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| Share Name | Share Symbol | Market | Type | Share ISIN | Share Description |
|---|---|---|---|---|---|
| Lekoil Limited | LSE:LEK | London | Ordinary Share | KYG5462G1073 | ORD USD0.00005 (DI) |
| Price Change | % Change | Share Price | Bid Price | Offer Price | High Price | Low Price | Open Price | Shares Traded | Last Trade | |
|---|---|---|---|---|---|---|---|---|---|---|
| 0.00 | 0.00% | 0.95 | 0.00 | 01:00:00 |
| Industry Sector | Turnover | Profit | EPS - Basic | PE Ratio | Market Cap |
|---|---|---|---|---|---|
| 0 | 0 | N/A | 0 |
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LEKOIL LIMITED (LEK)
Final Results
04-Jun-2018 / 07:00 GMT/BST
Dissemination of a Regulatory Announcement that contains inside information according to
REGULATION (EU) No 596/2014 (MAR), transmitted by EQS Group.
The issuer is solely responsible for the content of this announcement.
4 June 2018
LEKOIL - 2017 Audited Annual Results
("LEKOIL", the "Group" or the "Company")
LEKOIL (AIM: LEK), the Africa focused oil and gas exploration and production company with
interests in Nigeria and Namibia, announces its final audited results for the year to 31
December 2017.
Highlights
Operational
Otakikpo
? Continuous commercial production and cash flow generation at Otakikpo;
? Otakikpo production increased to 7,600 barrels of oil per day (bopd) in December,
ending the year continuously over 7,000 bopd and having produced approximately 1.56
million barrels (bbls) of oil;
? 1,448,911 gross barrels exported (1,188,732 barrels net to LEKOIL), with crude selling
at a premium to Brent.
? 12 month average production from May 2017 to May 2018 was 5,547 bopd;
? The Otakikpo project has now recorded over 1.27 million hours with no lost time
injuries;
? 3D seismic acquisition programme to cover the entire Otakikpo area commenced in
February 2018 with results expected to be available in Q3 2018 and which will be
followed by an updated CPR; and
? Planning for Phase 2 field development underway, targeting 20,000 bopd to be reached
in 2020, subject to securing additional funding from industry sources.
OPL 310
? Planning for a two well appraisal drilling programme of Ogo underway, with long lead
time items ordered (such as well heads and oil country tubular goods ("OCTG");
? MoU signed with GE Oil & Gas for the full field development of Ogo; and
? Receipt of Ministerial Consent for the transfer of initial 17.14% participating
interest on OPL310 farm-in, application made in March 2018 to the Federal High Court in
Nigeria for a declaration that is expected to expedite the consent process for the
second, 22.86%, tranche.
OPL 325
? Independent Technical Evaluation Report, completed in January 2018, confirms the block
prospectivity;
? Geophysical evaluation of approx. 800 sq km of 3D seismic data identified eleven
prospects and leads on the block. It is estimated to contain potential gross aggregate
Oil-in-Place volumes of over 5,700 mmbbls, as an un-risked, Best Estimate case; and
? Farm out process to be initiated following a prospect/lead risking study, which is
expected to commence this year.
Namibia
? Relinquished block 2514A during H2 2017; and
? Updating de-risking for 2514B and data sharing opportunities with others which will
aid in improving understanding of the regional basin.
Financial
*********
? Revenues of US$30.8 million (2016: nil)
? Cost of sales of US$15.9 million (2016: nil)
? Profit for the year US$6.5 million (2016: loss of US$15.8 million)
? Profit per share of US$0.01 (2016: loss per share of US$0.03)
? Period end cash of $6.9 million; cash at end April 2018 of $5.9 million; (2016
year-end cash of US $3.3 million)
Outlook
*******
? Increasing Otakikpo production volumes towards 20,000 bopd targeted to be reached in
2020;
? Secure finance to appraise and test Ogo discovery in OPL 310; and
? Initiate farm out process for OPL 325.
Samuel Adegboyega, Chairman, said, "To our great satisfaction, 2017 saw LEKOIL's first
commercial production, and first crude oil sales. These are perhaps the most important
milestones in the history of the Company, and represent the fruits of efforts that have
been ongoing since LEKOIL's inception in 2010."
Lekan Akinyanmi, Lekoil's CEO, added, "Our priority for 2018 is to continue to grow
production volumes and profitability at Otakikpo. In tandem, we will aim to progress the
appraisal and development of our Ogo discovery in OPL 310. Once we receive the second
Ministerial Consent, we plan to finalise funding plans for an appraisal drilling
programme. The programme will comprise two wells which will include flow testing. Our aim
is to secure enough information to enable the partners to take a Final Investment Decision
in 2019 and then to proceed with development in partnership with GE Oil & Gas."
For further information, please visit www.lekoil.com [1] or contact:
LEKOIL Limited
Alfred Castaneda, Investor +44 20 7920 3150
Relations
+44 20 7920 3150
Lisa Mitchell, Chief Financial
Officer
Strand Hanson Limited (Financial &
Nominated Adviser)
+44 20 7409
James Harris / James Spinney / 3494
Ritchie Balmer
Mirabaud Securities Limited
(Joint Broker)
+44 20 7878 3362 / +44 20
Peter Krens / Edward Haig-Thomas 7878 3447
BMO Capital Markets (Joint
Broker)
+44 20 7236 1010
Jeremy Low / Neil Haycock /
Thomas Rider
Numis Securities (Joint Broker)
John Prior / Ben Stoop +44 20 7260 1000
Tavistock (Financial PR)
Simon Hudson / Barney Hayward / +44 20 7920 3150
Charles Vivian
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").
LEKOIL's annual report and accounts for the year ended 31 December 2017, together with the
Notice of Meeting will be posted to shareholders later today and will be available to
download on the Company's website at http://www.lekoil.com/ [2]
Chairman's and CEO's Statement
Introduction
To our great satisfaction, 2017 saw LEKOIL's first commercial production, first sale of
oil, and first crude oil sales. These are perhaps the most important milestones in the
history of the Company, and represent the fruits of efforts that have been ongoing since
LEKOIL's inception in 2010.
Otakikpo
Otakikpo ended the year producing over 7,000 bopd continuously, following a steady rise in
daily production through the second half of the year. In Q1 2018, perforation activity was
undertaken in one of two production strings at well-003 as previously announced, and
production performance on the lower member sand of zone E1 showed small increases in water
cut. Current production is now stable at 6,000 bopd in line with production and reservoir
management best practices. The Otakikpo Joint Venture Partners (with LEKOIL as Financial
and Technical Partner to Green Energy International Limited as Operator) have agreed to
continue production at current levels pending additional information from well and
reservoir management and development activities (3D seismic and well drilling) in Phase
Two.
The Joint Venture remains focused on Phase Two of the Otakikpo Field Development Plan
which aims to increase steady state production up to approximately 20,000 bopd in 2020.
Phase 2 of the development includes acquiring 3D seismic coverage of the entire Otakikpo
field and the incremental development of the rest of the field with new wells planned. As
an initial step in delivering Phase 2, the Otakikpo Joint Venture signed a contract with
Sinopec Changjiang Engineering Services Limited (Sinopec) to acquire 197 sq km of 3D
seismic data at Otakikpo, which commenced on 1 February 2018, following the securing of
permits. This survey is on schedule to be completed in Q3 2018, followed by seismic
processing and a subsequent release of an updated Competent Person's Report (CPR). The
completion of this seismic survey and planned development wells in the Phase Two programme
will help to gather more information to optimize development and production. Drilling will
commence after interpreting the seismic survey, as we continue to focus on increasing
steady state production up to the 20,000 bopd target.
Ten liftings have been completed since production commenced and we have received cash
proceeds within 30 days of each lift in line with the Crude Sales Agreement with Shell
Trading. We have realised an average premium for the Otakikpo blend of US$1 or more above
Brent pricing since inception. At current oil prices, the cash netback is above US$30 per
barrel.
OPL310
We retain our confidence in the world class Ogo discovery contained within the OPL 310
licence area. Having received Ministerial Consent in June 2017 for our initial 17.14%
interest resulting from our farm-in in 2013, we have been awaiting consent for the 22.86%
interest we acquired in December 2015. Despite progressing exploration and appraisal
activities on OPL 310, no such consent has been forthcoming nor a satisfactory explanation
why we have not received it. As a result, we took the decision to apply to the Federal
High Court for a declaration that is expected to expedite the consent process, and
preserve the unexpired tenure in the licence. Assuming granting of the consent, LEKOIL
will hold a 40% participating interest and a 70% economic interest in the OPL310 block.
The final consent will allow LEKOIL and Optimum Petroleum Development Company, our local
partner in OPL310, to proceed with an appraisal drilling programme, subject to finalising
funding. Details on the appraisal drilling work programme will be announced in due course,
but it is anticipated it will include flow testing.
From well data collected from the Ogo 1 and Ogo 1-ST wells, our third-party consultants
estimate P50 gross recoverable resources to be at least 774 mmboe across Ogo. Ongoing work
on an updated OPL310 CPR continues, which we expect to be ready after the conclusion of
the appraisal programme.
The next phase of the development of the Ogo discovery in OPL310 will be undertaken in
partnership with GE Oil & Gas, a subsidiary of General Electric Company (NYSE:GE).
Following the successful completion of the appraisal phase and a subsequent FEED study, GE
Oil & Gas, through a consortium, and LEKOIL through its potential funding partners, intend
to invest funds towards the full field development capital of the project. LEKOIL
estimates this cost (on a gross basis) to be approximately US$400 million for full field
oil development and US$600 million for subsequent upstream gas field development.
In return GE Oil & Gas is expected to receive a percentage of LEKOIL's future cash flows
from Ogo, as well as the opportunity to supply its products and provide technical
expertise throughout the life of the project. LEKOIL's 40% participating interest in
OPL310 will remain intact, allowing us to leverage GE's equipment and technical expertise
throughout the life of the project, without diluting LEKOIL's equity interest in OPL310.
OPL325
The completion of an independent Technical Evaluation Report for OPL325 was announced on
31 January 2018. OPL325 is located offshore in the Dahomey Basin, straddling the western
Niger Delta, 50km south of OPL310. LEKOIL holds 62% equity interest in OPL325, through
Ashbert Oil and Gas Limited.
Geophysical evaluation of approximately 800 sq km of 3D seismic data by Lumina Geophysical
identified a total of eleven prospects and leads on the block, estimated to contain
potential gross aggregate Oil-in-Place volumes of over 5,700 mmbbls, as an un-risked, Best
Estimate case.
We are delighted that the report helps confirm our belief in the prospectively of the
block and that we have enhanced our optionality on the next phases of exploration.
We intend to farm-down a portion of our working interest in OPL325 following a detailed
prospect/lead risking study, which is expected to commence this year.
Namibia
As per the terms of our licence, we have relinquished block 2514A in H2 2017 and are
currently in the process of de-risking 2514B, sharing data with others that should help us
improve our understanding of this regional basin.
The Nigerian Business Environment
Nigeria continues to be a promising environment for LEKOIL. We anticipate that the net
effect of planned regulatory change will be positive for indigenous companies and are
engaged in active advocacy in that regard. We also do not expect that any update will make
Nigeria significantly uncompetitive. Stable and competitive fiscal terms, particularly in
the oil and gas industry as compared to other regions and lower risk continue to encourage
overall investment. Government engagements to address militancy in the Niger Delta and the
North East have been largely successful. As an indigenous company, these factors allow
LEKOIL to maintain its "edge" in better understanding the Nigerian landscape.
After the Naira weakened to a record low in mid-2016, the currency situation with the
Naira stabilised further in the second half of 2017 in conjunction with stronger oil
prices. This has led to some easing of inflationary pressures, improving economic growth
and in turn steadily increasing investor confidence. These factors should continue to be
supportive of the Naira heading into 2018, barring a return to capital controls that were
in place from 2015-2016.
Board
We were very pleased to welcome as our new CFO Lisa Mitchell, most recently CFO and
Executive Director of Fastjet plc (AIM: FJET), the African focused low cost airline, prior
to which she was CFO at Ophir Energy plc (LSE: OPHR).
At Ophir Energy, Lisa was responsible for contributing to the overall business strategy of
Ophir; leading the finance function - including all financial, taxation, treasury and
funding issues; IR, and providing financial support for all M&A activity.
Bruce Burrows resigned as CFO in order to pursue another opportunity that better fit his
family circumstances and we wish him well.
In addition, LEKOIL was also pleased to announce the appointment of Tom Schmitt, a US
citizen, as a Non-Executive Director. Tom Schmitt, aged 60, is president of Hunt Refining
Company in Alabama. Prior to this, he was senior vice president with Hunt Oil Company for
Hunt's development in Kurdistan, Iraq. Tom also has extensive experience in investment
management as a former portfolio manager of the Global Research Growth Fund at Alliance
Bernstein.
Operational Review
Otakikpo Marginal Field - Producing Asset
Situated in a swamp area in OML 11, Otakikpo commenced production in February 2017.
Background
The original farm-in fee paid to Green Energy was US$7 million (an implied $0.5/bbl
acquisition price) with a production bonus of US$4 million (which was paid in December
2017 after production commencement and the receipt of Ministerial Consent). LEKOIL will
preferentially recover costs from an entitlement to 88 per cent of production revenue. The
license terms also include a commitment to develop a small scale gas utilisation project.
Three wells originally drilled in the field by the previous operator (Shell) in the 1980s
encountered hydrocarbons in multiple intervals. 2D and 3D seismic analysis by LEKOIL
revealed reserve estimates considerably in excess of those available at the time of
acquisition in May 2014.
The Company has budgeted US $4.5 million to date for the completion of a permanent early
production facility as part of Phase One. The Field Development Plan ("FDP") comprises two
phases which will target incremental production, the commissioning of a new Central
Processing Facility and seven additional wells.
As a result of the work put into the tendering process, LEKOIL has driven down the cost of
production, resulting in a break-even point of less than US$30 per bbl (life of field
basis). By continuing to explore new ways of reducing production costs we increase the
long term viability of the field - even in any protracted low oil price environment.
We received our first crude payment in June 2017, officially marking our transition from
an exploration company to a true exploration and production company. Production reached
approximately 7,600 bopd in December 2017, steadily progressing from initial production
levels of 5,000 bopd when the field started commercial production earlier in the year.
Otakikpo crude sold at a premium to Brent and as the backdrop for oil prices became
increasingly constructive. Approximately 1.6 million barrels of oil have been produced in
2017 and the project has recorded over 1.27 million hours with no lost time injuries. With
these commercial production milestones achieved, attention shifted to Phase Two of
development for Otakikpo, which started in February 2018 with the commencement of 3D
seismic acquisition both on and offshore. Phase Two targets production of 20,000 bopd to
be achieved in 2020, subject to securing additional funding from industry sources.
Otakikpo Reserves / Unrisked Contingent
Resources @ $60/bbl (MMbbls)
Phase 1 & Phase 2 Cases
100% Lekoil Ltd. Net
LOW (P90) 1P+1C 47.00 16.92
MID (P50) 2P+2C 56.60 20.38
HIGH (P10) 3P+3C 66.20 23.83
Ogo Discovery and OPL 310 - Appraisal and Exploration Asset
LEKOIL originally commissioned a regional basin study and identified the Dahomey Basin
block OPL 310 as a key target. The OPL 310 licence is located in the Upper Cretaceous
fairway that runs along the West African Transform Margin. The block extends from the
shallow water continental shelf close by the City of Lagos, Nigeria into deeper water. The
main prospects within the licence area are in water depths ranging from 100 to 800 metres
and are within close proximity to the West Africa Gas Pipeline.
Status Appraisal & Exploration
Participating interest 40 per cent*
Economic interest 70 per cent*
LEKOIL status Technical and Financial
Partner
Partner Optimum Petroleum Development
Limited
P50 Gross Risked Prospective 774.0 mmboe
Resources
* 22.86% subject to Ministerial Consent
Background
In 2013, we invested our pro-rata share of the total US$160 million spent - including the
funding of the first US$50 million from our IPO on London's AIM market - in drilling an
appraisal well and sidetrack targeting Eko, Agege and the Syn-rift prospects. The result
was a significant discovery in the Ogo prospect. Based on data from the vertical and side
track wells, revised estimates for the P50 gross recoverable resources attributable to
LEKOIL from the Ogo field were identified as being 232 mmboe (P50) from gross recoverable
resources of 774 mmboe. This far exceeded the expected pre-drill P50 gross recoverable
resource estimates of 202 mmboe attributable to Lekoil. Additionally, Syn-rift leads
identified within OPL 310 are expected to contain light oil or condensate-rich gas, and
further shallow water leads are being explored.
In December 2015 LEKOIL agreed to acquire Afren's 22.86% participating interest (40%
economic interest) in OPL 310, increasing LEKOIL's consolidated participating interest
from 17.14% to 40%, subject to Ministerial Consent, and will become the technical and
financial partner. Optimum Petroleum Development Company, the operator and local partner
in OPL 310, retains a 60% participating interest. LEKOIL received the first of two
Ministerial Consents for OPL310 in June 2017, for the original farm-in to OPL310 (17.14%
participating interest). Although we believed that progress had been made on the second
Ministerial Consent for the 22.86% participating interest acquired from Afren, we were
disappointed not to have received the consent, or a timetable for its granting, in the
first quarter of 2018. We therefore took the decision at the end of March 2018 to apply to
the Federal High Court of Nigeria for a declaration that is expected to expedite the
consent process, and preserve the unexpired tenure in the licence which is otherwise due
to expire in February 2019. Post the acquisition of Afren's interest, our economic
interest in the block increases from 30% to 70%.
OPL 325 - Exploration Asset
OPL 325 was also identified as a target in LEKOIL's regional basin study covering the
Dahomey Basin. The OPL 325 licence area is located in the offshore Dahomey Basin within
the wrench zone that straddles the western Niger Delta and is a promising exploration
licence located 50km to the south of OPL 310.
Status Exploration
Participating interest 62 per cent
Economic interest 62 per cent
LEKOIL status Operator*
Partner National Petroleum Development
Company Ltd and Local Content
Vehicle
Gross STOIIP unrisked 5-6 billion boe
prospective resources
*via LEKOIL's majority stake in Ashbert Oil & Gas Limited, which holds 70% working
interest of OPL325
Background
In October 2015, LEKOIL entered into an agreement with Ashbert Limited to acquire, via
LEKOIL Exploration and Production Nigeria Limited (LEPNL), 88.57 per cent of the issued
share capital of Ashbert Oil and Gas Limited, which was awarded the OPL 325 licence for an
initial consideration of US$16.1 million, with other payments due at developmental
milestones totalling US$24.1 million.
We have had access to 3D seismic data over 740km2 and are encouraged by the results and
our interpretation of the analysis. In January 2018, a thorough, final independent
technical study by Lumina, prepared for LEKOIL, affirmed their preliminary review of oil
in place volumes of 5.7 billion boe as an un-risked, Best Estimate case. We intend to
farm-down a portion of our working interest in OPL325 following a subsequent detailed
prospect and lead risking study, which we intend to commence this year.
Namibia 2514 B - Exploration Asset
With a history of oil seeps, LEKOIL is now working to prove and quantify the reserves held
within the block.
Status Exploration
Participating interest 77.5 per cent
Economic interest 77.5 per cent
LEKOIL status Operator
Partner National Petroleum Corporate of Namibia,
Local Content Vehicle
Background
Under the original terms of our licence we had a mandatory relinquishment of 50% of our
acreage and we duly relinquished block 2514A in H2 2017. We received a license extension
on block 2514B, with minimal capital obligations, effective September 2017 and valid
through July 2019. We are currently in the process of de-risking block 2514B, sharing data
with others that should help us improve our understanding of this regional basin. We are
following a similar footprint to the work we performed on the Dahomey Basin that led to
OPL310 and OPL325 opportunities.
Corporate & Social Responsibility
LEKOIL maintains high, ethical standards in its business activities. We have respect for
all our people regardless of age, designation and gender. We work in an environment that
fosters effective communication and we deal courteously with all our stakeholders. And we
respect the customs and rules of the countries in which we operate.
We act responsibly, promoting accountability as individuals and as a company. We operate
with ethics and fairness and comply with all required rules and regulations.
We are committed to the welfare and development of the communities around our operations.
In our dealings with the local communities surrounding our producing asset, Otakikpo,
LEKOIL 's corporate and social responsibility ("CSR") plan continues to focus on three
strategic aims:
i) education,
ii) economic empowerment (including women and children development) and,
iii) environmental sustainability.
We are a part of the communities in which we operate. In the coastal town of Ikuru, close
to Otakikpo, we recognised the need for community support for our work yet we also
understood that creating a supportive environment works both ways. To that end, LEKOIL has
been helping improve the quality of life for the residents.
We have organised events, working with local non-profit organizations to bring the
community together. We have signed a land lease agreement with the people of Ikuru backed
by a Memorandum of Understanding that places on us a responsibility to develop
sustainably. We have also operated a health outreach programme, providing medical services
to those with greatest need. From the youngest to the oldest, we provided vaccinations,
health checks, eye tests and glasses, and surgery for those in most urgent need. We
understand it was gratefully received.
Not only is LEKOIL providing active help to the communities surrounding our ?rst
development, it is also a sponsor of three pan-African initiatives aimed at empowering
children, helping women in business and spreading an entrepreneurial culture.
LEKOIL supports educational competition with Spellbound Africa, an international spelling
competition that challenges children studying in Africa. Spellbound Africa is the ?rst
English word-spelling contest among children aged between 10 and 15 in the
English-Speaking African countries. It gathers the most hard working and word-versatile
children in the continent and engages them.
We are also promoting diversity and equality with Women in Management, Business and Public
Service (WIMBIZ), a Nigeria based non-pro?t organisation with an overriding vision "to be
the catalyst that elevates the status and in?uence of women and their contribution to
nation building". WIMBIZ programmes are geared towards elevating the status of women and
their contributions to nation building, increasing the success rate of female
entrepreneurs and the proportion of women in senior positions in corporate organisations.
Finally, LEKOIL is a supporter of ENACTUS, an international not-for-pro?t organisation
with a community of students, academic and business leaders. ENACTUS is committed to using
the power of entrepreneurial action to transform lives and shape a better more sustainable
world by providing a platform for teams of outstanding university students to create
community development projects that put people's own ingenuity and talents at the centre
of improving their livelihoods.
Environment
Nigeria's Environmental Impact Assessment Act (EIAA) requires every company whose activity
or project is likely to have a signi?cant e?ect on the environment to carry out an impact
assessment programme prior to the commencement of the project.
LEKOIL is committed to demonstrating leadership in stewardship of the environment, and in
complying with the requirements and regulations in Nigeria, as well as in every other
territory in which we operate. We believe we have demonstrated this commitment in our
operations in the communities surrounding our Otakikpo development.
These outcomes do not happen by accident. They occur because of the technical expertise of
our people and partners. They happen because of a strong leadership team. And they happen
because we hold true to our values - especially our ability to think di?erently.
Outlook
Our ambition to grow our business for our shareholders remains undiminished. We seek to do
so in two ways: first, by adding value to, and/or monetising existing assets and second,
by value accretive acquisitions.
Our priority for 2018 is to continue to grow production volumes at Otakikpo. In order to
achieve our target of 20,000 bopd in 2020, we must finalise and then implement Phase 2 of
our field development plan. The first step will be to complete the 3D data acquisition and
interpretation that began in February 2018 prior to drilling additional production wells
and expanding the processing and evacuation facilities to cope with the higher volumes.
Upside for our Otakikpo interests could also be delivered from exploration and appraisal
drilling on structures identified to the south of the current producing field.
In tandem with the further development of Otakikpo, we will aim in 2018 to progress the
appraisal and development of our Ogo discovery in OPL 310. Assuming we receive the second
Ministerial Consent for the acquisition of Afren's 22.86% working interest, we plan to
finalise funding plans for an appraisal drilling programme. The programme will comprise of
two wells, which will include flow testing. This is scheduled to begin in late second half
of this year. Our aim is to secure enough information to enable the partners to take a
Final Investment Decision in 2019 and then to proceed with development in partnership with
GE Oil & Gas.
We will continue to study acquisition opportunities in our areas of geographic interest
where we believe we can add material value. Such opportunities may take the form of
farm-ins to 'near to' production assets, outright corporate vehicle acquisitions or
potential new business streams in the energy or mid-stream space.
2018 will therefore provide a number of key catalysts for value appreciation for
shareholders as we continue to lay the foundations for what we believe will become a
leading African focused exploration and production business.
Samuel Adegboyega Olalekan Akinyanmi
Chairman Chief Executive Officer
1 June 2018
Financial Review
Overview
LEKOIL had a successful year bringing commercial oil production online in February 2017,
securing debt financing US$30 million and Naira 9.5 billion for the development of
Otakikpo thereby delivering on the key objective for 2017. The results reflect its first
year with production and with gearing, excluding trade payables, at 16% providing the
financial requirement to invest in the business. The Group recorded a total comprehensive
profit of US$6.5 million for the year ended 31 December 2017 (2016: US$15.8 million). Cash
and cash balances at the end of the year were US$6.9 million (2016: US$3.3 million), with
year end net debt of $63.8 million (2016: $62.5 million).
In US '000s Dollars 2017 2016
Cash and cash balances 6,922 3,283
Net debt 63,766 62,523
Working Interest Revenue 30,848 -
Profit/ (loss) for the year 6,496 (15,772)
Profit/ (loss) per share 0.01 (0.03)
Cash flow (used in)/ generated from operations (11,712) (8,822)
Production and Revenues
Revenues derived from 11 months of commercial production from Otakikpo were US$30.8
million. Total production from the Otakikpo marginal field for the year was 1,560,125
gross barrels. The Group's entitlement crude was 1,223,248 barrels. Of these barrels, the
Group lifted 1,188,732 barrels (31 December 2016: nil) and the balance of 34,516 barrels
representing the Group's share of overriding royalty crude was lifted on its behalf by its
joint venture partner based on an agreed lifting arrangement. The entitlement crude is
comprised of equity crude of 583,720 barrels (sales value US$30.8 million) and cost
recovery crude of 639,528 barrels (US$ 33.7 million). The cost recovery crude is not
included in revenue and is utilized to reduce prepaid development costs borne by the Group
on behalf of partner GEIL. The Group's realised oil price was US$52.65 for the year. The
Group does not currently have oil price hedging in place apart from amounts required under
the current debt facilities however as part of the Company's risk management strategy this
approach will be reviewed during 2018.
Cost of sales, depreciation, impairments and administrative expenditure
Underlying cost of sales were US$15.9 million or US$25.5/bbl (2016: Nil). Depletion and
amortisation costs on oil and gas assets were US$6.2 million (2016: US$0.2 million) or
US$9.9/ bbl.
General and administrative expenses were US$17.4 million compared to US$21.1 million for
the same period in 2016. Operating expenses were US$11.3 million as at 31 December 2017
compared to US$0.6 million as at 31 December 2016. The decrease in general &
administrative expenses in 2017 was due to the re-allocation of certain overheard costs to
operating expenses following the commencement of production. The production bonus (a one
off obligation arising from the terms of the licence farm-in agreement with GEIL) was
US$4.0 million and was paid in December 2017 (2016: nil). Exploration and evaluation
expenses in respect of the block 2514A write off and goodwill impairment expense on
Ashbert Oil and Gas Limited Acquisition were US$0.7 million (2016: nil).
Capital investment
The Group's capital expenditure for the year was US$8.4 million (2016: US$26.3 million)
and focused on additional Otakikpo storage tanks and exploration and appraisal activities
of the Group's interests in OPL 310 and OPL 325.
Taxes
As a Nigerian producing business, the Group became subject to the Petroleum Profit Tax Act
of Nigeria (PPTA) and the Company Income Tax Act of Nigeria (CITA). Tax benefit for year
was US$21.3 million made up of Petroleum Profit Tax of US$0.2 million, Company Income Tax
expense of US$1.6 million (2016: nil), Tertiary Education Tax expense of US$0.1 million,
and a Deferred Tax credit of US$23.2 million was recognized in relation to Lekoil Oil and
Gas Limited (the holder of the Otakikpo producing asset).
Profit/ (loss) for the year and loss per share
The Group recorded a total comprehensive profit of US$6.5 million for the year to 31
December 2017 (2016: loss of US$15.8 million) and a basic and diluted profit per share of
US$1 cent (2016: loss of US$3 cents).
Cash and bank balances
The Group had cash and bank balances of US$6.9 million as at 31 December 2017 (2016:
US$3.3 million). Restricted cash of US$3.3 million (2016: US$1.1 million), which
represents cash funding of the debt service reserve accounts for two quarters of interest
for FBN Capital Notes and one quarter of interest and principal payment of the Shell
Western facility, has been reported as part of other assets.
Loans and borrowings
The Group had the following debt facilities in place at year end:
In US$'000 Interest rate p.a. 2017 2016
US$10 million FBNC Dollar 11.25% + LIBOR 5,828 9,455
Facility
4.5 billion naira FBNM 6% + NIBOR 7,212 14,351
Naira Facility
US$15 million Shell 10% + LIBOR 13,275 -
Facility
5 billion naira Sterling 26% 2,191 3,584
Bank Facility
US$5 million FBNM working 11.25% + LIBOR 1,003 -
Facility
Total 29,509 27,390
Less borrowings, current (17,317) (10,366)
Borrowings, non-current 12,192 17,024
Please refer to note 29 in the financial statements for a further breakdown.
Assets and liabilities
The Group's non-current assets were US$210.4 million as at 31 December 2017 (US$191.8
million at 31 December 2016), reflecting depreciation, depletion and amortization of oil
and gas assets during the year, including the initial recognition of deferred tax assets
of US$23.2 million (2016: nil). Current assets, which represent the Group's cash
resources, other assets and other receivables, decreased from US$72.1 million as at 31
December 2016 to US$66.1 million as at 31 December 2017. The decrease is as a result of a
reduction in prepaid development costs which relate to the Otakikpo field cost recovery
arrangement under the GEIL farm out agreement. Inventories which consist of the Group's
share of crude stock increased from US$0.7 million as at 31 December 2016 to US$1.1
million as at 31 December 2017.
Current liabilities consist of the loan facilities set out above due within twelve months,
amounting to US$17.3 million (31 December 2016: US$10.4 million), trade and other payables
amounting to US$32.5 million (31 December 2016: US$30.9 million), income tax payable
amounting to US$1.9 million (31 December 2016: nil) and deferred income representing
interest on prepaid development costs amounting to US$6.7 million (31 December 2016:
US$7.4 million).
Dividend
The Directors do not recommend the payment of a dividend for the year ended 31 December
2017 (2016: Nil).
Accounting policies
The Group's significant accounting policies and details of the significant judgments and
critical accounting estimates are disclosed within the notes to the financial statements.
The Group has not made any material changes to its accounting policies in the year ended
31 December 2017.
Liquidity risk management and going concern
The Group closely monitors and manages its liquidity risk and ability to service debt as
it falls due. Cash forecasts are regularly produced and sensitivities run for different
scenarios including (but not limited to) changes in production rates and commodity
pricing, and cost overruns for approved projects.
At 31 December 2017, the Group had liquid resources of approximately US$6.9 million in the
form of cash and bank balances available to meet capital, operating and administrative
expenditure.
The ability of the Group to continue to operate as a going concern is dependent on a
number of factors considered by the Directors as disclosed below:
? The ability of the Group to maintain steady state production and lifting on the
Otakikpo marginal field;
? The operational success of the Otakikpo Phase 2 field development and planned growth
in production to 20,000 bopd;
? Commodity pricing given there is no oil price hedging currently in place other than
that required by lenders for debt service;
? Availability of financing for development of OPL310, which is not currently factored
into the cash forecasts; and
? Ability to defer activities to future periods in the event required.
The Directors have determined that over the course of the next 12 months and taking into
consideration the factors mentioned above, there is a reasonable expectation there will be
a sufficient source of funds for the Group. In making their assessment, the Directors have
considered the Group's current cash position and the generation of funds from forecast
production over the period, against the need to service the Group's debt portfolio, and
tested the scenarios at different commodity prices. The Group further anticipates that
additional funding, if appropriate, could be met by the divestment of assets along with
access to the debt and capital markets. Based on their assessment, and taking into
consideration the material uncertainties that exist, the Directors have a reasonable
expectation that the Group will be able to continue in operation and meet its liabilities
as they fall due over the 12 month period in 2019.
These annual consolidated financial statements therefore have been prepared on the going
concern basis of accounting, which assumes the Group will continue in operation for the
foreseeable future and be able to realise its assets and discharge its liabilities and
commitments in the normal course of business.
Lisa Mitchell
Chief Financial Officer
1 June 2018
Statement of Directors' Responsibilities in relation to the consolidated financial
statements
The Directors of LEKOIL Limited ("the Company" and its subsidiaries (together referred to
as "the Group")) are responsible for the preparation of consolidated financial statements
that give a true and fair view of the financial position of the Group as at 31 December
2017, and the results of their operations, cash flows and changes in equity for the year
ended, in compliance with International Financial Reporting Standards ("IFRS").
In preparing the consolidated financial statements, the Directors are responsible for:
? properly selecting and applying accounting policies;
? presenting information, including accounting policies, in a manner that provides
relevant, reliable, comparable and understandable information;
? providing additional disclosures when compliance with the specific requirements in
IFRSs are insufficient to enable users to understand the impact of particular
transactions, other events and conditions on the Group's financial position and
financial performance; and
? making an assessment of the Group's ability to continue as a going concern.
The Directors are responsible for:
? designing, implementing and maintaining an effective and sound system of internal
controls throughout the Group; maintaining adequate accounting records that are
sufficient to show and explain the Group's transactions and disclose with reasonable
accuracy at any time the financial position of the Group, and which enable them to
ensure that the financial statements of the Group comply with IFRS; maintaining
statutory accounting records in compliance with the legislation of Nigeria and IFRS;
? taking such steps as are reasonably available to them to safeguard the assets of the
Group; and
? preventing and detecting fraud and other irregularities.
Going concern:
The Directors have made an assessment of the Group's ability to continue as a going
concern and as disclosed in Note 2(b), and they believe the Group will remain a going
concern in the year ahead.
The consolidated financial statements for the year ended 31 December 2017 were approved by
the Directors on 1 June 2018.
Signed on behalf of the Board of Directors by:
Olalekan Akinyanmi Lisa Mitchell
Chief Executive Officer Chief Financial Officer
1 June 2018
INDEPENT AUDITOR'S REPORT
To the Shareholders of Lekoil Limited
Opinion
We have audited the consolidated financial statements of Lekoil Limited ("the Company")
and its subsidiaries (together referred to as "the Group") which comprise the consolidated
statement of financial position as at 31 December 2017, and the consolidated statement of
profit or loss and other comprehensive income, the consolidated statement of changes in
equity and the consolidated statement of cash flows for the year then ended, and the notes
to the consolidated financial statements, including a summary of significant accounting
policies.
In our opinion, the consolidated financial statements present fairly, in all material
respects, the consolidated financial position of Lekoil Limited as at 31 December 2017,
and the consolidated financial performance and statement of cash flows for the year then
ended in accordance with the International Financial Reporting Standards (IFRS) as adopted
by the European Union (EUIFRS).
Basis for Opinion
We conducted our audit in accordance with International Standards on Auditing (ISAs). Our
responsibilities under those standards are further described in the Auditor's
Responsibilities for the Audit of the Consolidated Financial Statements section of our
report. We are independent of the Group in accordance with the requirements of the
International Ethics Standards Board for Accountants' Code of Ethics for Professional
Accountants (IESBA Code) and other independence requirements applicable to performing
audits of financial statements. We believe that the audit evidence we have obtained is
sufficient and appropriate to provide a basis for our opinion.
Material Uncertainty Related to Going Concern
We draw attention to Note 2(b) in the consolidated financial statements, which indicates
that the Group has a negative operating cash flows of US$11.7 million for the year ended
31 December 2017 and as of that date, the Group's accumulated deficits amounts to US$61.9
million (2016: US$67 million). These events or conditions, along with other matters as set
forth in Note 2(b), indicate that a material uncertainty exists that may cast significant
doubt on the Group's ability to continue as a going concern. Our opinion is not modified
in respect of this matter.
Key Audit Matters
Key audit matters are those matters that, in our professional judgment, were of most
significance in our audit of the consolidated financial statements of the current year.
These matters were addressed in the context of our audit of the consolidated financial
statements as a whole, and in forming our opinion thereon, and we do not provide a
separate opinion on these matters. In addition to the matter described in the Material
Uncertainty Related to Going Concern section above, we have determined the matters
described below to be the key audit matters to be communicated in our report on the
consolidated financial statements.
Key Audit Matter How the matter was addressed in
the audit
Revenue recognition
Lekoil Oil and Gas Investment To test the appropriateness of
Limited, a subsidiary of Lekoil the revenue recognition, we
Limited, entered into a joint performed the following
operating agreement with Green procedures:
Energy International Limited
(GEIL) on the Otakikpo marginal
field in OML 11 with a 40%
interest while GEIL retained
60%.
? Reviewed the design, the
Following an agreement to implementation and the
finance GEIL's 60% of the operating effectiveness of
Initial Field Development Costs the controls surrounding
(IFDC), the company was awarded revenue recognition.
48% of GEIL's 60% equity crude
(less Government and overriding
royalty) to recover such costs
plus an average interest of 10%
-13% until payout is achieved
? Performed detailed
substantive procedures on
revenue recognition taking
into consideration the
appropriateness of the
Lekoil therefore currently allocation of sales proceeds
sells its crude entitlement between revenue and prepaid
being a combination of equity development costs.
share of 40% and 48% crude oil
recovery from GEIL Free On
Board (FOB) to Shell Western
Supply and Trading Limited.
Revenue is recognized on the
basis of the Company's equity
participation of 40% of the
production, while the remaining
There is a risk that revenue 48% is taken as recovery to
may be misstated due to unwind the IFDC cost incurred
improper recognition of revenue on behalf of GEIL.
amount.
We found the Group's revenue
recognition for the current
year appropriate and this has
been adequately disclosed in
the consolidated financial
statements.
Share based payment arrangements
The Group has three share based We focused our testing of the
payments arrangements - The fair value of the share based
Share option scheme, payments on the key assumptions
Non-Executive Director share made by the management.
plan and Long term incentive
plan scheme.
Our audit procedures included:
The Directors engaged the
services of an expert in order
to calculate the fair value of ? Evaluating the model used
these share options. The fair by the Management's experts
value is determined based on to determine the fair value
various assumptions such as of the share based payment
share price, weighted average arrangements and also to
life of share option, expected ascertain compliance with the
volatility, etc. requirements of IFRS 2 Share
based Payments.
This is a complex account
balance which is subject to a ? Validating the inputs used
significant amount of estimates to calculate the fair value
and assumptions and recalculating this value.
? Evaluating the
reasonableness of the
estimates and assumptions
used by management and
management's expert.
We found the assumptions used
by the management in the
calculation of the fair value
of the share based payment to
be appropriate and the Group's
share based payments for the
year have been adequately
valued and disclosed in the
financial statements.
Carrying value of Exploration and Evaluation assets
Exploration and Evaluation We focused our testing of the
assets represent a significant impairment assessment of
portion of the Group's total Exploration and Evaluation
assets. These assets have been assets on the key assumptions
recognised in the consolidated made by management.
statement of financial position
in relation to the Group's
interest in OPL 310, OPL 325
and Block 2514B. Our audit procedures included:
As required by the applicable ? Evaluating the
accounting standards, appropriateness and the
management conducts an annual reasonableness of the model
impairment assessment to and inputs used by management
determine the existence of an and also to ascertain whether
impairment trigger and assesses it complies with the
the recoverability of the requirements of IFRS 6
carrying value of the E&E Exploration for and
assets. This is performed using Evaluation of Mineral
discounted cash flow models. As Resources and IAS 36
disclosed in note 17, Impairment of Assets.
management has made a number of
key sensitive judgments in
determining the inputs into
these models.
? Challenging the assumptions
used by management regarding
future development and fiscal
matters.
Accordingly, the impairment
test of these assets is
considered to be a key audit
matter.
? Analysing the future
projected cash flows used in
the models to determine
whether they are reasonable
and consistent with the
current oil price climate and
expected future performance
of the field.
? Comparing the projected
cash flows, including the
assumptions relating to
production, price and
operating margins, against
market peers to test the
reasonableness of
management's projections.
We found the assumptions used
by management in the
determination of the net
present value of cash flows on
the exploration and evaluation
assets to be appropriate and as
such impairment charge is not
considered necessary.
Other Information
The Directors are responsible for the other information. The other information comprises
the Chairman's and CEO's Statements, Financial Review, Directors' Report and Remuneration
Committee's Report, which we obtained prior to the date of this auditor's report. The
other information does not include the consolidated financial statements and our auditor's
report thereon.
Our opinion on the consolidated financial statements does not cover the other information
and we do not express any form of assurance conclusion thereon.
In connection with our audit of the consolidated financial statements, our responsibility
is to read the other information and, in doing so, consider whether the other information
is materially inconsistent with the financial statements or our knowledge obtained in the
audit, or otherwise appears to be materially misstated.
Based on the work we have performed on the other information that we obtained prior to the
date of this auditor's report, if we conclude that there is a material misstatement of
this other information, we are required to report that fact. We have nothing to report in
this regard.
Auditor's Responsibilities for the Review of the Consolidated Financial Statements
Our objectives are to obtain reasonable assurance about whether the consolidated financial
statements as a whole are free from material misstatement, whether due to fraud or error,
and to issue an auditor's report that includes our opinion. Reasonable assurance is a high
level of assurance, but is not a guarantee that an audit conducted in accordance with ISAs
will always detect a material misstatement when it exists. Misstatements can arise from
fraud or error and are considered material if, individually or in the aggregate, they
could reasonably be expected to influence the economic decisions of users taken on the
basis of these consolidated financial statements.
As part of an audit in accordance with ISAs, we exercise professional judgment and
maintain professional skepticism throughout the audit. We also:
? Identify and assess the risks of material misstatement of the consolidated financial
statements, whether due to fraud or error, design and perform audit procedures
responsive to those risks, and obtain audit evidence that is sufficient and appropriate
to provide a basis for our opinion. The risk of not detecting a material misstatement
resulting from fraud is higher than for one resulting from error, as fraud may involve
collusion, forgery, intentional omissions, misrepresentations, or the override of
internal control.
? Obtain an understanding of internal control relevant to the audit in order to design
audit procedures that are appropriate in the circumstances, but not for the purpose of
expressing an opinion on the effectiveness of the Group's internal control.
? Evaluate the appropriateness of accounting policies used and the reasonableness of
accounting estimates and related disclosures made by the directors.
? Conclude on the appropriateness of the directors' use of the going concern basis of
accounting and based on the audit evidence obtained, whether a material uncertainty
exists related to events or conditions that may cast significant doubt on the Group's
ability to continue as a going concern. If we conclude that a material uncertainty
exists, we are required to draw attention in our auditor's report to the related
disclosures in the consolidated financial statements or, if such disclosures are
inadequate, to modify our opinion. Our conclusions are based on the audit evidence
obtained up to the date of our auditor's report. However, future events or conditions
may cause the Group to cease to continue as a going concern.
? Evaluate the overall presentation, structure and content of the consolidated financial
statements, including the disclosures, and whether the consolidated financial statements
represent the underlying transactions and events in a manner that achieves fair
presentation.
? Obtain sufficient appropriate audit evidence regarding the financial information of
the entities or business activities within the Group to express an opinion on the
consolidated financial statements. We are responsible for the direction, supervision and
performance of the group audit. We remain solely responsible for our audit opinion.
We communicate with the Audit Committee regarding, among other matters, the planned scope
and timing of the audit and significant audit findings, including any significant
deficiencies in internal control that we identify during our audit.
We also provide the Audit Committee with a statement that we have complied with relevant
ethical requirements regarding independence, and to communicate with them all
relationships and other matters that may reasonably be thought to bear on our
independence, and where applicable, related safeguards.
From the matters communicated with the Audit Committee, we determine those matters that
were of most significance in the audit of the consolidated financial statements of the
current period and are therefore the key audit matters. We describe these matters in our
auditor's report unless law or regulation precludes public disclosure about the matter or
when, in extremely rare circumstances, we determine that a matter should not be
communicated in our report because the adverse consequences of doing so would reasonably
be expected to outweigh the public interest benefits of such communication.
Olufemi Abegunde FCA-FRC/2013/ICAN/000000004507
for: Deloitte & Touche Nigeria
Chartered Accountants
Lagos, Nigeria
1 June 2018
Consolidated statement of pro?t or loss and other comprehensive income
For the year ended 31 December
Notes 2017 Restated*
US$'000 2016
US$'000
Revenue 8 30,848 -
Cost of sales 9 (15,913) -
Gross profit 14,935 -
Operating expenses 10 (11,329) (629)
Production bonus 11 (4,000) -
Exploration & evaluation expenses 12 (718) -
General and administrative expenses 13 (17,405) (21,082)
Operating loss (18,117) (21,711)
Finance income 14 11,349 6,868
Finance costs 14 (8,073) (929)
Net finance income 3,276 5,939
Loss before income tax (14,841) (15,772)
Income tax benefit 15 (d) 21,337 -
Profit/ (loss) for the year 6,496 (15,772)
Total comprehensive profit/ (loss) 6,496 (15,772)
Attributable to:
Owners of the Company 5,150 (14,906)
Non-controlling interests 1,346 (866)
6,496 (15,772)
Total comprehensive profit/ (loss) for 6,496 (15,772)
the year
Profit/ (loss) per share:
Basic profit/ (loss) per share ($) 16 (a) 0.01 (0.03)
Diluted profit/ (loss) per share ($) 16 (b) 0.01 (0.03)
*Certain amounts shown here do not correspond to the 2016 financial statements and reflect
restatements made, refer to Note 3(r).
The notes below are an integral part of these consolidated ?nancial statements.
Consolidated statement of ?nancial position
As at 31 December
Notes 2017 Restated*
US$'000 2016
US$'000
Non-current assets
Property, plant and equipment 17 34,593 39,625
Exploration and evaluation assets 18 130,773 128,732
Intangible assets 19 6,269 8,237
Deferred tax assets 15 23,249 -
Other receivables 22 2,487 2,422
Other assets 23 13,000 12,756
210,371 191,772
Current assets
Inventories 20 1,090 672
Trade receivables 21 6,044 -
Other receivables 22 3,680 57
Other assets 23 5,901 1,288
Pre-paid development costs 24 42,463 66,825
Cash and bank balances 25 6,922 3,283
66,100 72,125
Total assets 276,471 263,897
Current liabilities
Trade and other payables 26 32,475 30,899
Current tax payables 15 1,912 -
Deferred income 28 6,685 7,426
Loans and borrowings 29 17,317 10,366
58,389 48,691
Non-current liabilities
Provision for Asset Retirement 27 107 91
Obligation
Loans and borrowings 29 12,192 17,024
12,299 17,115
Total liabilities 70,688 65,806
Net assets 205,783 198,091
Capital and reserves
Share capital 30(a) 27 27
Share premium 30(b) 264,004 264,004
Accumulated deficit (61,855) (67,005)
Other reserves 22 22
Share based payment reserve 7,675 6,479
Equity attributable to owners of the 209,873 203,527
Company
Non-controlling interests 31 (4,090) (5,436)
Total equity 205,783 198,091
*Certain amounts shown here do not correspond to the 2016 financial statements and reflect
restatements made, refer to Note 3(r).
These consolidated ?nancial statements were approved by the Board of Directors on 01 June
2018 and signed on its behalf by:
Olalekan Akinyanmi - Chief Lisa Mitchell - Chief
Executive Officer Financial Officer
The notes on below are an integral part of these consolidated ?nancial statements.
Consolidated statement of changes in equity
For the year ended 31 December
In US$'000
Restated*
Notes Share Share Accumulated Other Share-based Total Non-controlling Total
capit premi deficit reser payments interests equit
al um ves reserve y
As at 1 24 252,2 (52,099) 22 5,174 205,3 (4,570) 200,7
January 2016 08 29 59
Total
comprehensiv
e loss for
the year
Loss for the - - (14,906) - - (14,9 (866) (15,7
year 06) 72)
Transactions
with owners
of the
Company
Issue of 3 11,79 - - - 11,79 - 11,79
ordinary 6 9 9
shares
Share-based 32 - - - - 1,305 1,305 - 1,305
payment-
personnel
expenses
As at 31 27 264,0 (67,005) 22 6,479 203,5 (5,436) 198,0
December 04 27 91
2016
Total
comprehensiv
e profit for
the year
Profit for - - 5,150 - - 5,150 1,346 6,496
the year
Transactions
with owners
of the
Company
Share-based 32 - - - - 1,196 1,196 - 1,196
payment-
personnel
expenses
Balance at 27 264,0 (61,855) 22 7,675 209,8 (4,090) 205,7
31 December 04 73 83
2017
*Certain amounts shown here do not correspond to the 2016 financial statements and reflect
restatements made, refer to Note 3(r).
The notes below are an integral part of these consolidated ?nancial statements.
Consolidated statement of cash ?ows
For the year ended 31 December
Notes 2017 Restated*
US$'000 2016
US$'000
Operating activities
Total comprehensive profit/ (loss) for 6,496 (15,765)
the year
Adjustments to reconcile total
comprehensive loss to net cash
generated from/ (used in) by operating
activities:
- Equity-settled share-based payment 1,196 1,305
- Finance income - (73)
- Property, plant and equipment 4,423 -
restatement
- Prepaid development costs restatement 5,477 -
- Prepaid development costs carried (6,921) (5,058)
interest
- Intangible cost adjustment 291 -
- Derecognition of block 2514A 268 -
- Finance cost 6,850 -
- Revaluation adjustments (2,649) -
- Deferred tax (23,249) -
- Depreciation and amortization 17&19 8,366 1,196
Cash flow generated from/(used in) 548 (18,395)
operations before working capital
adjustments
Changes in:
Inventory (418) (672)
Trade and other payables 835 29,263
Other assets (4,857) (1,851)
Trade and other receivables (9,732) 477
Cash (used in)/generated from (13,624) 8,822
operations
Income taxes 1,912 -
Net cash (used in)/generated from (11,712) 8,822
operating activities
Investing activities
Acquisition of property, plant and 17 (6,080) (24,924)
equipment
Prepaid development costs 24 (7,894) (32,960)
Recoveries from prepaid development 24 33,700 -
costs
Expenditure on behalf of Partner - (396)
Interest received - 73
Acquisition of exploration and 18 (2,309) (675)
evaluation assets
Acquisition of intangible assets 19 - (672)
Net cash generated from/(used in) 17,417 (59,554)
investing activities
Financing activities
Proceeds from issue of share capital 30 - 11,799
Proceeds from issue of loan note 29 18,137 28,028
Repayment of loan 29 (13,568) (8,000)
Interest and transaction costs related 29 (6,635) (3,828)
to loan
Net cash (used in)/generated from (2,066) 27,999
financing activities**
Increase/(decrease) in cash and bank 3,639 (22,733)
balances
Cash and bank balances at 1 January 25 3,283 26,016
Cash and bank balances at 31 December 25 6,922 3,283
*Certain amounts shown here do not correspond to the 2016 financial statements and reflect
restatements made, refer to Note 3(r).
**Changes in liabilities arising from financing activities have been disclosed in note
29(e).
The notes below are an integral part of these consolidated ?nancial statements.
Notes to the ?nancial statements
1 Reporting entity
Lekoil Limited (the "Company" or "Lekoil") is a company domiciled in the Cayman Islands
with registration number WK- 248859. The address of the Company's registered office is
Intertrust Group, 190 Elgin Avenue, Georgetown, Grand Cayman, Cayman Islands. These
consolidated financial statements comprise the Company and its subsidiaries (together
referred to as the "Group" and individually as "Group entities"). The Group's principal
activity is exploration and production of oil and gas.
2 Basis of preparation
(a) Statement of compliance
These consolidated financial statements have been prepared in accordance with
International Financial Reporting Standards (IFRS) as adopted by the European Union (EU).
The consolidated financial statements were authorised for issue by the Board of Directors
on 1 June 2018.
A number of new standards, amendments to standards and interpretations effective for
annual periods beginning after 1 January 2017, have not been applied in preparing these
consolidated financial statements.
(b) Going concern basis of accounting
These consolidated financial statements have been prepared on the going concern basis of
accounting.
The Group closely monitors and manages its liquidity risk and ability to service debt as
it falls due. Cash forecasts are regularly produced and sensitivities run for different scenarios over both a detailed 13 week forecast period and a rolling 12 month period. The ability of the Group to continue to operate as a going concern is dependent on a number of factors considered by the Directors as disclosed below: ? The ability of the Group to maintain steady state production and liftings on the Otakikpo marginal field; ? The operational success of the Otakikpo Phase 2 field development and planned growth in production to 20,000 bopd; ? Commodity pricing given there is no oil price hedging currently in place, other than that required by the lenders for debt service; ? Availability of financing for development of OPL310, which is not currently factored into the preparation of the cashflow; and ? Ability to defer activities to future periods in the event required. The Directors have determined that over the course of the next 12 months and taking into consideration the factors mentioned above, there is a reasonable expectation that there will be sufficient sources of funds for the Group. In making their assessment, the Directors have considered the Group's current cash position and the generation of funds from forecast production over the period, against the need to service the Group's debt portfolio, and tested the scenarios at different commodity prices. The Company further anticipates that additional funding, if appropriate, could be met by the divestment of assets along with access to the debt and capital markets. Based on their assessment, and taking into consideration the material uncertainties that exist, the Directors have a reasonable expectation that the Company will be able to continue in operation and meet its liabilities as they fall due over the 12 month period in 2019. Accordingly the Directors continue to adopt the going concern basis of preparation of the financial statements for the year ended 31 December 2017. (c) Basis of measurement These consolidated financial statements have been prepared on the historical cost basis except for share based payments which are measured at fair values. (d) Functional and presentation currency These consolidated financial statements are presented in US Dollars which is the Company's functional currency. All amounts have been rounded to the nearest thousands of dollars (1,000), unless otherwise indicated. (e) Use of estimates and judgments The preparation of these consolidated financial statements in conformity with IFRS requires management to make judgments, estimates and assumptions that affect the application of accounting policies and the reported amounts of assets, liabilities, income and expenses. Actual results may differ from these estimates. Estimates and underlying assumptions are reviewed on an ongoing basis. Revisions to accounting estimates are recognized prospectively. (i) Judgments Information about judgments made in applying accounting policies that have the most significant effects on the amounts recognized in the consolidated financial statements is included in the following notes: - Note 2(b) - Going concern basis of accounting. - Note 18(a) - Exploration and evaluation accounting judgment. The Group policy is to capitalise all expenditure incurred during the exploration and appraisal phase until the determination process has been completed or until such point as commercial reserves have been established. Exploration and evaluation assets are expected to be recouped in future through successful development and exploitation of the area of interest. - Note 18(c) - The Group has a reasonable expectation that OPL 310 license will be either extended for an additional 12 months or converted to OML as appropriate before the expiration date, based on the usual practice within the oil and gas industry in Nigeria and interaction with the appropriate government agencies. - Note 18(e) - The Group has concluded its consultation on whether Ministerial Consent is required before it can exercise control over Ashbert Oil and Gas Limited. The Group has a reasonable expectation that it does not require Ministerial Consent to exercise control over Ashbert and the interest in mineral rights in OPL 325 held by Ashbert. Consequently, 2016 balances have been restated to reflect Ashbert's transactions. - Note 23 - On the basis that the Group requires Ministerial Consent to take control of the oil mineral rights interest held by Afren Oil and Gas, the Group has not consolidated Afren Oil and Gas and has accounted for payments made in respect of the Afren Oil and Gas acquisition as other assets. (ii) Assumptions and estimation uncertainties Information about assumptions and estimation uncertainties that have a significant risk of resulting in a material adjustment to the carrying amounts of assets and liabilities in the year ended 31 December 2017 is included in the following notes: Note 2(b) - Going concern. Key assumptions made and judgment exercised by the Directors in preparing the Group's cash forecast. Note 15(c) - Unrecognised deferred tax assets. Availability of future taxable profit against which carry forward losses can be used. Notes 17, 18 and19 - Impairment test of property plant and equipment, exploration and evaluation assets and intangible assets: Key assumptions underlying recoverable amounts. Note 18(c) - The Directors are have a reasonable expectation that the license for OPL 310 will be converted or renewed as appropriate upon expiration. Note 18(d) - Carrying value of exploration and evaluation assets. Basis for the conclusion that the carrying value of E&E assets do not exceed their recoverable amount. Note 27- Provisions. Key assumptions underlying the obligation as at year end. Notes 23 and 24 - Carrying value of other assets and prepaid development costs. Basis for the conclusion that the carrying value of other assets and prepaid development costs do not exceed their recoverable amount. Note 32 - Share based payment arrangements. Key assumptions made in measuring fair values. Note 36 - Financial commitments and contingencies. Key assumptions about the likelihood and magnitude of an outflow of economic resources. Oil and gas reserves. Key assumptions underlying the estimation of oil and gas reserves. 3 Significant accounting policies The Group has consistently applied the following accounting policies to all periods presented in these consolidated financial statements. (a) Basis of consolidation (i) Business combinations The Group accounts for business combinations using the acquisition method when control is transferred to the Group. The consideration transferred in the acquisition is generally measured at fair value, as are the identifiable net assets acquired. Any goodwill that arises is tested annually for impairment. Any gain on a bargain purchase is recognised in profit or loss immediately. Transaction costs are expensed as incurred, except if related to the issue of debt or equity securities. The consideration transferred does not include amounts related to the settlement of pre-existing relationships. Such amounts are generally recognised in profit or loss. Any contingent consideration is measured at fair value at the date of acquisition. If an obligation to pay contingent consideration that meets the definition of a financial instrument is classified as equity, then it is not remeasured and settlement is accounted for within equity. Otherwise, other contingent consideration is remeasured at fair value at each reporting date and subsequent changes in the value of the contingent consideration are recognised in profit or loss. If share-based payments awards (replacement awards) are required to be exchanged for awards held by the acquiree's employees (acquiree's awards), then all or a portion of the amount of the acquirer's replacement awards is included in measuring the consideration transferred in the business combination. This determination is based on the market-based measure of the replacement awards compared with the market-based measure of the acquiree's award and the extent to which the replacement awards relates to pre-combination service. (ii) Non-controlling interests Non-controlling interests (NCI) are measured at their proportionate share of the acquiree's identifiable net assets at the acquisition date. Changes in the Group's interest in a subsidiary that do not result in a loss of control are accounted for as equity transactions. (iii) Subsidiaries Subsidiaries are entities controlled by the Group. The Group controls an entity if: i) it has power over the investee i.e. it has existing rights that give it the ability to direct the relevant activities (the activities that significantly affect the investee's returns) ii) it has exposure, or rights, to variable returns from its involvement with the investee iii) it has the ability to use its power over the investee to affect the amount of the investor's returns. The Group is deemed not to control an entity where regulatory approval is a substantive requirement for the passing of control. The financial statements of subsidiaries are included in the consolidated financial statements from the date that control commences until the date on which control ceases. (iv) Interests in equity-accounted investees The Group's interests in equity-accounted investees comprise interests in associates and a joint venture. Associates are those entities in which the Group has significant influence, but not control or joint control, over the financial and operating policies. A joint arrangement is an arrangement in which the Group has joint control, whereby the Group has rights to the net assets of the arrangement, rather than rights to its assets and obligations for the liabilities. Interests in associates and the joint venture are accounted for using the equity method.
They are initially recognised at cost, which includes transaction costs. Subsequent to initial recognition, the consolidated financial statements include the Group's share of the profit or loss and other comprehensive income (OCI) of equity-accounted investees, until the date on which significant influence or joint control ceases. (v) Transactions eliminated on consolidation Intra-group balances and transactions, and any unrealised income and expenses arising from intra-group transactions, are eliminated. Unrealised gains arising from transactions with equity-accounted investees are eliminated against the investment to the extent of the Group's interest in the investee. Unrealised losses are eliminated in the same way as unrealised gains, but only to the extent that there is no evidence of impairment. (b) Foreign currency (i) Foreign currency transactions Transactions in foreign currencies are translated into the respective functional currencies of Group entities at exchange rates at the dates of the transactions. Monetary assets and liabilities denominated in foreign currencies at the reporting date are translated to the functional currency at the exchange rate at the reporting date. Non-monetary assets and liabilities that are measured at fair value in a foreign currency are translated into the functional currency at the exchange rate when the fair value was determined. Non-monetary items that are measured based on historical cost in a foreign currency are translated at the exchange rate at the date of the transaction. Foreign currency differences are generally recognised in profit or loss. However, foreign currency differences arising from the translation of the following items are recognised in OCI: - available-for-sale equity investments (except on impairment, in which case foreign currency differences that have been recognised in OCI are reclassified to profit or loss); - a financial liability designated as a hedge of the net investment in a foreign operation to the extent that the hedge is effective; and - qualifying cash flow hedges to the extent that the hedges are effective. (ii) Foreign operations The assets and liabilities of foreign operations, including goodwill and fair value adjustments arising on acquisition, are translated into US Dollars at the exchange rates at the reporting date. The income and expenses of foreign operations are translated into US Dollars at the exchange rates at the dates of the transactions. Foreign currency differences are recognised in OCI and accumulated in the translation reserve, except to the extent that the translation difference is allocated to NCI. When a foreign operation is disposed of its entirety or partially such that control, significant influence or joint control is lost, the cumulative amount in the translation reserve related to that foreign operation is reclassified to profit or loss as part of the gain or loss on disposal. If the Group disposes of part of its interest in a subsidiary but retains control, then the relevant proportion of the cumulative amount is reattributed to NCI. When the Group disposes of only part of an associate or joint venture while retaining significant influence or joint control, the relevant proportion of the cumulative amount is reclassified to profit or loss. (c) Revenue (i) Sale of crude Revenue is recognised when the significant risks and rewards of ownership have been transferred to the customer, recovery of the consideration is probable, the associated costs and possible return of goods can be estimated reliably and there is no continuing management involvement with the crude and the amount of revenue can be measured reliably. Revenue is measured net of returns, trade discounts and volume rebates. (ii) Costs of sales Production expenditure, crude treatment and processing expenditure, crude evacuation and lifting expenditure, depreciation, depletion and amortisation of oil and gas assets and crude handling expenditure are reported as costs of sales. (iii) Interest income Interest income, including income arising from finance leases and other financial instruments, is recognised using the effective interest method. (iv) Overlift and underlift Overlift/ underlift arises when the Group lifts more than/ or less than its volume of working interest crude. The Group adopts the entitlements method in which revenue is recognised as its share of working interest crude while a payable (overlift) or receivable (underlift) is reported for the difference between volumes it sold and its working interest. The initial measurement of the overlift liability and underlift asset is at the market price of the crude at the date of lifting. (d) Share capital (i) Ordinary shares Ordinary shares are classified as equity. Incremental costs directly attributable to the issue of ordinary shares are recognised as a deduction from equity, net of any tax effects. (e) Financial instruments The Group classifies non-derivative financial assets into loans and receivables and non-derivative financial liabilities into the other financial liabilities category. (i) Non-derivative financial assets The Group initially recognizes loans and receivables on the date that they are originated. All other financial assets and financial liabilities are recognised initially on the trade date at which the Group becomes a party to the contractual provisions of the instrument. The Group derecognises a financial asset when the contractual rights to cash flows from the asset expire, or it transfers the rights to receive the contractual cash flows in a transaction in which substantially all the risks and rewards of ownership of the financial asset are transferred or it neither transfers nor retains substantially all of the risks and rewards of ownership and does not retain control over the transferred asset. Any interest in such derecognised assets that is created or retained by the Group is recognised as a separate asset or liability. Financial assets and liabilities are offset and the net amount presented in the statement of financial position when, and only when, the Group has a legal right to offset the amounts and intends either to settle them on a net basis or to realise the asset and settle the liability simultaneously. The Group has the following non-derivative financial assets: loans and receivables. Loans and receivables Loans and receivables are financial assets with fixed or determinable payments that are not quoted in an active market. Such assets are recognised initially at fair value plus any directly attributable transaction costs. Subsequent to initial recognition, loans and receivables are measured at amortised cost using the effective interest method, less any impairment losses. Short term loans and receivables that do not attract interest rate are measured at their original invoice amount where the effect of discounting is not material. Financial assets classified as loans and other receivables comprise cash and bank balances, trade and other receivables. Cash and bank balances Cash and bank balances comprise cash balances and call deposits with maturities of three months or less from the acquisition date that are subject to an insignificant risk of changes in their fair value, and are used by the Group in the management of its short-term commitments. (ii) Non-derivative financial liabilities All financial liabilities are recognised initially on the trade date at which the Group becomes a party to the contractual provisions of the instrument. The Group derecognises a financial liability when its contractual obligations are discharged, cancelled or expired. The Group has the following non-derivative financial liabilities: trade and other payables and loans & borrowings. Such financial liabilities are recognised initially at fair value less any directly attributable transaction costs. Subsequent to initial recognition, these financial liabilities are measured at amortised cost using the effective interest rate method. Short term payables that do not attract interest are measured at original invoice amount where the effect of discounting is not material. (iii) Impairment Non-derivative financial assets Financial assets not classified at fair value through profit or loss (FVTPL), including an interest in an equity-accounted investee, are assessed at each reporting date to determine whether there is objective evidence of impairment. A financial asset is impaired if there is an objective evidence of impairment as a result of one or more events that occurred after the initial recognition of the asset, and that loss event had an impact on the estimated future cash flows of that asset and can be estimated reliably. An impairment loss in respect of a financial asset measured at amortised cost is calculated as the difference between its carrying amount and the present value of the estimated future cash flows discounted at the asset's original effective interest rate. Losses are recognised in profit or loss and reflected in an allowance account against loans and receivables. Non-financial assets At each reporting date, the Group reviews the carrying amounts of its non-financial assets to determine whether there is any indication of impairment. If any such indication exists, then the asset's recoverable amount is estimated. For impairment testing, assets are grouped together into the smallest group of assets that generates cash inflows from continuing use that are largely independent of the cash inflows of other assets or cash generating units (CGUs). The recoverable amount of an asset or CGU is the greater of its value in use and its fair value less costs to sell. Value in use is based on the estimated future cash flows, discounted to their present value using a pre-tax discount rate that reflects current market assessments of the time value of money and the risks specific to the asset or CGU.
An impairment loss is recognised if the carrying amount of an asset or CGU exceeds its
recoverable amount. Impairment losses are recognised in profit or loss. An impairment loss
is reversed only to the extent that the asset's carrying amount does not exceed the
carrying amount that would have been determined, net of depreciation or amortisation, if
no impairment loss had been recognised.
(iv) Hedges
As part of the requirements under its debt facilities, the Group is required to hedge a
certain amount of production covering its forecasted debt service payments. The hedge
volume is a function of the estimated quarterly debt service payment and the designated
strike prices.
(f) Property, plant and equipment
(i) Recognition and measurement
Items of property, plant and equipment are measured at cost, which includes capitalised
borrowing costs, less accumulated depreciation and any accumulated impairment losses. Cost
includes expenditure that is directly attributable to the acquisition of the asset. When
parts of an item of property, plant and equipment have different useful lives, they are
accounted for as separate items (major components) of property, plant and equipment. Any
gain or loss on disposal of an item of property, plant and equipment (calculated as the
difference between the net proceeds from disposal and the carrying amount of the item) is
recognised in profit or loss.
(ii) Subsequent expenditure
Subsequent expenditure is capitalised only if it is probable that the future economic
benefits associated with the expenditure will flow to the Group.
(iii) Depreciation
Items of property, plant and equipment are depreciated from the date they are available
for use or, in respect of self-constructed assets, from the date that the asset is
completed and ready for use.
Depreciation is calculated to write off the cost of items of property, plant and equipment
less their estimated residual values using the straight-line basis over their estimated
useful lives. Depreciation is generally recognised in profit or loss, unless the amount is
included in the carrying amount of another asset. Leased assets are depreciated over the
shorter of the lease term and their useful lives unless it is reasonably certain that the
Group will obtain ownership by the end of the lease term.
The estimated useful lives of property, plant and equipment for the current and
comparative years are as follows:
* Motor vehicles - 5 years
* Furniture and ?ttings - 5 years
* Leasehold improvement - 2 years
* Computer and household - 4 years
equipment
* Leasehold property - 25 years
* Property, plant and machinery - 4 years
* Oil and gas assets - Unit of production method
based on estimated proved
developed reserves
Depreciation methods, useful lives and residual values are reviewed at each reporting date
and adjusted if appropriate.
(g) Exploration and Evaluation (E&E) expenditures
(i) licence acquisition costs: licence acquisition costs are capitalized as intangible E&E
assets. These costs are reviewed on a continual basis by management to confirm that
activity is planned and that the asset is not impaired. If no future activity is planned,
the remaining balance of the licence and property acquisition costs is written off.
Capitalised licence acquisition costs are measured at cost less accumulated amortisation
and impairment losses. Costs incurred prior to having obtained the legal rights to explore
an area are expensed directly as they are incurred.
(ii) Exploration expenditure: All exploration and appraisal costs are initially
capitalized in well, field or specific exploration cost centres as appropriate pending
future exploration work programmes and pending determination. All expenditure incurred
during the various exploration and appraisal phase is capitalized until the determination
process has been completed or until such point as commercial reserves have been
established. Payments to acquire technical services and studies, seismic acquisition,
exploratory drilling and testing, abandonment costs, directly attributable administrative
expenses are all capitalized as exploration and evaluation assets. Capitalised exploration
expenditure is measured at cost less accumulated amortisation and impairment losses.
Treatment of E & E assets at conclusion of exploratory and appraisal activities
Exploration and evaluation assets are carried forward until the existence, or otherwise,
of commercial reserves has been determined. If commercial reserves have been discovered,
the related E&E assets are assessed for impairment on a cost pool basis as set out below
and any impairment loss is recognised in the income statement. The carrying value, after
any impairment loss, of the relevant E&E assets is then reclassified as development and
production assets within property, plant and equipment or intangible assets. If however,
commercial reserves have not been found, the capitalised costs are charged to expense
after the conclusion of the exploratory and appraisal activities. Exploration and
evaluation costs are carried as assets and are not amortised prior to the conclusion of
exploratory and appraisal activities.
An E&E asset is assessed for impairment when facts and circumstances suggest that the
carrying amount may exceed its recoverable amount. Such circumstances include the point at
which a determination is made as to whether or not commercial reserves exist. Where the
E&E asset concerned falls within the scope of an established full cost pool, the E&E asset
is tested for impairment together with any other E&E assets and all development and
production assets associated with that cost pool, as a single cash generating unit. The
aggregate carrying value is compared against the expected recoverable amount of the pool,
generally by reference to the present value of the future net cash flows expected to be
derived from production of commercial reserves. Where the E&E asset to be tested falls
outside the scope of any established cost pool, there will generally be no commercial
reserves and the E&E asset concerned will be written off in full.
(h) Development expenditure
Once the technical feasibility and commercial viability of extracting oil and gas
resources are demonstrable, expenditure related to the development of oil and gas
resources which are not tangible in nature are classified as intangible development
expenditure. Capitalised development expenditure is measured at cost less accumulated
amortisation and impairment losses. Amortization of development assets attributable to the
participating interest is recognized in profit or loss using the unit-of-production
method.
(i) Leases
(i) Determining whether an arrangement contains a lease
At inception of an arrangement, the Group determines whether the arrangement is or
contains a lease.
At inception or on reassessment of an arrangement that contains a lease, the Group
separates payments and other consideration required by the arrangement into those for the
lease and those for other elements on the basis of their relative fair values. If the
Group concludes for a finance lease that it is impracticable to separate the payments
reliably, then an asset and a liability are recognised at an amount equal to the fair
value of the underlying asset; subsequently, the liability is reduced as payments are made
and an imputed finance cost on the liability is recognised using the Group's incremental
borrowing rate.
(ii) Leased assets
Assets held by the Group under leases that transfer to the Group substantially all of the
risks and rewards of ownership are classified as finance leases. The leased assets are
measured initially at an amount equal to the lower of their fair value and the present
value of the minimum lease payments. Subsequent to initial recognition, the assets are
accounted for in accordance with the accounting policy applicable to that asset.
Assets held under other leases are classified as operating leases and are not recognised
in the Group's statement of financial position.
(iii) Lease payments
Payments made under operating leases are recognised in profit or loss on a straight-line
basis over the term of the lease. Lease incentives received are recognised as an integral
part of the total lease expense, over the term of the lease.
Minimum lease payments made under finance leases are apportioned between the finance
expense and the reduction of the outstanding liability. The finance expense is allocated
to each period during the lease term so as to produce a constant periodic rate of interest
on the remaining balance of the liability.
(j) Inventories
Inventories comprise of crude oil stock at period end and consumable materials.
Inventories are valued at the lower of cost and net realisable value. Cost of consumable
materials is determined using the weighted average method and includes expenditures
incurred in acquiring the stocks, and other costs incurred in bringing them to their
existing location and condition.
Net realisable value is the estimated selling price in the ordinary course of business,
less the estimated costs of completion and selling expenses. Inventory values are adjusted
for obsolete, slow-moving or defective items where appropriate.
(k) Intangible assets
An intangible asset is an identifiable non-monetary asset without physical substance. The
Group expends resources or incurs liabilities on the acquisition, development, maintenance
or enhancement of intangible resources such as scientific or technical knowledge, design
and implementation of new processes on systems, licences, signature bonus, intellectual
property, market knowledge and trademarks.
The Group recognises an intangible asset if, and only if;
(a) economic benefits that are attributable to the asset will flow to the entity; and
(b) the costs of the asset can be measured reliably.
The Group assesses the probability of future economic benefits using reasonable and
supportable assumptions that represent management's best estimate of the set of economic
conditions that will exist over the useful life of the asset. Intangible assets are
measured initially at cost.
Amortisation is calculated to write off the cost of the intangible asset less its
estimated residual value using the straight-line basis over the estimated useful lives or
using the units of production basis from the date that they are available for use. The
estimated useful life and methods of amortisation of intangible assets for current and
comparative years are as follows:
Type of asset Basis
Mineral rights acquisition costs Unit of production method based
(signature bonus) on estimated proved developed
reserves.
Accounting software Amortised over a useful life of
three years.
Geological and geophysical Amortised over a useful life of
software ?ve years.
(l) Employee benefits
(i) Short-term employee benefits
Short-term employee benefit are expensed as the related service is provided. A liability
is recognised for the amount expected to be paid if the Group has a present legal or
constructive obligation to pay this amount as a result of past service provided by the
employee and the obligation can be estimated reliably.
(ii) Share-based payment transactions
The grant-date fair value of equity-settled share-based payment awards granted to
employees and others providing similar services is recognised as an employee expense and
other general and administrative expense respectively, with a corresponding increase in
equity, over the vesting period that the employees become unconditionally entitled to the
awards. The amount recognised as an expense is adjusted to reflect the number of awards
for which the related service and non-market performance conditions are expected to be
met, such that the amount ultimately recognised is based on the number of awards that meet
the related service and non-market performance conditions at the vesting date. For
share-based payment awards with non-vesting conditions, the grant-date fair value of the
share-based payment is measured to reflect such conditions and there is no true-up for
differences between expected and actual outcomes.
(iii) Post-employment benefits
Defined contribution plan
A defined contribution plan is a post-employment benefit plan (pension fund) under which
the Group pays fixed contributions into a separate entity. The Group has no legal or
constructive obligations to pay further contributions if the fund does not hold sufficient
assets to pay all employees the benefits relating to the employee service in the current
and prior periods.
In line with the provisions of the Pension Reform Act 2014 (Amended), a subsidiary
domiciled in Nigeria has instituted a defined contribution pension scheme for its
permanent staff. Staff contributions to the scheme are funded through payroll deductions
while the subsidiary's contribution is recognised in profit or loss as employee benefit
expense in the periods during which services are rendered by employees. Employees
contribute 8% each of their gross salary to the fund on a monthly basis. The subsidiary's
contribution is 10% of each employee's gross salary.
(m) Provisions
A provision is recognised if, as a result of a past event, the Group has a present legal
or constructive obligation that can be estimated reliably, and it is probable that an
outflow of economic benefits will be required to settle the obligation. Provisions are
determined by discounting the expected future cash flows at a pre-tax rate that reflects
current market assessments of the time value of money and the risks specific to the
liability. The unwinding of the discount is recognised as finance cost.
The Group's asset retirement obligation ("ARO") primarily represents the estimated present
value of the amount the Group will incur to plug, abandon and remediate its areas of
operation at the end of their productive lives, in accordance with applicable
legislations. The Group determines the ARO on its oil and gas properties by calculating
the present value of estimated cash flows related to the liability when the related
facilities are installed or acquired.
Contingent liabilities
A contingent liability is a possible obligation that arises from past events and whose
existence will be confirmed only by the occurrence or non-occurrence of one or more
uncertain future events not wholly within the control of the Group, or a present
obligation that arises from past events but is not recognised because it is not probable
that an outflow of resources embodying economic benefits will be required to settle the
obligation; or the amount of the obligation cannot be measured with sufficient
reliability.
Contingent liabilities are only disclosed and not recognised as liabilities in the
statement of financial position. If the likelihood of an outflow of resources is remote,
the possible obligation is neither a provision nor a contingent liability and no
disclosure is made.
(n) Finance income and finance costs
Finance income comprises, where applicable, interest income on funds invested (including
available-for-sale financial assets), dividend income, gains on the disposal of
available-for-sale financial assets, fair value gains on financial assets at fair value
through profit or loss, gains on the remeasurement to fair value of any pre-existing
interest in an acquiree in a business combination, gains on hedging instruments that are
recognised in profit or loss and reclassifications of net gains previously recognised in
other comprehensive income. Interest income is recognised as it accrues in profit or loss,
using the effective interest method. Dividend income is recognised in profit or loss on
the date that the Group's right to receive payment is established.
Finance costs comprise, where applicable, interest expense on borrowings, unwinding of the
discount on provisions and deferred consideration, losses on disposal of
available-for-sale financial assets, dividends on preference shares classified as
liabilities, fair value losses on financial assets at fair value through profit or loss
and contingent consideration, impairment losses recognised on financial assets (other than
trade receivables), losses on hedging instruments that are recognised in profit or loss
and reclassifications of net losses previously recognised in other comprehensive income.
Borrowing costs that are not directly attributable to the acquisition, construction or
production of a qualifying asset are recognised in profit or loss using the effective
interest method.
Foreign currency gains and losses are reported on a net basis as either finance income or
finance cost depending on whether foreign currency movements are in a net gain or net loss
position.
(o) Earnings per share
The Group presents basic and diluted earnings per share (EPS) data for its ordinary
shares. Basic EPS is calculated by dividing the profit or loss attributable to ordinary
shareholders of the Company by the weighted average number of ordinary shares outstanding
during the year. Diluted earnings per share is determined by adjusting the profit or loss
attributable to ordinary shareholders and the weighted average number of ordinary shares
outstanding for the effects of all dilutive potential ordinary shares which comprise share
options granted to employees. Potential ordinary shares are treated as dilutive when, and
only when, their conversion to ordinary shares would decrease earnings per share or
increase loss per share from continuing operations.
(p) Segment reporting
An operating segment is a component of the Group that engages in business activities from
which it may earn revenues and incurs expenses, including revenues and expenses that
relate to transactions with any of the Group's other components. The Group defines
geographical areas as operating segments in accordance with IFRS 8- Operating Segments.
(q) Income tax
Income tax expense comprises current and deferred tax. It is recognised in profit or loss
except to the extent that it relates to a business combination, or items recognised
directly in equity or other comprehensive income.
(i) Current tax
Current tax comprises the expected tax payable or receivable on the taxable income or loss
for the year and any adjustment to tax payable or receivable in respect of previous years.
The amount of current tax payable or receivable is the best estimate of the tax amount
expected to be paid or received that reflects uncertainty related to income taxes, if any.
It is measured using tax rates enacted or substantively enacted at the reporting date.
Current tax also includes any tax arising from dividends.
(ii) Deferred tax
Deferred tax is recognised in respect of temporary differences between the carrying
amounts of assets and liabilities for financial reporting purposes and the amount used for
taxation purposes.
Deferred tax is not recognised for:
- temporary differences on the initial recognition of assets or liabilities in a
transaction that is not a business combination and that affects neither accounting nor
taxable profit or loss;
- temporary differences related to investments in subsidiaries, associates and joint
arrangements to the extent that the Group is able to control the timing of the reversal of
the temporal differences and it is probable that they will not reverse in the foreseeable
future; and
- taxable temporary differences arising on the initial recognition of goodwill.
Deferred tax assets are recognised for unused tax losses, unused tax credits and
deductible temporary differences to the extent that it is probable that future taxable
profit will be available against which they can be used. Future taxable profits are
determined based on the reversal of relevant taxable temporary differences. If the amount
of taxable temporary difference is insufficient to recognise a deferred tax asset in full,
then future taxable profits, adjusted for reversals of existing temporary differences, are
considered, based on the business plans for individual subsidiaries in the Group. Deferred
tax assets are reviewed at each reporting date and are reduced to the extent that it is no
longer probable that the related tax benefit will be realised; such reductions are
reversed when the probability of future taxable profits improves.
Unrecognised deferred tax assets are reassessed at each reporting date and recognised to
the extent that it has become probable that future profits will be available against which
they can be used.
Deferred tax is measured at the tax rates that are expected to be applied to temporary
difference when they reverse, using tax rates enacted or substantively enacted at the
reporting date.
The measurement of deferred tax reflects the tax consequences that would follow from the
manner in which the Group expects, at the reporting date, to recover or settle the
carrying amount of its assets and liabilities. For this purpose, the carrying amount of
investment property measured at fair value is presumed to be recovered through sale, and
the Group has not rebutted this presumption.
Deferred tax assets and liabilities are offset only if certain criteria are met.
(r) Restatement of 2016 balances
(i) Following the Group's decision to consolidate Ashbert Oil and Gas Limited in 2017
consolidated financial statements, 2016 balances have been restated to reflect Ashbert Oil
and Gas Limited transactions. In addition, other areas of restatement include the
reclassification of a Director's loan of US$1.63 million from current asset to non-current
and, reclassification of restricted cash of US$1.1 million from cash and bank to other
assets.
Prior year adjustments have been processed in respect of the following:
Exploration and evaluation assets
Prior year adjustment related to correction for signature bonus of Ashbert Oil and Gas
Limited.
Other receivables
Prior year adjustment related to correction for reclassification of Directors loan from
current assets to non-current assets.
Other assets
Prior year adjustment related to correction for balances receivable from Ashbert Oil and
Gas Limited which was eliminated on consolidation of Ashbert Oil and Gas Limited and the
reclassification of restricted cash to other assets.
Cash and bank balances
Prior year adjustment related to correction for bank balances for the reclassification of
restricted cash balances to other assets.
Trade and other payables
Prior year adjustment related to correction for trade payable balances in Ashbert Oil and
Gas Limited which were consolidated into the Group's account.
Accumulated deficit
Prior year adjustment related to correction for accumulated deficit in Ashbert Oil and Gas
Limited which was consolidated into the Group's account.
Other reserves
Prior year adjustment related to correction for other reserve balances in Ashbert Oil and
Gas Limited which were consolidated into the Group's account.
(ii) Restatement impact on comparatives
As previously Adjustment Restated
reported in 2016
Statement of financial
position
Exploration and evaluation 112,652 16,080 130,773
assets (note 18)
Other receivables (note 2,479 - 2,479
22)
Other assets (note 23) 32,326 (18,282) 14,044
Cash and bank balances 4,384 (1,101) 3,283
(note 25)
Trade and other payables 31,347 (448) 30,899
(note 26)
Accumulated deficit 66,974 31 67,005
Other reserves - 22 22
Statement of comprehensive
income
General and administrative 21,075 7 21,082
expenses (note 13)
Loss for the year 15,765 7 15,772
The adjustment to the general and administrative expenses resulted from the increase of
the audit fees.
4 Measurement of fair values
A number of the Group's accounting policies and disclosures require the measurement of
fair values, for both financial and non-financial assets and liabilities.
The Group has an established control framework with respect to the measurement of fair
values. This includes a valuation expert that has responsibility for overseeing all
significant fair value measurements, including Level 3 fair values, and reports directly
to the General Manager of Commercial.
When measuring the fair value of an asset or a liability, the group uses observable market
data as far as possible. Fair values are categorised into different levels in a fair value
hierarchy based on the inputs used in the valuation techniques as follows:
? Level 1: quoted prices (unadjusted) in active markets for identical assets or
liabilities.
? Level 2: inputs other than quoted prices included in Level 1 that are observable for
the asset or liability, either directly (i.e. as prices) or indirectly (i.e. derived
from prices).
? Level 3: inputs for the asset or liability that are not based on observable market
data (unobservable inputs).
If the inputs used to measure the fair value of an asset or a liability might be
categorised in different levels of the fair value hierarchy, then the fair value
measurement is categorised in its entirety in the same level of the fair value hierarchy
as the lowest level input that is significant to the entire measurement.
The Group recognises transfers between levels of the fair value hierarchy at the end of
the reporting period during which the change has occurred. Further information about the
assumptions made in measuring fair values is included in the following notes:
Note 32 - share-based payment arrangements
Note 37 - financial risk management and financial instruments
5 Adoption of new and revised International Financial Reporting Standards
5.1 Accounting standards and interpretations issued that became effective during the year
2018
In the current year, the Group considered a number of amendments to IFRSs issued by the
International Accounting Standards Board (IASB) that are mandatory and effective for an
accounting period that begins on or after 1 January 2018.
IFRS 9 - Financial Instruments
IFRS 9 replaces IAS 39, Financial Instruments - Recognition and Measurement. The IASB
developed IFRS 9 in three phases, dealing separately with the classification and
measurement of financial assets, impairment and hedging. It includes requirements on the
classification and measurement of financial assets and liabilities, it also includes an
expected credit losses model that replaces the current incurred loss impairment model.
The standard will ensure that more assets will have to be measured at fair value with
changes in fair value recognized in profit and loss as they arise, possible provision for
future credit losses in the very first reporting period a loan goes on the books - even if
it is highly likely that the asset will be fully collectible and a greater disclosure
requirement amongst others.
The transitional provisions described above are likely to change once the IASB completes
all phases of IFRS 9. Effective for annual periods beginning on or after 1 January 2018.
The application of IFRS 9 is expected to have no material impact on the Group's financial
statement based on preliminary assessment taking into consideration the operations of the
Group.
IFRS 15 - Revenue from contracts with customers
The FASB and IASB issued their long awaited converged standard on revenue recognition on
29 May 2014. It is a single, comprehensive revenue recognition model for all contracts
with customers to achieve greater consistency in the recognition and presentation of
revenue. Revenue is recognised based on the satisfaction of performance obligations, which
occurs when control of good or service transfers to a customer. Effective for annual
periods beginning on or after 1 January 2018.
Amendment to IFRS 15 - Revenue from contracts with customers.
The IASB has amended IFRS 15 to clarify the guidance, but there were no major changes to
the standard itself.
The amendments comprise clarifications of the guidance on identifying performance
obligations, accounting for licences of intellectual property and the principal versus
agent assessment (gross versus net revenue presentation). New and amended illustrative
examples have been added for each of these areas of guidance. The IASB has also included
additional practical expedients related to transition to the new revenue standard.
Effective for annual periods beginning on or after 1 January 2018
IFRS 15 - Revenue from contracts with customers will have no impact on the Group's
financial statement as revenue is already recognised in line with this provisions.
5.2 Accounting standards and interpretations issued but not yet effective
The following revisions to accounting standards and pronouncements that are applicable to
the Group were issued but are not yet effective. Where IFRSs and IFRIC interpretations
listed below permits early adoption, the Group has elected not to apply them in the
preparation of these Consolidated financial statements. The Group plans to adopt the
standard when it becomes effective.
The full impact of these IFRSs and IFRIC interpretations is currently being assessed by
the Group, but none of these pronouncements are expected to result in any material
adjustments to the consolidated financial statements"
Pronouncement Nature of change Effective date
Financial Finalised Applies to annual
Instruments version, periods beginning on
(Amendments to incorporating or after 1 January
IFRS9) requirements for 2018.
classification
and measurement,
impairment,
general hedge
accounting and
derecognition.
Sale or The amendments Effective date of the
Contribution deal with amendments is yet to
of Assets situations where be set by the IASB
between an there is a sale
Investor and or contribution
its Associate of assets between
or Joint an investor and
Venture its associate or
(Amendments to joint venture.
IFRS 10 and
IAS 28)
Classification The amendments Applicable to annual
and clarify the periods beginning on
Measurement accounting for or after 1 January
the effects of 2018
vesting and
non-vesting
of Share- conditions in
based Payment estimating the
Transactions fair value of a
(Amendments to cash-settled
IFRS 2) share-based
payment.
They also clarify
how to account
for modification
of a share- based
payment that
changes the
transaction from
cash-settled to
equity-settled.
Transfers of The amendments Effective for annual
Investment clarify when an periods beginning on
Property entity should or after
(Amendments transfer 1 January 2018.
to IAS 40) property,
including
property under
construction or
development into,
or out of
investment
property. The
amendments state
that a change in
use occurs when
the property
meets, or ceases
to meet, the
definition of
investment
property and
there is evidence
of the change in
use. A mere
change in
management's
intentions for
the
use of a property
does not provide
evidence of a
change in use.
IFRIC The Effective for annual
Interpretation interpretation periods beginning on
22 Foreign clarifies that in or after
Currency determining the 1 January 2018.
Transactions spot
and Advance exchange rate to
Consideration use on initial
recognition of
the related
asset, expense or
income (or part
of it) on the
derecognition of
a nonmonetary
asset or
non-monetary
liability
relating to
advance
consideration,
the date of the
transaction is
the date on which
an entity
initially
recognises the
non-monetary
asset or
nonmonetary
liability arising
from the advance
consideration. If
there are
multiple payments
or receipts in
advance, then the
entity must
determine a date
of the
transactions for
each payment or
receipt of
advance
consideration.
IFRIC The Effective for annual
Interpretation Interpretation periods beginning on
23 Uncertainty addresses the or after
over Income accounting for 1 January 2019
Tax Treatments income taxes when
tax treatments
involve
uncertainty that
affects the
application of
IAS 12. The
Interpretation
does not apply to
taxes or levies
outside the scope
of IAS 12, nor
does it
specifically
include
requirements
relating to
interest and
penalties
associated with
uncertain tax
treatments.
IFRS 15 The IASB has Effective for
Revenue from amended IFRS 15 annual periods
Contracts with to clarify the beginning on or after
Customers guidance, but 1 January 2018.
there were no
major changes to
the standard
itself.
The amendments
comprise
clarifications of
the guidance on
identifying
performance
obligations,
accounting for
licences of
intellectual
property and the
principal versus
agent assessment
(gross versus net
revenue
presentation).
New and amended
illustrative
examples have
been added for
each of these
areas of
guidance.
The IASB has also
included
additional
practical
expedients
related to
transition to the
new revenue
standard.
IFRS 16 - This standard Effective for annual
Leases replaces the periods beginning on
current guidance or after
in IAS 17 and is 1 January 2019
a far reaching
change in
accounting by
lessees in
particular. Under
IAS 17, lessees
were required to
make a
distinction
between a finance
lease (on balance
sheet)
and an operating
lease (off
balance sheet).
IFRS 16 now
requires lessees
to recognise a
lease liability
reflecting
future lease
payments and a
'right-of-use
asset' for
virtually all
lease contracts.
The IASB has
included an
optional
exemption for
certain
short-term leases
and leases of
low-value assets;
however, this
exemption can
only be
applied by
lessees
6 Operating segments
The Group has a single class of business which is exploration, development and production
of petroleum oil and natural gas. The geographical areas are defined by the Group as
operating segments in accordance with IFRS 8- Operating Segments. As at the year end, the
Group had operational activities mainly in one geographical segment, Nigeria.
Geographical information
In presenting information on the basis of geographical segments, segment assets are based
on the geographical location of the assets.
Non-current assets
2017 Restated
US$'000 2016
US$'000
Nigeria 208,123 191,267
Namibia 440 465
Cayman* 1,787 -
Others 21 40
210,371 191,772
Non-current assets presented consists of property, plant & equipment, intangible assets,
long term prepayment, other receivables and E&E assets.
Profit and
loss
2017
In US$'000
Nigeria Namibia Cayman Island* Others Total
Revenue 30,848 - - - 30,848
Loss from (10,388) (381) (6,290) (1,058) (18,117)
operating
activities
Net finance 3,165 52 (1,568) 1,627 3,276
income/
(costs)
Income tax 21,337 - - - 21,337
benefit
Total 14,114 (329) (7,858) 569 6,496
comprehensive
profit/ (loss)
for the year
2016
Restated
Nigeria Namibia Cayman Island Others Total
Revenue - - - - -
Loss from (11,174) (144) (9,793) (600) (21,711)
operating
activities
Net finance 5,708 139 84 8 5,939
income
Total (5,466) (5) (9,709) (592) (15,772)
comprehensive
loss for the year
*Cayman Island and USA segments have been merged into one segment.
7 Capital Management
The Group's policy is to maintain a strong capital base so as to maintain investor,
creditor and market confidence and to sustain future development of the business
The Group monitors capital using a ratio of adjusted net debt to adjusted equity. For this
purpose, adjusted net debt is defined as total liabilities less cash and bank balances.
The Group's net debt to equity ratio at the end of the reporting year was as follows:
2017 Restated
US$'000 2016
US$'000
Total liabilities 70,688 65,806
Less: cash and bank balances (6,922) (3,283)
Net debt 63,766 62,523
Equity 205,783 198,091
Net debt to equity ratio 0.31 0.32
There were no changes in the Group's approach to capital management during the year. The
Group is not subject to externally imposed capital requirements.
8 Revenue
2017 2016
US$'000 US$'000
Crude proceeds (a) 30,848 -
30,848 -
(a) Crude proceeds of US$30.8 million represents the Group's share of crude oil sales from
Otakikpo operation during the year, which is recognised as revenue ("Equity Crude"), (31
December 2016: nil). The Group's entitlement crude was 1,223,248 barrels out of which the
Group lifted 1,188,732 barrels (31 December 2016: nil). The balance of 34,515 barrels
representing the Group's share of overriding royalty crude was lifted on its behalf by its
joint venture partner based on an agreed lifting arrangement. The entitlement crude is
comprised of equity crude of 583,720 barrels and cost recovery crude of 639,528 barrels,
which were applied as recoveries for prepaid development costs.
2017 2016
Barrels US$'000 Barrels US$'000
Equity crude 583,720 30,848 - -
Cost recovery crude 639,528 33,700 - -
1,223,248 64,548* - -
*Represents 88% crude entitlement
9 Costs of sales
2017 2016
US$'000 US$'000
Depletion and amortization 6,191 -
Crude handling, evacuation and production 6,071 -
operation costs
Royalty expenses 3,935 -
Closing stock adjustments (418) -
Other expenses 134 -
15,913 -
10 Operating expenses
2017 2016
US$'000 US$'000
Field 2,502 -
personnel
costs
Field facility 1,009 -
management
costs
Field travel 849 -
costs
Depletion and - 162
amortization
Community and 2,151 112
security
expenses
Field civil 1,237 -
works, waste
management,
safety and
environment
Cabotage and 634 -
port dues
Field office 552 -
costs
Other operating costs 2,395 355
11,329 629
11 Production bonus
Under the farm-in agreement with Green Energy International Limited (GEIL), Lekoil Oil and
Gas Investments Limited is liable to pay a US$4 million production bonus upon commencement
of commercial production above 2,000 bopd. US$4 million has been recognised as production
bonus during the period (2016: nil) in line with the farm-in agreement. This production
bonus was paid during 2017 (2016: nil).
12 Exploration and evaluation expenses
Exploration and evaluation expenses of US$0.7 million (2016: nil) comprise of E& E
expenditure on block 2514A written off following relinquishment of the block, and the
goodwill impairment loss on acquisition Ashbert Oil and Gas Limited.
2017 2016
US$'000 US$'000
Block 2514A E&E expenditure write -off 268 -
Goodwill impairment loss on acquisition Ashbert 450 -
Oil and Gas Limited
718 -
13 General and administrative expenses
2017 2016
US$'000 US$'000
Personnel expenses (a) 7,808 8,584
Depreciation and amortization (Notes 17 and 19) 2,175 1,034
Audit fees 347 746
(a) Personnel expenses
2017 2016
US$'000 US$'000
Wages and salaries 6,529 7,074
Defined contribution pension expense 82 205
Equity settled share-based payment 1,197 1,305
7,808 8,584
(b) Operating leases
The Group leases office and residential facilities under cancellable operating leases.
Lease payments are made upfront covering the lease period with no additional obligations.
(c) Key management personnel compensation
In addition to their salaries, the Group also provides non-cash benefits to key management
personnel, in form of share base payments.
(i) Key management personnel compensation comprised the following:
2017 2016
US$'000 US$'000
Short-term benefits 2,282 1,965
Share-based payment 390 147
2,672 2,112
(ii) Key management personnel compensation comprised the following:
2017 2016
US$'000 US$'000
Salaries 1,217 931
Fees 565 540
Bonus 500 494
2,282 1,965
Details of Directors' remuneration (including the fair value of share based payments)
earned by each Director of the Company during the period have been disclosed in the
remuneration report.
14 Finance income and costs
2017 2016
US$'000 US$'000
Finance income
Joint venture partner carry interest income (a) 5,294 -
Other interest income (b) 418 73
Foreign exchange gains (c) 5,637 6,795
11,349 6,868
Finance costs
Finance expenses (d) 8,073 929
(a) Joint venture partner carry interest income
Joint venture partner carry interest income represents interest on prepaid development
costs. Following the commencement of production and sale of crude, the Group commenced
recoveries from the prepaid development costs. Consequently, the group reclassifies the
interest portion of the prepaid development costs to finance income proportionately over
the period over which the cost recovery occurs by reference to cost recoveries in each
period as a percentage of the total capital and operating costs incurred to date in the
development of the field.
(b) Other interest income
Other interest income represents interest earned on short term deposits and call accounts
transactions with the Group's bankers.
(c) Foreign exchange gains
Foreign exchange gains presents realised currency exchange difference gains resulting from
the conversion of US$ amounts to Nigerian Naira amounts, to meet obligations settled in
Nigerian Naira. The significant devaluation of Nigerian Naira to the US$ during the year
and the exchange rate disparity between the official exchange rate and the parallel market
exchange rate accounted for the significant foreign exchange gain.
(d) Finance expenses
Finance costs consist largely of interest costs on third party loans during the year. The
interest costs are no longer capitalised following the completion of development works for
which the loans were procured.
15 Taxes
(a) Petroleum profit tax
The Group with its principal assets and operations in Nigeria is subject to the Petroleum
Profit Tax Act of Nigeria (PPTA). The Group's Petroleum Profit Tax charge for the period
is summarised below:
2017 2016
US$'000 US$'000
Balance at 1 January - -
Charge for the year 181 -
Tertiary education tax 37 -
Payment for the year - -
Balance at year end 218 -
(b) Company income tax
Interest on recovered carried cost and technical fees earned on Otakikpo operations of the
group is subject to Company Income Tax Act of Nigeria (CITA). The Group's Company Income
Tax charge for the year is summarised below:
2017 2016
US$'000 US$'000
Balance at 1 January - -
Charge for the year 1,588 -
Tertiary education tax 106 -
Payment for the year - -
Balance at year end 1,694 -
(c) Deferred tax assets
The Group has an estimated deferred tax asset of US$72.7 million (31 December 2016:
US$57.0 million), out of which the Group has recognized deferred tax assets of US$23.2
million in the current year; derived from the activities of its subsidiary Lekoil Oil and
Gas Investments Limited. The Directors have assessed the future profitability of its
operation in Otakikpo marginal field and have a reasonable expectation that the Group will
make sufficient taxable profit from Lekoil Oil and Gas Investments Limited in the near
future to utilise the deferred tax assets. The balance of US$49.45 million of unrecognised
deferred tax assets relates to unutilised capital allowances and tax losses from its other
subsidiaries in which the Directors are not certain when there will be available taxable
profit from the subsidiaries to utilize the deferred tax assets.
2017 2016
US$'000 US$'000
Recognised deferred tax assets 23,249 -
Unrecognised deferred tax assets 49,451 -
72,700 -
(d) Total income tax benefit/ (expense) recognised in the year.
2017 2016
US$'000 US$'000
Petroleum profit tax (181) -
Company income tax (1,588) -
Tertiary education tax (143) -
Recognised deferred tax 23,249 -
21,337 -
(e) Current tax liabilities
2017 2016
US$'000 US$'000
Balance at 1 January - -
Charge for the year
- Petroleum profit tax 181 -
- Company income tax 1,588 -
- Tertiary education tax 143 -
Payment during the year - -
Balance at 31 December 1,912 -
16 Profit/ (loss) per share
(a) The calculation of basic earnings/(loss) per share has been based on the following
loss attributable to ordinary shareholders and weighted-average number of ordinary shares
outstanding.
(i) earnings/(Loss) attributable to ordinary 2017 Restated
shareholders (basic)
US$'000 2016
US$'000
In US Dollars
Earnings/(loss) for the year attributable to 5,150 (14,906)
owners of the Group
(ii) Weighted-average number of ordinary 2017 2016
shares (basic)
Issued ordinary shares 536,529,983 488,199,893
Effect of shares issued in October 2016 - 10,299,836
Weighted-average number of ordinary 536,529,983 498,499,729
shares at 31 December
(b) The calculation of diluted earnings/(loss) per share has been based on the following
earnings/(loss) attributable to ordinary shareholders and weighted-average number of
ordinary shares outstanding after adjustment for the effects of all dilutive potential
ordinary shares. Basic and diluted loss per share are equal as all options are anti-
dilutive.
(i) earnings/ (loss) attributable to ordinary 2017 Restated
shareholders (basic)
US$'000 2016
US$'000
Earnings/(loss) for the year attributable to 5,150 (14,906)
owners of the Company
(ii) Weighted-average number of ordinary 2017 2016
shares (diluted)
Issued ordinary shares 536,529,983 498,499,729
Effect of shares options - -
Weighted-average number of ordinary 536,529,983 498,499,729
shares at 31 December
17 Property, Plant and Equipment
In US$'000
(a) The movement on this account was as follows:
Oil and Motor Furniture Computers Plant Leasehold Total
Gas , ,
Communica Machi
tion nery,
Vehicles & Stora Improvement
Assets Fittings ge
Tank
&
Household
&
Other
Equipment s
Cost: 11,064 296 353 589 - 1,160 13,46
2
Balance at 1
January 2016
Additions 27,376 - 56 159 126 63 27,78
0
Balance at 38,440 296 409 748 126 1,223 41,24
31 December 2
2016
Balance at 1 38,440 296 409 748 126 1,223 41,24
January 2017 2
Additions 6,034 - 8 16 22 - 6,080
**
Restatements (4,415) - - - - (24) * (4,43
*** 9)
Balance at 40,059 296 417 764 148 1,199 42,88
31 December 3
2017
Accumulated
depreciation
and
impairment
losses:
Balance at 1 - 109 98 150 - 501 858
January 2016
Charge for 136 52 72 182 10 307 759
the year
Balance at 136 161 170 332 10 808 1,617
31 December
2016
Balance at 1 136 161 170 332 10 808 1,617
January 2017
Charge for 6,207 42 79 187 38 136 6,689
the year
Restatements (16)*** - - - - - (16)
Balance at 6,327 203 249 519 48 944 8,290
31 December
2017
Carrying
amounts:
At 31 33, 732 93 168 245 100 255 34,59
December 3
2017
At 31 38,304 135 239 416 116 415 39,62
December 5
2016
* Restatement of leasehold improvement represents adjustment in variation contract for
office space.
** The additions of US$6.1 million during the year is in respect of capital expenditure on
production facilities in the Otakikpo marginal field.
*** Restatement of oil and gas asset represents prior period adjustments for transactions
charged to the joint venture, that have been determined to be a sole costs to each
respective partner.
18 Exploration and Evaluation (E &E) assets
E & E assets represents the Group's oil mineral rights acquisition and exploration costs.
(a) The movement on the E & E assets account was as follows:
2017 *Restated
US$'000 2016
US$'000
Balance at 1 January 128,732 128,057
Additions during the year (b) 2,309 675
Derecognition of block 2514A (f) (268) -
Balance at 31 December 130,773 128,732
(b) The additions during the year consists of US$1.3 million Ministerial Consent fee
payment for the Group's 17.14% participating interest in OPL 310 and other exploration and
evaluation expenditure in OPL 310 of US$0.7 million, OPL 325 of US$0.1 million and Namibia
of US$0.2 million. Total expenditure incurred on OPL 310 from inception of farm-in
agreement to 31 December 2017 amounts to US$114.2 million.
(c) The OPL 310 lease term expires in February 2019. The Company has commenced the renewal
process of OPL310 license. Based on the usual practice within the oil and gas industry in
Nigeria and interaction with the appropriate government agencies, the Directors are
confident that the license will be either extended for an additional 12 months or
converted to OML as appropriate before the expiration date. In June 2017 the Group
received the consent of the Honorable Minister of Petroleum for the complete transfer of
the original 17.14% participating interest acquired in OPL 310 in February 2013 by Mayfair
Assets and Trust Limited, a subsidiary of the Group.
(d) OPL 310 was tested for impairment by the Directors and it was concluded no impairment
charge was necessary. This was based upon management's assessment of the assets value in
use, its expectation on renewals and the planned expenditure for 2018 to enable appraisal
drilling. The Group estimates value in use by using a discounted cashflow with pre-tax
discount rates of between 8% - 20%.
(e) The Directors believe that the Group has control over Ashbert Oil and Gas Limited in
line with IFRS 10. Consequently, Ashbert Oil and Gas Limited has been consolidated and the
exploration and evaluation assets restated to reflect the signature bonus payment of
US$16.1 million made in September 2015.
(f) Lekoil Exploration and Production (Pty) Limited relinquished block 2514A and renewed
block 2514B until July 2019. The exploration and evaluation assets on block 2514A were
written off.
* Restatement of 2016 E&E assets to reflect the signature bonus payment for OPL 325
following the consolidation of Ashbert Oil and Gas Limited.
19 Intangible Assets
In US$'000
The movement on the intangible assets account was as follows:
Mineral Rights Geological and
Geophysical
Software
Acquisition Accounting
Costs**
Software Total
Costs
Balance at 1 7,000 1,406 104 8,510
January 2016
Additions during - 672 - 672
the year
Balance at 31 7,000 2,078 104 9,182
December 2016
Balance at 1 7,000 2,078 104 9,182
January 2017
Additions during - - - -
the year
Adjustment - (291)* - (291)
Balance at 31 7,000 1,787 104 8,891
December 2017
Accumulated
amortization
Balance at 1 - 470 38 508
January 2016
Charge for the 26 409 2 437
year
Balance at 31 26 879 40 945
December 2016
Balance at 1 26 879 40 945
January 2017
Charge for the 1,292 358 27 1,677
year
Balance at 31 1,318 1,237 67 2,622
December 2017
Carrying amounts 5,682 550 37 6,269
At 31 December
2017
At 31 December 6,974 1,199 64 8,237
2016
* Adjustment to software maintenance cost wrongly capitalised in prior year.
** Mineral rights acquisition costs represents the signature bonus for the Otakikpo
marginal field amounting to US$7.0 million.
20 Inventories
Inventories consist of the Group's share of crude stock of US$1.1 million as at 31
December 2017 (31 December 2016: US$0.7 million).
21 Trade receivables
Trade receivables comprise: 2017 2016
US$'000 US$'000
Sales proceeds receivable (a) 6,044 -
(a) Trade receivables consist of the Otakikpo crude proceeds balance due from the crude
offtaker from the last lifting for the year.
22 Other receivables
Other receivables comprise: 2017 2016
US$'000 US$'000
Non-current
Director's loan (b) 1,691 1,626
Due from Afren Investment Oil & Gas (Nigeria) 796 796
Limited (c)
2,487 2,422
Current
Cash call receivable from joint venture partner- 3,606 -
GEIL (a)
Employee loans and advances 10 21
Other receivables 64 36
3,680 57
(a) The cash call due receivable from joint venture partner (GEIL), represents GEIL's
share of cash calls paid by the Group on their behalf.
(b) The Director's loan represents the balance due on an unsecured loan of US$1,500,000
granted to a Director on 9 December 2014. The loan had a three year term and bore interest
at a rate of four per cent per annum. In September 2017, the loan was extended for another
3 years to 9 December 2020 under the same terms and conditions (note 33 (a) (i)).
(c) The amount due from Afren Investment Oil & Gas (Nigeria) Limited (Afren) represents
Afren's share of Optimum's overheads paid by the Group on Afren's behalf.
23 Other assets
Other assets comprise: 2017 *Restated
2016
US$'000 US$'000
Non-current
Deposit for investments in Afren Investments 13,000 12,000
Oil & Gas (Nigeria) Limited (a)
Prepaid rent - 213
Prepaid insurance - 209
Others - 334
13,000 12,756
Current
Non-Government Royalty (b) 1,779 -
Restricted cash (c) 3,294 1,102
Prepaid rent 361 186
Prepaid insurance 53 -
Others 414 -
5,901 1,288
* Restatement of other assets to reflect the accounting and consolidation of Ashbert Oil
and Gas Limited
(a) On 30, November 2015, Lekoil 310 Limited, a wholly owned subsidiary of Lekoil Limited
executed a sale and purchase agreement with the Administrators of Afren Nigeria Holdings
Limited and Afren Plc relating to the entire issued share capital of Afren Investment Oil
& Gas (Nigeria) Limited and certain intra-company debts.
In accordance with the agreement, Lekoil 310 Limited shall acquire the entire share
capital of Afren Investment Oil & Gas (Nigeria) Limited and will be assigned the
intra-company debts of Afren Nigeria Holdings Limited and Afren Plc, with Afren Investment
Oil & Gas (Nigeria) Limited for considerations of US$1, US$6.4 million and US$6.6 million
respectively.
Consequently on 18 November 2015, Lekoil 310 Limited made the Initial Payments of US$5.9
million and US$6.1 million for Afren Investment Oil & Gas (Nigeria) Limited intra-company
debts with Afren Plc and Afren Nigeria Holdings Limited respectively. The Group further
paid the balance US$1 million in December 2017. The cumulative payment of US$13 million
has been reported as deposit for shares pending the receipt of the consent of the Minister
of Petroleum.
(b) Non-government royalty represents the Group's share of royalty crude payable to the
Head Farmor (being Nigerian National Petroleum Corporation, The Shell Petroleum
Development Company of Nigeria, Total E&P Nigeria Limited and Nigerian AGIP Oil Company
Limited) which was lifted by Green Energy International Limited. GEIL is expected to pay
the joint venture royalty obligation to the Head Farmor and provide evidence of the
payment. The Group has recognised an asset and a corresponding liability for its share of
the royalty obligation.
(c) Restricted cash represents cash funding of the debt service reserve accounts for two
quarters of interest for the FBN Capital Notes and one quarter of interest and principal
payment of the Shell Western facility.
24 Prepaid development costs
Prepaid development costs comprise:
2017 2016
US$'000 US$'000
Balance at 1 January 66,825 28,807
Restatement (b) (5,477) -
Addition during the year 7,894 32,960
Recoveries during the year (33,700) -
Interest for the year 6,921 5,058
Balance at 31 December (a) 42,463 66,825
(a) Prepaid development costs represents Green Energy International Limited's share of
costs (60% of joint operations' costs) in the Otakikpo marginal field. Under the terms of
the farm-in agreement, Lekoil Oil and Gas Investment Limited undertakes to fund GEIL's
participating interest share of all costs relating to the joint operation on the Otakikpo
marginal field, until the completion of the Initial Work Programme. The Group will recover
costs at a rate of LIBOR plus a margin of 10% through crude oil lifting as the field
commences production. However, for expenditure above US$70 million, the recovery rate
increases to LIBOR plus a margin of 13%. The interest on carried costs has been included
as part of the prepaid development costs.
With production beginning in February 2017, the Group commenced recovery of prepaid
development costs in April 2017 and has recovered a total sum of US$33.7 million as at
year end.
(b) Restatement to prepaid development costs represent the reversal of unrealised accrued
joint venture costs in prior years that were allocated to GEIL. The Otakikpo joint venture
partners have determined that these costs should be treated as sole transactions of the
partners.
25 Cash and bank balances
2017 2016
US$'000 US$'000
Bank balances 6,922 3,283
Cash and bank balances 6,922 3,283
26 Trade and other payables
2017 *Restated
US$'000 2016
US$'000
Accounts payable 16,833 18,076
Accrued expenses 7,409 10,303
Other statutory deductions 6,114 2,373
Non-Government Royalties Payable (See Note 23 2,044 -
(c))
Payroll liabilities - 5
Other payables 75 142
32,475 30,899
27 Provisions for asset retirement obligation
The movement in the provision for asset 2017 2016
retirement obligation account was as follows:
US$'000 US$'000
Balance at 1 January 91 177
Additions during the year - -
Unwinding of discount 16 20
Effect of changes to decommissioning estimates - (105)
Balance at 31 December 107 91
The Group has recognised a provision for asset retirement obligation ("ARO") which
represents the estimated present value of the amount the Group will incur to plug, abandon
and remediate Otakikpo operation at the end of its productive life, in accordance with
applicable legislation. These costs are expected to be incurred in approximately 2040
dependent on government legislation and the future production profiles of the project. The
provision has been estimated at a US inflation rate of 2% and discounted to present value
at 17%. The provision recognised represents 40% of the net present value of the estimated
total future cost as the Company's partner, GEIL is obligated to bear 60% of the cost.
A corresponding amount equivalent to the provision is recognised as part of the cost of
the related property, plant and equipment. The amount recognised is the estimated cost of
decommissioning, discounted to its net present value, and is reassessed each year in
accordance with local conditions and requirements, reflecting management's best estimates.
The unwinding of the discount on the decommissioning is included as a finance cost.
Changes in the estimated timing of decommissioning, or decommissioning cost estimates are
dealt with prospectively by recording an adjustment to the provision and a corresponding
adjustment to property, plant and equipment.
During the year, there was no revision in the Group's decommissioning costs estimate.
Management believe the estimates continue to form a reasonable basis for the expected
future costs of decommissioning, which are expected to be incurred in approximately 2040.
28 Deferred income
The movement in deferred income was as follows: 2017 2016
US$'000 US$'000
Balance at 1 January 7,426 2,369
Additions during the year 4,553 5,057
Charge to finance income (a) (5,294) -
Balance at 31 December 6,685 7,426
(a) In 2017 and following the commencement of production and recovery of prepaid
development costs, the Group reclassifies the interest portion of the prepaid development
costs to finance income (see note 24 (a)) proportionately over the period over which the
cost recovery occurs by reference to cost recoveries in each period as a percentage of the
total capital and operating costs incurred to date in the development of the field.
29 Loans and borrowings
(a) FBN Capital Limited Notes Issuance Agreements - two-tranche facility
The Company entered into notes issuance agreements dated 16 June, 2016 with FBN Capital
Limited ("FBNC") providing for a loan of US$10 million with a 3-year tenor ("FBNC dollar
facility") and a loan of 2 billion Naira (approximately US$10 million at the time of
issuance) with a three-year tenor ("FBNC naira facility", together the "FBNC facilities").
The FBNC facilities are fully drawn and are secured by the LOGL assets as well as a Lekoil
Limited guarantee.
(i) FBNC dollar facility
The full US$10 million was drawn on the facility in June 2016 to fund the repayment of an
existing bridge facility issued by FBNC in May 2015 and to fund the Otakikpo field
development. As of May 2016, the bridge facility remaining balance was US$5 million with
repayment due in May 2016. In May 2016, the maturity date of the bridge facility was
extended from May 2016 to August 2016. The US$5 million balance was subsequently repaid in
June 2016 with proceeds from the FBNC dollar facility.
Interest is charged on the FBNC dollar facility at 3-month LIBOR plus 11.25% per annum and
interest payments are due at the end of each quarterly period. The loan is repayable in 10
(ten) quarterly instalments starting from March 2017 in accordance with a repayment
schedule.
The loan has a final maturity date of June 30, 2019 and is secured by the Company's
interest in the Otakikpo fields and facilities as well as a parent company guarantee.
(ii) FBNC naira facility
The full 2 billion naira was drawn on the facility in June 2016 to fund the Otakikpo field
development. Interest is charged on the FBNC naira facility at the greater of 3-month
NIBOR plus 6% or 20% per annum, and interest payments are due at the end of each quarterly
period. The loan is repayable in 10 (ten) quarterly instalments starting from March 2017
in accordance with a repayment schedule.
The loan has a final maturity date of 30 June 2019 and is secured by the Company's
interest in the Otakikpo field and facilities as well as a parent company guarantee.
In September 2016, the Company upsized the FBNC naira facility by 2.5 billion naira. The
fully drawn amount was used to fund Otakikpo expenditures.
In September 2017, FBNC moved the loan to its affiliate, FBN Merchant Bank (FBNM) for
administrative purposes.
(b) US$5 million FBN Merchant Bank Working Capital Facility
The Company put in place a one-year US$5 million revolving credit facility in December
2017. The primary purpose of the revolver was to manage the working capital funding
requirements of the Company. The facility has a 60-day repayment cycle for any drawn down
amount and interest rate is charged at 90-day LIBOR plus 11.25% per annum. As at 31
December, 2017 the Company had drawn US$1 million, which was fully repaid with interest in
28 February 2018.
(c) 5-billion naira Sterling Bank Corporate Loan Facility
On 23 June 2016, the Company signed an agreement with Sterling Bank Plc ("Sterling") to
secure a three-year Corporate Loan Facility for 5 billion naira ("Sterling facility). The
purpose of the facility was to fund the Otakikpo field development.
In September 2016, the Company drew down 1 billion naira on the facility. Interest charged
on the Sterling facility was initially at the greater of 3-month NIBOR plus 10% per annum
and interest payments are due at the end of each quarterly period from June 2017. The
interest rate was subsequently amended to 26% per annum in February 2017. The loan is
repayable in 10 (ten) quarterly instalments starting from June 2017 in accordance with a
repayment schedule.
The loan has a final maturity date of 30 September 2019 and is secured by the Company's
interest in the Otakikpo field and facilities as well as a parent company guarantee.
As at 31 December 2017, the Company has 4 billion naira available under the Sterling
facility.
In March 2017, the Company entered into an agreement with Cardinal Stone Partners Limited
("CSP") for a 350 million naira loan facility with a 90-day tenor ("CSP facility"). The
CSP facility was secured by a guarantee under the Sterling facility. The purpose of the
CSP facility was to manage working capital. The facility has been fully repaid.
(d) US$15 Million Shell Western Supply and Trading Limited Advance Payment Facility
On 30 March 2017, the Company signed an agreement with Shell Western Supply and Trading
Limited ("Shell"), a member of the Royal Dutch Shell group of companies (LSE: RDSA, RDSB)
to secure a three-year advance payment facility for US$15 million (the "Shell facility").
The full US$15 million was drawn on the facility in March 2017 to fund the residual
pre-production development costs in the Otakikpo field.
Interest is charged on the Shell facility at 3-month LIBOR plus 10% per annum and interest
payments are due at the end of each quarterly period. The loan is repayable in 10 (ten)
quarterly instalments starting from December 2017 in accordance with a repayment schedule.
The loan has a final maturity date of 31 March 2020 and is secured by the Company's
interest in the Otakikpo field and facilities as well as a parent company guarantee.
As part of the requirements under the Shell facility, the Company is required to enter
into a series of monthly oil price related put options. At balance date, the oil price was
well above the exercise price resulting in the hedges having no value.
The following is the outstanding balance of interest bearing loans and borrowings as at
the year end:
In US$'000 Interest rate p.a. 2017 2016
US$10 million FBNC Dollar 11.25% + LIBOR 5,828 9,455
Facility
4.5 billion naira FBNM 6% + NIBOR 7,212 14,351
Naira Facility
US$15 million Shell 10% + LIBOR 13,275 -
Facility
5 billion naira Sterling 26% 2,191 3,584
Bank Facility
US$5 million FBNM working 11.25% + LIBOR 1,003 -
Facility
Total 29,509 27,390
Less borrowings, current (17,317) (10,366)
Borrowings, non-current 12,192 17,024
The movement in the loan account was as follows:
2017 2016
US$'000 US$'000
Balance at 1 January 27,390 8,247
Draw-down during the year 18,137 28,028
Effective interest during the year 6,834 2,943
Principal repayment during the year (13,568) (8,000)
Interest and fees paid during the year (6,635) (3,828)
Revaluation adjustments (2,649) -
Balance at 31 December 29,509 27,390
(e) Changes in liabilities arising from financing activities:
Cash changes Non-cash changes
1 Draw-down Principal Interest Effective Revaluation Other 31
January during repayment and fees interest adjustments changes Decembe
2017 the year paid (ii) r 2017
US$'000 US$'000 US$'000 US$'000 US$'000 US$'000 US$'000 US$'000
Bank 27,390 18,137 (13,568) (6,635) 6,834 (2,649) - 29,509
loans
(note
29(d)
)
? ? ? ? ? ? ? ?
Total 27,390 18,137 (13,568) (6,635) 6,834 (2,649) - 29,509
liabi
litie
s
from
finan
cing
activ
ities
? ? ? ? ? ? ? ?
30 Capital and reserves
(a) Share capital
Ordinary shares 2016
2017 US$'000
US$'000
Authorised 50 50
Issued, called up and fully paid 27 27
Total issued and called up share capital 27 27
2017 2016
US$'000 US$'000
In issue at 1 January 27 24
Issued for cash - 3
In issue at 31 December - fully paid 27 27
Authorised - par value US$0.00005 1,000,000,000 1,000,000,000
(2015: US$0.00005)
(b) Share premium
Share premium represents the excess of amount received over the nominal value of the total
issued share capital as at the reporting date.
The movement in share premium during the year 2017 2016
was as follows:
US$'000 US$'000
Balance at 1 January 264,004 252,208
Additional issue of shares during the year - 11,796
Balance at 31 December 264,004 264,004
The increase of $11.8 million in 2016 relates to the placement of new ordinary shares
issued in October 2016. The Company raised capital by issuing 48,330,200 new ordinary
shares at a placing price of $0.37 (21 pence) per share raising gross proceeds of $12.4
million and net proceeds of $11.8 million.
31 Non-controlling interest
% of ownership 2017 2016
US$'000 US$'000
Lekoil Nigeria Limited 10 3,885 5,297
Lekoil Exploration and Production 20 205 139
(Pty) Limited
4,090 5,436
This shows the net asset of the minority interest analysed to the relevant company.
32 Share-based payment arrangements
At 31 December 2017, the Group had the following share-based payment arrangements:
Long-term incentive plan scheme (equity-settled)
The long-term incentive plan scheme ("LTIP") was approved on 19 November 2014 and amended
on 21 December 2015. The Board approved the grant of 2,500,000 stock options to the CEO,
Lekan Akinyanmi on 28 June 2017. The Board further approved the grant of 7,109,750 stock
options to employees of the Group and 1,500,000 stock options to the CFO, Lisa Mitchell on
23 August 2017 and 1 October 2017 respectively.
The options vest three years from the grant date subject to meeting certain performance
criteria. If they vest, they will remain exercisable for seven years after the vesting
date. The granted share options are subject to market-based vesting conditions.
The options will vest subject to the Company's annual compound Total Shareholder Return
("TSR") over the three year performance period starting on the grant date, with:
? no options vest if annual compound TSR is less than 10%;
? 30% of options vest if annual compound TSR is 10%;
? 100% options vest if annual compound TSR is 20% or more; and
? between 30% and 100%, the percentage of options that will vest is determined on a
straight-line basis for annual compound TSR between 10% and 20%.
The number and weighted average exercise prices of share options are as follows:
Weighted Number of Weighted Number of
average options average options
exercise exercise
price US$ price US$
2017 2016
Outstanding at 0.62 20,501,000 0.62 10,978,000
1 January
Granted during 0.27 8,609,750 0.27 9,800,000
the year
Forfeited 0.27 (1,584,000) 0.27 (277,000)
during the
year
Outstanding at 0.53 27,526,750 0.46 20,501,000
31 December
The options outstanding at 31 December 2017 had exercise prices in the range of US$0.27 to
US$0.62 and a weighted average contractual life of 4.22 years.
Inputs for measurement of grant date fair values
The fair value of each stock option granted was estimated on the date of grant using the
Black-Scholes option-pricing model with the following inputs:
Fair value of share options and
assumptions
2017 2016 2015
Weighted average fair value at grant US$0.12 US$0.62 US$0.67
date for options issued during the
year
Share price at grant date - Stock US$0.21 - -
options issued on 28 June 2017
Share price at grant date - Stock US$0.22 - -
options issued on 23 August 2017
Share price at grant date - Stock US$0.23 - -
options issued on 1 October 2017
Share price at grant date - Stock - US$0.27 -
options issued on 4 October 2016
Share price at grant date - Stock - - US$0.46
options issued on 26 June 2015
Share price at grant date - Stock - - US$0.31
options issued on 23 December 2015
Exercise price - Stock options issued US$0.20 - -
on 28 June 2017
Exercise price - Stock options issued US$0.21 - -
on 23 August 2017
Exercise price - Stock options issued US$0.23 - -
on 1 October 2017
Exercise price - Stock options issued - US$0.27 -
on 4 October 2016
Exercise price - Stock options issued - - US$0.62
on 26 June 2015
Exercise price - Stock options issued - - US$0.59
on 23 December 2015
Option life (Expected life in Years) 6 year 6 year 3.5 year
of options issued during the year
Weighted average expected volatility 57% 61% 62.5%
- Stock options issued during the
year
Weighted average Risk-free Interest 0.68% 0.34% 1.5%
rate for options issued during the
year
Expected dividends na na na
Volatility was estimated with reference to empirical data for proxy companies with listed
equity.
Share option scheme (equity-settled)
The Group established a share option scheme available to Directors, key management
personnel, employees and consultants providing employment-type services, which provides
the opportunity to purchase shares in the Group. In accordance with the scheme, holders of
vested options are entitled to purchase shares at prices of the shares established at the
date of grant, during a period expiring on the tenth anniversary of the effective date
i.e. grant date. The grant dates for awards were 3 December 2010, 1 June 2011, 1 November
2011, 4 June 2012, 19 February 2013, 7 April 2013, 17 May 2013 and 26 March 2014 based
upon a shared understanding of the terms of the awards at that time. This share option
scheme has been replaced by the LTIP scheme described above. As such, no new options were
granted in 2017 under this scheme.
The number and weighted average exercise prices of share options are as follows:
Weighted Number of Weighted Number of
average options average options
exercise exercise
price US$ price US$
2017 2016
Outstanding at 0.58 17,462,986 0.58 17,462,986
1 January
Granted during - - - -
the year
Forfeited - - - -
during the
year
Exercised - - - -
during the
year
Outstanding at 0.58 17,462,986 0.58 17,462,986
31 December
Exercisable at 0.75 17,462,986 0.75 17,352,986
31 December
The options outstanding at 31 December 2017 have a weighted average contractual life of
4.05 years (2016: 5.05 years).
Inputs for measurement of grant date fair values
The fair value of each stock option granted was estimated on the date of grt using the
Black-Scholes Option Pricing Model for plain vanilla European call options with the
following inputs:
2017 2016 2015
Fair value of share options and assumptions
Weighted average fair value at grant date $0.54 $0.54 $0.54
Share price at grant date $0.91 $0.91 $0.91
Exercise price $0.75 $0.75 $0.75
Option life (Expected weighted average life in 7.0 7.0 5.0
Years)
Expected volatility 60% 60% 60%
Risk-free Interest rate 1.70% 1.70% 1.70%
Expected dividends na na na
Non-Executive Director Share Plan (equity-settled)
The Board established the Non-Executive Director share plan on 21 December 2015.
These stock options are not subject to any performance criteria and vest three years from
the grant date, subject to successful completion of a three year service period starting
on the grant date. The options can be exercised over a seven year period beginning on the
expiry of the service period.
During the year the Board approved the award of 500,000 stock options in June 2017.
The number and weighted average exercise prices of share options are as follows:
Weighted Number of Weighted Number of
average options average options
exercise exercise
price US$ price US$
2017 2016
Outstanding at 0.43 1,000,000 0.59 500,000
1 January
Granted during 0.27 500,000 0.27 500,000
the year
Outstanding at 0.35 1,500,000 0.43 1,000,000
31 December
The options outstanding at 31 December 2017 had a weighted average exercise price of $0.35
to and a weighted average contractual life of 7.5 years.
Inputs for measurement of grant date fair values
The fair value of each stock option granted was estimated on the date of grant using the
Black-Scholes Option Pricing Model with the following inputs:
2017 2016 2015
Weighted average fair value at grant US$0.12 US$0.59 US$0.13
date
Share price at grant date US$0.22 US$0.27 US$0.31
Exercise price US$0.21 US$0.27 US$0.59
Option life (Expected life in Years) 6.0 6.0 6.0
Expected volatility - Stock options 57% 61% 65%
issued
Risk-free Interest rate 0.68% 0.3% 1.5%
Expected dividends na na na
Employee benefit expenses
2017 2016
US$'000 US$'000
Non-Executive Director Share Plan 57 22
(equity-settled)
Long-term incentive plan scheme (equity-settled) 1,081 838
Share option scheme (equity-settled) 59 445
Total expense recognised as employee costs 1,197 1,305
33 Related Party Transactions
The Group had transactions during the period with the following related parties:
(a) Transactions with key management personnel
Key management personnel are those persons having authority and responsibility for
planning, directing and controlling the activities of the Group, directly or indirectly.
These are the Directors of the Group.
(i) Loans to key management personnel
An unsecured loan of US$1,500,000 was granted to a Director on 9 December 2014. The loan
had a three year term and bears interest at a rate of four per cent per annum. Repayment
was due at the end of the term. In September 2017, the loan was extended for another 3
years up to 9 December 2020 under the same terms and conditions. At 31 December 2017, the
balance outstanding was US$1,691,364 (2016: US$1,626,312) and is included in 'Other
receivables'. Interest income from the loan during the year amounted to US$65,000 (2016:
US$ 62,000)
(ii) Key management personnel transactions
The value of the outstanding balance at year end due to key management personnel and
entities over which they have significant influence was US$1.72 million (2016: US$1.87
million). In 2015, Lekoil Oil & Gas Investments Limited entered into a contract with
SOWSCO Wells Services Nigeria Limited, a company controlled by a Director, for the
provision of well completion services.
(iii) Key management personnel compensation
Details of key management personnel compensation during the year have been disclosed in
the remuneration report on page 25.
(iv) Key management personnel and director transactions
Directors of the Company control 8.27% (2016: 8.73%) of the voting shares of the Company.
(b) Lekoil Limited, Cayman Islands has a Management & Technical Services Agreement with
Lekoil Management Corporation (LMC) under the terms of which LMC was appointed to provide
management, corporate support and technical services. The remuneration to LMC includes
reimbursement for charges and operating costs incurred by LMC.
34 Group entities
(a) Significant subsidiaries:
Country of incorporation Ownership interest
2017 2016
Lekoil Nigeria Nigeria 40% 40%
Limited (See
(a)(i))
Lekoil Exploration Namibia 80% 80%
and Production
(Pty) Limited
Lekoil Management USA 100% 100%
Corporation
Lekoil Singapore Singapore 100% 100%
PTE Limited
Lekoil Limited Benin 100% 100%
SARL
Lekoil 310 Limited Cayman Islands 100% 100%
Lekoil Management Cayman Islands 100% 100%
Services
(i) Although the Company holds less than a 50% ownership interests in Lekoil Nigeria
Limited, it has control over the entity through common Directors and it is entitled to 90%
of the economic benefits related to its operations and net assets based on the terms of
agreements under which the entity was established. Consequently, the Company consolidates
Lekoil Nigeria Limited.
Lekoil Nigeria Limited has seven wholly owned subsidiaries, namely: Mayfair Assets and
Trust Limited, Lekoil Oil & Gas Investments Limited, Lekoil Exploration and Production
Nigeria Limited Lekoil Energy Nigeria Limited, Princeton Assets and Trust Limited, Lekgas
Nigeria Limited, and Lekpower Limited. The results of these subsidiaries have been
included in the consolidated financial results of Lekoil Nigeria Limited.
(b) Non-controlling interests (NCI)
The following table summarises the information relating to each of the Group's
subsidiaries, before any intra-group eliminations:
31 December Lekoil Lekoil Intra -group Total
2017 Nigeria Exploration eliminations
Limited and Production
Group (Pty) Limited
In US$'000
NCI Percentage 10% 20%
Non-current 184,874 440
assets
Current assets 87,970 75
Non-current (324,808) (1,267)
liabilities
Current (40,758) (77)
liabilities
Net assets (92,722) (829)
Carrying (9,272) (166) 5,348 (4,090)
amount of NCI
Revenue 30,848 -
Loss (10,388) (381)
Net finance (24,200) 52
income/ (cost)
Income tax 21,338 -
benefit
Total (13,250) (329)
comprehensive
income
Profit/ (loss) (1,325) (66) 2,737 1,346
allocated to
NCI
OCI allocated - -
to NCI
Cash flows (9,555) (156)
from operating
activities
Cash flows 15,037 (108)
from
investment
activities
Cash flows (2,066) 273
from financing
activities
Net decrease 3,416 9
in cash and
bank balances
31 December
2016
In US$'000 Lekoil
Exploration
and
Lekoil Production Intra -group
Nigeria
In US$'000 Limited (Pty) Limited eliminations
Dollars Group
NCI Percentage 10% 20%
Non-current 158,483 465
assets
Current assets 72,596 17
Non-current (267,543) -
liabilities
Current (30,243) (1,180)
liabilities
Net assets (66,707) (698)
Carrying (6,671) (140) 1,375 (5,437)
amount of NCI
Revenue - -
Loss (14,366) (144)
Net finance (14,491) 139
income/ (cost)
Total (28,857) (5)
comprehensive
income
Loss allocated (2,886) (1) 2,021 (867)
to NCI
OCI allocated - -
to NCI
Cash flows 16,618 (92)
from operating
activities
Cash flows (59,536) -
from
investment
activities
Cash flows 43,610 60
from financing
activities
Net decrease 692 (32)
in cash and
bank balances
35 Events after the Reporting Date
In January 2018, the Group announced the completion of a Technical Evaluation Report for
OPL 325. Lumina Geophysical, an oil and gas industry specialist, carried out a geophysical
evaluation of approximately 800sqkm of 3D seismic data. Following the seismic review, the
Group has identified and reported a total of eleven prospects and leads on the block,
estimated to contain potential gross aggregate Oil-in-Place volumes of over 5,700 mmbbls
(un-risked, Best Estimate case).
In February 2018, the Group announced it has commenced the shooting of 3D seismic survey
at the Otakikpo marginal field, onshore and offshore. Sinopec Chanjiang Engineering
Services was contracted to carry out the survey. The survey is expected to be completed
around June 2018.
In March 2018, the Group announced that it has taken the decision to apply to the Federal
High Court for a declaration that is expected to expedite the consent process for the
additional 22.8 percent participating interest in OPL 310, and preserve the unexpired
tenure in the licence.
There have been no events between the reporting date and the date of authorising these
financial statements that have not been adjusted for or disclosed in these financial
statements.
36 Financial Commitments and Contingencies
(a) Lekoil Exploration and Production (Pty) Limited has relinquished Namibian block 2514A
and has renewed block 2514B until July 2019. The Group is bound to a work programme for
the block 2514B licence which includes; acquisition of 2D seismic data over an area
covering at least 1000 sq. km, acquisition of new CSEM (Control Source
Electromagnetic/Hydroscan) data over an area covering at least 200 km or acquisition of
new 3D over an area of at least 200 sq.km, data integration and interpretation, lead
identification and portfolio inventorisation, lead de-risking and portfolio analysis and
ranking, and a minimum exploration expenditure of US$2 million.
(b) On 5 December 2014, the Green Energy International Limited/Lekoil Oil and Gas
Investments Limited joint venture signed a Memorandum of Understanding (MoU) with its host
community, Ikuru with respect to the Otakikpo marginal field area. The key items of the
MoU include the following:
? The joint venture will allocate 3% of its revenue from the Liquefied Petroleum Gas (LPG)
produced from the field to the Ikuru Community in each financial year;
? The joint venture will allocate the sum of US$0.53 million (NGN 90 million) annually for
sustainable community development activities.
(c) In May 2015, the Company provided a corporate guarantee in favour of FBN Capital for
the full sum of the loan notes issued by Lekoil Oil and Gas Investment Limited, a
sub-subsidiary of the Company.
(d) In March 2017, the Company provided a corporate guarantee in favour of Shell Western
Supply and Trading Limited for the full sum of the Advance Payment Facility with Lekoil
Oil and Gas Investment Limited, a sub-subsidiary of the Company.
(e) Litigation and claims
There are no litigations or claims involving the Group as at 31 December 2017 (2016: Nil).
37 Financial risk management and financial instruments
Overview
The Group has exposure to the following risks from its use of financial instruments:
? credit risk
? liquidity risk
? market risk
This note presents information about the Group's exposure to each of the above risks, the
Group's objectives, policies and processes for measuring and managing risk, and the
Group's management of capital. Further quantitative disclosures are included throughout
these financial statements.
Risk management framework
The Board of Directors has overall responsibility for the establishment and oversight of
the Group's risk management framework.
The Group's risk management policies are established to identify and analyse risks faced
by the Group, to set appropriate risk limits and controls, and to monitor risks and
adherence to limits. Risk management policies and systems are reviewed regularly to
reflect changes in market conditions and the Group's activities. The Group, through its
training and management standards and procedures, aims to develop a disciplined and
constructive control environment in which all employees understand their roles and
obligations.
(a) Credit risk
Credit risk is the risk of financial loss to the Group if a customer or counterparty to a
financial instrument fails to meet its contractual obligations, and arises principally
from the Group's receivables from joint venture partners, employees and related parties.
Exposure to credit risk
The carrying amount of financial assets represents the maximum credit exposure. The
maximum exposure to credit risk at the reporting date was:
In US Dollars
2017 2016
Notes US$'000 US$'000
Cash and bank balances 25 6,922 3,283
Trade receivables 21 6,044 -
Other receivables 22 6,167 2,479
In respect of the Group's trade sales, the Group manages credit risk through dealing with,
whenever possible, international energy companies or those with a track record of
creditworthiness. The Group closely monitors the risks and maintains a close dialogue with
those counterparties considered to be highest risk in this regard. The Group trades only
with recognised, creditworthy third parties, and as such collateral is not requested nor
is it the Group's policy to securitise its trade and other receivables.
Other receivables represent employee receivables and a loan to a Director which management
has assessed as unimpaired.
The Group made significant recoveries on prepaid development costs during the year from
crude and with production expected to be undisrupted, management has assessed the prepaid
development as unimpaired.
Cash and bank balances
The cash and bank balances of US$6.9 million (2016: US$3.3 million) are held with
reputable financial institutions.
(b) Liquidity risk
Liquidity risk is the risk that the Group will not be able to meet its financial
obligations as they fall due. The Group's approach to managing liquidity is to ensure, as
far as possible, that it will always have sufficient liquidity to meet its liabilities
when due, under both normal and stressed conditions, without incurring unacceptable losses
or risking damage to the Group's reputation.
Liquidity risk is impacted by the recoverability of the prepaid development costs balance
in note 24.
The following are the contractual maturities of financial liabilities, and excluding the
impact of netting agreement:
Notes Carrying Contractual 6 months
amount cash flows or less
Non-derivative financial
liabilities
31 December 2017
Loans and Borrowings 29 29,509 35,354 11,786
Trade and other payables* 26 26,361 26,361 26,361
55,870 61,715 38,147
31 December 2016
Loans and Borrowings 29 27,390 35,311 7,592
Trade and other payables* 26 28,526 28,526 28,526
55,916 63,837 36,118
It is not expected that the cash flows included in the maturity analysis could occur
significantly earlier, or at significantly different amounts.
* The carrying amount of trade and other payables is stated net of statutory deductions.
(c) Market risk
Market risk is the risk that changes in market prices, such as foreign exchange rates,
interest rates and equity prices will affect the Group's income or the value of its
holdings of financial instruments. The objective of market risk management is to manage
and control market risk exposures within acceptable parameters, while optimising the
return.
The Group manages market risks by monitoring market developments and discussing issues
regularly, and mitigating actions taken where necessary.
Currency risk
The Group is exposed to currency risk on bank balances, employee receivables and trade and
other payables denominated in Nigerian Naira.
The summary of quantitative data about the Group's exposure to currency risks are as
follows:
Carrying amounts
2017 2016
US$'000 US$'000
Trade and other receivables 38 228
Cash and bank balances 276 327
Trade and other payables (2,507) (1,632)
Net exposure (2,193) (1,077)
Sensitivity analysis
A 20 percent strengthening of the US Dollar against the following currencies at 31
December would have increased (decreased) equity and loss by the amounts shown below. This
analysis assumes that all other variables, in particular interest rates, remain constant.
In US$'000 Foreign exchange rate risk
20% (-20%)
Carrying Profit or Other Profit or Other
loss Movements loss Movements
in Equity in Equity
Amount
31
December
2017
Financial
Assets:
Naira
Cash and 276 55 - (55) -
bank
balances
Trade and 38 8 - (8) -
other
receivable
s
Impact on - 63 - (63) -
financial
assets
Financial
Liabilitie
s:
Naira
Accounts (2,507) (501) - 501 -
payable
Impact on - (501) - 501 -
financial
liabilitie
s
Total - (438) - 438 -
increase
(decrease)
In US$'000 Foreign exchange rate risk
20% (-20%)
Carrying Profit or Other Profit or Other
loss Movements loss Movements
in Equity in Equity
Amount
31
December
2016
Financial
Assets:
Naira
Cash and 327 65 - (65) -
bank
balances
Trade and 228 46 - (46) -
other
receivable
s
Impact on 111 - (111) -
financial
assets
Financial
Liabilitie
s:
Naira
Accounts (1,632) (326) - 326 -
payable
Impact on - (326) - 326 -
financial
liabilitie
s
Total - (215) - 215 -
increase
(decrease)
The amounts shown represent the impact of foreign currency risk on the groups consolidated
profit or loss. The foreign exchange rate movements have been calculated on a symmetric
basis. This method assumes that an increase or decrease in foreign exchange movement would
result in the same amount and further assumes the currency is used as a stable
denominator.
(d) Fair values
Fair values vs carrying amounts
The following table shows the carrying amounts and fair values of financial assets and
financial liabilities. It does not include fair value information for financial assets and
financial liabilities not measured at fair value if the carrying amount is a reasonable
approximation of fair value.
In US$'000 Carrying amount
Note Loans and Other financial Total
receivables liabilities
31 December 2017
Loans and
receivables
Trade receivables 21 6,044 6.044
Other receivables 22 6,167 - 6,167
Cash and bank 25 6,922 - 6,922
balances
19,133 - 19,133
Financial
liabilities
measured at
amortised costs
Loan 29 - 29,509 29,509
Trade and other 26 - 26,361 26,361
payables*
- 55,870 55,870
In US$'000 Carrying amount
Note Loans and Other financial Total
receivables liabilities
31 December 2016
Loans and
receivables
Other receivables 22 2,479 - 2,479
Cash and bank 25 3,283 - 3,283
balances
5,762 - 5,762
Financial
liabilities
measured at
amortised costs
Loan 29 - 27,390 27,390
Trade and other 26 - 28,526 28,526
payables
- 55,916 55,916
* The carrying amount of trade and other payables is stated net of statutory deductions.
-ends-
ISIN: KYG5462G1073
Category Code: ACS
TIDM: LEK
LEI Code: 213800T6JMZ84UEF5C40
OAM Categories: 1.1. Annual financial and audit reports
Sequence No.: 5614
EQS News ID: 691841
End of Announcement EQS News Service
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(END) Dow Jones Newswires
June 04, 2018 02:21 ET (06:21 GMT)
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