Monthly Update
The April 2012 data update is now available ...

New Image Layer
The April update includes the OZ Proterozoic SEEBASE image supplied to us by FrOG Tech ...

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 ...

Industry Summary
AWE Ltd 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 ...

Permit Updates and Changes
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 ...
 


Monthly Update


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 basement-involved traps.

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
here.

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 -

  1. 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

  2. the first consistent testable structural model for the evolution of Australia’s sedimentary basins

  3. 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 tectonic history

  4. a base for a new set of maps of palaeogeography, crustal heat flow, crustal thickness, hydrocarbon generation volumes etc.

Display notes -

  1. polygon/line/point data is displayed above image data so by default parts of the image are obscured

  2. the landmass is covered by the Coast Medium Res and Coast High Res layers in the COAST ETC group

  3. 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 image underneath

  4. reset your display to factory settings at any time using Help > System Restore and selecting the default option

  5. the image will switch off at zoom levels of 1:1 million or closer

Can't see the new data?

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 been installed. 

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 removed.

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/7, 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.


Industry Summary

Company News

AWE Ltd 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 Premium, 30/03/2012).

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, 04/04/2012).

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).

Development News

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, 23/03/2012).

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, 03/04/2012)
.

Discoveries

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 -

PAL2 – 20%
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 renewed.

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.


Northern Territory

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 relinquished.

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
.


Queensland

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 17/04/2031.

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
.


South Australia

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 20/10/2012.

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 13/05/2017.

Geothermal Permits

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 GEL 422.

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 to 23/05/2012.

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 to 24/05/2014.



Victoria

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%.



Western Australia

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 suspension.

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 P/L 16.66%.

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 -

Gazettal           Application             Applicant

L 10-1               STP-EPA-0039         Exceed Energy (Australia) P/L
L 10-7               STP-EPA-0020         Buru Energy Ltd
L 10-8               STP-EPA-0021         Buru Energy Ltd
L 10-9               STP-EPA-0030         Pangaea Resources P/L
L 10-10             STP-EPA-0031         Pangaea Resources P/L
L 11-1               STP-EPA-0044         Buru Energy Ltd
L 11-2               STP-EPA-0045         Buru Energy Ltd
L 11-3               STP-EPA-0048         Strata-X Ltd

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 consideration.

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 WA-1-P.

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 Chevron.

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 28/02/2017.

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 -

Year 1: 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 -

Year 1: 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 well $20m.

In the Canning Basin, WA-419-P is in the process of being relinquished.


New Zealand

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 -

9 months: 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 follows -

6 months: studies
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 -

12 months: 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 -

12 months: 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 follows -

12 months: 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 licence.

PRL 14 has had its expiry date extended to 13/05/2017.


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