February 2013

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

Locations
The permits database has been extended this month to include Locations ...

Industry Summary
Linc Energy Limited is pleased to announce that two independent reports have confirmed the significant potential for shale oil in the Arckaringa Basin. DeGolyer and MacNaughton estimated 103 billion barrels ...

Permit Updates and Changes
In the Clarence/Moreton Basin, Dart Energy has reached agreement to acquire 100% of PEL 445 from Arrow for a modest cash payment.  Dart will assume all the outstanding licence obligations ...

 


Monthly Update

The February 2013 GPinfo update is now available.
 


Locations

The permits database has been extended this month to include Locations.


What is a Location?

Exploration permit holders are able to set aside and identify blocks necessary to cover a discovery and then apply for a
Location over the blocks.  A Location is a mechanism for the transition of an exploration permit to a production licence or retention lease following the discovery of petroleum.  Once a Location has been declared, the permit holders may select the blocks to form the basis of an application for a retention lease or a production licence.

Please note -

  1. We have included only granted Locations, not Locations which are still under application.
  2. We have categorised Locations as Granted Oil & Gas Exploration Permits. 
  3. Locations overlay part of the Exploration permit on which they are based and so can be hidden from view in the Map Window.  To ensure all permit outlines on a layer are visible, please check View > Options and make sure that Draw all outlines for overlapping polygons within a layer is switched on.
  4. The flag to indicate that a permit is a Location is the inclusion of the word Location in the Block field.

Currently there are 25 granted Locations, as follows -



You can identify Locations via a GPinfo query in one of the following ways -




 


Industry Summary

Company News

Linc Energy Limited is pleased to announce that two independent reports have confirmed the significant potential for shale oil in the Arckaringa Basin. DeGolyer and MacNaughton estimated 103 billion barrels of oil equivalent and Gustavson Associates 233 billion barrels of oil equivalent of unrisked prospective resources in unconventional reservoirs on Linc’s Arckaringa acreage. Gustavson has also conducted a preliminary assessment of resource potential in conventional reservoirs in portions of the Arckaringa Basin, amounting to a separate 125 billion barrels of oil equivalent on an unrisked basis. (Source: Linc Energy announcement, 23/01/2013 and Energy News Premium, 23/01/2013).

Octanex NL is pleased to announce that upon grant of application area 5/07-8 EP (Derby Block) it will acquire a 25% interest in the permit for a purchase price of $1.75 million, payable to Oil Basins Ltd on completion. Oil Basins has proposed that both it and Backreef transfer a 12.5% stake to Octanex. Should this offer be accepted both parties will each own 37.5% of the Derby Block and Octanex will own 25% after grant. (Source: Octanex NL announcement, 24/01/2013 and 06/02/2013).

The Albers group of companies has entered into a binding agreement with Raisama Energy Limited to earn 34.8% interest in Raisama via a two-part placement. The initial placement will occur immediately and will result in Albers holding a 19.4% interest in Raisama for $1.14 million. The second tranche of $1.86 million is subject to shareholder approval at a general meeting. (Source: Raisama Energy announcement, 31/01/2013).

Armour Energy Limited has entered into a contract with Silver City Drilling for the supply of drilling services to carry out the planned 2013 exploration program in North Queensland and the Northern Territory. The program will commence during late April in ATP 1087 targeting the Lawn Hill Formation which is a highly prospective shale gas region. Lawn Hill will involve three vertical wells and one lateral well. Amour Energy and independent consultants have estimated there is a prospective recoverable resource of about 22 trillion cubic feet of gas. (Source: Armour Energy Limited announcement, 05/02/2013).

Armour Energy Limited has provided an update on their planned 2013 Northern Territory exploration program. Armour predicts drilling 21 wells across the Coxco Dolomite, a free-flowing reservoir in the Batten Trough, has the potential to generate a 2C contingent resource of 314 petajoules of gas. If successful, this would more than double the previously announced mean prospective resource of 156PJ for the Glyde Sub-basin, containing the Glyde 1/ST1 discovery well. A feasibility study will be undertaken to confirm the commerciality of the resources. Armour is also focused on unconventional naturally-fractured and shale gas accumulations in the Batten Trough with an estimated mean prospective resource of 18.7 trillion cubic feet. (Source: Armour Energy Limited announcement, 12/02/2013).

WestSide Corporation Ltd is pleased to announce a significant upgrade to its certified reserves after receiving a new reserves report on the Meridian SeamGas CSG gas field in the Bowen Basin. WestSide’s total net 1P reserves were up more than six-fold to 47.2 petajoules, the 2P reserves rose 34.5% to 347 petajoules and the 3P reserves increased 22% to 885 petajoules. (Source: WestSide Corporation announcement, 12/02/2013).

Buru Energy Limited is pleased to announce that RISC has completed an assessment of the prospective resources of the Basin Centred Gas System in the Laurel Formation in the Canning Basin. Based on data from the recent Buru drilling campaign and regional well and geological date, the best estimate of the unrisked gross recoverable resource in Western Australia’s Kimberley region is a volume of 47 trillion cubic feet of gas and 1177 million barrels of condensate, not including hydrocarbon liquids. The data shows there is a combination of conventional and unconventional resources, but further work is needed to assess the proportions. RISC also has analysed the prospective resources in the Yulleroo area and returned a best estimate of 6.6 trillion cubic feet of gas. (Source: Buru Energy Limited announcement, 08/02/2013).

Developments

MEO Australia Limited has provided an update in relation to the commercialisation progress of the first Tassie Shoal Methanol Plant. MEO advised it is in discussions with a multinational corporation seeking to develop a non-exclusive commercial relationship and taking a majority equity stake in the Tassie Shoal Methanol Plant. MEO has advised it has narrowed the potential buyers of methanol from the plant to three and has signed non-binding Letters of Intent with three preferred long term major methanol buyers. (Source: MEO Australia announcement, 06/02/2013).

InterOil has announced that bids for the partnering process to develop the Gulf LNG Project and condensate stripping plant using gas from the Elk and Antelope fields will close on February 28, 2013.
The InterOil Board of Directors intends to meet the Company’s advisors during the first week of March 2013 to evaluate the bids received and selecting a partner(s) for the development of the Gulf LNG Project in Papua New Guinea. (Source: InterOil announcement, 24/01/2013).

AGL Energy Limited has received approval from the Commonwealth Department of Sustainability, Environment, Water Population and Communities for Stage 1 of the Gloucester Gas Project
. Stage 1 will include up to 110 gas wells and associated infrastructure. Mike Moraza, AGL group general manager upstream gas, said the project would help secure new natural gas supplies for New South Wales homes and businesses. AGL will now work on satisfying the conditions of the EPBC Act approval and the New South Wales planning approval. (Source: AGL Energy Ltd announcement, 12/02/2013).

Rio Tinto has decided to keep its Gove Alumina Refinery in the Northern Territory after chief minister Terry Mills guaranteed a supply of gas from the state’s water and power utility for 10 years. The deal is worth about $1.2 billion, with the Northern Territory government advising that Eni would put up $500 million to upgrade infrastructure to allow gas from the Blacktip field to Gove. Meanwhile, Rio will spend $200 million converting its diesel-powered generators at the plant to gas. The decision by the NT Government to make gas available for the Gove Alumina refinery, paves the way for the Commonwealth to give detailed consideration to facilitating construction of a pipeline that would transport the gas to Gove. (Source: Energy News Premium, 13/02/2013 and Minister for Resources, Energy & Tourism announcement, 13/02/2013).

Discoveries

Chevron Corporation today announced the 20th discovery off the Western Australian coast since mid-2009 following further drilling success in the Exmouth Plateau area of the Carnarvon Basin. The Kentish Knock South 1 exploration well encountered approximately 75 meters of net gas pay in the upper Mungaroo Sands. The well is located in the WA-375-P permit area with Chevron Australia as operator and 50% interest while Shell Development (Australia) holds the other 50%. (Source: Chevron Corporation announcement, 07/02/2013).

Beach Energy Limited and joint venture partner Icon Energy Limited advise that the Halifax 1 unconventional vertical well in ATP 855P is flowing back gas at a constrained rate of 2.23 million standard cubic feet per day. This flow rate is expected to increase as the stimulation fluid is recovered and choke is opened further. (Source: Beach Energy Limited announcement 14/02/2013, Icon Energy Limited announcement 14/02/2013).

Comet Ride’s Scrubber Gully 2 well in the Mahalo block in Queensland’s Bowen Basin has intersected 7.2 metres of net coal. Scrubber Gully 2 is the first of four step-out core holes to be drilled after the recent drilling of pilot production wells in the Mira field. (Source: Comet Ridge Limited announcement, 15/02/2013)
.
 


Permit Updates and Changes

New South Wales

In the Darling Basin, PEL 422 is in the process of being renewed.

Also in the Darling Basin, PEL 424 is in the process of being renewed.

In the Clarence/Moreton Basin, Dart Energy has reached agreement to acquire 100% of PEL 445 from Arrow for a modest cash payment.  Dart will assume all the outstanding licence obligations. The agreement is subject to government approvals.

In the Gunnedah Basin, the renewals of PEL 468, PEL 468 and PEL 470 have been offered and accepted.

Geothermal

In the Sydney Basin, EL 6740 has been cancelled at the request of the holder
.


Northern Territory

In the Browse Basin, the Crux joint venture has received an offer for a 5 year retention lease over production licence AC/L 9. The joint venture has reviewed the conditions of the retention lease and has formally accepted.

In the Bonaparte Basin, a location was declared at AC/P 24 over Katandra on 04/04/2012. In addition, a retention lease application is pending over Katandra.

In the Vulcan Basin, a location was declared at AC/P 33 over Oliver on 24/06/2011.

Also in the Vulcan Basin, AC/P 40 is in the process of being surrendered.

In the Browse Basin, the year 5 work program for AC/P 48 has been varied and is now - 430 sq km 3D seismic reprocessing, geotechnical studies - $0.7m.

In the Beetaloo Basin, Hess has completed the seismic acquisition on exploration permits EP 76, EP 98 and EP 117. Following completion of the seismic program, Hess may elect to drill and evaluate 5 wells to earn 62.5% equity in the permits. Hess has until 30th June 2013 to make this election.

In the Amadeus Basin, Central Petroleum now holds 100% of EP 125 MK (Mt Kitty Block) and EP 82 M (Magee Block).

Also in the Amadeus Basin, EP 82 was renewed on 30/01/2013. The licence will expire on 29/01/2018.

In the Pedirka Basin, EP 93 was renewed on 30/01/2013. The licence will expire on 29/01/2018.

In the Money Shoal Basin, gazettal area NT 11-2 was re-released and closed on 08/11/2012.  The area received no bids and now reverts to vacant acreage.

In the Bonaparte Basin, a location was declared at NT/P 61 over Caldita on 04/07/2012.

In the Bonaparte Basin, MEO Australia has agreed to give Eni more time to decide whether to drill a follow-up to Heron South 1 in NT/P68. Under the terms of the farm-in agreement, Eni had 60 days from the completion of Heron South 1 on December 14. Eni now has until March 1 to drill a second Heron well or withdraw from the permit. Furthermore, Eni has committed to drilling a well in the Blackwood area of NT/P 68.


Joint Petroleum Development Area

In the Timor Gap, JPDA 06-103 has had its expiry date extended to 15/01/2014.  A conditional licence extension has been granted on the proviso that the joint venture secures a rig by 15/06/2013 and that the well be tested by 15/01/2014. A partial relinquishment is pending.


Queensland

In the Surat Basin, PLR 2012-1-1 and PLR 2012-1-2 closed on 14/02/2013 and are currently under consideration.

Also in the Surat Basin, ATP 336P Waldegrave has undergone a partial relinquishment and now covers a reduced area of 31 sq km.

In the Nagoorin Basin, ATP 679P now covers an increased area of 351 sq km after various blocks were added back into the licence by DEEDI.

In the Eromanga Basin, ATP 739P was granted to Black Gold Oil P/L 100% on 21/01/2013.  The licence will expire on 31/01/2017.

In the Bowen Basin, Arrow has withdrawn its renewal applications for ATP 748P and ATP 753P as well as applications for potential commercial areas PCA 8 and PCA 10.  These all revert to vacant acreage.

In the Eromanga and Surat Basins, Apiti Oil & Gas has relinquished ATP 772P, ATP 800P and ATP 801P
.

In the Bowen Basin, KOGAS has indicated it is not in a position to currently enter into a farmin agreement with Blue Energy with regards to ATP 814P.

In the Adavale Basin, ATP 863P is being renewed over a reduced area of 4,766 sq km.

In the Surat/Bowen Basin, ATP 893P and ATP 901P are in the process of being relinquished.

In the Adavale Basin, ATP 1069P was granted to Seymour Energy P/L 100% on 24/01/2013.  The licence will expire on 31/01/2017.  Overlapping applications ATP 1067P (Surat Gas) and ATP 1068P (Coomooroo Energy) were refused.

In the Eromanga Basin, ATP 1072P was granted to Surat Gas P/L 100% on 24/01/2013.  The licence will expire on 31/01/2017.

In the Bowen Basin, ATP 1079P was granted to Santana Resources Co 100% on 17/01/2013. The licence will expire on 31/01/2017. Overlapping applications ATP 1075P (Armour Energy), ATP 1076P (Planet Unconventional Energy P/L), ATP 1077P (Icon Energy Ltd), ATP 1078P (Oil Investments P/L), ATP 1080P (Blackall Oil P/L), ATP 1081P (Jurassic Energy P/L), ATP 1082P (Seymour Energy P/L), ATP 1083P (Arrow Energy P/L), ATP 1084P (Black Diamond Gas P/L) and ATP 1085P (Rawson Resources Ltd) were refused.

In the Surat Basin, PL 56 expired on 29/01/2013.

Also in the Surat Basin, CNOOC has completed the acquisition of 4% of PL 171 from BG.  Interests in the licence are Roma Petroleum 60%, Senex Energy 20%, BG Int (Aus) 16% and CNOOC Coal Seam Gas 4%.

In the Cooper Basin, production licence application PL 460 has been withdrawn.

In the Surat Basin, production licence applications PL 477 and PL 480 have been withdrawn
.


South Australia

In the Duntroon Basin, the year 1 work programs for EPP 41 and EPP 42 have been extended by 12 months from 07/07/2013 to 06/07/2014.  The licenses have had their expiry dates extended to 06/07/2019 and 06/07/2018 respectively.

In the Cooper Basin, Senex Energy has acquired Lion Petroleum’s 25% interest in PEL 115. Senex, through its subsidiary, now holds 80% and Komodo Energy 20%.

In the Cooper Basin in November 2012, Senex acquired a 5% interest in PEL 182 from Strategic Energy. This acquisition triggered certain rights for Acer under the PEL 182 joint venture to acquire additional interests. Following discussions with Senex, Drillsearch through Acer has agreed to acquire an additional 2.5% interest, taking its interest to 40%.


Tasmania

Offshore in the Bass Basin, a number of locations have been declared over discoveries in T/18P These include locations over Bass (expiring 23/05/2015), Rockhopper (expiring 23/05/2015), Trefoil (23/05/2015) and White Ibis (expiring 23/05/2015).

Onshore, receiver managers of Great South Land Minerals have scheduled an appeal against the Minister’s decision not to renew EL 14/2009.  The appeal will be heard on 22/04/2013.


Victoria

Offshore in the Gippsland Basin, gazettal areas V 11-3 and V 11-4 were re-released and closed on 08/11/2012.  The areas did not receive bids and now revert to vacant acreage.

Also in the Gippsland Basin, CIECO has withdrawn from VIC/L 26, VIC/L 27 and VIC/L 28 effective 31/12/2012.  The interest will be distributed pro-rata to the remaining BMG joint venture parties.  Following the re-distribution, interests will be Roc Oil (Vic) 37.5%, Beach Energy 37.5%, PT Pertamina 12.5% & Sojitz Energy Aust 12.5%.

In the Otway Basin, a suspension and extension request has been lodged on VIC/P 62 which is due to expire on 12/03/2013.

Also in the Otway Basin, WHL's farm-out process on VIC/P 67 received some non-binding farm-in offers. However, the company has elected not to pursue these at this time.  WHL continues to hold discussions with a number of interested parties.

In the Otway Basin, PEP 151 has had its expiry date extended to 15/01/2015.

Also in the Otway Basin, PEP 163 has had its expiry date extended to 18/10/2014.

In the Gippsland Basin, PEP 166 has had its expiry date extended to 02/10/2015.

In the Otway Basin, PEP 169 has had its expiry date extended to 24/06/2014.

In the Gippsland Basin, Beach Energy and Cooper Energy have elected not to exercise their Phase 2 farm-in option for PRL 2.  Phase 1 is suspended pending removal of the Victorian state government moratorium on fracture stimulation operations.  Following Phase 1, interests in the licence will be Lakes/Petro Tech 85%, Beach Energy 10% and Cooper Energy/Somerton Energy 5%.


Western Australia

In the Perth Basin, EP 447 is in the process of being renewed.

In the Canning Basin, Gas2Grid have transferred their interests in EP 453 to Goshawk Energy (Lennard Shelf) P/L.

In the Perth Basin, EP 484 was granted to Dynasty Metals Australia Ltd 100% on 31/01/2013. The licence will expire on 30/01/2019. Work program is as follows -

Year 1: 1 well, 35 km 2D seismic $0.32m
Year 2: 1 well, 25 km 2D seismic $0.34m
Year 3: 1 well, 40 km 2D seismic $0.375m
Year 4: 2 wells, 40 km 2D seismic $0.48m
Year 5: 2 wells, 40 km 2D seismic $0.5m
Year 6: geotechnical studies $0.23m

Also in the Perth Basin, EP 485 was granted to Dynasty Metals Australia Ltd 100% on 31/01/2013. The licence will expire on 30/01/2019. Work program is as follows -

Year 1: 1 well, 35 km 2D seismic $0.36m
Year 2: 1 well, 30 km 2D seismic $0.35m
Year 3: 1 well, 40 km 2D seismic $0.375m
Year 4: 2 wells, 40 km 2D seismic $0.48m
Year 5: 2 wells, 40 km 2D seismic $0.5m
Year 6: geotechnical studies $0.23m

In the Canning Basin, Special Prospecting Authority with Acreage Option SPA 7 AO was granted to Goshawk Energy Pty Ltd 100% on 01/01/2013. The acreage will expire on 31/12/2013.

In the Carnarvon Basin, Special Prospecting Authority with Acreage Option SPA 8 AO was granted to Fleet Resources Pty Ltd 100% on 02/01/2013. The acreage will expire on 31/12/2013.

In the Browse Basin, gazettal area W 11-3
was re-released and closed on 08/11/2012. The area received no bids and now reverts to vacant acreage.

In the Carnarvon Basin, a location was declared at WA-191-P over Fletcher/Finucane South on 12/08/2009.

In the Dampier Basin, Apache Northwest applied for a location at WA-209-P over Okapi on 22/01/2013.

In the Carnarvon Basin, locations were declared at WA-268-P over Chandon on 06/11/2009 and Yellowglen on 12/04/2010.

In the Carnarvon Basin, the WA-350-P year 4 and year 5 work programs have been swapped.

In the Carnarvon Basin, WA-36-R is in the process of being renewed.

In the Browse Basin, locations were declared at WA-274-P over Argus on 25/10/2011 and over Ichthys North/Concerto on 21/05/2012.

In the Browse Basin, a location was declared at WA-344-P over Mimia on 21/01/2010.

In the Carnarvon Basin, a location was declared at WA-364-P over Brederode on 17/06/2011.

In the Carnarvon Basin, locations were declared at WA-365-P over Kentish Knock on 14/06/2011, Scarborough on 14/06/2011 and Thebe on 14/06/2011.

In the Carnarvon Basin, locations were declared at WA-374-P over Achilles/Satyr on 04/11/2011, Eurytion Extension on 04/04/2012, Clio North on 04/04/2012 and Clio South on 04/04/2012.

In the Bremer Basin, the year 5 work program for WA-379-P and WA-380-P have been extended by 12 months from 09/01/2013 to 08/01/2014.  The licenses have had their expiry dates extended to 08/01/2015. The year 5 and 6 work programs for both permits have been varied and are now -

Year 5 - 3000 km 2D infill seismic $3.5m
Year 6 - 3000 km 2D infill seismic processing, G&G studies $1m

In the Carnarvon Basin, WA-383-P is in the process of being renewed and a location was declared over Scarborough Extension on 31/08/2012.

In the Carnarvon Basin, WA-386-P was renewed on 07/02/2013 over a reduced area of 5,212 sq km.  The licence will expire on 06/02/2018. Work program is as follows -

Year 1: geotechnical studies, licence 213 km New Dawn 2D seismic and 45 km Duvalia 2D seismic $0.35m
Year 2: 800 km 2D seismic $1.3
Year 3: seismic interpretation $0.35m
Year 4: 275 sq km 3D seismic $5.5m
Year 5: 1 well $50m

In the Carnarvon Basin, WA-387-P was renewed on 07/02/2013 over a reduced area of  2,438 sq km.  The licence will expire on 06/02/2018. Work program is as follows -

Year 1: geotechnical studies, licence 110 km 2D seismic $0.35m
Year 2: 700 km 2D seismic $1.2
Year 3: seismic interpretation $0.35m
Year 4: 275 sq km 3D seismic $5.5m
Year 5: 1 well $50m

In the Carnarvon Basin, a location was declared at WA-390-P over Equus on 01/12/2011.

In the Barrow Basin, applications have been lodged with NOPTA to surrender WA-391-P and WA-413-P.

In the Carnarvon Basin, a location was declared at WA-392-P over Sappho on 09/10/2012.

In the Browse Basin, WA-396-P and WA-397-P are in the process of being renewed.

In the Canning Basin, NOPTA has approved the WA-435-P and WA-437-P farm-out. Following approval, interests are Apache 40% (operator), JX Nippon 20%, Carnarvon Petroleum 20% and Finder Exploration 20%.

In the Rowley Sub Basin, the Year 1 work program for WA-462-P has been varied and is now – 3585 sq km 3D seismic, geotechnical studies $21.89m.

In the Rowley Sub Basin, the Year 1 work program for WA-466-P has been varied and is now -geotechnical studies, 3590 sq km 3D seismic $21.95m.

In the Carnarvon Basin, the Year 2 work program for WA-476-P has been varied and is now – 80 sq km 3D seismic, geotechnical studies $0.575m.


New Zealand

In the West Southland Basin, application APP 53626 has been withdrawn.

In the Taranaki Basin, Raisama Energy Ltd is withdrawing from its farm-in to PEP 51311. NZOG will hold 100% interest in the permit following Raisama’s withdrawal.

In the Canterbury Basin, Beach Petroleum (NZ) P/L 100% has lodged extension of land application PEP 52717 EX.

In the Southland Basin, PEP 53669 was surrendered on 08/02/2013.

In the Taranaki Basin, Pan Pacific Petroleum will increase its participating interest in the Oi 1 well to be drilled in PMP 38158 to 50%. AWE and Mitsui will participate at reduced equities of 25% and 12.5% respectively, with the option to restore their full equities in any development. NZOG will participate at 12.5%.


Papua New Guinea

In the Papuan Basin, Oil Search is offering PPL 276 for farmout.

Also in the Papuan Basin, PPL 385 was granted in October 2012 for 5 years.  Oil Search is offering 50% of PPL 385 for farmout.

In the Papuan Basin, negotiations have been initiated between PPL 259 and PRL 4 partners with regards to the formation of a Unit to include a small portion of the Stanley field that possibly encroaches into PPL 259.


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