TIDMOEX
RNS Number : 5811D
Oilex Ltd
30 January 2015
Summary
CAMBAY PSC, ONSHORE GUJARAT, INDIA
-- Successfully finished the Cambay-77H production test
-- Delivered the Proof of Concept, demonstrating the Cambay
Field can be commercially developed
-- Initial production profiles indicate robust economics,
despite the recent sharp drop in oil prices
-- Government of India approve the grant of an extension of the
Petroleum Mining Lease for the Cambay Field to 22 September
2019
BHANDUT FIELD, ONSHORE GUJARAT, INDIA
-- Endorsement from the Government of India for the sale of gas
from the Bhandut-3 well, located within the Bhandut Field
-- Commenced establishing production facilities for Bhandut-3,
including a compressed natural gas (CNG) loading facility that will
enable CNG "bullet" trucks to be loaded at site for transportation
of the gas to end users
STP-EPA-0131 (Formerly SPA 17 AO), ONSHORE CANNING BASIN,
WESTERN AUSTRALIA
-- WA Department of Mines and Petroleum (DMP) approval of
Oilex's application to convert the Special Prospecting Authority
(SPA 17 AO) to Exploration Permit Application
-- The newly acquired survey data with 2D seismic, regional
gravity, magnetic, surface geological and well data, confirms
Oilex's structural model of the Wallal Graben and its extension
into STP-EPA-0131
CORPORATE
-- Completion of Share Purchase Plan raising a total of A$2.5 million before costs
-- On 28 January 2015 Oilex announced the appointment of Mr Jeffrey D Auld as an independent Non-Executive Director. The appointment of a UK based independent non-executive director, with significant experience in the London capital markets and upstream oil and gas industry, is in line with the Company's decision to appoint additional directors to achieve the right mix of skills, experience and diversity which reflects the Company's strategy and increase the balance of independence on the Board.
Operations review
HEALTH, SAFETY, SECURITY AND ENVIRONMENT
No Lost Time Incident recorded during the quarter.
TOTAL NET OIL PRODUCTION - 849 BBLS for the quarter
CAMBAY FIELD, GUJARAT, INDIA
(Oilex: Operator and 45% interest)
The Cambay Field delivered net oil production of 849 barrels for
the three months to 31 December, a decrease of 43% on the previous
quarter due to the shut-in of Cambay -77H after finishing the
production test.
Significant progress was achieved during the quarter on the
Cambay Field development. The Company successfully completed the
Cambay-77H production test. The test was focused on acquiring long
term performance data which is essential for assessment of
reservoir properties and will supplement surface data collected
during flowback. A 5 day shut-in period preceded the test to allow
the well to stabilise after 85 days of flowback production.
The formal test had two distinct sections:
-- 300 hour (12.5 days) flow period, where the well flowed on a
constant choke size after achieving stable flow soon after opening;
and
-- 300 hour shut-in period, where data continues to be recorded and monitored.
The production test is the final major field activity for
Cambay-77H. Oilex will now focus on putting Cambay-77H into
production as soon as possible, as well as incorporating the proof
of concept outcomes into the planning for the next drilling
campaign.
Delivering the Proof of Concept
Proof of Concept objectives are critical to demonstrating that
the Cambay Field can be commercially developed using multi-stage
fracture treatments (fracs) in horizontal wells. Key objectives
achieved include:
-- Efficient drilling operations demonstrating the repeatability of targeting the Y zone
-- Y zone reservoir properties are laterally consistent, having
variability within expectations
-- Successful completion of 8 fracture treatments
-- Successfully demonstrated "Plug and Perf" completion technique in India
-- First horizontal well in the Cambay Basin with multiple
fracture treatments to achieve flowback
-- Flowback data used to calibrate horizontal well model for the first time
-- Future well designs may have wider frac spacing, leading to significant cost savings
The Cambay Field is expected to have robust economics, despite
the recent sharp drop in oil prices. Initial production profiles
modelled by the Company for the next three horizontal wells using
the Cambay-77H data provide the following indicative value metrics
per well:
Well configuration Product 10 Yr Assumed Payback NPV(10) /BOE
slate recovery (Months) US$
(BOE)
--------------------- ----------- -------------- ---------- -------------
700m lateral with 9
fracs Gas 531,000 48 $1
--------------------- ----------- -------------- ---------- -------------
700m lateral with 9
fracs Gas + Oil 680,000 22 $15
--------------------- ----------- -------------- ---------- -------------
1,400m lateral with Gas + Oil >1,000,000 12 >$20
18 fracs
--------------------- ----------- -------------- ---------- -------------
The above modelling assumes a US$70 / Bbl oil and US$8 / MSCF
gas price. The NPV calculation assumes utilisation of existing tax
losses. Full field economics will be assessed after completion of
the engineering studies, including determining the appropriate
throughput rate for gas processing facilities. A well with 700m
lateral and 9 fracs compares favourably with Oilex's previous
commercial assessment for Cambay.
The "700m gas only" well shows the economic impact of no revenue
from concurrent oil production. Initial modelling indicates that
even a gas well with no associated liquids is economic. A further
positive from analysis of the Cambay-77H data is the significantly
higher oil gas ratio (OGR), which has a material positive impact on
the revenue stream from future Cambay horizontal wells.
The well economics are underpinned by the significant excess
demand over supply within the Indian domestic economy, which is
forecast to grow. According to the US Energy Information
Agency:
-- India is a significant importer of crude oil, as the
country's demand growth continues to outstrip domestic supply
growth; and
-- Natural gas serves as a substitute for coal in electricity
generation and fertiliser production in India. The country began
importing liquefied natural gas in 2004 and increasingly relies on
imports to meet domestic natural gas needs.
Oilex has concluded two gas sale agreements (GSA) to date. GSAs
are conducted via a bid system, with buyers submitting offers to
purchase via a tender process. Given the demand for gas by nearby
industrial users, strong pricing is secured, above the floor price
recently established by the Indian Government.
Existing industry located within 15km of the Cambay Field also
means very low capital cost is associated with sales of gas to the
local market and the tie-in to existing gas transmission pipeline
network. The network has excess capacity for additional gas that
can be used for gas from the Cambay Field.
Subsequent to the reporting period:
Oilex has received approval from the Government of India for the
grant of an extension of the Petroleum Mining Lease (PML) for the
Cambay Field to 22 September 2019.
The Government of India has endorsed the sale of gas from
Cambay-77H. Oilex is pleased by the Indian Government's ongoing
support for the development of the Cambay Field.
Following the completion of the production test for Cambay-77H
and to ensure Oilex can execute the next phase of the development
at Cambay, Oilex has appointed Mr Jayant R Sethi, as Head of India
Assets. Mr Sethi will report directly to the Managing Director and
have overall responsibility for delivery of value from the Indian
business including the execution of the forthcoming drilling
campaign at Cambay. Mr Sethi has over 30 years of experience in Oil
& Gas Upstream industry, including with ONGC and Cairn India
before joining Oilex.
BHANDUT FIELD, GUJARAT, INDIA
(Oilex: Operator and 40% interest)
During the quarter Oilex received endorsement from the
Government of India for the sale of gas from the Bhandut-3 well,
located within the Bhandut Field. This is a critical milestone for
returning the field to production, supplying gas to the local
market and generating positive cash flow for the Company from a
previously idle asset.
Now that endorsement of the gas sales agreement has been
received, the Bhandut Joint Venture will proceed to establish the
appropriate production facilities for Bhandut-3. This will include
a compressed natural gas (CNG) loading facility that will enable
CNG "bullet" trucks to be loaded at site for transportation of the
gas to end users. Bhandut-3 gas is "lean" and therefore no material
condensate production is expected.
As previously announced on 20 August 2013, Bhandut-3 flowed at a
maximum rate of 6.5MMscfd through a 10mm choke with a flowing
tubing head pressure of 1,190 psia during an isochronal test. The
test confirmed the reservoir sand has a permeability of 124mD,
making it a conventional reservoir. It is planned to deliver
approximately 0.5-1MMscfd from the Bhandut-3 well. The Company
anticipates the cost of the production facilities payback in 7
months from commencement of production based upon the contracted
gas price.
SABARMATI FIELD, GUJARAT, INDIA
(Oilex: Operator and 40% interest)
During the quarter the Joint Venture finalised cost estimates
for the plug and abandonment of the Sabarmati-1 well and commenced
the process to obtain Government of India approval to relinquish
the Sabarmati Field. Plug and abandonment activities are expected
to be completed in Q1 2015. As part of the relinquishment of the
Sabarmati Field, Oilex plans to transfer equipment from Sabarmati
EPS facility for possible future use at Cambay field.
STP-EPA-0131 (Formerly SPA 17 AO) Wallal Graben, CANNING BASIN,
WESTERN AUSTRALIA
(Oilex: Operator and 100% interest)
During the quarter the WA Department of Mines and Petroleum
(DMP) approved Oilex's application to convert the Special
Prospecting Authority (SPA) (SPA 17 AO) to Exploration Permit
Application (STP-EPA-0131).
The committed work program for SPA 17 AO was fulfilled by the
acquisition, processing and interpretation of a 4,060 line km
gravity gradiometry/magnetic survey (Survey). Under the terms of
the SPA, Oilex had exclusive rights to negotiate a formal
exploration permit with the Government of Western Australia. The
terms of the SPA state that the area retained as an exploration
permit from within the SPA is limited to 30-50% of the total
area.
The final report for SPA 17 AO incorporating the newly acquired
Survey data with 2D seismic, regional gravity, magnetic, surface
geological and well data, confirmed Oilex's structural model of the
Wallal Graben and its extension into SPA 17 AO.
The committed work program negotiated for the exploration permit
comprises an airborne gravity/magnetic survey designed to "infill"
the recently acquired Survey. This will facilitate a much higher
resolution image and interpretation of the Wallal Graben extension.
The retained area (5,443 km(2) ) to be converted to STP-EPA-0131
encompasses the entire Wallal Graben extension and represents 48%
of the original SPA area (Figure 1).
The graben is present in Oilex's three, 100%-owned, exploration
areas encompassing approximately 11,900 km(2) (3 million acres).
The acreage is in a unique position in the Canning Basin as it is
adjacent to many world class mining projects in the Pilbara region.
This activity has led to the development of a significant amount of
infrastructure in the area with the Great Northern Highway,
numerous sealed roads, good quality graded roads and multiple
airstrips being present within the Oilex acreage. The Telfer Gas
pipeline traverses STP-EPA-0131 and any future pipelines from the
Canning Basin to the main export terminals at Port Hedland and
Karratha would have to pass through the acreage (Figure 2).
Farm-out activities are in progress and the new data and
commitment program has been incorporated into the discussions with
prospective farminees. Negotiations with the Traditional Owners on
Native Title Agreement(s) applicable for all areas are nearing
completion. The regulatory process of conversion to a formal
exploration permit have commenced with the DMP.
STP-EPA-0106, STP-EPA-0107 CANNING BASIN, WESTERN AUSTRALIA
(Oilex: Operator and 100% interest)
Negotiations with Traditional Owners on Native Title agreements
are continuing. Once agreements are finalised, the regulatory
process of conversion to a formal exploration permit will
commence.
JPDA 06-103, TIMOR SEA
(Oilex: Operator and 10% interest)
In October 2014 the ANP extended the temporary suspension of the
PSC for a further 3 months to enable the completion of the ANP
legal assessment and continued discussion between the parties to
address the way forward. Subsequent to the end of the quarter, a
further extension of the temporary suspension has been granted.
WEST KAMPAR PSC, CENTRAL SUMATRA, INDONESIA
(Oilex: 45% interest and further 22.5% secured*)
A Court approved Scheme of Arrangement has been approved by
creditors to repay acknowledged creditors over a 10 year period.
Oilex is pursuing enforcement of the Arbitration Award.
NEW OPPORTUNITIES
No work completed during the quarter.
CORPORATE
During the quarter the Company raised $2.5 million before costs
via a Share Purchase Plan which closed on 16 December 2014. At the
end of the quarter the Company retained a cash position of $5.4
million.
Dr Bruce McCarthy retired as a Non-Executive Director at the AGM
held 18 November 2014. On 28 January 2015 Oilex announced the
appointment of Mr Jeffrey D Auld as a Non-Executive Director. The
appointment of a UK based independent non-executive director, with
significant experience in the London capital markets and upstream
oil and gas industry, is in line with the Company's decision to
appoint additional directors to achieve the right mix of skills,
experience and diversity which reflects the Company's strategy and
increase the balance of independence on the Board. Further
appointments to the Board may be made, if the Board identifies
other non-executive directors with the right mix of skills,
experience and diversity which reflects the Company's strategy and
further increases the balance of independence on the Board.
CORPORATE DETAILS
Board of Directors Share Registry (as of 2 February
2015)
Max Cozijn Non-Executive Chairman Link Market Services Limited
Central Park
Level 4
152 St. Georges Terrace
Perth, WA 6000
Telephone:
+1300 554 474
Website:
https://investorcentre.linkmarketservices.com.au
Computershare Investor Services
PLC
The Pavilions
Bridgwater Road
Bristol BS13 8AE
United Kingdom
Telephone: +44 (0) 870 703
6149
Facsimile: +44 (0) 870 703
6116
Sundeep Bhandari Non-Executive Vice
Chairman
Jeffrey Auld Non-Executive Director
Ron Miller Managing Director
Company Secretary
Chris Bath Chief Financial Officer
& Company Secretary
Stock Exchange Listing
Australian Securities Exchange
Code: OEX
AIM Market of London Stock Exchange
Code: OEX
Capital Structure as at 31 December
2014
Ordinary Shares 677,905,419
Listed Options 188,597,091
Unlisted Options 35,225,000
---------------------------------------------- --------------------------------------------------
ASSET SCHEDULE - 31 DECEMBER 2014
----------------------------------------------------------------------------------------------------
ASSET LOCATION JOINT OPERATIONS PARTIES EQUITY OPERATOR
%
--------------- -------------------- ---------------------------- ---------- -------------------
Cambay Field Cambay/ Oilex Ltd 30.0 Oilex Ltd
PSC Gujarat/
India
--------------- -------------------- -------------------
Oilex NL Holdings (India)
Limited 15.0
-------------------
Gujarat State Petroleum
Corp. Ltd 55.0
----------------------------------------------------------------- ---------- -------------------
Bhandut Cambay/ Oilex NL Holdings (India) 40.0 Oilex NL Holdings
Field PSC Gujarat/ Limited (India) Limited
India
--------------- -------------------- -------------------
Gujarat State Petroleum
Corp. Ltd 60.0
----------------------------------------------------------------- ---------- -------------------
Sabarmati Cambay/ Oilex NL Holdings (India) 40.0 Oilex NL Holdings
Field PSC Gujarat/ Limited (India) Limited
India
--------------- -------------------- -------------------
Gujarat State Petroleum
Corp. Ltd 60.0
----------------------------------------------------------------- ---------- -------------------
West Kampar Central Oilex (West Kampar) 67.5 (1) PT Sumatera
PSC Sumatra/ Limited Persada Energi
Indonesia
--------------- -------------------- -------------------
PT Sumatera Persada
Energi 32.5
----------------------------------------------------------------- ---------- -------------------
JPDA 06-103 Flamingo/ Oilex (JPDA 06-103) 10.0 Oilex (JPDA
PSC Joint Petroleum Ltd 06-103) Ltd
Development
Area/Timor-Leste
& Australia
--------------- -------------------- -------------------
Japan Energy E&P JPDA
Pty Ltd 15.0
-------------------
GSPC (JPDA) Limited 20.0
Videocon JPDA 06-103
Limited 20.0
Bharat PetroResources
JPDA Ltd 20.0
Pan Pacific Petroleum
(JPDA 06-103) Pty Ltd 15.0
----------------------------------------------------------------- ---------- -------------------
STP-EPA-0131 Canning/Western Admiral Oil Pty 100.0 Admiral Oil
(formerly Australia Pty Ltd
SPA 17 AO)
--------------- -------------------- ---------------------------- ---------- -------------------
STP-EPA-0106 Canning/Western Admiral Oil and Gas 100.0 Admiral Oil
Australia (106) Pty Ltd and Gas (106)
Pty Ltd
--------------- -------------------- ---------------------------- ---------- -------------------
STP-EPA-0107 Canning/Western Admiral Oil and Gas 100.0 Admiral Oil
Australia (107) Pty Ltd and Gas (107)
Pty Ltd
--------------- -------------------- ---------------------------- ---------- -------------------
(1) Oilex (West Kampar) Limited is entitled to have assigned an
additional 22.5% to its holding through the exercise of its rights
under a Power of Attorney granted by SPE following the failure of
SPE to repay funds due. The assignment has been provided to BPMigas
(now SKK Migas) but has not yet been approved or rejected. If Oilex
is paid the funds due it will not pursue this assignment.
LIST OF ABBREVIATIONS AND DEFINITIONS
Barrel/bbl Standard unit of measurement for all oil and condensate
production. One barrel is equal to 159 litres or
35 imperial gallons.
------------- ------------------------------------------------------------
MMBO Million standard barrels of oil or condensate
------------- ------------------------------------------------------------
MSCFD Thousand standard cubic feet (of gas) per day
------------- ------------------------------------------------------------
MMSCFD Million standard cubic feet (of gas) per day
------------- ------------------------------------------------------------
BBO Billion standard barrels of oil or condensate
------------- ------------------------------------------------------------
BCF Billion Cubic Feet of gas at standard temperature
and pressure conditions
------------- ------------------------------------------------------------
Discovered Is that quantity of petroleum that is estimated,
in place as of a given date, to be contained in known accumulations
volume prior to production
------------- ------------------------------------------------------------
Undiscovered Is that quantity of petroleum estimated, as of a
in place given date, to be contained within accumulations
volume yet to be discovered
------------- ------------------------------------------------------------
PSC Production Sharing Contract
------------- ------------------------------------------------------------
Prospective Those quantities of petroleum which are estimated,
Resources as of a given date, to be potentially recoverable
from undiscovered accumulations by application of
future development projects. Prospective Resources
have both an associated chance of discovery and
a chance of development.
------------- ------------------------------------------------------------
Contingent Those quantities of petroleum estimated, as of a
Resources given date, to be potentially recoverable from known
accumulations, but the applied project(s) are not
yet considered mature enough for commercial development
due to one or more contingencies. Contingent Resources
may include, for example, projects for which there
are currently no viable markets, or where commercial
recovery is dependent on technology under development,
or where evaluation of the accumulation is insufficient
to clearly assess commerciality.
------------- ------------------------------------------------------------
Reserves Reserves are those quantities of petroleum anticipated
to be commercially recoverable by application of
development projects to known accumulations from
a given date forward under defined conditions. Reserves
must satisfy four criteria: they must be discovered,
recoverable, commercial, and remaining (as of the
evaluation date) based on the development project(s)
applied.
------------- ------------------------------------------------------------
Qualified Petroleum Reserves and Resources Evaluator
statement
Pursuant to the requirements of Chapter 5 of the ASX Listing
Rules, the information in this report relating to petroleum
reserves and resources is based on and fairly represents
information and supporting documentation prepared by or under the
supervision of Mr. Peter Bekkers, Chief Geoscientist employed by
Oilex Ltd. Mr. Bekkers has over 17 years' experience in petroleum
geology and is a member of the Society of Petroleum Engineers and
AAPG. Mr. Bekkers meets the requirements of a qualified petroleum
reserve and resource evaluator under Chapter 5 of the ASX Listing
Rules and consents to the inclusion of this information in this
report in the form and context in which it appears. Mr. Bekkers
also meets the requirements of a qualified person under the AIM
Note for Mining, Oil and Gas Companies and consents to the
inclusion of this information in this report in the form and
context in which it appears.
Rule 5.3
Appendix 5B
Mining exploration entity quarterly report
Introduced 1/07/96. Origin: Appendix 8. Amended 1/07/97,
1/07/98, 30/09/01, 1/06/10, 17/12/10, 01/05/13.
Name of entity
OILEX LTD
ABN Quarter ended ("current quarter")
50 078 652 632 31 December 2014
----------------- ---------------------------------
1 Consolidated statement of cash flows
----- -------------------------------------------------------------------------------------
Current quarter Year to date
$A'000 (6 months)
$A'000
---------------- -------------
Cash flows related to operating activities
Receipts from product sales and
1.1 related debtors 164 242
Payments for (a) exploration
1.2 and evaluation (1,534) (6,084)
(b) development - -
(c) production (119) (337)
(d) administration (net) (886) (1,658)
1.3 Dividends received - -
Interest and other items of a
1.4 similar nature received 9 34
1.5 Interest and other costs of finance
paid - -
1.6 Income taxes paid - -
1.7 Other - R&D Grant 358 358
------- -------------------------------------------------- ---------------- -------------
Net Operating Cash Flows (2,008) (7,445)
------- -------------------------------------------------- ---------------- -------------
Cash flows related to investing activities
Payment for purchases of:
(a) prospects - -
(b) equity investments - -
1.8 (c) other fixed assets (23) (31)
Proceeds from sale of:
(a) prospects (refer 2.2 below) - -
(b) equity investments - -
1.9 (c) other fixed assets - (1)
1.10 Loans to other entities (23) (24)
1.11 Loans repaid by other entities - -
1.12 Other - -
----------- ---------------------------------------------- ---------------- -------------
Net investing cash flows (46) (56)
----------- ---------------------------------------------- ---------------- -------------
Total operating and investing
1.13 cash flows (carried forward) (2,054) (7,501)
----------- ---------------------------------------------- ---------------- -------------
Current quarter Year to date
$A'000 (6 months)
$A'000
----- ---------------------------------- ---------------- -------------
Total operating and investing
1.13 cash flows (brought forward) (2,054) (7,501)
----- ---------------------------------- ---------------- -------------
Cash flows related to financing
activities
Proceeds from issues of shares,
1.14 options, etc (net) 2,313 5,403
Proceeds from sale of forfeited - -
1.15 shares
1.16 Proceeds from borrowings (net) - -
1.17 Repayment of borrowings - -
1.18 Dividends paid - -
1.19 Other - -
----- ---------------------------------- ---------------- -------------
Net financing cash flows 2,313 5,403
----- ---------------------------------- ---------------- -------------
Net increase (decrease) in cash
held 259 (2,098)
Cash at beginning of quarter/year
1.20 to date 5,149 7,456
Exchange rate adjustments to
1.21 item 1.20 18 68
----- ---------------------------------- ---------------- -------------
1.22 Cash at end of quarter 5,426 5,426
----- ---------------------------------- ---------------- -------------
Payments to directors of the entity and associates Current quarter
of the directors $A'000
Payments to related entities of the entity and associates
of the related entities
--------------------------------------------------------------- ----------------
Aggregate amount of payments to the parties
1.23 included in item 1.2 179
------- ------------------------------------------------------ ----------------
Aggregate amount of loans to the parties included
1.24 in item 1.10
------- ------------------------------------------------------ ----------------
1.25 Explanation necessary for an understanding of the transactions
------- ------------------------------------------------------------------------
2 Non-cash financing and investing activities
---- ------------------------------------------------------------
2.1 Details of financing and investing transactions which
have had a material effect on consolidated assets and
liabilities but did not involve cash flows
------------------------------------------------------------
N/A
---- ------------------------------------------------------------
2.2 Details of outlays made by other entities to establish
or increase their share in projects in which the reporting
entity has an interest
------------------------------------------------------------
N/A
---- ------------------------------------------------------------
3 Financing facilities available Amount available Amount used
Add notes as necessary for $A'000 $A'000
an understanding of the position.
---- -----------------------------------
3.1 Loan facilities - -
----------------- ------------
3.2 Credit standby arrangements - -
---- ----------------------------------- ----------------- ------------
4 Estimated cash outflows for next quarter $A'000
-------
4.1 Exploration and evaluation 1,500
-------
4.2 Development 580
-------
4.3 Production 150
-------
4.4 Administration 800
-------
Total 3,030
---- ----------------------------------------- -------
5 Reconciliation of cash
----- ----------------------------------------------------------------------
Reconciliation of cash at the
end of the quarter (as shown
in the consolidated statement
of cash flows) to the related Current quarter Previous quarter
items in the accounts is as follows. $A'000 $A'000
---------------------------------------- ---------------- -----------------
5.1 Cash on hand and at bank 5,286 3,058
5.2 Deposits at call 140 2,091
5.3 Bank overdraft - -
5.4 Other (provide details) - -
---------------- -----------------
Total: cash at end of quarter
(item 1.22) 5,426 5,149
----- --------------------------------- ---------------- -----------------
6 Changes in interests in mining tenements and petroleum
tenements
----
Interest Interest
Tenement Nature of interest at beginning at end
reference (note (2)) of quarter of quarter
---- ------------------------- ----------- ----------------------- -------------- ------------
6.1 Interests in
mining tenements
and petroleum Refer to Permit/Asset
tenements relinquished, Schedule in Quarterly
reduced or lapsed Report
---- ------------------------- ----------- ----------------------- -------------- ------------
6.2 Interests in
mining tenements
and petroleum Refer to Permit/Asset
tenements acquired Schedule in Quarterly
or increased Report
---- ------------------------- ----------- ----------------------- -------------- ------------
7 Issued and quoted securities at end of current quarter
Description includes rate of interest and any redemption
or conversion rights together with prices and dates.
---- ------------------------------------------------------------------------------------------
Issue price Amount paid
Total number Number quoted per security up per security
------------------------------ ------------- -------------- -------------- -----------------
7.1 Preference +securities
(description) - - - -
------------- -------------- -------------- -----------------
7.2 Changes during
quarter
(a) Increases through
issues - - - -
(b) Decreases through
returns of capital,
buy-backs, redemptions - - - -
---- ------------------------ ------------- -------------- -------------- -----------------
7.3 +Ordinary securities 677,905,419 677,905,419 Various -
------------- -------------- -------------- -----------------
7.4 Changes during
quarter
(a) Increases through
rights issue or -
placement 60,975,610 60,975,610 $0.041 -
(b) Increases through
employee performance
rights issues - - - -
(c) Increases through
issues (options
exercised) 2,000 2,000 $0.15 -
(d) Decreases through
returns of capital,
buy-backs - - - -
---- ------------------------ ------------- -------------- -------------- -----------------
Amount
Issue price paid up
Total number Number quoted per security per security
----- -------------------------- ------------- ---------------- -------------- --------------
7.5 +Convertible debt
securities (description) - - - -
------------- ---------------- -------------- --------------
7.6 Changes during quarter
(a) Increases through
issues - - - -
(b) Decreases through
securities matured,
converted - - - -
----- -------------------------- ------------- ---------------- -------------- --------------
Exercise Expiry
7.7 Options price date
------------- ---------------- -------------- --------------
(description and
conversion factor)
188,597,091 188,597,091 $0.15 07/09/2015
75,000 - $0.63 01/08/2015
3,000,000 - $0.15 17/12/2015
1,000,000 - $0.15 30/01/2016
5,000,000 - $0.25 08/03/2016
500,000 - $0.15 27/06/2016
2,000,000 - $0.15 04/11/2016
2,000,000 - $0.15 11/11/2016
3,000,000 - $0.15 05/12/2016
1,000,000 - $0.25 30/01/2017
250,000 - $0.15 10/03/2017
500,000 - $0.25 27/06/2017
1,325,000 - $0.25 05/08/2017
1,500,000 - $0.25 25/08/2017
2,000,000 - $0.25 11/11/2017
5,000,000 $0.10 22/12/2017
250,000 - $0.25 10/03/2018
1,325,000 - $0.35 05/08/2018
4,000,000 - $0.15 29/04/2019
1,500,000 - $0.35 25/08/2019
------------- ----------------
Total 223,822,091 188,597,091
----- -------------------------- ------------- ---------------- -------------- --------------
7.8 Issued during quarter 5,000,000 - $0.10 22/12/2017
----- -------------------------- --------------- -------------- -------------- --------------
Exercised during
7.9 quarter 2,000 2,000 $015 07/09/2015
----- -------------------------- --------------- -------------- -------------- --------------
7.10 Expired during quarter 8,737,500 - $0.37 10/11/2014
----- -------------------------- --------------- -------------- -------------- --------------
7.11 Debentures Nil Nil
(totals only)
----- -------------------------- --------------- --------------
7.12 Unsecured notes Nil Nil
(totals only)
----- -------------------------- --------------- -------------- -------------- --------------
Compliance statement
1 This statement has been prepared under accounting policies
which comply with accounting standards as defined in the
Corporations Act or other standards acceptable to ASX.
2 This statement does give a true and fair view of the matters disclosed.
Sign here: Date: 30 January 2015
CFO & Company Secretary
Print name: Chris Bath
This information is provided by RNS
The company news service from the London Stock Exchange
END
DRLPKKDQQBKKKDN
Synergia Energy (LSE:SYN)
Historical Stock Chart
From Mar 2024 to Apr 2024
Synergia Energy (LSE:SYN)
Historical Stock Chart
From Apr 2023 to Apr 2024
