New Image Layer
The April update includes a new image layer supplied to us by FrOG
Tech. The layer FrOG Tech Proterozoic SEEBASE is in Map Manager group IMAGES.
FrOG Tech Proterozoic SEEBASE depth-to-basement image with permit overlay (transparency 40%)
FrOG Tech’s OZ (Australian) SEEBASE™ Proterozoic Basins study provides a
first-pass, continent-wide interpretation of the structure and evolution
of many of Australia’s Phanerozoic, Paleoproterozoic and Mesoproterozoic
basins (FrOG Tech, 2006).
OZ Proterozoic SEEBASE™ is a depth-to-basement image/grid which provides
a view of the present-day shape of each basin and provides a framework
within which to place observations on stratal geometry and reservoir,
seal and source distribution. In addition, the knowledge of basement
structure and its possible response to younger stress events can be used
to predict the timing, distribution, type, size and integrity of
Completed in 2006, the OZ SEEBASE™ Proterozoic Basins project was
carried out by FrOG Tech Pty Ltd for Geoscience Australia, the
Geological Survey of Western Australia, the Northern Territory
Geological Survey, Primary Industries and Resources South Australia and
the Geological Survey of Queensland.
An ArcGIS project containing all interpretive layers and accompanying
reports can be downloaded
The principal objective of the OZ SEEBASE™ project has been to lower
risk and assist exploration for oil and gas, minerals and groundwater in
Australia’s sedimentary basins by providing -
a new view of Australia’s sedimentary basins from an
integrated regional interpretation of basement composition,
structure and depth to basement SEEBASE™ dataset for the whole of
onshore Australia and its offshore margins
the first consistent testable structural model for the evolution of
Australia’s sedimentary basins
a new illustration of the effects of basement geology on basin
evolution and petroleum systems in the individual basins, focusing
on structural evolution/reactivation, basin architecture and
a base for a new set of maps of palaeogeography, crustal heat flow,
crustal thickness, hydrocarbon generation volumes etc.
Display notes -
is displayed above image data so by default parts of the image are obscured
the landmass is covered by the Coast Medium
Res and Coast High Res layers in the COAST ETC group
expose the underlying image in one of the
following ways -
a. switching off the solid layers that display on top
b. switching off the fill on those layers but leaving
the outline on
c. making the filled layers transparent to expose the
reset your display to factory settings at any
Help > System
Restore and selecting the default option
the image will switch off at zoom levels of 1:1 million or closer
Can't see the new
Correct display of the new
data layer requires a modification to the structure of
your GPinfo configuration file. This should happen automatically
the first time you start a GPinfo session after the April data update has
If the April update has been installed but you still can't
see the new layer 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.
If you still can't see the data, please re-set your permissions to the
GPinfo data as described above under Data Permissions.
Removal of Permit Part Numbers
The Department of Mines and Petroleum in Western Australia
has historically used part numbers to identify the separate areas of non-contiguous
permits. It is no longer their practice to do so as numbering has
become increasingly complex due to further segmentation
of permits on renewal. This change brings WA into line with the other
states in naming conventions for non-contiguous permits.
Our practice in GPinfo has always been to match the convention of the
issuing authority when naming permits. Accordingly, this month part
numbers for non-contiguous permits in Western Australia have been
Now when you graphically select one part of a non-contiguous permit in
WA in the Map Window, the whole permit is highlighted.
For every affected licence, the first part has been retained and renamed
to exclude the part number. The remaining parts have been given the
same name. It
is important to know this if you are a user of the
GPinfo History Module. Parts 2 and higher will cease to exist after
March 2012, and the remaining and renamed Part 1 will appear to have
undergone a significant increase in area.
Permits affected are – EP 129, EP 325, EP 359,
TP/8, WA-1-P, WA-4-L, WA-6-L, WA-28-P,
WA-202-P, WA-214-P, WA-254-P and WA-350-P.
The only exception to this is WA-155-P (Parts 1 & 2) where
participants and percentage interests differ. WA-155-P (1) and WA-155-P
(2) are unchanged.
has received more than $A80 million after completing the sale of a stake
in the BassGas project to Toyota Tsusho. Late last year AWE
decided to sell 11.25% in T/L1 which includes the Yolla gas condensate
field and associated production infrastructure and 2.7% in T/18P which
includes the Trefoil gas condensate discovery. (Source: Energy News
Empire Oil & Gas NL
and ERM Gas P/L have agreed the terms of drilling petroleum
exploration well Black Arrow 1 in EP 432 in the North Perth Basin. ERM
Gas has agreed to farm into the northern 12 graticular blocks of EP 432,
called Area A, to earn an additional 35% in Area A by funding 60% of
Black Arrow 1. Upon completion of drilling Black Arrow 1, interests in
Area A will be Empire Oil Company (WA) Ltd 42.5% (operator), ERM Gas P/L
47.5% and Allied Oil & Gas plc 10%. The interests in the remainder of EP
432, Area B, are Empire Oil Company (WA) Ltd 77.5% (operator), ERM Gas
P/L 12.5% and Allied Oil & Gas plc 10%. The Farmin is subject to
executing a formal agreement. Furthermore, as part of this farmin,
Empire has farmed into the shallow rights of EP 454. This is called the
Yarragadee rights. The equities in the EP 454 Yarragadee Rights are
Empire Oil Company (WA) Ltd 83.33% (operator) and ERM Gas P/L 16.66%.
Empire is seeking to farmout some of its 83.33% to drill Charger 1 as
the second well following the drilling of Black Arrow 1. (Source:
Empire Oil & Gas announcement, 10/04/2012).
Oil Basins Ltd
and Green Rock Energy Ltd have executed a Heads of Agreement for
the farm-out of up to 20% interest in the Backreef Area, Canning Basin
WA with an upfront payment from Green Rock of $1.1 million. Under the
agreement, Green Rock can elect to attain a 5% interest in the Backreef
Area by acquiring Oil Basin’s wholly owned subsidiary OBL Backreef No 5
P/L, by making a second non-refundable payment of $625,000 to Oil
Basins. If Green Rock elects to take a 20% interest, they will acquire
the subsidiary for $2.5 million.
Furthermore, Green Rock have announced that Cygnet Capital P/L
has received firm commitments from investors for a minimum of $3.22
million which enables the Company to exercise its option by 30 April
2012 to acquire up to 20% of the Backreef Area. (Source: Oil Basins
announcement, 02/04/2012, Green Rock announcement, 12/04/2012 ).
Senex Energy Ltd
has received independent certification of a major reserves upgrade
across its Cooper Basin acreage following successful appraisal and
development drilling. Senex’s net share of 1P and 2P oil reserves has
both increased by 27% since 30 June 2011. The company said the rise was
largely attributed to successful drilling at the Growler oil field which
resulted in a 138% increase in Proved oil reserves and a 90% increase in
Proved and Probable reserves. (Source: Senex Energy announcement,
Tangiers Petroleum Ltd
is pleased to announce that the Milligans Fan oil play in its WA-422-P
and NT/P 81 permit areas is estimated to host mean prospective resources
of 218 million barrels of oil according to a report prepared by ISIS
Petroleum Consultants. Tangiers said 14 leads had been identified, with
eight structural traps and six being a combination of structural and
stratigraphic traps. Tangiers is exploring the area due to the Turtle
and Barnett discoveries which were made in 1984 and 1985, and further
appraised in 1989 and 1990. (Source: Energy News Premium 03/04/2012,
Tangiers Petroleum announcement, 03/04/2012).
The Commonwealth Minister for Resources and Energy and the WA Minister
for Mines and Petroleum have today approved a variation to the
conditions of the retention leases associated with the Woodside operated
Browse LNG Project. The Browse Joint Venture is now required to
be in a position to apply for a production licence and make a final
investment decision during the first half of 2013, instead of mid-2012.
The overall terms of the retention leases have not changed and are set
to expire in December 2014. Woodside said the variation to the leases
would allow time to better evaluate the outcomes of front-end
engineering and design work and the result of the tender processes for
the development’s major contracts. (Source: Woodside announcement,
10/04/2012, Energy News Premium, 10/04/2012).
Woodside Petroleum’s $15 billion Pluto LNG Project in Western
Australia is ready for start up with first gas entering the processing
train. First production of LNG will take place in the coming weeks
followed by deliveries to foundation customers and project participants
Kansai Electric and Tokyo Gas. Gas will be processed from the Pluto and
Xena fields in the offshore Carnarvon Basin, estimated to contain 5.5
trillion cubic feet of gas. The Pluto LNG Project is expected to
contribute 17 to 21 million barrels of oil equivalent to Woodside’s 2012
production. Long term average Pluto production is expected to contribute
about 37 million barrels of oil equivalent to Woodside’s annual volumes.
(Source: Woodside announcement 22/03/2012, Energy News Premium,
MEO Australia has secured a five year extension for its Tassie
Shoal LNG Project after the Federal Government revised the terms of
the environmental approval for the project. The terms were revised to
bring it in line with recent approval decisions brought about by the
Montara incident and its subsequent inquiry. The approval for the
project will remain valid until at least 28 March 2017. (Source: MEO
Australia announcement, 29/03/2012, Energy News Premium, 29/03/2012).
InterOil Corporation has extended Final Investment Decision
timelines with project partners Mitsui and Energy World Corp to a later
date this year for Gulf Province projects, Papua New Guinea. The Joint
Venture Operating Agreement for the Company’s proposed Condensate
Stripping Plant with Mitsui has been extended until 30 June 2012
while the new Final Investment Decision deadline with Energy World Corp
for the onshore modular LNG plant for the Gulf LNG Project is 31
December 2012. Both FIDs were previously expected in late-2012.
(Source: InterOil announcement, 30/03/2012).
MEO Australia Ltd is pleased to announce Major Project Facilitation
(MPF) status has been renewed for the Tassie Shoal Gas Processing
Projects until 31 December 2015. The MPF status will assist in
expediting any additional project approvals in addition to the existing
environmental approvals. (Source: MEO Australia announcement,
The Horizon Oil operated Elevala 2 appraisal well and its
associated sidetrack in Papua New Guinea has increased mean recoverable
Elevala field resources by almost 60% for gas and 45% for condensate. In
January, the Elevala 2/ST well defined a gas-water-contact to the
hydrocarbon accumulation and has established a field gas column height
of greater than 50 metres. The Elevala field is estimated to contain a
mean contingent resource of 480 billion cubic feet of gas and 27 million
barrels of condensate. (Source: Energy News Premium, 21/03/2012).
WestSide Corporation believes new wells will produce at similar high
rates as Pretty Plains 10 at the Meridian SeamGas fields which
has been flowing at a rate of more than 1,000,000 standard cubic feet a
day (scf/d), with the potential to further increase. The performance of
Pretty Plains 10 builds on the successful earlier commissioning of
Pretty Plains 2 and more recently Meridian 29, which has been
producing more than 700,000 scf/d of gas. Output from the new wells now
accounts for approximately 21% of production and continues to build as
new wells are progressively commissioned. (Source: WestSide
announcement 20/03/2012, Energy News Premium 20/03/2012).
TAG Oil Ltd is pleased to announce that the recently drilled
Cheal B6, Cheal A9 and Cheal A10 wells confirm a
commercial oil discovery within the Urenui Formation at a depth of
approximately 1,400 meters. Strong initial flow tests were achieved,
with each well having the capability to produce approximately 200
barrels of light oil per day, plus associated gas from high quality
reservoir sands. TAG plans to place the wells on production in the
second half of 2012. (Source: TAG Oil announcement, 02/04/2012).
Senex Energy has had its eleventh consecutive success at the Growler
oil field in the Cooper Basin with the Growler 10 appraisal well.
Growler 10 was drilled to a total depth of 1,850 metres with wireline
logs confirming the presence of a 15.2 metre gross oil column in the
Birkhead Formation over the interval 1,728.8 to 1,744.0 metres with
interpreted net oil pay of at least 14.0 metres. Senex expects to
commence production from Growler 10 during April 2012. (Source: Senex
Energy announcement, 11/04/2012).
Beach and Drillsearch have had further success with the Haslam 1
exploration well located in PEL 106B in the Cooper Basin, South
Australia. Haslam 1 encountered good hydrocarbon fluorescence and gas
shows in sands throughout the Patchawarra formation and Tirrawarra
sandstones, and flowed at a stabilised rate of 3 million cubic feet of
gas per day during a drill stem test. In addition, Haslam 1 intersected
thick gassy Patchawarra coals and shales which demonstrated
significantly elevated gas levels. The well has been suspended for
cased-hole extended production testing to further evaluate the wet gas
bearing sands. (Source: Drillsearch Energy announcement, 10/04/2012).
During drilling and coring of the Sasanof 1 unconventional
gas exploration well in PEL 516 Cooper Basin, Senex observed significant
gas shows across the Epsilon and Patchawarra tight sand reservoirs of
the Permian section. Subsequent analysis of the gas shows suggests the
presence of wet gas while initial desorption testing of the Roseneath
and Murteree shale samples and the Toolachee and Patchawarra coal
samples delivered positive gas content. Sasanof 1 has been cased and
suspended for an extensive hydraulic fracture stimulation program in May
2012 to evaluate the potential for commercial production of
unconventional gas. (Source: Senex Energy announcement, 11/04/2012).
Permit Updates and Changes
Federal Sequestration Gazettal
Applications for the Sequestration Gazettal of VLAM-01,
VLAM-02, PTRL-01, PETRL-02, OTWY-01, TORQ-01
and TORQ-02 closed on 30/03/2012. No bids were received.
New South Wales
TRUenergy Gunnedah Gas P/L has acquired the following interests -
PPL 3 – 20%
PEL 6 (Conventional) – 0.77%
PEL 6 (CSG) – 23.85%
PEL 6 Edendale (Conventional) – 1.54%
PEL 6 Edendale (CSG) – 24.62%
PEL 238 (Conventional) – 30.769%
PEL 238 (CSG) – 20%
PEL 427 (CSG) – 15.38%
PEL 428 (CSG) – 12.31%
PEL 433 – 20%
PEL 434 – 20%
On the Lachlan Fold Belt, an application has been made for special
prospecting authority PSPAPP 59 by Dart Energy Ltd 100%.
On the New England Fold Belt, PEL 285 is in the process of being
In the Sydney Basin, PEL 444 and PEL 469 are in the
process of being renewed.
In the Gunnedah Basin, PEL 456, PEL 468 and PEL 470
are in the process of being renewed.
In the Browse Basin, AC/P 36 has been renewed to 07/02/2017.
Furthermore, following the execution of a Sales and Purchase Agreement
for AC/P 36 on 15th February 2012, Finder Exploration’s 40% interest has
been transferred to Murphy Australia AC/P 36 Oil Pty Ltd.
In the Browse Basin, following Total’s withdrawal from AC/P 37
Lower Horizon, interests over the permit are now Apache Northwest 100%.
The permit is also in the process of being renewed.
In the Vulcan Basin, AC/P 39 was cancelled 21/03/2012.
In the Ashmore Platform, AC/P 42 is in the process of being
In the Amadeus Basin, Phoenix Oil & Gas Ltd acquired a 1% ORR from
Frontier Oil & Gas for permits EP(A) 111, EP 112, EP
115, EP 118 and EP(A) 120 and a 1% ORR from Ordiv
Petroleum P/L for EP(A) 124 and EP 125.
In the Money Shoal Basin, NT 11-1 and NT 11-2 closed
12/04/2012 and are now under consideration.
Offshore, in the Gulf of Carpentaria, Q/23P has had its expiry
date extended to 20/12/2013.
Onshore, in the Eromanga Basin, Phoenix Oil & Gas acquired a 4% NPI in
ATP 299P and its associated production licences (PL 29, PL 38,
PL 39, PL 52, PL 57, PL 95, PL 293,
PL 294 and PL 298) from the receivers of Gwalia.
In the Clarence/Moreton Basin, ATP 683P has undergone a partial
relinquishment and now covers a reduced area of 1,172 sq km.
In the Eromanga Basin, following the drilling of Sampdoria 1, interests
in ATP 752P Wompi Block are Santos QNT 35%, Victoria Oil
Exploration (1977) 22.75%, Avery Resources (Australia) 19.5%, Bow Energy
Ltd 13.65% and Ocellaris Oil P/L 9.10%.
In the Surat Basin, Senex Energy has 100% in the conventional/deep
rights in ATP 771P.
In the Galilee Basin, Westside is seeking to farmout ATP 974P
and ATP 978P through its subsidiary Nazara Energy.
In the Surat Basin, Australian-Canadian Oil Royalties Ltd, through
its subsidiary Chelsea Oil Australia P/L, acquired
the following interests from Brisbane Petroleum NL and Delbaere
Associates P/L effective 29/02/2012: 100% of PL 18, 50% of PL
280 and 100% of PL 40. Brisbane Petroleum and Delbaere
Associates will hold a joint 3% ORR on the interests sold to ACOR.
In the Bowen Basin, the correct expiry date for PL 94 is
In the Cooper Basin, the Inland Oil sale of interests in PL 256,
PL 482 and PL 483 to Bridgeport did not proceed and interests
in the licence are: Beach Energy 80%, Mawson Petroleum 13.9%, and
Inland Oil (Production) P/L 6.1%.
In the Bowen Basin, Bow Energy (now owned by Arrow Energy) has withdrawn
a number of production licence applications: PL 376 to PL 391
and PL 422 to PL 433.
In the Cooper Basin, PEL 93 has undergone a partial
relinquishment and now covers 621 sq km.
In the Cooper Basin, PEL 95 has had its expiry date extended to
In the Cooper Basin, Acer Energy have acquired Sundance Energy's 23.335%
in PEL 100.
In the Cooper Basin, the suspension period for PEL 104 ceased
on 03/11/2011. The licence will expire on 28/10/2014.
In the Arckaringa Basin, PEL 117, PEL 121 and PEL 122
are in the process of being renewed.
Also in the Arckaringa Basin, PEL 118 and PEL 119 have had
their expiry date extended to 31/12/2013.
In the Arrowie Basin, PEL 132 has had its expiry date extended to
23/08/2013. The year 4 work program now covers G&G studies instead of
50k 2D seismic.
In the Otway Basin, PEL 186 is in the process of being renewed.
There are also changes to the Year 3 to 5 work programs. They now cover
Y3 - data review, Y4 - G&G studies, Y5 - 50k 3D seismic.
In the Eromanga Basin, the area of PELA 511 has been extended and
now covers 9,881 sq km.
The applicants for PELA 580 and PELA 581 are now Kush
Mining Corporation Pty Ltd 80%, Gabriel Kushnir Holdings Pty Ltd 10% and
Bluehawk Capital Pty Ltd 10%.
In the Cooper Basin, PRL 14 has had its expiry date extended to
The following Eden Energy permits have been surrendered - GEL 169,
GEL 329, GEL 330, GEL 411, GEL 412, GEL
413, GEL 414, GEL 415, GEL 416, GEL 417,
GEL 418, GEL 419, GEL 420, GEL 421 and
In the Cooper Basin, GEL 211 has undergone a partial
relinquishment and now covers 107 sq km.
In the Cooper Basin, GEL 221 and GEL 220 are now
consolidated as GEL 220 which now covers 952 sq km.
In the St Vincent Basin, GEL 226 has had its expiry date extended
In the Pirie-Torrens Basin, GEL 230 has had its expiry date
extended to 23/05/2012.
In the St Vincent Basin, GEL 425 has had its expiry date extended
Applications for offshore Otway Basin area V 11-1 closed on
12/04/2012 and are currently under consideration.
Onshore in the Otway Basin, Interra Resources has withdrawn from PEP
167 and has assigned its 50% to Bass Strait Oil Co, with Bass Strait
Oil now holding 100% of the permit.
Also in the Otway Basin, Armour Energy is funding the drilling of Moreys
1 (due to spud 18/04/2012) to a cost of $2.5m to earn 51%.
In the Canning Basin, a 12 month suspension period has been granted to
the Year 3 work program for DR 9. Year 3 has been extended from
19/12/2011 to 19/12/2012. The licence will expire 19/12/2012.
In the Canning Basin, EP 129 (1) and EP 129 (2) are now
consolidated as EP 129.
Also in the Canning Basin, Green Rock Energy Ltd is farming into EP
129 BR and L 6 BR for up to 20%.
In the Perth Basin, EP 321 is pending suspension.
In the Carnarvon Basin, EP 325 (1) and EP 325 (2) are now
consolidated as EP 325, and EP 359 (1), EP 359 (2)
and EP 359 (3) are consolidated as EP 359.
In the Bonaparte Basin, a 12 month suspension period has been granted to
the Year 1 work program for EP 386. Year 1 has been extended from
31/03/2012 to 31/03/2013. The licence will expire 31/03/2017.
In the Perth Basin, EP 407 and EP 430 are pending
In the Perth Basin, EP 432 has been split into 2 permits, EP
432 A and EP 432 B, due to the Empire Oil & Gas NL and ERM
Gas P/L farm-in. ERM Gas has agreed to farm into the northern 12
graticular blocks of EP 432, called Area A, to earn an additional 35%.
The interests in the remainder of the EP 432 permit, Area B, are Empire
Oil Company (WA) Ltd 77.5% (operator), ERM Gas P/L 12.5% and Allied Oil
& Gas plc 10%.
In the Canning Basin, EP 448 has undergone a partial
relinquishment and now covers 8,468 sq km.
In the Perth Basin, Empire has farmed into the shallow rights of EP
454, called the Yarragadee rights. The equities in the EP 454
Yarragadee are Empire Oil Company (WA) Ltd 83.33% (operator) and ERM Gas
In the Officer Basin, Phoenix Oil & Gas retains a 2% ORR in EP 468
after selling Officer Basin Petroleum to Paltar Petroleum Ltd in 2011.
In the Perth Basin, ARC Energy holds 100% of the Dongara/Yardarino field
in L1 and 50% in the area excluding Dongara/Yardarino/Mondarra.
In the Canning Basin, the following gazettal areas are under application
Energy (Australia) P/L
Canning Basin application STP-EPA-0044 (L 11-1) by
Buru Energy has been extended and now covers 7,822 sq km.
The following areas closed 08/03/2012 and now under consideration - L
10-12, L 11-5, L 11-6, L 11-7, L 11-8,
L 11-9, L 11-10, L 11-11 and L 11-12.
In the Perth Basin, STP-SPA-0013 is an exploration application
over former Special Prospecting Area SPA 9/10-1 AO.
In the Carnarvon Basin, T 11-3 closed 08/03/2012 and is under
In the Barrow Basin, Apache has acquired Santos’ 15% interest in TL/2.
In the Barrow Basin, production licence TL/10 was granted on
22/03/2012. The licence will expire on 21/03/2033. Area covers
previous retention licence TR/2.
In the Barrow Basin, TP/7 (1), TP/7 (2), TP/7
(3) and TP/7 (4) are now consolidated as TP/7.
Furthermore, TP/7 is in the process of being renewed and Apache has
acquired Santos' interest in the permit.
In the Barrow Basin, TP/8 (1), TP/8 (2), TP/8 (3)
and TP/8 (4) are now consolidated as TP/8.
The following areas closed 12/04/2012 and are now under consideration -
W 11-2, W 11-3, W 11-4, W 11-5, W 11-6,
W 11-7, W 11-8, W 11-9, W 11-14, W 11-16,
W 11-17 and W 11-18.
In the Dampier Basin, WA-1-P (1), WA-1-P (2), WA-1-P
(3), WA-1-P (4) and WA-1-P (5) are now consolidated under
In the Dampier Basin, WA-4-L (1) and WA-4-L (2) are now
consolidated as WA-4-L.
In the Carnarvon Basin, WA-6-L (1) and WA-6-L (2) are now
consolidated as WA-6-L.
In the Dampier Basin, WA-28-P (1), WA-28-P (2) and
WA-28-P (3) are now consolidated as WA-28-P.
In the Carnarvon Basin, Kyushu Electric Wheatstone Australia P/L
acquired 1.83% in WA-46-L, WA-47-L and WA-48-L from
In the Dampier Basin, retention lease WA-47-R has been granted
over WA-254-P (2). Licence will expire 23/02/2017.
In the Browse Basin, production licence WA-50-L has been granted
over WA-37-R. Licence will expire 28/02/2017.
In the Browse Basin, production licence WA-51-L has been granted
over the location block area in WA-285-P. Licence will expire
In the Carnarvon Basin, WA-202-P (1) and WA-202-P (2) are
now consolidated as WA-202-P.
In the Carnarvon Basin, WA-214-P (1), WA-214-P (2) and
WA-214-P (3) are now consolidated as WA-214-P.
In the Dampier Basin, WA-254-P (1), WA-254-P (3) and
WA-254-P (4) are now consolidated under WA-254-P. The
expiry date for the permit has been extended to 11/05/2013.
In the Carnarvon Basin, Strike Energy retains 19.937% in WA-261-P
after it failed to agree to Terms for Apache to acquire its interest.
In the Browse Basin, the area of WA-285-P has been reduced due to
the grant of production licence WA-51-L. WA-285-P now covers
1,002 sq km.
In the Carnarvon Basin, WA-335-P has been renewed over a reduced
area to 26/03/2017 and now covers 1,604 sq km. Furthermore, BHP
acquired an additional 6.5% from Apache, lifting its interest to 52.5%.
The S&P agreement was approved by NOPTA on 13/01/2012 and registered on
06/03/2012. Work program is as follows -
G&G studies $0.5m
Year 2: 1 well $50m
Year 3: G&G studies $0.5m
Year 4: G&G studies $0.5m
Year 5: 1 well $50m
In the Carnarvon Basin, WA-350-P (1) and WA-350-P (2) are
now consolidated as WA-350-P.
In the Browse Basin, WA-377-P has been renewed to 22/03/2017.
Work program is as follows -
geotechnical studies $0.3m
Year 2: geotechnical studies $0.3m
Year 3: 1 well $20m
Year 4: geotechnical studies $0.3m
Year 5: geotechnical studies $0.3m
In the Carnarvon Basin, there has been a change to the WA-385-P
year 6 work program. It now covers 560k 2D seismic $1.5m instead of 1
In the Canning Basin, WA-419-P is in the process of being
In the Canterbury
Basin, APP 52717 is being proposed solely by Beach Petroleum (NZ)
Pty Ltd. Initially the application was proposed by a JV consisting of
NZOG, AWE, Beach and Roc Oil.
In the Wanganui Basin, APP 52952 was formally withdrawn by Solid
Energy NZ on 10/04/2012.
In the East Coast Basin, PEP 38346 has been renewed over a
reduced area to 02/07/2016 and now covers 1,083 sq km. Work program is
as follows -
studies, 1 well
24 months: 150k 2D seismic reprocessing, studies
44 months: studies
48 months: studies, 50k 2D seismic
75 months: geochemical sampling
78 months: 10k 2D seismic, 1 well
96 months: studies
108 months: 70k 2D seismic
116 months: 1 well
120 months: studies
In the Taranaki Basin, PEP 38479 has been renewed over a reduced
area to 23/09/2016 and now covers 411 sq km. Work program is as
36 months: 500k 2D seismic
72 months: 1 well
120 months: 100k 3D seismic
135 months: 1 well
141 months: 1 well
In the West Coast Basin, PEP 38527 was surrendered on 28/03/2012.
In the Taranaki Basin, there has been a change in area to PEP 38614.
The permit now covers 1,514 sq km.
In the Taranaki Basin, PEP 38778 was surrendered on 30/03/2012.
In the Great South Basin, an extension of land has been granted to
PEP 50119. The permit now covers 33,478 sq km. PEP 50120 has
been surrendered due to the grant of the extension of land.
In the Great South Basin, PEP 50122 EX is an extension of land
application by Greymouth Gas Taranaki Ltd 50% and Greymouth Gas
Exploration Ltd 50%. The permit contains numerous exclusions.
In the Taranaki Basin, Roc Oil has notified joint venture partners of
its withdrawal from PEP 52181, subject to normal industry terms &
conditions, including necessary government approvals.
In the East Coast Basin, PEP 52676 has undergone a partial
relinquishment and now covers 995 sq km.
In the Taranaki Basin, PEP 53473 was granted to Octanex NZ Ltd
100% on 20/3/2012. The licence will expire on 19/03/2017. Work program
is as follows -
1000k 2D seismic, studies
24 months: 250k 3D seismic, studies
36 months: 1 well
60 months: studies
60 months: studies
In the Cook Strait Sub Basin, PEP 53674 has been granted over a
reduced area to Rawson Taranaki
Ltd (operator) 50% and Zeanco (NZ) Ltd 50% on 15/03/2012. The licence
will expire on 14/03/2017. Work program is as follows -
studies, geochemical sampling
24 months: 20k 2D seismic reprocessing, studies
30 months: studies, 40k magnetotelluric or 40k 2D seismic
48 months: 1 well
60 months: studies
In the Taranaki Basin, PEP 381203 has been renewed over a reduced
area to 09/08/2017 and now covers 107 sq km. Work program is as
50k 3D seismic reprocessing, studies
72 months: studies, 1 well
84 months: 40k 3D seismic
114 months: 1 well
120 months: studies
In the Taranaki Basin, an extension of duration is currently under
consideration for PEP 381204.
Papua New Guinea.
Mitsubishi, through its subsidiary Diamond Gas Niugini BV will acquire -
17% of Talisman's 39.285% interest in PRL 8
20% of Talisman's 50% interest in PRL 28
40% of Talisman's 100% interest in PPL 235
Mitsubishi, through its subsidiary Diamond Gas Foreland 239 BV will
acquire 20% of Talisman's 60% interest in PPL 239.
Mitsubishi, through its subsidiary Diamond Gas Foreland 261 BV will
acquire 40% of Talisman's 100% interest in PPL 261.
Mitsubishi, through its subsidiary Diamond Gas Foreland 268 BV will
acquire 20% of Talisman's 50% interest in PPL 269. The arm's
length value of the consideration is US$5.18 million.
Mitsui E&P Australia acquired 10% each from Sasol Petroleum PNG and
Talisman Niugini Ltd in PPL 285, with Mitsui holding 20% of the
has had its expiry date extended to 13/05/2017
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