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November 2013

GPinfo 5.7.5
Following on from the recent user survey, the November update includes a new version of the GPinfo program with a range of new features requested by users including a Locator Map, 1' Block Labels ...

GAMS 2013
New version of the Geoscience Australia Marine Seismic or GAMS database released by Geoscience Australia in October 2013 - see data layer GAMS 2013 in the SEISMIC group ...

Industry Summary
Cott Oil and Gas has carried out further seismic work on six prospects at its PPL 437 permit, including the Rosewood, Tea Tree, Candlenut and Ebony leads in the western and northern part of the licence ...

Permit Updates and Changes
In the Amadeus Basin, the year 5 work program for EP 125 has been extended by 6 months from 08/12/2013 to 06/06/2014. The licence has had its expiry date extended to 06/06/2014 ...

 


 

GPinfo 5.7.5

Following on from the recent user survey, the November update includes a new version of the GPinfo program with a range of new features requested by users.

GPinfo 5.7.5 will be installed automatically along with the monthly data update.

This is an essential software update.

Data Changes

We have added a new category of Unsuccessful applic to the Permit Status field to accommodate Queensland applications where the applicant is not the preferred tenderer. 

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The practice adopted in recent years by the Queensland Department of Mines and Energy of allocating application numbers to all applications for gazetted areas pending the formal grant of the permit has long created a confusing situation in GPinfo.  In some cases as many as 10 competing applications exist, with one of them flagged as the preferred tenderer.

Results of queries that include these permits can be misleading.  Generally you would want to exclude such permits from your queries.  The new Unsuccessful applic category allows you to easily identify them.

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Please note that the Suspended category of the Status field is now used only to indicate permits where a genuine suspension is in place.  An explanatory comment is included to provide more information on the nature of the suspension.

New Software Features

  1. Locator Map - A Locator Map option has been added to the main toolbar.   http://web2.encom.com.au/GPinfo/Nov13-1.png

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    -  Toggle the Locator Map on and off using the Locator Map button on the main toolbar.
    -  The Locator Map shows the extents of your current Map Window as a red rectangle. 
    -  Click-and-drag the Locator Map to the desired location in the Map Window.
    -  It is dynamically linked to the Map Window so it automatically changes with your map area.
    -  It is automatically captured along with the contents of the Map Window when you Copy Map.
     
  2. 1' Block Labels - The properties of the Lat/Lon Grid layer have been extended to allow the display of 1' graticular block labels.

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    -  Please ensure you are zoomed in appropriately before switching on 1' or 5' block boundaries.
    -  Right-click on the Lat/Lon Grid layer in the MAP SHEETS group and select Properties to
       change the display settings for the grid layer.
    -  Each 5' block contains 25 x 1' blocks, labelled A to Z but excluding I, in accordance with
       standard regulatory conventions.
    -  Grid lines are drawn with respect to the current map datum. Note that permits are defined in
       relation to either AGD66 or GDA94 graticular blocks, depending on the jurisdiction e.g. QLD
       uses AGD66 while SA uses GDA94. If the grid appears to be offset, it is because there is a
       mismatch between the map datum and the permit datum.
    -  The grid is automatically captured with the contents of the Map Window when you Copy Map.
    -  Tip: make the grid transparent so you can see permit boundaries through the grid.
     
  3. Cursor Location in UTM Co-ordinates - The Cursor Location fields at the right-hand side of the Status Bar have been modified so that they can now report in UTM co-ordinates plus zone for the cursor location.
     
    DMS
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    -  Click a Cursor Location field to toggle between displaying location in DMS, DD or UTM.
    -  Co-ordinates are reported with respect to the current display datum. 
    -  Click on the Map Datum field on the Status Bar to toggle between AGD66, AGD84 and GDA94.
     
  4. Clone a Query - An option has been added to the Query Manager which allows you to select an existing query, modify it in some way and then save it with a new name. 

    -  Open the Query Manager, select a query and click Clone.
    -  The original query remains unchanged. 
    -  The default name for the cloned query is the original query name followed by a numeric counter.
     
  5. Export from the Map Manager - A shortcut has been added to the Map Manager for the export of graphical data.

    -  Right-click on a layer in the Map Manager and select Export.
    -  If you have any currently selected data on that layer, the export wizard defaults to your selection.
    -  You can of course override this if you wish and export the whole layer. 
    -  This option is only available to users whose GPinfo subscriptions provide graphical export.
     
  6. End of Session Files - The ability to save and restore session files in GPinfo has been removed.  Session files were a legacy feature from earlier versions of the GPinfo system.  To record current map limits in the absence of session files, create your own user views.  See Help > Help Topics > Standard View > Define.

If you have any questions, please contact GPinfo Support on 02 9437 6255 by email.

 


GAMS 2013

The November update includes the newly released update to the Geoscience Australia Marine Seismic or GAMS database. 

First released in December 2012 and sourced from original navigation files, SNIP navigation files and digitised survey track maps, GAMS is an updated collection of navigation for marine seismic surveys in Australia.  The October 2013 release provides improved metadata together with the inclusion of additional open file surveys.

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Coverage of the GAMS 2013 data set.

The GAMS data set is the property of Geoscience Australia.  Please click here for more information.


Industry Summary

Company News

Cott Oil and Gas
has carried out further seismic work on six prospects at its PPL 437 permit, including the Rosewood, Tea Tree, Candlenut and Ebony leads in the western and northern part of the licence and the Kandis and Mango leads to the east of the Ubuntu discovery. Figures released by the company using probabilistic methods provide for resource estimates of 12 bcf of gas, best estimates of 70 bcf and high estimates of 491 bcf. Resource estimates for condensate are 0.4 mmbl for low, 3.6 mmbl for best and 27 mmbl for high. Cott said further exploration appraisal and evaluation was required to determine the existence of a significant quantity of potentially moveable hydrocarbons. (Source: Cott Oil and Gas announcement, 16/10/2013).

Galilee Energy has received a letter from the Mercantile Investment Company stating its intention to launch a proportional takeover offer for 50% of each member’s shareholding in Galilee. Mercantile plans to offer 15 cents per share. (Source: Galilee Energy announcement, 21/10/2013).

Geodynamics has decided to extend the offer period for its off-market takeover bid for all the shares in KUTh Energy. The offer will now close on 29/11/2013, unless further extended or withdrawn. The board of directors of KUTh continue to support the Geodynamics bid. (Source: Geodynamics announcement, 06/11/2013, KUTh Energy announcement, 06/11/2013).

Orica has entered into a three year gas sales agreement with Esso Australia and BHP Billiton to purchase up to 42 PJ of gas from Longford in Victoria. The agreement will begin in 2017 and will provide about 14 PJ per year over three years. The agreement will provide gas from the Gippsland Basin via the Longford processing plant and will have an oil-linked component. The arrangement allows for an extension beyond 2019. (Energy News Premium, 11/11/2013).

Octanex NL and Peak Oil & Gas have agreed to work towards a merger of the two companies. The merger is proposed to be implemented by a Scheme of Arrangement under which Peak members will exchange their Peak shares for Octanex shares for a consideration of not less than 1c to each Peak share, with the full consideration to be determined in Q1, 2014. In order to provide Peak with working capital prior to the implementation of the Scheme, Octanex will fully underwrite a rights issue by Peak, which aims to give Peak shareholders the right to subscribe for two new shares in Peak for every five held at an issue price of 1c each, to raise $1.94 million. (Source: Octanex announcement, 15/11/2013).

Developments

ExxonMobil has announced the start-up of the Kipper Tuna Turrum Project in Bass Strait. Natural gas production has commenced from the Tuna field via two new pipelines and oil is being produced from the Turrum field through the new Marlin B platform. The $4.5 billion Kipper Tuna Turrum Project is the largest domestic oil and gas development on the eastern seaboard. Production from Kipper Tuna Turrum will help maintain gas production levels from Bass Strait, which has been producing for more than 40 years. Kipper production is expected to start in 2016 after mercury removal facilities have been installed. (Source: ExxonMobil announcement, 22/10/2013).

The Gladstone LNG Project and the Australia Pacific LNG Project joint ventures have signed gas swap and infrastructure connection agreements to improve capital and operational outcomes. The new agreements will make gas transportation from the Surat and Bowen Basin fields more efficient and reduce the need for additional pipeline infrastructure. Under the deal, two pipeline connection points will be built between GLNG and APLNG infrastructure while gas swap agreements are expected to minimise gas movements and operational costs. Without this agreement both projects would need a total of 140km of additional pipelines and multiple connection points at compressor stations to each deliver its gas to Curtis Island. (Source: Origin Energy announcement, 25/10/2013).

Federal approval for Arrow Energy’s $15 billion Curtis Island LNG Plant has been delayed as Federal Environment Minister Greg Hunt takes more time to assess the potential impacts of the project. A decision had been expected on 23/10/2013, however the deadline has now been extended until December 2013. If federal approval is given the project is set to become the fourth LNG development on Curtis Island near Gladstone. (Source: Energy News Premium, 23/10/2013).

BG Group has completed transactions with China National Offshore Oil Corporation (CNOOC) for the sale of additional interests in the Queensland Curtis LNG (QCLNG) Project in Australia for US$1.93 billion. CNOOC will move to 50% interest in Train 1 of the QCLNG project and receive 20% in reserves and resources of some BG permits in the Walloon Fairway region and 25% equity in other BG permits in the Bowen and Surat Basins. Under a separate agreement, BG Group will also supply CNOOC with an additional 5 million tonnes per annum of LNG for 20 years beginning in 2015. (Source: BG Group announcement, 11/11/2013).

Exxon Mobil Corp and BHP Billiton’s proposed plan to develop the Scarborough Gas Field discovery on the Exmouth plateau offshore Western Australia has received conditional approval from Australian Environment Minister Greg Hunt. Initial plans are for a FLNG development, but there is no guarantee that the partners will go ahead with the project. Front-end engineering and design on the vessel is scheduled to start next year, with a final investment decision not due until the 2015 financial year. The FLNG vessel will be 495 m long and 75 m wide and will be capable of processing 6-7 million tonnes/year of LNG. The environmental application described the project as processing gas from 12 wells to be drilled during two phases from 2018. (Source: Energy News Premium, 12/11/2013).

Chevron has confirmed an expansion of the Gorgon LNG Project is on hold until the joint venture knows how much the three train start-up development on Barrow Island is going to cost. Chevron Chief Financial Officer Patricia Yarrington said the cost structure is different today than it was in 2009 when the first three trains were taken to final investment decision. She said the cost structure has “elevated” and that has put at risk some of Australia’s global competitiveness. She said, “from a Chevron standpoint, we are going to look at Train 4 and assess it under those new conditions and look at it relative to other opportunities in our portfolio”. Despite this, Chevron will continue with environmental approvals for Train 4. Chevron also wants to have 70% of Train 4 committed under long-term contracts by the time it reaches the FID point. (Source: Energy News Premium, 04/11/2013).

Discoveries

The Beach operated Butlers 8 well in PEL 92 on the western flank of the Cooper Basin has penetrated 6 metres of net oil pay in the Namur sandstone reservoir. The well was drilled to total depth of 1,650 metres and will be completed as an oil producer and linked up to the existing Butlers production facilities. (Source: Cooper Energy announcement, 22/10/2013).

Eni has successfully completed the Evans Shoal North 1 appraisal well in the Evans Shoal gas field in the Timor Sea. During the well production test the gas flow reached the facility constraint of 30 mmscf per day. Eni estimates that the Evans Shoal gas field contains at least 8 tcf of raw gas in place. (Source: Eni announcement, 24/10/2013).

Horizon Oil’s Tingu 1 exploration well in Papua New Guinea’s Western Province flowed at an average of 48 mmcfd with no water at the end of the clean-up flow period. The well produced an average condensate per gas ratio of 65 barrels of condensate per million cubic feet over three hours during the main flow period of testing. More analysis is planned but Horizon said the results were certainly encouraging so far. Multi-rate flow testing is planned before suspending the well for future production operations. (Source: Horizon Oil announcement, 28/10/2013).

Beach Energy and Cooper Energy have had success at the Callawonga 9 development well in PPL 220 on the western flank of the Cooper Basin. The well penetrated 6 metres of gross oil column in the McKinlay Member and the Namur Sandstone, with at least 4 metres of net oil pay. Callawonga 9 has been cased and suspended as a future oil producer.  (Source: Cooper Energy announcement, 01/11/2013).

Senex Energy has had success at the Sprigg 1 exploration well in PEL 514. The well has been cased and suspended after intersecting 6.3 metres interpreted net pay in the Murta Formation with gas shows in the Arrabury and Birkhead Formations. (Source: Senex Energy announcement, 06/11/2013).

The Pirie 1/ST1 exploration well in the South Australian Cooper Basin encountered moderate oil shows in the Birkhead Formation after the original well was sidetracked. Operator Tellus Resources has cased and suspended the well as a potential Birkhead Formation oil producer. As part of the farmin agreement with Senex Energy, the operatorship of PEL 105 will be transferred to Senex. Senex has an obligation to drill a further well in the permit by 30/06/2014. (Source: Tellus Resources announcement, 12/11/2013).

In a first for the Australian oil and gas industry, Armour Energy has successfully used multi-stage hydraulic stimulation technology on a horizontal shale well to achieve continuous gas flows from Egilabria 2. This is the first successful application of this lateral well technology created in the US on an Australian well. The well has flowed back 44% of stimulation fluids and is flowing about 13 barrels per day in conjunction with initial volumes of gas. The company expects the flow rate to increase as drilling fluid is further removed. (Source: Energy News Premium, 04/11/2013).


Permit Updates and Changes

New South Wales

In the Gunnedah Basin, PAL 2 is in the process of being renewed.

In the Eromanga Basin, PSPAPP 54 has been transferred to NSW Oil & Gas P/L.

Geothermal

In the Sydney Basin, EL 5886 has been renewed to 22/02/2016 with no reduction in area.

In the Lachlan Fold belt, the renewal of EL 7069 has been refused.


Northern Territory

In the Vulcan Basin, the year 4 work program for AC/P 4 has been extended by 6 months from 24/12/2013 to 23/06/2014. The licence has had its expiry date extended to 23/06/2015.

In the Bonaparte Basin, location NT/P 48 L was granted over Evans Shoal on 18/10/2013.

Also in the Bonaparte Basin, NT/P 61 expired on 13/10/2013. The area reverts to vacant acreage.

In the Bonaparte Basin, NT/P 76 was relinquished on 23/10/2013.

In the Bonaparte Basin, Samsung Oil & Gas Australia P/L has transferred its 30% interest in NT/P 80 to Murphy Australia NT/P 80 Oil P/L.

In the Amadeus Basin, the year 5 work program for EP 125 has been extended by 6 months from 08/12/2013 to 06/06/2014. The licence has had its expiry date extended to 06/06/2014.

In the Money Shoal Basin, applications EP(A) 214 and EP(A) 224 have been varied and now cover 5,667 sq km and 3,129 sq km respectively.

In the Daly Basin, application EP(A) 218 has been varied and now covers 9,778 sq km.

In the Pine Creek Geosyncline, application EP(A) 255 has been varied and now covers 12,280 sq km.

In the Amadeus Basin, Frontier Oil & Gas P/L has applied for L 6 over the Surprise field.

Also in the Amadeus Basin, Magellan Petroleum (NT) P/L has applied for L 7 over the Dingo field.


Joint Petroleum Development Area

In the Timor Gap, JPDA 06-101 was due to expire on 29/10/2013.  The licence is pending a decision by the ANP.

Also in the Timor Gap, the renewal of JPDA 06-105 over a reduced area is pending finalisation by the ANP.


Queensland

In the Eromanga Basin, ATP 299P has been renewed to 31/12/2016.  Drillsearch Energy acquired a further 29% in ATP 299P and the associated production licences from Santos QNT, raising its interest to 40%.

Also in the Eromanga Basin, Santos will acquire 50% of Drillsearch's 66.666% interest in ATP 549P W and will assume operatorship.

In the Eromanga Basin, ATP 582P is held 100% by Cooper-Erom Oil Inc, a subsidiary of Chelsea Oil & Gas.

Also in the Eromanga Basin, ATP 635P, ATP 720P and ATP 789P have been relinquished.

In the Surat Basin, ATP 687P has been relinquished.

In the Surat Basin, ATP 647P has undergone a partial relinquishment.  ATP 647P FO covers 76 sq km, ATP 647P BG block covers 77 sq km and the remainder of ATP 647P has been relinquished.

In the Laura Basin, Mantle Mining has reached a Conduct & Compensation Agreement (CCA) with the relevant pastoral stations holder allowing Mantle to carry out exploration activities in ATP 718P as approved by the relevant Native Title Party.  Mantle believes that all pre-requisites for the grant of the licence have been satisfied and once granted, the final tenement transfer from Calcifer to Mantle will occur.

In the Galilee Basin, ATP 744P has undergone a partial relinquishment and now covers a reduced area of 4,301 sq km.

In the Galilee Basin, ATP 780P has been relinquished.

In the Eromanga Basin, ATP 794P has undergone a partial relinquishment.  The Remainder and Brightspot blocks have been relinquished, there is no change to the Springfield and Barcoo Junction blocks, and the Regleigh and Barcoo blocks now cover reduced areas of 697 sq km and 2,638 sq km respectively.

In the Surat/Bowen Basin, ATP 852P has undergone a partial relinquishment and now covers a reduced area of 1,010 sq km.

In the Galilee Basin, ATP 984P has been relinquished.

In the Galilee Basin, Queensland Energy Resources has applied to split ATP 1015P into three smaller licences.  Details have yet to be finalised.

Real Energy Queensland has notified the Queensland Government that it intends to accept the offer of  ATP 1161P.  The company has started Native Title negotiations.

In the Surat Basin, PL 272 was granted on 02/10/2013.  The licence will expire on 01/10/2043.  As a result of the grant, ATP 692P now covers a reduced area of 390 sq km.

In the Cooper Basin, Santos has submitted renewals for a number of production licences:  PL 107 will be renewed as PL 496, PL 109 will be renewed as PL 495 and PL 110 will be renewed as PL 497.

In the Surat/Bowen Basin, BG has applied for PL 498 over 219 sq km.  The production licence application will replace PL 462, PL 465, PL 468 and part of PL 299.  PL 462, PL 465 and PL 468 will be withdrawn and PL 299 will be reduced/amended after grant of PL 498.

Arrow has applied for  number of Potential Commercial Areas over ATP 1103P:  PCA 140 (192 sq km),  PCA 141 (226 sq km), PCA 142 (204 sq km), PCA 143 (191 sq km), PCA 144 (210 sq km), PCA 145 (105 sq km), PCA 146 (189 sq km), PCA 147 (240 sq km), PCA 148 (218 sq km) and PCA 149 (243 sq km).


South Australia

In the Ceduna Basin, S 12-1 was granted as EPP 43 to Murphy Australia Oil P/L 50% (operator) and Santos Offshore P/L 50% on 22/10/2013. The licence will expire on 21/10/2019. Work program is as follows -

Year 1: G&G studies $0.5m
Year 2: 9000 sq km 3D seismic, prospect review & well planning $36.5m
Year 3: 2 wells $200m
Year 4: G&G studies $0.5m
Year 5: 1000 sq km 3D seismic $4m
Year 6: G&G studies, prospect review $4.5m

In the Ceduna Basin, S 12-2 was granted as EPP 44 to Chevron Australia New Ventures P/L on 22/10/2013. The licence will expire 21/10/2019. Work program is as follows -

Year 1: G&G studies $0.5m
Year 2: 9000 sq km 3D seismic, prospect review & well planning $36.5m
Year 3: 2 wells $200m
Year 4: G&G studies $0.5m
Year 5: 1000 sq km 3D seismic $4m
Year 6: G&G studies, prospect review $4.5m

In the Ceduna Basin, S 12-3 was granted as EPP 45 to Chevron Australia New Ventures P/L on 22/10/2013. The licence will expire 21/10/2019. Work program is as follows -

Year 1: G&G studies $0.5m
Year 2: 12000 sq km 3D seismic, prospect review & well planning $48.5m
Year 3: 2 wells $200m
Year 4: G&G studies $0.5m
Year 5: 1000 sq km 3D seismic $4m
Year 6: G&G studies, prospect review $4.5m

In the Cooper Basin, Santos has purchased Drillsearch’s 25.8% in PEL 100 for $15 million.

In the Cooper Basin, following rig release on Pirie 1, operatorship of PEL 105 was transferred to Senex Energy.

In the Cooper Basin, Santos acquired a 60% interest and operatorship in PEL 106 and PEL 513 by committing to fund a work program valued at $100-200 million.

In the Arckaringa Basin, PEL 118 and PEL 119 are being renewed.

In the Cooper Basin, PEL 218, PEL 90 and PEL 92 are being renewed.

In the Otway Basin, the year 4 work program for PEL 82 has been extended by 12 months from 04/09/2013 to 03/09/2014. The licence has had its expiry date extended to 03/09/2015.

In the Arckaringa Basin, application PELA 604 has been varied and now covers 9,412 sq km.

In the Cooper Basin, Mawson Petroleum has transferred their 25% interest in PPL 211 to Victoria Oil Exploration (1977) P/L.

In the Cooper Basin, PPL 245 has been granted to Beach Energy Ltd 75% and Cooper Energy Ltd 25% on 28/10/2013 for an indefinite term.

In the Cooper Basin, Beach Energy Ltd has applied for 17 retention licences - PRLA 33 to PRLA 49.

Also in the Cooper Basin, Senex Energy Ltd has applied for 26 retention licences - PRLA 50 to PRLA 75.

Geothermal

In the Arrowie Basin, GEL 254 and GEL 336 are being renewed.

In the Simpson Basin, GEL 366 to GEL 376 have expired. The areas revert to vacant acreage.

Sequestration

In the Eromanga Basin, Beach Energy Ltd has applied for GSELA 633 over 1,604 sq km.


Tasmania

In the Sorell Basin, T 12-2 has been re-released and closes on 22/05/2014.

In the Bass Basin, T/47P was cancelled effective 17/10/2013.

In the Otway Basin, 3D Oil has commenced discussions with potential farmin partners with relation to T/49P.


Victoria

In the Gippsland Basin, V 12-3 has been re-released and closes on 22/05/2014.

Also in the Gippsland Basin, a location was granted in VIC/P 47 over Moby on 26/08/2013.  The location expires on 25/08/2015.  In addition, Bass Strait has advised the joint venture that it intends to withdraw from the licence.

In the Gippsland Basin, NOPTA has approved the field development plan for West Seahorse and a production licence has been offered over the West Seahorse location in VIC/P 57.


Western Australia

In the Carnarvon and Rowley Sub-basins, W 12-7 and W 12-11 have been re-released and close 22/05/2014.

In the Carnarvon Basin, an application to suspend the work program and extend the licence date for WA-255-P has been lodged with NOPTA - a decision is pending.

In the Carnarvon Basin, a retention lease application has been lodged with NOPTA over the Chandon location WA-268-P LC.

In the Carnarvon Basin, the year 5 work program for WA-346-P is now: 1070 sq km seismic reprocessing, well planning, geotechnical studies $2.4m. Furthermore, a location application was submitted over Jupiter on 14/10/2013.

In the Carnarvon Basin, the year 5 work program for WA-399-P has been extended by 6 months from 07/09/2013 to 06/03/2014. The licence has had its expiry date extended to 06/03/2015. Furthermore, Apache and the other Joint Venture partners have given notice that they are withdrawing from the permit.

In the Rowley Sub-basin, W 12-6 granted as WA-495-P on 17/09/2013 to Woodside Energy Ltd 75% and Mitsui E&P Australia P/L 25%. The licence will expire on 16/09/2019. Work program is as follows -

Year 1: 3328 sq km 3D seismic $20.5m
Year 2: 3328 sq km pre-stack depth migration processing of 3D seismic, geotechnical studies $2.7m
Year 3: geotechnical studies $1m
Year 4: geotechnical & engineering studies $0.8m
Year 5: 1 well $50m
Year 6: geotechnical studies $0.7m

In the Carnarvon Basin, Santos has sold 4.1% in WA-26-L and WA-27-L to KUFPEC.

In the Carnarvon Basin, participants in WA-35-L C, WA-55-L and WA-55-L FO are Apache PVG Pty Ltd 52.501% and INPEX Alpha Ltd 47.499%.

In the Perth Basin, the year 3 work program for DR 11 has been extended by 12 months from 05/06/2013 to 04/06/2014. The licence has had its expiry date extended to 04/06/2014.

In the Canning Basin, Apache Energy has entered into an agreement with Buru Energy and Mitsubishi Corporation to earn 50% in EP 390, EP 471 and EP 473 and up to 50% in EP 438 by funding a $25 million exploration program. Furthermore, Apache has the option to earn 40% in EP 472, EP 476 and EP 477, up to 40% in EP 478 and up to 50% in EP 474. Mitsubishi has an option to farm-in for 30% in EP 474.

In the Perth Basin, EP 413 has been renewed to 22/08/2018. Work program is as follows -

Year 1: 110 sq km 3D seismic $3.5m
Year 2: 3D seismic interpretation $0.2m
Year 3: 1 well $15m
Year 4: commercial studies $0.2m
Year 5: 1 well $15m

In the Canning Basin, EP 428, EP 431 and EP 436 are being renewed.

In the Perth Basin, the year 6 work program for EP 437 has been extended by 6 months from 07/05/2013 to 07/11/2013. The licence has had its expiry date extended to 07/11/2013. Furthermore, Key Petroleum (Australia) P/L has assumed operatorship.

In the Perth Basin, EP 447 has been renewed to 22/08/2018. Work program is as follows -

Year 1: geotechnical studies $0.25m
Year 2: 1 well $5m
Year 3: 30 sq km 3D seismic $1m
Year 4: geotechnical studies $0.25m
Year 5: 1 well $5m

In the Perth Basin, the year 6 work program for EP 454 has been extended by 12 months from 26/05/2013 to 25/05/2014. The licence has had its expiry date extended to 25/05/2014.

In the Carnarvon Basin, L 13-1, L 13-2 and re-released area L 12-1 closed 14/11/2013 and are under consideration.

In the Perth and Officer Basins, L 13-3, L 13-4 and L 13-5 closed 14/11/2013 and are under consideration.

In the Canning Basin, gazettals L 12-8 and L 12-9 are under application as STP-EPA-106 and STP-EPA-107 respectively by Admiral Oil NL.

In the Carnarvon Basin, SPA 5 AO and SPA 6 AO are under application as STP-EPA-110 and STP-EPA-111 respectively by Rusa Resources (Australia) P/L.

In the Canning Basin, SPA 4 AO and SPA 3 AO are under application as STP-EPA-112 and STP-EPA-113 respectively by Hess Australia Exploration (New Ventures) P/L.

In the Canning Basin, application STP-EPA-28 has been varied and now covers 2,689 sq km.

Geothermal

In the Perth Basin, GEP 1 and GEP 2 are being relinquished.

In the Perth Basin, GEP 8 was relinquished on 22/10/2013.

In the Perth Basin, GEP 13 and GEP 15 – GEP 21 were cancelled on 10/10/2013.

In the Canning Basin, GEP 43 is being relinquished.


New Zealand

In the Southland Basin, PEP 38226 was relinquished on 08/11/2013.

In the Taranaki Basin, PEP 51151 has been renewed to 22/09/2018 over a reduced area of 241 sq km. Work program is as follows -

12 months: 60 km 2D seismic reprocessing
20 months: 50 km 2D seismic
32 months: 1 well
48 months: 40 sq km 3D seismic
60 months: technical studies
66 months: 1 well
78 months: 20 km 2D seismic reprocessing, 20 sq km 3D seismic reprocessing
96 months: 1 well

In the Taranaki Basin, Origin Energy has completed the divestment of PML 38138, PML 38140 and PML 38141. Upon closing, New Zealand Energy Corp holds 50% (operator) and L&M Energy Ltd has acquired 50%.


Papua New Guinea

In the North New Guinea Basin, Heritage Oil plc has reached agreement to earn a 70% interest in PPL 337 by drilling two shallow exploration wells.  In addition, Heritage will make a US$500,000 contribution to Kina's back costs on the licence.  In the event of a discovery, Heritage will carry Kina Petroleum's costs of up to 100 km of appraisal seismic. Heritage will take over as operator.

In the Papuan Basin, Heritage Oil plc will earn 30% of PPL 437 from Kina Petroleum by carrying Kina through its share of 100 km of seismic. In addition, Heritage will make a US$300,000 contribution to Kina's back costs on the licence.  Heritage will operate the seismic work program.  In addition, Heritage has an option to acquire a further 20% in, and operatorship of, the licence through the drilling and potential testing of a well.
 


For more information please contact GPinfo support on +61 2 9437 6255 or e-mail to info@gpinfo.com.au.

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