Lidia Novosel, Cynthia Thomas and Rob Healy will be attending the APPEA Conference in Brisbane from 16 to 19 May ...
The following 31 areas are being offered in the 2010 Federal Offshore Acreage Release ...
MEO Australia’s long-running attempt to find a partner for WA-360-P has been achieved with Brazilian state oil company Petrobras signing up to earn a 50% stake in the permit by funding the cost of drilling the Artemis 1 well ...
In the Sydney Basin, PELA 131 is a new application by Central Coast Green Energy P/L over 639 sq km ...
Lidia Novosel, Cynthia Thomas and Rob Healy will be attending the APPEA Conference in Brisbane from 16 to 19 May. We will have a stand in the registration area as usual and will be releasing the 2010 editions of the Petroleum Permits of Australasia Map and Book. If you are attending the conference please drop by to say hello.
If you need urgent GPinfo support during the week of the conference, please contact Rob Healy who will be monitoring and responding to email - firstname.lastname@example.org.
Federal Offshore Acreage Release
The following 31 areas are available in the 2010 Offshore Acreage Release:
Licence Basin Closing
Queensland Onshore Release
Licence Basin Closing
South Australian Onshore Release
Licence Basin Closing
Victorian Onshore Release
Licence Basin Closing Date
Western Australian Onshore Release
Licence Basin Closing
MEO Australia’s long-running attempt to find a partner for WA-360-P has been achieved with Brazilian state oil company Petrobras signing up to earn a 50% stake in the permit by funding the cost of drilling the Artemis 1 well. Petrobras will also pay MEO a cash bonus of $US31.5 million ($A34.8 million) and reimburse the company’s share of past costs of around $US7.5 million. WA-360-P farm-in represents Petrobras’ initial entry into Australia and is subject to Australian regulatory and government approvals, including Foreign Investment Review Board approval. (Source: www.petroleumnews.net, 14/04/2010).
The Australian Competition & Consumer Commission (ACCC) has as expected passed Shell and PetroChina’s proposed $3.4 billion bid for Arrow Energy, saying the deal was unlikely to lessen competition in the domestic market. Shell and PetroChina still have to clear the Foreign Investment Review Board, which is widely expected to take a close look at the deal and could well require additional conditions, though others believed the transparent pricing of LNG meant strong concerns about the deal were unlikely. Arrow’s board has already voted in favour of the bid, which values the company at $4.70 per share, while the company’s largest shareholder New Hope Corporation, which holds 16.7% of Arrow, has already said it would accept the Shell and PetroChina bid. (Source: www.petroleumnews.net, 15/04/2010).
Essential Petroleum Resources Limited's name change to Somerton Energy Limited was approved by shareholders at the Annual General Meeting held on 22/04/2010. Somerton Energy Ltd commenced trading on ASX with new code SNE on 05/05/2010. (Source: ASX Announcements, 30/04/2010, 05/05/2010).
Santos says it could defer a decision on whether to proceed with its Gladstone liquefied natural gas project by up to six months, though this should not affect the anticipated 2014 start date. Speaking after the company’s annual general meeting, chief executive David Knox said the final investment decision on the future of its LNG plant would be pushed back. “I will make that decision in light of all the risks we face,” The Australian quoted Knox as saying. Despite Santos pushing back its decision, Knox said there was no revision to the anticipated 2014 start-up date. The GLNG project consists of a one-train 3.6 million tonne per annum LNG plant. Santos owns 60% of GLNG and has a binding agreement with Petronas, which holds a 40% stake in the project, for 2MMtpa. The company is also in discussions with several Asian buyers for the remaining 1.6MMtpa and an announcement on these talks is expected soon. (Source: www.petroleumnews.net, 07/05/2010).
Shell is progressing its Prelude Floating Liquefied Natural Gas development (FLNG) off Western Australia, issuing a $A1.27 billion order to Korea’s Samsung Heavy Industries to build an FLNG facility. Samsung revealed the order last month, saying the contract order price would be fixed in early April. The FLNG vessel will be jointly designed by Samsung and Technip, under the Technip-Samsung consortium signed with Shell last July to work on the design, construction and installation of multiple FLNG facilities over a period of up to 15 years. The vessel is expected to be built in Samsung’s Geoje Shipyard starting in 2012 with delivery expected in 2016. The Prelude FLNG development will be capable of producing 3.5 million tonnes of LNG per annum and handling liquefied petroleum gas and condensate, taking total liquid production up to, and in excess of, 5MMtpa. A final investment decision on the project is targeted by early 2011. Commissioning of the development is expected in 2015 before first gas in 2016. (Source: www.petroleumnews.net, 16/04/2010).
InterOil Corp. has signed an agreement with Japan’s Mitsui & Co for the joint funding and operation of preliminary works for a proposed condensate stripping facility to be constructed at InterOil’s Elk-Antelope fields in Papua New Guinea’s Gulf province. The agreement involves all work required to move the project through front-end engineering and design to a final investment decision. Under the deal, Mitsui will carry InterOil for its 50% of the costs. The plant will be capable of processing 400 MMcfd of gas to yield about 9,000 b/d of condensate. The plan is to reinject the dry gas back into the reservoir for reproduction once the proposed Liquid Niugini Gas LNG facility has been built. Antelope field flowed at record levels last year when the No. 2 well recorded rates of 705 MMcfd of gas plus 11,200 b/d of associated condensate. (Source: Oil & Gas Journal www.ogj.com, 19/04/2010).
Chevron Australia has let a $180 million contract to China Offshore Oil Engineering Corp. Ltd. (COOEC) for the fabrication of process modules for the Gorgon-Jansz LNG project on Barrow Island. COOEC will build and supply more than 157 process modules for the 3-train LNG plant and domestic gas facilities on the island. Work on the modules will begin in China during January 2011 and be completed by October 2012. The company hopes this contract will lay the foundation for further work in the Australian market. The Gorgon-Jansz facilities will produce 15 million tonnes/year of LNG and 300 TJ/day of gas. First LNG is scheduled for 2014 and first domestic gas by end 2015. (Source: Oil & Gas Journal www.ogj.com, 27/04/2010).
ENI’s Kitan oil field in the Joint Petroleum Development Area, Timor Sea, is set for first production in the second half of 2011 after Timor Leste’s regulatory authority, ANP, approved the development. Italian major Eni started the development of the Kitan oil field in JPDA 06-105 between Timor Leste and the Australian coast after receiving Timor Leste government approval. The Kitan field will be developed through three subsea wells connected to the Glas Dowr floating, production, storage and offloading vessel. First production from the block, which could hold 30-40 million barrels of oil, is expected to start in the second half of next year. (Source: www.petroleumnews.net, 2704/2010).Liquefied Natural Gas Ltd has signed a lease agreement with Gladstone Ports Corporation for the site of its planned 3 million tonne per annum LNG plant at Fisherman’s Landing. The 30-year lease is conditional on the company securing a gas supply for its plant by July 1, 2011, a process that LNG Ltd said it had been actively progressing and was close to finalising. Once this condition is met, LNG Ltd will have a further three months to satisfy other outstanding conditions such as the approvals to construct the plant, which was already well advanced. (Source: www.petroleumnews.net, 10/05/2010).
Buru Energy is aiming to restore oil production from the 1984 West Kora 1 oil well in Western Australia’s Canning Basin after it was granted a production licence over the discovery. The L15 licence was awarded by the WA Department of Mines and Petroleum and runs for 21 years from April 1. The licence contains the West Kora-1 oil discovery which was drilled in 1984 and had flowed oil before the water cut increased to unproductive levels. In June 1992 operator Anzoil perforated a new interval from 1693-1696m and ran a through tubing bridge plug. However, this failed to isolate water production in the well, which was believed to originate from the original lower of three Esso perforated intervals. Further testing in 1992, and over the period December 1997 to January 1998 demonstrated the need for a workover program to isolate the water production. Buru along with its JV partners will decide on an appropriate workover program for the well. (Source: www.petroleumnews.net, 23/04/2010).
ESSO Australia and partner BHP Billiton have discovered oil and gas at the South East Remora 1 exploration wildcat well in Bass Strait. South East Remora 1, which was drilled in the offshore Gippsland Basin, found oil and gas in the Latrobe and Golden Beach groups. An Esso Australia spokesperson told PetroleumNews.net the company would carry out formation evaluation and fluid and pressure analysis to evaluate the discovery. The evaluation is expected to take several months. The spokesperson also said the JV was considering drilling other wells in the area. South East Remora-1 was drilled in water depths of 57m with the Ocean Patriot semi-submersible rig to a depth of 3602m. The well is close to the existing Marlin A platform. Esso Australia, a subsidiary of ExxonMobil, holds a 50% interest and is operator of the JV. BHP holds the remaining 50%. (Source: www.petroleumnews.net, 23/04/2010).Beach Energy and Drillsearch Energy are flowing 18 million cubic feet of gas per day from their Brownlow wet gas discovery in the PEL 106B Beach Farmin Block, Western Cooper Basin. The well, which is undergoing an extended production test, also flowed 120 barrels of associated condensate per day. Beach had drilled the Brownlow-1 exploration well as part of its farm-in work obligations to earn a 50% interest in the block. The well confirmed gas pay in a 7m thick sand in the Permian mid-Patchawarra Formation though pressure data indicated a total gas column of up to 30m. Drillsearch said the EPT was aimed at confirming the overall potential gas resources within the find, the quality of the reservoir sands as well as the long-term flow and deliverability of the discovery. Condensate production from the test will be recovered and sold via the Moomba oil terminal facilities. (Source: www.petroleumnews.net, 05/05/2010).
New South Wales
In the Sydney Basin, PELA 131 is a new application by Central Coast Green Energy P/L over 639 sq km.
The following applications have been granted:
Licence Application Basin Permit Holder Expiry Date
PEL 481 PELA 124 Gunnedah Surat Resources P/L 08/04/2012
PEL 482 PELA 125 Gunnedah Surat Resources P/L 08/04/2012
PSPA 37 PSPAPP 50 Clarence-Moreton Clarence Moreton Resources P/L 27/04/2011
PSPA 37 Licence was granted over a reduced area.
The following Geothermal Permits have been granted:
Licence Gazettal Basin Permit Holder Expiry Date
Gunnedah Macquarie Energy P/L 07/04/2013
EL 7507 G8TA_G Gunnedah Centennial Coal Co Ltd 07/04/2013
EL 7508 G8TA_H Gunnedah Centennial Coal Co Ltd 07/04/2013
EL 7509 G8TA_I Sydney Granite Power Ltd 07/04/2013
EL 7510 G8TA_O Sydney Gradient Energy Ltd 07/04/2013
EL 7511 G8TA_P Sydney Centennial Coal Co Ltd 07/04/2013
EL 7512 G8TA_R Sydney Gradient Energy Ltd 07/04/2013
EL 7513 G8TA_S Sydney Gradient Energy Ltd 07/04/2013
In the Murray Basin, EL 7366 was cancelled at the holder's request (Granite Power Ltd).
There are 12 new applications in the Georgina and McArthur basins:
Application Basin Applicant Area (sq km)
EP(A) 177 Georgina Armour Energy P/L 15,939
EP(A) 178 Georgina Armour Energy P/L 15,689
EP(A) 179 Georgina Armour Energy P/L 16,108
EP(A) 180 McArthur Imperial Oil & Gas P/L 14,976
EP(A) 181 McArthur Imperial Oil & Gas P/L 14,506
EP(A) 182 McArthur Imperial Oil & Gas P/L 12,571
EP(A) 183 McArthur Imperial Oil & Gas P/L 862
EP(A) 184 McArthur Imperial Oil & Gas P/L 11,243
EP(A) 185 McArthur Imperial Oil & Gas P/L 8,065 overlaps EP(A) 176
EP(A) 186 McArthur Imperial Oil & Gas P/L 3,473 overlaps EP(A) 171
EP(A) 187 McArthur Imperial Oil & Gas P/L 3,686 overlaps EP(A) 158
EP(A) 188 McArthur Imperial Oil & Gas P/L 1,460 overlaps EP(A) 158
In the Bonaparte Basin, NT/P 68 was renewed and will now expire on 22/02/2015.
Also in the Bonaparte Basin, Samsung Oil & Gas Australia P/L has purchased 30% of Murphy Australia Oil P/L interest in NT/P 80. The interests in NT/P 80 are now Murphy Australia P/L (operator) 40%, Diamond Resources Australia 30% and Samsung Oil & Gas Australia P/L 30%.
Applications GEP 27837, GEP 27838 and GEP 27839 were withdrawn by Gradient Energy Ltd.
Several permits have been
partially relinquished and
now cover the following areas:
EPG 29 was granted on 13/04/2010 to Gradient Energy. The licence will expire on 30/04/2015. Applications EPG 24, 25, 26, 27, 28 and 30 over the same area are cancelled.
Holloman Energy is reviewing offers from potential joint venture partners to farm-in to PEL 112 and PEL 444.
PELA 558 is a new application in the Murray Basin by Liberty Resources Ltd over 3,865 sq km.
In the Otway Basin, Adelaide Energy is acquiring interest from Beach
Energy and Origin in PRL 13.
GELA 557 is a new application by Green Rock Energy
Ltd in the Arrowie Basin over 294 sq km.
Also in the Arrowie Basin,
was renewed until 02/02/2015 with the reduction in area and now covers
over 1,459 sq km.
In the Eromanga Basin, Geothermal Permit application GELA 287 has
GELA 557 is a new application by Green Rock Energy Ltd in the Arrowie Basin over 294 sq km.
Also in the Arrowie Basin, GEL 128 was renewed until 02/02/2015 with the reduction in area and now covers over 1,459 sq km.
In the Eromanga Basin, Geothermal Permit application GELA 287 has been withdrawn.
Offshore, in the Sorrell Basin, both T/36P and T/48P were surrendered on 21/04/2010.
Onshore Tasmania, SEL 15/2010 is a new geothermal permit application by KUTh Exploration P/L over 193 sq km.
In the Murray Basin, PEP 165 was surrendered and will revert to vacant acreage.
Onshore in the Gippsland Basin, Latrobe Fuels Ltd is farming in for up to 50% in the Gormandale block PEP 166 G within PEP 166. Latrobe is required to drill, at its own cost, up to 2 wells. Drilling of the first well should commence by 31/12/2010.
Also in the Gippsland Basin, Beach Energy can earn up to 50% in PRL 2 (incl. Trifon Block) in two phases. Phase 1 - Beach can earn up to initial 15% by funding 100% of the cost of frac, post-frac testing and flow testing of Wombat 4 and Boundary Creek 2 wells, up to $10m. Phase 2 - Beach can earn up to a further 35% by funding additional appraisal and development activities, up to $40m. Beach will be operator of both phases of the program.
Offshore in the Gippsland Basin, VIC/P 55 was relinquished and VIC/RL 3 is being renewed.
In the Perth Basin, EP 320 is being renewed.
In the Bonaparte Basin, EP 386 is being renewed.
In the Browse Basin, WA-344-P is being renewed.
The following petroleum licences have had their expiry dates extended -
Licence Basin New Expiry Date
EP 321 Perth
The following Exploration Permits have been granted -
Licence Application Basin Permit Holder Expiry Date
EP 469 25/07-8 EP
Warrego Energy Limited
Offshore in the Carnarvon Basin, application for retention licence 2/08-9 R was granted as R 5 over EP 409. Retention licence R 5 will expire on 27/04/2015. EP 409 was surrendered on grant of R 5.
Also in the Carnarvon Basin, Retention Licence WA-38-R was granted over part of WA-209-P. WA-38-R covers 161 sq km and will expire on 27/04/2015. Area of WA-209-P was reduced by 2 blocks and now covers 404 sq km.
Onshore in the Canning Basin, EP 428 has undergone partial relinquishment and now covers a reduced area of 6,476 sq km. Permit term was extended until 01/12/2010.
In the Canning Basin, application for Production Licence 1/98-9 L has been granted as Production Licence L 15 over 164 sq km. The licence will expire on 31/03/2031.
SPA 4/09-0 AO was granted to David Powter T/A field Analysis and Sampling Technologies on 14/04/2010. The SPA will expire on 13/10/2010. The acreage option will expire on 14/04/2011.
In the Barrow Basin, BHP Billiton has withdrawn from WA-354-P. Apache now holds 100%.
In the Exmouth Basin, Woodside Petroleum is farming in for 65% in WA-389-P.
Exploration permits WA-280-P and WA-291-P were surrendered.
In the Perth Basin, the following Geothermal Permits have been granted -
Licence Application Permit Holder Expiry Date
GEP 39 14/08-9
GEP Green Rock Energy Ltd
There are five new applications on the east coast of South Island -
Application Basin Applicant
APP 52589 Canterbury
Rawson Taranaki Ltd
Offshore in the Taranaki Basin, exploration permit applications APP 52181 and APP 52200 were reduced in area and now cover 172 sq km 184 sq km respectively.
Crown Minerals approved interest transfer under farm-in agreement in offshore Canterbury Basin permit PEP 38262. Interests in the permit are Origin Energy Resources NZ 50% and Anadarko NZ 50%.
Offshore in the Taranaki Basin, Maari operator OMV NZ Ltd has applied for extension of PMP 38160 production licence area over PEP 38413 that is due to expire on 31/12/2010.
Also in the Taranaki Basin, Crown Minerals approved interest transfer under farm-in agreement in PEP 38451. Interests in permit are Anadarko NZ Taranaki Co (operator) 45%, Hyundai Hysco Co Ltd 30%, AWE New Zealand P/L 10%, Global Resource Holdings LLC 10% and Randall C Thompson LLC 5%.
Onshore in the Taranaki Basin, Greymouth Gas Taranaki Ltd became 100% holder of PEP 38746 and Mosaic Oil is farming in for 10% interest in PEP 51149.
Papua New Guinea
In the Papuan Basin, PPL 233 was renewed to 10/06/2014.
Also in the Papuan Basin, Production Licence PDL 8 was issued over 4 blocks of PRL 11 and covers 428 sq km. The area of PRL 11 was reduced and now covers 171 sq km.
PDL 9 was issued over
6 blocks of PRL 2 and covers 514 sq km. PRL 2 is being
renewed, its area was reduced and now covers 342 sq km.
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