December 2015 GPinfo Update                                                                                          


 


Data Update

 

The December 2015 data update is now available …

 

Industry Summary

 

Royal Dutch Shell plc has announced that its acquisition of BG Group plc has received unconditional merger clearance from the Australian Competition and Consumer Commission. ACCC chairman Rod Sims said the regulator had decided that the proposed acquisition is “unlikely to substantially lessen competition in the wholesale natural gas market

 

Permit Updates and Changes

 

In the Sydney Basin, the PEP 11 partners lodged a suspension, extension and variation application with NOPTA on 09/11/2015 …


 Data Update                                                                                                                             

 

The December 2015 GPinfo data update is now available.


 

Data Dictionary

 

A data dictionary has been added for the Permits and Wells layers.  To access, right-click on the layer name in the Map Manager and select View data provenance. 

 

The data dictionary is a work in progress.  We welcome your feedback on its contents and will be happy to add more detail on any information that is unclear.

 


 

Data Changes

 

Permits Resource category “Oil and Gas” has been renamed “Conventional” for consistency with other Resource categories. 

 

Important note – existing queries based on Resource might need to be recreated following the renaming of the Resource category. 

 

Theme layer Permits by Resource has been redefined to reflect the new category, and theme layer Petroleum by Expiry Date has also been redefined with new time categories.

 

 
 

 

 Industry Summary                                      

 

Company News

 

Royal Dutch Shell plc has announced that its acquisition of BG Group plc has received unconditional merger clearance from the Australian Competition and Consumer Commission. ACCC chairman Rod Sims said the regulator had decided that the proposed acquisition is “unlikely to substantially lessen competition in the wholesale natural gas market, in either Queensland or eastern Australia more broadly”. In addition, Shell has received approval from the Australian Foreign Investment Review Board for its merger with BG Group. Together with the previously announced clearances in Brazil and the European Union, four of the five pre-conditions to the combination have now been satisfied. The one remaining pre-conditional clearance is from China’s Ministry of Commerce. (Source: Energy News Premium, 19/11/2015 & 04/12/2015).

 

New Standard Energy has signed a binding agreement with China’s Huizhou Energy Investment Company to help raise $2.5 million and secure a farm-in partner for its assets in Western Australia. Huizhou will take a placement of 91.4 million shares at 1c per share to raise $914,000, and then the company will seek to raise a further $1.6 million on a 1:3 share placement. Huizhou will become New Standard’s largest shareholder with 19.15% of the expanded capital base. (Source: New Standard Energy announcement, 24/11/2015).

 

Armour Energy’s proportional takeover by American Energy Partners (AEP) has opened. AEP is seeking to acquire 13.62% of Armour shareholders’ shares for $0.25 per share.  It is also offering to buy any unmarketable parcels. AEP already holds 5.26% in Armour and has agreed to farm-in to Armour’s McArthur Basin oil and gas tenements in the Northern Territory, earning 75% of the leases in return for funding an accelerated work program. AEP received Foreign Investment Review Board approval in December. (Source: Armour Energy announcement, 01/12/2015 & 02/12/2015).

 

Comet Ridge has announced a 2P reserves upgrade at its Mahalo gas project in Queensland’s Bowen Basin. The project’s 2P reserves have increased by 36% to 30 PJ while 3P reserves now stand at 219 PJ, representing a 77% increase. The latest reserves assessment has been independently certified by MHA Petroleum Consultants. The increase in reserves is a result of the success of the Mahalo 7 horizontal well in providing significant gas flows, allowing the conversion from the 1C contingent resource category into the 3P category, plus some conversion of 3P to 2P reserves. (Source: Comet Ridge announcement, 02/12/2015, Energy News 02/12/2015).

 

Woodside has decided to drop its bid for Oil Search, withdrawing its proposal to merge the two businesses. Oil Search previously rejected the $US8.3 billion bid on the basis the offer grossly undervalued the company. Woodside said it would not be pursuing any alternative transactions to combine the businesses. (Source: Woodside Petroleum announcement, 08/12/2015).

 

Blue Energy is pleased to announce a significant increase in gas reserves for its ATP 814P coal seam gas asset in the Bowen Basin, Queensland. 2P reserves for the project have jumped by 29% to 71 PJ which is equivalent to about 12 million barrels of oil equivalent. Meanwhile 3P reserves have jumped by 49% to 298 PJ. Blue described the result as pleasing, noting it had achieved the reserve upgrade in the current low oil price environment while many other operators were witnessing reductions in their reserves. Blue Energy managing director John Phillips said the reserve upgrade was timely given the growing demand for gas in the Townsville and North Queensland region. (Source: Blue Energy announcement, 08/12/2015).

 

Transerv Energy is pleased to announce that an independent assessment has increased the size of its Warro onshore gas field in Western Australia by over two times. The new figures provided by RISC Advisory indicate a contingent resource low estimate of 2.4 tcf of total gas initially in-place which is approximately double the amount previously assessed by Gaffney, Cline & Associates prior to the Alcoa farmin work . RISC has calculated that, based on the results of Warro 5 and Warro 6, there could be as much as 11.6 tcf of gas-in-place, an increase of over 15% on the earlier review. RISC says the total recoverable gas resource of between 2.6 to 5.4 tcf, which is far in excess of the 50 to 75 bcf minimum economic field size. The company hopes to have flow results next year. (Source: Transerv Energy announcement, 19/11/2015).

 

Cooper Energy has upgraded its 2C contingent resource estimate for the Sole field to 121 PJ following reinterpretation of the results of special core analysis of the reservoir section in the Sole 2 well in VIC/RL 3 in the Gippsland Basin. The field now has a gross 3C upside of 285 PJ and 49 million barrels of oil equivalent. The joint venture partners have commenced Front End Engineering and Design (FEED) and the studies are progressing on schedule and within budget, for the Final Investment Decision on development in the September quarter of 2016 to supply gas to eastern Australia from early 2019. (Source: Cooper Energy announcement, 26/11/2015).

 


 

Developments

 

NOPSEMA is not satisfied that BP's environment plan for exploration drilling in the Great Australian Bight has met regulatory requirements. After a thorough and rigorous assessment, NOPSEMA determined that the environment plan does not yet meet the criteria for acceptance under the environment regulations, and has advised BP of this decision. NOPSEMA is required by law to provide BP with a reasonable opportunity to modify the environment plan. If BP chooses to resubmit a modified plan, it will then be assessed by NOPSEMA, a process that should take about 30 days from submission. (Source: Energy News Premium, 18/11/2015).


Jemena has been announced as the preferred bidder to construct an $800 million gas pipeline connecting the Northern Territory to the eastern states' gas market. Jemena will build the 622 km North East Gas Interconnector (NEGI) Pipeline connecting the Alice Springs to Darwin pipeline at Tennant Creek to the mining hub of Mount Isa, allowing the gas to be sold into the east coast gas market. The NEGI pipeline still requires final environmental and financial approvals. The NT Government wants the pipeline to be operational by 2018. (Source: Energy News Bulletin, 18/11/2015).


BG Group plc announces that commercial operations have started from Train 2 at its Queensland Curtis LNG (QCLNG) Plant. QGC, BG’s Australian subsidiary, has also assumed control of Train 2 from Bechtel Australia which built the facility. BG Group now has full control of both LNG trains and associated facilities at QCLNG. By mid-2016 the integrated project is expected to reach plateau production, producing enough LNG to load a combined ten vessels/month, which is equivalent to exporting 8 million tonnes/year.
Since starting production in December 2014, 71 cargoes have been shipped. (Source: Oil & Gas Journal, 25/11/2015).

Woodside Petroleum Ltd has awarded two geotechnical site investigation contracts to geosciences company Benthic for the proposed Browse FLNG Development and the Greater Enfield Development located off the coast of Western Australia. Benthic plans to use its Portable Remotely Operated Drill (PROD3) equipment with support from the vessel Jaya Vigilant. Benthic will begin operations in the Q4 2015 at the proposed Browse FLNG Development site. The Browse investigations will include in-situ testing and sampling to identify bottom sediment conditions and evaluate the geotechnical properties. PROD3 will operate in water as deep as 620 metres and penetrate up to 35 metres below the seabed. This will be followed by a similar operation at Greater Enfield. (Source: Energy News Premium, 25/11/2015).

 

Monadelphous Group Limited has secured a long-term maintenance and modifications services contract valued at more than $200 million for Shell Australia’s Prelude FLNG Project. Monadelphous will provide maintenance, brownfield modifications and turnaround services to the LNG process plant, support utilities, hull and non-process infrastructure including accommodation and control rooms. The scope of the work also involves the delivery of fabrication services from Darwin in support of offshore operations. The contract is for an initial period of seven years with a further two two-year extension options. (Source: Energy News Bulletin, 24/11/2015).

 

SPIE Oil & Gas Services will provide maintenance services to BG Group’s Queensland Curtis LNG Project, under an initial three-year, $18 million contract. Through its local Australian subsidiary, SPIE will work to ensure a lean and automated controls and communications network for the QCLNG project. The maintenance team will include control system engineers and instrument/electrical technicians providing planned and unplanned maintenance as well as identifying and optimising the controls and communications network to deliver efficiencies and improvements to increase production. (Source: Energy News Bulletin, 01/12/2015).

 

MEO Australia advises that the Department of Infrastructure and Regional Development has concluded that the Tassie Shoal Projects are unlikely to require assistance with the secondary level state and federal government approvals in the short to medium term. Consequently the Major Project Facilitation (MPF) status will not be renewed when it expires 31/12/2015. The Department has encouraged the company to re-apply for MPF services once the projects reaches a stage where secondary level approvals are required. (Source: MEO Australia announcement, 02/12/2015).

 

Wood Group has won a new, multi-year contract with ConocoPhillips in Australia. Effective immediately, Wood Group PSN will deliver brownfield engineering services to the Bayu-Undan Field and to the Darwin Liquefied Natural Gas (LNG) Plant. The contract also covers associated floating, storage and offloading facilities and subsea pipelines. A Wood Group Kenny team based in Perth, Western Australia will supply subsea engineering expertise. (Source: Energy News Bulletin, 09/12/2015).

Wood Group has secured its second FEED contract for the proposed Browse Floating Liquefied Natural Gas (FLNG) Development offshore Western Australia. Under the new contract with Woodside, effective immediately, Wood Group Kenny (WGK) will progress the configuration design of the flexible risers and umbilicals for the asset's offshore gas-condensate fields - Brecknock, Calliance and Torosa. Wood Group began a contract earlier this year for the subsea flowline FEED with Woodside for the development, located 300 km from the Kimberley coast. (Source: Energy New Bulletin, 10/12/2015).

 

A six-month parliamentary inquiry into Unconventional Gas in Victoria handed down its findings yesterday, but the committee could not agree on a recommendation on extending the moratorium for another five years or banning the unconventional gas industry altogether. Two government MPs and one Greens MP supported a permanent ban on unconventional gas, the Coalition MPs supported a five-year extension of the existing moratorium, and one Labor MP, Adem Somyurek, called for a three-year moratorium on fraccing, but for conventional drilling for onshore gas to be permitted. According to energy minister Lily D’Ambrosio, Victoria will have a new policy on unconventional gas announced by the middle of next year, but until then the state’s gas industry will be paralysed by the extension on the existing moratorium. (Source: Energy News Premium, 09/12/2015 & 10/12/2015).

 

The participants of the North West Shelf Project have approved the Greater Western Flank Phase 2 Project (GWF-2) off Western Australia. The GWF-2 will develop 1.6 tcf of 2P raw gas reserves from the combined Keast, Dockrell, Sculptor, Rankin, Lady Nora, and Pemberton fields using subsea infrastructure and will be connected by a 35 km, 16-inch pipeline to the existing Goodwyn A platform. Total investment in GWF-2 is estimated to be $2 billion. The project is scheduled to be brought on stream during second-half 2019 with initial production coming from five wells in the Lady Nora, Pemberton, Sculptor and Rankin fields, and followed by three wells in the Keast and Dockerell fields in the first half of 2020. (Woodside Petroleum announcement, 11/12/2015).

 

Origin Energy has confirmed Australia Pacific LNG has commenced production of liquefied natural gas (LNG) at its Curtis Island Facility. The $24.7 billion project is the third CSG-LNG development on Curtis Island following the BG Group and the Santos group in the past 12 months. APLNG’s first LNG shipment is expected before year end. Australia Pacific LNG produces natural gas from Australia’s largest 2P CSG reserves located in the Surat and Bowen Basins in Queensland, which is piped to its LNG facility on Curtis Island where it is converted to LNG for export to customers in Asia. (Source: Origin announcement, 11/12/2015, Oil & Gas Journal, 11/12/2015).

 


 

Discoveries

 

The Total-led led joint venture has reported logging of the Antelope 4/ST 1 well in Papua New Guinea has confirmed a southern extension of the Elk-Antelope field’s high-quality, gas-bearing dolomite. The logs measured 182m of dolomite and a vertical gross gas column of about 339m, which surprised the company to the upside. The well intersected the top of the reservoir 36m higher than the original Antelope 4 penetration, and the latest data suggests that the field-wide gas-water contact is deeper than previously interpreted. The joint venture intends to begin drilling Antelope 6 in December this year as part of the appraisal program to define the resource for the Papua LNG project and is considering an additional appraisal well on the western flank of the field, targeting an additional 1 to 3 tcf. (Source: InterOil announcement, 18/11/2015).

 

Drilling operations have successfully concluded on the Amungee NW 1H horizontal well for Falcon, Origin Energy and Sasol, the first horizontal well drilled in the Beetaloo Basin which was brought forward after promising results in the vertical section.  Highlights of preliminary results from the Amungee NW 1H horizontal exploration well include:

·           Favourable shale properties extending from the Amungee NW 1 vertical well qualify the area as a prospective and laterally extensive sweet spot in the north of the Beetaloo Basin.

·           Excellent gas shows throughout indicate the likelihood of high levels of gas saturation across the entire horizontal section.

·           Consistent lithology, clay mineral composition and total gas readings recorded throughout the drilled 'B Shale' section provides a very solid platform for multi-stage hydraulic fracturing planned for 2016.

 

The Amungee NW 1H well will be cased, cemented and suspended until the performance of the multi-stage hydraulic fracturing planned for 2016. The rig will be stacked on location for the wet season. (Source: Falcon Oil & Gas announcement, 18/11/2015).

 

Senex Energy’s Martlet 2 development well has been successfully drilled 190m south-west of Martlet 1. The well is designed to accelerate recovery of remaining oil from the Namur Sandstone in the field. Martlet 2 intersected 4.5m of net pay in the target zone and was cased and suspended as a future oil producer. The joint venture expects to bring the well online in early 2016. (Source: Senex Energy announcement, 02/12/2015).

 

 Permit Changes                                                                

 

New South Wales

 

In the Sydney Basin, the PEP 11 partners lodged a suspension, extension and variation application with NOPTA on 09/11/2015.

 


 

Northern Territory

 

In the Vulcan Sub Basin, work program area AC 15-2 has been re-released. Bids close 21/04/2016.

 

In the Browse Basin, work program area AC 15-3 received no bids. The area reverts to vacant acreage.

 

In the Petrel Sub Basin, NT 15-1 received no bids. The area reverts to vacant acreage.

 

In the Vulcan Sub Basin, the year 5 work program for AC/P 21 has been extended by 12 months from 13/01/2016 to 12/01/2017. The licence has had its expiry date extended to 12/01/2017. A change to the work program has been approved –

Year 5: geotechnical studies, 1 well $30.75m

 

In the Bonaparte Basin, the year 5 work program for NT/P 68 has been extended by 6 months from 27/10/2015 to 26/04/2016. The licence has had its expiry date extended to 26/04/2016.

 

In the Vulcan Sub Basin, Cosmo Energy Exploration & Production Co Ltd has transferred its interest in AC/RL 4 to PTTEP Australia Timor Sea P/L.

 

Also in the Vulcan Sub Basin, Cosmo Oil Ashmore Ltd has transferred its interest in AC/RL 5 to PTTEP Australia Timor Sea P/L.

 

In the Browse Basin, a change to the work program for AC/RL 8 has been approved –

Years 3-4: seismic reprocessing, drilling engineering studies, seismic interpretation, pressure modelling

 

In the Pedirka Basin, EP 163 was relinquished on 23/11/2015.

 

In the Daly Basin, application EP(A) 218 has been varied and now covers a reduced area of 9397 sq km.

 

In the Amadeus Basin, applications EP(A) 253 and EP(A) 286 were refused on the 24/11/2015. The areas revert to vacant acreage.

 

In the Pine Creek Geosyncline, application EP(A) 255 was refused on the 24/11/2015. The area reverts to vacant acreage.

 


 

Queensland

 

In the Eromanga Basin, ATP 862 has been relinquished.

 

In the Galilee Basin, the following licences have been relinquished:  ATP 1010, ATP 1032, ATP 1044, ATP 1070 and ATP 1074.

 

Also in the Galilee Basin, the following applications have been withdrawn:  ATP 1179, ATP 1180 and ATP 1181.

 

In the Surat Basin, Bridgeport (Surat Basin) P/L has signed a sales and purchase agreement to acquire, from Santos QNT P/L the following interests:  100% of PL 1 Moonie and PL 1 Cabawin, 54.05% of PL 1 Cabawin FO, 100% of PL 2 Alton and 63.5% of PL 2 Alton Farmout.   Further agreements were reached for Bridgeport (Surat Basin) P/L to acquire Santos QNT’s interests in PL 2A and PL 2B, however, Bounty Oil has exercised its pre-emptive rights and increased its interest in PL 2 A & B Koroon Blocks to 81.75%.

 

In the Surat Basin, PL 12 has been renewed to 28/02/2021.

 

In the Bowen Basin, PL 43 has been renewed to 25/05/2026.

 

Also in the Bowen Basin, PL 504 was granted to Peabody (Bowen) P/L 100% on 03/12/2015.  The licence will expire on 02/02/2041.

 

Sequestration

 

In the Surat Basin, EPQ 7 has undergone a partial relinquishment and now covers a reduced area of 2079 sq km.

 

Also in the Surat Basin, EPQ 14 is non-current and no longer exists.  The Minister has not made any decision regarding land release for the area

 


 

South Australia

 

In the Cooper Basin, the term of PEL 103 has ended as PRL 180 - PRL 182 have been granted over the whole area.

 

In the Cooper Basin, the term of PEL 110 has ended as PRL 183 - PRL 190 have been granted over the whole area.

 

In the Cooper Basin, the term of PEL 513 has ended as PRL 191 - PRL 206 have been granted over the whole area.

 

In the Cooper Basin, PPL 261 and PPL 262 were granted to Beach Energy Ltd 40% and Great Artesian Oil & Gas P/L 60% on 05/11/2015 for an indefinite term.

 

In the Cooper Basin, PPL 73 and PPL 74 are being renewed.

 

In the Cooper Basin, PRL 180 and PRL 181 were granted to Acer Energy P/L 100% on 20/11/2015. The licenses will expire on 19/11/2020.

 

In the Cooper Basin, PRL 182 was granted to Acer Energy P/L 75% and Bengal Energy (Australia) P/L 25% on 20/11/2015. The licence will expire on 19/11/2020.

 

In the Cooper Basin, PRL 183 - PRL 190 were granted to Victoria Oil Exploration (1977) P/L 80% and Cooper Energy Ltd 20% on 03/11/2015. The licenses will expire on 02/11/2020.

 

In the Cooper Basin, PRL 190 - PRL 206 were granted to Santos QNT P/L 60% and Drillsearch (513) P/L 40% on 09/10/2015. The licenses will expire on 08/10/2020.

 

Geothermal

 

In the Cooper Basin, Beach Energy has elected not to participate in the proposed farm-in agreement for the geothermal exploration tenements GEL 211, GEL 268, GRL 3 - GRL 12, GRL 20 - GRL 24 at Innamincka.

 

In the Otway Basin, GEL 214 and GEL 498 were relinquished on 23/10/2015.

 

Sequestration

 

In the Cooper Basin, GSEL 659 was granted to Acer Energy P/L 100% on 20/11/2015. The licence will expire on 19/11/2020. 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: G&G studies

 

In the Cooper Basin, GSEL 660 was granted to Acer Energy P/L 75% and Bengal Energy (Australia) P/L 25% on 20/11/2015. The licence will expire on 19/11/2020. 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: G&G studies

 


 

Tasmania

 

Offshore in the Otway Basin, T/30P had a variation approved to its work program on 23/11/2015.  Varied work program is as follows -

 

Years 1-3: 530 sq km 3D seismic reprocessing, geotechnical studies, 1 exploration well $37.795m
Year 4: geotechnical studies including post well analysis $1m
Year 5: geotechnical studies including analysis & interpretation

 

Also in the Otway Basin, T/34P had a variation approved to its work program on 23/11/2015.  Varied work program is as follows –

 

Years 1-3: 559 km 2D seismic reprocessing, 430 sq km 3D seismic reprocessing, geotechnical studies $2.82m
Year 4: 1 exploration well $30m
Year 5: geotechnical studies $0.5m

 

Geothermal

 

Onshore, gazettal area ERA 981 has been varied and now covers a reduced area of 2887 sq km.

 


 

Victoria

 

In the Gippsland Basin, V 15-3 has been re-released as a work program area and will close on 21/04/2016.

 

Offshore, in the Gippsland Basin, Bass Strait Oil Co and Oil Basins Ltd are both trying to farmout their interests in VIC/P 41.

 

Also in the Gippsland Basin, VIC/P 47 has had year 5 of its work program suspended for 12 months to 15/12/2016.  The licence term has been extended to 15/12/2016.

 


 

Western Australia

 

In the Browse Basin, W 14-2 and W 15-18 received no bids. The areas have reverted to vacant acreage.

 

In the Carnarvon Basin, W 14-6, W 15-16 and W 15-17 received no bids. The areas have reverted to vacant acreage.

 

In the Carnarvon Basin, WA-202-P was relinquished on 02/12/2015. The Gungurru/Cherring Location has also been revoked.

 

In the Dampier Basin, a suspension and extension for WA-209-P was lodged on 18/11/2015.

 

In the Carnarvon Basin, the year 5 work program for WA-253-P has been extended by 9 months from 30/12/2015 to 29/09/2016. The licence has had its expiry date extended to 29/09/2016.

 

In the Petrel Sub Basin, a suspension and extension for WA-313-P was lodged on 01/12/2015.

 

In the Carnarvon Basin, the year 4 work program for WA-323-P has been extended by 12 months from 06/01/2016 to 05/01/2017. The licence has had its expiry date extended to 05/01/2018.

 

In the Dampier Basin, the year 3 work program for WA-330-P has been extended by 12 months from 06/04/2016 to 05/04/2017. The licence has had its expiry date extended to 05/04/2019.

 

In the Carnarvon Basin, a suspension and extension for WA-335-P was lodged on 03/12/2015.

 

In the Carnarvon Basin, the year 5 work program for WA-351-P has been extended by 6 months from 28/12/2015 to 27/06/2016. The licence has had its expiry date extended to 27/06/2016.

 

In the Carnarvon Basin, WA-360-P is being relinquished.

 

In the Carnarvon Basin, a suspension and extension for WA-387-P was lodged on 09/12/2015.

 

In the Petrel Sub Basin, a suspension and extension for WA-407-P was lodged on 17/11/2015.

 

In the Bonaparte Basin, the Ascalon Location extension WA-420-P L was granted on 18/11/2015.

 

In the Petrel Sub Basin, a suspension and extension for WA-454-P was lodged on 08/12/2015.

 

In the Rowley Sub Basin, a change to the WA-464-P program has been approved –

 

Year 1: 4213 sq km 3D seismic, velocity modelling study $25.6m
Year 2: geotechnical studies, 1 well, pore pressure prediction analysis $35.7m

 

In the Rowley Sub Basin, WA-466-P is being cancelled.

 

In the Beagle Basin, a change to the WA-467-P program has been approved –

 

Year 5: 1010 sq km 3D seismic, geotechnical studies $0.6m

 

In the Petrel Sub Basin, the year 2 work program for WA-488-P has been extended by 12 months from 22/05/2015 to 21/11/2016. The licence has had its expiry date extended to 21/11/2020. A change to the work program has been approved –

 

Year 2: G&G studies, survey data proprietary processing, 150 km 2D seismic reprocessing $0.65m

 

In the Browse Basin, a change to the WA-508-P program has been approved –

 

Years 1-3: 1000 km 2D seismic reprocessing, G&G studies, 221 sq km 3D seismic $2.12m

 

In the Browse Basin, a change to the WA-509-P program has been approved –

 

Year 1: 1000 km 2D seismic reprocessing, G&G studies, 1411 sq km 3D seismic $12.87

 

In the Perth Basin, AWE and Elixir have agreed to extend the due diligence period for the agreement under which Elixir can acquire a 57.5% working interest in the Cliff Head oil field WA-31-L from 30/11/2015 to 18/12/2015. The parties have also agreed that the exclusivity period can be further extended to 29/01/2016.

 

In the Carnarvon Basin, WA-61-R was granted to BHP Billiton Petroleum (Northwest Shelf) P/L 100% on 26/11/2015. The licence will expire on 25/11/2020. Work program is as follows –

 

Years 1-5: subsurface studies, development concept evaluation, future technology evaluation, marketing $2m

 

In the Carnarvon Basin, WA-62-R was granted to BHP Billiton Petroleum (Northwest Shelf) P/L 100% on 26/11/2015. The licence will expire on 25/11/2020. Work program is as follows –

 

Years 1-5: commercial, subsurface, marketing and environmental studies, Front End Engineering Design activities $13m - $20m

 

In the Carnarvon Basin, WA-63-R was granted to BHP Billiton Petroleum (Northwest Shelf) P/L 100% on 26/11/2015. The licence will expire on 25/11/2020. Work program is as follows –

 

Years 1-5: subsurface studies, development concept evaluation, future technology evaluation, marketing $2m

         

In the Canning Basin, Mosman Oil & Gas has elected to cancel its option for 17.5% in EP 478.

 

In the Perth Basin, Southern Sky Energy has transferred 50% interest in EP 494 to Macallum Group Ltd. Macallum has the right to earn up to a further 25% interest by meeting certain expenditure obligations.

In the Officer Basin, gazettals L 14-10, L 14-7, L 14-8 and L 14-9 received no bids. The areas revert to vacant acreage.

 

In the Canning Basin, application STP-EPA-102 has been withdrawn. The area reverts to vacant acreage.

 

In the Perth Basin, Southern Sky Energy has transferred a 50% interest in STP-EPA-65 to Macallum Group Ltd. Macallum has the right to earn up to a further 25% interest by meeting certain expenditure obligations.

 

In the Perth Basin, the Amangu native title agreement with the traditional owners has been signed relating to application STP-EPA-90. Following delivery of final signed documents by the Amangu traditional owner group the agreements will be executed by Black Rock Mining and delivered to the DMP. The permit can then be granted.

 


 

Papua New Guinea

 

Rawson resources have applied for four areas in PNG:  APPL 549 over 4984 sq km in the North New Guinea Basin, APPL 550 over 1625 sq km and APPL 551 over 257 sq km in the Papuan Basin and APPL 560 over 4680 sq km in the Cape Vogel Basin. APPL 560 is over an area previously held by Eaglewood (PPL 257) which was relinquished at the time Eaglewood was acquired by Transform Exploration.

 

In the Papuan Basin, PDL 2 was extended to 09/12/2035.

 

 

                                                                                                                                   

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