The May 2014 GPinfo update is now
The May update includes the newly released update to the Geoscience
Australia Marine Seismic or GAMS database ...
Fields & Pipelines
This month's update includes new versions of the Fields and Pipelines
Torrens Energy has completed its off-market takeover of Phoenix Oil
and Gas, changing its name to High Peak Royalties. Torrens
acquired over 98% of Phoenix’s issued shares, with the remainder ...
Permit Updates and Changes
In the Clarence/Moreton Basin, applications PELA 127 and PELA 128 were
refused on 16/04/2014 as they are not deemed to be in the public interest ...
The May 2014 GPinfo update is now
Changes to GPinfo Reports
Several changes have been made to the Report sub-system.
Please note the
1. The Company
Permits report generates a list, sorted by company, of all permits in
which the company
has an interest, for all selected companies.
2. The Wells in Permits report generates a list, sorted by
permit, of all wells within the permit, for all selected permits.
3. Permit Details and Permits
Ownership reports operate on selections and queries based on the Permits
data layer, while Petroleum Details and Petroleum Ownership
operate on sections and queries based on the Petroleum data layer.
4. Reports are configured for display on a standard page as defined in File
> Print Setup. Permit Details, Petroleum Details, Wells
and Wells in Permits reports are all best suited to a landscape
page orientation, while the remainder best suit portrait.
5. To view and print the report, select the Preview
option. To export the report for display in third party software,
select the Export option (creates a CSV file).
Can't see the new data?
If you can't see the new GAMS 2014 layer or the updated reports list, you can
force GPinfo to apply the required structural changes by selecting View
> Options > Updates and clicking on the Update GPinfo
system layers now button.
May update includes the newly released update to the Geoscience Australia
Marine Seismic or GAMS database.
First released in December 2012 and sourced from original navigation files,
SNIP navigation files and digitised survey track maps, GAMS is an updated
collection of navigation for marine seismic surveys in Australia. The
2014 version includes recent open-file surveys and improved metadata.
Coverage of the GAMS 2014 data set.
The GAMS data set is the property of Geoscience Australia. Please click
Fields & Pipelines
This month's update includes new versions of the Fields and Pipelines layers.
New or changed fields include Acrasia, Bianchi, Cadenza, Cash/Maple, Chimmchurri,
Chorizo, Crown/Proteus, Gaius, Geographe, Hornet, Iona, Jalfrezi, Jane,
Montara, Nimrod, Nutmeg, Olympus, Paprika, Paranta, Rockhopper, Rossco,
Seamer, Smegsy, Thylacine, Utopia, Washpool, Wilga and Winchester.
Pipelines have undergone a major update across the board, but particularly in
the Surat-Bowen area of Queensland and in central New South Wales.
Our thanks to those companies who supplied and assisted in the verification
of updated data for display on the 2014 Petroleum Permits Map, and for giving
permission for its inclusion in GPinfo.
Energy has completed its off-market takeover
of Phoenix Oil and Gas, changing its name to High Peak Royalties.
Torrens acquired over 98% of Phoenix’s issued shares, with the remainder to
be compulsorily acquired in due course, and raised $6 million via a public
offer through the takeover process. High Peak expects to be reinstated on the
Australian Securities Exchange in early May, when it expects to be the
leading listed royalty company, with cash over $8 million to support the
acquisition of additional royalties. High Peak will trade under the code HPR.
(Source: High Peak Royalties announcement, 17/04/2014).
Landbridge Group Co Ltd has withdrawn its previous intention to
make an off-market takeover bid to acquire all the ordinary shares in WestSide
Corporation at $0.36 per share announced on 10/03/2014. Landbridge
Energy Australia P/L, a wholly owned subsidiary of Landbridge Group Co
Ltd, has made a new off-market takeover bid to acquire all the ordinary
shares in WestSide for $0.40 per share. Offer period ends 24/06/2014.
WestSide has rejected Landbridge Group’s second takeover offer, claiming its
latest bid did not represent fair value for the company. WestSide’s board
recommends its shareholders do not accept Landbridge’s offer. (Source:
WestSide Corporation announcement, 28/04/2014 & 05/05/2014).
Roc Oil Company and Horizon Oil Ltd have entered into a
Merger Implementation Deed under which they have agreed to merge. Horizon
shareholders will receive 0.724 Roc shares for each Horizon share they hold.
Following completion of the merger Roc shareholders will own approximately
42% of the merged entity while Horizon shareholders will own approximately
58%. The merger proposal has support of both Roc and Horizon boards. Merger
implementation is expected to take place by the end of August 2014. (Source:
Horizon Oil announcement, 29/04/2014).
Baosteel Resources Australia P/L and Aurizon Operations Ltd
together are proposing an off-market takeover for all the outstanding
ordinary shares in Aquila Resources Ltd that they do not already own.
The bidders propose to offer Aquila shareholders $3.40 for each Aquila share,
valuing the equity in Aquila at approximately $1.42 billion. The offer
is subject to a minimum 50% acceptance, FIRB approvals and other customary
conditions. (Source: Aquila Resources announcement, 05/05/2014).
INPEX has celebrated a major milestone with the first hull block of the Ichthys
LNG Project’s central processing facility laid down on the 02/04/2014. A
ceremony was held at Samsung Heavy Industries’ Geoje shipyard in South Korea
for the dry-dock based milestone. “Today’s event is another major step
towards the completion of this world-class facility by late 2015, and a major
step in the delivery of the Ichthys LNG Project – one of the world’s most
exciting and challenging developments,” Ichthys project managing director
Louis Bon said. “Successful delivery of the CPF is of great importance as it
is the centre of the project’s offshore development, with all future
production being processed through this facility.” (Source: Energy News
Santos' Gladstone LNG Project in Queensland has reached another
milestone, with the final three modules for the first train arriving and
being moved to site at Curtis Island. They are the last of the major
components needed to deliver the first liquefaction processing plant, due to
start production next year. Train 1 comprises 82 modules and has taken almost
two years to build, with US private company Bechtel acting as the main
engineering and construction contractor. (Source: Energy News Premium,
Santos has submitted a preliminary environmental assessment for the $2
billion Narrabri CSG Project to the New South Wales government. If all
goes to plan, the 70 PJ per annum project could start construction in
mid-2015 and produce first gas in late 2017. “Mobilisation and construction
of the gas processing facility and water treatment facility would occur for
two years between approximately 2016 and 2017, with wells progressively
drilled from mid-2015 over the life of the development,” consultancy GHD
said. In terms of economic benefits, the project is expected to produce enough
gas for about 50% of the state’s consumption according to the NSW Chief
Scientist and Engineer’s 2013 data, host a 25-year life span and generate
$1.6 billion in government royalties. The project aims to install and operate
up to 850 individual production wells from a maximum of 425 well sets. (Source:
Energy News Premium, 04/04/2014).
Kentz has been awarded a $615 million Ichthys contract to deliver the
electrical and instrumentation construction packages on the project’s onshore
LNG facilities. The contract scope includes the provision of services for
site wide E&I installation on a unit rate re-measurable basis for the two
process trains and utilities. It also includes additional
pre-commissioning and commissioning expertise. The contract was awarded by
JKC Australia – a joint venture between JGC Corporation, KBR and Chiyoda
Corporation. (Source: Energy News Premium, 10/04/2014).
The Papua New Guinea government has approved Horizon Oil’s proposed $300
million development of the Stanley gas-condensate field in the
country’s western province. PNG Petroleum and Energy Minister Nixon Duban has
been authorized by the National Executive Council to sign a gas agreement
with Horizon and its fellow partners. This agreement prescribes the key
rights and obligations of the state and licensees for the Stanley project.
The Stanley field will now be issued with a petroleum development license
(PDL 10) and a pipeline license (PL 10) following the formal ceremony to sign
the gas agreement. Stanley will initially be developed as a condensate
extraction project with re-injection of dry gas until a market develops, both
locally and potentially as part of a wider gas-gathering
system associated with the country’s LNG projects. The plan is to produce at a rate of
140 mmcfd of gas from two wells, which is expected to yield a condensate flow
of 400 b/d, plus potential for 40 tonnes/day of LPG. (Source: Oil &
Gas Journal, 14/04/2014).
ExxonMobil Corporation today announced the $19 billion PNG LNG Project
has started producing LNG ahead of schedule. Production from the first LNG
train will increase over the coming weeks and the first cargo is expected to
be shipped to Asian markets before mid-year. Work on the second train is also
progressing and LNG production from this unit is expected to start in the
next several weeks. (Source: ExxonMobil announcement, 28/04/2014).
The Santos operated Mt Kitty 1 in the Amadeus Basin of central
Australia has flowed gas on test from four zones in the target Heavitree
formation. Elevated gas readings were recorded upon penetration of the
formation, with a flow test at 2,144 meters initially producing 500,000 cfd,
before declining to 70,000 cfd after 10 minutes. A test at 2,156 meters
produced at a rate of 530,000 cfd, decreasing to 420,000 cfd after 18 minutes
accompanied by a gas flare and no water. Comparable flows were then recorded
at 2,185 meters and 2,252 meters. Santos said it is too early to speculate on
the commercial significance of the gas find. The joint venture is now
conducting wireline operations and detailed gas sample analysis. (Source:
Central Petroleum announcement, 15/04/2014).
AWE has advised that the Pateke 4H development well has been drilled
to a revised total depth of 4,772 meters offshore Taranaki, New Zealand. The
well will now be completed and suspended to enable production in Q1 2015,
following the installation of sub-sea flowline infrastructure and tie-back to
the Tui FPSO. The oil-bearing qualities of the targeted Kapuni F10 reservoir
have proved positive and a 6 5/8 inch slotted production liner is being run.
Further analysis is required to determine the expected recovery from Pateke
4H, but initial evaluation suggests a resource range consistent with the
pre-drill estimate of 2.5 million barrels gross. (Source: AWE
Senex Energy advises that successful appraisal and development drilling
has extended the Spitfire oil field. Results from the company’s recent
drilling in the field have confirmed the reservoir has a higher top sand
location, lower oil-water contact and greater lateral extent than previously
thought. Senex has cased and suspended four appraisal and development
wells in the Spitfire field this year, with Spitfire 4 placed on
production in April, Spitfire 6 heading for initial production testing
in early May, and Spitfire 3 and 5 heading for production not
long after. (Source: Senex Energy announcement, 07/05/2014).
Permit Updates and Changes
New South Wales
In the Clarence/Moreton Basin, applications PELA
127 and PELA 128 were refused on 16/04/2014 as they are not deemed
to be in the public interest.
In the Sydney Basin, EL 7509 expired on 07/04/2014 and now reverts
to vacant acreage.
In the Browse Basin, AC/P 41 has been renewed to 23/04/2019 over a
reduced area of 1,165 sq km. Work program is as follows -
Year 1: 325 sq km 3D seismic reprocessing, geotechnical studies
Year 2: seismic interpretation & technical studies $0.7m
Year 3: geological & geophysical studies $0.6m
Year 4: 250 sq km 3D seismic $5m
Year 5: 250 sq km 3D seismic reprocessing $1.1m
On the Ashmore Platform, AC/P 44 expired 14/04/2014. The area
reverts to vacant acreage.
On the Ashmore Platform, AC/P 45 is being renewed.
In the Vulcan Sub-basin, the year 6 work program for AC/P 51 is now -
geotechnical studies $0.15m.
Also in the Vulcan Sub-basin, AC 13-4 has been granted as AC/P 57
to Murphy Australia Oil P/L 60% and Mitsui E&P Australia P/L 40% on
14/04/2014. The licence will expire 13/04/2020. Work program is
as follows -
Year 1: 114 sq km 3D seismic reprocessing, G&G studies $0.15m
Year 2: 335 sq km 3D PSTM reprocessing, AVO studies, G&G studies
Year 3: 335 sq km 3D PSDM reprocessing, G&G studies $0.4m
Year 4: well planning, G&G studies $0.2m
Year 5: 1 well $60m
Year 6: post well studies $0.1m
In the Money Shoal Basin, NT 12-2 is now vacant acreage.
In the Petrel Sub-basin, NT 13-4 has not been re-released and reverts
to vacant acreage.
In the Bonaparte Basin, the year 5 work program for NT/P 82 is now -
geotechnical studies $0.5m.
In the Beetaloo Basin, Origin Energy Resources Ltd and Sasol Petroleum
Australia Ltd are farming in to EP 117, EP 76 and EP 98
for 35% each with Origin also assuming operatorship. Falcon will retain a 30%
interest. Origin and Sasol will each pay Falcon $20 million on completion of
the farm-in. They may reduce or surrender their interests back to Falcon only
after drilling the first five wells. The deal is still conditional on various
approvals, with Origin willing to acquire Sasol’s interest if the company
does not obtain regulatory approval for its stake.
In the Beetaloo Basin, EP 99 has been relinquished by Falcon Oil &
Gas as it was not considered core to the unconventional gas play.
Joint Petroleum Development Area
In the Joint Petroleum Development Area, JPDA
06-103 has had its suspension extended and will now expire on 15/07/2014.
No preferred tenderers were announced for PRL
2013-3-1, PLR 2013-3-2, PLR 2013-3-4 and PLR 2013-4-1 and
these areas now revert to vacant acreage.
In the Eromanga Basin, ATP 560 was renewed to 30/11/2017.
In the Bowen Basin, ATP 564 is in the process of being renewed.
In the Surat Basin, ATP 626 will undergo a partial relinquishment of
1,466 sq km.
In the Galilee Basin, ATP 666 and ATP 667 have undergone
partial relinquishments and now cover reduced areas of 1,686 sq km and 1,901
sq km respectively.
In the Nagoorin Basin, ATP 679 has been relinquished and now reverts
to vacant acreage. Overlapping production licence PL 206 and potential
commercial area application PCA 128 have both been withdrawn.
In the Surat Basin, ATP 689 has been relinquished and now reverts to
In the Styx Basin, ATP 700 has been relinquished and now reverts to
In the Capricorn Basin, ATP 716 has been relinquished and now reverts
to vacant acreage.
In the Bowen Basin, ATP 758 and ATP 759 have been renewed to
In the Surat/Bowen Basin, ATP 795 has been renewed to
31/10/2017. Work program from 01/11/2013 to 31/10/2017 is – G&G
review, assessment/selection of drilling location/ 1 CSG well (to 350m).
In the Surat/Bowen Basin, ATP 803 has undergone a partial
relinquishment and now covers a reduced area of 387 sq km.
In the Bowen Basin, ATP 804 has undergone a partial relinquishment and
now covers a reduced area of 157 sq km. Work program from 01/04/2014 to
31/03/2018 is as follows:
Year 1: G&G studies
Year 2: G&G studies
Year 3: 1 appraisal well (400m-1200m), evaluation of drilling results
Year 4: G&G studies.
In the Adavale Basin, ATP 863 was not renewed and now reverts to
In the Surat Basin, PLR 2013-1-4 closed on 22/11/2013. Competing
applications ATP 1183, ATP 1184 and ATP 1185 were
received for the area. NAVGAS P/L with ATP 1183 has been
announced as preferred tenderer. Overlapping applications ATP 1184 and
ATP 1185 are unsuccessful applications.
In the Cooper Basin, production licences PL 256 (Bargie), PL 482
(Marcoola) and PL 483 (Glenvale/Coolum) were granted on
17/04/2014. The licences will expire on 16/04/2019. As a result, ATP
269 now covers a reduced area of 636 sq km.
In the Galilee Basin, the potential commercial area applications PCA 34 to
PCA 79 were withdrawn on 30/04/2014.
In the Arckaringa Basin, PEL 124 has been suspended by 12 months from
28/03/2014 to 27/03/2015. The licence has had its expiry date extended to
In the Otway Basin, PEL 155 has been suspended by 6 months from
19/03/2014 to 18/09/2014. The licence has had its expiry date extended to
In the Cooper Basin, PEL 182 has been suspended by 12 months from
24/03/2014 to 23/03/2015. The licence has had its expiry date extended to
In the Eromanga Basin, PEL 183 has been relinquished.
In the Cooper Basin, PEL 516 has been split into two permits, PEL 516
and PEL 637, as part of the Senex Energy and Origin Energy farm-out
announced in February 2014. PEL 516 now covers 1,555 sq km.
In the Eromanga Basin, PEL 568 and PEL 569 have been suspended
by 6 months from 28/03/2014 to 27/09/2014. The licenses have had their expiry
dates extended to 15/12/2017.
In the Cooper Basin, PEL 637 has been granted to Stuart Petroleum P/L
100% on 24/04/2014. The licence will expire 01/05/2016. Origin Energy is
farming in for 40% interest and has the option to increase its working
interest by 10% and become operator. Work program is as follows -
Year 1: G&G studies
Year 2: 2 wells
Year 3: G&G studies
Year 4: 2 wells, 300 km 2D seismic, 1000 km seismic reprocessing
Year 5: G&G studies
In the Eromanga Basin, PEL 88 is being renewed.
In the Cooper Basin, Strike Energy has resolved its dispute with Australian
Gasfields Ltd over neglected cash call payments relating to PEL 96.
Strike said that it had funded nearly $1.5 million of outstanding cash calls,
which Australian Gasfields had not paid. As a result, Strike threatened to
assign Australian Gasfield’s interest in the PEL 96 JV to itself. Strike has
confirmed that Australian Gasfields had paid the cash calls in full, with
both companies contributing their respective share to the forthcoming
fracture stimulation and flow testing program.
In the Cooper Basin, PPL 251 has been granted to Victoria Oil Exploration
(1977) P/L 55%, Stuart Petroleum P/L 25% and Komodo Energy P/L 20% on
16/04/2014 for an indefinite term.
In the Cooper Basin, Santos Ltd has applied for PRLA 111 to PRLA
In the Pirie-Torrens and St Vincent Basins, GEL 571 to GEL 574
have been suspended by 5 months from 17/03/2014 to 13/05/2014. The licenses
have had their expiry dates extended to 26/07/2017.
Offshore in the Gippsland Basin, a suspension and
extension was lodged on 24/04/2014 for VIC/P 44 and is currently being
assessed by NOPTA.
Also in the Gippsland Basin, a variation was lodged on 17/04/2014 for VIC/P
47 and is currently being assessed by NOPTA.
In the Gippsland Basin, VIC/P 63 and VIC/P 64 expired on 28/03/2014
and now revert to vacant acreage.
In the Otway Basin, V 13-1 was granted as VIC/P 69 to Origin
Energy Resources Ltd 100% on 16/04/2014. The licence will expire on
15/04/2020. Work program is as follows:
Year 1: G&G studies, 1500 km 2D seismic reprocessing $0.7m
Year 2: G&G studies, 517 sq km 3D seismic $15.15m
Year 3: G&G studies $0.7m
Year 4: G&G studies $0.7m
Year 5: G&G studies, 1 exploration well $30.7m
Year 6: G&G studies $0.5m
In the Carnarvon Basin, W 13-14 has not been re-released and reverts
to vacant acreage. W 13-15, W 13-16 and W 13-17 have
been re-released and close 02/10/2014.
In the Carnarvon Basin, WA-208-P is being renewed.
In the Browse Basin, INPEX Browse Ltd has transferred its interest in WA-274-P,
WA-281-P and WA-410-P to INPEX Browse E&P P/L.
In the Browse Basin, the Ichthys/Concerto Location WA-274-P LI has
been extended to 20/05/2016.
In the Carnarvon Basin, location WA-346-P LJ has been granted over
Jupiter on 16/04/2014.
In the Browse Basin, an application to suspend the work program and extend
the licence date for WA-410-P has been lodged with NOPTA - a decision
In the Browse Basin, WA-411-P expired on 04/05/2014 and the area
reverts to vacant acreage.
In the Browse Basin, the year 5 work program for WA-425-P has been
extended by 9 months from 02/04/2014 to 02/01/2015. The licence has had its
expiry date extended to 02/01/2016.
In the Browse Basin, the year 5 work program for WA-431-P is now -
geotechnical studies $1.5m.
In the Canning Basin, WA-443-P is being relinquished.
In the Petrel Sub-basin, WA-446-P is being relinquished.
In the Carnarvon Basin, WA-451-P was cancelled on 08/04/2014.
Also in the Carnarvon Basin, Shell Development (Australia) P/L has sold its
33.33% interest in WA-45-L to KUFPEC Australia (Wheatstone Iago) P/L.
In the Carnarvon Basin, W 13-18 has been granted as WA-497-P to
AWE Australia P/L 100% on 3/04/2014. The licence will expire on 2/04/2020.
Work program is as follows -
Year 1: 250 km 2D seismic reprocessing, G&G studies, 726 sq km 3D
seismic reprocessing $0.8m
Year 2: 400 sq km 3D seismic inversion, G&G studies $0.5m
Year 3: G&G studies $0.2m
Year 4: 1 well $20m
Year 5: G&G studies $0.2m
Year 6: 1 well $20m
In the Carnarvon Basin, W 13-10 has been granted as WA-498-P to
Santos Offshore P/L 75% and JX Nippon Oil and Gas Exploration (Australia) P/L
25% on 16/04/2014. The licence will expire 15/04/2020. Work program is as
Year 1: 80 sq km 3D seismic reprocessing, G&G studies $0.235m
Year 2: G&G studies $0.075m
Year 3: G&G studies $0.075m
Year 4: CSEM feasibility studies, G&G studies $3.1m
Year 5: 1 well, G&G studies $25.1m
Year 6: G&G studies $0.1m
In the Dampier Basin, W 13-13 has been granted as WA-499-P to
Apache Northwest P/L on 17/04/2014. The licence will expire 16/04/2020. Work
program is as follows -
Year 1: 890 sq km 3D seismic, 890 sq km PSDM processing, studies $8m
Year 2: studies $0.4m
Year 3: 1 well $12m
Year 4: 650 sq km 3D seismic, 650 sq km PSDM processing $6m
Year 5: geotechnical studies $0.2m
Year 6: geotechnical studies $0.2m
In the Carnarvon Basin, W 13-9 has been granted as WA-500-P to
Finder No 7 P/L on 17/04/2014. The licence will expire 16/04/2020. Work program
is as follows –
Year 1: G&G studies, 1200 sq km 3D seismic $1.1mm
Year 2: G&G studies $0.25m
Year 3: G&G studies, 201 km 2D seismic $0.85m
Year 4: G&G studies, 500 sq km 3D QI/reservoir characterisation
Year 5: G&G studies $0.1m
Year 6: G&G studies $0.1m
In the Dampier Basin, W 13-12 has been granted as WA-501-P to
Carnarvon Petroleum Ltd on 23/04/2014. The licence will expire 22/04/2020.
Work program is as follows –
Year 1: seismic interpretation, 80 sq km 3D seismic reprocessing,
biostratigraphy & reservoir studies $0.22m
Year 2: seismic interpretation, petrophysical studies $0.03m
Year 3: studies $0.02m
Year 4: G&G studies $0.02m
Year 5: G&G studies $0.1m
Year 6: 1 well $20m
In the Browse Basin, WA-342-P L Cornea Location was granted as WA-54-R
to Cornea Oil & Gas P/L 17%, Cornea Petroleum P/L 14.875%, Enegex NL
14.875%, Cornea Resources P/L 13.1%, Octanex NL 10.25%, Cornea Energy P/L
8.5%, Coldron P/L 7.5%, Moby Oil & Gas Ltd 7.5% and Auralandia P/L
6.4% on 06/05/2014. The licence will expire 05/05/2019. Work program is as
Year 1: G&G, reservoir, well & field design studies $0.45m
Year 2: economic, field & drilling studies $0.5m
Year 3: drilling, impact, logistics & economic studies $0.75m
Year 4: 1 well $40m
Year 5: review of production test outcomes $0.25m
In the Carnarvon Basin, WA-11-L is being renewed.
In the Canning Basin, the year 4 work program for EP 129 has been
extended by 12 months from 31/01/2014 to 31/01/2015. The licence has had its
expiry date extended to 31/01/2016.
Also in the Canning Basin, the contractual relationship for future payable
royalties relating to the 3% Lennard Shelf Royalty EP 129, L6
and L 8 is between Fitzroy and Buru alone.
In the Canning Basin, the year 4 work program for EP 390 has been extended
by 12 months from 31/01/2014 to 31/01/2015. The licence has had its expiry
date extended to 30/01/2016.
In the Canning Basin, the year 3 work programs for EP 457 and EP
458 have been extended by 12 months from 24/10/2012 to 23/10/2013. The
licenses have had their expiry dates extended to 23/10/2016.
In the Perth Basin, the year 3 work program for EP 467 has been
extended by 12 months from 01/12/2012 to 30/11/2013. The licence has had its
expiry date extended to 30/11/2016.
In the Canning Basin, application STP-EPA-97 has been varied and now
covers a reduced area of 2,090 sq km.
In the Canning Basin, STP-EPA-106 and STP-EPA-107 are under
application by Admiral Oil & Gas (106) P/L and Admiral Oil & Gas
(107) P/L respectively.
In the Perth Basin, AWE has withdrawn from the farm-in to the Mid-West
Geothermal Energy Project for 50% in one of GEP 23 to GEP 28 or
GEP 41. The two parties were working under a Memorandum of
Understanding announced 05/03/2013.
The 2014 Block Offer
application areas have been finalised with bids closing on 25/09/2014.
Gazettal areas 14ECT-R1, 14GSC-R1, 14PEG-R1, 14TAR-R2
and 14WEC-R1 have been varied and now cover reduced areas of 1,340 sq
km, 141,679 sq km, 75,421 sq km, 1,160 sq km and 6,749 sq km respectively. 14TAR-R1
has been extended to cover 54,898 sq km. Areas
are defined in 62.5 sq km blocks onshore and 250 sq km blocks offshore. Applications can be lodged for a single block or multiple contiguous
blocks up to certain pre-set maximums.
In the Reinga Basin, TGS-Nopec Geophysical Company P/L has applied for
prospecting permit APP 56377.
In the Taranaki Basin, MEO has executed a binding agreement with Kea
Petroleum to farm into PEP 51153. The farm in will take place by way
of a staged work program, where MEO will initially earn a 30% interest by
funding $NZ4 million of the $5 million phase I work program. Following the
completion of phase I, MEO will have options to acquire Kea's remaining
interest or proceed with phase II of the work program to be capped at $NZ9
million. In phase II, MEO can increase its interest in the permit to 50% by
paying $NZ7.5 million of this program.
In the Taranaki Basin, PEP 51313 is being renewed.
Also in the Taranaki Basin, PEP 54867 is being relinquished.
In the New Caledonia Basin, PPP 55377 has been granted to Energy
Holdings Offshore Ltd 37.5%, CNOOC International Ltd 37.5% and Anadarko New
Zealand Company 25% on 15/04/2014. The licence will expire on 14/12/2016.
Work program is as follows -
12 months: technical studies, remote sensing study
18 months: 30000 sq km multi-beam seafloor survey
20 months: 10000 km 2D seismic
24 months: 10000 km 2D seismic
32 months: technical studies
Papua New Guinea
In the Papuan Basin, PDL 10 over the Stanley
field (PRL 4) has been offered and accepted and is expected to be granted
shortly. The Unitisation agreement will subsequently be finalised and
will affect the single PPL 259 graticular block that Stanley encroaches into.
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