GPinfo Update

 

May 2015

 

Monthly Update

 

The May 2015 data update is now available …

 

2015 Offshore Acreage Release

 

The 2015 Federal Gazettal of Offshore Areas has been finalised with 29 areas available for application …

 

2015 Petroleum Permits of Australasia Map & Book

 

The 2015 editions of the Petroleum Permits of Australasia Map and Book were released at the APPEA Conference in Melbourne on Monday 18th May …

 

Industry Summary

 

TAP Oil’s dispute with its partner, Thai businessman Chatchai Yenbamroong’s Northern Gulf Petroleum (NGP), has intensified with NGP lodging a payment demand from Tap …

 

Permit Updates and Changes

 

In the Surat/Bowen Basin, Comet Ridge’s 97.5% in the Conventional resource of PEL 6 is held by Comet Ridge Ltd …

 


 

Monthly Update

 

The May 2015 GPinfo data update is now available.
 


 

2015 Offshore Acreage Release

 

The 2015 Federal Gazettal of Offshore Areas has been finalised with 29 areas available for application -

 

Licence

 

Basin

 

Closing Date

AC 15-1

Vulcan Sub

29/10/2015      Work program area

AC 15-2

Vulcan Sub

29/10/2015      Work program area

AC 15-3

Browse

29/10/2015      Work program area

NT 15-1

Petrel Sub

29/10/2015      Work program area

NT 15-2

Petrel Sub

04/02/2016      Cash bid area

S 15-1

Ceduna

21/04/2016      Work program area

T 15-1

Otway

21/04/2016      Work program area

T 15-2

Otway

21/04/2016      Work program area

T 15-3

Otway

21/04/2016      Work program area

V 15-1

Otway

21/04/2016      Work program area

V 15-2

Gippsland

29/10/2015      Work program area

V 15-3

Gippsland

29/10/2015      Work program area

W 15-1

Petrel Sub

04/02/2016      Cash bid area

W 15-2

Bonaparte

29/10/2015      Work program area

W 15-3

Browse

21/04/2016      Work program area

W 15-4

Browse

21/04/2016      Work program area

W 15-5

Rowley Sub

29/10/2015      Work program area

W 15-6

Carnarvon

21/04/2016      Work program area

W 15-7

Carnarvon

21/04/2016      Work program area

W 15-8

Carnarvon

21/04/2016      Work program area

W 15-9

Dampier

04/02/2016      Cash bid area

W 15-10

Dampier

04/02/2016      Cash bid area

W 15-11

Carnarvon

04/02/2016      Cash bid area

W 15-12

Dampier

04/02/2016      Cash bid area

W 15-13

Carnarvon

29/10/2015      Work program area

W 15-14

Carnarvon

21/04/2016      Work program area

W 15-16

Carnarvon

29/10/2015      Work program area

W 15-17

Carnarvon

29/10/2015      Work program area

W 15-18

Browse

29/10/2015      Work program area

 

Pre-qualification for areas W 15-9, W 15-10, W 15-11 and W 15-12 closes on 15/10/2015.

 

Click here for more information.

 


 

2015 Petroleum Permits of Australasia Map & Book

 

The 2015 editions of the Petroleum Permits of Australasia Map and Book are now available.  They were released at the APPEA Conference in Melbourne on Monday 18th May and can be purchased from our booth at the conference or by mail order from our Sydney office.  Click here to download a copy of the order form.

 


 

Industry Summary

 

Company News

 

TAP Oil’s dispute with its partner, Thai businessman Chatchai Yenbamroong’s Northern Gulf Petroleum (NGP), has intensified with NGP lodging a payment demand from Tap of $US14.6 million. NGP says the payment is overdue, whereas Tap says it intends to make the payment, but only once operator Mubadala Petroleum has finalised the 2P reserves review for the Manora field. Tap says there is no basis for the statutory demand from NGP, Tap’s lawyers will now take the necessary steps to seek to set aside this statutory demand and seek payment of Tap's legal costs. Tap also considers that this statutory demand is an abuse of the statutory demand process. (Source: Tap Oil announcement, 14/04/2015).

 

A two year dispute between Fitzroy River Corporation and Buru Energy over the interpretation of a royalty agreement over several of Buru’s oldest permits in Canning Basin has been resolved in the courts. The Western Australian Supreme Court has dismissed Fitzroy’s claim in relation to the royalty payable under the Canning Basin Royalty Deed and confirmed that Buru and Mitsubishi Corporation’s interpretation of the deed is correct. As a result of this decision Fitzroy will continue to receive a 2% royalty based on the value of the petroleum at the well head. (Source: Buru Energy announcement, 15/04/2015).

 

Strike Energy has boosted resources for its Southern Cooper Basin Gas Project, with its first contingent resources of 155 bcf (2C) the minimum amount needed to support an economic development. DeGolyer and MacNaughton was engaged by Strike to undertake an independent review of the gas resources in PEL 96 based on the data and information acquired from drilling and flow testing programs carried out at the Le Chiffre 1, Klebb 1, Klebb 2 and Klebb 3 wells. The calculations by DeGolyer and MacNaughton include 105 bcf (1C) and 225 bcf (3C). Only the initial zones have been tested to date in the Le Chiffre 1 and Klebb 1 wells and, considering the thickness of the coals intersected, Strike is confident it is defining a multi-trillion cubic feet resource given it has only drilled in a small area so far. (Strike Energy announcement, 27/04/2015).

 

Metgasco Ltd announces that the NSW Supreme Court has found in its favour in Metgasco’s challenge to the NSW Government’s suspension of its Rosella drilling approval with the drilling suspension being lifted. The company has announced it will pursue the New South Wales government for damages for its decision to suspend the Rosella well drilling approval. Metgasco’s managing director Peter Henderson told Energy News that Rosella 1 could finally spud within three months. (Source: Metgasco announcement, 24/04/2015, Energy News Premium, 28/04/2015).

 

Mosman Oil and Gas Ltd has resolved to lodge a Notice of Variation in respect of the takeover of MEO Australia Ltd with ASIC. The key variations include extending the offer period to 12/06/2015, increasing the offer consideration to one Mosman share for every five MEO shares (previously one for ten) and freeing the offer from many of the conditions including the minimum acceptance of 90% and Mosman Shareholder approval. (Source: Mosman Oil & gas announcement, 01/05/2015).

 

A once-in-a-generation chance to acquire 285,000 sq km of the Northern Territory is being offered by KordaMentha via the sale or farm-in of Australian Oil & Gas’ extensive, early-stage exploration assets, Energy News has been told. Starting in 2010 AOG was able to secure licences covering one-fifth of the NT across 10 almost completely unexplored frontier basins. Palladion Partners has been tasked with promoting AOG’s assets, after the company fell into administration last year. Palladion’s Andrew Bald told Energy News the corporate advisory has already had some interest in the early stage assets despite the depressed market for oil and gas, because interest in the NT basins – particularly the Greater Macarthur Basin – remains high. The package includes 28 application areas which have been working their way through the native title process and there are four granted licences, three of which are covered by Blue Energy’s Wiso Basin farm-in agreement. The company is looking to get expressions of interest by the end of May, ahead of a financial close targeted before the end of June.  (Source: Energy News Premium, 05/05/2015).

 

Developments

 

The Gorgon LNG Project on Western Australia’s Barrow Island has achieved an important milestone with the successful start-up of the first of its five gas turbine generators, a critical element in the gas plant start-up sequence. The turbines will provide the necessary power to conduct live commissioning of various systems, which is an important part of the start-up sequence. Gorgon is now approaching completion, with first cargoes expected in the second half of the year. (Source: Energy News Bulletin, 15/04/2015).

 

Saipem has awarded Kongsberg Oil and Gas Technologies a contract for delivery of subsea structures for the gas export pipeline project of the Inpex-operated Ichthys LNG Project. The scope of work involves adjustable pipe support (APS) structures to the pipeline to support the pipeline and bring it to the required height and orientation at the end termination. Kongsberg will do engineering, procurement, construction and delivery while Saipem will do the installation. The construction is being undertaken in Henderson, WA. The design started in January 2015 and the APS will be tested and ready for installation by the end of July. (Source: Energy News Bulletin, 15/04/2015).

 

Chevron Corporation has submitted plans to decommission the Thevenard Island oil and gas facilities on and offshore Thevenard Island in Western Australia, now that the associated fields have reached the end of their economic lives. Production from the offshore fields Saladin, Cowle, Yammaderry, Crest, Roller, and Skate ceased in January 2014. Chevron and partners Santos Ltd and ExxonMobil Corp have tried to sell the facilities without success. Chevron plans to disconnect the subsea pipelines but leave them in place. All the structures offshore and onshore will be removed. The 22 offshore wells and 14 directional wells drilled from onshore will be decommissioned. It is anticipated the work will begin in 2016 and take about 12 months to complete the offshore work. Onshore decommissioning and remedial work on Thevenard, including removal of roads, footings and pathways, will take 2 years. (Source: Oil & Gas Journal, 16/04/2015).

 

Logistics services provider Toll Group has officially opened its offshore logistics base in Darwin to service the multi-billion dollar Inpex-operated Ichthys LNG Project. Northern Territory deputy Chief Minister Willem Westra van Holthe joined Ichthys LNG managing director Louis Bon and Toll’s resources and government logistics CEO David Jackson to officially open the new facility yesterday. Toll designed and built, and now operates the facility on a 4.5ha site in Darwin’s East Arm. The base will support the Ichthys LNG project’s major offshore facilities in the Ichthys field in the Western Australia’s Browse Basin, 820 km southwest of Darwin. (Source: Energy News Bulletin, 17/04/2015).

 

Santos has narrowed the start-up date for its US$18.5 billion Gladstone LNG Project on Queensland’s Curtis Island to the end of the third quarter. Construction of the Gladstone LNG Project has reached 95% completion with first LNG expected by the end of September. This first LNG timeframe was long-flagged by Macquarie Wealth Management with Santos’ previous guidance being the second half of 2015. The two-train GLNG project is targeting 7.8 million tonnes per annum of LNG export capacity. (Source: Energy News Bulletin, 17/04/2015).

 

Origin Energy has marked a major milestone in the development of its $24.7 billion Australia Pacific LNG Project on Queensland’s Curtis Island, starting up the first of seven gas turbine power generators. While most natural gas arriving at the LNG facility will be processed and exported as LNG, a small amount will be used to power the gas turbine generators to generate the electrical power required to operate the two LNG processing trains. Australia Pacific LNG CEO Page Maxson said the successful start-up of the first turbine was another achievement for the business, following on from the completion of the pipeline and first gas arriving at the LNG facility earlier this year.  “Over the coming months, we will progressively test and start additional critical elements of the processing trains to bring the LNG facility on line and ready for first LNG export.” Maxson said. Gas sales from APLNG are expected before the end of the year. (Source: Energy News Bulletin, 22/04/2015).

 

BG Group has started the process for the development of the Anya CSG Field, in a new area adjacent to its QCLNG trains. The proposed field lies in ATP 1188, within the Braemar State Forest. BG Group is asking for environmental approval for the construction, operation, decommissioning and rehabilitation of the proposed development which comprises 25 wells with associated gathering and access tracks. Gas and water produced from the development will be gathered to storage and compression facilities constructed as part of the approved QCLNG project and will be managed using the same systems and processes. (Source: Energy News Premium, 22/04/2018).

 

The Inpex-operated Ichthys LNG Project has lifted the first topside modules onto the hulls of its two major offshore facilities, marking the start of the topsides integration phase for the central processing facility (CPF) and the floating production, storage and offloading (FPSO) facility. This phase involves the hull and topsides for each facility coming together as single, connected structures for the first time. Ichthys managing director Louis Bon said the CPF and FPSO topside module lifts, which are the first in a sequence, were a major step towards the completion of the two world-class, semi-submersible facilities. Once complete, the CPF and FPSO will be towed 5600km to the Ichthys field, offshore Western Australia, where they will be moored permanently to the seabed for the life of the project. (Source: Energy News Bulletin, 23/04/2015).

 

Chevron has marked a major milestone with the installation of Wheatstone’s platform topsides off the Pilbara Coast. A spokesperson for Chevron said the Wheatstone Platform was the largest offshore gas processing platform ever installed in Australia. The installation was also said to be the largest single integrated float-over installation Chevron has delivered globally, with a topsides weight of 37,000 tonnes, and a height of 28 metres above the sea level. The Wheatstone project is now nearly 60% complete according to Chevron, with delivery and installation of modules at the LNG plant site ongoing. (Source: Oil & Gas Australian Mining announcement, 06/05/2015).

 

Discoveries

 

Senex Energy has had success with the Dunoon 3 oil well. The well encountered 3 metres of net pay in the McKinlay Formation. Dunoon 3 also intersected encouraging oil shows in the Murta Formation, providing further validation over the Dunoon Ridge portion of the Murta fairway being targeted as part of the Company’s tight oil growth project. The well was cased and suspended as a future McKinlay oil producer with initial production from this well expected in Q1 FY16. (Source: Senex Energy announcement, 29/04/2015).

 

Chevron Australia has made a natural gas discovery with its Isosceles 1 wildcat drilled in the greater Gorgon gas project area offshore Western Australia. The well encountered 134 metres of net gas pay in the Triassic-age Mungaroo Sand reservoir in permit WA-392-P about 95 km northwest of Barrow Island where the Gorgon LNG Plant is nearing completion. The discovery is a continuation of the company’s exploration success in the region and adds to the resources available to the LNG project. (Source: Energy news Bulletin, 30/04/2015).

 

The Beach Energy and Cooper Energy joint venture have had success at the Callawonga 10 oil development well located in PPL 220 on the western flank of the Cooper Basin. Oil shows were observed in the primary targets, McKinlay Member and Namur Sandstone. A total gross oil column of 4.8 metres is interpreted in Callawonga 10. The well will be cased and suspended to accelerate oil production from the southern area of the field. (Source: Cooper Energy announcement, 01/05/2015).

 

The Santos-led joint venture with Drillsearch Energy is pleased to announce a new wet gas discovery at the Emery 1 exploration well on the Western Wet Gas Fairway of the Cooper Basin. Excellent gas shows were observed across the Patchawarra Formation from 2,641 metres to 3,174.5 metres, with stacked reservoirs identified. Drillsearch’s preliminary petrophysical interpretation of wireline logs calculated approximately 18.6 metres of net pay across several zones in the Patchawarra Formation with a gross interval of 533 metres and approximately 7.7 metres of net pay in the Tirrawarra Sandstone with a gross interval of 37 metres. Several zones with potential for unconventional pay were also observed. The well has been cased and suspended as a future gas producer. (Source: Drillsearch Energy announcement, 04/05/2015).

 

AWE could commercialise new sources of gas in Western Australia’s Perth Basin by mid next year after discovering an estimated 149 bcf of gas at the Irwin and Synaphea structures. Analysis of wireline logs at the Irwin 1 exploration well, located in the onshore Perth Basin, indicates a 32 metre gas column in the Dongara/Wagina tight gas reservoir with a gas/water contact interpreted at 3,085 metres total vertical depth subsea. AWE said this was the same depth as the log indicated gas/water contact in Warradong 1, previously drilled in the adjacent Synaphea structure, 4.5km to the south. “The common contact suggests that these two wells may have intersected the down-dip portion of a single large gas accumulation that includes both the Irwin and Synaphea structures,” AWE said. AWE estimates gross 2C contingent resources of 15 bcf of gas for Irwin and 134 bcf of gas for Synaphea. Meanwhile, AWE wasn’t so lucky at the Kingia Sandstone interval at Irwin 1 which was found to be water bearing. (Source: AWE announcement, 07/05/2015).

 


 

Permit Updates and Changes

 

New South Wales

 

In the Surat/Bowen Basin, Comet Ridge’s 97.5% in the Conventional resource of PEL 6 is held by Comet Ridge Ltd.

 

Also in the Surat/Bowen Basin, Comet Ridge’s 22.5% interest in the CSG resource of PEL 6 is held by Comet Ridge Ltd.

 

In the Surat/Bowen Basin, Comet Ridge’s entire 100% interest in the Conventional resource for PEL 427 and PEL 428 is held by Comet Ridge Ltd.

 


 

Northern Territory

 

On the Ashmore Platform, AC 14-1 has been re-released. The area closes 29/10/2015.

 

In the Browse Basin, AC 14-3 and AC 14-4 have reverted to vacant acreage.

 

In the Vulcan Sub Basin, MEO Australia has advised that the international oiler that was considering farming into AC/P 50 and AC/P 51 has provided written notice it will not exercise its options in relation to the permits. MEO intends to relinquish 100% of the permits if it cannot negotiate a moderate three-year work program with the regulator.

 

In the Bonaparte Basin, NT 14-1 and NT 14-2 have reverted to vacant acreage.

 

In the Timor Basin, NT 14-3 has reverted to vacant acreage.

 

On the Ashmore Platform, AC/RL 11 has been granted over the Puffin Field to Sinopec O&G Australia (Puffin) P/L 60% and AED Oil Ltd 40% on 21/04/2015. The licence will expire on 20/04/2020. Work program is as follows –

 

Year 1: geotechnical review, production systems, cost reduction innovations, facilities sharing initiatives $0.15m

Year 2: geotechnical review, production systems, cost reduction innovations, facilities sharing initiatives $0.1m

Year 3: geotechnical review, production systems, cost reduction innovations, facilities sharing initiatives $0.15m

Year 4: geotechnical review, production systems, cost reduction innovations, facilities sharing initiatives $0.1m

Year 5: geotechnical review, cost reduction innovations, facilities sharing initiatives $0.2m

 

In the Georgina Basin, Statoil has indicated that it will not be proceeding to Phase 2B of the farm-in to EP 103, EP 104, EP(A) 213 and EP(A) 252. Petrofrontier intends to relinquish these permits in due course.

 

In the Amadeus Basin, EP 156 expiry date has been extended to 6/05/2017.

 

In the Birrindudu Basin, EP 300 was relinquished 31/03/2015.

 


 

Queensland

 

The Queensland Department of Natural Resources and Mines has gazetted a number of onshore areas: one in the Surat Basin (PLR 2015-1-1) and 19 in the Eromanga Basin (PLR 2015-2-1 to PLR 2015-2-19).  All areas close on 08/10/2015.

 

High Peak Royalties’ ORR interest in ATP 299 (and associated PLs) is held by wholly-owned subsidiary Oil & Gas Royalties P/L.

 

In the Surat Basin, ATP 470 expired on 28/02/2015 and now reverts to vacant acreage.

 

In the Eromanga Basin, Strike Energy has withdrawn from the Cypress Block of ATP 549.  Its interest has yet to be re-assigned to the remaining partners.

 

In the Laura Basin, application ATP 718 was withdrawn by the applicant and now reverts to vacant acreage.

 

In the Eromanga Basin, ATP 737 was granted over a reduced area of 490 sq km on 06/02/2015.  The licence will expire on 28/02/2019.

 

In the Adavale Basin, ATP 1093 was granted to Seymour Energy P/L 100% on 22/04/2015.  The licence will expire on 30/04/2019.  Overlapping applications ATP 1090, ATP 1091 and ATP 1094 were refused.  Work program is as follows –

 

Year 1: G&G studies, 500 km 2D seismic reprocessing, 350 sq km aerial geophysics reprocessing
Year 2: G&G studies, 50 km 2D seismic, 2 wells to 1800m
Year 3: G&G studies, 4 wells to 2000m
Year 4: G&G studies, 5 wells to 2000m

 

In the Bowen Basin, CH4’s 0.7% interest in ATP 1103 (and associated & PCAs) is held by CH4 P/L.

 

In the Galilee Basin, Queensland Energy Resources’ interest in ATP 1179 and ATP 1180 is being transferred to wholly-owned subsidiary QER CSG P/L.

 

Also in the Bowen Basin, CH4’s 3.5% interest in PL 191, PL 196, PL 223, PL 224 and PL 499 is held by CH4 P/L.

 

In the Bowen Basin, CH4’s 70% interest in PL 500 is held by CH4 P/L.

 

Australia Pacific LNG P/L’s 0.24% interest in the SW Queensland Gas Unit has been transferred back to Origin Energy Resources Ltd.

 


 

South Australia

 

In the Cooper Basin, Bridgeport's interest in PEL 630 has been transferred to Bridgeport (Cooper Basin) P/L.

 

In the Eromanga Basin, PEL 71 has been suspended from 26/03/2015 to 25/09/2015. The licence has had its expiry date extended to 05/11/2018.

 

In the Aldinga Basin, Strike's interest in PPL 210 is held by Strike Energy 95 P/L.

 

In the Cooper Basin, PRL 17 is being renewed.

 


 

Victoria

 

Offshore in the Gippsland Basin, VIC/P 41 has had Year 3 of the work program suspended for 6 months to 28/11/2015.  The licence term has been extended for 6 months to 28/11/2017.

 

Also in the Gippsland Basin, VIC/P 68 has had Year 3 of the work program has been varied to 225 sq km 3D seismic and 255 sq km seismic reprocessing.  The Year 3 work program has also been suspended and extended to 03/11/2015.

 

In the Otway Basin, VIC/P 69 had an application lodged with NOPTA on 08/04/2015 for a variation.

 

Onshore, in the Otway Basin, applications have been made to suspend and extend PEP 150, PEP 151, PEP 168 and PEP 171.

 


 

Western Australia

 

In the Carnarvon Basin, W 13-8, W 13-15, W 13-17, W 14-9, W 14-11, W 14-13 and W 14-14 have reverted to vacant acreage.

 

In the Perth Basin, W 13-20 has reverted to vacant acreage.

 

In the Browse Basin, W 14-2 has been re-released. The area closes 29/10/2015.

 

Also in the Browse Basin, W 14-3 has reverted to vacant acreage.

 

In the Carnarvon Basin, WA-191-P is being renewed.

 

In the Carnarvon Basin, WA-19-R has been renewed to 16/04/2020. Work program is as follows –

 

Year 1: seismic interpretation, subsurface, engineering & technical studies $0.3m

Year 2: subsurface, engineering & technical studies $0.3m
Year 3: subsurface, engineering & technical studies $0.15m
Year 4: subsurface, engineering & technical studies $0.15m
Year 5: gas market, cost review $0.15m

 

In the Carnarvon Basin, WA-20-R has been renewed to 16/04/2020. Work program is as follows –

 

Year 1: seismic interpretation, sub: surface, engineering & technical studies $0.35m
Year 2: subsurface, engineering & technical studies $0.25m
Year 3: subsurface, engineering & technical studies $0.15m
Year 4: subsurface, engineering & technical studies $0.15m
Year 5: gas market, cost review $0.15m

 

In the Carnarvon Basin, WA-21-R has been renewed to 16/04/2020. Work program is as follows –

 

Year 1: seismic processing & interpretation $0.1m
Year 2: subsurface interpretation $0.1m
Year 3: subsurface studies $0.15m
Year 4: technical & marketing studies $0.05m
Year 5: gas market, cost review $0.05m

 

In the Carnarvon Basin, WA-22-R has been renewed to 16/04/2020. Work program is as follows –

 

Year 1: seismic interpretation, sub: surface, engineering & technical studies $0.35m
Year 2: subsurface engineering & technical studies $0.25m
Year 3: subsurface engineering & technical studies $0.15m
Year 4: subsurface engineering & technical studies $0.15m
Year 5: gas market, cost review $0.15m

 

In the Carnarvon Basin, WA-23-R has been renewed to 16/04/2020. Work program is as follows –

 

Year 1: seismic processing & interpretation $0.1m
Year 2: seismic interpretation $0.1m
Year 3: subsurface studies $0.15m
Year 4: technical & marketing studies $0.05m
Year 5: gas market, cost review $0.05m

 

In the Carnarvon Basin, WA-24-R has been renewed to 16/04/2020. Work program is as follows –

 

Year 1: seismic interpretation& sub: surface studies $0.2m
Year 2: subsurface studies $0.2m
Year 3: subsurface engineering & technical studies $0.2m
Year 4: subsurface engineering & technical studies $0.15m
Year 5: gas market, cost review $0.15m

 

In the Carnarvon Basin, a change to WA-36-R work program has been approved –

 

Year 1: studies, analysis of Canyon, Norton and Laverda $24m
Year 2: studies, oil spill modelling, environmental approval $18.7m

 

In the Dampier Basin, WA-38-R has expired. The area reverts to vacant acreage.

 

In the Browse Basin, the year 3 work program for WA-408-P has been extended by 12 months from 16/04/2015 to 17/04/2016.  The licence has had its expiry date extended to 17/04/2017. A change to the year 3 work program has been approved –

 

Year 3: 350 sq km 3D seismic, 3 wells, studies, 506 sq km 3S seismic, 506 Sq km PSDM reprocessing $78.2m

 

In the Carnarvon Basin, the year 6 work program for WA-409-P has been extended by 12 months from 30/04/2015 to 29/04/2016. The licence has had its expiry date extended to 29/04/2016. A change to the year 6 work program has been approved –

 

Year 6: 566 sq km 3D seismic PSDM reprocessing, studies $1.85m

 

In the Bonaparte Basin, WA-421-P expired. The area reverts to vacant acreage.

 

In the Browse Basin, a change to the work program for WA-424-P has been approved –

 

Year 4: geotechnical studies, 200 sq km 3D seismic reprocessing $0.3m
Year 5: geotechnical studies $0.2m
Year 6: geotechnical studies, 1 well $14.2m

 

In the Browse Basin, WA-431-P and WA-432-P have expired. The areas revert to vacant acreage.

 

In the Petrel Sub Basin, the year 4 work program for WA-454-P has been extended by 6 months from 09/06/2015 to 08/12/2015. The licence has had its expiry date extended to 08/12/2017. A change to the work program has been approved –

 

Year 4: geotechnical studies, 600 sq km 3D PSDM reprocessing $0.85m
Year 5: 600 sq km 3D PSDM interpretation, geotechnical studies $0.25m
Year 6: 1 well $20m

 

In the Carnarvon Basin, WA-469-P and WA-470-P have been relinquished.

 

In the Carnarvon Basin, a change to the WA-476-P work program has been approved –

 

Year 4: evaluation of rock properties, studies, seismic inversion $0.2m
Year 5: 1 well $20m

 

In the Petrel Sub Basin, the year 2 work program for WA-488-P has been extended by 6 months from 22/05/2015 to 21/11/2015.  The licence has had its expiry date extended to 21/11/2019. A change to the work program has been approved –

 

Year 2: G&G studies, survey data proprietary processing $0.5m

 

In the Carnarvon Basin, WA-5-R has been renewed to 16/04/2020. Work program is as follows –

 

Year 1: seismic processing & interpretation $0.5m
Year 2: subsurface interpretation & static updates $0.3m
Year 3: subsurface, engineering & technical studies $0.3m
Year 4: subsurface, engineering & technical studies $0.3m
Year 5: gas market, cost review $0.15m

 

In the Canning Basin, application 17/07-8 EP has been withdrawn.

 

In the Perth Basin, Eneabba gas exercised its option to acquire GCC Methane P/L. Greenpower has now effectively sold its 50% interest in EP 447 for cash consideration of $850,000. Green Power will retain an interest in the permit via a 1.5% production royalty interest.

 

In the Perth Basin, EP 479 was relinquished 24/04/2015.

 

In the Carnarvon Basin, L 13-2 did not receive any bids. The area will revert to vacant acreage.

 

In the Canning Basin, L 14-3, L 14-4, L 14-5 and L 14-6 did not receive any bid but will be reserved for consideration for re-release.

 

In the Carnarvon Basin, R 5 has expired. The area reverts to vacant acreage.

 

In the Canning Basin, application STP-EPA-131 has been varied and now covers a reduced area of 5,301 sq km.

 

In the Perth Basin, Eneabba Gas executed an extension of the closing date for the acquisition of the Ocean Hill Project STP-EPA-90 with Black Rock Mining. The agreement has been extended to 15/07/2015 due to the longer than expected time frame for the grant of the permit by the state as a result of slower completion of the remaining native title agreement.  The native title approvals are expected to be completed in the next 60 days.

 

In the Canning Basin, Buru Energy and Mitsubishi can now secure the production licence over the Ungani oil field in Western Australia’s Canning Basin after the third native title claimants, the Yawuru, executed the final agreement. The granting of STP-PRA-4 and STP-PRA-5 is expected to take several months.

 


 

New Zealand

 

In the East Coast Basin, application APP 56365 has been varied and now covers a reduced area of 369,791 sq km.

 

In the Taranaki Basin, PEP 38773 and PEP 53537 were relinquished 21/04/2015.

 

Also in the Taranaki Basin, PEP 55790 was relinquished 30/04/2015.

 


 

Papua New Guinea

 

In the Papuan Basin, CNOOC Ltd is the operator of PPL 374, PPL 375, PPL 378 and PPL 405.

 

Also in the Papuan Basin, PRL 13 has had its expiry date extended to 26/01/2017.

 


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