TIDMUEP TIDMNSN
RNS Number : 5522F
UMC Energy PLC
24 May 2013
UMC Energy Plc
("UMC" or the "Company")
Final Results
For the year ended 31 December 2012
The Directors present the results of UMC Energy Plc ("Company")
and of the consolidated entity, being the Company and its
subsidiaries ("Group") and the Group's interest in associates, for
the year ended 31 December 2012.
CHAIRMAN'S STATEMENT
Papua New Guinea
In September 2011, the Group acquired one on-shore (PPL 378) and
two off-shore (PPLs 374 and 375) Petroleum Prospecting Licences
(PPLs) in Papua New Guinea through the acquisition of PNG Energy
Limited (PNG Energy) and that company's wholly owned subsidiary
Gini Energy Limited (Gini Energy). Subsequently, in May 2012, Gini
Energy was granted a further on-shore licence, PPL 405, by the
government of Papua New Guinea.
On 26 March 2012, the Company entered transformational
agreements with CNOOC Australia Limited (CNOOC), a subsidiary of
CNOOC Limited, the Chinese multi-national oil and gas company
listed on the New York and Hong Kong Stock Exchanges, whereby CNOOC
subscribed for a 70% equity interest in PNG Energy and UMC Energy
retained a 30% equity interest.
Pursuant to the agreements, and in consideration for the share
subscription, CNOOC will be responsible for funding all exploration
and appraisal expenditure in respect of the PPLs up to commercial
development. Such expenditure will be repaid to CNOOC out of
production revenues and off take of oil and gas once the assets of
Gini Energy enter production, should such production occur. If
exploration and appraisal work indicates the probable existence of
commercial reservoirs of oil or gas in any part of the PPLs at the
end of the exploration phase, the parties must each finance their
pro-rata share of all expenditure required in respect of the
development plan, either themselves or by procuring sufficient
finance from a third party.
In addition, the agreements entitle CNOOC to appoint two
directors to the boards of each of PNG Energy and Gini Energy, with
the Company entitled to appoint one director to each board. With
effect from entering the agreements, the PNG Energy Ltd group
became an associate of the Company, accounted for under the equity
method.
2D seismic acquisition and four initial wells are planned during
the first four year term of the permits, two wells on-shore and two
off-shore, at an estimated cost for the work programmes of circa
$450 million. It is also likely that 3D seismic will be acquired
over the most prospective leads in the offshore permits prior to
drilling. (Note that this anticipated expenditure is a UMC Energy
management estimate which has not yet been budgeted or approved by
the PNG Energy Ltd Group; the expenditure actually incurred in due
course would form part of CNOOC's non-recourse loan).
The onshore PPLs are adjacent to existing oil and new gas
pipeline infrastructure recently built for PNG LNG Project - a $19
billion investment to supply major LNG customers in Asia, and which
is anticipated to commence production in 2014.
Since March 2012, CNOOC has been conducting various technical
studies and has been mobilising to conduct on-site exploration
activities, including procurement of existing data and new seismic
acquisition.
Separately, UMC Energy has engaged 3D-GEO Pty Limited
("3D-GEO"), a Melbourne based firm of consulting petroleum
engineers, considered to be highly experienced with regard to Papua
New Guinea petroleum structural and geological interpretation, to
review the available geological data, identify leads and prospects,
quantify any contingent resources and prospective resources and
provide technical advice in regard to the permits.
In relation to PPL 378 (west), the Paua-1 well drilled in 1996
by BP is a declared discovery with gas encountered in the Toro
sands and oil recovered from a 33 metre gross oil column in the
Iagifu sands.
Independent expert assessment of the well logs, seismic data and
geological structural modelling has provided the following
estimated Contingent Resource and Prospective Resource values,
prepared in accordance with Petroleum Resources Management System
(PRMS) sponsored by the Society of Petroleum Engineers.
The following table presents the recoverable Contingent Resource
values for the Paua Discovery.
All values GROSS NET ATTRIBUTABLE TO UMC RISK
in MMbbls* ENERGY FACTOR
or BCF*
------------- --------------------------------------------- --------------------------------------------- ---------
PPL 378 Low Best Low Best
Operator: Estimate Estimate High Estimate Estimate Estimate High Estimate
CNOOC 1C 2C 1C 2C
------------- ----------- ----------- ------------------- ----------- ----------- ------------------- ---------
3C(a) 3C(b) 3C(a) 3C(b)
------------- ----------- ----------- --------- -------- ----------- ----------- --------- -------- ---------
Oil
Contingent
Resource 0.44 11.28 67.96 6 0.13 3.38 20.4 1.8 .5
------------- ----------- ----------- --------- -------- ----------- ----------- --------- -------- ---------
Total for
Oil 0.44 11.28 67.96 6 0.13 3.38 20.4 1.8
------------- ----------- ----------- --------- -------- ----------- ----------- --------- -------- ---------
Gas
Contingent
Resource 20 5.6 336.8 793.6 6 1.7 101 238 .5
------------- ----------- ----------- --------- -------- ----------- ----------- --------- -------- ---------
Total for
Gas 20 5.6 336.8 793.6 6 1.7 101 238
------------- ----------- ----------- --------- -------- ----------- ----------- --------- -------- ---------
*Note: MMbbls = million barrels of recoverable oil, BCF =
billion standard cubic feet of recoverable gas
The 1C and 2C cases only consider hydrocarbon resources in the
forelimb of the structure. It would be unusual for only the
forelimb to be charged as depicted, but as the Paua-1 well only
intersected this part of the Paua structure accordingly the
estimates are based on this actual intersection data. The 3C cases
consider charge in the backlimb of the structure, either gas or
oil.
The prospectivity review of PPL378 (west) also identified Poro,
an untested structure. Probabilistic volumes of potential resources
calculated by Monte Carlo simulations have provided the following
values within the permit:
PPL378 (west) Recoverable Oil (MMbbls) Recoverable Gas (Bcf)
Poro Lead
---------------- ------------------------------ ---------------------------
Reservoir P90 P50 P10 P90 P50 P10
---------------- --------- -------- --------- ------- -------- --------
Toro & Iagifu 14 127 1150 31.7 238.5 1796.8
---------------- --------- -------- --------- ------- -------- --------
The prospectivity review of PPL378 (east) identified two
untested structures, Lead A and Lead B. Probabilistic volumes of
potential resources calculated by Monte Carlo simulations have
provided the following values within the permit:
PPL378 (east) Recoverable Oil (MMbbls) Recoverable Gas (Bcf)
Lead A
---------------- ------------------------------ ---------------------------
Reservoir P90 P50 P10 P90 P50 P10
---------------- -------- --------- --------- -------- ------- --------
Toro & Iagifu 69.9 320.0 1465.3 131.4 484.4 1819.8
---------------- -------- --------- --------- -------- ------- --------
PPL378 (east) Recoverable Oil (MMbbls) Recoverable Gas (Bcf)
Lead B
---------------- ------------------------------ ---------------------------
Reservoir P90 P50 P10 P90 P50 P10
---------------- -------- --------- --------- -------- ------- --------
Toro & Iagifu 29.9 139.5 655.7 60.9 218.5 797.4
---------------- -------- --------- --------- -------- ------- --------
In relation to PPL 405, the Wasuma-1 well drilled in 2010 by Oil
Search Ltd encountered a 4.7 metre oil column in the Iagifu B sands
within the Wasuma structure. Independent analysis of the well log
and seismic data combined with geological modelling suggests the
well may have been drilled in a poor location and the structure has
an estimated potential for a significant recoverable oil
Prospective Resource ranging from 7 MMbbls (P90) to 190 MMbbls
(P10), with 30% attributable to UMC as detailed below. The Wasuma
structure is located within the PPL405 permit held by Gini.
All values GROSS NET ATTRIBUTABLE TO RISK FACTOR
in MMbbls* UMC ENERGY
-------------- ----------------------------------------- -------------------------------------------- -------------
PPL 405 Low Best High Low Best High
Operator: Estimate Estimate Estimate Estimate Estimate Estimate
CNOOC 1C 2C 3C 1C 2C 3C
-------------- ------------- ------------ ------------ ------------- ------------- -------------- -------------
Oil
Prospective
Resource 7.21 37.34 193.28 2.16 11.20 57.98 .25
-------------- ------------- ------------ ------------ ------------- ------------- -------------- -------------
Total for
Oil 7.21 37.34 193.28 2.16 11.20 57.98
-------------- ------------- ------------ ------------ ------------- ------------- -------------- -------------
The prospectivity review of PPL405 has also identified three
untested structures, Lead C, Warra Deep and Lead D. Probabilistic
volumes of potential resources calculated by Monte Carlo
simulations have provided the following values of these three
untested leads within the permit:
PPL405 Recoverable Oil (MMbbls) Recoverable Gas (Bcf)
Lead C
---------------- ------------------------------ ---------------------------
Reservoir P90 P50 P10 P90 P50 P10
---------------- -------- --------- --------- ------- -------- --------
Toro & Iagifu 17.1 108.9 777.4 57.0 331.5 2189.3
---------------- -------- --------- --------- ------- -------- --------
PPL405 Recoverable Oil (MMbbls) Recoverable Gas (Bcf)
Warra Deep
Lead
---------------- ------------------------------ ---------------------------
Reservoir P90 P50 P10 P90 P50 P10
---------------- -------- -------- ---------- ------- -------- --------
Toro & Iagifu 9.1 54.1 331.5 27.5 140.6 747.4
---------------- -------- -------- ---------- ------- -------- --------
PPL405 Recoverable Oil (MMbbls) Recoverable Gas (Bcf)
Lead D
---------------- ------------------------------ ---------------------------
Reservoir P90 P50 P10 P90 P50 P10
---------------- -------- -------- ---------- ------- -------- --------
Toro & Iagifu 5.5 44.8 383.1 21.7 160.3 1237.2
---------------- -------- -------- ---------- ------- -------- --------
Additional subsurface activities are presently being planned by
the joint venture parties to further reduce uncertainties and
develop the identified leads into drillable prospects. This
includes selective reprocessing of existing 2D seismic data, new 2D
seismic acquisition, detailed reviews of structural modelling and
full reservoir engineering reviews for each lead.
3D-GEO was engaged to conduct a review of the offshore permits,
including interpretation of the 2D data, regional reservoir and
source rock studies, source generation timing and hydrocarbon
migration studies utilizing proprietary Genesis and Trinity
software packages to model the probability of hydrocarbon charge
within trap timing, and the development of a leads inventory.
Lead mapping of the offshore permits has identified a number of
potentially large structures, including Lead H in PPL375, where a
phase reversal (or soft kick) was observed in the 2D seismic data
in the interpreted Cretaceous reservoir horizon. This observation
is often regarded as a direct
hydrocarbon indicator, or DHI, which may be indicative of a gas
cap. Lead H is a fault block closure with up to 135 km(2) of
closure.
A number of leads have been identified across the two permits,
many with closure at both Cretaceous and Miocene reservoir
horizons. The seismic grid is presently too sparse across the
offshore permits to have sufficient confidence in the structural
mapping to elevate any of the leads to prospect status at this
time. However, several large structures have been mapped with
recoverable gas volumes within the permits estimated in the multi
Tcf range (a mean of over 10Tcf for the five largest leads).
Un-risked, probabilistic volume calculations of the potential
resources have provided the following recoverable gas values of
these five highest ranked untested leads within the permit:
LEAD P90 P50 Mean P10
-------------------------- ------- ------- -------- -------
(Recoverable Gas: Bcf)
-------------------------- -----------------------------------
Lead H Structure in PPL
375 Totals 375 1,490 1,825 3,690
-------------------------- ------- ------- -------- -------
Lead A Structure Totals 570 1,920 2,215 4,235
-------------------------- ------- ------- -------- -------
Lead B Structure Totals 1,050 3,750 4,425 8,640
-------------------------- ------- ------- -------- -------
Lead G Structure Totals 520 1,680 1,970 3,785
-------------------------- ------- ------- -------- -------
Lead C Structure Totals 105 370 440 850
-------------------------- ------- ------- -------- -------
Total 10,875
-------------------------- ------- ------- -------- -------
De-risking of these leads will require acquisition of new
seismic data and further interpretation and mapping. The
development of the leads inventory was required so that the 2D
seismic survey planned for 2013 can be optimally designed.
Madagascar Madagascar continues to experience a period of
political upheaval and uncertainty. Despite the fact that the
Company has not, in any way, been negatively affected by these
events, it has resolved to take a cautious approach to exploration
and accordingly has not conducted exploration activities during the
2012 financial year. The Company continues to monitor the
situation. Given these circumstances, the Directors have resolved
that it is appropriate to recognise an impairment adjustment of
GBP1,925,000 (31 December 2011: GBPnil) against the carrying value
of the intangible asset.
Financing The Company remains dependent on loan funds being made
available to it by Natasa Mining Ltd to meet its working capital
and other requirements.
C Kyriakou
Chairman
CONSOLIDATED INCOME STATEMENT
FOR THE YEAR ENDED 31 DECEMBER 2012
Year Year
Ended Ended
31 December 2012 31 December 2011
GBP GBP
Administrative expenses (1,610,425) (569,850)
Impairment charge (1,925,000) -
Gain on dilution of subsidiary 93,178 -
Share of net result of associates (8,307) -
_________ ________
Loss from operations (3,450,554) (569,850)
Finance costs (646,165) (191,312)
_________ ________
Loss before taxation (4,096,719) (761,162)
Income tax expense - -
Loss for the year (4,096,719) (761,162)
Attributable to:
Equity holders of the parent (3,918,188) (542,635)
Non-controlling interest (178,531) (218,527)
_________ ________
(4,096,719) (761,162)
Loss per share in pence -
including
share of associate's results
Basic (0.81) (0.22)
Loss per share in pence -
excluding
share of associate's results
Basic (0.81) (0.22)
CONSOLIDATED STATEMENT OF COMPREHENSIVE INCOME
FOR THE YEAR ENDED 31 DECEMBER 2012
Year Year
Ended Ended
31 December 2012 31 December 2011
GBP GBP
Loss for the year (4,096,719) (761,162)
Foreign currency translation
differences
for foreign operations 1,623 4,781
_____ _____
Other comprehensive income for
the year 1,623 4,781
________ ________
Total comprehensive expense for
the year (4,095,096) (756,381)
Attributable to:
Equity holders of the parent (3,715,096) (540,234)
Non-controlling interest (380,000) (216,147)
________ ________
Total comprehensive expense for
the year (4,095,096) (756,381)
CONSOLIDATED STATEMENT OF FINANCIAL POSITION
AS AT 31 DECEMBER 2012
31 December 2012 31 December 2011
ASSETS GBP GBP
Non-current assets
Intangible assets - 15,314,346
Property, plant and equipment 626 1,156
Investment in group undertaking 16,342,975 -
_________ _________
Total non-current assets 16,343,601 15,315,502
Current assets
Taxation receivable 2,406 897
Trade and other receivables 336,069 31,035
Cash and cash equivalents 77,708 130,909
Total current assets 416,183 162,841
_________ _________
TOTAL ASSETS 16,759,784 15,478,343
EQUITY AND LIABILITIES
Current liabilities
Loans 6,219,105 1,715,124
Trade and other payables 62,410 80,874
Total current liabilities 6,281,515 1,795,998
________ ________
Total liabilities 6,281,515 1,795,998
Equity
Share capital 2,422,224 2,422,224
Share premium account 17,044,183 17,044,183
Share based payments reserve 901,999 10,979
Foreign currency translation
reserve 144,477 157,532
Accumulated loss (9,654,614) (5,736,426)
Equity attributable to equity
holders of the parent 10,858,269 13,898,492
Non-controlling Interest (380,000) (216,147)
Total equity 10,478,269 13,682,345
_________ _________
TOTAL EQUITY AND LIABILITIES 16,759,784 15,478,343
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
FOR THE YEAR ENDED 31 DECEMBER 2012
Share Foreign
Based Currency Non-
Share Share Payment Translation Accumulated Controlling
Capital Premium Reserve Reserve Loss Interest Total
GBP GBP GBP GBP GBP GBP GBP
1 January
2012 2,422,224 17,044,183 10,979 157,532 (5,736,426) (216,147) 13,682,345
Total
comprehensive
expense for
the year:
Loss - - - - (3,918,188) (178,531) (4,096,719)
Total other
comprehensive
income /
(expense) - - - (13,055) - 14,678 1,623
Total
comprehensive
expense for
the year - - - (13,055) (3,918,188) (163,853) (4,095,096)
Share options
granted in
year - - 891,020 - - - 891,020
________ _______ ______ _______ _________ ________ ________
31 December
2012 2,422,224 17,044,183 901,999 144,477 (9,654,614) (380,000) 10,478,269
CONSOLIDATED STATEMENT OF CHANGES IN EQUITY
FOR THE YEAR ENDED 31 DECEMBER 2012
Share Foreign
Based Currency Non-
Share Share Payment Translation Accumulated Controlling
Capital Premium Reserve Reserve Loss Interest Total
GBP GBP GBP GBP GBP GBP GBP
1 January
2011 1,222,223 4,756,183 104,028 155,131 (5,286,840) - 950,725
Total
comprehensive
expense for
the year:
Loss - - - - (542,635) (218,527) (761,162)
Total other
comprehensive
income /
(expense) - - - - - 2,380 4,781
Total
comprehensive
income/
(expense)
for the year - - - 2,401 (542,635) (216,147) (756,381)
Share issue
on
acquisition
of investment 1,200,001 12,288,000 - - - - 13,488,001
Total shares
issued on
acquisition 1,200,001 12,288,000 - - - - 13,488,001
Reserve
transfer - - (93,049) - 93,049 - -
________ _______ ______ _______ _________ ________ ________
31 December
2011 2,422,224 17,044,183 10,979 157,532 (5,736,426) (216,147) 13,682,345
CONSOLIDATED STATEMENT OF CASH FLOWS
FOR THE YEAR ENDED 31 DECEMBER 2012
Year Year
Ended Ended
31 December
2012 31 December 2011
GBP GBP
Net cash outflow from operating
activities (1,154,126) (540,453)
Investing activities
Tangible fixed assets additions (1,002) -
Investments in group undertaking (2,863,284) -
Cash acquired on acquisition of
subsidiary - 89,903
_________ _______
Net cash outflow from investing
activities (2,864,286) 89,903
Financing activities
Loans 4,611,376 749,399
Loan interest & charges (646,165) (191,312)
_______ _______
Net cash inflow from financing
activities 3,965,211 558,087
Net cash increase in cash and cash
equivalents (53,201) 107,537
Cash and cash equivalents at beginning
of year 130,909 23,372
Cash and cash equivalents at end
of year 77,708 130,909
NOTES TO THE FINANCIAL STATEMENTS
FOR THE YEAR ENDED 31 DECEMBER 2012
1. General information
UMC Energy Plc is a company incorporated in England and Wales.
The Company's registered office is First Floor, 10 Dover Street,
London, W1S 4LQ. The registration number of the Company is
05331770.
The principal activity of the Group is the investment in, and
exploration and development of natural resources projects,
specifically in a petroleum exploration project in Papua New Guinea
and a uranium exploration project in Madagascar.
The Group's principal activity is carried out in US dollars. The
financial statements are presented in pounds sterling as this is
the currency of the country (the UK) where the Company is
incorporated and its ordinary shares admitted for trading.
2. Loss per share
Including share of associate's results
Loss per share has been calculated by dividing the loss for the
year after taxation, including share of associate's results
attributable to the equity holders of the parent company of
GBP3,918,188 (31 December 2011: GBP542,635) by the weighted average
number of shares in issue at the year end of 484,444,763 (31
December 2011: 245,759,831).
Excluding share of associate's results
Loss per share has been calculated by dividing the loss for the
year after taxation, excluding share of associate's results
including share of associate's results, attributable to the equity
holders of the parent company of GBP3,909,881 (31 December 2011:
GBP542,635) by the weighted average number of shares in issue at
the year end of 484,444,763 (31 December 2011: 245,759,831).
3. Intangible assets - Group
31 December 2012 31 December 2011
Development expenditure GBP GBP
Cost
Balance brought forward 1,596,346 1,596,346
Additions - -
Translation reserve - -
Balance carried forward 1,596,346 1,596,346
Exploration licences
Balance brought forward 17,501,372 4,112,026
Additions at cost - 13,389,346
Transfer of assets on dilution (13,389,346) -
of subsidiary
Balance carried forward 4,112,026 17,501,372
Impairment
Balance brought forward 3,783,372 3,783,372
Charge in year 1,925,000 -
Translation reserve - -
Balance carried forward 5,708,372 3,783,372
_________ _________
Total - 15,314,346
The development expenditure relates to development of the
uranium exploration project in the Morondava basin of
Madagascar.
The licences relate to uranium exploration licences in the
Morondava basin and the petroleum exploration project in Papua New
Guinea.
The Morondava uranium project has yet to reach a stage of
development where a determination of the technical feasibility or
commercial viability can be assessed. In addition, as Madagascar is
presently experiencing a period of political upheaval and
uncertainty, the Company has resolved to take a cautious approach
to exploration and accordingly has not conducted exploration
activities during the current financial year and does not expect to
undertake any material exploration activities in Madagascar whilst
this period of uncertainty prevails. In these circumstances,
whether there is any indication that the asset has been impaired is
a matter of judgement, as is the determination of the quantum of
any required impairment adjustment. The directors have resolved
that it is not appropriate to capitalise any further expenditure on
the intangible asset until circumstances change. The Directors have
used their experience to conclude that an impairment adjustment of
GBP1,925,000 is required in the current year (31 December 2011: GBP
nil).
In March 2012, the PNG Energy Group ceased to be controlled by
the company and therefore, the exploration licences were
transferred on dilution of the subsidiary. See note 11 for further
information.
4. Investments in associated undertaking
On 26 March 2012, the Company entered agreements with CNOOC
Australia Limited ("CNOOC"), a subsidiary of CNOOC Limited, the
Chinese multi-national oil and gas company listed on the New York
and Hong Kong Stock Exchanges, whereby CNOOC subscribed for a 70%
equity interest in PNG Energy Limited with UMC Energy retaining a
30% equity interest.
As a result of this transaction, in March 2012 the PNG Energy
group ceased to be controlled by the Company and became an equity
accounted associate.
On 4 December 2012, the Company entered a deed with UMC Energy
Ltd (incorporated in the British Virgin Islands (BVI)), an indirect
wholly owned subsidiary of the Company, whereby it transferred its
shares in PNG Energy Ltd to UMC Energy Ltd. At the same time, the
company assigned the intellectual property rights pertaining to the
assets owned by PNG Energy Ltd to UMC Energy Ltd.
As a result of this transaction, since December 2012 the Group
has an equity holding in the following associate undertaking:
PNG Energy
Group
Direct -
Indirect 30%
Total 30%
The country of incorporation of the associate undertaking is the
British Virgin Islands and the principal place of business is Papua
New Guinea.
31 December 2012 31 December 2011
Group GBP GBP
Cost
Balance brought forward - -
Additions in the year 16,351,282 -
Share of associated undertaking's (8,307) -
results
Balance carried forward 16,342,975 -
Amortisation/impairment
Balance brought forward - -
Impairment charge - -
Balance carried forward - -
Net Book Value 16,342,975 -
The Papua New Guinea petroleum project has yet to reach a stage
of development where a determination of the technical feasibility
or commercial viability can be assessed. In these circumstances,
whether there is any indication that the asset has been impaired is
a matter of judgment, as is the determination of the quantum of any
required impairment adjustment. The Directors have used their
experience to conclude that no impairment adjustment is required in
the current year.
Summarised results of the associate undertaking, PNG Energy
Group, as translated into sterling are as follows:
Year ended 31 December Year ended 31
2012 December 2011
GBP GBP
Revenue 1,980 949
Loss for the period 91,771 28,745
Total assets 91,504 98,887
Total liabilities 266,739 127,600
5. Post balance sheet events
Since 1 January 2013, the Company has advanced a further
US$237,939 (GBP157,226) to Uramad SA, for use on uranium
exploration project development activities.
Since 1 January 2013, the Company has borrowed a further
A$551,121 (GBP376,177) from Natasa Mining Ltd, for working capital
purposes.
6. Publication of non statutory accounts
The financial information set out in this announcement does not
constitute statutory accounts.
The financial information for the year ended 31 December 2012
has been extracted from the Group's statutory financial statements
to that date upon which the auditors' opinion is modified on the
basis of an emphasis of matter opinion on going concern and
significant uncertainty.
7. Annual Report and Annual General Meeting
The Annual Report for the year ended 31 December 2012 will be
available from the Company's website www.umc-energy.com today.
The annual general meeting of the Company has been convened for
10.00 a.m. on 26 June 2013 at First Floor, 10 Dover Street London
W1S 4LQ
Enquiries:
Chrisilios Kyriakou, Chairman
Laurence Read, Corporate Development Officer
UMC Energy Plc
Telephone: +44(0) 20 7290 3102
Angela Hallett/ James Spinney
Strand Hanson Limited
Telephone: +44 (0) 20 7409 3494
Philip Haydn-Slater/Paul Dudley
HD Capital Partners LLP
Telephone: +44 (0) 20 3551 4870
Jerry Keen / Stephane Auton / Patrick Castle
Shore Capital Stockbrokers Limited
Joint Broker
Telephone: +44 (0)20 7408 4090
This information is provided by RNS
The company news service from the London Stock Exchange
END
FR KMGZKMDLGFZM
Natasa Min (LSE:NSN)
Historical Stock Chart
From May 2024 to Jun 2024
Natasa Min (LSE:NSN)
Historical Stock Chart
From Jun 2023 to Jun 2024
