TIDMGPX
RNS Number : 4714G
Gulfsands Petroleum PLC
30 May 2017
Certain statements included herein constitute "forward-looking
statements" within the meaning of applicable securities
legislation. These forward-looking statements are based on certain
assumptions made by Gulfsands and as such are not a guarantee of
future performance. Actual results could differ materially from
those expressed or implied in such forward-looking statements due
to factors such as general economic and market conditions,
increased costs of production or a decline in oil and gas prices.
Gulfsands is under no obligation to update or revise any
forward-looking statements, whether as a result of new information,
future events or otherwise, except as required by applicable
laws.
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"). Upon the
publication of this announcement via Regulatory Information Service
("RIS"), this inside information is now considered to be in the
public domain. If you have any queries on this, then please contact
Andrew Morris, the Finance Director of the Company (responsible for
arranging release of this announcement) at 5th Floor, 88 Kingsway,
London, WC2B 6AA or on +44 20 7841 2727.
GULFSANDS PETROLEUM PLC
ANNUAL AUDITED RESULTS FOR THE YEARED 31 DECEMBER 2016
30 May 2017
Gulfsands Petroleum plc ("Gulfsands", the "Group" or the
"Company" - AIM: GPX), the oil and gas company with activities in
Syria, Tunisia, Colombia and Morocco, is pleased to announce its
audited results for the year ended 31 December 2016.
For further information, please refer to the Company's website
at www.gulfsands.com or contact:
Gulfsands Petroleum Plc +44 (0)20 7841 2727
John Bell, Managing Director
Andrew Morris, Finance Director
James Ede-Golightly, Non-Executive Chairman
Cantor Fitzgerald Europe
Sarah Wharry
Craig Francis +44 (0)20 7894 7000
About Us
Gulfsands Petroleum plc is an independent oil and gas
exploration and production company, incorporated in the United
Kingdom, whose shares are traded on the Alternative Investment
Market ("AIM") of the London Stock Exchange (symbol: GPX).
The Group's core interest is in Block 26, a world class
reservoir in North East Syria (under Force Majeure as a result of
EU sanctions). The Group also has oil and gas exploration projects
in Morocco, Tunisia and Colombia, which are being rationalised.
Highlights
Good progress made streamlining the business to focus on its
assets in Syria
-- Extension of the initial period of the Moulay Bouchta Licence
in Morocco to June 2017 together with a revised work programme
approved.
-- Exit from Tunisia initiated.
-- Llanos 50 licence in Colombia extended by 18 months to May
2018 and work commenced on MMA and EIA environmental work.
-- Work commenced on the Consulta Previa on the Putumayo 14 licence in Colombia.
Core assets in North East Syria appear to be in good order,
materially undamaged and operationally fit
-- Group working interest 2C Contingent Resources in Syrian
assets of 86.4 mmboe (reclassified from 2P reserves in 2015 due to
EU sanctions).
-- Over 20 year resource life.
-- Involvement in Syrian operations remains suspended during
continuation of EU sanctions, which Gulfsands remains committed to
full compliance with.
-- Production in Block 26, without the participation of Gulfsands, has reportedly increased to approximately 15-20,000 barrels per day through January - April 2017 - no revenues recognised by Gulfsands.
-- While the status of this production under the terms of the
PSC is unclear at this time, the production does appear to
demonstrate the reservoir quality and that the field continues to
be operable.
-- Increasing stability in the area surrounding Block 26, with
no major disruptions during the year.
-- Gulfsands is focused on maintaining its readiness to resume
operational activities once sanctions are lifted.
Costs reduced significantly
-- Continued initiatives to reduce the ongoing expenses across
the Group with gross office costs falling 43% from $8.7 million to
$5 million.
-- Further cost efficiencies planned for 2017 and 2018.
Continued financial support from major shareholders
-- Open Offer completed in January 2016, with 354,837,296 shares
subscribed for and admitted to AIM, raising GBP14.2 million ($20.4
million) at 4.0 pence per share. The proceeds were used, in part,
to repay the $14.5 million Convertible Loan Facility.
-- Placing completed in August 2016, with 47,272,344 new
ordinary shares subscribed for and admitted to AIM, raising GBP1.5
million ($1.9 million) at 3.125 pence per share.
-- Completion of Secured Term Financing Facility (the "2017
Facility") of up to GBP4.0 million (c. $5.0 million) in February
2017.
-- Cash at 31 December 2016 of $1.0 million. Current cash
available, after three 2017 Facility draw downs, of $2.4
million.
John Bell, Managing Director said:"We continue to focus on
capital efficiency while protecting and preserving the value within
Block 26, our core assets in North East Syria, by ensuring
readiness to recommence operations there once EU Sanctions and the
security situation permit. To remind shareholders, the 2C
Contingent Resources in the Syrian assets are 86.4 mmboe (Group
working interest).
"We have also continued to make strong progress during the year
managing our non-core assets elsewhere, while cutting our operating
expenses by 43%. We remain focused on controlling our costs going
forward and will look to reduce these further over the coming
year."
Strategic Report
Our Business Model
The Group's strategy is to focus on capital efficiency and
protecting and preserving the value within Block 26, its core
assets in North East Syria, by ensuring readiness to recommence
operations there once EU sanctions and the security situation
permit.
Dear Shareholder
During 2016 and early 2017 the Board has remained resolute in
realigning the strategy of the Group to be consistent with its
financial capacity and risk tolerance, despite a continued
challenging business environment. It continues to pursue
restructuring and farm-out or divestiture of its non-core assets,
while its Syrian assets remain the core part of the Group's
strategy with management monitoring the situation closely to ensure
our ongoing readiness to return to operation when the political
situation allows and EU sanctions are lifted.
In Syria, Gulfsands is the operator of, and holds a 50% working
interest in the Block 26 Production Sharing Contract ("PSC"), a
geo-technically world class asset. Block 26 is located in the
relatively stable area of North East Syria and, although Gulfsands
is unable, due to EU sanctions, to be actively involved in
operations, the assets appear to be in good order, materially
undamaged and operationally fit. Gulfsands is not presently
involved in any production or exploration activities on Block 26 as
Force Majeure has been declared in respect of the contract
following the introduction of EU sanctions in Syria. Subsequent to
the reporting period, the Group has been informed by DPC that the
oil fields in Block 26 were returned to production during January
2017, with oil being produced from up to twelve production wells.
The average oil production rate from both fields combined between
January 2017 and the end of April 2017 appears to be around
15-20,000 BOPD, however the Company is still working to verify
this. The status of this production under the terms of the PSC is
unclear at this time. Gulfsands has not recognised any revenue for
any production under the PSC since the advent of Force Majeure.
Gulfsands remains committed to full compliance with EU sanctions
and is focused on maintaining its readiness to resume operational
activities once sanctions are lifted.
During the period, we continued to rationalise the non-core
portfolio in Morocco, Tunisia and Colombia.
In Morocco, the Group's remaining licence, Moulay Bouchta, was
due to expire in June 2016. Following constructive discussions with
the Office National des Hydrocarbures et des Mines ("ONHYM") an
agreement was reached, to restructure the minimum work programme
and secure an extension of twelve months. Post year-end, this
extension was confirmed. The Company has engaged in further
discussions to further extend the initial phase to June 2018 to
allow for the Company to complete its minimum work program and
fully analyse the results. However, the Company intends to only
take advantage of this extension if it is able to find a partner
who would be interested in a farm-out of this project and help ease
the financial burden. Elsewhere in Morocco, the Group continues
discussions with ONHYM to close out outstanding matters relating to
the Rharb and Fes permits which expired in 2015.
In Tunisia, the Group's subsidiary, Gulfsands Petroleum Tunisia
Limited informed the Tunisian authorities that, if it could not
find a partner for its projects, it intended to cease all Tunisian
operations at the year end, and post year end the Group has
initiated the close down of its activities in-country.
In Colombia, Gulfsands continues to invest significant time and
resources into its assets with a view to finding a partner(s) who
can assist in taking this part of the business forward as well as
exploring other structures to enable these assets to be funded as a
standalone South American strategy. The Llanos-50 ("LLA-50")
licence expired in November 2016 and the Group has been in
discussions with Agencia Nacional de Hidrocarburos ("ANH") since
then to secure an extension to the licence together with a revised
work program. This extension was confirmed in May 2017 and the
Group has now commenced work on reprocessing legacy seismic and
initial environment studies in advance of further seismic
acquisition. The Putumayo-14 ("PUT-14") licence expires in November
2017 and the Group is in dialogue with ANH to secure an extension
for this licence. In October 2016, Gulfsands announced that it had
entered into a Farm-Out Agreement with Samarium for the licence but
has been unable to agree a mutually acceptable way to move forward
with its implementation. As a result, Gulfsands took the decision
to pursue the work programme alone, to ensure ongoing compliance
with the terms of the licence, and amongst other things, contracted
for the commencement of the first phase of work, the Consulta
Previa in March 2017. In May 2017, the Farm-Out Agreement was
terminated, and Gulfsands has reverted to having a 100% interest in
the PUT-14 licence.
Financial overview
During early 2016 the Company significantly strengthened its
Balance Sheet with the completion of a $20.4 million Open Offer,
underwritten by two of our major shareholders. The proceeds were,
in part, used to repay the $14.5 million debt outstanding under the
Convertible Loan Facility. In the first half of the year we
welcomed a new major Shareholder, ME Investments Limited, to our
register, and in August 2016, the now three major shareholders,
once again demonstrated their continued support for the Company
with a $1.9 million mid-market equity placing. In February 2017,
these shareholders provided further funding for the Group through a
Secured Term Financing Facility (the "2017 Facility") of up to GBP4
million (c. $5 million) which is to be drawn-down in tranches,
subject to certain conditions. If fully drawn down, upon approval
by the lenders, this 2017 Facility should fund the Group's expected
G&A through to Q2 2018.
Note 1.3 (Going concern) of this Annual Report describes further
the funding requirements.
The Group posted a loss for the period of $19.8 million,
including E&E write-offs and impairments of $8.1 million, of
which, $5.3 million relates to Chorbane in Tunisia, $1.1 million
relates to Llanos 50 in Colombia, $1.1 million relates to Putumayo
14 in Colombia.
The Group continues to focus on controlling costs to a
sustainable level given the activities of the Group. This
initiative has resulted in the ongoing operating expenses across
the Group falling 43% from $8.7 million in 2015 to $5.0 million in
2016 (see Financial Review on page 19).
At 31 December 2016 the Group had total unrestricted cash and
cash equivalents of $1.0 million.
As at 31 December 2016 the Group had zero debt after repaying
the $14.5 million outstanding under the Convertible Loan Facility
as part of the $20.4 million Open Offer which completed in January
2016. In February 2017, the 2017 Facility of up to GBP4.0 million
(c. $5.0 million) was entered into with our three major
shareholders. This 2017 Facility is extinguishable with equity at
maturity, at the Company's option into shares of the Company at a
price equal to the lower of (i) the 90 day average closing price at
the time of repayment and (ii) the lowest price at which the
Company has raised equity capital during the life of the
Facility.
At the date of this Report, the Group had unaudited unrestricted
cash and cash equivalents of $2.4 million, subsequent to the first
three draw downs of GBP0.8 million each under the GBP4.0 million
2017 Facility.
The Group continues to have material work obligations under its
various exploration licences, as outlined in note 2.4, and if these
obligations are not met, the Group may be forced to forfeit its
working interests in these contracts and any sums of restricted
cash lodged with host governments as guarantees for our performance
of the minimum work obligations. Since some of the licences contain
provisions for the payment of penalties if the minimum work
obligations are not fulfilled, potential penalties may apply. The
Company is currently engaged in various discussions to restructure
its minimum work obligations and to divest or bring in partners in
order to reduce or eliminate the Group's net exposure to such
obligations. There is no certainty that any or all of the
restructurings or farm-outs or divestments will be successful.
The 2016 Financial Statements have been prepared on a going
concern basis (see note 1.3), and further details on this can be
found in the Financial Review on page 19.
Board and management changes
In July 2016 Mr. Alastair Beardsall stepped down as Executive
Chairman, as well as a Director and Executive of the Company. At
the same time Mr. John Bell assumed the role of Managing Director,
Mr. Andrew Morris assumed the role of Finance Director and Mr.
James Ede-Golightly assumed the role of Non-Executive Chairman.
In October 2016 we welcomed Mr Michael Kroupeev and Mr Richard
Milne to the Board as Non-Executive Directors and Mr Milne was
subsequently elected chair of the Audit Committee. In December 2016
Andrew West stood down as a Non-Executive Director, returning the
size of the Board to six members.
In December 2016 the Group settled its long outstanding dispute
with former Chief Executive Officer, Mr Mahdi Sajjad. Under the
terms of the settlement, all actions against the Group by Mr Sajjad
in the London High Court, the Employment Tribunal in England, and
in the Lebanese Arbitration Court, as well as the Group's
counterclaim against Mr Sajjad, were settled without any admission
of liability by either party.
Outlook for 2017 and beyond
The Group remains committed to controlling costs and preserving
the value inherent in its Syrian assets. It considers its
partnership with General Petroleum Corporation ("GPC") as a key
element for the safe stewardship of Block 26 while the various
sanctions prevent Gulfsands from a more active role.
We continue to enjoy the support of our three major
shareholders, without whose support, the Company would be seriously
financially challenged. We intend to further rationalise the
non-core portfolio through farm-out or divestment, and where this
is not possible we will exit countries as efficiently as possible.
While progressing our projects ourselves in the near term in
Colombia, we continue to seek to find a solution for these assets
whereby we can benefit from any success but without being exposed
to the full cost of exploration.
We would like to thank all our staff for their hard work over
the last twelve months and look forward to working with them in the
future to develop Gulfsands into an oil and gas company we can all
be proud to be part of.
Yours sincerely,
John Bell James Ede-Golightly
Managing Director Non-Executive Chairman
26 May 2017
Strategic Report
Operations Review
Syria
Gulfsands is the operator of the Block 26 Production Sharing
Contract ("PSC") and holds a 50% working interest in the PSC along
with Sinochem Group (also 50% working interest).
Gulfsands is not presently involved in any production or
exploration activities on Block 26 as Force Majeure has been
declared in respect of the contract following the introduction of
EU sanctions in Syria.
The Group seeks to ensure that it remains compliant with all
applicable sanctions in relation to Syria and intends to return to
production and exploration activities as soon as permitted.
Position during 2016
-- Continued compliance with applicable sanctions.
-- Block 26 facilities, wells and infrastructure remain secure and predominantly functional.
-- Office presence maintained in Damascus.
Block 26 is located in North East Syria and the PSC grants
rights to the joint venture to the benefits of production from
discovered fields for a minimum of 25 years from the date of
development approval with an extension of a further ten years
thereto at the partners' option. Gulfsands joint venture partner in
Block 26 is Sinochem Group, a Chinese conglomerate primarily
engaged in the production and trading of chemicals and fertilizer,
and exploration and production of oil.
Under the Group's operatorship, two oil fields containing
reservoirs of Cretaceous age have been discovered and appraised and
approved for Development within the PSC area, Khurbet East (2008)
and Yousefieh (2010). During 2011, combined production from these
fields reached a level of just under 25,000 barrels of oil per day
before the impact of EU sanctions resulted in the curtailing of
production levels. Two additional oil and gas discoveries within
reservoirs of Triassic age have been identified within the
Kurrachine and Butmah Dolomite formations, beneath the Cretaceous
aged oil producing reservoir in the Khurbet East field. Development
approvals for these Triassic discoveries were granted in 2008 and
2011 respectively. A further oil discovery was made late in 2011 by
Gulfsands in the Cretaceous aged reservoirs penetrated by the Al
Khairat exploration well, a few kilometres east of the Yousefieh
field. This discovery awaits further evaluation and development
work, and is not currently incorporated into the Company's existing
Production Licence areas.
Operation of the Khurbet East and Yousefieh fields during the
production phase has been undertaken by Dijla Petroleum Corporation
("DPC"), a joint operating company formed between Gulfsands,
Sinochem and Syrian General Petroleum Company ("GPC") for this
purpose, to which staff of both Gulfsands and GPC had previously
been seconded. As a consequence of the EU's imposition of further
sanctions in Syria which came into effect in early December 2011,
in accordance with the terms of the PSC for Block 26, a Notice of
Force Majeure was served on GPC, the principal counterparty to the
PSC. The imposition of EU sanctions has prohibited Gulfsands'
involvement in petroleum production operations in Syria and
restricted its activities in relation to Block 26 generally, and
unless and until these sanctions are lifted or otherwise modified
so as to permit the Company's return to its prior involvement in
those activities, the Company will be obliged to maintain its
current position with respect to Block 26 PSC matters. Since the
introduction of EU sanctions on 1 December 2011 and the subsequent
declaration of Force Majeure under the PSC, Gulfsands has had no
involvement with the operations of DPC, and Gulfsands staff
seconded to DPC have been withdrawn, leaving DPC under the
management of GPC secondees.
The final exploration period of the PSC legally expired in
August 2012. It is understood that the Syrian authorities may be
prepared to grant the Group an additional period to undertake
exploration work on Block 26 to replace that period of time which
was lost when Force Majeure was declared. The Group has ensured
that it remains compliant with all applicable sanctions in relation
to Syria and intends to return to production and exploration
activities as soon as permitted and conditions allow.
During 2015 the Group's Syria Reserves were reclassified to
Contingent Resources as a result of the continuing EU sanctions in
Syria. This process was subject to external audit and confirmation.
During 2016 this classification as Contingent Resources
continued.
Since December 2011, Gulfsands has received from DPC updates on
oil volumes produced from the Group's Syrian fields under DPC's
operation. These updates have been received on an infrequent and
irregular basis and it has not been possible for Gulfsands to
verify the content of the information provided. The Group has been
updating its remaining recoverable resource volumes for these
fields on at least an annual basis based on the information that
has been received from DPC.
In February 2016 the Group received information from DPC stating
that 0.267 million bbls of oil had been produced from the Group's
fields during 2015 and exported by pipeline to the regional oil
gathering station at Tal Addas, 22 km north east of the Group's
Production Concessions. In addition, DPC reported for the first
time, that oil also had been lifted from the Group's fields by an
alternative oil export method, via production into tankers using
gantry loading at the Khurbet East Production Facility, and that
this method had been in operation throughout 2014 and 2015. Total
oil production, by both methods, were therefore restated to being
2.384 million bbls of oil for 2014, and 1.421 million bbls of oil
for 2015.
In early 2017, DPC reported total produced volumes of oil during
2016, via both export methods of 0.477 million barrels of oil. Of
this volume, 0.184 million bbls has been exported by pipeline to
Tal Addas and 0.263 million bbls of oil has been exported via
production into tankers using gantry loading.
Subsequent to the reporting period, the Group has also been
informed by DPC that the Group's Syrian fields were returned to
production in January 2017, with oil being produced from up to
twelve production wells (nine Khurbet East, three Yousefieh). The
average oil production rate from both fields combined between
January 2017 and April 2017 appears to be around 15-20 thousand
bopd, with a cumulative gross oil volume of approximately two
million barrels of oil having been produced during 2017 from both
fields.
The Group is challenged to independently verify this production
information from DPC, and whilst remaining sanctions compliant,
continually seeks to gain additional information regarding the
ongoing status of production operations at its Syrian fields.
The status of this production under the terms of the PSC is
unclear at this time and the Group has not recognised any revenue
for this or indeed any production, post the imposition of EU
Sanctions, but has updated its remaining recoverable resource
volumes for these fields based on this new production
information.
Contingent Resources
The Group has evaluated that it holds within the Massive, Butmah
and Kurrachine reservoirs of Khurbet East field, and the Yousefieh
field, 2C Contingent Resources of 68.7 mmbbls of oil and
condensate, and 33.4 bcf of gas (working interest basis).
The Group has also evaluated that the oil discovery at Al
Khairat contains 2C Contingent Resources of 12.0 mmbbls of oil
(working interest basis). These resources have been subject to
external audit.
Sanction compliance
Gulfsands has taken extensive legal advice with respect to its
obligations under the sanctions in place at the time and has
liaised regularly with relevant regulators and advisers and
generally acted cautiously to be confident of remaining compliant
with all relevant sanctions. The Board is determined to ensure that
the Group's activities remain compliant and Management will
continue to liaise closely with the relevant regulatory authorities
to ensure this objective is achieved while continuing to keep GPC
fully informed of the breadth and scope of restrictions on our
activities as a result of continuing to comply with applicable
sanctions.
Plan to monitor assets during 2017
-- Continued compliance with applicable sanctions.
-- Maintain an office presence in Damascus.
-- Continue efforts to assimilate and verify where possible
information from the field regarding:
o oil production data
o asset operations and facility / well integrity; and
o overall status of security in the near field area.
-- Re-confirm to the extent that it is possible Gulfsands'
financial position including regarding cost recovery.
-- Update Gulfsands' plans to maintain readiness to resume
operational activities when sanctions are lifted, including
developing a re-entry plan.
Colombia
Gulfsands has Exploration and Production Contracts ("E&P
contracts") over two onshore contract areas, Llanos Block 50
("LLA-50") and Putumayo Block 14 ("PUT-14"), covering approximately
514 km(2) and 464 km(2) respectively. Gulfsands is operator of both
Blocks with 100% working interest. Both contracts were awarded as
part of the Ronda 2012 national licensing round, and are subject to
tax/royalty systems incorporating a low bid level of additional "X"
factors royalties and work programme contributions.
Llanos Block 50
Contract expiry First exploration phase, May
date: 2018.
Minimum work Acquisition of an additional
obligation: 160 km of 2D seismic data to
be captured in a new survey;
and drilling one exploration
well.
Further details are provided
in note 2.4 to the Consolidated
Financial Statements.
----------------- ----------------------------------
The LLA-50 Block is located towards the eastern margin of the
Llanos Basin. The Block is considered prospective for medium
quality oil, and it is on strike with producing oil fields in the
Blocks to the south. The primary play system has been identified as
structural-stratigraphic, linked to Tertiary channel sands which
are thought to be present in the east of the Block where on-strike
faults are also observed on seismic. Conceptual leads are
identified, and the 2D seismic work programme has been targeted to
better define the closure of these leads with an aim to mature them
to drillable prospects. A well was previously drilled down dip in
the west of the Block by another operator which confirmed the
presence of good quality reservoir and seal elements.
The Llanos-50 licence was originally due to expire in November
2014, when an application for an extension of 18 months to May 2018
was made by the Group to the Agencia Nacional de Hidrocarburos in
Colombia ("ANH"). As part of this application the Group indicated
its willingness to acquire a further 52 km of 2D seismic data in
addition to the 108 km already specified in the Minimum Exploration
Programme work obligation. This extension was confirmed in May 2017
and work has commenced on the environmental studies on the
Llanos-50 licence.
Putumayo Block 14
Contract expiry First exploration phase, November
date: 2017.
Minimum work Acquisition of an additional
obligation: 98 km of 2D seismic data to be
captured in a new survey; and
drilling one exploration well.
Further details are provided
in note 2.4 to the Consolidated
Financial Statements.
----------------- -----------------------------------
The PUT-14 Block is located at the eastern margin of the
Putumayo Basin and is considered prospective for medium quality
oil. A limited amount of legacy seismic available on the Block
nevertheless indicates the potential continuation into the Block of
stacked Cretaceous sands which have been encountered in wells in
Blocks to the west and north in Putumayo, and to the south in
Ecuador's Oriente Basin where there also exist on strike producing
oil fields. The potential for large stratigraphic pinch out leads
in PUT-14 has been identified both by Gulfsands and by another
operator in the area. In addition the on Block legacy seismic data
indicates subtle structural leads west of the Basin margin that
appear somewhat analogous to producing oil fields in the Putumayo
Basin to the west. A 2D seismic programme is planned to better
define all of these leads, aiming to mature them to drillable
prospects.
The Putumayo-14 licence expires in November 2017 and the Group
is in dialogue with ANH to also secure an extension for this
licence. In October 2016 the terms of a farm-out were agreed with
Samarium Energy & Resources Corporation, a fully owned
subsidiary of Samarium Tennessine Corporation and Samarium
Investment Corporation, acting as Guarantor (together "Samarium").
The Company simultaneously entered into a Joint Operating Agreement
("JOA") with Samarium Energy & Resource Corporation regarding
the operations of the Putumayo-14 Contract. Under the terms of the
farm-out Agreement, Samarium had the opportunity to earn 100%
working interest in the PUT-14 Licence in return for funding the
entire Minimum Exploration Programme.
Since October, Samarium and Gulfsands have been in regular
dialogue regarding the implementation of this Agreement but have
been unable to agree a mutually acceptable way to move forward. As
a result, Gulfsands took the decision to pursue the work programme
alone, to ensure ongoing compliance with the terms of the PUT-14
licence, and amongst other things contracted for the commencement
of the first phase of work, the Consulta Previa in March 2017. In
May 2017, the Farm-Out Agreement was terminated and Gulfsands has
reverted to having a 100% interest in the PUT-14 licence.
The Group requires funding to execute the work programme on both
permits and, to this end, continues farm-out or divestment
exercises for its interests in the contract areas prior to any
significant financial commitment with respect to further
exploration work.
Morocco
Gulfsands is the operator of the onshore Moulay Bouchta
exploration permit in northern Morocco which incorporates proven
conventional oil and biogenic gas petroleum systems. Moroccan
hydrocarbon exploration and exploitation permits are subject to a
tax/royalty fiscal system which is considered favourable by
international standards.
Moulay Bouchta contract
Contract expiry Initial Exploration Phase, June
date: 2017
Minimum work Acquisition and processing of
obligation: 200 km of 2D seismic data; reprocessing
and interpretation of selected
legacy 2D seismic lines; and
a legacy oil field reactivation
study. Further details are provided
in note 2.4 to the Consolidated
Financial Statements.
----------------- ------------------------------------------
The Group acquired operatorship of the Moulay Bouchta permit
during 2014, taking a 75% participating interest while Morocco's
Office National des Hydrocarbures et des Mines ("ONHYM") retained a
25% participating interest, the attributable cost of which will be
carried by Gulfsands upon the usual terms for such participation
through the exploration phase of the permit and until a commercial
hydrocarbon discovery is made.
The Moulay Bouchta permit encompasses an elongated area running
west to east covering approximately 2,808 km(2), and is located to
the north of the cities of Rabat, Meknes and Fes. It covers terrain
where the existence of a working petroleum system has been
confirmed with the discovery and development of three light oil
fields, the most recent of which was the Haricha Field which had
produced a total of 2.8 mmboe of oil and 4.2 bcf of gas when
production ceased in 1990. The prospectivity within Moulay Bouchta
is considered to relate mainly to the potential for deeper and
possibly larger hydrocarbon bearing structures within Jurassic and
Cretaceous aged reservoirs to exist and be found within the permit
area.
An agreement was reached with ONHYM, but only confirmed by
government approval post year end, to extend the duration of the
Initial Phase of the Exploration Period from two years to three
years such that the Initial Phase will now run to 19 June 2017
(previously 19 June 2016). A revised work programme for the
extended Initial Phase was also confirmed and approved, of:
-- acquisition of 200 km 2D line seismic;
-- reprocessing and interpretation of selected legacy 2D seismic data; and
-- legacy field study with the aim to identify any potential for re-activation.
The Company has engaged in further discussions to extend the
Initial Phase to June 2018 to allow time for the Company to
complete its minimum work program and fully analyse the results.
However, the Company will only take advantage of this extension if
it is able to find a partner who would be interested in a farm-out
of this project and help ease the financial burden.
If a partner is found, GPML plans to execute a focused work
programme, incorporating acquisition of 200 km 2D line seismic over
an oil prospective area identified to the east of the depleted
Haricha oil field. Following re-interpretation of existing 2D
legacy seismic data on the permit, and prior to the acquisition of
further 2D data, the Group has identified best estimate Prospective
Resources of 11.4 mmboe of oil and gas (75% working interest)
within the Moulay Bouchta permit area. These resources have been
subject to external audit.
Additional reprocessing and interpretation of selected 2D lines
to the east of the depleted Haricha oil field has resulted in the
identification of new lead concepts, with gross recoverable
Prospective Resources now estimated at 149 mmboe. This estimate has
not been subject to external audit.
The Group continues to seek to farm-down or divest its interest
in the Moulay Bouchta Petroleum Agreement, to reduce its future
financial commitments.
Note that there exists no parent company guarantee under the
Moulay Bouchta Petroleum Agreement.
Other exploration contracts
Exploitation concessions located on former Rharb Centre
permit
The Group also holds interests in three exploitation concessions
lying within the former Rharb Centre permit area as follows:
-- Zhana 1, a 25 year concession that expires in June 2025 (GPX: 65%, ONHYM: 35%);
-- Zhana 2, a 15 year concession that expires in February 2018 (GPX: 75%, ONHYM: 25%); and
-- Sidi Amer 1, a 15 year concession that expires in July 2019 (GPX: 75%, ONHYM: 25%).
There are four wells on these three concessions that penetrate
depleted, or near depleted gas reservoirs. The Group has no plans
to re-enter or produce from these four legacy wells or gas fields
as such activities have been evaluated to be economically
unattractive.
Expired Rharb and Fes contracts
The Rharb and Fes exploration contracts both expired during
2015.
The Group continues to discuss with ONHYM the status of the
restricted cash totalling $6.0 million previously held as
performance guarantees for these permits (Rharb $1.0 million and
Fes $5.0 million). The Group believes there are no grounds for any
potential claims for financial sums or penalties resulting from the
expiry of these licences, and therefore continues to request that
ONHYM release these funds back to the Group. Discussions with ONHYM
continue.
In this regard, in January 2016 Gulfsands gave notice to ONHYM
that if various matters including those of any potential penalty
for non-fulfilment of the minimum exploration work programme and
the return of guarantee funds called are not resolved then
Gulfsands reserves the right to proceed with arbitration as set out
under the Rharb and Fes Petroleum Agreements.
Note, no parent company guarantee exists under the Fes Petroleum
Agreement, or the Rharb Petroleum Agreement.
Tunisia
Gulfsands has a 100% interest in the operated Chorbane
exploration permit onshore Tunisia covering approximately 1,942
km(2). The permit is subject to a PSC signed in 2009. The fiscal
terms of the PSC are considered reasonable when compared on an
international basis.
Chorbane contract
Contract expiry Second phase July 2017 following
date: approval by the Ministry of a
two year extension.
Minimum work Drilling one exploration well;
obligation: and acquisition of 200 km of
2D seismic data.
Further details are provided
in note 2.4 to the Consolidated
Financial Statements.
----------------- ----------------------------------
The exploration risk level associated with the drilling of
identified prospects and leads is considered to be medium for light
oil in Eocene and Cretaceous aged formations which exhibit moderate
to good reservoir quality, but relatively high for wet gas in
deeper Jurassic aged formations which are anticipated to be of low
reservoir quality.
The Group has identified best estimate Prospective Resources of
44 mmboe of oil and gas (100% working interest) within the Chorbane
permit area. This resource estimate has been subject to external
audit.
The current exploration period under the contract originally ran
to mid-July 2015. In May 2015, Gulfsands submitted an application
for a two year extension to this period during which the work
obligation of acquiring 200 line km of 2D seismic and the drilling
of one exploration well must be completed. The extension was
granted to July 2017 but since then there has been a dispute over
the work required and the Group has been unable to agree an
appropriate work program with Entreprise Tunisienne d'Activités
Pétrolières ("ETAP").
Consequently, in November 2016, the Group's subsidiary,
Gulfsands Petroleum Tunisia Limited informed the Tunisian
authorities that, if it could not find a partner for its projects,
it intended to cease all Tunisian operations at the year end. Post
year end the Group has initiated the close down of its Tunisian
activities.
Note, no parent company guarantee exists under the Chorbane
exploration permit.
Reserves
Reserves are categorised into Proved, Probable and Possible
Reserves in accordance with the 2007 Petroleum Resources Management
classification system ("PRMS") of the Society of Petroleum
Engineers ("SPE"). Definitions for Proved, Probable and Possible
Reserves are contained in the Glossary.
Working interest Reserves estimates for Syria have, to date,
represented the proportion attributable to the Group's 50%
participating interest, of forecast future hydrocarbon production
during the economic life of the Block 26 PSC, including the share
of that production attributable to General Petroleum Corporation
("GPC"). Hydrocarbons discovered on the Block 26 PSC contract area
in Syria have been evaluated as Reserves for several years leading
up to, and after, the imposition of EU sanctions in Syria. The
Group's Reserves over this period have been based on estimates made
by Gulfsands' technical teams which are then reviewed by
independent petroleum engineers from external parties. External
reviews of the Group's Reserves have been performed by Senergy (GB)
Limited ("Senergy") since 2009.
As a consequence of the EU's imposition of further sanctions in
Syria which came into effect in early December 2011, GPC has
assumed operational full control and responsibility for the
management of DPC (the joint venture operating company set up for
managing development and production operations within Block 26),
and Gulfsands has withdrawn all of its staff previously seconded to
DPC.
Since December 2011 Gulfsands has received updates from DPC on
oil volumes produced from the Group's Syrian fields under DPC's
operation. These updates have been received on an infrequent and
irregular basis and it has not been possible for Gulfsands to
verify the content of the information provided. The Group has
updated its remaining recoverable Reserves / Resource volumes for
these fields on at least an annual basis based on the information
that has been received from DPC.
Since the date of the first commercial oil production from the
Block 26 area by the Group, cumulative oil production from the
Group's fields is understood to have exceeded 26 mmbbls by year end
2016.
The Company recognises that it cannot give a definite timeline
for the resumption of the full field development of the discovered
fields within Block 26 that was suspended under the declaration of
Force Majeure in 2011. Furthermore, the SPE PRMS Guidelines suggest
that if the (re)commencement of development is five or more years
from the date of evaluation then the volumes of hydrocarbons should
be classified as Contingent Resources. The Company concluded in
December 2015 that the uncertainty in any timeline over which EU
sanctions in Syria may be lifted require that the volumes of oil,
gas and condensate previously reported as Syrian Reserves be
reclassified by the Company as Contingent Resources. During 2016,
this classification a Contingent Resources has continued.
Whilst no definite timeline for the Syrian conflict can be
substantiated, the Board believes that the EU sanctions ultimately
will be lifted and will continue to monitor all activity focused on
resolving the situation in Syria and reconsider the basis for
reversing this reclassification in line with any future
developments.
Resources
The Group's Resources are based on estimates made by Gulfsands'
technical teams which are then reviewed by independent petroleum
engineers from external parties. External reviews of the Group's
Resources have been performed for the Group by Senergy since
2009.
Summary of Contingent Resources
Contingent Resources are those quantities of petroleum
estimated, as of a given date, to be potentially recoverable from
known accumulations by the application of development projects, but
are not currently considered to be commercially recoverable due to
one or more contingencies. Contingent Resources are further
categorised by the SPE into 1C, 2C and 3C according to the level of
uncertainty associated with the estimates.
In accordance with the 2007 SPE PRMS, a guideline risk factor
should be stated associated with the Contingent Resources quoted
for each category; the risk factor indicates the likelihood that
the Group will ultimately commercially develop the Resource. The
risk factor considers all technical and non-technical factors that
are impacting or are likely to impact on the likelihood of
development, and is termed the "Chance of Development".
In estimating the Resources it has been assumed that the period
of time elapsed during which the Group has declared Force Majeure
on its Block 26 development and production activities will
ultimately be added as an equivalent time period extension to the
contractually specified time period following which the Block 26
Production Concessions were due to expire.
In February 2016 the Group received information from DPC stating
that 0.267 million bbls of oil had been produced from the Group's
fields during 2015 and exported by pipeline to the regional oil
gathering station at Tal Addas, 22 km north east of the Group's
Production Concessions. In addition, DPC reported for the first
time, that oil also had been lifted from the Group's fields by an
alternative oil export method, via production into tankers using
gantry loading at the Khurbet East Production Facility, and that
this method had been in operation throughout 2014 and 2015. Total
oil production, by both methods, were therefore restated to being
2.384 million bbls of oil for 2014, and 1.421 million bbls of oil
for 2015.
In early 2017, DPC reported total produced volumes of oil during
2016, via both export methods of 0.477 million barrels of oil. Of
this volume, 0.184 million bbls has been exported by pipeline to
Tal Addas and 0.263 million bbls of oil has been exported via
production into tankers using gantry loading.
Subsequent to the reporting period the Group has also been
informed by DPC that the Group's Syrian fields were returned to
production in January 2017, with oil being produced from up to 12
production wells (9 Khurbet East, 3 Yousefieh). The average oil
production rate from both fields combined between January 2017 and
April 2017 appears to be around 15-20 thousand bopd, with a
cumulative gross oil volume of approximately 2 million barrels of
oil having been produced during 2017 from both fields.
The Group is challenged to independently verify this production
information from DPC, and whilst remaining sanctions compliant,
continually seeks to gain additional information regarding the
ongoing status of production operations at its Syrian fields.
The status of this production under the terms of the PSC is
unclear at this time and the Group has not recognised any revenue
for this or indeed any production, post the imposition of EU
sanctions, but has updated based on this new production information
the Group's Contingent Resource bookings (Gulfsands working
interest 50%), which are stated below as of 1 January 2017. The
revised Resource figures have not been reviewed by independent
resource engineers.
In addition, Contingent Resources are estimated for the oil
discovery at Al Khairat which is located a few kilometres outside
of the Company's existing Block 26 Production Concession areas.
These estimates have been reviewed by Senergy.
Unrisked working interest basis
As at 1 January 2017
Risk factor
(Chance
of
Constituent 1C 2C 3C development)
-------------------------- --------------- ------ ------ ------- ---------------
Syria Block 26
(Working interest
50%)
Oil and
Khurbet East Condensate,
and Yousefieh mmbbl 38.5 68.9 111.3 90%
Production Concessions Gas, bscf 14.7 33.4 68.7 90%
Al Khairat discovery Oil, mmbbl 2.9 12.0 45.7 30%
Total mmboe 43.8 86.4 168.4
------------------------- ---------------- ------ ------ ------- ---------------
Risked working interest basis
---------------------------------------------
Total mmboe 37.7 70.6 124.1
-------- -------- ------ ------ -------
Note certain figures may not add up due to roundings.
"Oil" includes condensate and NGLs.
Gas is converted to mmboe at the conversion factor 1 bcf =
0.1667 mmboe.
Summary of Prospective Resources
Prospective Resources are those quantities of petroleum
estimated, as of a given date, to be potentially recoverable from
undiscovered accumulations. They are further categorised by the
2007 SPE PRMS into Low, Best and High estimates. The quoted Low,
Best and High estimates are the 90% probability ("P90"), 50%
probability ("P50") and 10% probability ("P10") values respectively
derived from probabilistic estimates generated using a "Monte
Carlo" statistical approach.
In accordance with the 2007 SPE PRMS, a guideline risk
assessment should be provided associated with the Prospective
Resources quoted for Low, Best and High estimate categories. The
risk assessment here is the Chance of Discovery; the additional
risk assessment relating to the Chance of Development is not
normally quantified at this level of Resource classification.
The Group has estimated Prospective Resources for its Moroccan
Moulay Bouchta and Tunisian Chorbane onshore permits, and these
estimates have been reviewed by Senergy.
Note that with the impending maturities of, and the Group's
strategy with respect to, the Moulay Bouchta and Chorbane licences,
it is likely that these Prospective resources will significantly
reduce in 2017.
Unrisked working
interest basis
As at 1 January
2017 Risk factor
(Chance
of
Constituent Low Best High discovery)
-------------------- -------------- ----- ------ ------ -------------
Morocco Moulay Bouchta
permit
(Working interest
75%)
Oil and
Sales Gas,
Jurassic leads mmboe 1 11 75 Medium-High
Morocco total mmboe 1 11 75
-------------------- -------------- ----- ------ ------ -------------
Risk factor
(Chance
of
Constituent Low Best High discovery)
------------------------- -------------- ----- ------ ------ ---------------------
Tunisia Chorbane permit
(Working interest
100%)
Sidi Agareb
prospect Eocene/Upper
Cretaceous Oil, mmbbl 8 27 63 9%-25%
Lafaya Deep
and Sidi Daher
prospects Jurassic Sales Gas,
leads bcf 21 103 398 11%
Tunisia total mmboe 12 44 129
------------------------- -------------- ----- ------ ------ ---------------------
Please note, certain figures may not add up due to
roundings.
"Oil" includes condensate and NGLs.
Gas is converted to mmboe at the conversion factor 1 bcf =
0.1667 mmboe.
Strategic Report
Financial Review
Selected operational and financial data
Year ended Year ended
31 December 31 December
2016 2015
$'000 $'000
-------------------------------- ------------- -------------
General administrative
expenses (4,182) (6,965)
Exploration costs
written-off/impaired (8,055) (53,799)
Adjustment to estimated
decommissioning obligations (1,136) -
Adjustment to estimated
penalty costs (2,800) -
Loss from continuing
operations (19,755) (69,200)
E&E cash expenditure (1,879) (10,085)
Cash and cash equivalents 1,036 420
Restricted cash balances 500 3,691
-------------------------------- ------------- -------------
Financial highlights for the year ended 31 December 2016
-- The loss for the year from continuing operations was $19.8 million (2015: $69.2 million).
-- Gulfsands has continued to reduce its office expenses which
have reduced by 43% in the year compared with 2015, as outlined in
the table below.
-- $5.3 million of E&E assets related to the Tunisian
Chorbane licence have been written off at 31 December 2016, in
addition, estimated potential penalty costs of $3.8 million which
have been provided for.
-- $1.1 million of E&E assets related to the Colombian
Llanos 50 licence have been fully impaired as a result of the
initial expiry of the licence in November 2016; in addition, the
related restricted cash balances of $1.5 million have also been
provided against.
-- $1.1 million of E&E assets related to the Colombian
Putumayo 14 licence have been fully impaired at 31 December 2016,
given the time left on the licence; in addition, the related
restricted cash balances of $1.8 million have also been provided
against.
-- $0.5 million of costs related to the Moulay Bouchta licence
were incurred and immediately impaired during the year. This was
offset by a $1.0 million reduction to the estimated potential
penalty costs provided for, subsequent to the amendment of the
minimum work programme.
-- The estimated decommissioning provision obligations of the
Rharb permit has been increased by $1.1 million.
-- The Group continues to hold its investment in its Syrian
interest at a carrying value of $102.0 million.
-- Cash and cash equivalents increased by $0.6 million in the
year to $1.0 million at 31 December 2016 (31 December 2015: $0.4
million).
Operating performance
General administrative
expenses Year ended Year ended
31 December 31 December
2016 2015
$'000 $'000
-------------------------------- ------------- -------------
Office expenses 4,986 8,727
Partner recoveries (276) (552)
Restructuring costs - 1,044
Depreciation and amortisation 78 506
Office expenses capitalised (606) (2,760)
-------------------------------- ------------- -------------
General administrative
expenses 4,182 6,965
-------------------------------- ------------- -------------
General administrative expenses for the year ended 31 December
2016 totalled $4.2 million (2015: $7.0 million). This decrease
follows a reduction of activity in Colombia, Morocco and Tunisia,
an increased focus of management on the Syrian Block 26 asset, and
continuing efforts to manage costs to fit the current business
model and strategy.
Exploration and evaluation ("E&E") asset impairments for the
period totalled $8.1 million (2015: $51.0 million) and relate
predominantly to the Tunisia (the Chorbane licence) and Colombia
(the Llanos 50 block and the Putumayo 14 block).
In November 2016, the Llanos-50 contract expired, and given that
there was uncertainty over whether the licence could be
successfully extended, the expenditure to date attributed to the
Llanos-50 contract of $1.1 million has been fully impaired.
Alongside this, the recovery of restricted cash balance of $1.5
million held as performance guarantees in relation to the minimum
work obligation under this contract has also been fully provided
against. Subsequent to the year end the contract was successfully
extended by 18 months to May 2018, however despite this extension,
there remains uncertainty as to whether the Group will attract a
partner to execute the work programme and so this treatment has
been retained.
The Putumayo-14 licence expires in November 2017 and the company
is in dialogue with ANH regarding an extension. However, given the
time left on the licence, and notwithstanding the Samarium farm-out
deal, in accordance with Group policy, the Board has taken the
prudent approach of providing against the $1.7 million of
restricted cash supporting the Putumayo-14 Letter of Credit, and
the expenditure to date attributed to the Putumayo-14 contract of
$1.1 million has been fully impaired.
On the Moulay Bouchta licence, discussions to extend the licence
progressed during the year with an agreement reached to extend the
Initial phase to June 2017, which was eventually approved in
February 2017. The extension reduces the minimum work programme
commitment by $1 million, and so the provision for a potential
penalty has been commensurately reduced by $1 million. $0.5 million
of internally capitalised costs in 2016 were immediately
impaired.
In late 2016, the Group made a strategic decision to exit from
Tunisia if it could not find a partner for its projects, where it
holds the Chorbane contract which is due to expire in July 2017.
The capitalised E&E asset under the Chorbane contract during
the period of the contract, totalling $5.3 million, has been fully
impaired, with associated penalty costs of the minimum work
obligation of $3.8 million being provided for. No restricted cash
balances are held as a guarantee in relation to the minimum work
obligation under the Chorbane contract.
The Group reported a loss before tax for continuing operations
for the year ended 31 December 2016 of $19.8 million (2015: $69.2
million).
Balance Sheet
While the Group still has interests in a number of E&P
contracts in its portfolio, the Group's intangible exploration and
evaluation ("E&E") assets are now held at a net book value of
$nil at 31 December 2016 (31 December 2015: $7.1 million). Capital
expenditures totalled $0.9 million for the year (2015: $8.5
million).
Management has reviewed the carrying value of all its remaining
E&E assets at the date of this Report and notes that there are
uncertainties caused by the upcoming expiry dates on certain
contracts and the potential for non-fulfilment of work obligations
in the necessary timeframes. Despite the write-downs and
impairments in accordance with its accounting policies,
management's strategy remains to protect the value of all of its
E&E assets, and where possible it is seeking contract
extensions and the restructuring of certain of its work obligations
to allow the contracts to be appropriately farmed down, divested or
exited. It should be noted that management may not be successful in
its strategies for the E&E assets. The contract/licence expiry
dates, capital commitments and restricted cash balances held are
detailed further in note 2.4 to the Consolidated Financial
Statements.
The Group's investment in DPC, the entity established in Syria,
pursuant to the PSC, to administer the Group's Syrian oil and gas
development and production assets (and which is considered to also
include the related rights to production under the PSC), is
recorded as an available-for-sale investment. Due to the unknown
duration of EU sanctions in force against Syria and uncertainty
over the eventual outcome of events in the country, any valuation
attributed to the investment is highly subjective and subject to
material change and uncertainty. Management reviewed the internal
valuation methodology in 2016, and as per 2015, continues to
believe that as a result of the passage of time and the high degree
of judgement required, it is no longer possible to reliably
estimate the investment's fair value. Management, as it did at 31
December 2015, continues to carry forward the last valuation which
could be reliably determined, being the $102 million previously
disclosed. This value will be reviewed periodically for impairment
and any impairment losses recognised through the Income
Statement.
At 31 December 2016, management has carried out an impairment
review, using an economic model of the estimated future cash flows
that could be generated in respect of the Group's entitlement
volumes in Block 26 (see note 4.2 for details). The Management team
has reviewed this economic model in detail and believes, due to the
high degree of subjectivity inherent in the valuation, that it is
imperative that the valuation model and its key drivers and
assumptions are as transparent as possible. Management assessed the
key drivers to be: the oil price, and the delay to resumption of
production. For the year ended 31 December 2016 Management has
decided to use the Brent forward curve to 2022 (Source: Hannam
& Partners) for its oil price assumption, and then a 2% per
annum escalation factor applied thereafter as the forecast for the
'base case' comparative. Given the other sources of oil price data
reviewed, Management consider this to be a conservative approach.
Gulfsands cannot give a definite timeline for the resumption of the
full field development of the discovered fields within Block 26
that was suspended under the declaration of Force Majeure in 2011.
Whilst no definite timeline can be substantiated, the Board
continues to believe that the EU Sanctions will be lifted within
five years and will continue to monitor all activity focused on
resolving the situation in Syria. Management has decided to use
commencement of production in five years as the 'base case'
comparative.
The 'base case' comparative model calculates: a gross Contractor
undiscounted NPV(0) of $1.93 billion; Gulfsands 50% interest NPV(0)
of $0.97 billion and Gulfsands discounted NPV(15) of $150.7
million. Therefore, Management believes no impairment is necessary
and has maintained the $102 million carrying value on the Balance
Sheet at year end. Following consideration, Management consider it
premature to revalue the carrying value to the $150.7 million
discounted cash flow given the ongoing risks of the Block 26 asset
in Syria.
The Board's view is that there has been little significant
change to the circumstances and status of the Group's Syrian
interests during the year. The Board is still unable to provide a
firm view as to the eventual outcome and the timing of resolution
of the situation in Syria that would lead to the EU lifting
sanctions against Syria, allowing Gulfsands to return, however,
they continue to consider that its position in respect of its
interests remains strong and all indications are that the Syrian
authorities expect Gulfsands and its partner to return to
operational control of their interests in accordance with the terms
of the PSC as soon as circumstances permit.
The Directors have reviewed the carrying value of this
available-for-sale financial asset at 31 December 2016 and are of
the opinion that the carrying value, although subject to
significant uncertainty, remains appropriate in the
circumstances.
Inventory held at 31 December 2016 totalled $1.1 million (2015:
$1.1 million) related to inventory held in Morocco. Due to
Management's strategy in Morocco, it is anticipated that the
inventory will not be utilised on future drilling and production
activities and instead value will be likely extracted via
disposal.
At 31 December 2016, the Group has decommissioning and/or
restoration obligations in respect of a number of wells and well
sites in Morocco under the Moroccan Hydrocarbon Code. A provision
has been established for these obligations totalling $1.6 million
(2015: $0.4 million). The wells and well sites are located on the
expired Rharb and Fes permits and on the three exploitation
concessions located within these permits. These include the three
discoveries on the Rharb Centre permit: LTU-1, DRC-1 and DOB-1,
which have all been temporarily suspended. Included within the
decommissioning and/or restoration obligations are obligations on
all legacy wells drilled prior to the Group's acquisition of those
interests. Following continued examination during 2016 of the scope
of work involved, it is anticipated that the fulfilment of these
obligations can be completed by a combination of well work-over
completions (in conjunction with a plug and abandonment programme
with other operators in-country) and full column cementing (based
upon technical and/or health and safety interpretation). The Rharb
and Fes petroleum contracts expired during 2015, and as at 31
December 2016 all decommissioning provisions are disclosed as
current liabilities and no discount rate has been applied to the
estimated cost of decommissioning works.
While this provision has been established as a liability under
IFRS, the Company considers that this decommissioning obligation
should be fully satisfied by part of the performance guarantees
inappropriately taken by ONHYM in respect of the Rharb and Fes
licences, as described in note 6.6.
At the end of 2015, the Company made an Open Offer to all
qualifying Shareholders to provide an opportunity to subscribe for
an aggregate of 354,837,296 Open Offer Shares (representing a
subscription of 350,733,941 new ordinary shares and a purchase of
4,103,355 Treasury Shares) on the basis of 3.01 Open Offer Shares
for every one existing share held as at the Record Date, at an Open
Offer Price of 4.0 pence per Open Offer Share. The Open Offer
closed for acceptances at 11:00 a.m. on 12 January 2016 and the
Company announced that it had received valid acceptances in respect
of 151,760,157 Open Offer Shares from Qualifying Shareholders.
Pursuant to the Underwriting, a further 203,077,139 Open Offer
Shares were subscribed for by Waterford Finance & Investment
Limited ("Waterford") and Blake Holdings Limited ("Blake"), (a
company owned and controlled by Mr. Richard Griffiths), such that a
total of 354,837,296 Open Offer Shares were subscribed for under
the Open Offer. The Company therefore raised aggregate gross
proceeds of GBP14,193,491.84 through the Open Offer. The
350,733,941 new ordinary shares were admitted to trading on AIM on
14 January 2016. The Company also sold its 4,103,355 treasury
shares to Qualifying Shareholders under the terms of the Open
Offer. Following the issue of the new ordinary shares and the sale
of the treasury shares, at 30 June 2016 Gulfsands had 472,723,441
ordinary shares of 1.0 pence each in issue.
Subsequent to the closing of the Open Offer, the Convertible
Loan Facility was discharged in full on 14 January 2016. The
balance outstanding on the Convertible Loan Facility at this date
was $14.5 million inclusive of rolled up interest and facility
fees.
On 12 August 2016 the Company raised approximately GBP1.5
million ($1.9 million) by a placing of 47,272,344 new ordinary
shares at 3.125 pence per share ("Placing Shares"), the mid-market
closing price per ordinary share on 9 August 2016 (the "Placing").
The Placing Shares were subscribed for by existing shareholders in
the Company, Waterford, Blake, and ME Investments Limited (the
"Major Shareholders"), and the proceeds were used for general
working capital purposes. Following the Placing the total number of
ordinary shares in the Company in issue is 519,995,785, which
remains unchanged at the date of this Report.
On 15 February 2017, the Company entered into a Secured Term
Financing Facility of up to GBP4.0 million (the "2017 Facility")
with its Major Shareholders (the "Lenders"). The 2017 Facility is
available for drawdown by the Company in five equal tranches of
GBP0.8 million each. The first tranche was drawn immediately upon
the satisfaction of various administrative conditions precedent in
February 2017, with the further tranches being available on or
after 31 March 2017 (which was completed in April 2017), 30 June
2017, 30 September 2017 and 31 December 2017. The first two
tranches, were committed by the Lenders, with the final three
tranches, being subject to re-approval by each of the Lenders prior
to each drawdown request. At the time of writing, the first three
tranches have been drawn down after the Lenders unanimously
agreeing to allow the third tranche to be drawn down ahead of the
scheduled date of 30 June, 2017, in late April 2017, to assist with
working capital requirements. . Further details of the Facility are
outlined in note 6.7.
Cash flow
The total increase in cash and cash equivalents during the year
was $0.6 million (2015: $7.5 million decrease). Net cash outflow
from operating activities during the period totalled $5.0 million
(2015: $5.5 million). Investing cash outflow from continuing
operations during the period totalled $1.9 million (2015: $10.1
million). Net cash received from financing activities totalled $7.5
million, due to the January 2016 Open Offer and August 2016
placing, net of repayment of the Convertible Loan Facility.
Financial position
At 31 December 2016 the Group had total unrestricted cash and
cash equivalents of $1.0 million (31 December 2015: $0.4
million).
Restricted cash balances at the end of the year (which are
presented as long-term financial assets in the Balance Sheet)
totalled $0.5 million (31 December 2015: $3.7 million), and
represent funds securitised as collateral in respect of future work
obligations - with amounts not provided against, principally being
in respect of the Group's Syrian Block 26 interest. At 31 December
2016, a provision of $3.2 million was made against the restricted
cash balances securitised as collateral in respect of future work
obligations on the Llanos-50, and the Putumayo-14 licence.
In 2015 $6.0 million of restricted cash balances had been
provided for in relation to the maturing Rharb and Fes Petroleum
Agreements. During 2015 ONHYM seized these funds. The Group
considers that this restricted cash should not be retained by ONHYM
and continues to pursue the return of these restricted funds from
ONHYM in relation to the Fes and Rharb licences.
Going concern
As at the date of this Report, the Group has cash balances
immediately available to it totalling approximately $2.4 million
and ongoing General and Administrative costs are expected to
further decrease by the end of the second half of 2017 to a level
of approximately $0.2 million per month. .
On 15 February 2017, the company entered into a Secured Term
Financing Facility of up to GBP4 million (the "2017 Facility") with
its Major Shareholders (the "Lenders"). The 2017 Facility is
available for drawdown by the Company in five equal tranches of
GBP0.8 million, the first was drawn immediately upon the
satisfaction of various administrative conditions precedent in
February 2017, with the further tranches being available on or
after 31 March 2017 (which was completed in early April 2017), 30
June 2017, 30 September 2017 and 31 December 2017. The first two
tranches, were committed by the Lenders, while the final three
outstanding tranches, remain subject to re-approval by each of the
Lenders prior to each drawdown request. In late April 2017, the
Lenders unanimously agreed to allow the third tranche to be drawn
down ahead of the scheduled date of 30 June, 2017 to assist with
working capital requirements. Further details of the Facility are
outlined in note 6.7.
In the absence of any other sources of cashflow, the Group will
need to raise additional capital by the end of Q3 2017 to fund
ongoing operations. There remains up to GBP1.6 million (c. $2.0
million) available under the 2017 Facility, and should that be
approved for drawdown by the Lenders, the Group's cash forecast
indicates that the Group would have sufficient funds until Q2
2018.
The company remains reliant on the support of its three major
shareholders, without whose support, the Company would be seriously
financially challenged. Based upon its experience and ongoing
discussions with those shareholders, the Board believes that the
Group will be able to access the appropriate resources, either
through the remaining 2017 Facility drawdowns and/or through
equity, to finance the revised strategy, however there are no
binding agreements or commitments in place. ,
If the Company and Group do not complete the minimum work
commitments within agreed time periods, either directly, or via
strategic divestments or transactions with third party entities,
penalties equal to the unfulfilled contracted work commitments may
be payable. These could be substantial and additional details of
the capital commitments for the Company's licences/permits/are
fully described in note 2.4.
Potential liabilities to licences in Morocco and Tunisia, are
housed in dedicated subsidiaries without any parent company
guarantees in place. In analysing the Group's financial needs, the
Board has considered the timing and likelihood of the payment of
all current and potential liabilities.
Following completion of a review of the going concern position
of the Company and Group at the meeting of the Board of Directors
on 26 May 2017, including the uncertainties described above, the
Board has concluded that, with current consolidated cash and cash
equivalents totalling $2.4 million and taking into account both the
Board's current strategy and the new financial resources that the
Board might reasonably expect to become available, the Company and
the Group will have sufficient resources to continue in operational
existence for the foreseeable future, a period not less than twelve
months from the date of approval of this Financial Report.
Accordingly, the Directors consider it appropriate to continue to
adopt the going concern basis in preparing these Financial
Statements.
Notwithstanding the confidence that the Board has in its ability
to finance the Group's re-shaped business, the Directors, in
accordance with Financial Reporting Council guidance in this area,
conclude that at this time there is material uncertainty that such
finance can be procured and failure to do so might cast significant
doubt upon the Company's and the Group's ability to continue as a
going concern and that the Company and the Group may therefore be
unable to realise their assets and discharge their liabilities in
the normal course of business. These Financial Statements do not
include the adjustments that would result if the Group was unable
to continue as a going concern.
These Financial Statements consolidate the accounts of Gulfsands
Petroleum plc and all its subsidiary undertakings drawn to 31
December each year.
This Strategic Report was approved by the Board of Directors on
26 May 2017.
John Bell
Managing Director
26 May 2017
Cautionary statement
This Strategic Report has been prepared solely to provide
additional information to shareholders to assess the Group's
strategies and the potential for those strategies to succeed.
The Strategic Report contains certain forward-looking
statements. These statements are made by the Directors in good
faith based on the information available to them up to the time of
their approval of this report and such statements should be treated
with caution due to the inherent uncertainties, including both
economic and business risk factors, underlying any such
forward-looking information.
The Directors, in preparing this Strategic Report, have been
guided by the requirements of section 414c of the Companies Act
2006. The Report has been prepared for the Group as a whole and
therefore gives emphasis to those matters which are significant to
the Group as a whole.
Governance
Directors' Report
The Directors present their Annual Report together with the
audited Financial Statements of Gulfsands Petroleum plc and its
subsidiary undertakings (the "Group" or the "Company" or
"Gulfsands") for the year ended 31 December 2016.
The Corporate Governance Report, Audit Committee Report and
Directors' Remuneration Report set out on pages 25 to 33 form part
of this Directors' Report.
Any significant events since the Balance Sheet date are detailed
in note 6.7 to the Consolidated Financial Statements, however an
indication of possible future developments in the business of the
Group are included in the Strategic Report on pages 3 to 23.
Dividends
The Directors do not recommend payment of a dividend in respect
of 2016 (2015: $nil).
Capital structure
Details of the issued share capital, together with details of
the movements in the Company's issued share capital during the year
are set out in note 6.1 to the Consolidated Financial Statements.
The ordinary and deferred shares carry no right to fixed income.
Each ordinary share carries the right to one vote at general
meetings of the Company. The deferred shares have no voting
rights.
On 14 January 2016 the Company completed an Open Offer of
ordinary shares to shareholders on the record date resulting in the
issue of 350,733,941 new ordinary shares and the sale of 4,103,355
treasury shares.
On 12 August 2016 the Company completed a Placing of ordinary
shares to existing shareholders in the Company, Waterford, Blake,
and ME Investments Limited, and the proceeds were used for general
working capital purposes. Following the Placing the total number of
ordinary shares in the Company in issue is 519,995,785.
There are no specific restrictions on the size of a holding nor
on the transfer of shares, which are both governed by the general
provisions of the Articles of Association and prevailing
legislation. The Directors are not aware of any agreements between
holders of the Company's shares that may result in restrictions on
the transfer of securities or on voting rights.
Details of employee share schemes are set out in note 6.1 to the
Consolidated Financial Statements.
No person has any special rights of control over the Company's
share capital. As at 31 December 2016 all issued shares were fully
paid.
Substantial shareholders
Except for the holdings of ordinary shares listed below, the
Company has not been notified by, or become aware of, any persons
holding 3% or more of the issued ordinary shares of the Company at
26 May 2017:
Number of % of shares
Name shares in issue
----------------------------------- ------------- -------------
Waterford Finance and Investment
Limited (1) 194,042,618 37.32%
Blake Holdings Limited
(2) 145,856,452 27.70%
ME Investments Limited 72,623,428 13.97%
Seren Capital Management
Limited (2) 9,730,717 2.06%
Cream Capital Limited (2) 8,020,000 1.70%
Richard Griffiths 50,000 0.01%
----------------------------------- ------------- -------------
(1) Companies associated with Michael Kroupeev.
(2) Companies associated with Richard Griffiths.
Directors and their interests
The Directors, who served during the year except as noted, and
their interests in the Company's shares were as follows:
At 31 December At 31 December
2016 2015
--------------------------- -------------------------
Number Number
of of
Number Number
ordinary of share ordinary of share
shares options shares options
------------------ ------------- ------------ ------------ -----------
A Beardsall
(1) - - - -
A West
(5),(6) 561,977 - 140,144 -
A Morris
(2, 6) 320,800 5,000,000 80,000 -
J Darby
(6) 100,250 -- 25,000 -
J Bell
(3) - 8,000,000 - -
J Ede-Golightly
(6) 80,200 2,000,000 20,000 -
M Kroupeev
(4) (7) 194,042,618 1,000,000 33,100,513 -
R Milne
(4) - 1,000,000 - -
(1) Appointed 14 April 2015. Resigned on 22 July 2016.
(2) Appointed Non-Executive Director on 22 April 2015, appointed
Finance Director on 22 July 2016.
(3) Appointed Non-Executive Director on 13 August 2014,
appointed Managing Director on 22 July 2016.
(4) Appointed 10 October 2016.
(5) Resigned 31 December 2016.
(6) Following the Open Offer on 14 January 2016, Mr West, Mr
Morris, Mr Darby and Mr Ede-Golightly all took up their entitlement
of 3.01 shares per existing share and increased their shareholdings
to the following: Mr West 561,977; Mr Morris 320,800; Mr Darby
100,250 and Mr Ede-Golightly 80,200.
(7) Mr Kroupeev is an ultimate beneficial owner of
Waterford.
Directors' interests in transactions
Details of transactions with Directors for the year ended 31
December 2016 are set out in note 6.3 to the Consolidated Financial
Statements.
Statement of Directors' responsibilities
The Directors are responsible for preparing the Strategic
Report, Directors' Report and the Financial Statements in
accordance with applicable laws and International Financial
Reporting Standards ("IFRS") as adopted by the EU.
Company law requires the Directors to prepare financial
statements for each financial year. Under that law, the Directors
have elected to prepare the Group and Company financial statements
in accordance with IFRS as adopted by the European Union. Under
company law, the Directors must not approve the financial
statements unless they are satisfied that they give a true and fair
view of the state of affairs of the Group and Company and of the
profit or loss of the Group for that period. The Directors are also
required to prepare financial statements in accordance with the
rules of the London Stock Exchange for companies trading securities
on the Alternative Investment Market.
In preparing these financial statements, the Directors are
required to:
-- select suitable accounting policies and then apply them consistently;
-- make judgements and accounting estimates that are reasonable and prudent;
-- state whether they have been prepared in accordance with IFRS
as adopted by the European Union, subject to any material
departures disclosed and explained in the financial statements;
and
-- prepare the Financial Statements on the going concern basis
unless it is inappropriate to presume that the Company will
continue in business.
The Directors are responsible for keeping adequate accounting
records that are sufficient to show and explain the Company's
transactions and disclose with reasonable accuracy at any time the
financial position of the Company and enable them to ensure that
the financial statements comply with the requirements of the
Companies Act 2006. They are also responsible for safeguarding the
assets of the Company and hence for taking reasonable steps for the
prevention and detection of fraud and other irregularities.
Website publication
The Directors are responsible for ensuring the Annual Report and
the financial statements are made available on a website. Financial
statements are published on the Company's website in accordance
with legislation in the United Kingdom governing the preparation
and dissemination of financial statements, which may vary from
legislation in other jurisdictions. The maintenance and integrity
of the Company's website is the responsibility of the Directors.
The Directors' responsibility also extends to the ongoing integrity
of the financial statements contained therein.
Statement of disclosure to the auditor
So far as the Directors, at the time of approval of their
Report, are aware:
-- there is no relevant audit information of which the Company's auditor is unaware; and
-- each Director has taken steps that they ought to have taken
to make themselves aware of any relevant audit information and to
establish that the auditor is aware of that information.
This confirmation is given and should be interpreted in
accordance with section 418 of the Companies Act 2006.
Auditor
A resolution to reappoint BDO LLP as auditor and to authorise
the Directors to fix their remuneration will be put to shareholders
at the Annual General Meeting.
By order of the Board,
John Bell
Managing Director
26 May 2017
Governance
Directors' Remuneration Report for the year ended 31 December
2016
Companies listed on the main market of the London Stock Exchange
are required to comply with the UK Corporate Governance Code.
Gulfsands Petroleum shares are traded on AIM and as such, the
Company is not subject to the requirements of the UK Corporate
Governance Code on corporate governance. However, as a publicly
quoted company, the Company is committed to maintaining appropriate
standards of corporate governance.
The UK Corporate Governance Code represents the 'gold standard'.
However, the UK Corporate Governance Code was not designed with
smaller companies in mind. Adherence to the full UK Corporate
Governance Code is often impractical for smaller companies.
The Directors recognise the importance of sound corporate
governance and seeks to comply with the Main Principles of the UK
Corporate Governance Code and the detailed provisions of the QCA
corporate governance code 2013, as is appropriate for a company of
Gulfsands's current size and stage of development.
In order to communicate its corporate governance standards to
employees, contract staff and contractor personnel across the
Group, the Board has established a Code of Business Conduct and
Ethics which is available on the Company's website and supported by
detailed internal policies and procedures. Compliance with the Code
of Business Conduct and Ethics is a contractual requirement for all
personnel.
The Gulfsands Board
The role of the Board
The Board sets the Group's strategic objectives taking into
account the financial and human resources available within the
Group to meet these objectives. The Board determines the Company's
key policies, values and standards, effectively communicating these
throughout the Group. Periodically the Board reviews the potential
risks to the Group, and ensures the probability of these risks
affecting the business are minimised via management and
mitigation.
The Board's role is to provide entrepreneurial leadership of the
Group within a framework of effective controls and periodic
reporting; this enables operational and financial performance to be
actively monitored and managed.
The composition of the Board
Gulfsands' business carries political, commercial and technical
risks. Accordingly, particular attention is paid to the composition
and balance of the Board to ensure that it has experience of the
oil and gas industry, the regulatory environments in which the
Group operates and has appropriate financial and risk management
skills to lead the Group.
The Board considers that objectivity and integrity are
prerequisites for all appointments, as are the skills, experience,
ability and diversity that will assist the Board in its key
functions and decision-making. The Board sees the role of the
Non-Executive Directors to be to independently and constructively
challenge the performance of the Executive Management and to offer
assistance and mentor where their skills and experience can assist
the performance of the Management team in the delivery of agreed
objectives.
The Board of Directors currently comprises six Directors; the
Non-Executive Chairman, the Managing Director, the Finance
Director, and three Non-Executive Directors including a Senior
Independent Director. In accordance with the QCA code the Board
includes two independent Non-Executive Directors, Joe Darby and
Richard Milne. A brief description of each of the Directors'
backgrounds and experience can be found on page 24. The Board
continues to review its composition.
Terms and conditions of appointment of Non-Executive Directors
are set out in appointment letters.
How the Board operates
A detailed schedule of matters reserved for the Board has been
established and is periodically reviewed. The key matters reserved
are the consideration and approval of:
-- the Group's overall strategy and objectives;
-- material acquisitions and disposals and major expenditure commitments;
-- borrowing and hedging of oil and gas sales;
-- the issuance of equity and options;
-- annual work programme and budget;
-- the Group's annual and half-yearly Financial Statements;
-- Board appointments, remuneration and roles; and
-- corporate policies and corporate governance arrangements.
Through the publication of regular announcements, and
face-to-face meetings where appropriate, the Board has sought to
communicate its strategy, objectives and performance to all
shareholders on a timely basis.
The Board of Directors expects to hold Board Meetings
approximately six times per year. On occasions, additional meetings
are convened to resolve urgent business matters.
Committees of the Board
The Company has established two sub-committees of the Board, an
Audit Committee and a Remuneration Committee; the purpose of which
are to review areas of the business mandated by the Board and to
present findings and recommendations to the Board for its decision.
Each of the Committees has its own written terms of reference;
copies of which are available on the Company's website.
1. Audit Committee
The Audit Committee Report on pages 31 to 33 includes a
discussion of the role, structure and composition of the Audit
Committee.
2. Remuneration Committee
The Directors' Remuneration Report on pages 27 to 30 includes a
discussion of the role, structure and composition of the
Remuneration Committee.
The number of meetings of the Board and its Committees during
2016, and individual attendance by Directors, is shown below:
Board Audit Remuneration
---------------------- ------- ------- --------------
Number of meetings
2016 15 4 5
---------------------- ------- ------- --------------
Attendance:
---------------------- ------- ------- --------------
Alastair Beardsall 6 n/a n/a
---------------------- ------- ------- --------------
Andrew West 12 n/a n/a
---------------------- ------- ------- --------------
Andrew Morris 15 4 n/a
---------------------- ------- ------- --------------
Joe Darby 13 n/a 5
---------------------- ------- ------- --------------
John Bell 14 3 2
---------------------- ------- ------- --------------
James Ede-Golightly 14 2 5
---------------------- ------- ------- --------------
Michael Kroupeev(1) 2 0 3
---------------------- ------- ------- --------------
Richard Milne(1) 2 1 n/a
---------------------- ------- ------- --------------
(1) Appointed 10 October 2016.
As noted in the Corporate Governance Report, the Board delegates
certain of its duties, responsibilities and powers to the
Remuneration Committee, so that these can receive suitably focused
attention. However, it acts on behalf of the full Board, and the
matters reviewed and managed by the Committee remain the
responsibility of the Board of Directors as a whole.
This report has been prepared having regard to sections 473(3)
and 1290 of the Companies Act 2006. The report has been divided
into separate sections for audited and unaudited information. It
has been prepared by the Remuneration Committee and has been
approved by the Board for submission to shareholders.
Unaudited information
Role of the Remuneration Committee
The activities of the Remuneration Committee are governed by
terms of reference which cover its mandate, its composition, the
independence and expertise of the members, frequency of meetings,
and its responsibilities which include: determining and developing
the remuneration policy and determining the remuneration packages
of the Executive Board. The terms of reference were reviewed in
March 2016 and are available on the Company's website.
The Remuneration Committee derives its authorities from the
Delegation of Board Authorities, which was last reviewed in October
2016, and is the Committee responsible for ensuring that the
Company's overall reward philosophy is consistent with achievement
of the Company's strategic objectives in line with the Company's
values.
It is responsible for considering and making recommendations to
the Board in respect of remuneration for the Chairman and Executive
Directors. The Committee also has oversight of the remuneration
arrangements for the direct reports to the Executive Directors, the
remuneration for whom is set by the Managing Director in
conjunction with the Chairman.
The remuneration of Non-Executive Directors is a matter for the
Chairman in consultation with the Managing Director and the
Chairman of the Remuneration Committee, with fees being determined
by the Board excluding the Non-Executive Directors.
Composition of the Remuneration Committee
Joe Darby was Chairman of the Remuneration Committee throughout
the year initially with James Ede-Golightly and John Bell as
members of the Committee. Following the appointment of John Bell as
Managing Director, his place on the Committee was taken by Michael
Kroupeev. A brief description of their backgrounds and experience
can be found on page 24. The varied backgrounds of the Committee's
members, and their collective skills, experience and knowledge of
the Company, allows them to fulfil the Committee's remit and to
oversee the Company's remuneration policy.
The Remuneration Committee has the power to engage such external
advisers as it deems necessary to discharge its
responsibilities.
Number of Remuneration Committee meetings and attendance
The Remuneration Committee normally meets at least twice a year
but during 2016 met on several occasions and had numerous meetings
by telephone to review the remuneration reporting in the Annual
Report and Accounts for 2015 and in the interim report for 2016,
and to determine remuneration packages for the Chairman, Managing
Director, Finance Director and new Non-Executive Directors
following Board changes which occurred in July 2016 and
subsequently.
Remuneration policy
The overall policy of the Group is to attract, motivate and
retain high-quality employees capable of pursuing the Company's
long-term strategic objectives and delivering its short to
medium-term goals.
Directors and employees may be remunerated by a combination of
salary, annual bonuses and share-based awards which reflect the
size of the Company, the scope of its activities and its financial
position. Salary levels will reflect the seniority of the
individuals and responsibilities of their roles. Variable elements
of remuneration, annual bonus and share incentive awards, will be
dependent upon Company and individual performance, and/or linked to
length of service. Generally, variable remuneration will comprise a
significant part of overall remuneration.
The policy was reviewed in 2011 by Hewitt New Bridge Street,
independent remuneration consultants, who undertook a benchmarking
exercise in 2013 comparing remuneration of Directors and other
staff with their equivalent peers in other independent oil and gas
companies. Hewitt New Bridge Street were also consulted in 2016 on
remuneration packages for Executive and Non-Executive Directors
appointed in 2016.
Annual bonus
The annual bonus scheme provides bonuses up to 100% of base
salary for Executive Directors and staff for achievement of
performance in excess of normal expectations. In the past, bonuses
were entirely discretionary based upon performance during the year
compared to budget and plan. This practice may continue In the
future, but it is likely to be supplemented or replaced by setting
challenging targets in advance against which performance can be
measured and bonuses paid accordingly.
No bonuses were paid to Executive Directors in respect of
2016.
All staff are eligible to be considered for the award of annual
bonuses but these are entirely at the discretion of the
Company.
Share incentive schemes
The only share-based plan currently in operation is the
Gulfsands Restricted Share Plan which was introduced in 2010 and
expires in 2020. Under this plan, share awards may be granted to
Directors and members of staff and may be based upon length of
service and/or linked to achievement of performance criteria.
No share awards were granted to Directors or employees between
2011 and 2015. As a result of the fall in share price since the
imposition of sanctions against Syria towards the end of 2011,
options held by Directors at that time have either lapsed or, if
still outstanding, are exercisable at share prices significantly in
excess of the current share price.
During 2016, John Bell was appointed full time Managing Director
and Andrew Morris was appointed Finance Director on a less than
full time basis. In view of the continuing uncertainty surrounding
the Company's business in Syria and the shortage of available
funds, it was decided that remuneration packages for these two
executives should be a combination of base salary and share
options. Accordingly, John Bell was awarded 8 million share options
and Andrew Morris 5 million share options. 4 million of Mr. Bell's
options and 3 million of Mr. Morris' will vest quarterly over a two
-year period from July 2016 dependent in part on continued service
during that period and in part on performance criteria related to
the achievement of strategic objectives. The vesting schedule of
the additional 4 million and 2 million options respectively have
yet to be determined. Once vested, the options are exercisable for
a period of 10 years.
Share options were also granted to the Chairman and two new
Non-Executive Directors as detailed in the table below. These
options are not subject to performance criteria. Half of their
respective awards vested on the date of award and the other half
will vest after one year.
Audited information
Remuneration of Directors
The remuneration of the Directors for the year ended 31 December
2016 was as follows:
Annual remuneration ($'000)
--------------------------------------------------------------
Salary Benefits
and fees Bonuses in kind Total
-------------- -------------- -------------- --------------
2016 2015 2016 2015 2016 2015 2016 2015
----------------------- ------ ------ ------ ------ ------ ------ ------ ------
A Beardsall(2) 253 304 - - - - 253 304
A West(1,6) 45 72 - - - - 45 72
A Morris(3) 124 40 - - 1 - 125 40
J Darby(1) 52 69 - - - - 52 69
J Bell(4) 129 59 - - 1 - 130 59
J Ede-Golightly(1,7) 54 59 - - - - 54 59
M Kroupeev
(1,5) 9 - - - - - 9 -
R Milne
(1,5) 9 - - - - - 9 -
----------------------- ------ ------ ------ ------ ------ ------ ------ ------
677 603 - - 2 - 679 603
----------------------- ------ ------ ------ ------ ------ ------ ------ ------
(1) Non-Executive Director.
(2) Appointed as Executive Chairman on 14 April 2015. Resigned
22 July 2016.
(3) Appointed Non-Executive Director 22 April 2015. Appointed
Finance Director 22 July 2016.
(4) Appointed Non-Executive Director 13 August 2014. Appointed
Managing Director 22 July 2016.
(5) Appointed 10 October 2016.
(6) Resigned 31 December 2016.
(7) Non-Executive Director 1 January 2016 - 21 July 2016.
Appointed Chairman 22 July 2016.
In addition to the remuneration shown, the Group incurred
share-based payment charges of $159K (2015: nil) in respect of the
above named Directors relating to options granted in 2016.
Share options
The interests of the Directors, who held office during the 2016,
in options over the Company's shares are set out in the table
below:
Number of options
---------------------------------------------------
Exercisable
At at 31 Date
1 At 31 Exercise December from
January December price 2016 which Expiry
2016 Issued 2016 (GBP) exercisable date
---------------- ------------- ----------- ----------- ---------- ------------- ---------------------- ------------
J Bell - 8,000,000 8,000,000 0.01 1,000,000 11/11/2016 11/11/2026
A Morris - 5,000,000 5,000,000 0.01 620,000 11/11/2016 11/11/2026
J Ede-Golightly - 2,000,000 2,000,000 0.0375 1,000,000 11/11/2016 11/11/2026
M Kroupeev - 1,000,000 1,000,000 0.0375 500,000 11/11/2016 11/11/2026
R Milne - 1,000,000 1,000,000 0.0375 500,000 11/11/2016 11/11/2026
All other Directors held no share options or restricted share
options at 31 December 2015 or 2016.
This Report was approved by the Board of Directors on 26 May
2017 and signed on its behalf by:
Joe Darby
Chairman of the Remuneration Committee
26 May 2017
Governance
Audit Committee Report for the year ended 31 December 2016
The Audit Committee, which reports to and advises the Board,
comprises Non-Executive Directors of the Company. It is the Board's
view that the membership meets the requirement for recent and
relevant financial experience.
During 2016, four meetings were held which were also attended by
Executive Directors and members of staff who had input relevant to
the meeting agendas.
As far as financial reporting was concerned, attention focused
mainly upon the value of the Group's assets in Syria, the carrying
values for tangible and intangible assets, disclosure of contingent
liabilities and the going concern basis for reporting. In addition,
the Committee reviewed the key risks to which the Group is
exposed.
The relationship with, and performance of, the external auditor
was evaluated. The Audit Committee is satisfied that non-audit fees
payable to the external auditor are not material enough to impact
auditor objectivity or independence.
After consultation with the external auditor following the full
year 2016 audit, the Committee advised the Board that in its view
the Annual Report and Financial Statements for 2016 are a true and
fair reflection of the Company's and the Group's performance and
position at year end, and provide the information necessary for
shareholders to understand the Company and make their own
assessments.
As noted in the Corporate Governance Report, the Board delegates
certain of its duties, responsibilities and powers to the Audit
Committee, so that these can receive suitably focused attention.
However, it acts on behalf of the full Board, and the matters
reviewed and managed by the Committee remain the responsibility of
the Board of Directors as a whole.
Composition of the Audit Committee
Andrew Morris began the year as Chairman of the Audit Committee,
but following his appointment as Finance Director, James
Ede-Golightly was appointed interim Chairman of the Committee.
Richard Milne was appointed Chairman of the Committee in November
2016 and the members became and remain James Ede-Golightly and
Michael Kroupeev. A brief description of the background and
experience of the current members of the Committee can be found on
page 24. The varied backgrounds of the Committee's members, and
their collective skills, experience and knowledge of the Company,
allows them to fulfil the Committee's remit and to oversee the
Company's auditor.
The Audit Committee invites Executive Directors and other
relevant staff as it wishes, to attend Audit Committee meetings
although none attend as of right. For the annual results the
independent external auditor is invited to attend the meeting and
discuss the conclusions arising from their audit and their
assessment of the Group's internal controls.
The Audit Committee has the power to engage such external
advisers as it deems necessary to discharge its
responsibilities.
Role of the Audit Committee
The activities of the Audit Committee are governed by terms of
reference which cover its mandate, its composition, the
independence and expertise of the members, frequency of meetings,
and its responsibilities which include oversight of the external
audit function, risk management, internal controls, financial
reporting, and the provision by the auditor of non-audit services.
The terms of reference were last updated in March 2016 and can be
found on the Company's website.
The authority of the Audit Committee derives from the Delegation
of Board Authority which was last reviewed in October 2016. As
further set out in the terms of reference, the primary duties of
the Audit Committee are:
-- to review and consider the integrity of the Company's Financial Statements and regulatory announcements;
-- to keep under review the effectiveness of the Company's internal controls;
-- to assist the Board in ensuring that it receives appropriate
financial and risk reporting to enable it to make its business
decisions;
-- to regularly review the Company's risk management processes
and the risks to which the Company is exposed;
-- to oversee the relationship with the external auditor;
-- to review the Company's whistle-blowing processes; and
-- to report to the Board on how the Audit Committee has discharged its responsibilities.
Activities of the Audit Committee during the year
The work of the Audit Committee in the financial year 2016
principally fell under three main areas and is summarised
below:
Accounting and Internal controls External auditor
financial reporting and risk
* Reviewed the Interim and Annual Financial Statements * Considered reports from the external auditor on its * Considered and approved the audit approach and scope
and the significant financial reporting judgements. assessment of the control environment. of the audit work to be undertaken by the external
auditor and the fees for the same.
* Considered the solvency and liquidity risks and basis * Reviewed periodic management accounts and cash and
for preparing the Company and the Group Interim and going concern forecasts prepared by Management. * Reviewed the auditor's reports on audit findings.
Annual Accounts on a going concern basis and reviewed
the related disclosures in the Annual Report and
Accounts. * Considered and approved the structure, scope of cover * Considered and approved letters of representation
and renewal terms of the Group's Directors and issued to the external auditor.
Officers insurances.
* Reviewed an accounting matters update, including
consideration of relevant accounting standards and * Considered the independence of the auditor and their
underlying assumptions. * Reviewed the Group's risk management process and effectiveness taking into account:
reports generated from it and considered the key
risks facing the Group and strategies for mitigation.
* Reviewed disclosures in the Annual Report and o non-audit work
Accounts in relation to internal controls, risk undertaken by
management, principal risks and uncertainties and the * Reviewed Code of Corporate Governance/QCA practice the external
work of the Audit Committee. and reporting requirements. auditor and compliance
with the policy;
and
* Approved the Group accounting policies. o the Committee's
own assessment.
------------------------------------------------------------ ------------------------------------------------------------ ---------------------------------------------------------------
Significant issues considered by the Audit Committee
Carrying value of the Group's producing operations in Syria
(see note 4.2 to the Consolidated Financial Statements)
Following loss of joint control over DPC in 2011, the Group has
valued its investment in that entity at fair value. Due to the
unknown duration of EU sanctions in force against Syria and
uncertainty over the eventual outcome of events in the country, any
valuation attributed to the investment is highly subjective and
subject to material change and uncertainty. Management reviewed the
internal valuation methodology in 2016, and as per 2015, continues
to believe that as a result of the passage of time and the high
degree of judgement required, it is no longer possible to reliably
estimate the investment's fair value. Management, as it did at 31
December 2015, continues to carry forward the last valuation which
could be reliably determined, being the $102 million previously
disclosed. This carrying value will be reviewed periodically for
impairment and any impairment losses recognised through the Income
Statement. Management has undertaken an impairment review at 31
December 2016 and believe no impairment is necessary. In order to
carry out an impairment review, Management uses an economic model
of the estimated future cash flows that could be generated in
respect of the Group's entitlement reserves in Block 26. The
Committee reviewed the economic model, the assumptions underpinning
the model being most significantly the oil price and the delay
until resumption of production. The Committee concluded that it
remained appropriate to retain a carrying value of $102 million for
the investment whilst EU sanctions are ongoing. The Committee has
also concluded that disclosures within this Report are fair and
appropriate.
The carrying value of intangible oil and gas assets
(see note 2.3 to the Consolidated Financial Statements)
At 31 December 2016, the Group has intangible exploration assets
with a carrying value of $nil on the Balance Sheet (2015: $7.1
million). The Committee reviewed an impairment paper prepared by
Management, which summarised the costs capitalised to cash
generating units as at 31 December 2016, those costs written off
during the year due to licence expiries and Management's impairment
assessment.
The Board concluded that for Colombia Llanos 50 licence,
subsequent to the licence expiry in November, the expenditure to
date attributed to the licence of $1.1 million, plus the $1.5
million of restricted cash should be impaired, however the
potential penalty for non completion of the minimum work obligation
should be not be recognised as a liability, as the Company was
confident of securing an extension, which was subsequently secured
in February 2017, and the Company is now pursuing farm-out
efforts.
The Board concluded that for Colombia Putumayo 14 licence, given
the licence expiry in November 2017, and the terms of the agreement
executed with Samarium in October 2016, the expenditure to date
attributed to the licence of $1.1 million, plus the $1.7 million of
restricted cash should be impaired, however the potential penalty
for non completion of the minimum work obligation should not be
recognised as a liability as a result of ongoing farm-out efforts
and discussion regarding a licence extension with ANH.
The Board concluded that for Tunisia, given the licence expiry
date for the initial exploration phase in July 2017; the
outstanding work commitments on the permit which could not
physically be fulfilled before this date; and the uncertainty
securing an industry partner before licence expiry, along with the
decision of the Company to exit the country if such a partner can
not be found, that the expenditure to date attributed to the
Tunisia licence of $5.3 million should be written-off. The Board
also concluded that the minimum work obligations totalling $3.8
million should be accrued as a potential penalty, whilst
recognising that no parent Company guarantee is in place.
Note 2.3 further sets out background and details of the E&E
assets to the Consolidated Financial Statements. The Committee has
therefore concluded that the carrying value of its intangible oil
and gas assets, which are stated at cost less any amounts
written-off and impairment, is fair and reasonable.
The Committee further notes that the realisation of value from
the assets will depend upon a number of factors including securing
farm-in partners or divesting assets and in some cases extensions
of licences which the Group is currently seeking to negotiate. More
details are included in the Operations Review on pages 8 to 18.
Should the Group be unsuccessful in completing a farm-in or
divestment transaction the realisable value of the assets may be
zero and under certain contracts penalties may be payable for
unfulfilled commitments (see note 2.4).
The going concern basis of reporting
(see note 1.3a to the Consolidated Financial Statements)
The Committee has regularly reviewed financial forecasts for the
Group throughout the year and closely monitored the Group's capital
raising activities, not least the Open Offer and Placing. At 31
December 2016, the Group was holding $1.5 million of cash resources
which consists of $1.0 million cash and cash equivalents and $0.5
million of restricted cash balances. As at the date of this Report
the Group has cash balances immediately available to it of $2.4
million and initiatives to reduce the ongoing costs by the end of
2017 onwards to approximately $0.2 million per month.
The Committee reviewed the level of these resources in the
context of the Group's work and expenditure plans over the
foreseeable future. The Board and Management have actively reviewed
the Group's strategy and adjusted it to one that it is confident
can be financed and can bring stability to the Group.
Notwithstanding the confidence that the Committee has in this
review, it has concluded, as required by FRC guidance, that there
is material uncertainty as to the Group's access to the financial
and commercial resources necessary to fund the activities going
forward. However, based upon feedback from current strategy
discussions and ongoing discussions with existing shareholders and
potential partners, the Committee concluded that the going concern
basis is appropriate in reporting and in the preparation of the
Financial Statements.
Further details are available in the Financial Review on page
19.
2016 Annual Report and Accounts
The Audit Committee reviewed the 2016 Annual Report and Accounts
with Management and the external auditor to enable it to conclude
that the Financial Statements as presented are true and fair and
include all disclosures required by IFRS and applicable
legislation.
Internal audit
The Audit Committee have reviewed whether the Group has a
requirement for an internal audit function and has concluded at
this time that it is not appropriate. Ad hoc internal audit reviews
may be commissioned from third parties from time to time and the
requirement for a dedicated internal audit function will be kept
under consideration.
On behalf of the Audit Committee:
Richard Milne
Chairman of the Audit Committee
26 May 2017
Primary Statements
Independent Auditor's Report to the members of Gulfsands
Petroleum plc
We have audited the financial statements of Gulfsands Petroleum
plc for the year ended 31 December 2016 which comprise the
Consolidated Income Statement, the Consolidated and Company Balance
Sheet, the Consolidated and Company Cash Flow Statement, the
Consolidated and Company Statement of Changes in Equity and the
related notes. The financial reporting framework that has been
applied in their preparation is applicable law and International
Financial Reporting Standards ("IFRSs") as adopted by the European
Union and, as regards the parent company Financial Statements, as
applied in accordance with the provisions of the Companies Act
2006.
This report is made solely to the Company's members, as a body,
in accordance with Chapter 3 of Part 16 of the Companies Act 2006.
Our audit work has been undertaken so that we might state to the
Company's members those matters we are required to state to them in
an auditor's report and for no other purpose. To the fullest extent
permitted by law, we do not accept or assume responsibility to
anyone other than the Company and the Company's members as a body,
for our audit work, for this report, or for the opinions we have
formed.
Respective responsibilities of Directors and Auditor
As explained more fully in the Statement of Directors'
Responsibilities, the Directors are responsible for the preparation
of the Financial Statements and for being satisfied that they give
a true and fair view. Our responsibility is to audit and express an
opinion on the Financial Statements in accordance with applicable
law and International Standards on Auditing (UK and Ireland). Those
standards require us to comply with the Financial Reporting
Council's ("FRC's") Ethical Standards for Auditors.
Scope of the audit of the Financial Statements
A description of the scope of an audit of financial statements
is provided on the FRC's website at
www.frc.org.uk/auditscopeukprivate.
Opinion on Financial Statements
In our opinion:
-- the Financial Statements give a true and fair view of the
state of the Group's and parent company's affairs as at 31 December
2016 and of the Group's loss for the year then ended;
-- the Group Financial Statements have been properly prepared in
accordance with IFRSs as adopted by the European Union;
-- the parent company Financial Statements have been properly
prepared in accordance with IFRSs as adopted by the European Union
and as applied in accordance with the provisions of the Companies
Act 2006; and
-- the Financial Statements have been prepared in accordance
with the requirements of the Companies Act 2006.
Emphasis of matter - carrying value of the Group's producing
operations in Syria
Without modifying our opinion on the Financial Statements for
the year ended 31 December 2016, we draw attention to the
disclosures made in note 4.2 to the Consolidated Financial
Statements concerning the valuation of the Group's suspended
producing operations in Syria, which is recorded at $102 million
following the loss of joint control in December 2011. There is
significant uncertainty as to the duration of the EU sanctions
imposed in December 2011 and the eventual outcome of events in
Syria. The potential impact any outcome will have on the carrying
value from the producing operations in Syria is not known.
Emphasis of matter - going concern
In forming our opinion on the Financial Statements, which is not
modified, we have considered the adequacy of the disclosures made
by the Directors in note 1.3a to the Consolidated Financial
Statements and within the Financial Review of the Strategic Report
concerning the Group and the Company's ability to continue as a
going concern. The Group will require additional funding in order
to meet both capital and administrative obligations and liabilities
as they fall due. The Directors believe, based upon discussions
with existing shareholders, that the Group will be able to secure
the necessary funds within the required timescale, but there are
currently no binding agreements in place.
These conditions, along with the other matters explained in note
1.3a to the Consolidated Financial Statements and within the
Financial Review of the Strategic Report, indicate the existence of
a material uncertainty which may cast significant doubt about the
Company's and the Group's ability to continue as a going concern.
The Financial Statements do not include the adjustments that would
result if the Group was unable to continue as a going concern.
Opinion on other matter prescribed by the Companies Act 2006
In our opinion based on the work undertaken in the course of the
audit:
-- the information given in the strategic report and directors'
report for the financial year for which the financial statements
are prepared is consistent with the financial statements; and
-- the strategic report and directors' report have been prepared
in accordance with applicable legal requirements.
Matters on which we are required to report by exception
In the light of the knowledge and understanding of the company
and its environment obtained in the course of the audit, we have
not identified material misstatements in the strategic report or
the directors' report.
We have nothing to report in respect of the following matters
where the Companies Act 2006 requires us to report to you if, in
our opinion:
-- adequate accounting records have not been kept by the parent
company, or returns adequate for our audit have not been received
from branches not visited by us; or
-- the parent company Financial Statements are not in agreement
with the accounting records and returns; or
-- certain disclosures of Directors' remuneration specified by law are not made; or
-- we have not received all the information and explanations we require for our audit.
Scott Knight (senior statutory auditor)
For and on behalf of BDO LLP, statutory auditor
London
United Kingdom
Date 26 May 2017
BDO LLP is a limited liability partnership registered in England
and Wales (with registered number OC305127).
Financial Statements
Consolidated Income Statement for the year ended 31 December
2016
2016 2015
Notes $'000 $'000
----------------------------------------- ------- ---------- ----------
Continuing operations
General administrative expenses (4,182) (6,965)
Share-based payments 5.3 (161) -
Exploration costs written-off/impaired 2.3 (8,055) (53,799)
Decommissioning - change
in estimate 2.6 (1,139) -
Penalty provisions - change
in estimates 2.6 (2,800) -
Restricted cash balances
provided against 3.3 (3,191) (5,750)
Inventory impairment 3.5 - (1,117)
Operating loss 5.2 (19,528) (67,631)
Foreign exchange losses (37) (43)
Loan facility finance cost 3.6 (51) (1,351)
Other finance expenses (162) (188)
Other finance income 5.7 23 13
----------------------------------------- ------- ---------- ----------
Loss before taxation (19,755) (69,200)
----------------------------------------- ------- ---------- ----------
Taxation 5.8 - -
----------------------------------------- ------- ---------- ----------
Loss for the year (19,755) (69,200)
----------------------------------------- ------- ---------- ----------
Loss per share attributable
to the owners of the parent
company (cents)
Basic and diluted 5.9 (4.17) (58.70)
----------------------------------------- ------- ---------- ----------
There are no items of comprehensive income outside of the
Consolidated Income Statement.
Financial Statements
Consolidated Balance Sheet as at 31 December 2016
2016 2015
Notes $'000 $'000
------------------------------------------------------ ------- ---------- ----------
Assets
Non-current assets
Property, plant and equipment 2.1 28 159
Intangible assets 2.3 - 7,168
Long-term financial assets 3.3 500 3,691
Investments 4.2 102,000 102,000
------------------------------------------------------ ------- ---------- ----------
102,528 113,018
------------------------------------------------------ ------- ---------- ----------
Current assets
Inventory 3.5 1,092 1,096
Trade and other receivables 3.1 171 790
Cash and cash equivalents 3.2 1,036 420
------------------------------------------------------ ------- ---------- ----------
2,299 2,306
------------------------------------------------------ ------- ---------- ----------
Total assets 104,827 115,323
------------------------------------------------------ ------- ---------- ----------
Liabilities
Current liabilities
Trade and other payables 3.4 1,531 3,969
Loan facility 3.6 - 14,406
Provisions 2.6 6,137 2,198
------------------------------------------------------ ------- ---------- ----------
7,668 20,573
------------------------------------------------------ ------- ---------- ----------
Non-current liabilities
Trade and other payables 3.4 3,446 3,427
Provisions 2.6 - -
3,446 3,427
------------------------------------------------------ ------- ---------- ----------
Total liabilities 11,114 24,000
------------------------------------------------------ ------- ---------- ----------
Net assets 93,713 91,324
------------------------------------------------------ ------- ---------- ----------
Equity
Capital and reserves attributable to equity holders
Share capital 6.1 18,803 13,131
Share premium 110,737 105,926
Merger reserve 11,709 11,709
Treasury shares - (11,502)
Retained loss (47,536) (27,940)
------------------------------------------------------ ------- ---------- ----------
Total equity 93,713 91,324
------------------------------------------------------ ------- ---------- ----------
These Consolidated Financial Statements were approved by the
Board of Directors on 26 May 2017 and signed on its behalf by:
Andrew James Morris
Finance Director
26 May 2017
Financial Statements
Consolidated Statement of Changes in Equity for the year ended
31 December 2016
Share Share Merger Treasury Retained Total
capital premium reserve shares (loss)/profit equity
$'000 $'000 $'000 $'000 $'000 $'000
------------------ --------- --------- --------- ----------- --------------- ----------
At 1 January
2015 13,131 105,926 11,709 (11,502) 41,291 160,555
Loss for 2015
Transactions
with owners - - - - (69,200) (69,200)
Options settled
or exercised - - - - (31) (31)
At 31 December
2015 13,131 105,926 11,709 (11,502) (27,940) 91,324
------------------ --------- --------- --------- ----------- --------------- ----------
Loss for 2016 - - - - (19,755) (19,755)
Transactions
with owners
Shares issued 5,672 4,811 - 11,502 - 21,985
Share-based
payment charge - - - - 159 159
At 31 December
2016 18,803 110,737 11,709 - (47,536) 93,713
------------------ --------- --------- --------- ----------- --------------- ----------
The merger reserve arose on the acquisition of Gulfsands
Petroleum Ltd and its subsidiaries by the Company by way of a
share-for-share exchange in April 2005, in conjunction with the
flotation of the Company on the Alternative Investment Market of
the London Stock Exchange.
Financial Statements
Consolidated Cash Flow Statement for the year ended 31 December
2016
2016 2015
Notes $'000 $'000
------------------------------------------------------------------------ ----------- ---------- -----------
Cash flows from operating activities
Operating loss from continuing operations (19,528) (67,631)
Depreciation and amortisation 2.1 & 2.3 89 507
Loss on disposal of tangible fixed assets 2.1 62 10
Exploration costs written off/impaired/costs accrued 2.3 8,055 53,799
Decommissioning estimates adjustment 2.6 1,139 -
Restricted cash balances forfeited/provided against 3.3 3,191 5,750
Inventory impairment 3.5 - 1,117
Share-based payment charge 5.3 159 -
Decrease in receivables 391 516
Increase in payables 1,587 522
Foreign exchange losses (37) (43)
Finance expenses paid (162) (101)
Interest received 23 13
Net cash used in operating activities by continuing operations (5,031) (5,541)
------------------------------------------------------------------------ ----------- ---------- -----------
Net cash generated by operating activities of discontinued operations - -
------------------------------------------------------------------------ ----------- ---------- -----------
Total net cash used in operating activities (5,031) (5,541)
------------------------------------------------------------------------ ----------- ---------- -----------
Investing activities
Exploration and evaluation expenditure (1,879) (10,085)
Other capital expenditures (2) (30)
Net cash used in investing activities by continuing operations (1,881) (10,115)
------------------------------------------------------------------------ ----------- ---------- -----------
Net cash used in investing activities by discontinued operations - -
------------------------------------------------------------------------ ----------- ---------- -----------
Total net cash used in investing activities (1,881) (10,115)
------------------------------------------------------------------------ ----------- ---------- -----------
Financing activities
Loan (repayment)/draw-down (14,457) 8,200
Funds received under Open Offer/share Placing 20,427 -
Share placing 1,949 -
Open Offer finance costs (391) -
Other payments in connection with options settled or exercised - (31)
------------------------------------------------------------------------ ----------- ---------- -----------
Net cash provided by financing activities of continuing operations 7,528 8,169
------------------------------------------------------------------------ ----------- ---------- -----------
Net cash used in financing activities of discontinued operations - -
------------------------------------------------------------------------ ----------- ---------- -----------
Total net cash provided by financing activities 7,528 8,169
------------------------------------------------------------------------ ----------- ---------- -----------
Cash disposed as part of disposal of discontinued operations - -
Increase/(decrease) in cash and cash equivalents 616 (7,487)
Cash and cash equivalents at beginning of year 420 7,907
------------------------------------------------------------------------ ----------- ---------- -----------
Cash and cash equivalents at end of year 3.2 1,036 420
------------------------------------------------------------------------ ----------- ---------- -----------
Notes to the Consolidated Financial Statements for the year
ended 31 December 2016
Section 1 - Basis of Preparation
1.1 Authorisation of Financial Statements and statement of
compliance with IFRS
Gulfsands Petroleum plc is a public limited company quoted on
AIM and incorporated in the United Kingdom. The principal
activities of the Company and its subsidiaries (the "Group") are
that of oil and gas production, exploration and development.
The Consolidated Financial Statements for the year ended 31
December 2016 were authorised for issue by the Board of Directors
on 26 May 2017 and the Balance Sheets were signed on the Board's
behalf by Andrew Morris, Finance Director.
The Consolidated Financial Statements have been prepared in
accordance with International Financial Reporting Standards
("IFRS") as adopted by the EU. The principal accounting policies
adopted are set out in note 1.3.
1.2 Adoption of International Financial Reporting Standards
The Consolidated Financial Statements for the year ended 31
December 2016 and for the comparative year ended 31 December 2015
have been prepared in accordance with International Financial
Reporting Standards as adopted by the EU and IFRIC (IFRS
Interpretations Committee) interpretations and with those parts of
the Companies Act 2006 applicable to companies reporting under
IFRS.
1.3 Significant accounting policies
a) Basis of preparation and accounting standards
The Consolidated Financial Statements have been prepared in
accordance with applicable International Financial Reporting
Standards as adopted by the EU and, except for share-based payments
and the valuation of available-for-sale investments, under the
historical cost convention.
Going concern
On 15 February 2017, the Company entered into a Secured Term
Financing Facility (the "2017 Facility") of up to GBP4 million (the
"Facility") with its Major Shareholders (the "Lenders"). The 2017
Facility is available for drawdown by the Company in five equal
tranches of GBP0.8 million each, the first three of which have been
drawn and the final two of which remain available on or after 30
September 2017 and 31 December 2017 respectively, subject to
re-approval by each of the Lenders prior to each drawdown request.
Further details of the 2017 Facility are outlined in note 6.7.
As at the date of this Report, the Group has cash balances
immediately available to it totalling approximately $2.4
million.
Ongoing General and Administrative costs are expected to further
decrease by the end of the second half of 2017 to a level of
approximately $0.2 million per month.
In the absence of any other sources of cash flow, the Group will
need to raise additional capital by the end of Q3 2017 to fund
ongoing operations. There remains up to GBP1.6 million (c. $2.0
million) available under the 2017 Facility, and should that be
approved for drawdown by the Lenders, the Group's cash forecast
indicates that the Group would have sufficient funds until Q2
2018.
The Company remains reliant on the support of its three Major
Shareholders, without whose support, the Company would be seriously
financially challenged. Based upon its experience and ongoing
discussions with those shareholders, the Board believes that the
Group will be able to access the appropriate resources, either
through the remaining 2017 Facility draw-downs and/or through
equity, to finance the revised strategy, however there are no
binding agreements or commitments in place.
If the Company and Group does not complete the minimum work
commitments under its various oil and gas licences within agreed
time periods, either directly, or via strategic divestments or
transactions with third party entities, penalties equal to the
unfulfilled contracted work commitments may be payable. These could
be substantial and additional details of the capital commitments
for the Company's licences are fully described in note 2.4.
Potential liabilities to licences in Morocco and Tunisia are
housed in dedicated subsidiaries without any parent company
guarantees in place. In analysing the Group's financial needs the
Board has considered the timing and likelihood of the payment of
all current and potential liabilities.
Following completion of a review of the going concern position
of the Company and Group at the meeting of the Board of Directors
on 26 May 2017, including the uncertainties described above, the
Board has concluded that, with current consolidated cash and cash
equivalents totalling $2.4 million and taking into account both the
Board's current strategy and the new financial resources that the
Board might reasonably expect to become available, the Company and
the Group will have sufficient resources to continue in operational
existence for the foreseeable future, a period not less than twelve
months from the date of approval of this Financial Report.
Accordingly, the Directors consider it appropriate to continue to
adopt the going concern basis in preparing these Financial
Statements.
Notwithstanding the confidence that the Board has in its ability
to finance the Group's re-shaped business, the Directors, in
accordance with Financial Reporting Council guidance in this area,
conclude that at this time there is material uncertainty that such
finance can be procured and failure to do so might cast significant
doubt upon the Company's and the Group's ability to continue as a
going concern and that the Company and the Group may therefore be
unable to realise their assets and discharge their liabilities in
the normal course of business. These Financial Statements do not
include the adjustments that would result if the Group was unable
to continue as a going concern.
These Financial Statements consolidate the accounts of Gulfsands
Petroleum plc and all its subsidiary undertakings drawn to 31
December each year.
b) New and amended IFRS
The following relevant new standards, amendments to standards
and interpretations are mandatory for the first time for the
financial year beginning 1 January 2016, but had no significant
impact on the Group or Company:
Standard Effective
date as
adopted
by the
EU
Amendments to IFRS 11 'Accounting 1 January
for Acquisitions of Interests in 2016
Joint Operations'
Amendments to IAS 16 and IAS 38 1 January
'Clarification of Acceptable Methods 2016
of Depreciations and Amortisation'
Amendments to IAS 16 and IAS 41 1 January
'Update on Agriculture: Bearer Plants' 2016
Amendments to IAS 27 'Separate Financial 1 January
Statements Permitting Investments 2016
in Subsidiaries, Joint Ventures
and Associates to be Optionally
Accounted for Using Equity Method'
Amendment to IAS 1 'Disclosure Amendments' 1 February
2016
c) Standards issued but not yet Effective
effective date as
The following relevant new standards, adopted
amendments to standards and interpretations by the
have been issued, but are not effective EU
for the financial year beginning
on 1 January 2016, as adopted by
the EU, and have not been early
adopted:
Standard
IFRS 15 'Revenue from Contracts 1 January
with Customers' 2018
IFRS 9 'Financial Instruments' 1 January
2018
IFRS16 'Leases' 1 January
2019
The Directors are currently assessing these standards but based
on current operations do not anticipate that the adoption of these
standards and interpretations will have a material effect on the
reported income or net assets of the Group or Company.
d) Basis of consolidation
Intra-group sales, profits and balances are eliminated fully on
consolidation.
The results of subsidiaries acquired or sold are consolidated
for the periods from, or to, the date when control passed.
Acquisitions are accounted for under the acquisition method. The
consideration transferred in a business combination is measured at
fair value, which is calculated as the sum of the acquisition date
fair values of assets transferred by the Group, liabilities
incurred by the Group to the former owners of the acquiree and the
equity interest issued by the Group in exchange for the control of
the acquiree. Acquisition related costs are recognised in the
Income Statement as incurred. At the acquisition date the
identifiable assets acquired and the liabilities assumed are
recognised at their fair value.
The Consolidated Financial Statements include the accounts of
subsidiary undertakings when the Company has the control over the
undertaking. The Company controls an investee if all three of the
following elements are present: power over the investee; exposure
to variable returns from the investee; and the ability of the
investor to use its power to affect those variable returns. Control
is reassessed whenever facts and circumstances indicate that there
may be a change in any of these elements of control.
The Group is engaged in oil and gas exploration, development and
production through joint operations. A joint operation is whereby
the parties that have joint control of the arrangement have rights
to the assets and obligations for the liabilities, relating to the
arrangement. As a joint operator the Group recognises its assets,
including its share of any assets incurred jointly; its
liabilities, including its share of any liabilities incurred
jointly; its revenues, including its share of revenue from the sale
of the output by the joint operation; and its expenses, including
its share of any expenses jointly incurred.
When the Group loses control or joint control of a subsidiary or
joint operation, the profit or loss on disposal is calculated as
the difference between (i) the aggregate of the fair value of the
consideration received and the fair value of any retained interest
and (ii) the previous carrying amount of the assets (including
goodwill), less liabilities of the subsidiary or joint operation
and any non-controlling interests. Amounts previously recognised in
other comprehensive income in relation to the subsidiary or joint
operation are accounted for in the same manner as would be required
if the relevant assets or liabilities are disposed of. The fair
value of any investment retained in the former subsidiary or joint
operation at the date when control is lost is regarded as the fair
value on initial recognition for subsequent accounting under IAS 39
'Financial Instruments: Recognition and Measurement' or, when
applicable, the costs on initial recognition of an investment in an
associate or jointly controlled entity.
e) Foreign and reporting currency
These Consolidated Financial Statements are presented in US
Dollars. The majority of all costs associated with foreign
operations are denominated in US Dollars and not the local currency
of the operations. Therefore the presentational and functional
currency of the Company, and the functional currency of all
subsidiaries, is the US Dollar. Gains and losses from foreign
currency transactions, if any, are recognised in the Income
Statement for the year. The effective exchange rate to the Pound
Sterling at 31 December 2016 was GBP1: $1.26 (2015: GBP1:
$1.47).
Foreign currency transactions of individual companies within the
Group are translated to the functional and reporting currency of US
Dollars at the rates prevailing when the transactions occurred.
Monetary assets and liabilities denominated in foreign currencies
are translated at the rate of exchange at the Balance Sheet date.
All differences are taken to the Income Statement.
1.4 Critical accounting judgements and key sources of estimation
uncertainty
In the application of the Group's accounting policies, the
Directors are required to make judgements, estimates and
assumptions about the carrying amounts of assets and liabilities
that are not readily apparent from other sources. The estimates and
associated assumptions are based on historical experience and other
factors that are
considered to be relevant. Actual results may differ from these estimates.
The estimates and underlying assumptions are reviewed on an
ongoing basis. Revisions to accounting estimates are recognised in
the period in which the estimate is revised if the revision affects
only that period, or in the period of revision and future periods
if the revision affects both current and future periods.
The following sets out the critical judgements that the
Directors have made in the process of applying the Group's
accounting policies and the key assumptions concerning the future
and other key sources of estimation uncertainty at the Balance
Sheet date that have a significant risk of causing a material
adjustment to the carrying values of assets and liabilities within
the next financial year:
-- going concern - for further details see note 1.3a;
-- recoverability of intangible oil and gas exploration and
evaluations assets - for further details see note 2.3;
-- recoverability of restricted cash balances - for further details see notes 2.4 and 3.3.
-- work obligation commitments - for further details see note 2.4;
-- decommissioning provisions - for further details see note 2.6; and
-- carrying value of the Group's investment in DPC - for further details see note 4.2.
Section 2 - Oil and Gas Assets
2.1 Property, plant and equipment
The Group applies the requirements of IFRS 6 'Exploration for
and Evaluation of Mineral Resources' and where additional guidance
is needed IAS 16 'Property, Plant and Equipment' and IAS 36
'Impairment of Assets' noting that several items in the latter two
standards are exempted for assets at the exploration and evaluation
stage due to the application of IFRS 6. Set out below is our
interpretation of the principles set out in IFRS 6 and other
IFRS.
Recognition and measurement
Development and production assets are accumulated on a cash
generating unit basis and represent the cost of developing the
Proved plus Probable Reserves discovered and bringing them into
production, together with the exploration and evaluation
("E&E") asset expenditures incurred in finding Proved plus
Probable Reserves, transferred from intangible E&E assets.
The cost of development and production assets also includes the
cost of acquisitions and purchases of such assets, directly
attributable overheads, and the cost of recognising provisions for
future restoration and decommissioning. See note 2.6 for further
details.
Depletion of producing assets
Expenditure within each cash generating unit is depleted by a
unit of production method using the ratio of oil and gas production
in the year compared to the estimated quantity of Proved and
Probable Reserves at the beginning of the year. Costs used in the
unit of production calculation comprise the net book value of
capitalised costs plus the estimated future field development costs
for Proved and Probable Reserves. Changes in estimates of
commercial reserves or future development costs are dealt with
prospectively.
Impairment
An impairment test is performed whenever events and
circumstances arising during the development or production phase
indicate that the carrying value of a development or production
asset may exceed its recoverable amount. The aggregate carrying
value is compared against the recoverable amount of the cash
generating unit, generally by reference to the present value of the
future net cash flows expected to be derived from production of
commercial reserves.
Oil and gas Other fixed
properties assets Total
$'000 $'000 $'000
------------------------------------------ -------------- ------------- ---------
Cost:
At 1 January 2015 - 2,835 2,835
Additions - 31 31
Changes to decommissioning estimates - - -
Disposals - (69) (69)
------------------------------------------ -------------- ------------- ---------
At 31 December 2015 - 2,797 2,797
------------------------------------------ -------------- ------------- ---------
Additions - 1 1
Disposals - (1,259) (1,259)
------------------------------------------ -------------- ------------- ---------
At 31 December 2016 - 1,539 1,539
------------------------------------------ -------------- ------------- ---------
Accumulated depreciation and depletion:
At 1 January 2015 - (2,550) (2,550)
Charge for 2015 - (147) (147)
Disposals - 59 59
------------------------------------------ -------------- ------------- ---------
At 31 December 2015 - (2,638) (2,638)
------------------------------------------ -------------- ------------- ---------
Charge for 2016 - (71) (71)
Disposals - 1,198 1,198
------------------------------------------ -------------- ------------- ---------
At 31 December 2016 - (1,511) (1,511)
------------------------------------------ -------------- ------------- ---------
Net book value at 31 December 2015 - 159 159
Net book value at 31 December 2016 - 28 28
------------------------------------------ -------------- ------------- ---------
During 2016, in parallel to head office relocation, computer
software costs and office fixtures and fittings were disposed
of.
2.2 Property, plant and equipment other than oil and gas
assets
Property, plant and equipment other than oil and gas assets are
stated at cost less accumulated depreciation and any provision for
impairment. Depreciation is charged so as to write-off the cost,
less estimated residual value, of assets on a straight-line basis
over their useful lives of between two and five years. Freehold
land is not depreciated. See note 2.1 for movements in property,
plant and equipment other than oil and gas assets in the year.
2.3 Intangible assets
Key accounting judgements, estimates and assumptions:
Recoverability of intangible oil and gas exploration and
evaluation assets
If there are indicators of impairment, the carrying values of
E&E assets are assessed for impairment which involves judgement
as to the (i) likely commerciality of the assets, (ii) future
revenues and costs pertaining and (iii) the discount rate to be
applied for the purpose of deriving a recoverable value. Additional
judgements apply to the Group's E&E assets affected by
sanctions in Syria. See note 4.2 for further details.
The Group applies the requirements of IFRS 6 'Exploration for
and Evaluation of Mineral Resources', set out below is our
interpretation of the principles set out in IFRS 6.
Recognition and measurement
The Group follows the successful efforts method of accounting
whereby costs for unsuccessful exploration activities are expensed.
All licence acquisition, exploration and evaluation costs are
initially capitalised as intangible fixed assets in cost centres by
licence or contract, as appropriate, pending determination of
commerciality of the relevant property. Directly attributable
administration costs are capitalised insofar as they relate to
specific exploration activities. Pre-licence costs and general
exploration costs not directly attributable to any particular
licence or prospect are expensed as incurred.
E&E assets relating to each exploration licence/prospect are
not amortised but 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 cash generating unit basis as set out
below and any impairment loss is recognised in the Income
Statement. The carrying value of the E&E assets, after any
impairment loss, is then reclassified as development and production
assets in property, plant and equipment. Costs of unsuccessful
exploration efforts are expensed at the time that a determination
is made that the exploration has failed to locate commercially
recoverable hydrocarbons.
Impairment
As the Group does not hold any intangibles with an indefinite
useful life, non-current assets are assessed for impairment on a
cash generating unit basis when facts and circumstances suggest
that the carrying amount may exceed its recoverable amount. Such
triggering events in respect of E&E assets include: the point
at which final determination is made as to whether commercial
reserves exist; actual or imminent expiry of exploration
licence/contract without expectation of renewal; and/or no further
plans to explore the licence/contract area.
Where there has been an indication of a possible impairment,
Management assesses the recoverability of the carrying value of the
cash generating unit by comparison with the estimated discounted
future net cash flows based on Management's expectation of the
future production, hydrocarbon prices and costs. Any identified
impairment is charged to the Income Statement.
Where conditions giving rise to impairment subsequently reverse,
the effect of the impairment charge is also reversed as a credit to
the Income Statement, net of any amortisation that would have been
charged since the impairment.
Exploration and evaluation assets
Computer
Syria Morocco Tunisia Colombia software Total
$'000 $'000 $'000 $'000 $'000 $'000
---------------------------------------- ---------- ---------- ---------- ---------- -----------
Cost:
At 1 January
2015 10,505 46,555 5,195 1,225 2,370 65,850
Additions - 7,773 75 654 2 8,504
Change in decommissioning
estimates - (529) - - - (529)
Exploration
expenditure
written off - (51,007) - - - (51,007)
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
At 31 December
2015 10,505 2,792 5,270 1,879 2,372 22,818
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
Additions - 528 44 334 - 906
Exploration
expenditure
written off - - (5,314) - - (5,314)
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
At 31 December
2016 10,505 3,320 - 2,213 2,372 18,410
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
Accumulated
amortisation:
At 1 January
2015 - - - - (1,518) (1,524)
Charge for 2015 - - - - (360) (360)
At 31 December
2015 - - - - (1,878) (1,878)
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
Charge for 2016 - - - - (19) (19)
At 31 December
2016 - - - - (1,897) (1,897)
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
Accumulated
impairment:
At 1 January
2015 (10,505) (2,792) - (475) (13,772)
Additions - - - - - (213)
At 31 December
2015 (10,505) (2,792) - - (475) (13,772)
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
Exploration
expenditure
impaired - (528) (2,213) - (2,741)
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
At 31 December
2016 (10,505) (3,320) - (2,213) (475) (16,513)
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
Net book value
at 31 December
2015 - - 5,270 1,879 19 7,168
Net book value
at 31 December
2016 - - - - - -
----------------------------- ---------- ---------- ---------- ---------- ---------- -----------
Syria
The accumulated costs of E&E assets in Syria represent the
Group's share of the drilling costs of the Al Khairat, Twaiba and
Wardieh wells and certain 3D seismic surveys. The Al Khairat well
was successfully tested but commercial development approval is yet
to be granted by the government of the Syrian Arab Republic. The
Twaiba and Wardieh wells are still under evaluation.
Following the imposition of EU sanctions against the oil
industry in Syria, an impairment test was conducted and the
carrying value of all E&E assets in Syria was impaired to nil
as it is was unclear whether the Group would be able to apply for
commercial development approval in the manner contemplated by the
Production Sharing Contract. That position remains at the date of
this Report.
Morocco
Moroccan E&E assets at 31 December 2016 represent
exploration expenditure on the Moulay Bouchta licence. The licence
expiry date for the initial exploration phase was initially June
2016 although his has since been extended to June 2017. Due to the
original expiry date the Company wrote off the expenditure
attributed to Moulay Bouchta at 2015 year-end and has maintained
this policy since then. The expenditure to date attributed to the
Moulay Bouchta licence has been impaired, including $0.5 million in
2016 (2015: $2.8 million, inclusive of $1.75 million potential
penalty for non-completion of the minimum work obligations). As
part of the extension granted during the year, and confirmed post
year-end, the minimum work obligations relating to the Moulay
Bouchta contract was reduced from $3.5 million to $2.5 million and
so the possible penalty accrued has also been reduced from $1.75
million to $0.75 million.
On 24 September 2015 the Fes Petroleum Agreement expired. All
E&E expenditure related to the Fes permit was written off in
2015, with write-offs totalling $22.2 million, inclusive of $12.0
million fair value recognised on acquisition.
On 9 November 2015, the extension period of the Rharb Petroleum
Agreement expired and the Company's request to further extend the
Rharb Petroleum Agreement for a period of two years to allow the
Company to appraise the gas discoveries made in 2014/15 was
rejected. All E&E expenditure related to the Rharb Centre and
Rharb Sud permits was written-off in 2015, with write-offs
totalling $28.8 million, inclusive of $5.8 million fair value
recognised on acquisition.
During 2016, the estimated decommissioning obligation for the
Rharb and Fes Petroleum Agreements was increased by $1.2 million,
from $0.4 million to $1.6 million, as described in note 2.6. This
was not booked through E&E assets but directly through the
Income Statement. While this provision has been established as a
liability under IFRS, the Company considers that this
decommissioning obligation should be fully satisfied by part of the
performance guarantees inappropriately taken by ONHYM on the Rharb
and Fes licences, as described in note 6.6.
Tunisia
At 31 December 2016 the Tunisian E&E assets represent
expenditures under the Chorbane contract including amounts paid
during 2013 and 2015 to increase participation in the contract. A
two year extension to the PSC was granted on 22 December 2015,
extending the contract date to 12 July 2017 but the Group has been
unable to agree an appropriate work program with Entreprise
Tunisienne d'Activités Pétrolières ("ETAP") since then, and with
the expiry date of the contract approaching, in accordance with the
Group's policy it has been decided to fully write-off the
expenditure attributed to Chorbane Contract as at 2016 year-end.
The total write-off was $5.3 million. As at 31 December 2016 $3.8
million (31 December 2015: $nil) has been accrued as potential
penalties of the minimum work programme.
While management continued to seek a partner to whom it can
farm-down or divest the Group's interests in the PSC during the
year, in November 2016, the Group's subsidiary, Gulfsands Petroleum
Tunisia Limited informed the Tunisian authorities that, if it could
not find a partner for its projects, it intended to cease all
Tunisian operations at the year-end. Post year-end the Group has
initiated the close down of its Tunisian activities.
Colombia
The Group has interests in E&P contracts over two blocks in
Colombia: Llanos 50 ("LLA-50") and Putumayo 14 ("PUT-14").
The Llanos-50 licence expired in November 2016 and given that
there was uncertainty over whether the licence could be
successfully extended, the expenditure to date attributed to the
Llanos-50 contract of $1.1 million has been fully impaired.
Alongside this, the recovery of restricted cash balance of $1.5
million held as performance guarantees in relation to the minimum
work obligation under this contract has also been fully provided
against. Subsequent to the year-end the contract was successfully
extended by 18 months to May 2018, however despite this extension,
and the commencement of work on reprocessing legacy seismic and
initial environment studies in advance of further seismic
acquisition, there remains uncertainty as to whether the Group will
attract a partner to execute the work programme and so it is
considered appropriate to retain the provisions in these
accounts.
The Putumayo-14 licence expires in November 2017. In October
2016, the Company entered into a farm-out agreement with Samarium
Energy & Resources Corporation ("Samarium") for the Putumayo-14
contract although this subsequently terminated post year-end. The
Company continues an active and constructive dialogue with the
Agencia Nacional de Hidrocarburos ("ANH") regarding an extension to
the Putumayo-14 licence and has commenced work on the initial
phase, the Consulta Previa. However, given the time left on the
licence, and notwithstanding the Samarium farm-out, in accordance
with Group policy it has been decided to fully impair the
expenditure attributed to the Putumayo-14 licence, of $1.1 million
as at 2016 year-end, as well as the $1.7 million of Restricted Cash
supporting the Putumayo-14 Letter of Credit.
No provision has been recognised as at 31 December 2016 for the
minimum work obligation commitments for the Putuamyo-14 licence, as
management was in active and positive discussion regarding a
licence extension with ANH.
2.4 Work obligation commitments
At 31 December 2016 the Group had the following capital
commitments in respect of its exploration activities:
Morocco
Moulay Bouchta permit - initial exploration phase expiry date
and deadline for fulfilment of capital commitments; June 2017
-- Acquisition and processing of 500 km of 2D seismic.
-- Reprocessing and interpretation of selected legacy 2D seismic
lines and the existing 3D seismic data.
-- Legacy oil field reactivation survey.
-- Total cost of commitments estimated at $2.5 million.
As at 31 December 2016 $1.75 million (31 December 2015: $1.75
million) of deposits have been lodged to support guarantees given
to ONHYM in respect of completion of these minimum work
commitments. These have been fully provided against at 31 December
2016, given the licence expiry date for the initial exploration
phase in June 2017. The Company remains in discussion with OMHYM
regarding a further extension and possible farm-out efforts
continue, but the Company only intends to only take advantage of
any extension ifthe Farmout efforts are successful. If the licence
is relinquished, in addition to the potential forfeiture of
restricted cash balances, a further $0.75 million potential penalty
for non-completion of the minimum work obligations could be
enforced on the Group. This has been provided for within these
accounts (2015: $1.75 million).
Tunisia
Chorbane permit - second phase of contract expiry date and
deadline for fulfilment of capital commitments; July 2017
-- Drilling of one exploration well.
-- Acquisition of 200 km of 2D seismic data, although this was disputed by ETAP.
-- Total contractual commitment: $3.8 million for the drilling of the exploration well.
There are no guarantees against the obligations relating to the
Chorbane Licence. Given the impending expiry of the licence in July
2017 and the decision by the Board to exit Tunisia a provision has
been recognised of $3.8 million to reflect the potential penalty
for non-fulfilment of the contractual work programme.
Colombia
Putumayo 14 - licence expiry date and deadline for fulfilment of
capital commitments; November 2017
-- Drilling of one exploration well.
-- 2D seismic minimum 93 km.
-- The Company has also undertaken to spend $100,000 on an
additional work programme obligation which may be satisfied via the
acquisition of an additional 5 km of 2D seismic.
-- Total commitments outstanding estimated at $16.1 million.
$1.7 million (31 December 2015: $1.7 million) of deposits have
been lodged to support guarantees given to the Agencia Nacional de
Hidrocarburos in respect of completion of the minimum work
commitments on Putumayo 14. These have been fully provided against
as at 31 December 2016 given the licence expiry date for the
initial exploration phase in November 2017, and uncertainty about
being granted an extension.
Llanos 50 - first exploration phase expiry date and deadline for
fulfilment of capital commitments; May 2018 following 18 month
extension confirmed in May 2017
-- Drilling of one exploration well.
-- 2D seismic minimum 103 km.
-- The Company has also undertaken to spend $100,000 on an
additional work programme obligation which may be satisfied via the
acquisition of an additional 5 km of 2D seismic.
-- Total commitments outstanding estimated at $13.9 million,
plus an additional $1.4 million for the extension i.e. $15.2
million.
$1.5 million (31 December 2015: $1.5 million) of deposits have
been lodged to support guarantees given to the Agencia Nacional de
Hidrocarburos in respect of completion of the minimum work
commitments on Llanos 50. These have been fully provided against as
at 31 December 2016 as, given the licence expiry date for the
initial exploration phase in November 2016 and uncertainty about
being granted an extension.
The deposits referenced in this note are shown as restricted
cash amounts in note 3.3.
There were no other material obligations or contracts
outstanding in relation to ongoing projects not provided or
disclosed in these Consolidated Financial Statements.
2.5 Intangible assets other than oil and gas assets - computer
software
Intangible assets other than oil and gas assets are stated at
cost less accumulated amortisation and any provision for
impairment. Amortisation is charged so as to write-off the cost,
less estimated residual value, of assets on a straight-line basis
over their useful lives of between two and five years. Amortisation
is included with depreciation and classified as cost of sales or
administrative expenses as appropriate. No intangible assets have
indefinite lives. See note 2.3 for movements in intangible assets -
computer software in the year.
2.6 Provisions
Decommissioning Note 2.6 (i) Licence penalties Note 2.6 (ii)
Total
$'000 $'000 $'000
--------------------------------------- ------------------------------ --------------------------------- -------
At 1 January 2016 448 1,750 2,198
Changes to decommissioning estimates 1,139 - 1,139
Change to licence penalties - 2,800 2,800
--------------------------------------- ------------------------------ --------------------------------- -------
At 31 December 2016 1,587 4,550 6,137
--------------------------------------- ------------------------------ --------------------------------- -------
Key accounting judgements, estimates and assumptions:
(i) Decommissioning: At 31 December 2016 the Group has
decommissioning and/or restoration obligations in respect of a
number of wells and well sites in Morocco under the Moroccan
Hydrocarbon Code. The wells and well sites are located on the
expired Rharb and Fes permits and on the three exploitation
concessions located within these permits. These include the three
discoveries on the Rharb Centre permit: LTU-1, DRC-1 and DOB-1,
which have all been suspended. Included within the decommissioning
and/or restoration obligations are obligations on all legacy wells
drilled prior to the Group's acquisition of those interests.
The Rharb and Fes petroleum contracts expired during 2015, and
consequently as at 31 December 2016 (and as at 31 December 2015)
all of the decommissioning provisions are disclosed as current
liabilities and no discount rate has been applied to the estimated
cost of decommissioning works.
Where a material liability for the removal of production
facilities and site restoration at the end of the productive life
of a field exists, a provision for decommissioning is recognised.
The amount recognised is the present value of estimated future
expenditure determined in accordance with local conditions and
requirements. A fixed asset of an amount equivalent to the
provision is also created (included in exploration or evaluation
assets or development and production assets) and depleted on a unit
of production basis. Changes in estimates are recognised
prospectively, with corresponding adjustments to the provision and
the associated fixed asset. Where the asset to which the
decommissioning provision relates has already been fully impaired
or written-off, the decommissioning asset is directly written off
to the Income Statement.
The movement in the provision for decommissioning was as
follows:
$'000
----------------------- -------
At 1 January 2015 977
Changes in estimates (529)
At 31 December 2015 448
----------------------- -------
Current portion 448
Non-current portion -
----------------------- -------
At 1 January 2016 448
Changes in estimates 1,139
At 31 December 2016 1,587
----------------------- -------
Current portion 1,587
Non-current portion -
----------------------- -------
The decommissioning provision of $1.6 million at 31 December
2016 (2015: $0.4 million) relates to decommissioning obligations in
respect of the Moroccan Rharb and Fes permits and the exploitation
concessions located within these permits. This includes provisions
for both Gulfsands drilled wells and legacy wells drilled prior to
the Group's acquisition of the interests. Following further
analysis and discussion with ONHYM during the year, the Company
believes that these obligations can be completed by a combination
of well work-over completions (in conjunction with a plug and
abandonment programme with other operators' in-country) and full
column cementing (based upon technical and/or health and safety
interpretation). The Company considers that this obligation should
be fully satisfied by part of the performance guarantees
inappropriately taken by ONHYM on the Rharb and Fes, as described
in Note 6.6 - Contingent Assets.
(ii) Licence penalties: The provision of $4.55 million at 31
December 2016 (2015: $1.75 million) includes an accrual of $0.75
million in respect to minimum work obligation of the Moulay Bouchta
licence (2015: $1.75 million), and $3.8 million in respect to the
minimum work obligation of the Chorbane licence (2015: $nil). See
note 2.3 for further details.
Section 3 - Working Capital
3.1 Trade and other receivables
Trade receivables are carried at original invoice amounts less
any provision made for impairment of receivables. A provision for
impairment of trade receivables is made when there is objective
evidence that the Group will not be able to collect all amounts due
according to the original terms of the debt.
2016 2015
$'000 $'000
--------------------------------- ------- -------
Trade receivables - -
Other receivables 78 96
Prepayments and accrued income 93 694
171 790
--------------------------------- ------- -------
At 31 December 2016 and 2015 the Group was owed $25.3 million by
the government of the Syrian Arab Republic relating to oil
delivered during the period of August to November 2011. The total
amount invoiced was $31.2 million and to November 2011 an amount of
$5.9 million had been paid. This asset was fully provided against
in 2011 due to the uncertainties of recovery. The recovery of this
amount is included within the impairment calculations modelled when
reviewing the Syrian investment for any impairment, see note 4.2
for further details.
3.2 Cash and cash equivalents
Cash and cash equivalents comprise cash in hand and deposits
repayable on demand by banks and other short-term investments with
original maturities of three months or less. Balances held in bank
accounts subject to escrow agreements as collateral for performance
bonds issued are excluded from cash and cash equivalents and are
shown as long-term financial assets.
2016 2015
$'000 $'000
---------------------------------- ------- ---------
Cash at bank and in hand 1,036 420
Restricted cash balances 500 3,691
---------------------------------- ------- ---------
Total cash and bank resources 1,536 4,111
Included in long-term financial
assets (note 3.3) (500) (3,691)
---------------------------------- ------- ---------
Total cash and cash equivalents 1,036 420
---------------------------------- ------- ---------
3.3 Long-term financial assets
Long-term financial assets comprise balances held in bank
accounts subject to escrow agreements as collateral for performance
bonds issued.
Key accounting judgements, estimates and assumptions:
Restricted cash balances at 31 December 2016 include $4.94
million (31 December 2015: $2.75 million) of deposits
collateralising guarantees given to state regulators to secure
minimum exploration work commitments in Morocco under the Moulay
Bouchta Petroleum Agreement ($1.75 million) the Llanos-50 licence
in Colombia ($1.48 million) and the Putumayo 14 licence ($1.71
million) in Colombia, which have all been fully provided against at
31 December 2016. Further details of the minimum work obligations
to which these guarantees relate are set out in note 2.4.
As explained further in Note 6.6, during October 2015 ONHYM drew
$5.0 million of restricted cash relating to the Fes Contract and in
January 2016, they drew $1.0 million relating to the Rharb
contract. These amounts are no longer recorded as restricted cash
balances but the Company continues to believe that these were
inappropriately drawn by ONHYM and that they should be refunded
back to Gulfsands. If any amounts are recovered, one third of the
balance is due to a third party.
2016 2015
$'000 $'000
---------------------------------- --------- ---------
Restricted cash balances 5,441 6,441
Provision against recovery
of restricted cash balances (4,941) (2,750)
Total cash and cash equivalents 500 3,691
---------------------------------- --------- ---------
3.4 Trade and other payables
Trade payables are not interest-bearing and are stated at their
nominal values.
2016 2015
$'000 $'000
------------------------ ------- --------
Current liabilities
Trade payables 315 1,534
Accruals and other
payables 868 2,086
Amounts due to oil
and gas partnerships 348 349
------------------------ ------- --------
1,531 3,969
------------------------ ------- --------
Non-current liabilities
Trade payables 1,893 1,893
Accruals and other
payables 1,553 1,534
-------------------------- ------- -------
3,446 3,427
-------------------------- ------- -------
Included within non-current liabilities is $3.4 million (2015:
$3.4 million) owed to parties subject to asset freezing regulations
under the EU sanctions regime. These amounts relate to goods and
services acquired before those entities were designated as
sanctioned parties. The Group is not in a position to make payments
for these goods or services until such time as sanctions are lifted
against the named parties. These liabilities are therefore
classified as non-current liabilities as payment of these balances
is not expected to be permissible within the next year.
3.5 Inventory
Inventories comprise materials and equipment, which are stated
at the lower of cost and net realisable value. Cost includes all
costs incurred in bringing the materials and equipment to its
present condition and location.
2016 2015
$'000 $'000
-------------------------- --------- ---------
Drilling and production
inventory 4,412 4,417
Provisions (3,320) (3,321)
-------------------------- --------- ---------
1,092 1,096
-------------------------- --------- ---------
Drilling and production inventory relates to Moroccan $2.2
million (2015: $2.2 million) and Syrian $2.2 million (2015: $2.2
million) operations.
Due to Management's revised strategy to farm-out/divest its
remaining Moroccan licence, it is anticipated that the inventory
will not be utilised on future drilling and production activities
in Morocco and instead value will be extracted via disposal.
Therefore a provision of $1.1 million (2015: $1.1 million) has been
recognised to reduce the value of the inventory to its expected net
realisable value.
During 2013, $0.7 million of inventory held for Syrian
operations was written-off due to a theft at the warehouse. An
insurance claim for the full value was submitted during 2013
however, due to the complexity of the insurance claim it has not
been appropriate, as yet, to recognise the claim as an asset as it
is not virtually certain that the claim will be paid. There has
been no change in this position during 2016.
At 31 December 2016 a provision of $2.2 million (2015: $2.2
million) has been carried forward against the value of the
remaining Syrian stock. Management believe this is appropriate in
light of the theft in 2013 and the lack of Management's control
over, and access to, the warehouse at this present time due to the
security situation in Syria.
3.6 Loans and borrowings
Recognition and measurement
Equity and debt instruments are classified as either equity or
as financial liabilities in accordance with the substance of the
contractual arrangement. Debt instruments include convertible
loans.
Convertible loan - hybrid financial instrument
Where, at inception, the conversion option is denominated in
foreign currency terms such that the option will not be settled by
the Company exchanging a fixed number of its own equity instruments
for a fixed amount of cash, the convertible loan (the host
contract) is accounted for as a hybrid financial instrument and the
option to convert is an embedded derivative.
The embedded derivative is separated from the host contract as
its risks and characteristics are not closely related to those of
the host contract. At each reporting date, the embedded derivative
is measured at fair value with changes in fair value recognised in
the Income Statement as they arise. The host contract carrying
value on initial recognition is based on the net proceeds of
issuance of the convertible loan reduced by the fair value of the
embedded derivative and is subsequently carried at each reporting
date at amortised cost. The embedded derivative and host contract
are presented under separate headings in the Balance Sheet.
Finance costs of debt are amortised over the term of the related
debt using the effective interest rate method. Transaction costs
are deducted from debt proceeds on initial recognition of the
liability and are amortised and charged to the Income Statement as
finance costs over the term of the debt.
3.6 Loans and borrowings (continued)
Convertible loan facility
On 18 November 2014, the Group and Arawak Energy Bermuda Ltd
("Arawak") entered into a strategic cooperation arrangement which
included an agreement pursuant to which Arawak agreed to provide a
three year loan facility of up to $20.0 million. The Convertible
Loan Facility (including amounts drawn, accrued but unpaid interest
and fees) was convertible at any time prior to maturity into
ordinary shares, initially at a price of GBP0.80. In addition, the
Lender had the right to participate in any equity offering by the
company up to the amount of the outstanding facility and has
certain other anti-dilution protections as well as certain use of
proceeds restrictions. More detailed terms were described in the
2015 Annual Report.
The Convertible Loan Facility was secured by a floating charge
over all of the assets of Gulfsands Petroleum Holdings Ltd, the
holding company for the Group's interest in Block 26, and a share
mortgage over the shares in Gulfsands Petroleum Morocco Ltd (the
holding company for the Group's interests in Morocco) with further
credit support provided by a guarantee from the Company. The
Convertible Loan Facility contained representations, warranties and
indemnities in favour of the Lender and provided for events of
default and a negative pledge.
On 23 January 2015, Arawak terminated its strategic cooperation
agreement with the Company amid circumstances under which the
holder of the facility may demand repayment of the Convertible Loan
Facility in full.
On 30 June 2015, the Company announced that Arawak had entered
into an assignment agreement with Weighbridge Trust Limited
("Weighbridge"), acting as agent for Waterford and Blake, to
acquire the Convertible Loan Facility from Arawak. Subsequent to
the assignment of the Convertible Loan Facility, a further $3.2
million was advanced under the facility during the latter half of
2015 and Weighbridge made certain commitments about delaying the
right to immediate repayment.
Following the Open Offer which closed in January 2016 and was
underwritten by Waterford and Blake, the Convertible Loan Facility
was discharged in full on 14 January 2016
The movement on the loan balance in the year is represented as
follows:
$'000
------------------------------------ -----------
At 1 January 2016 14,406
Interest expense 51
Amortisation of transaction costs -
Repayment of loan facility (14,457)
------------------------------------ -----------
At 31 December 2016 -
------------------------------------ -----------
Section 4 - Other Assets and Liabilities
4.1 Investments
The Company's investments in subsidiary undertakings are shown
below. All investments are in ordinary shares and are directly or
indirectly owned by the Company as stated below:
Proportion of voting
shares
at 31
December Nature of Country of
Name of company 2016 business incorporation
--------------------- ------------- ------------------- ----------------
Directly held by
the Company:
Gulfsands Petroleum Holding
Ltd.(1) 100% company Cayman Islands
----------------------- ----------- ------------------- ----------------
Indirectly held
by the Company:
Gulfsands Petroleum Holding
Holdings Ltd(1) 100% company Cayman Islands
Gulfsands Petroleum Oil and
Levant Ltd(1) 100% gas exploration Cayman Islands
Gulfsands Petroleum Oil and
Iraq Ltd(1) 100% gas exploration Cayman Islands
Gulfsands Petroleum Oil and
Tunisia Ltd(1) 100% gas exploration Cayman Islands
Gulfsands Petroleum Oil and
Morocco Ltd(1) 100% gas exploration Cayman Islands
Gulfsands Petroleum Oil and
Morocco Ltd(2) 100% gas exploration Cyprus
Gulfsands Petroleum Oil and
(MENA) Ltd(1) 100% gas exploration Cayman Islands
Gulfsands Petroleum Oil and
Sud America Ltd(1) 100% gas exploration Cayman Islands
----------------------- ----------- ------------------- ----------------
Company registered addresses:
1. 31 The Strand, 46 Canal Point Drive, Grand Cayman KY1-1105,
Cayman Islands.
2. Chapo Central, 3rd Floor, 20 Spyrou Kyprianou Avenue, 1075
Nicosia, Cyprus.
4.2 Available-for-sale financial assets
Key accounting judgements, estimates and assumptions
Fair value of the Group's investment in Dijla Petroleum Company
("DPC")
The Group's investment in DPC, the entity established in Syria,
pursuant to the PSC, to administer the Group's Syrian oil and gas
development and production assets (and which is considered to also
include the related rights to production under the PSC), is
recorded as an available-for-sale investment. Due to the unknown
duration of EU sanctions in force against Syria and uncertainty
over the eventual outcome of events in the country, any valuation
attributed to the investment is highly subjective and subject to
material change and uncertainty. Management have reviewed their
internal valuation methodology and believe that as a result of the
further passage of time and the high degree of judgement required,
it is no longer possible to reliably estimate the investment's fair
value. Management will therefore carry forward the last valuation
which could be reliably determined, being the $102 million
previously disclosed. This value will be reviewed periodically for
impairment and any impairment losses recognised through the Income
Statement.
Where they can be reliably measured, available-for-sale
financial assets are stated at fair value. Gains and losses arising
from changes in fair value are recognised in other comprehensive
income and accumulated in the investments revaluation reserve with
the exception of impairment losses which are recognised directly to
the Income Statement. Where the investment is disposed of or is
determined to be impaired, the cumulative gain or loss previously
recognised in the investments revaluation reserve is reclassified
to profit or loss. Where the fair value cannot be reliably measured
the available-for-sale investments are held at the deemed cost,
being the last valuation at which they could be reliably measured.
Available-for-sale investments held at cost are reviewed for
impairment when there has been an indication of a possible
impairment. Management assess the recoverability of the carrying
value of the available-for-sale investment by comparison with the
estimated discounted future net cash flows based on Management's
expectation of the future production, hydrocarbon prices, estimated
time to resumption of production and costs. Any identified
impairment is charged to the Income Statement.
The Group is party to a PSC for the exploitation of hydrocarbon
production in Block 26 in Syria. Pursuant to the PSC the Group
operates its Syrian oil and gas production assets through a joint
venture administered by DPC in which the Group has a 25% equity
interest. The Group lost joint control of DPC on 1 December 2011
following the publication of European Union Council Decision
2011/782/CFSP. For the purposes of EU sanctions, DPC is considered
to be controlled by General Petroleum Corporation. Since the Group
has neither joint control nor significant influence over the
financial and operating policy decisions of the entity, it carries
its investment in DPC and the associated rights under the Block 26
PSC as an available-for-sale financial asset. The carrying value of
the available-for-sale investment at 31 December 2016 is $102
million (2015: $102 million).
Impairment review of the Group's investment in DPC
In order to carry out an impairment review, Management use an
economic model of the estimated future cash flows that could be
generated in respect of the Group's entitlement volumes in Block
26. The Management team have reviewed this in detail and believe
due to the high degree of subjectivity inherent in the valuation it
is imperative that the valuation model and its key drivers and
assumptions are as transparent as possible. Management assessed the
key drivers to be:
-- the oil price; and
-- the delay to resumption of production.
1. Oil price
There has been a significant downward movement in the oil price
since 2014 although there has been some recovery since the lows of
early 2016. It is difficult to predict the oil price in these
volatile times. For the year ended 31 December 2016 Management has
used the Brent forward curve to 2022 and then a 2% per annum
escalation factor applied thereafter as the forecast for the 'base
case' comparative valuation for the impairment review. Given the
other sources of oil price data reviewed, Management considers this
to be a conservative approach.
2. Delay to resumption of production
Gulfsands cannot give a definite timeline for the resumption of
the full field development of the discovered fields within Block 26
that was suspended under the declaration of Force Majeure in 2011.
Whilst no definite timeline can be substantiated, the Board
continues to believe that the EU Sanctions will be lifted within
five years and will continue to monitor all activity focused on
resolving the situation in Syria. Management have decided to use
commencement of production in five years as the estimate 'base
case' comparative valuation for the impairment review.
Other model assumptions
The model uses the production profiles based upon 2C contingent
resources at Khurbet East (Massive, Butmah and Kurrachine Dolomite)
and Yousefieh. Receivables are included in relation to oil produced
and invoiced but not yet received, and oil produced and not yet
invoiced, on the expectation that these amounts will be recovered
once EU sanctions are lifted. A 15% discount rate is then applied
to give a net present value ("NPV").
4.2 Available-for-sale financial assets (continued)
The valuation model calculates:
-- a Gross Contractor undiscounted NPV(0) of $1.93 billion;
-- Gulfsands 50% interest NPV(0) of $0.97 billion; and
-- Gulfsands discounted NPV(15) of $150.7 million.
The Group has used the NPV(15) of $150.7 million (2015: $107.2
million) to conclude that no impairment is necessary but the
following table sets out the NPV(15) calculated when adjusting the
two key drivers: oil price and time delay to resumption of
production. All figures are presented in $'000:
Oil price Delay to first production
Three Five year Seven year
year delay delay delay
20% decrease 133,967 102,652 78,820
10% decrease 164,212 126,729 97,792
Brent forward
curve 195,071 150,667 116,655
10% increase 225,413 174,514 135,446
20% increase 255,734 198,345 154,224
---------------- ------------- ----------- ------------
The following table sets out the impact that changes in the key
variables would have on the comparative valuation of the asset,
$150.7 million, for the impairment review.
Change in comparative
valuation
of investment from $150.7
million
$'000
----------------------- ---------------------------
Delay until first
production
7 years (34,012)
3 years 44,404
----------------------- ---------------------------
Oil price
20% decrease (48,015)
10% decrease (23,939)
10% increase 23,847
20% increase 47,677
Change in discount
rate to
20% (59,340)
10% 108,525
----------------------- ---------------------------
Change in forecast
capex
5% increase (1,302)
5% decrease 1,302
----------------------- ---------------------------
Change in forecast
opex
5% increase (805)
5% decrease 805
----------------------- ---------------------------
The Directors have reviewed the carrying value of this
available-for-sale financial asset at 31 December 2016 and are of
the opinion that no impairment is required to the carrying value.
Although the carrying value is subject to significant uncertainty,
Management believes it remains appropriate in the circumstances,
although not necessarily reflective of the value of the Group's
investments in its Syrian operations over the long-term. Management
reiterate that there is a high degree of subjectivity inherent in
the valuation calculated for impairment purposes, due to the
unknown duration of the sanctions and the eventual outcome of
events in Syria. Accordingly, it may change materially in future
periods depending on a wide range of factors and an impairment may
then be required.
Section 5 - Results for the Year
5.1 Segmental analysis of continuing operations
For management purposes, at 31 December 2016 the Group operated
in three geographical areas: Morocco, Tunisia and Colombia with
suspended operations in Syria as discussed in note 4.2. All
segments are involved with the production of, and exploration for,
oil and gas. The "Other" segment represents corporate and head
office costs.
The Group's result and certain asset and liability information
for the year are analysed by reportable segment as follows.
5.1 Segmental analysis of continuing operations (continued)
Year ended 31 December 2016
Syria Morocco Tunisia Colombia Other Total
$'000 $'000 $'000 $'000 $'000 $'000
-------------------------- --------- ---------- ---------- ---------- --------- ----------
Total administrative
expenditure (456) (421) (322) (238) (2,906) (4,343)
Exploration costs
written off/impaired - (528) (5,314) (2,213) - (8,055)
Decommissioning
- change in estimate - (1,139) - - - (1,139)
Penalty provision
- change in estimate - 1,000 (3,800) - - (2,800)
Restricted cash
forfeited/ provided
against - - - (3,191) - (3,191)
Operating loss (456) (1,088) (9,437) (5,642) (2,905) (19,528)
Financing cost (227)
----------
Net loss from
continuing operations (19,755)
-------------------------- --------- ---------- ---------- ---------- --------- ----------
Total assets 102,539 1,190 9 53 1,036 104,827
Total liabilities (4,048) (2,608) (3,896) (78) (484) (11,114)
E&E capital expenditure - 528 44 334 - 906
-------------------------- --------- ---------- ---------- ---------- --------- ----------
Year ended 31 December 2015
Syria Morocco Tunisia Colombia Other Total
$'000 $'000 $'000 $'000 $'000 $'000
------------------------- --------- ---------- --------- ---------- ---------- ----------
Total administrative
expenditure (180) (950) (418) (112) (5,305) (6,965)
Exploration
costs written
off/impaired - (53,799) - - - (53,799)
Restricted cash
balances forfeited/
provided against - (5,750) - - - (5,750)
Inventory adjustments - (1,117) - - - (202)
Operating loss (180) (61,616) (418) (112) (5,305) (67,631)
Net financing
cost credit (1,569)
Net loss from
continuing operations (69,200)
------------------------- --------- ---------- --------- ---------- ---------- ----------
Total assets 102,574 1,385 5,294 1,913 4,157 115,323
Total liabilities (3,929) (3,211) (74) (49) (16,737) (24,000)
E&E capital
expenditure - 7,773 75 654 - 8,502
------------------------- --------- ---------- --------- ---------- ---------- ----------
5.2 Operating loss
The Group's operating loss for continuing operations is stated
after charging:
2016 2015
$'000 $'000
------------------------------------ ------- --------
Share-based payment charges 159 -
(note 5.3)
Depreciation and amortisation
of other assets (notes
2.1 and 2.3) 78 507
Exploration expenditure
written-off/impaired (note
2.3) 8,055 53,799
Restricted cash balances
forfeited/provided against
(note 3.3) 3,191 5,750
Staff costs excluding share-based
payments (note 5.5) 2,474 5,217
Operating lease rentals:
Buildings 399 887
Vehicles and equipment - 90
------------------------------------ ------- --------
Operating leases
Rentals payable under operating leases are charged to the Income
Statement on a straight-line basis over the lease term.
5.3 Share-based payments
The Company has made equity-settled share-based payments to
certain employees and/or Directors by way of issues of share
options. The fair value of these payments is calculated at grant
date by the Company using the Black-Scholes option pricing model
excluding the effect of non market-based vesting conditions. The
expense is recognised on a straight-line basis over the period from
the date of award to the date of vesting, based on the Company's
best estimate of the number of options that will eventually vest.
At each Balance Sheet date, the Company revises its estimates of
the number of options expected to vest as a result of the effect of
non market-based vesting conditions. The impact of the revision of
the original estimates, if any, is recognised in profit or loss
such that the cumulative expense reflects the revised estimate,
with a corresponding adjustment to retained profit.
The only share-based plan currently in operation is the
Gulfsands Restricted Share Plan which was introduced in 2010 and
expires in 2020. Under this plan, share awards may be granted to
Directors and members of staff and may be based upon length of
service and/or linked to achievement of performance criteria. All
instruments outstanding and issued during the year under this plan
are share options to purchase Ordinary Shares in the Company.
5.3 Share-based payments (continued)
Share options are issued with an exercise price equivalent to
the underlying share price averaged over a period immediately prior
to the date of grant, or such other higher exercise price as the
Remuneration Committee may determine. Share options will usually
have a deferred vesting period and a maximum validity period of ten
years.
The share-based payment charge for the period is based upon the
requirements of IFRS 2 'Share-based Payment'. For this purpose, the
weighted average estimated fair value of the share options and
restricted share options granted was calculated using a
Black-Scholes option pricing model. The expected average life of
options and restricted share options was assumed to be four
years.
No dividends were factored into the model. Volatility has been
estimated based on the historical volatility of the underlying
shares.
No share options were issued in 2015. During 2016, 17,000,000
restricted stock options were issued to serving Directors.
The estimated fair value of share options with a deferred
vesting period is charged to the Income Statement over the vesting
period of the options concerned. The estimated fair value of
options and restricted shares exercisable immediately is expensed
at the time of issuance of the award. The charge for the year was
$159,000 and further details are provided in note 6.1.
No share awards were granted to Directors or employees between
2011 and 2015. As a result of the fall in share price since the
imposition of sanctions against Syria towards the end of 2011,
options held by Directors at that time have either lapsed or, if
still outstanding, are exercisable at share prices significantly in
excess of the current share price.
During 2016, John Bell was appointed full time Managing Director
and Andrew Morris was appointed Finance Director on a less than
full time basis. In view of the continuing uncertainty surrounding
the Company's business in Syria and the shortage of available
funds, it was decided that remuneration packages for these two
executives should be a combination of base salary and share
options. Accordingly, John Bell was awarded 8 million share options
and Andrew Morris 5 million share options. 4 million of Mr Bell's
options and 3 million of Mr Morris' will vest quarterly over a two
-year period from July 2016 dependent in part on continued service
during that period and in part on performance criteria related to
the achievement of strategic objectives. The vesting schedule of
the additional 4 million and 2 million options respectively have
yet to be determined. Once vested, the options are exercisable for
a period of 10 years.
Share options were also granted to the Chairman and two new
Non-Executive Directors. These options are not subject to
performance criteria. Half of their respective awards vested on the
date of award and the other half will vest after one year.
Fair value of share options granted
The fair value of options granted under the share options scheme
is estimated as at the date of grant using a variant of the Black
Scholes model, taking into account the terms and conditions upon
which the options are granted, which includes the performance
conditions. The following table lists the inputs to the model used
for the options granted in the years ended 31 December 2016 and 31
December 2015. The expected future volatility has been determined
by reference to the historical volatility.
Exercise period 2016 2015
--------------------- ---- ---- ---------- ------
Dividend yield n/a n/a
Expected share
price volatility 50.0% n/a
Risk free interest
rate 2.0% n/a
Exercise price 1p -
3.375p n/a
Expected life
of option (years) 10 n/a
5.4 Auditor's remuneration
Details of the auditor's remuneration is set out in the table
below:
2016 2015
$'000 $'000
----------------------------------- ------- --------
Fees payable to the Company's
principal auditor for the
audit of:
Company's accounts 78 90
Company's subsidiaries 1 20
----------------------------------- ------- --------
Total audit fees 79 110
----------------------------------- ------- --------
Audit related assurance services 8 13
Taxation compliance services - 1
Other services - 60
----------------------------------- ------- --------
Total non-audit fees 8 74
----------------------------------- ------- --------
Fees payable to other auditors
for the audit of:
Company's subsidiaries 33 26
----------------------------------- ---- ----
Total audit fees 33 26
----------------------------------- ---- ----
Taxation compliance services 6 8
Other taxation advisory services 2 12
Total non-audit fees 8 20
----------------------------------- ---- ----
5.5 Staff costs
The aggregate payroll costs of staff and Directors were as
follows:
2016 2015
$'000 $'000
------------------------------ ------- -------
Wages and salaries 2,235 4,769
Social security costs 191 334
Share-based payment charges 159 -
Other benefits in kind 48 114
2,633 5,217
------------------------------ ------- -------
Included in wages and salaries above is an amount of $nil in
respect of termination payments to staff accrued or paid during
2016 (2015: $0.1 million).
The average monthly number of persons employed by the Group,
including Directors was as follows:
2016 2015
---------------------------- ------ ------
Operational and technical 4 13
Administrative 21 30
---------------------------- ------ ------
25 43
---------------------------- ------ ------
5.6 Directors' emoluments
Details of the remuneration of Directors are included in the
Directors' Remuneration Report on page 27. No employees other than
Directors are determined to be key management personnel.
In addition, the aggregate amount paid to former directors as
compensation for loss of office was $819,000 (2015: $nil).
5.7 Net interest receivable
Interest income is accrued on a time basis, by reference to the
principal outstanding and the effective rate applicable.
2016 2015
$'000 $'000
----------------------------------- ------- -------
Short-term bank deposit interest 23 13
----------------------------------- ------- -------
5.8 Taxation
Current tax
Current tax, including UK Corporation Tax and overseas tax, is
provided at amounts expected to be paid (or recovered) using the
tax rates and laws that have been enacted or substantively enacted
by the Balance Sheet date.
Where current or deferred tax arises from the initial accounting
for a business combination, the tax effect is included in the
accounting for the business combination.
2016 2015
$'000 $'000
-------------------------- ------- -------
Current Corporation Tax:
UK Corporation Tax - -
Overseas Corporation Tax - -
-------------------------- ------- -------
Total credit - -
-------------------------- ------- -------
The Group's effective tax rate differs from the theoretical
amount that would arise using the UK domestic corporation tax rate
applicable to profits of the consolidated companies as follows:
2016 2015
$'000 $'000
----------------------------------- ---------- ----------
Total loss before tax from
continuing operations (19,755) (69,200)
----------------------------------- ---------- ----------
Tax calculated at domestic
rate of 20% (2015: 20.25%) (3,951) (14,200)
Effects of:
Expenses not deductible for
tax purposes 3,254 11,615
PSC expenses not subject to
corporation tax(1) 145 103
Tax losses utilised - -
Tax losses for which no deferred
tax asset was recognised 590 957
Impact of local tax rates (38) 1,338
- -
----------------------------------- ---------- ----------
(1) The Group's tax liabilities in Syria are settled on its
behalf by the national oil companies out of the latter's share of
royalties and profit oil and, as such, are not reflected in the
Group's tax charge for the year.
In Morocco under section 42 of law no. 21-90 related to the
Hydrocarbon Code, the Group benefits from a ten-year exemption from
Moroccan corporate income tax in respect of each exploitation
concession, commencing on the date on which regular production
begins from that exploitation concession.
Deferred tax
Deferred tax assets and liabilities are determined based on
differences between financial reporting and tax bases of assets and
liabilities and are measured using the enacted, or substantively
enacted, tax rates and laws that will be in effect when the
differences are expected to reverse. The recoverability of deferred
tax assets is evaluated annually and an impairment provision is
made if it is more likely than not that the deferred tax asset will
not give rise to future benefits in the Group's tax returns.
Deferred tax assets are not provided where the Group does not
consider it probable that sufficient future taxable profits will be
made to offset the deductions represented by those deferred tax
assets. In performing this calculation the Group considers deferred
tax balances relating to each tax authority separately. No deferred
tax assets have been provided in respect of losses carried forward
and other temporary timing differences as the Board does not
consider it probable that sufficient future taxable profits will be
made to offset the deductions represented by those deferred tax
assets.
The tax effect of amounts for which no deferred tax asset has
been recognised is as follows:
2016 2015
$'000 $'000
--------------------------------- --------- ----------
DD&A and impairment in excess
of tax allowances 247 5,874
Other short-term temporary - -
differences
Tax losses carried forward 8,125 8,797
Unprovided deferred tax asset (8,371) (14,671)
--------------------------------- --------- ----------
Deferred tax asset/(liability) - -
at 31 December
--------------------------------- --------- ----------
$0.2 million of the Group's unutilised tax losses expire within
one to five years of the Balance Sheet date.
5.9 Loss per share
The basic and diluted loss per share has been calculated using
the loss for the year ended 31 December 2016 of $19.8 million
(2015: $69.2 million) for continuing operations and $19.8 million
(2015: $69.2 million) for the loss attributable to the owners of
the parent company. The basic loss per share was calculated using a
weighted average number of ordinary shares in issue less treasury
shares held of 473,428,648 (2015: 117,886,145). The weighted
average number of ordinary shares, allowing for the exercise of
share options, for the purposes of calculating the diluted loss per
share was 480,880,703 (2015: 117,965,804).
Where there is a loss, the impact of share options is
anti-dilutive and hence, basic and diluted loss per share are the
same.
Section 6 - Capital Structure and Other Disclosures
Equity instruments
Equity instruments issued by the Company, being any instruments
with a residual interest in the assets of the Company after
deducting all its liabilities, are recorded at the proceeds
received, net of direct issue costs.
Repurchase of the Company's own equity instruments is recognised
and deducted directly in equity. No gain or loss is recognised in
profit or loss on the purchase, sale, issue or cancellation of the
Company's own equity instruments.
6.1 Share capital
Group and Company
2016 2015
$'000 $'000
--------------------------------- -------- --------
Allotted, called up and fully
paid:
519,995,785 (2015: 121,989,500) 18,803 13,131
--------------------------------- -------- --------
On 17 September 2015, each of the Company's existing ordinary
shares were subdivided into one ordinary share of 1 pence and one
deferred share of 4.7142865 pence. Consequently, other than the
ordinary share referenced in the above table, there are in issue
121,989,500 deferred shares. The rights of both the ordinary and
the deferred shares are as set out in the Articles of Association
as amended 15 September 2015. Deferred shares on issue do not have
voting rights and are not entitled to dividends.
On 14 January 2016 the Company completed an Open Offer of
ordinary shares to shareholders on the record date resulting in the
issue of 350,733,941 new ordinary shares and the sale of 4,103,355
treasury shares.
On 10 August 2016 the Company completed a Placing of ordinary
shares to 47,272,344.
The movements in share capital and share options were:
Number Weighted
of deferred Number average
shares of Number price
Number 2005 of 2010 of
of ordinary share share options
shares options options (GBP)
----------------------- -------------- --------------- ----------- ------------- ----------
At 31 December
2015 121,989,500 121,989,500 465,000 136,693 2.35
Share capital - - - -
raised under Open
Offer 350,733,941
Share capital - - - -
raised in Placing 47,272,344
Restricted share
options lapsing
unexercised - - - (19,065) -
Share options
lapsing unexercised
Share options - - (465,000) - -
granted - - - 17,000,000 0.016
At 31 December
2016 519,995,785 121,989,500 - 17,117,628 0.016
----------------------- -------------- --------------- ----------- ------------- ----------
Of the share options outstanding, 117,628 options have an
exercise price of 5.714 pence per share, 13,000,000 options have an
exercise price of 1 pence per share, and 4,000,000 options have an
exercise price of 3.375 pence per share, as shown in the table
below.
The detail of the share options outstanding at 31 December 2016
are as follows:
Exercise period Weighted
average
exercise
Year price
share of options Number
options (GBP of share
vest pence) options
---------------------- ----- -------------- ------------- -------------
4 April 2012 -
3 April 2017 2013 5.714 58,814
4 April 2012 -
3 April 2017 2014 5.714 58,814
22 October 2016
- 22 October 2026 2016-2018 1.558 17,000,000
1.587 17,117,628
------------------------------------------- ------------- -------------
Of the total options issued during the year, 17,000,000 options
were granted to Directors in office at that time (31 December 2015:
nil), no options were granted to current employees (31 December
2015: nil).
The average share price during 2016 was GBP0.05 (2015: GBP0.13).
The highest share price during the year was GBP0.14 and the lowest
price was GBP0.03 (2015: GBP0.38 and GBP0.03).
6.2 Financial instruments, derivatives and capital
management
Risk assessment
The Group's oil and gas activities are subject to a range of
financial risks, as described below, which can significantly impact
its performance.
Liquidity risk
At the end of the year the Group had cash and cash equivalents
of $1.0 million, and further bank balances of $0.5 million held in
escrow to guarantee minimum work obligations.
Cash forecasts identifying the liquidity requirements of the
Group are produced frequently. These are reviewed regularly by
Management and the Board.
The following table details the Group's remaining contractual
maturity for its non-derivative financial assets and liabilities
with agreed repayment periods. The table has been drawn up based on
the undiscounted cash flows of the financial assets and liabilities
based upon the earliest date on which the Group can be required to
pay or receipt. The table includes both interest and principal cash
flows.
Three
Less months One More
than to to than
three one three three
months year years years Total
$'000 $'000 $'000 $'000 $'000
----------------------------- ---------- --------- -------- --------- ----------
31 December 2016
Current trade
and other payables (1,183) - - - (1,183)
Non-current trade
and other payables - - - (3,446) (3,446)
Loan facility - - - - -
----------------------------- ---------- --------- -------- --------- ----------
(1,183) - - (3,446) (4,629)
----------------------------- ---------- --------- -------- --------- ----------
31 December 2015
Current trade
and other payables (3,620) - - - (3,620)
Non-current trade
and other payables - - - (3,427) (3,427)
Loan facility (14,406) - - - (14,406)
------------------------------ ---------- --------- -------- --------- ----------
(18,026) - - (3,427) (21,453)
----------------------------- ---------- --------- -------- --------- ----------
During 2015, the loan facility bears a weighted average
effective interest rate of 10%. No other balances in the table
above are interest bearing.
Currency risk
The Group has currency exposure arising from transactions
denominated in currencies other than the functional currency of the
Company and all its subsidiaries, US Dollars. These transactions
relate to certain costs of its oil and gas exploration and
production operations which are denominated in local currencies or
in Euro, and its head office costs which are denominated in Pounds
Sterling.
In Syria and Tunisia where the operations are covered by PSCs,
costs incurred in currencies other than US Dollars are recoverable
under the terms of the PSC at the rate of exchange between US
Dollars and that currency at the date of payment of the
expense.
The Group maintains part of its cash balances in Pounds Sterling
to defray head office costs but limits exposure to other currencies
as far as practicable.
The following table demonstrates the sensitivity to changes in
the US Dollar exchange rate, with all other variables held
constant, on the Group's net assets:
Effect on
Change in net assets
US Dollar rate $'000
------- ----------------- -------------
2016 (+ or -) 5% +/- 33
2015 (+ or -) 5% +/- 145
------- ----------------- -------------
The following table demonstrates the sensitivity to changes in
the US Dollar exchange rate, with all other variables held
constant, on the Group's profit before tax:
Effect on profit
Change in before tax
US Dollar rate $'000
------- ----------------- ------------------
2016 (+ or -) 5% +/- 234
2015 (+ or -) 5% +/- 431
------- ----------------- ------------------
6.2 Financial instruments, derivatives and capital management
(continued)
Credit risk
Credit risk refers to the risk that a counter-party will default
on its contractual obligations resulting in a financial loss to the
Group. The Group's operations are typically structured via
contractual joint venture arrangements. As such, the Group is
reliant on joint venture partners to fund their capital or other
funding obligations in relation to assets and operations which are
not yet cash generative. The Group closely monitors the risks and
maintains a close dialogue with those counterparties considered to
be highest risk in this regard.
The Directors do not consider that any further provision is
necessary against any financial assets.
Capital risk management
The Group's objectives when managing capital are to safeguard
the Group's ability to continue as a going concern in order to
provide returns for shareholders and benefits for other
stakeholders and, to maintain an optimal capital structure to
reduce the cost of capital. In order to maintain or adjust the
capital structure, the Group may return capital to shareholders,
issue new shares or sell assets to reduce debt.
The capital structure of the Group consists of net debt
(borrowings as disclosed in note 3.6 after deducting cash and cash
equivalents and restricted cash balances as disclosed in note 3.2)
and equity of the Group (comprising issued capital, reserves and
retained earnings).
Financial assets
The Group's financial assets consist of long-term financial
assets, its available-for-sale investment in DPC, cash at bank and
receivables. The interest rate profile at 31 December for these
assets at US Dollar equivalents was as follows:
Financial Financial
assets assets
on which
on which no
interest interest
is earned is earned Total
$'000 $'000 $'000
------------------- --------------------- --------------------- ---------
2016
US Dollar 89 102,637 102,726
Pound Sterling 33 4 37
Euro 27 94 121
Syrian Pound 14 - 14
Moroccan
Dirham 2 - 2
Other currencies 20 11 31
------------------- --------------------- --------------------- ---------
185 102,746 102,931
------------------- --------------------- --------------------- ---------
Financial Financial
assets assets
on which
on which no
interest interest
is earned is earned Total
$'000 $'000 $'000
------------------- ------------ ------------ ---------
2015
US Dollar 3,290 102,637 105,927
Pound Sterling 34 4 38
Euro 122 94 216
Syrian Pound 15 - 15
Moroccan
Dirham 2 - 2
Other currencies 11 11 22
------------------- ------------ ------------ ---------
3,474 102,746 106,220
------------------- ------------ ------------ ---------
The Pound Sterling, Euro, Moroccan Dirham and Syrian Pound
assets principally comprise cash in hand, cash in instant access
accounts and short-term money market deposits. The US Dollar assets
represent an available-for-sale financial asset, cash on call
accounts, money market accounts, and short-term receivables. The
Group earned interest on its interest bearing financial assets at
rates between 0.01% and 0.35%.
In the current economic climate with exceptionally low interest
rates, the Group is not sensitive to fluctuations in the interest
rate received on bank and money market deposits and accordingly no
sensitivity analysis is published.
Included in financial assets on which no interest is earned at
31 December 2016 and 2015 was a gross amount of $25.3 million of
trade receivables that has been fully provided against. This amount
is due from the government of the Syrian Arab Republic in respect
of oil sales in Syria. Due to the ongoing sanctions against the
country's oil industry the payment of this amount has been delayed
and, taking into account the current exceptional circumstances in
Syria and the consequential difficulty of predicting the timing of
future payment, has been fully impaired. The recovery of this
amount is included within the impairment calculations modelled when
reviewing the Syrian investment for any impairment, see note 4.2
for further details.
6.2 Financial instruments, derivatives and capital management
(continued)
The remaining trade receivables consist of amounts receivable
from various counterparties where the Group considers the credit
risk to be low. This risk is monitored by the Group.
Financial liabilities
The Group's financial liabilities consist of both short-term and
long-term payables in addition to the loan facility. None of the
short and long-term payables bear interest to external parties.
However, the loan facility bears interest at 10% per annum. The
Group's short-term liabilities are considered to be payable on
demand. At 31 December financial liabilities are classified as
shown below:
Financial Financial
liabilities liabilities
on which
on which interest no
interest Total
is charged is charged
$'000 $'000 $'000
------------------- ------------------- -------------- --------
2016
US Dollar - 8,836 8,836
Pound Sterling - 331 331
Euro - 166 166
Syrian Pound - 54 54
Moroccan Dirham - 106 106
Other currencies - 17 17
------------------- ------------------- -------------- --------
- 9,510 9,510
------------------- ------------------- -------------- --------
2015
US Dollar 14,406 5,548 19,954
Pound Sterling - 1,905 1,905
Euro - 579 579
Syrian Pounds - 153 153
Moroccan Dirham - 230 230
Other currencies - 87 87
------------------- ------------------- -------------- --------
14,406 8,502 22,908
------------------- ------------------- -------------- --------
Commodity price risk
The realisation of the carrying values of oil and gas assets
within these Consolidated Financial Statements, and the value of
the Group's available-for-sale financial assets, being the Syrian
interests, are in part dependent upon future oil and gas prices
achieved. Note 4.2 gives details of the impact of a change in the
oil price on the valuation of available-for-sale financial
assets.
In 2016 and 2015 the Group did not enter into any derivative
contracts in respect of its exposure to fluctuations in the price
of oil and gas.
Fair values
The Group's investment in DPC, the entity established in Syria,
pursuant to the PSC, to administer the Group's Syrian oil and gas
development and production assets (and which is considered to also
include the related rights to production under the PSC), is
recorded as an available-for-sale investment. Due to the unknown
duration of EU sanctions in force against Syria and uncertainty
over the eventual outcome of events in the country, any valuation
attributed to the investment is highly subjective and subject to
material change and uncertainty. Management believes that as a
result of the further passage of time and the high degree of
judgement required, it is no longer possible to reliably estimate
the investment's fair value. Management will therefore carry
forward the last valuation which could be reliably determined,
being the $102 million previously disclosed. This value will be
reviewed periodically for impairment and any impairment losses
recognised through the Income Statement, this is described further
in note 4.2.
At 31 December 2016 and 2015, the Directors considered the fair
values and book values of the Group's financial assets and
liabilities to be level 3 valuations.
6.3 Related party transactions and key management
Key management of the Group are considered to be the Directors
of the Company. Directors' interests in shares and their
remuneration and share options are disclosed in the Directors'
Remuneration Report on pages 27 to 30.
The remuneration of Directors is set out below in aggregate for
each of the categories specified in IAS 24 'Related Party
Disclosures'.
2016 2015
$'000 $'000
----------------------- ------- -------
Short-term employee
benefits 677 1,235
Share-based payments 159 -
----------------------- ------- -------
836 1,235
----------------------- ------- -------
All of the above related party transactions were made on terms
equivalent to those that prevail in arm's length transactions.
Balances and transactions between the Company and its
subsidiaries, which are related, have been eliminated on
consolidation and are not disclosed in this note. Transactions
between the Group and its subsidiaries are disclosed in note 6.6 of
the Company Financial Statements.
There were no other related party transactions of the Group
during the years ended 31 December 2016 or 2015.
6.4 Obligations under operating leases
At the end of the year the Group had commitments for future
minimum lease payments under non-cancellable operating leases as
follows:
2016 2015
-------------------- --------------------
Land and Land and
buildings Other buildings Other
$'000 $'000 $'000 $'000
------------------ ----------- ------- ----------- -------
Amounts payable
on leases:
Within one
year 109 - 647 -
In two to five - - 95 -
years
------------------ ----------- ------- ----------- -------
109 - 742 -
------------------ ----------- ------- ----------- -------
There are no future minimum sublease payments expected to be
received under non--cancellable subleases at the end of the
reporting period (31 December 2015: $nil).
6.5 Contingent liabilities
Legal claim - Mahdi Sajjad
In December 2016 the Group settled its long outstanding dispute
with former Chief Executive Officer, Mr Mahdi Sajjad. Under the
terms of the settlement, all actions against the Group by Mr.
Sajjad in the London High Court, the Employment Tribunal in
England, and in the Lebanese Arbitration Court, as well as the
Group's counterclaim against Mr. Sajjad, were settled without any
admission of liability by either party.
Claim by Al Mashrek Group in Syria
Al Mashrek Global Investment Ltd ("Al Mashrek") has filed a
claim with the Courts in Damascus, Syria, against Gulfsands
Petroleum Levant Limited (incorporated in Cayman Islands) ("GPLL")
and the Syrian registered branch of GPLL on the grounds that Al
Mashrek was not properly notified of the Open Offer completed in
January 2016 and hence lost the opportunity to subscribe for new
shares in the Open Offer and as a result Al Mashrek's equity was
subsequently diluted.
The Court of Appeal of Damascus has issued an order of
provisional attachment on GPLL's moveable and immovable assets,
including GPLL's share of Block 26, to secure Al Mashrek's claim of
an amount of Syrian pounds equivalent to $2.0 million. While
Gulfsands continues to investigate the alleged claim it is
determined to protect its rights in Syria. Gulfsands are seeking
legal advice on this matter. Management believe the outflow of
funds in relation to this claim to be possible but not probable and
therefore no provision has been made as at 31 December 2016.
6.5 Contingent liabilities (continued)
Penalties sought by ONHYM under the Rharb Petroleum
Agreement
In late 2015 (9 November 2015), the extension period of the
Rharb Petroleum Agreement expired and the Company submitted a
request to further extend the Rharb Petroleum Agreement for a
period of two years to allow the Company to appraise the gas
discoveries made in 2014/15.
On 30 November 2015, the Company received a response from ONHYM,
dated 26 November 2015, advising that its request for an extension
to the Rharb Petroleum Agreement had been rejected and furthermore
that:
-- Gulfsands Morocco will forfeit its $1.0 million in restricted
cash held as a performance guarantee in relation to its minimum
work obligation under the Rharb Petroleum Agreement;
-- ONHYM is seeking a penalty equal to the estimated cost of the
minimum exploration work programme of the Rharb Petroleum Agreement
less the costs actually incurred in respect of exploration work
required, whereby ONHYM is claiming a sum of $7.5 million;
-- ONHYM advised they will also, by separate request, seek the
outstanding amount under the training obligation of the Rharb
Petroleum Agreement; and
-- ONHYM was seeking an update on the Company's progress in
relation to the abandonment of the legacy producing wells and the
cleaning and restoring of the well sites in the Rharb Centre permit
area.
The Company strongly refutes the claims for financial sums and
penalties and is seeking legal advice on the matter.
In these 2016 year-end Financial Statements the $1.0 million
restricted cash balance has been fully provided against and
decommissioning and restoration provisions of $1.6 million covering
all Gulfsands drilled wells and legacy wells have been provided
for, although the Company considers that this decommissioning
obligation should be fully satisfied by part of the performance
guarantees inappropriately taken by ONHYM on the Rharb and Fes
licences, as described in note 6.6.
No provisions have been made for training obligations or the
penalty.
6.6 Contingent assets
Recovery of guarantee amounts under the Rharb Petroleum
Agreement
In late 2015, on 30 November 2015 the Company received a
response from ONHYM stating Gulfsands Morocco will forfeit its $1.0
million in restricted cash held as a performance guarantee in
relation to its minimum work obligation under the Rharb Petroleum
Agreement. ONHYM drew this amount in January 2016.
Gulfsands have provided ONHYM with details of the costs actually
incurred in respect of the exploration work required to be carried
out during the extension period and these costs significantly
exceed the $15 million estimated costs of the minimum exploration
work programme. Therefore Gulfsands believe that in accordance with
the Rharb Petroleum Agreement no penalty payment is due. As a
result the $1.0 million drawn by ONHYM was not drawn under the
provisions of the Rharb Petroleum Agreement as no penalty was due
and therefore should be refunded back to Gulfsands. Of the $1.0
million, $0.33 million is due back to a third party if released by
ONHYM.
No asset has been recognised in these Financial Statements for
this contingent asset.
Recovery of guarantee amounts under the Fes Petroleum
Agreement
In late 2015 (16 October 2015), the Company announced that the
extension period of the Fes Petroleum Agreement expired on 24
September 2015 and the request to further extend the agreement was
not granted by ONHYM, and furthermore that:
-- ONHYM advised that Gulfsands Morocco will forfeit its $5.0
million in restricted cash held as a performance guarantee in
relation to its minimum work obligation under the Fes Petroleum
Agreement and the restricted cash had been drawn by ONHYM; and
-- ONHYM had requested details of the costs incurred during the
six year extension period in order to determine if a penalty was
payable, with such penalty being the estimated cost of the minimum
exploration work programme of $18.5 million, less the costs
actually incurred in respect of exploration work required to be
carried out during the extension period.
Gulfsands provided ONHYM with details of the costs actually
incurred in respect of the exploration work required to be carried
out during the extension period and these costs significantly
exceed the $18.5 million estimated costs of the minimum exploration
work programme. Therefore, Gulfsands believes that in accordance
with the Fes Petroleum Agreement no penalty payment is due. As a
result the $5.0 million drawn by ONHYM was not drawn under the
provisions of the Fes Petroleum Agreement as no penalty was due and
therefore should be refunded back to Gulfsands. Of the $5.0
million, $1.33 million is due back to a third party if released by
ONHYM.
No asset has been recognised in these Financial Statements for
this contingent asset.
6.7 Post balance sheet events
Secured Term Financing Facility
Subsequent to the year end, on 15 February 2017, the Company
closed a Secured Term Financing Facility of up to GBP4 million (the
"2017 Facility") with its Major Shareholders, Waterford, Blake and
ME Investments Limited.
The 2017 Facility is available for drawdown by the Company in
five equal tranches of GBP0.8 million, the first available
immediately upon the satisfaction of various administrative
conditions precedent (completed in February 2017), and the further
tranches being available on or after 31 March 2017, 30 June 2017,
30 September 2017 and 31 December 2017. The first two tranches,
were committed by the Lenders, with the final three tranches, being
subject to re-approval by each of the Lenders prior to each
drawdown request.
At the date of this report, the first three tranches have been
drawn down: the initial tranche was drawn immediately, the 31 March
tranche was drawn down in early April 2017, and in late April 2017,
the Lenders unanimously agreed to allow the third tranche to be
drawn down ahead of the scheduled date of 30 June, 2017 to assist
with working capital requirements.
Interest on loans made (together with accrued fees and interest)
shall run at 7% per annum. A commitment fee of 1% per annum shall
run on any undrawn proportion of the Facility. All fees and
interest accrue quarterly until maturity. All, or part, of the
undrawn portion of the Facility may be cancelled at any time by the
Company. The Company may prepay the whole or any part (if at least
GBP0.8 million) of the outstanding amounts at any time subject to
paying a 10% premium on the amount pre-paid.
The proceeds will be used for general and administrative
expenses of the Group and for working capital purposes.
The maturity date of the 2017 Facility is three years from the
first drawdown date, at which date all outstanding amounts will be
repayable in cash unless the Company has exercised an equity
conversion right. Pursuant to that right, the outstanding amounts
to be repaid may be converted at the Company's option into shares
of the Company at a price equal to the lower of (i) the 90 day
average closing price at the time of repayment and (ii) the lowest
price at which the Company has raised equity capital during the
life of the 2017 Facility.
The Facility is secured: by a mortgage over the shares of the
Company's direct subsidiary, Gulfsands Petroleum Limited; by a
charge over certain intercompany receivables of the Company; by a
charge over certain bank accounts of the Company (should the
Lenders require such a charge to be created); and through the issue
of one ordinary share in the share capital of Gulfsands Petroleum
Limited to the security trustee. The security trustee for the
Facility is Weighbridge Trust. The articles of association of
Gulfsands Petroleum Limited have also been amended to include
certain reserved matters requiring unanimous shareholder consent,
pre-emption provisions and compulsory transfer provisions. In
addition to the right to enforce the security, on an
insolvency-related event of default, the Lenders have the right to
convert outstanding amounts under the Facility into a direct equity
holding in Gulfsands Petroleum Limited, at a fair price (from a
financial point of view taking into account all relevant
circumstances) to be determined by an expert at the time.
Glossary of Terms
1C Low estimate (P90) Contingent Resources
2C Best estimate (P50) Contingent Resources
3C High estimate (P10) Contingent Resources
AIM Alternative Investment Market of the London Stock Exchange
Arawak Arawak Energy Bermuda Ltd
bbls Barrels of oil
bcf Billion cubic feet of gas
Blake Blake Holdings Limited
Code UK Corporate Governance Code
CSR Corporate social responsibility
DD&A Depletion, depreciation and amortisation
DOB-1 Douar Ouled Balkhair location
DPC Dijla Petroleum Company
DRC-1 Dardara South East location
E&E Exploration and evaluation
E&P Exploration and production
FD Finance Director
FRC Financial Reporting Council
G&A General and administrative expenses
GPC General Petroleum Corporation
Gulfsands Levant Gulfsands Petroleum Levant Limited
Gulfsands (MENA) Gulfsands Petroleum (MENA) Limited
Gulfsands Morocco Gulfsands Morocco Limited
HSES Health, safety, environment and security
IFRS International Financial Reporting Standards
km Kilometres
km(2) Square kilometres
KPI Key performance indicator
Lender Arawak Energy Bermuda Ltd
LLA 50 Llanos Block 50
MD Managing Director
MENA Middle East and North Africa
mmbbl Millions of barrels of oil
mmboe Millions of barrels of oil equivalent
NGLs Natural gas liquids
NPV Net present value
ONHYM Office National des Hydrocarbures et des Mines (Morocco)
P10 There exists a 10% probability that the true quantity or
value is greater than or equal to the stated P10 quantity or
value
P50 There exists a 50% probability that the true quantity or
value is greater than or equal to the stated P50 quantity or
value
P90 There exists a 90% probability that the true quantity or
value is greater than or equal to the stated P90 quantity or
value
Possible Reserves Possible Reserves are those additional
reserves which analysis of geological and engineering data suggests
are less likely to be recoverable than Probable Reserves. The total
quantities ultimately recovered from the project have a low
probability to exceed the sum of Proved plus Probable plus Possible
("3P") Reserves, which is equivalent to the high estimate scenario.
In this context, when probabilistic methods are used, there should
be more than a 10% probability that the quantities actually
recovered will equal or exceed the 3P estimate.
Probable Reserves Probable Reserves are those unproved reserves
which analysis of geological and engineering data suggests are more
likely than not to be recoverable. In this context, when
probabilistic methods are used, there should be more than a 50%
probability that the quantities actually recovered will equal or
exceed the sum of estimated Proved plus Probable Reserves.
Proved Reserves Proved Reserves are those quantities of
petroleum which, by analysis of geological and engineering data,
can be estimated with reasonable certainty (normally over 90% if
measured on a probabilistic basis) to be commercially recoverable,
from a given date forward, from known reservoirs and under defined
economic conditions, operating methods, and government
regulations.
PRMS The 2007 Petroleum Resources Management classification system of the SPE
PSC Production Sharing Contract
PUT 14 Putumayo Block 14
Senergy Senergy (GB) Limited
SPE Society of Petroleum Engineers
Waterford Waterford Finance and Investment Limited
Weighbridge Weighbridge Trust Limited
This information is provided by RNS
The company news service from the London Stock Exchange
END
FR EAKSNASXXEFF
(END) Dow Jones Newswires
May 30, 2017 02:01 ET (06:01 GMT)
Gulfsands Petroleum (LSE:GPX)
Historical Stock Chart
From Feb 2025 to Mar 2025
Gulfsands Petroleum (LSE:GPX)
Historical Stock Chart
From Mar 2024 to Mar 2025
