January 2013

Monthly Update
The January 2013 data update is now available ...

GAMS 2012
The January update includes the newly released Geoscience Australia Marine Seismic or GAMS data set ...

Proposed 2013 Offshore Acreage Release
The Minister for Resources and Energy, the Hon Martin Ferguson AM MP, is scheduled to announce the 2013 Acreage Release at the APPEA Conference in Brisbane (26 - 29 May 2013) ...

Industry Summary
BHP Billiton has signed a definitive agreement with PetroChina International Investment (Australia) P/L to sell its 8.33% interest in the East Browse Joint Venture and 20% interest in the West Browse Joint Venture ...

Permit Updates and Changes
In the Gunnedah Basin, the renewal of PEL 12 has been offered and accepted and is expected to be finalised towards the end of January 2013 ...

 


Monthly Update

The January 2013 GPinfo update is now available.

 


GAMS 2012

The January update includes the newly released Geoscience Australia Marine Seismic or GAMS data set. 

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. 



Coverage of GAMS 2012 data set.


The GAMS data set is the property of Geoscience Australia.  Please click here to view metadata.



2008 Browse Basin survey Omar 3D - general survey information in the Details Window (left), individual line specifics in the Browser Window (bottom) and spatial location highlighted in red in the Map Window (right).


Map Manager Layer Structure

A new layer called GAMS 2012 will automatically be created in the SEISMIC group when you first start a GPinfo session after the January update has been installed. 

The SNIP database is still available via layer SNIP 2005, but all SNIP subsets and theme layers have now been removed.  Although much of the SNIP data has been absorbed into GAMS, SNIP is still useful for coverage of New Zealand and onshore Australia, neither of which are included in GAMS.

The OVERLAYS group, which contains a series of proprietary seismic data sets, is now nested inside the SEISMIC group.



By default, the SEISMIC group is located between the COAST ETC and IMAGES groups, towards the bottom of the Map Manager hierarchy.  We suggest that the appropriate location for SEISMIC is above the PERMITS group, as shown.  This will force 3D seismic polygons to appear over permits rather than under them when the layers are rendered in the Map Window.

If seismic data is of no interest to you, switch the group off and leave it in the default location. 

However, if it is of interest, please move the group as follows -

  • Collapse the SEISMIC group by clicking on the '-' to the right of the group name in the Map Manager.
  • Drag-and-drop the SEISMIC layer so that it is above the PERMITS group in the Map Manager.

Can't see the new data?

Correct display of the new data structure requires a modification to your GPinfo configuration file.  This should happen automatically the first time you start a GPinfo session after the January update has been installed.

If the January update has been installed but the new structure has not been applied, you can force GPinfo to make the required structural changes by selecting View > Options > Updates and clicking on the Update GPinfo system layers now button.

For assistance, please contact GPinfo support.

 


Proposed 2013 Offshore Acreage Release

The Minister for Resources and Energy, the Hon Martin Ferguson AM MP, is scheduled to announce the 2013 Acreage Release at the APPEA Conference in Brisbane (26 - 29 May 2013).

Areas shortlisted for inclusion in the 2013 Release can be found in this month’s edition of GPinfo.  Please note that the proposed areas and associated boundaries have not been finalised, are still the subject of consultation with stakeholders and are subject to change prior to the launch of the Acreage Release by the Minister. Any work undertaken by companies in relation to future bids prior to the launch of the Acreage Release in May2013, is done so at own commercial risk and cost.

 

Permit

Basin

AC 13-1, AC 13-2, AC 13-3, AC 13-4

Vulcan

NT 13-1, NT 13-2

Bonaparte

NT 13-3, NT 13-4, NT 13-5

Petrel

V 13-1

Otway

V 13-2

Gippsland

W 13-1, W 13-2, W 13-3, W 13-4, W 13-5

Browse

W 13-6, W 13-7, W 13-8, W 13-9, W 13-10, W 13-14, W 13-15, W 13-16, W 13-17, W 13-18

Carnarvon

W 13-11, W 13-12, W 13-13

Dampier

W 13-19

Houtman/Abrolhos

W 13-20

Perth

For further information, please contact petroleum.exploration@ret.gov.au.

Cash Bidding

The Australian Government has decided to incorporate cash-bidding into the offshore petroleum acreage release from 2014 onwards.  A cash-bidding system will be used to allocate offshore petroleum acreage in mature areas or areas containing known petroleum accumulations. The existing work program bidding system will be maintained for all other areas.

Cash bidding is expected to prevent over-exploration in areas where none or little may be required and ensures the release of these areas is equitable, economic and efficient.  The Government recognises that in a global context, most of Australia’s petroleum basins have been lightly explored and for these areas, the existing work program bidding system will continue.


Click here to view a fact sheet on competitive cash bidding from the RET website.

(Source: Department of Resources, Energy & Tourism Australian Petroleum News, Dec 2012).
 


Industry Summary

Company News

BHP Billiton has signed a definitive agreement with PetroChina International Investment (Australia) P/L to sell its 8.33% interest in the East Browse Joint Venture and 20% interest in the West Browse Joint Venture for a cash consideration of US$1.63 billion. Existing Joint Venture partners Shell, BP, Mitsui, Woodside and Mitsubishi have a customary period to decide whether they will match the PetroChina offer through pre-emptive rights. The transaction is subject to regulatory approval. (Source: BHP Billiton announcement, 12/12/2012).

MEO Australia Ltd and Eni Australia Ltd have agreed to defer the election deadline for the Blackwood well by one month to 04/02/2013. In the event Eni elects not to drill a well in the Blackwood area, MEO will regain 100% interest in the Blackwood area.  (Source: MEO Australia Ltd announcement, 13/12/2012).

Santos has executed a farm-in agreement with Tamboran Resources P/L to earn up to 75% in EP 161 in the Georgina Basin, and in EP 162, EP 189 and EP(A) 299 in the McArthur Basin. Santos will immediately earn a 50% operated interest in the four permits by funding a $41 million phase one work program within three years. Santos has the option to earn a further 25% stake by agreeing to fund a $30 million phase two work program. Furthermore, Santos has agreed to acquire a 14% interest in Tamboran for $10 million. (Source: Santos announcement, 12/12/2012).

Transfield Services has secured $65 million in contracts on two major gas projects. Transfield won a maintenance services contract worth $45 million at Woodside’s Western Australia offshore oil and gas production facilities with work starting in 2013. The company also won a $20 million contract to install and complete a series of coal seam gas wells in central Queensland for QGC. Work is expected to start in December and be completed by June 2013. (Source: Energy News Bulletin, 11/12/2012).

Icon Energy Ltd and Shantou SinoEnergy Co Ltd have agreed to extend the completion date for a gas sales agreement to deliver 40 million tonnes of LNG or 2 million tonnes per annum for 20 years. Icon will now have until 30/06/2014 to provide a reserves certificate of at least 2 trillion cubic feet of gas on a proved plus probable basis. Icon will also need to demonstrate it has authorisation for development of feedstock fields and associated LNG facilities. (Source: Icon Energy Ltd announcement, 19/12/2012, Energy News Premium, 20/12/2012).

Origin Energy Ltd has signed a long-term gas sales agreement with the MMG Group to supply gas for its existing Century Mine and the development of the Dugald River Project. Under the agreement, Origin will supply MMG with a total volume of up to 22 petajoules of gas over a seven year period, commencing with supply to Century Mine in 2013. The gas will be sourced from Origin’s east coast fuel portfolio. In a separate deal, Origin has entered into an agreement to sell a portion of its future oil and condensate production in exchange for US$300 million up front. The deal will start from 2015 and take oil from its Australian and New Zealand portfolio, with the cash used to retire existing debt. Goldman Sachs is a counterparty in connection with the transaction. (Source: Origin Energy announcements, 20/12/2012 and 21/12/2012).

Nexus Energy Ltd advises it has exercised a put option to sell a 2% stake in the Crux AC/L 9 development to Shell Development (Australia) P/L for $75 million. The right to sell Shell a 2% stake in the project was agreed at the time of the consolidation of interest transaction with Shell and Osaka Gas. Nexus will retain a 15% stake in the project, Shell now taking an 82% operating interest, while Osaka Gas retains 3%. Nexus said it made the decision to make the sale after reviewing its short-term funding obligations. (Source: Nexus Energy announcement, 19/12/2012).

Buru Energy Ltd announced that its Ungani drilling has confirmed the high quality of the field. Initial independent volumetric estimate by RISC of gross 2C contingent resources were up 1.9 million barrels of oil from previous estimates. Estimates of 2C resources at the Ungani field stands at 9.9 million barrels with further upside potential of up to 20 million barrels following completion of 3D seismic survey and further appraisal drilling in 2013. RISC also said the recently drilled Ungani North 1 led to an assessment of 6 million barrels of oil for the Ungani North area. (Source: Buru Energy Ltd announcement, 17/12/2012).

Beach Energy has advised that oil production has commenced through the new Western Flank flowlines which are tied-in to the Moomba facility. Dry and wet testing and commissioning of the Growler to Lycium, Callawonga to Lycium and Lycium to Moomba flowlines is complete and oil is now flowing through these lines to Moomba. Construction of the Bauer to Lycium flowline is currently underway with expected capacity of about 10,000 barrels of oil per day and is expected to be completed in the first quarter of 2013.  (Source: Beach Energy announcement, 12/12/2012).

Coalbank Ltd has sold its subsidiary Surat Gas P/L to Gobi Lithium Ltd (to be renamed Sierra Oil Ltd) for an up-front payment of $250,000 and a scrip-based offer representing approximately 27% of the issued capital of Sierra Oil. (Source: Coalbank Ltd announcement, 21/12/2012).

Fortescue Metals Group Ltd has terminated the agreement with Oil Basins Ltd to acquire an 18% stake in Oil Basins Ltd and to farm in for 25% in 5/07-8-EP after the granting of the permit. (Source: Oil Basins Ltd announcement, 15/01/2013).

Developments

BHP Billiton and Esso have each committed $496.3 million to the Longford Gas Conditioning Plant project as part of the Gippsland Basin Joint Venture. The Longford facility processes oil and gas from Bass Strait, and the new gas conditioning plant will remove carbon dioxide from the gas. The upgrade is designed to allow the plant to process about 400 million cubic feet of gas per day, with the processed gas to have less than 3% of CO2. Saleable gas production is being targeted for 2016, with construction work on the upgrade slated to begin in Q3 2013. (Source: Energy News Premium 13/12/2012, The Australian, 13/12/2012).

Oceaneering Services P/L has been awarded the contract to commission, operate and maintain the Red Gully Gas and Condensate Processing Facility located near Gingin, Western Australia. The commissioning procedures are now being established with Oceaneering in consultation with design engineers from Momentum Engineering, construction engineers from Primero Group, together with Empire personnel. The commissioning will now not be undertaken in stages commencing in January 2013 as was initially planned but will instead be undertaken once the entire facility is handed over from Primero Group at practical completion stage, expected to occur in March 2013. (Source: Empire Oil & Gas NL announcement, 17/12/2012).

The Directors of Liquefied Natural Gas Ltd are pleased to advise that the estimated total cost of the Gladstone Fisherman’s Landing Project worked out by engineering, procurement and construction contractor China Huanqiu Contracting & Engineering Corporation (HQC) are broadly in line with previous expectations. Furthermore, HQC and LNG Ltd are closer to signing a final engineering, procurement and construction (EPC) contract, with the pair now on the third draft of the agreement which should be finalised during the first quarter of 2013. The EPC is a key contract required for the project to progress to final investment decision. (Source: Liquefied Natural Gas Ltd announcement, 18/12/2012).

Toll Mermaid Logistics Broome has been awarded a five year contract worth $20 million to provide supply base services to INPEX in Broome, Western Australia. Under the contract Toll Mermaid will develop dedicated infrastructure and provide various services at its Broome supply base to support INPEX’s Ichthys LNG Project development drilling works. (Source: Energy News Bulletin, 13/12/2012).

Leighton Contractors has won a $923 million contract to undertake the Ichthys LNG Project onshore facilities’ main civil works in Blaydin Point, Darwin. It also has won a $280 million, four year operations and maintenance contract for the temporary site facilities works at Blaydin Point. On the temporary site facilities contract Leighton will be working with Morris Corporation to deliver operations and maintenance services, with service mobilisation expected to start in February. (Source: Energy News Premium, 31/12/2012)
.

Discoveries

Beach Energy has reported Moonta 1 in PEL 218 of the Cooper Basin was flowing at a maximum controlled rate of 2.6 million cubic feet per day and is currently flowing at 1.6MMscfd through a 1.5" choke. Moonta 1 achieved the highest flow rate of the three PEL 218 Permian unconventional exploration wells that Beach has flow tested. Moonta 1 was designed to prove up the basin centred gas play and stimulate in nine stages through the Patchawarra formation and a single stage in the Murteree shale. With gas now flowing from Moonta 1, the basin centred gas play has been established and Beach will now refine its understanding of the play in the upcoming program. (Source: Beach Energy announcement, 18/01/2013).

Comet Ridge Ltd has had success at its Mira 3, Mira 4 and Mira 5 wells located in the Queensland Bowen Basin. Mira 3 intersected 8.9 metres of coal over four separate, closely spaced intervals in the Castor Pollux reservoir. Wireline testing was conducted on all four of the coal intervals, indicating good to excellent coal productivity at the location. While Mira 4 and Mira 5 both intersected 8.7m of coal over four separate closely spaced intervals in the Castor Pollux reservoir. The three wells have been suspended as future pilot production wells. (Source: Comet Ridge Ltd announcements, 02/01/2013, 08/01/2013 and 14/01/2013).

Chevron Australia has made two significant gas discoveries offshore Western Australia. The Pinhoe 1 exploration well encountered approximately 60 metres of net gas pay in the Barrow and Mungaroo Sands. The Arnhem 1 exploration well confirmed 45.5 metres of net gas pay in the upper Mugaroo Sands. Chevron believes t
he two discoveries are significant as they are located further out from other discoveries in the Greater Gorgon and Wheatstone development regions in the Carnarvon Basin, providing development potential across a much broader province. (Source: Chevron announcement, 27/12/2012).
 


Permit Updates and Changes

New South Wales

In the Gunnedah Basin, the renewal of PEL 12 has been offered and accepted and is expected to be finalised towards the end of January 2013.

In the Gunnedah Basin, PEL 452 is in the process of being renewed
.


Northern Territory

In the Vulcan Basin, AC/RL 6 was renewed to 03/01/2017.

In the Browse Basin, AC/RL 8 was renewed to 28/11/2017.

In the Amadeus Basin, EP 106, EP 112 and EP 115 have had their expiry dates extended to 27/05/2015, 20/07/2015 and 16/04/2014 respectively.

In the Georgina Basin, EP 127 and EP 128 have had their expiry dates extended to 13/12/2014 and 13/06/2015 respectively.

In the Pedirka Basin, EP 134 has had its expiry date extended to 25/02/2014.

In the Daly, Wiso and Victoria River Basins, EP 167, EP 168 and EP 198 were granted to Pangaea (NT) P/L 100% on 10/01/2013. The licenses will expire on 09/01/2018.

In the McArthur Basin, EP 174 and EP 190 were granted to Armour Energy Ltd 100% on 11/12/2012. The licenses will expire on 10/12/2017.

In the Amadeus Basin, EP 82 has had its expiry date extended to 01/09/2013.

In the McArthur Basin, EP(A) 243 has had its application varied and now covers a reduced area of 82 sq km.

In the Pine Creek Geosyncline, EP(A) 255 has had its application varied and now covers a reduced area of 13,580 sq km.

In the McArthur Basin, Paltar Petroleum Ltd 100% has applied for EP(A) 308 over 249 sq km.

In the Petrel Sub Basin, MEO Australia Ltd has executed binding agreements with Finder Exploration Ltd to acquire 65% interest and operatorship in NT/P 79 by reimbursing Finder $200,000.

In the Timor Basin, NT/RL 2 and NT/RL 4 have been renewed to 20/12/2017.


Queensland

Offshore, in the Carpentaria Basin, Q/23P has had its year 6 work program varied to 150 sq km 3D seismic and G&G studies ($2m).

Onshore, In the Eromanga Basin, ATP 299P is in the process of being renewed.

Also in the Eromanga Basin, ATP 539P is in the process of being renewed over a reduced area of 1,239 sq km.

In the Bowen Basin, ATP 553P was renewed to 30/11/2013.  Work program from 11/12/2012 to 30/11/2013 consists of G&G studies and 2 exploration wells (Cotton Gin 1 and New Fowler 1).

In the Maryborough Basin, ATP 674P was renewed to 31/12/2016 over a reduced area of 1,315 sq km.

Also in the Maryborough Basin, ATP 733P was granted on 21/12/2012.  The licence will expire on 31/12/2016.  Holders are: Blue Energy/Eureka Petroleum P/L 75% & Beach Energy/Australian Unconventional Gas P/L 25%.

In the Clarence/Moreton Basin, ATP 746P has undergone a partial relinquishment and now covers a reduced area of 2,998 sq km.

In the Galilee Basin, work program for ATP 799P is as follows:  Years 1-4 (01/03/2010 to 28/02/2014) - 3 core wells, 100km 2D seismic, G&G and hydrological studies.

In the Adavale Basin, Red Sky Energy and Resolve Geo have mutually terminated Red Sky's farm-in to ATP 946P and Resolve Geo P/L now holds 100% of both the conventional and CSG interests.

CNOOC failed to obtain Chinese Government approvals to increase its interest from 50% to 60% in ATP 991P, ATP 996P, ATP 999P, ATP 1005P, ATP 1008P, ATP 1127P, ATP 1130P, ATP 1137P and ATP 1150P and the agreement with Exoma Energy lapsed on 31/12/2012.

In the Bowen Basin, Bow Energy withdrew its application for ATP 1053P No decision has yet been made on whether to appoint a new preferred  tenderer.  Other bids for the area included: ATP 1051P by Eureka Petroleum P/L, ATP 1052P by Stanwell Corp Ltd, ATP 1054P by QCoal P/L and ATP 1055P by Australia Pacific LNG.

In the Carpentaria Basin, ATP 1087P was granted to Armour Energy Ltd 100% on 19/12/2012.  The licence will expire on 31/12/2016.  Work program for Year 1 (2013) is for 3 vertical wells, 1 lateral well and seismic.

In the Bowen Basin, PL 399 was granted over the Polaris field on 24/12/2012.  The licence will expire on 23/12/2042.  As a result, ATP 768P FO Block now covers a reduced area of 121 sq km.

In the Surat/Bowen Basin, PL 401 was granted over the Cameron field on 24/12/2012.  The licence will expire on 23/12/2042.  As a result, ATP 852P now covers a reduced area of 1,014 sq km.

In the Surat Basin, PL 408 was granted over the Combabula field on 24/12/2012.  The licence will expire on 23/12/2042.  As a result, ATP 606P now covers a reduced area of 863 sq km.

Also in the Surat Basin, PL 443 was granted over the Owen Field on 24/12/2012.  The licence will expire on 23/01/2042.  QGC applied for PPL 443 over Arrow's ATP 676P/PL 253 with consent from Arrow.  As a result, ATP 676P and PL 253 now cover reduced area of 1,068 sq km and 218 sq km respectively
.


South Australia

In the Ceduna Basin, BP Developments Australia P/L is partially exempt from compliance with the EPP 37 year 1 work program. Year 1 is now - 2,920 sq km 3D seismic $18m.

In the Cooper Basin, the year 4 work program for PEL 113 has been extended by 6 months from 30/04/2013 to 29/10/2013. The licence has had its expiry date extended to 29/10/2014.

In the Cooper Basin, PEL 114 area has been reduced due to the grant of PRL 31. PEL 114 now covers 446 sq km.

In the Otway Basin, PEL 496 was surrendered on 19/12/2012.

In the Murray Basin, PEL 610 was granted to Dunstone 100% on 10/12/2012. The licence will expire on 09/12/2017. Work program is as follows -

Year 1: G&G studies
Year 2: G&G studies
Year 3: G&G studies
Year 4: G&G studies
Year 5: 1 well

In the Cooper Basin, Victoria Oil Exploration (1977) P/L 40%, Impress (Cooper Basin) P/L 25%, Permian Oil P/L 20% and Springfield Oil & Gas P/L 15% have applied for PPLA 242 over 8 sq km.

In the Cooper Basin, the year 4 work program for PRL 17 has been extended by 12 months from 28/01/2013 to 27/01/2014. The licence has had its expiry date extended to 27/01/2015.

In the Cooper Basin, PRL 31 was granted to Santos Ltd 100% on 08/01/2013. The licence will expire on 07/01/2018.

Geothermal

In the Arrowie Basin, the year 2 work program for GEL 181 has been extended by 12 months from 22/11/2012 to 21/11/2013. The licence has had its expiry date extended to 21/11/2017.

In the Cooper Basin, GEL 185 has expired and is not being renewed while GEL 281 is in the process of being renewed.


Tasmania

Geothermal


Onshore Tasmania, SEL 45/2007 expired on 19/12/2012.


Western Australia

In the Canning Basin, Fortescue Metals Group has terminated the agreement with Oil Basins for 25% farm-in right to 5/07-8-EP.

In the Perth Basin, the year 3 work program for DR 11 has been extended by 5 months from 04/01/2013 to 04/06/2013. The licence has had its expiry date extended to 04/06/2013.

In the Canning Basin, DR 9 expired 19/12/2012. The area reverts to vacant acreage.

In the Canning Basin, EP 104 is in the process of being renewed.

Also in the Canning Basin, the year 4 work program for EP 129 has been extended by 12 months from 31/01/2013 to 31/01/2014.The licence has had its expiry date extended to 31/01/2015.

In the Carnarvon Basin, the EP 325 work program is pending suspension.

In the Canning Basin, the year 6 work program for EP 438 has been extended by 6 months from 31/01/2013 to 31/07/2013.The licence has had its expiry date extended to 31/07/2013.

In the Canning Basin, the year 5 work program for EP 448 has been varied and is now - 100 km geochemical studies, geotechnical studies $2m.

In the Canning Basin, EP 453 is in the process of being renewed.

In the Carnarvon Basin, EP 483 was granted to Finder No 3 P/L 100% on 07/01/2013. The licence will expire on 06/01/2019. Work program is as follows -

Year 1: 1500 km 2D seismic reprocessing $0.25m
Year 2: 115 sq km 3D seismic $1.92m
Year 3: geotechnical & environmental studies $0.3m
Year 4: 1 well $6.1m
Year 5: geotechnical studies $0.1m
Year 6: geotechnical & commercial studies $0.15m

In the Perth Basin, L 11 is in the process of being renewed.

In the Browse Basin, BHP Billiton has signed a definitive agreement with PetroChina International Investment (Australia) P/L to sell its 8.33% interest in the East Browse Joint Venture R 2, TR/5, WA-30-R, WA-31-R, WA-32-R and 20% interest in the West Browse Joint Venture WA-275-P, WA-28-R, WA-29-R for a cash consideration of US$1.63 billion. Existing Joint Venture partners have a customary period to decide whether they will match the PetroChina offer through pre-emptive rights.

In the Canning Basin, gazettal L 10-6 is under application as STP-EPA-0028 by Pangaea Resources P/L 100%.

In the Barrow Basin, TP/25 was granted to Finder No 3 P/L 100% on 07/01/2013. The licence will expire on 06/01/2019. Work program is as follows -

Year 1: 1500 km 2D seismic reprocessing $0.25m
Year 2: 115 sq km 3D seismic $1.92m
Year 3: geotechnical & environmental studies $0.3m
Year 4: 1 well $6.1m
Year 5: geotechnical studies $0.1m
Year 6: geotechnical & commercial studies $0.15m

In the Carnarvon Basin, the participating interests for WA-191-P exclude the Fletcher & Finucane Fields and are Santos Ltd 37.502%, KUFPEC (Perth) P/L 37.498% and JX Nippon Oil & Gas Exploration (Australia) P/L 25%.  WA-191-P F represents interests in the Finucane field only which are Santos Ltd 41.598%, KUFPEC (Perth) P/L 33.402% and JX Nippon Oil & Gas Exploration (Australia) P/L 25%. 
WA-191-P FL represents interests in the Fletcher field only which are Santos Ltd 55.464% and KUFPEC (Perth) P/L 44.536%.

In the Dampier Basin, a correction was made to the NOPTA register for WA-209-P. The licence renewal started from 09/01/2012 instead of 28/12/2011. Expiry date is now 08/01/2017.

In the Carnarvon Basin, Woodside has entered an agreement with Santos to sell its 8.2% interest in the Mutineer Exeter oil project, WA-26-L and WA-27-L. The agreement is subject to customary approvals and is expected to be completed in Q1 2013.

In the Browse Basin, the year 6 work program for WA-385-P has been extended by 6 months from 20/10/2012 to 20/04/2013. The licence has had its expiry date extended to 20/04/2013. The year 6 work program has also been varied and is now - 560 km 2D seismic, 12 km 2D well-tie lines, 175 km 2D PreSDM reproc, 571 km 2D seismic inversion, studies $1.645m.

In the Dampier and Barrow Basins, Santos has sold its 45% interest in WA-38-R and its 50% interest in WA-41-R to Hydra Energy (WA) P/L, subject to customary approvals expected in early 2013.

In the Carnarvon Basin, Murphy Australia Oil P/L has transferred title interest in WA-476-P to Murphy Australia WA-476-P Oil P/L
.

Geothermal

In the Perth Basin, GEP 14 is in the process of being surrendered.

In the Carnarvon Basin, GEP 30, GEP 31, GEP 32, GEP 33, GEP 34, GEP 35 and GEP 36 are in the process of being surrendered.

In the Perth Basin, GEP 8 has been transferred to CSIRO.


New Zealand

In the Great South Basin, 12GS2 was granted as PEP 54863 to Shell GSB Ltd 59% (operator), OMV New Zealand Ltd 26% and Mitsui E&P Australia P/L 15% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

12 months: studies, 500 km 2D seismic reprocessing
18 months: 2000 km 2D seismic, remote sensing study
24 months: studies
30 months: studies
42 months: 1500 sq km 3D seismic
48 months: studies
60 months: 1 well

In the East Coast Basin, 12PEG1 was granted as PEP 54858 to Anadarko New Zealand Company 100% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

12 months: 2600 km 2D seismic, 1380 km 2D seismic reprocessing, studies
24 months: studies
36 months: 750 sq km 3D seismic, studies
48 months: studies
60 months: 1 well

In the East Coast Basin, 12PEG2 was granted as PEP 54861 to Anadarko New Zealand Company 100% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

12 months: 1700 km 2D seismic, 1380 km 2D seismic reprocessing, studies
24 months: studies
36 months: 1250 sq km 3D seismic, studies
48 months: studies
60 months: 1 well

In the Taranaki Basin, 12TAR3 was granted as PEP 54876 to Cheal Petroleum 50% (operator) and East West Petroleum (NZ) 50% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

12 months: 200 km 2D seismic, 1 well
24 months: 40 km 2D seismic
36 months: 1 well, studies
48 months: 10 sq km 3D seismic
60 months: studies

In the Taranaki Basin, 12TAR4 was granted as PEP 54877 to Cheal Petroleum 70% (operator) and East West Petroleum (NZ) 30% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

12 months: 1 well
24 months: 200 km 2D seismic reprocessing, 1 well
36 months: studies, 1 well
48 months: 1 well
60 months: studies

In the Taranaki Basin, 12TAR5 was granted as PEP 54879 to Cheal Petroleum 50% (operator) and East West Petroleum (NZ) 50% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

12 months: 1 well
24 months: 100 km 2D seismic reprocessing
36 months: 1 well, studies
48 months: 1 well
60 months: studies

In the Taranaki Basin, 12TAR6 was granted as PEP 54873 to Tag Oil (NZ) Ltd 100% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

12 months: 100 km 2D seismic reprocessing, 1 well
24 months: 60 km 2D seismic
36 months: 1 well, studies
48 months: 1 well
60 months: studies

In the Taranaki Basin, 12TAR7 was granted as PEP 54867 to NZEC Manaia Ltd 60% (operator) and NZOG 38259 Ltd 40% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

18 months: studies, 70 km 2D seismic, 1 km 2D seismic reprocessing
36 months: studies, 30 sq km 3D seismic
48 months: 1 well
60 months: studies

In the Taranaki Basin, 12TAR8 was granted as PEP 54857 to NZOG Canterbury Ltd 100% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

24 months: studies, 400 km 2D seismic, 1000 km 2D seismic reprocessing
36 months: 300 sq km 3D seismic, studies
60 months: 1 well

In the Taranaki Basin, 12TAR9 was granted as PEP 54865 to Todd Exploration Ltd 80% (operator) and Cue Taranaki Ltd 20% on 11/12/2012. The licence will expire on 10/12/2017. Work program is as follows -

30 months: studies, 285 sq km 3D seismic
48 months
: 1 well, studies

The following areas in the 2012 Block Offer were not awarded and so now form part of the area available for application in the 2013 Offshore Block Offer - 12CB1, 12CB2, 12EC2, 12GS1, 12MUR1, 12STH1, 12TAR10, 12TAR11, 12TAR12, 12TAR13, 12TAR14, 12WAI1 and 12WC1

In the Canterbury Basin, application APP 52614 has been withdrawn.

In the West Southland Basin, application APP 53621 has been withdrawn.

In the East Coast Basin, Apache has informed TAG Oil that it will elect not to undertake the Phase 2 program for permits PEP 38348, PEP 38349 and PEP 50940 under the East Coast Basin farm-out dated 01/09/2011.

In the West Coast Basin, PEP 38526 was renewed over a reduced area of 143 sq km. The licence will expire on 04/09/2017.

In the Taranaki Basin, PEP 51149 now covers a reduced area of 439 sq km due to the 2013 Block Offer area 13TAR.

In the Taranaki Basin, Extension of Land applications PEP 51152 EX and PEP 51153 EX have been withdrawn.

In the Taranaki Basin, PEP 51155 EX has been reduced and now covers 23 sq km.

In the Taranaki Basin, L&M Energy Ltd has exercised its pre-emptive right in respect to PEP 53247. Mosaic Oil NZ Ltd had previously said it was selling its 75% interest in the permit. Following completion of the transaction L&M will hold 100% in the permit.

In the Taranaki Basin, prospecting permit PEP 54827 was granted to Schlumberger Seaco Inc 100% on 20/12/2012. The licence will expire on 19/06/2014. Work program is as follows -

8 months- 4000 sq km 3D seismic
18 months: 1600 sq km 3D seismic


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