to further
appraisal drilling.
The resources in Sea Lion Phase 1 will be commercialised
utilising a conventional FPSO development scheme with approximately
23 subsea wells. Estimated gross capex to first oil remains US$1.5
billion. The Sea Lion financing plan comprises funding elements
including senior project finance debt, vendor financing from
contractors and equity from the joint venture. Rockhopper's share
of the joint venture equity is to be funded through the carry
arrangements with Premier.
Through 2017 and 2018, work focused on securing agreements with
key supply chain contractors and, as a result, LOIs have been
signed for the provision of key services, including the FPSO, the
drilling rig, well services, subsea production systems and
helicopter services, as well as vendor funding. The process to
convert the LOIs into fully termed executed contracts is well
advanced and letters of award will be issued as we go through the
sanction process.
Through 2018, discussions continued with FIG on a range of
fiscal, environmental and regulatory matters. Following the
submission of a revised draft FDP to FIG in early March 2018, the
FDP is now considered substantially agreed with a final FDP
submission expected in the lead-up to sanction. With the FDP and
EIS largely complete, a 42-day public consultation on the EIS
commenced in January 2018. No material objections were raised
through the consultation process and various comments identified
through the process have been addressed in the final EIS
submission. Engagement with FIG continues with a view to obtaining
the consents and agreements necessary to be in a position to reach
a final investment decision.
The Sea Lion Discovery Area is due to expire on 15 April 2020.
The submission of the final Field Development Plan for FIG approval
is expected before that date and therefore no further license
extension is currently thought to be required from FIG.
South and East Falkland Basin (100% working interest)
Through the acquisition of Falkland Oil and Gas ("FOGL") in
2016, Rockhopper acquired a 52% interest in Noble Energy operated
acreage to the South and East of the Falkland Islands. Following
the results of the Humpback well, Noble and Edison gave notice to
withdraw from this acreage and, as a result, during 2017 Rockhopper
became operator of the South and East Falkland Basin acreage with a
100% working interest. No outstanding financial or operational
commitments exist in relation to the Company's South and East
Falkland Basins' interests.
Abu Sennan, Egypt (22% working interest)
Production from the six development leases within the Abu Sennan
concession increased during 2018 with production during the period
averaging approximately 813 boepd net to Rockhopper (2017: 760
boepd).
In July 2018, Rockhopper was pleased to announce the
commencement of the 2018 drilling campaign on the Abu Sennan
concession which included the drilling of two development wells
("Al Jahraa-6" and "Al Jahraa-10"), one exploration well
("ASZ-1X"), and a water injection programme targeting the Al Jahraa
field.
Al Jahraa-6
The Al Jahraa-6 development well spudded on 4 July 2018 and
reached total depth of 3,935m MD (-3,623m tvdss) in the Kharita
Formation on 19 August 2018. Mudlogs indicated the presence of oil
in the Abu Roash C, D, E and G levels and the deeper exploration
target in the Bahariya Formation. The Bahariya formation was put on
test on 22 September 2018 and, after clean-up, is producing in
excess of 550 barrels of oil per day ("bopd") with a stable water
cut of 22%. This represents the first commercial oil production
from the Bahariya formation within the Abu Sennan concession. The
well has been completed to allow potential future production from
Abu Roash G and C levels. The Company believes that the Bahariya
discovery de-risks additional exploration targets at the same level
elsewhere in the concession.
Al Jahraa-10
The Al Jahraa-10 development well reached total depth on 16
October 2018 in the Abu Roash-F Formation. Oil pay was calculated
in the Abu Roash-C and Abu Roash-D levels. Following testing
operations, the well was brought into production from Abu Roash-C
at a rate of 130 bopd gross, and subject to further increase.
Upside potential exists in Abu Roash-D which is being evaluated for
possible acid stimulation.
ASZ-1X
Exploration well ASZ-1X located on Prospect S was spudded on 8
November 2018 and was the first of two commitment wells to be
drilled in the first phase of the new concession. An oil discovery
was made in the Abu Roash-C level. The award of a development lease
over the discovery has recently been approved by EGPC and
production has commenced.
Water injection
The water injection programme in Al Jahraa began on 14 July
2018. Injection rates have increased steadily over time, with an
accompanying reduction in wellhead pressure, indicating that
reservoir injectivity has become established. Injection rates into
the Al Jahraa-9 well are currently averaging approximately 2,000
barrels of water per day, which is sufficient to re-pressurise the
reservoir.
2019 drilling campaign
Following joint venture approval, an active drilling programme
has been agreed for 2019 including the drilling of one exploration
well (SW-ASH-1X), two in-fill oil producer wells (Al Jahraa-11 and
Al Jahraa-7) and a second water injection well on the Al Jahraa
field. Activity in 2019 continues the planned development programme
in the Al Jahraa field, as well as further exploration on the
concession.
The Al Jahraa-11 development well, the first in the 2019
programme, was spudded on 13 March 2019 and is targeting the AR-C
and Bahariya reservoirs. The well is expected to take approximately
two months to complete.
Guendalina, Italy (20% working interest)
Production decline at Guendalina continued to be broadly in line
with expectations during 2018 with production over the period
averaging approximately 30,000 standard cubic metres ("scm") per
day of gas net to Rockhopper (approximately 180 boe per day). Plant
availability over the period continued to be strong with production
from the side-track well in 2015 continuing to make a material
contribution to field production. Efforts continue with the
operator to manage declining production levels as well as reduce
operating costs.
Civita, Italy (100% working interest)
In February 2018, a depressurisation event occurred at the
Civita pipeline and, as a result, production was suspended.
Following remedial works and reinstatement of the pipeline,
production recommenced in July 2018 at pre-incident levels of
approximately 20,000 scm per day of gas (approximately 130 boe per
day).
As described later in the Financial Review, the Company agreed
in June 2017 the terms for the disposal of a package of non-core
interests in Italy, including the Civita field, to Cabot Energy
plc. However, following failure to satisfy all relevant conditions
precedent, including receipt of requisite regulatory approvals in
Italy, the Company and Cabot have mutually agreed not to proceed
with the transaction.
Monte Grosso, Italy (23% working interest)
Rockhopper transferred the operatorship of the Serra San Bernado
permit (which contains the Monte Grosso prospect) to Eni during
2016. Since that time, options for the design of a well on the
Monte Grosso prospect have been explored and work undertaken to
secure the permits and approvals required to drill a well.
However, on 12 February 2019, the Italian government introduced
certain further changes to oil and gas law through the "Sustainable
Energy Bill". These changes include, amongst other things, a
temporary suspension on exploration activities including the
drilling of exploration wells. Discussions are ongoing between the
Serra San Bernado joint venture partners to agree a forward
plan.
El Qa'a Plain, Egypt (25% working interest)
Exploration commitment well Raya-1X in the El Qa'a Plain
concession was spudded on 17 June 2018 and reached TD approximately
two weeks later. At the primary Nukhul Formation objective,
wireline logging confirmed the presence of good porosity sands,
although no hydrocarbons were encountered. The well has been
plugged and abandoned and the concession relinquished.
FINANCIAL REVIEW
Overview
During 2018, significant progress was made to advance and
execute the financing plan for the Sea Lion Phase 1 development.
Submission of the PIM and formal funding application for senior
project finance debt, expected in Q2 2019, represents a material
milestone in the funding process.
Our Greater Mediterranean portfolio continues to provide a
low-cost, short-cycle production base which has delivered strong
revenues and operating cash flows for the Company which have more
than covered the Group's G&A costs.
RESULTS SUMMARY
US$m (unless otherwise specified) 2018 2017
Production (kboepd) 1.1 1.2
Revenue 10.6 10.4
Cash operating costs 4.6 4.1
Recurring administrative expenses
("G&A") 5.3 5.3
Loss after tax (7.1) (6.1)
Cash in flow from operating activities 5.4 1.6
Cash resources 40.4 50.7
Net assets 415.3 420.6
Results for the year
For the year ended 31 December 2018, the Group reported revenues
of US$10.6 million and cash from operating activities of US$5.4
million.
Revenue
The Group's revenues of US$10.6 million (2017: $10.4 million)
during the year relate entirely to the sale of oil and natural gas
in the Greater Mediterranean (Egypt and Italy). The increase in
revenues from the comparable period reflects an increase in
realised oil and gas prices, offset by a modest reduction in
production (due to natural field decline at Guendalina and pipeline
issues at Civita).
Working interest production averaged approximately 1,064 boepd
during 2018, a small reduction over the comparable period (2017:
1,184 boepd).
During the year, the Group's gas production in Italy was sold
under short-term contract with an average realised price of Euro
0.25 per scm (2017: Euro 0.19 per scm), equivalent to US$8.2 per
thousand standard cubic feet ("mscf"). Gas is sold at a price
linked to the Italian "PSV" (Virtual Exchange Point) gas marker
price.
In Egypt, all of the Group's oil and gas production is sold to
EGPC. The average realised price for oil was US$68.4 per barrel, a
small discount to the average Brent price over the same period. Gas
is sold at a fixed price of US$2.65 per million British thermal
units ("mmbtu").
Operating costs
Cash operating costs, excluding depreciation and impairment
charges, amounted to US$4.6 million (2017: US$4.1 million). The
small increase in underlying cash operating costs is primarily due
to the costs associated with the development wells and water
injection programme being carried out at Abu Sennan as well as
incremental operating costs at Guendalina. Cash operating costs on
a per barrel of oil equivalent basis remain attractive at US$11.7
per boe.
The Group continues to manage corporate costs having achieved an
approximate 50% reduction in G&A cost, excluding non-recurring
expenses related to restructuring and acquisitions, since 2014.
G&A costs in 2018 amounted to US$5.3 million, flat with the
comparable year (2017: US$5.3 million).
Following the decision in February 2016 by the Ministry of
Economic Development not to award the Group a Production Concession
covering the Ombrina Mare field, in March 2017, the Group commenced
international arbitration proceedings against the Republic of
Italy. All costs associated with the arbitration are funded on a
non-recourse ("no win - no fee") basis from a specialist
arbitration funder.
Cash movements and capital expenditure
At 31 December 2018, the Group had cash resources of US$40.4
million (31 December 2017: US$50.7 million) and no debt.
Cash resources movements during the year:
US$m
----------------------------------------- -----
Opening cash balance (31 December 2017) 51
Revenues 11
Cost of sales (5)
Falkland Islands (11)
Greater Mediterranean (4)
Admin and miscellaneous (2)
Closing cash balance (31 December 2018) 40
----------------------------------------- -----
Falkland Islands spend of US$11.0 million relates primarily to
pre-development activities on Sea Lion (2017: US$6.7 million).
Spend in the Greater Mediterranean largely relates to the
Egyptian drilling campaigns at Abu Sennan and El Qa'a Plain.
Admin and miscellaneous includes G&A, foreign exchange,
movements in working capital balances as well as a non-recurring
VAT credit received during the period.
Impairment of oil and gas assets
Rockhopper has tested the carrying value of its assets for
impairment. Carrying values are compared to the value in use of the
assets based on discounted cash flow models. Future cash flows were
estimated using an oil price assumption equal to the Brent forward
curve during the period 2018 to 2020, with a long-term price of
US$70/bbl (in "real" terms) thereafter. A post-tax nominal discount
rate of 10% and 12.5% was used for the Group's Greater
Mediterranean and Falkland Islands assets respectively.
With no cash flow generation expected from Sea Lion until 2022
at the earliest, the impact of the Brent forward curve during the
period 2018 to 2020 on the fair value calculation is limited. As
such, no impairment arises on the Sea Lion project. A range of
sensitivities have been considered as part of the impairment
testing process. Even in the event of a US$20 per barrel reduction
in the Group's long-term oil price assumption, no impairment on Sea
Lion arises. Equally, no impairment would arise even if the Group
assumed project sanction was delayed by seven years.
Mergers, acquisitions and disposals
On 8 June 2017, Rockhopper announced the conditional disposal of
a portfolio of non-core interests onshore Italy to Northern
Petroleum Plc ("Northern"). Northern has subsequently undertaken a
corporate name change to Cabot Energy plc ("Cabot").
Following failure to satisfy all relevant conditions precedent,
including receipt of requisite regulatory approvals in Italy, the
Company and Cabot have mutually agreed not to proceed with the
transaction. As a result, Rockhopper retains the benefit of the
positive cash flows generated from the Civita portfolio which, had
the transaction proceeded, would have been paid to Cabot.
Taxation
On the 8 April 2015, the Group agreed binding documentation
("Tax Settlement Deed") with the FIG in relation to the tax arising
from the Group's farm out to Premier Oil.
The Tax Settlement Deed confirms the quantum and deferment of
the outstanding tax liability and is made under Extra Statutory
Concession 16.
As a result of the Tax Settlement Deed, the outstanding tax
liability was confirmed at GBP64.4 million and is payable on the
earlier of: (i) the first royalty payment date on Sea Lion; (ii)
the date of which Rockhopper disposes of all or a substantial part
of the Group's remaining licence interests in the North Falkland
Basin; or (iii) a change of control of Rockhopper Exploration
plc.
During the first half of 2017, as a result of the Group
receiving the full Exploration Carry from Premier during the
2015/16 drilling campaign, the Falkland Islands Commissioner of
Taxation agreed to reduce the tax liability in line with the terms
of the Tax Settlement Deed. As such, the tax liability has been
revised downwards to GBP59.6 million.
Due to the movement in the Sterling:US dollar exchange rate, the
outstanding tax liability in US dollar terms has reduced to US$76.1
million (31 December 2017: US$80.6 million). The outstanding tax
liability is classified as non-current and is discounted to a
year-end value of US$37.9 million.
Full details of the provisions and undertakings of the Tax
Settlement Deed were disclosed in the Group's 2014 Annual Report
and these include "creditor protection" provisions including
undertakings not to declare dividends or make distributions while
the tax liability remains outstanding (in whole or in part).
Brexit
It is the view of the Board that, given the Group's focus on the
North Falkland Basin and Greater Mediterranean region, Rockhopper's
business, assets and operations will not be materially affected by
Brexit. Rockhopper derives a significant proportion of its revenue
from crude oil, a globally traded commodity priced in US
dollars.
Liquidity, counterparty risk and going concern
The Group monitors its cash position, cash forecasts and
liquidity on a regular basis and takes a conservative approach to
cash management, with surplus cash held on term deposits with a
number of major financial institutions.
Following the Group's acquisition of production and exploration
assets in Egypt, the Group is exposed to potential payment delay
from EGPC, which is an issue which has historically been common to
many upstream companies operating in the country. As at 31 December
2018, Rockhopper's EGPC receivable balance was approximately US$1.3
million.
Cash forecasts are regularly produced based on, inter alia, the
Group's production and expenditure forecasts and management's best
estimates of future commodity prices. Sensitivities are run to
reflect different scenarios including changes in production rates,
possible reductions in commodity prices and increased costs.
Management's base case forecast assumes an oil price of US$65/bbl
in 2019 and 2020, production in line with prevailing rates and
expenditures in line with approved budgets. The Group has run
downside scenarios, where oil prices are reduced by a flat $10/bbl
throughout the going concern period and where cost expenditures
have increased by 5%.
Under the base case forecast and the downside scenarios run, the
Group will have sufficient financial headroom to meet forecast cash
requirements for the 12 months from the date of approval of the
2018 financial statements. However, beyond the 12 month going
concern assessment depending on the timing of sanction for the Sea
Lion development, in the absence of any mitigating actions, the
Group may have insufficient funds to meet its forecast cash
requirements.Potential mitigating actions could include non-core
asset disposals, collection of arbitration award proceeds, deferral
of expenditure or raising additional equity.
Accordingly, after making enquiries and considering the risks
described above, the Directors have assessed that the cash balance
held provides the Group with adequate headroom over forecasted
expenditure for the following 12 months - as a result, the
Directors have adopted the going concern basis of accounting in
preparing the annual financial statements.
Principal risk and uncertainties
A detailed review of the potential risks and uncertainties which
could impact the Group are outlined elsewhere in this Strategic
Report. The Group identified its principal risks at the end of 2018
as being:
> sustained low oil price;
> joint venture partner alignment and funding issues, both of
which could ultimately create a delay to the Sea Lion Final
Investment Decision; and
> insufficient liquidity and funding capacity in the event of
a protracted delay to the Sea Lion Final Investment Decision.
Stewart MacDonald
Chief Financial Officer
1 April 2019
Group income statement
for the YEAR ended 31 DeCEMBER 2018
Year Year
ended ended
31 Dec 18 31 Dec 17
Notes $'000 $'000
------------------------------------------------------------- ------ ------------ -----------
Revenue 10,580 10,401
------------------------------------------------------------- ------ ------------ -----------
Other cost of sales (4,563) (4,100)
Depreciation and impairment of oil and gas assets (3,968) (5,473)
------------------------------------------------------------- ------ ------------ -----------
Total cost of sales 4 (8,531) (9,573)
------------------------------------------------------------- ------ ------------ -----------
Gross profit/(loss) 2,049 828
Exploration and evaluation expenses 5 (5,014) (3,422)
------------------------------------------------------------- ------ ------------ -----------
Costs in relation to acquisition and group restructuring (58) -
Recurring administrative costs (5,328) (5,282)
------------------------------------------------------------- ------ ------------ -----------
Total administrative expenses 6 (5,386) (5,282)
Charge for share based payments 9 (1,478) (864)
Other income 943 -
Foreign exchange movement 10 1,208 (966)
Results from operating activities and other income (7,678) (9,706)
Finance income 11 825 783
Finance expense 11 (253) (39)
------------------------------------------------------------- ------ ------------ -----------
Loss before tax (7,106) (8,962)
Tax 12 (25) 2,823
------------------------------------------------------------- ------ ------------ -----------
LOSS FOR THE YEAR ATTRIBUTABLE TO THE
EQUITY SHAREHOLDERS OF THE PARENT COMPANY (7,131) (6,139)
------------------------------------------------------------- ------ ------------ -----------
Loss per share: cents
Basic 13 (1.57) (1.34)
Diluted 13 (1.57) (1.34)
------------------------------------------------------------- ------ ------------ -----------
All operating income and operating gains and losses relate to
continuing activities.
Group statement of comprehensive income
for the YEAR ended 31 DECEMBER 2018
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
------------------------------------------------ --------- --------
Loss for the year (7,131) (6,139)
Exchange differences on translation of foreign
operations 371 (1,151)
------------------------------------------------ --------- --------
TOTAL COMPREHENSIVE LOSS FOR THE YEAR (6,760) (7,290)
------------------------------------------------ --------- --------
Group balance sheet
as at 31 DECEMBER 2018
31 Dec 31 Dec
2018 2017
Notes $'000 $'000
--------------------------------------------- ------ ---------- ----------
NON CURRENT ASSETS
Exploration and evaluation assets 14 447,035 432,147
Property, plant and equipment 15 11,836 11,585
Goodwill 16 10,308 10,789
CURRENT ASSETS
Inventories 1,779 1,621
Other receivables 17 9,510 16,840
Restricted cash 18 568 540
Term deposits 19 30,000 30,000
Cash and cash equivalents 10,426 20,729
Assets held for sale 20 - 3,814
--------------------------------------------- ------ ---------- ----------
TOTAL ASSETS 521,462 528,065
--------------------------------------------- ------ ---------- ----------
CURRENT LIABILITIES
Other payables 21 15,148 12,772
NON-CURRENT LIABILITIES
Tax payable 22 37,860 40,057
Provisions 23 13,888 5,986
Deferred tax liability 24 39,223 39,202
Liabilities directly associated with assets
held for sale 20 - 9,450
--------------------------------------------- ------ ---------- ----------
TOTAL LIABILITIES 106,119 107,467
--------------------------------------------- ------ ---------- ----------
EQUITY
Share capital 25 7,205 7,200
Share premium 26 3,422 3,282
Share based remuneration 26 5,103 5,609
Own shares held in trust 26 (3,369) (3,383)
Merger reserve 26 74,332 74,332
Foreign currency translation reserve 26 (9,748) (10,119)
Special reserve 26 456,680 460,077
Retained losses 26 (118,282) (116,400)
--------------------------------------------- ------ ---------- ----------
ATTRIBUTABLE TO THE EQUITY SHAREHOLDERS OF
THE COMPANY 415,343 420,598
--------------------------------------------- ------ ---------- ----------
TOTAL LIABILITIES AND EQUITY 521,462 528,065
--------------------------------------------- ------ ---------- ----------
These financial statements were approved by the directors and
authorised for issue on 1 April 2019 and are signed on their behalf
by:
STEWART MACDONALD
CHIEF FINANCIAL OFFICER
Group statement of changes in equity
for the YEAR ended 31 DECEMBER 2018
Foreign
Shares currency
Share Share Share based held Merger translation Special Retained Total
capital premium remuneration in reserve reserve reserve losses Equity
trust
$'000 $'000 $'000 $'000 $'000 $'000 $'000 $'000 $'000
--------------- -------- -------- ------------- -------- -------- ------------ -------- ---------- ----------
Balance
at 31
December
2016 7,194 3,149 6,251 (3,407) 74,332 (8,968) 462,549 (114,106) 426,994
Total
comprehensive
loss for
the year - - - - - (1,151) - (6,139) (7,290)
Share based
payments - - 864 - - - - - 864
Share issues
in relation
to SIP 6 133 - (109) - - - - 30
Other
transfers - - (1,506) 133 - - (2,472) 3,845 -
Balance
at 31
December
2017 7,200 3,282 5,609 (3,383) 74,332 (10,119) 460,077 (116,400) 420,598
--------------- -------- -------- ------------- -------- -------- ------------ -------- ---------- ----------
Total
comprehensive
loss for
the year - - - - - 371 - (7,131) (6,760)
Share based
payments
(see note
9) - - 1,478 - - - - - 1,478
Share issues
in relation
to SIP 5 140 - (118) - - - - 27
Other
transfers - - (1,984) 132 - - (3,397) 5,249 -
Balance
at 31
December
2018 7,205 3,422 5,103 (3,369) 74,332 (9,748) 456,680 (118,282) 415,343
--------------- -------- -------- ------------- -------- -------- ------------ -------- ---------- ----------
Group cash flow statement
for the YEAR ended 31 DECEMBER 2018
Year Year
ended ended
31 Dec 31 Dec
18 17
Notes $'000 $'000
-------------------------------------------------- ------ --------- ---------
CASH FLOWS FROM OPERATING ACTIVITIES
Net loss before tax (7,106) (8,962)
Adjustments to reconcile net losses to cash:
Depreciation 15 4,111 5,687
Share based payment charge 9 1,478 864
Exploration impairment expenses 14 3,884 2,321
Finance expense 253 40
Finance income (825) (783)
Foreign exchange 10 (2,256) 3,331
-------------------------------------------------- ------ --------- ---------
Operating cash flows before movements in working
capital (461) 2,498
Changes in:
Inventories (23) -
Other receivables 7,029 (964)
Payables (103) 110
Movement on other provisions (1,012) (14)
-------------------------------------------------- ------ --------- ---------
Cash from/(utilised by) operating activities 5,430 1,630
-------------------------------------------------- ------ --------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES
Capitalised expenditure on exploration and
evaluation assets (13,940) (25,366)
Purchase of property, plant and equipment (1,844) (1,451)
Acquisition of Beach Egypt (658) (6,266)
Interest 750 566
Investing cash flows before movements in capital
balances (15,692) (32,517)
Changes in:
Restricted cash (28) (45)
Cash flow from investing activities (15,720) (32,562)
-------------------------------------------------- ------ --------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES
Share incentive plan 27 30
Finance expense (9) (43)
-------------------------------------------------- ------ --------- ---------
Cash flow from financing activities 18 (13)
-------------------------------------------------- ------ --------- ---------
Currency translation differences relating to
cash and cash equivalents (31) 655
Net cash flow (10,272) (30,945)
Cash and cash equivalents brought forward 20,729 51,019
-------------------------------------------------- ------ --------- ---------
CASH AND CASH EQUIVALENTS CARRIED FORWARD 10,426 20,729
-------------------------------------------------- ------ --------- ---------
Notes to the group financial statements
for the Year ended 31 DECEMBER 2018
1 Accounting policies
1.1 GROUP AND ITS OPERATIONS
Rockhopper Exploration plc, the 'Company', a public limited
company quoted on AIM, incorporated and domiciled in the United
Kingdom ('UK'), together with its subsidiaries, collectively 'the
'Group' holds certain exploration licences for the exploration and
exploitation of oil and gas in the Falkland Islands. In 2014, it
diversified its portfolio into the Greater Mediterranean through
the acquisition of an exploration and production company with
operations principally based in Italy and during 2016 augmented
this through the acquisition of exploration and production assets
in Egypt. The registered office of the Company is 4th Floor, 5
Welbeck Street, London, W1G 9YQ.
1.2 Statement of compliance
The consolidated financial statements are prepared in compliance
with International Financial Reporting Standards (IFRS) as adopted
by the European Union and applied in accordance with UK company
law. The consolidated financial statements were approved for issue
by the board of directors on 1 April 2019 and are subject to
approval at the Annual General Meeting of shareholders on 15 May
2019.
1.3 Basis of preparation
The results upon which these financial statements have been
based were prepared using the accounting policies set out below.
These policies have been consistently applied unless otherwise
stated.
These consolidated financial statements have been prepared under
the historical cost convention except, as set out in the accounting
policies below, where certain items are included at fair value.
Items included in the results of each of the Group's entities
are measured in the currency of the primary economic environment in
which that entity operates (the "functional currency").
All values are rounded to the nearest thousand dollars ($'000)
or thousand pounds (GBP'000), except when otherwise indicated.
1.4 change in accounting policy
Changes in accounting standards
In the current year new and revised standards, amendments and
interpretations were effective and are applicable to the
consolidated financial statements of the Group but did not affect
amounts reported in these financial statements.
At the date of authorisation of this report the following
standards and interpretations, which have not been applied in this
report, were in issue but not yet effective.
-- IFRS16 Leases (effective date for annual periods beginning on or after 1 January 2019);
Management does not believe that the application of this
standard will have a material impact on the financial
statements.
1.5 Going concern
At 31 December 2018, the Group had available cash and term
deposits of $40 million. In addition the first phase of the Group's
main development, Sea Lion, is fully funded from sanction through a
combination of Development Carries and a loan facility from the
operator.
The Group monitors its cash position, cash forecasts and
liquidity on a regular basis and takes a conservative approach to
cash management, with surplus cash held on term deposits with a
number of major financial institutions.
Following the Group's acquisition of production and exploration
assets in Egypt, the Group is exposed to potential payment delay
from EGPC, which is an issue which has historically been common to
many upstream companies operating in the country. As at 31 December
2018, Rockhopper's EGPC receivable balance was approximately US$1.3
million.
Cash forecasts are regularly produced based on, inter alia, the
Group's production and expenditure forecasts and management's best
estimates of future commodity prices. Sensitivities are run to
reflect different scenarios including changes in production rates,
possible reductions in commodity prices and increased costs.
Management's base case forecast assumes an oil price of US$65/bbl
in 2019 and 2020, production in line with prevailing rates and
expenditures in line with approved budgets. The Group has run
downside scenarios, where oil prices are reduced by a flat $10/bbl
throughout the going concern period and where cost expenditures
have increased by 5%.
Under the base case forecast and the downside scenarios run, the
Group will have sufficient financial headroom to meet forecast cash
requirements for at least the 12 months from the date of approval
of the 2018 financial statements.
However, beyond the 12 month going concern assessment depending
on the timing of sanction for the Sea Lion development, in the
absence of any mitigating actions, the Group may have insufficient
funds to meet its forecast cash requirements.
Potential mitigating actions could include non-core asset
disposals, collection of arbitration award proceeds, deferral of
expenditure or raising additional equity.
Accordingly, after making enquiries and considering the risks
described above, the Directors have assessed that the cash balance
held provides the Group with adequate headroom over forecasted
expenditure for the following 12 months - as a result, the
Directors have adopted the going concern basis of accounting in
preparing the annual financial statements.
1.6 Significant accounting policies
(a) Basis of accounting
The Group has identified the accounting policies that are most
significant to its business operations and the understanding of its
results. These accounting policies are those which involve the most
complex or subjective decisions or assessments, and relate to the
capitalisation of exploration expenditure. The determination of
this is fundamental to the financial results and position and
requires management to make a complex judgment based on information
and data that may change in future periods.
Since these policies involve the use of assumptions and
subjective judgments as to future events and are subject to change,
the use of different assumptions or data could produce materially
different results. The measurement basis that has been applied in
preparing the results is historical cost with the exception of
financial assets, which are held at fair value.
The significant accounting policies adopted in the preparation
of the results are set out below.
(b) Basis of consolidation
The consolidated financial statements include the results of
Rockhopper Exploration plc and its subsidiary undertakings to the
balance sheet date. Where subsidiaries follow differing accounting
policies from those of the Group, those accounting policies have
been adjusted to align with those of the Group. Inter-company
balances and transactions between Group companies are eliminated on
consolidation, though foreign exchange differences arising on
inter-company balances between subsidiaries with differing
functional currencies are not offset.
(c) Segmental reporting
Operating segments are reported in a manner consistent with the
internal reporting provided to the chief operating decision maker
as required by IFRS8 Operating Segments. The chief operating
decision maker, who is responsible for allocating resources and
assessing performance of the operating segments, has been
identified as the board of directors.
The Group's operations are made up of three segments, the oil
and gas exploration and production activities in the geographical
regions of the Falkland Islands and the Greater Mediterranean
region as well as its corporate activities centered in the UK.
(d) Oil and Gas Assets
The Group applies the successful efforts method of accounting
for exploration and evaluation ("E&E") costs, having regard to
the requirements of IFRS6 - 'Exploration for and evaluation of
mineral resources'.
Exploration and evaluation ("E&E") expenditure
Expensed exploration & evaluation costs
Expenditure on costs incurred prior to obtaining the legal
rights to explore an area, geological and geophysical costs are
expensed immediately to the income statement.
Capitalised intangible exploration and evaluation assets
All directly attributable E&E costs are initially
capitalised in well, field, prospect, or other specific, cost pools
as appropriate, pending determination.
Treatment of intangible E&E assets at conclusion of
appraisal activities
Intangible E&E assets related to each cost pool are carried
forward until the existence, or otherwise, of commercial reserves
have been determined, subject to certain limitations including
review for indicators of impairment. If commercial reserves have
been discovered, the carrying value, after any impairment loss, of
the relevant E&E assets, are then reclassified as development
and production assets within property plant and equipment. However,
if commercial reserves have not been found, the capitalised costs
are charged to expense.
The Group's definition of commercial reserves for such purpose
is proved and probable reserves on an entitlement basis. Proved and
probable reserves are the estimated quantities of crude oil,
natural gas and natural gas liquids which geological, geophysical
and engineering data demonstrate with a specified degree of
certainty (see below) to be recoverable in future years from known
reservoirs and which are considered commercially producible. There
should be a 50% statistical probability that the actual quantity of
recoverable reserves will be more than the amount estimated as
proved and probable. The equivalent statistical probabilities for
the proven component of proved and probable reserves are 90%.
Such reserves may be considered commercially producible if
management has the intention of developing and producing them and
such intention is based upon:
- a reasonable assessment of the future economics of such
production;
- a reasonable expectation that there is a market for all or
substantially all the expected hydrocarbon production;
- evidence that the necessary production, transmission and
transportation facilities are available or can be made available;
and
- the making of a final investment decision.
Furthermore:
(i) Reserves may only be considered proved and probable if
producibility is supported by either actual production or a
conclusive formation test. The area of reservoir considered proved
includes: (a) that portion delineated by drilling and defined by
gas-oil and/or oil-water contacts, if any, or both; and (b) the
immediately adjoining portions not yet drilled, but which can be
reasonably judged as economically productive on the basis of
available geophysical, geological and engineering data. In the
absence of information on fluid contacts, the lowest known
structural occurrence of hydrocarbons controls the lower proved
limit of the reservoir.
(ii) Reserves which can be produced economically through
application of improved recovery techniques (such as fluid
injection) are only included in the proved and probable
classification when successful testing by a pilot project, the
operation of an installed programme in the reservoir, or other
reasonable evidence (such as, experience of the same techniques on
similar reservoirs or reservoir simulation studies) provides
support for the engineering analysis on which the project or
programme was based.
Development and production assets
Development and production assets, classified within property,
plant and equipment, are accumulated generally on a field-by-field
basis and represent the costs of developing the commercial reserves
discovered and bringing them into production, together with the
E&E expenditures incurred in finding commercial reserves
transferred from intangible E&E assets.
Depreciation of producing assets
The net book values of producing assets are depreciated
generally on a field-by-field basis using the unit-of-production
method by reference to the ratio of production in the year and the
related commercial reserves of the field, taking into account the
future development expenditure necessary to bring those reserves
into production.
Disposals
Net cash proceeds from any disposal of an intangible E&E
asset are initially credited against the previously capitalised
costs. Any surplus proceeds are credited to the income
statement.
Decommissioning
Provision for decommissioning is recognised in full when the
related facilities are installed. The amount recognised is the
present value of the estimated future expenditure. A corresponding
amount equivalent to the provision is also recognised as part of
the cost of the related oil and gas property. This is subsequently
depreciated as part of the capital costs of the production
facilities. Any change in the present value of the estimated
expenditure is dealt with prospectively as an adjustment to the
provision and the oil and gas property. The unwinding of the
discount is included in finance cost.
(E) Capital commitments
Capital commitments include all projects for which specific
board approval has been obtained up to the reporting date. Projects
still under investigation for which specific board approvals have
not yet been obtained are excluded.
(F) Foreign currency translation
Functional and presentation currency:
Items included in the results of each of the Group's entities
are measured using the currency of the primary economic environment
in which the entity operates, the functional currency. The
consolidated financial statements are presented in US$ as this best
reflects the economic environment of the oil exploration sector in
which the Group operates. The Group maintains the accounts of the
parent and subsidiary undertakings in their functional currency.
Where applicable, the Group translates subsidiary accounts into the
presentation currency, US$, using the closing rate method for
assets and liabilities which are translated at the rate of exchange
prevailing at the balance sheet date and rates at the date of
transactions for income statement accounts. Differences are taken
directly to reserves.
Transactions and balances:
Foreign currency transactions are translated into the functional
currency using the exchange rates prevailing at the dates of the
transactions. Foreign exchange gains and losses resulting from the
settlement of such transactions and from the translation at year
end exchange rates of monetary assets and liabilities denominated
in foreign currencies are capitalised in the income statement,
except when deferred in equity as qualifying cash flow hedges and
qualifying net investment hedges.
The period end rates of exchange actually used were:
31 Dec 2018 31 Dec 2017
----------- ------------ ------------
GBP : US$ 1.28 1.35
EUR : US$ 1.15 1.20
----------- ------------ ------------
(g) Revenue and income
(i) Revenue
Revenue arising from the sale of goods is recognised when
control over a product or service is transferred to a customer,
which is typically at the point that title passes, and the revenue
can be reliably measured. Revenue is measured at the fair value of
the consideration received or receivable and represents amounts
receivable for goods provided in the normal course of business, net
of discounts, customs duties and sales taxes.
(ii) Investment income
Investment income consists of interest receivable for the
period. Interest income is recognised as it accrues, taking into
account the effective yield on the investment.
(h) NON-DERIVATIVE Financial instruments
Financial assets and financial liabilities are recognised on the
Group's balance sheet when the Group has become a party to the
contractual provisions of the instrument.
(i) Other receivables
Other receivables are classified as loans and receivables and
are initially recognised at fair value. They are subsequently
measured at their amortised cost using the effective interest
method less any provision for impairment. A provision for
impairment is made where there is objective evidence that amounts
will not be recovered in accordance with original terms of the
agreement. A provision for impairment is established when the
carrying value of the receivable exceeds the present value of the
future cash flow discounted using the original effective interest
rate. The carrying value of the receivable is reduced through the
use of an allowance account and any impairment loss is recognised
in the income statement.
(ii) Term deposits
Term deposits are disclosed separately on the face of the
balance sheet when their term is greater than three months and they
are unbreakable.
(iii) Restricted cash
Restricted cash is disclosed separately on the face of the
balance sheet and denoted as restricted when it is not under the
exclusive control of the Group.
(iv) Cash and cash equivalents
Cash and cash equivalents comprise cash in hand and at bank and
other short-term deposits held by the Group including breakable and
unbreakable deposits with terms of less than three months and
breakable term deposits of greater terms than three months where
amounts can be accessed within three months without material loss.
They are stated at carrying value which is deemed to be fair
value.
(v) Financial liabilities and equity
Financial liabilities and equity instruments are classified
according to the substance of the contractual arrangements entered
into. An equity instrument is any contract that evidences a
residual interest in the assets of the Group after deducting all of
its liabilities.
(vi) Account and other payables
Account payables are initially recognised at fair value and
subsequently at amortised cost using the effective interest
method.
(vii) Equity instruments
Equity instruments issued by the Company are recorded at the
proceeds received, net of direct issue costs.
(I) INCOME TAXES AND DEFERRED TAXATION
The current tax expense is based on the taxable profits for the
period, after any adjustments in respect of prior years. Tax,
including tax relief for losses if applicable, is allocated over
profits before tax and amounts charged or credited to reserves as
appropriate.
Deferred taxation is recognised in respect of all taxable
temporary differences that have originated but not reversed at the
balance sheet date where a transaction or events have occurred at
that date that will result in an obligation to pay more, or a right
to pay less or to receive more, tax, with the exception that
deferred tax assets are recognised only to the extent that the
directors consider that it is probable that there will be suitable
taxable profits from which the future reversal of the underlying
temporary differences can be deducted.
Deferred tax is measured on an undiscounted basis at the tax
rates that are expected to apply in the periods in which temporary
differences reverse, based on tax rates and laws enacted or
substantively enacted at the balance sheet date.
(j) Share based remuneration
The Group issues equity settled share based payments to certain
employees. Equity settled share based payments are measured at fair
value (excluding the effect of non market based vesting conditions)
at the date of grant. The fair value determined at the grant date
of the equity settled share based payments is expensed on a
straight line basis over the vesting period, based on the Group's
estimate of shares that will eventually vest and adjusted for non
market based vesting conditions.
Fair value is measured by use of either Binomial or Monte-Carlo
simulation. The main assumptions are disclosed in note 9.
Cash settled share based payment transactions result in a
liability. Services received and liability incurred are measured
initially at fair value of the liability at grant date, and the
liability is remeasured each reporting period until settlement. The
liability is recognised on a straight line basis over the period
that services are rendered.
2 Use of estimates, assumptions and judgements
The Group makes estimates, assumptions and judgements that
affect the reported amounts of assets and liabilities. Estimates,
assumptions and judgements are continually evaluated and based on
historical experience and other factors, including expectations of
future events that are believed to be reasonable under the
circumstances.
The key assumptions concerning the future, and other key sources
of estimation uncertainty at the balance sheet date, that have a
significant risk of causing a material adjustment to the carrying
amounts of assets and liabilities within the next financial year,
are discussed below.
Carrying value of intangible exploration and evaluation assets
(note 14) and property, plant and equipment (note 15)
The amounts for intangible exploration and evaluation assets
represent active exploration and evaluation projects. These amounts
will be written off to the income statement as exploration costs
unless commercial reserves are established or the determination
process is not completed and there are indications of impairment in
accordance with the Group's accounting policy.
In addition for assets under evaluation where discoveries have
been made, such as Sea Lion, and property plant and equipment
assets their carrying value is checked by reference to the net
present value of future cashflows which requires key assumptions
and estimates in relation to: commodity prices that are based on
forward curves for a number of years and the long-term corporate
economic assumptions thereafter, discount rates that are adjusted
to reflect risks specific to individual assets, the quantum of
commercial reserves and the associated production and cost
profiles. Future development costs are estimated taking into
account the level of development required to produce the reserves
by reference to operators, where applicable, and internal
engineers.
Carrying value of goodwill (note 16)
Following the acquisition of Mediterranean Oil & Gas plc
during 2014, Rockhopper recognised goodwill in line with the
requirements of IFRS 3- Business Combinations. Management performs
annual impairment tests on the carrying value of goodwill and the
Greater Mediterranean CGU that the goodwill is attributed to. The
calculation of the recoverable amount is based on the likely future
economic benefits of the exploration and evaluation assets in the
acquired portfolio and is based on estimated value of the potential
and actual discoveries as noted above.
Decommissioning costs (note 23)
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 and amount of
expenditure 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 external expert and the results of the most recent
available review used as a basis for the amounts in the Financial
Statements. Provision for environmental clean-up and remediation
costs is based on current legal and contractual requirements,
technology and price levels.
3 REVENUE AND SEGMENTAL INFORMATION
YEARED 31 DECEMBER 2018
Falkland Greater
Islands Mediterranean Corporate Total
$'000 $'000 $'000 $'000
--------------------------------------- --------- -------------- ---------- --------
Revenue - 10,580 - 10,580
Cost of sales - (8,531) - (8,531)
--------------------------------------- --------- -------------- ---------- --------
Gross profit - 2,049 - 2,049
Exploration and evaluation
expenses (253) (3,682) (1,079) (5,014)
--------------------------------------- --------- -------------- ---------- --------
Costs in relation to acquisition
and group restructuring - (58) - (58)
Recurring administrative costs - (1,406) (3,922) (5,328)
--------------------------------------- --------- -------------- ---------- --------
Total administrative expenses - (1,464) (3,922) (5,386)
Charge for share based payments - - (1,478) (1,478)
Other income - 943 - 943
Foreign exchange gain/(loss) 2,197 (100) (889) 1,208
--------------------------------------- --------- -------------- ---------- --------
Results from operating activities
and other income 1,944 (2,254) (7,368) (7,678)
Finance income - 8 817 825
Finance expense - (254) 1 (253)
--------------------------------------- --------- -------------- ---------- --------
Loss before tax 1,944 (2,500) (6,550) (7,106)
Tax - (25) - (25)
--------------------------------------- --------- -------------- ---------- --------
Profit/(loss) for year 1,944 (2,525) (6,550) (7,131)
--------------------------------------- --------- -------------- ---------- --------
Reporting segments assets 440,314 41,992 39,156 521,462
Reporting segments liabilities 76,996 18,183 10,940 106,119
Depreciation - 3,991 120 4,111
Year ended 31 December 2017
Falkland Greater
Islands Mediterranean Corporate Total
$'000 $'000 $'000 $'000
--------------------------------------- --------- -------------- ---------- --------
Revenue - 10,401 - 10,401
Cost of sales - (9,573) - (9,573)
--------------------------------------- --------- -------------- ---------- --------
Gross profit - 828 - 828
Exploration and evaluation
expenses - (2,369) (1,053) (3,422)
--------------------------------------- --------- -------------- ---------- --------
Costs in relation to acquisition - - - -
and group restructuring
Other administrative costs (7) (1,487) (3,788) (5,282)
--------------------------------------- --------- -------------- ---------- --------
Total administrative expenses (7) (1,487) (3,788) (5,282)
Charge for share based payments - - (864) (864)
Foreign exchange movement (3,791) 366 2,459 (966)
--------------------------------------- --------- -------------- ---------- --------
Results from operating activities
and other income (3,798) (2,662) (3,246) (9,706)
Finance income - - 783 783
Finance expense - (30) (9) (39)
--------------------------------------- --------- -------------- ---------- --------
Loss before tax (3,798) (2,692) (2,472) (8,962)
Tax 2,866 (43) - 2,823
--------------------------------------- --------- -------------- ---------- --------
Loss for year (932) (2,735) (2,472) (6,139)
--------------------------------------- --------- -------------- ---------- --------
Reporting segments assets 425,971 51,647 50,447 528,065
Reporting segments liabilities 80,462 19,551 7,454 107,467
Depreciation - 5,498 189 5,687
4 Cost of sales
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
-------------------------------------------------- --------- --------
Cost of sales 4,563 4,100
Depreciation of oil and gas assets (see note 15) 3,968 5,473
8,531 9,573
-------------------------------------------------- --------- --------
5 exploration and evaluation expenses
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
-------------------------------------------------- --------- --------
Allocated from administrative expenses (see note
6) 891 597
Capitalised exploration costs impaired (see note
14) 3,884 2,321
Other exploration and evaluation expenses 239 504
5,014 3,422
-------------------------------------------------- --------- --------
6 Administrative expenses
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
-------------------------------------------------- --------- --------
Directors' salaries and fees, including bonuses
(see note 7) 1,727 1,934
Other employees' salaries 2,638 2,604
National insurance costs 637 651
Pension costs 164 260
Employee benefit costs 88 92
Total staff costs (including group restructuring
costs) 5,254 5,541
Amounts reallocated (2,105) (2,200)
-------------------------------------------------- --------- --------
Total staff costs charged to administrative
expenses 3,149 3,341
Auditor's remuneration (see note 8) 251 244
Other professional fees 1,058 992
Other 1,648 1,481
Depreciation 143 214
Amounts reallocated (863) (990)
-------------------------------------------------- --------- --------
5,386 5,282
-------------------------------------------------- --------- --------
The average number of staff employed during the year was 20 (31
December 2017: 24). The relative decrease between years reflects
the continued restructuring of the Greater Mediterranean operation.
As at 31 December 2018 the number of staff employed had reduced to
19.
Amounts reallocated relate to the costs of staff and associated
overhead in relation to non administrative tasks. These costs are
allocated to exploration and evaluation expenses or capitalised as
part of the intangible exploration and evaluation assets as
appropriate.
7 directors' remuneration
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
------------------------------------------------- --------- --------
Executive salaries 912 1,141
Executive bonuses 250 267
Company pension contributions to money purchase
schemes & pension cash allowance 137 104
Benefits 28 37
Non-executive fees 400 385
1,727 1,934
------------------------------------------------- --------- --------
The total remuneration of the highest paid director was:
Year Year
ended ended
31 Dec 31 Dec
18 17
GBP GBP
-------------------------------- --------- --------
Annual salary 373,000 362,100
Bonuses 93,000 108,600
Money purchase pension schemes 55,900 36,900
Benefits 11,200 10,904
533,100 518,504
-------------------------------- --------- --------
Interest in outstanding share options and SARs, by director, are
separately disclosed in the directors' remuneration report.
8 Auditor's remuneration
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
---------------------------------------------------------- --------- --------
KPMG LLP
Fees payable to the Company's auditor for the audit
of the Company's annual financial statements 128 117
Fees payable to the Company's auditor and its associates
for other services:
Audit of the accounts of subsidiaries 72 63
Half year review 38 45
Tax compliance services 13 19
251 244
---------------------------------------------------------- --------- --------
9 Share based Payments
The charge for share based payments relate to options granted to
employees of the Group.
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
--------------------------------------------------- --------- --------
Charge for the long term incentive plan options 1,360 768
Charge for shares issued under the SIP throughout
the year 118 96
--------------------------------------------------- --------- --------
1,478 864
--------------------------------------------------- --------- --------
The models and key assumptions used to value each of the grants
and hence calculate the above charges are set out below:
Long term incentive plan
During 2013 a long term incentive plan ("LTIP") was approved by
shareholders. The LTIP is operated and administered by the
Remuneration Committee. During the year a number of LTIP awards
('Awards'), structured as nil cost options, were granted to
executive directors and senior staff.
LTIP awards will generally only vest or become exercisable
subject to the satisfaction of a performance condition measured
over a three year period ("Performance Period") determined by the
Remuneration Committee at the time of grant. The performance
conditions must contain objective conditions, which must be related
to the underlying financial performance of the Company. The current
performance condition used is based on Total Shareholder Return
("TSR") measured over a three-year period against the TSR of a peer
group of at least 9 other oil and gas companies comprising both
FTSE 250, larger AIM oil and gas companies and Falkland Islands
focused companies ("Peer Group"). The Peer Group for the Awards may
be amended by the Remuneration Committee at their sole discretion
as appropriate.
Performance measurement for the Awards are based on the average
price over the relevant 90 day dealing period measured against the
90 dealing day period three years later. Awards will typically vest
on a sliding scale from 35% to 100% for performance in the top two
quartiles of the Peer Group. No awards will vest for performance in
the bottom two quartiles.
The Awards granted on 8 October 2013 and 10 March 2014 had an
additional performance condition so that no awards would vest if
the Company's share price did not exceed GBP1.80 based on the
average price over the 90 day dealing period up to 31 March 2016.
The Remuneration Committee has exercised its discretion to vary the
performance condition so that the period for achievement of the
GBP1.80 hurdle rate is extended to 31 March 2023. As a result, any
LTIP awards that would have vested on 31 March 2016 will not be
exercisable unless the Company's share price exceeds GBP1.80 based
on an average price over any 90 day dealing period up to 31 March
2023. At the same time, the Remuneration Committee agreed to remove
its discretion to allow vesting for performance in the third
quartile for all existing and future LTIP awards.
The LTIP has been valued using a Monte Carlo model the key
inputs of which are summarised below
Grant date: 23 April 16 June 22 Apr 13 Apr
2018 2017 2016 2015
Closing share price 25.7p 21.25p 31.5p 64.0p
Number granted 7,000,000 6,700,000 10,047,885 4,111,838
Weighted average volatility 44.4% 53.3% 60.4% 44.5%
Weighted average volatility
of index 64.0% 71.4% 71.2% 55.8%
Weighted average risk free
rate 0.90% 0.18% 0.58% 0.70%
Correlation in share price
movement with comparator
group 13.0% 15.3% 27.5% 33.5%
Exercise price 0p 0p 0p 0p
Dividend yield 0% 0% 0% 0%
----------------------------- ---------- ---------- ----------- ----------
The following movements occurred during the year:
At 31 December
At 31 December
Issue date Expiry date 2017 Issued Lapsed 2017
---------------- ------------- ----------------- ---------- ------------ ---------------
8 October
8 October 2013 2023 546,145 - - 546,145
10 March
10 March 2014 2024 70,391 - - 70,391
13 April
13 April 2015 2025 2,977,944 - (2,977,944) -
22 April
22 April 2016 2026 6,017,850 - - 6,017,850
16 June
16 June 2017 2027 6,700,000 - - 6,700,000
23 April
23 April 2018 2028 - 7,000,000 - 7,000,000
---------------- ------------- ----------------- ---------- ------------ ---------------
16,312,330 7,000,000 (2,977,944) 20,334,386
------------------------------ ----------------- ---------- ------------ ---------------
Share incentive plan
The Group has in place an HMRC approved Share Incentive Plan
("SIP"). The SIP allows the Group to award Free Shares to UK
employees (including directors) and to award shares to match
Partnership Shares purchased by employees, subject to HMRC
limits.
Throughout this and the prior year the Group issued two Matching
Shares for every Partnership Share purchased.
In the year the Group made a free award of GBP41,997 (year ended
31 December 2017 GBP41,997) worth of Free Shares to eligible
employees.
This resulted in 156,268 (year ended 31 December 2017: 154,826)
Free Shares and under the SIP scheme matching and partnership
shares issued were 223,131 (year ended 31 December 2017: 302,622)
in the period.
31 Dec 31 Dec
2018 2017
------------------------------------------------------ ------- -------
The average fair value of the shares awarded (pence) 28 23
Vesting 100% 100%
Dividend yield Nil Nil
Lapse due to withdrawals Nil Nil
------------------------------------------------------ ------- -------
The fair value of the shares awarded will be spread over the
expected vesting period.
Share appreciation rights
A share appreciation right ("SAR") is effectively a share option
that is structured from the outset to deliver, on exercise, only
the net gain in the form of new ordinary shares that would have
been made on the exercise of a market value share option.
No consideration is payable on the grant of a SAR. On exercise,
an option price of 1 pence per ordinary share, being the nominal
value of the Company's ordinary shares, is paid and the relevant
awardee will be issued with ordinary shares with a market value at
the date of exercise equivalent to the notional gain that the
awardee would have made, being the amount by which the aggregate
market value of the number of ordinary shares in respect of which
the SAR is exercised, exceeds a notional exercise price, equal to
the market value of the shares at the time of grant (the "base
price"). The remuneration committee has discretion to settle the
exercise of SARs in cash.
The following movements occurred during the period on SARs:
Exercise At 31 Dec At 31
price Dec
Issue date Expiry date (pence) 2017 Exercised Lapsed 2018
---------------- -------------- --------- ---------- ---------- --------- --------
22 November 22 November
2008 2018 19.25 355,844 (355,844) - -
3 July 2009 3 July 2019 30.87 103,368 - - 103,368
11 January 11 January
2011 2021 372.75 196,712 - (21,664) 175,048
14 July 2011 14 July 2021 239.75 43,587 - - 43,587
16 August
16 August 2011 2021 237.00 17,035 - - 17,035
13 December 13 December
2011 2021 240.75 29,594 - - 29,594
17 January 17 January
2012 2022 303.75 269,026 - (24,485) 244,541
30 January 30 January
2013 2023 159.00 317,845 - (40,683) 277,162
---------------- -------------- --------- ---------- ---------- --------- --------
1,333,011 (355,844) (86,832) 890,335
------------------------------- --------- ---------- ---------- --------- --------
10 FOREign Exchange
Year ended Year ended
31 Dec 31 Dec
18 17
$'000 $'000
-------------------------------------------------- ------------- -----------
Foreign exchange gain/(loss) on Falkland Islands
tax liability (see note 22) 2,197 (3,791)
Foreign exchange gain on term deposits, cash and
restricted cash 59 460
-------------------------------------------------- ------------- -----------
2,256 (3,331)
Foreign exchange on operating activities (1,048) 2,365
-------------------------------------------------- ------------- -----------
Total net foreign exchange gain/(loss) 1,208 (966)
-------------------------------------------------- ------------- -----------
11 FINANCE INCOME AND EXPENSE
Year ended Year ended
31 Dec 31 Dec
18 17
$'000 $'000
----------------------------------------------------- ------------- -------------
Bank and other interest receivable 825 783
Total finance income 825 783
----------------------------------------------------- ------------- -------------
Unwinding of discount on decommissioning provisions
(see note 23) 244 (4)
Other 9 43
----------------------------------------------------- ------------- -------------
Total finance expense 253 39
----------------------------------------------------- ------------- -------------
12 Taxation
Year ended Year ended
31 Dec 31 Dec
18 17
$'000 $'000
-------------------------------------------------------- ----------- -----------
Current tax:
Overseas tax - (14)
Adjustment in respect of prior years - (2,866)
-------------------------------------------------------- ----------- -----------
Total current tax - (2,880)
-------------------------------------------------------- ----------- -----------
Deferred tax:
Overseas tax 25 57
-------------------------------------------------------- ----------- -----------
Total deferred tax - note 24 25 57
-------------------------------------------------------- ----------- -----------
Tax on profit on ordinary activities 25 (2,823)
-------------------------------------------------------- ----------- -----------
Loss on ordinary activities before tax (7,106) (8,962)
-------------------------------------------------------- ----------- -----------
Loss on ordinary activities multiplied at 26% weighted
average rate (31 December 2017: 26%) (1,848) (2,330)
Effects of:
Income and gains not subject to taxation (2,528) (1,884)
Expenditure not deductible for taxation 1,688 3,005
Depreciation in excess of capital allowances 1,050 (722)
IFRS2 Share based remuneration cost 384 189
Losses carried forward 1,275 1,656
Effect of tax rates in foreign jurisdictions (21) 134
Adjustments in respect of prior years 25 (2,866)
Other - (5)
-------------------------------------------------------- ----------- -----------
Tax charge/(credit) for the year 25 (2,823)
-------------------------------------------------------- ----------- -----------
On the 8 April 2015 the Group agreed binding documentation ("Tax
Settlement Deed") with the Falkland Island Government ("FIG") in
relation to the tax arising from the Group's farm out to Premier
Oil plc ("Premier"). As such the Group is able to defer this tax
liability under Extra Statutory Concession 16. As it is deferred,
the liability is classified as non-current and discounted.
Additional information is given in Note 22 Tax payable.
The total carried forward losses and carried forward pre trading
expenditures potentially available for relief are as follows:
Year ended Year ended
31 Dec 31 Dec
18 17
$'000 $'000
------------------ ----------- -----------
UK 66,740 62,033
Falkland Islands 592,483 576,121
Italy 75,278 61,961
------------------ ----------- -----------
In Egypt under the terms of the PSC any taxes arising are
settled by EGPC on behalf of the Group. Consequently, any carried
forward losses would have no impact on the reported profits of the
Group.
No deferred tax asset has been recognised in respect of
temporary differences arising on losses carried forward,
outstanding share options or depreciation in excess of capital
allowances due to the uncertainty in the timing of profits and
hence future utilisation. Losses carried forward in the Falkland
Islands includes amounts held within entities where utlisation of
the losses in the future may not be possible.
13 Basic and diluted loss per share
31 Dec 31 Dec
18 17
Number Number
------------------------------------------------ ------------ ------------
Shares in issue brought forward 457,116,500 456,659,052
Shares issued
- Issued under the SIP 379,399 457,448
------------------------------------------------ ------------ ------------
Shares in issue carried forward 457,495,899 457,116,500
------------------------------------------------ ------------ ------------
Weighted average number of Ordinary Shares for
the purposes of basic earnings per share 457,369,112 456,945,871
Effects of dilutive potential Ordinary shares
Contingently issuable shares - -
------------------------------------------------ ------------ ------------
457,369,112 456,945,871
------------------------------------------------ ------------ ------------
$'000 $'000
------------------------------------------------------ -------- --------
Net loss after tax for purposes of basic and diluted
earnings per share (7,131) (6,139)
------------------------------------------------------ -------- --------
Loss per share - cents
Basic (1.57) (1.34)
Diluted (1.57) (1.34)
------------------------------------------------------ -------- --------
The average market value of the Company's shares for the purpose
of calculating the dilutive effect of share options was on quoted
market prices for the year during which the options were
outstanding. The calculation of loss per share is based upon the
loss for the year and the weighted average shares in issue. As the
Group is reporting a loss in the year then in accordance with IAS33
the share options are not considered dilutive because the exercise
of the share options would have the effect of reducing the loss per
share.
14 intangible exploration and evaluation assets
Falkland Greater
Islands Mediterranean Total
$'000 $'000 $'000
---------------------------- --------- -------------- --------
As at 31 December
2016 418,584 7,835 426,419
Additions 7,387 1,317 8,704
Written off to exploration
costs - (2,321) (2,321)
Transfer to assets
held for sale (see
note 20) - (824) (824)
Foreign exchange
movement - 169 169
------------------------------ --------- -------------- --------
As at 31 December
2017 425,971 6,176 432,147
Additions 14,595 3,364 17,959
Written off to exploration
costs (252) (3,632) (3,884)
Transfer from assets
held for sale (see
note 20) - 834 834
Foreign exchange
movement - (21) (21)
------------------------------ --------- -------------- --------
As at 31 December
2018 440,314 6,721 447,035
------------------------------ --------- -------------- --------
FALKLAND ISLANDS LICENCES
The additions during the period of $14.6 million relate
principally to the Sea Lion development.
In assessing whether it is necessary to undertake a detailed
impairment test, management consider whether there are any
triggers, e.g. a significant change in the view on long term oil
pricing or project cost, that would suggest such a detailed test is
necessary. Management do not consider there to be any such
triggers.
Nevertheless, management, as a matter of good practice, run
their cashflow model regularly. At the year end, the key inputs to
this model were a 2019 real terms Brent oil price of $70/bbl, a
post-tax discount rate of 12.5% and utilising the operator's
current estimates of capital and operating costs and production
profiles. The project is targeting project sanction decision at the
end of 2019 (with such decision dependent on securing funding) and
is expected to take three and half years from sanction to first
oil. The remaining barrels in Sea Lion are expected to be recovered
along with those in near field discoveries in a second phase of
development.
Sensitivity analysis is performed by, in turn, reducing oil
price by $10/bbl, reducing production by 10%, increasing capital
expenditure by 10%, increasing operating expenditure by 10% and
delaying the development by one year. None of these sensitivities
would have led to an impairment charge in the year.
Costs associated with Isobel/Elaine discoveries and a potential
phase 3 development are carried at cost and no indication of
impairment currently exists although the assets require further
appraisal.
GREATER MEDITERRANEAN LICENCES
The $3.6 million additions during the period predominantly
relate to work on the Egyptian license interests. An impairment of
$3.4 million was recognised during the year in respect of the
Raya-1X exploration commitment well in the El Qa'a Plain concession
which encountered no hydrocarbons.
15 property, plant and equipment
Oil and Other Oil and Other
gas gas
assets assets 31 Dec assets assets 31 Dec
18 17
$'000 $'000 $'000 $'000 $'000 $'000
--------------------------- --------- ------- --------- --------- ------- ---------
Cost brought forward 31,043 1,134 32,177 32,378 1,096 33,474
Additions 1,996 25 2,021 970 17 987
Foreign exchange (762) (10) (772) 2,524 21 2,545
Disposals - (271) (271) - - -
Transfer from/(to)
assets held for sale 4,891 - 4,891 (4,829) - (4,829)
--------------------------- --------- ------- --------- --------- ------- ---------
Cost carried forward 37,168 878 38,046 31,043 1,134 32,177
--------------------------- --------- ------- --------- --------- ------- ---------
Accumulated depreciation
and impairment loss
brought forward (19,751) (841) (20,592) (14,831) (618) (15,449)
Current year depreciation
charge (3,968) (143) (4,111) (5,473) (214) (5,687)
Foreign exchange 611 7 618 (1,790) (9) (1,799)
Disposals - 271 271 - - -
Transfer (from)/to
assets held for sale (2,396) - (2,396) 2,343 - 2,343
--------------------------- --------- ------- --------- --------- ------- ---------
Accumulated depreciation
and impairment loss
carried forward (25,504) (706) (26,210) (19,751) (841) (20,592)
--------------------------- --------- ------- --------- --------- ------- ---------
Net book value brought
forward 11,292 293 11,585 17,547 478 18,025
--------------------------- --------- ------- --------- --------- ------- ---------
Net book value carried
forward 11,664 172 11,836 11,292 293 11,585
--------------------------- --------- ------- --------- --------- ------- ---------
All oil and gas assets relate to the Greater Mediterranean
region, specifically producing assets in Italy and Egypt.
Asset additions relate almost entirely to the addition of the
Abu Sennan production asset in Egypt.
Consistent with the approach taken to assess whether the
Falkland Island licences should be subject to impairment testing,
management did not identify any triggers that would require a
formal impairment calculation to be undertaken. Therefore, no
impairment was recognised in the period (2017: $nil).
Nonetheless, similar to the Falkland Islands licences future
discounted cash flows expected to be derived from production of
commercial reserves (the value in use being the recoverable amount)
were compared against the carrying value of the asset. The future
cash flows were estimated using a realised oil and gas price
assumption equal to existing contracts in place and relevant
forward curve in 2019 and 2020, and a Brent oil price of $70/bbl
and a gas price of EUR0.25/sm3 in 2019 real terms thereafter and
were discounted using a post-tax rate of 10%. Assumptions involved
in the impairment measurement include estimates of commercial
reserves and production volumes, future oil and gas prices and the
level and timing of expenditures, all of which are inherently
uncertain. No impairments were identified in this process.
16 GOODWILL
Greater
Mediterranean
$'000
--------------------------- --------------
As at 31 December 2017 10,789
Foreign exchange movement (481)
------------------------------ --------------
As at 31 December 2018 10,308
------------------------------ --------------
Goodwill relates to the corporate acquisition of Mediterranean
Oil & Gas plc ("MOG") during the period ended 31 December 2014.
This goodwill is included in the Greater Mediterranean segment and
allocated to the Italian CGU which have the optionality and
potential to provide value in excess of this fair value as well as
representing the strategic premium associated with a significant
presence in a new region. The functional currency of MOG is euros.
As such the goodwill is also expressed in the same functional
currency and subject to retranslation at each reporting period end.
The reduction in the period of $481,000 (2017: $1,350,000 increase)
is entirely due to this foreign currency difference. None of the
goodwill recognised is expected to be deductible for tax
purposes.
The Group tests goodwill annually for impairment or more
frequently if there are indicators goodwill might be impaired. The
recoverable amounts are determined by reference to a value in use
calculation. Future cashflows are estimated using a long term
realised gas price of EUR0.25/sm3 and a realised long-term oil
price of $70/bbl in 2019 real terms and were discounted using a
post-tax rate of 10%. Assumptions involved in the impairment
measurement include estimates of commercial reserves and production
volumes, future oil and gas prices and the level and timing of
expenditures, all of which are inherently uncertain.
17 OTHER Receivables
31 Dec 31 Dec
18 17
$'000 $'000
--------------------- ------- -------
Current
Receivables 3,811 9,826
Prepayments 332 473
Accrued interest 396 323
Income tax 81 85
Other 4,890 6,133
--------------------- ------- -------
9,510 16,840
--------------------- ------- -------
The carrying value of receivables approximates to fair value.
The decrease in receivables in the year is due to the reduction of
the receivable due from EGPC. At 31 December 2018, the receivable
balance due from EGPC was $1.3 million which is due solely to
Rockhopper following the settlement of the amount which was payable
to the former parent company of Rockhopper Egypt Pty. Limited,
Beach Energy Limited.
Other receivables predominantly relate to IVA balances due from
the Italian tax authorities which are in the process of being
reclaimed.
18 Restricted cash
31 Dec 31 Dec
18 17
$'000 $'000
------------------ ------- -------
Charged accounts 568 540
568 540
------------------ ------- -------
19 Term Deposits
31 Dec 31 Dec
18 17
$'000 $'000
-------------------------------- ------- -------
Maturing after the period end:
Within three months 10,000 10,000
Six to nine month 10,000 10,000
Nine months to one year 10,000 10,000
-------------------------------- ------- -------
30,000 30,000
-------------------------------- ------- -------
Term deposits are disclosed separately on the face of the
balance sheet when their term is greater than three months and they
are unbreakable.
20 Disposal group held for sale
On 8 June 2017, the Group announced the disposal of a portfolio
of non-core interests in onshore Italy. Following failure to
satisfy all relevant conditions precedent, including receipt of
requisite regulatory approvals in Italy, the Group has decided not
to proceed with the transaction.
21 Other payables and accrualS
31 Dec 31 Dec
18 17
$'000 $'000
------------------ ------- -------
Accounts payable 2,462 2,551
Accruals 12,246 8,654
Other creditors 440 1,567
------------------ ------- -------
15,148 12,772
------------------ ------- -------
Accruals have increased due to costs associated with the Sea
Lion development.
All amounts are expected to be settled within twelve months of
the balance sheet date and so the book values and fair values are
considered to be the same.
22 Tax payable
31 Dec 31 Dec
18 17
$'000 $'000
------------------------- ------- -------
Current tax payable - -
Non current tax payable 37,860 40,057
------------------------- ------- -------
37,860 40,057
------------------------- ------- -------
On the 8 April 2015, the Group agreed binding documentation
("Tax Settlement Deed") with the Falkland Island Government ("FIG")
in relation to the tax arising from the Group's farm out to Premier
Oil plc ("Premier").
The Tax Settlement Deed confirms the quantum and deferment of
the outstanding tax liability and is made under Extra Statutory
Concession 16.
As a result of the Tax Settlement Deed the outstanding tax
liability was confirmed at GBP64.4 million and payable on the first
royalty payment date on Sea Lion. Currently the first royalty
payment date is anticipated to occur within six months of first oil
production which itself is estimated to occur approximately three
and a half years after project sanction. As such the tax liability
has been reclassified as non-current and discounted at 15%. The tax
liability was revised downwards in the year ended 31 December 2017
to GBP59.6 million, due to the full benefit of the exploration
carry being received from Premier on the 2015/16 drilling campaign
and the Falkland Islands Commissioner of Taxation agreeing to
reduce the liability on that basis in line with the terms of the
Tax settlement Deed. A foreign exchange gain of US$2.2 million
(2017: US$3.8 million loss) has been recognised in the year.
23 Provisions
Abandonment Other
provision provisions 31 Dec 31 Dec
18 17
$'000 $'000 $'000 $'000
---------------------------------- ------------ ----------- ------- --------
Brought forward 5,892 94 5,986 14,914
Amounts utilized (854) (27) (881) (1,704)
Amounts arising in the period - 10 10 11
Unwinding of discount 247 - 247 -
Transfer from/(to) liabilities
associated with assets held for
sale 8,750 - 8,750 (8,772)
Foreign exchange (220) (4) (224) 1,537
---------------------------------- ------------ ----------- ------- --------
Carried forward at period end 13,815 73 13,888 5,986
---------------------------------- ------------ ----------- ------- --------
The abandonment provision relates to the Group's licences in the
Greater Mediterranean region. The provision covers both the plug
and abandonment of wells drilled as well as any requisite site
restoration. Assumptions, based on the current economic
environment, have been made which management believe are a
reasonable basis upon which to estimate the future liability. These
estimates are reviewed regularly to take into account any material
changes to the assumptions. However, actual decommissioning costs
will ultimately depend upon future market prices for the necessary
decommissioning works required which will reflect market conditions
at the relevant time. Furthermore, the timing of decommissioning is
likely to depend on when the fields cease to produce at
economically viable rates. This in turn will depend upon future oil
and gas prices, which are inherently uncertain.
Other provisions include amounts due to employees for accrued
holiday and leaving indemnity for staff in Italy, that will become
payable when they cease employment.
24 deferred tax liability
31 Dec 31 Dec
18 17
$'000 $'000
------------------------ ------- -------
At beginning of period 39,202 39,145
Movement in period 21 57
At end of period 39,223 39,202
------------------------ ------- -------
The deferred tax liability arises due to temporary differences
associated with the intangible exploration and evaluation
expenditure. The majority of the balance relates to historic
expenditure on licences in the Falklands, where the tax rate is
26%, being utilised to minimise the corporation tax due on the
consideration received as part of the farm out disposal during
2012.
Total carried forward losses and carried forward pre-trading
expenditures available for relief on commencement of trade at 31
December 2018 are disclosed in note 12 Taxation. No deferred tax
asset has been recognised in relation to these losses due to
uncertainty that future suitable taxable profits will be available
against which these losses can be utilised. The potential deferred
tax asset at the 31 December 2018 would be $185 million (31
December 2017: $176 million).
25 Share capital
31 Dec 2018 31 Dec 2017
-------------------- --------------------
$'000 Number $'000 Number
----------------------------------- ------ ------------ ------ ------------
Called up, issued and fully paid:
Ordinary shares of GBP0.01 each 7,205 457,495,899 7,200 457,116,500
----------------------------------- ------ ------------ ------ ------------
For details of all movements during the year, see note 13.
26 reserves
Set out below is a description of each of the reserves of the
Group:
Share premium Amount subscribed for share capital in excess of
its nominal value.
Share based The share incentive plan reserve captures the equity
remuneration related element of the expenses recognised for the
issue of options, comprising the cumulative charge
to the income statement for IFRS2 charges for share
based payments less amounts released to retained
earnings upon the exercise of options.
Own shares Shares held in trust represent the issue value of
held in trust shares held on behalf of participants in the SIP
by Capita IRG Trustees Limited, the trustee of the
SIP as well as shares held by the Employee Benefit
Trust which have been purchased to settle future
exercises of options.
Merger reserve The difference between the nominal value and the
fair value of shares issued on acquisition of subsidiaries.
Foreign currency Exchange differences arising on consolidating the
translation assets and liabilities of the Group's subsidiaries
reserve are classified as equity and transferred to the
Group's translation reserve.
Special reserve The reserve is non distributable and was created
following cancellation of the share premium account
on 4 July 2013. It can be used to reduce the amount
of losses incurred by the Parent Company or distributed
or used to acquire the share capital of the Company
subject to settling all contingent and actual liabilities
as at 4 July 2013. Should not all of the contingent
and actual liabilities be settled, prior to distribution
the Parent Company must either gain permission from
the actual or contingent creditors for distribution
or set aside in escrow an amount equal to the unsettled
actual or contingent liability.
Retained losses Cumulative net gains and losses recognised in the
financial statements.
27 Lease commitments
The future aggregate minimum lease payments under
non-cancellable operating leases in respect of land and buildings
were as follows:
31 Dec 31 Dec
18 17
$'000 $'000
--------------------------------------- ------- -------
Total committed within 1 year 504 569
Total committed between 1 and 5 years 351 1,285
--------------------------------------- ------- -------
855 1,854
--------------------------------------- ------- -------
28 CAPITAL COMMITMENTS
Capital commitments represent the Group's share of expected
costs in relation to its licence interests net of any carry
arrangements that are in force.
As at the date of these account the Group committed to fund its
share of the approved work programs and budgets for our licence
interests in the calendar year ending 31 December 2019 of US$18
million.
29 Related Party Transactions
The remuneration of directors, who are the key management
personnel of the Group, is set out below in aggregate. Further
information about the remuneration of individual directors is
provided in the Directors' Remuneration Report on pages 35 to
45.
Year Year
ended ended
31 Dec 31 Dec
18 17
$'000 $'000
------------------------------ --------- ---------
Short term employee benefits 1,636 1,875
Pension contributions 137 59
Share based payments 742 120
------------------------------ --------- ---------
2,515 2,054
------------------------------ --------- ---------
30 Risk management policies
Risk review
The risks and uncertainties facing the Group are set out in the
risk management report. Risks which require further quantification
are set out below.
Foreign exchange risks: The Group is exposed to foreign exchange
movements on monetary assets and liabilities denominated in
currencies other than US$, in particular the tax liability with the
Falkland Island Government which is a GBGBP denominated balance. In
addition a number of the Group's subsidiaries have a functional
currency other than US$, where this is the case the Group has an
exposure to foreign exchange differences with differences being
taken to reserves.
Asset balances include cash and cash equivalents, restricted
cash and term deposits of $41.0 million of which $35.3 million was
held in US$ denominations. The following table summarises the split
of the Group's assets and liabilities by currency:
Currency denomination $ GBP EUR EGP GBP CAD $
of balance
$'000 $'000 $'000 $'000 $'000
----------------------- -------- ------- ------- -------- ------
Assets
31 December 2018 491,148 2,440 27,234 640 -
31 December 2017 495,535 2,989 29,496 22 -
------------------------ -------- ------- ------- -------- ------
Liabilities
31 December 2018 51,200 38,346 16,518 - 55
31 December 2017 47,087 42,031 18,349 - -
------------------------ -------- ------- ------- -------- ------
The following table summarises the impact on the Group's pre-tax
profit and equity of a reasonably possible change in the US$ to
GBGBP exchange rate and the US$ to euro exchange:
Pre tax profit Total equity
+10% US$ -10% US$ +10% US$ -10% US$
rate rate rate rate
increase decrease increase decrease
$'000 $'000 $'000 $'000
------------------- ---------- ---------- ---------- ----------
US$ against GBGBP
31 December 2018 (3,591) 3,591 (3,591) 3,591
31 December 2017 (3,904) 3,904 (3,904) 3,904
------------------- ---------- ---------- ---------- ----------
US$ against euro
31 December 2018 1,072 (1,072) 1,072 (1,072)
31 December 2017 1,117 (1,117) 1,117 (1,117)
------------------- ---------- ---------- ---------- ----------
Capital risk management: the Group manages capital to ensure
that it is able to continue as a going concern whilst maximising
the return to shareholders. The capital structure consists of cash
and cash equivalents and equity. The board regularly monitors the
future capital requirements of the Group, particularly in respect
of its ongoing development programme.
Credit risk; the Group recharges partners and third parties for
the provision of services and for the sale of Oil and Gas. Should
the companies holding these accounts become insolvent then these
funds may be lost or delayed in their release. The amounts
classified as receivables as at the 31 December 2018 were
$3,948,000 (31 December 2017: $9,826,000). Credit risk relating to
the Group's other financial assets which comprise principally cash
and cash equivalents, term deposits and restricted cash arises from
the potential default of counterparties. Investments of cash and
deposits are made within credit limits assigned to each
counterparty. The risk of loss through counterparty failure is
therefore mitigated by the Group splitting its funds across a
number of banks, two of which are part owned by the British
government.
Interest rate risks; the Group has no debt and so its exposure
to interest rates is limited to finance income it receives on cash
and term deposits. The Group is not dependent on its finance income
and given the current interest rates the risk is not considered to
be material.
Liquidity risks; the Group makes limited use of term deposits
where the amounts placed on deposit cannot be accessed prior to
their maturity date. The amounts applicable at the 31 December 2018
were $30,000,000 (31 December 2017: $30,000,000).
Glossary:
2C best estimate of contingent resources
2P proven plus probable reserves
3C a high estimate category of contingent resources
AGM Annual General Meeting
Beach Energy Beach Petroleum (Egypt) Pty Limited
Best a best estimate category of Prospective Resources
also used as a generic term to describe a
best, or mid estimate
Board the Board of Directors of Rockhopper Exploration
plc
boe barrels of oil equivalent
bopd barrels of oil per day
boepd barrels of oil equivalent per day
Capex capital expenditure
Cash resources Cash and term deposits
Company Rockhopper Exploration plc
E&P exploration and production
EGPC Egyptian General Petroleum Company
EIS Environmental Impact Statement
ERCE ERC Equipoise Limited
Farm-down to assign an interest in a licence to another
party
FEED Front End Engineering and Design
FDP Field Development Plan
FID Final Investment Decision
FIG Falkland Islands Government
FOGL Falkland Oil and Gas Limited
FPSO Floating Production, Storage and Offtake
vessel
G&A General and administrative costs
Group the Company and its subsidiaries
High high estimate category of Prospective Resources
also used as a generic term to describe a
high or optimistic estimate
IFRS International Financial Reporting Standard
kboepd thousand barrels of oil equivalent per day
Low a low estimate category of Prospective Resources
also used as a generic term to describe a
low or conservative estimate
LOI Letter of Intent
mmbbls million barrels
mmboe million barrels of oil equivalent
mmbtu million British thermal units
MMstb million stock barrels (of oil)
mscf thousand standard cubic feet
net pay the portion of reservoir containing hydrocarbons
that through the placing of cut offs for
certain properties such as porosity, water
saturation and volume of shale determine
the productive element of the reservoir
P&A plug and abandon
PIM Project Information Memorandum
Premier Premier Oil plc
PSV virtual exchange point
scm standard cubic metre
STOIIP stock-tank oil initially in place
SURF Subsea, Umbilicals, Risers and Flowlines
tvdss true vertical depth subsea
This information is provided by RNS, the news service of the
London Stock Exchange. RNS is approved by the Financial Conduct
Authority to act as a Primary Information Provider in the United
Kingdom. Terms and conditions relating to the use and distribution
of this information may apply. For further information, please
contact rns@lseg.com or visit www.rns.com.
END
FR GMGGDFMMGLZZ
(END) Dow Jones Newswires
April 02, 2019 02:01 ET (06:01 GMT)
Rockhopper Exploration (AQSE:RKH.GB)
Historical Stock Chart
From Oct 2024 to Nov 2024
Rockhopper Exploration (AQSE:RKH.GB)
Historical Stock Chart
From Nov 2023 to Nov 2024
