GPinfo Update November 2017

  

 

Data Update

 

The November 2017 data update is now available …

 

The November update includes new layers in the COAST ETC group. Layers Coast (line only), Land (fill only) and State boundaries are based on the GeoData Coast 100K 2004 dataset, replacing layers …

 

Map/Book Discount Bundle

 

Buy the 2017 Petroleum Permits Map & Book for the bundle price of $150 and save $70 off the full retail price. Receive an A0-sized laminated copy of the 2017 map PLUS the November edition of the book …

 

Industry Summary

 

In September 2017, Zeta Resources, through its 100% owned subsidiary Zeta Energy, made a partial takeover offer to acquire at least 42% of the shares of New Zealand Oil & Gas Ltd that it did not

 

The Stag oilfield off the coast of Western Australia reached a milestone production of 3600 bopd over a 10-day period Jadestone Energy said. This represents a 40% increase in production since the company …

 

Permit Updates and Changes

 

Sinopec O&G Australia (NT) P/L and OPIC Australia P/L have entered a withdrawal agreement under which SIPC and OPIC will assign their respective 30% interests in AC/P21 to Eni Australia Ltd …

 

Horizon Oil has entered into an agreement with Todd Maari Ltd to acquire its 16% interest in PMP 38160 for a consideration of US$17.6m, subject to New Zealand Government Ministerial approval …


 

The November 2017 update for GPinfo is now available.

 

Updated Coast Layers

 

The November update includes new layers in the COAST ETC group.

 

Layers Coast (line only), Land (fill only) and State boundaries replace Coast High Res and Coast Medium Res which have been removed.

 

For Australia, the new layers are based on the GeoData Coast 100K 2004 dataset (New Zealand and Papua New Guinea coastlines are unchanged).

 

The following changes have been made –

 

1.     Attribute information omitted.

2.     Islands with area less than 0.25 sq km removed.

3.     Polylines and polygons split to improve response times.

 

The new layers should be automatically added and the old layers removed at the start of your first GPinfo session following the November data update. If this does not happen, you can manually apply the changes by selecting View > Options > Updates > Update GPinfo system layers now.

 

 

Map/Book Discount Bundle                      

 

Buy the 2017 Petroleum Permits Map & Book for the bundle price of $150 and save $70 off the full retail price.

The bundle includes –

 

-  an A0-sized laminated copy of the 2017 Permits Map, normally $120

-  an A3-sized copy of the Permits Map

-  the November edition of the 2017 Permits Book, scheduled for release next week, normally $100

-  an update to the Permits Book in February 2018

-  free delivery

 

All for $150

 

Visit our web store to place your order.

 

 

Industry Summary                                       

 

Company News

 

In September 2017, Zeta Resources, through its 100% owned subsidiary Zeta Energy, made a partial takeover offer to acquire at least 42% of the shares of New Zealand Oil & Gas Ltd that it did not already hold or control for $0.72 per fully paid ordinary share. Zeta Energy’s offer closed on 18/10/2017. The minimum acceptance condition was not met, and accordingly the offer has now lapsed. (Source: Zeta Energy announcement, 19/10/2017).

 

Pan Pacific Petroleum NL (PPP) is pleased to advise that the scheme of arrangement pursuant to which Zeta Resources Ltd will acquire all the ordinary shares in PPP has been implemented for consideration of $0.038 cash per PPP or one Zeta share for every 10 PPP shares. All PPP shares have been transferred to Zeta. PPP was removed from the ASX on 13/11/2017. (Source: Pan Pacific Petroleum NL announcement, 10/11/2017).

 

Australia Pacific LNG will supply a further 41 PJ of natural gas to the Australian domestic market after reaching a gas sales agreement with Origin. The 14-month contract started on 01/11/2017 and comprises of 4 PJ in 2017 and 37 PJ in 2018. The new contract increases Australia Pacific LNG’s total domestic contracted supply commitment for 2018 to over 186 PJ. This represents almost 30% of Australian east coast domestic gas demand, up from 20% in 2017. (Source: Australia Pacific LNG, announcement, 26/10/2017).

 

Cooper Energy has completed the transaction for APA Group to acquire, upgrade and operate the Orbost Gas Plant announced 01/06/2017. As part of the transaction, APA Group acquired 100% of the shares in the entity which owns the Orbost Gas Plant, Cooper Energy (PBGP) P/L, for $20m. Cooper Energy (PBGP) P/L was subsequently renamed APA Orbost Gas Plant P/L. The transaction is a key milestone for the Sole gas project, which will bring a new source of gas supply to south-east Australia from 2019. The agreement also provides for the Orbost gas plant to process gas from Cooper's adjacent Manta gas field and potentially other gas fields. APA will also undertake the $250 million plant upgrade. (Source: Cooper Energy announcement, 01/11/2017).

 

Mineral Resources Ltd has acquired all the assets of Empire Oil & Gas NL, including the Red Gully Processing Facility and all its petroleum exploration tenure, through acquiring Empire Oil Company (WA) Ltd. The transaction, which completed on 08/11/2017, was undertaken pursuant to a Deed of Company Arrangement approved by creditors of Empire on 02/11/2017. (Source: Mineral Resources Ltd announcement, 09/11/2017).

 

Searcher Seismic is pleased to announce a regional multi-client airborne gravity, gravity-gradiometry and magnetics survey over the near-shore areas, Gulf of Papua. The Roho survey covers approximately 60,700 sq km along the southern coast of PNG and follows several marine seismic and geochemical projects recently completed by Searcher aimed at assessing the hydrocarbon potential of the Gulf of Papua and adjacent Coral Sea areas, offshore PNG. The Roho survey is designed to bridge the gap between the onshore areas of PNG where many wells have been drilled, providing good geological control points, and the offshore regions in the Gulf of Papua and Coral Sea, where a substantial database of new, high quality seismic data is now available, but well data is sparse or absent all together. Mobilisation is underway and acquisition will commence in late November 2017. Final data will be available early 2018 and a regional interpretation of the new data will also be completed by June 2018. (Source: Searcher Seismic announcement, 30/10/2017, Energy News, 31/10/2017).

 

Geoscience Australia has released the first-ever seismic data from the Northern Territory-Queensland South Nicholson Basin. The South Nicholson gravity survey was conducted in July 2017, with 2724 new gravity stations completed at 4 km spacing covering an area of 43,330 sq km. The dataset gathered from the gravity-survey has not yet given any indication of what resources are available but government has said further information will be available early next year. (Source: Energy News, 31/10/2017).

 

On 5 October 2017, Lakes Oil NL made an open, formal offer to the Victorian Minister for Resources presenting an opportunity for the Government to work cooperatively with Lakes to address gas supply and pricing issues that are burdening Victorian industry and households. Features of the proposal included:

1:  The Company would undertake specified conventional onshore drilling activity, within the parameters of the state’s existing petroleum legislation as recently amended by Government, to confirm gas can be produced from the Company’s known onshore gas fields.

2: Gas from the Company’s onshore Victorian fields will be supplied to Victorian consumers and industry as a first priority.

3: The Company will commit to payment of a proportion of gas sales revenue to landowners upon whose land, and to communities within which, gas production activities are carried out.

4: The Company offered to relinquish its sensitive surf-coast exploration permit, PEP163, subject to agreement

(Source:  Lakes Oil Quarterly Report, September 2017).

 


 

Developments

 

The Stag oilfield off the coast of Western Australia reached a milestone production of 3600 bopd over a 10-day period Jadestone Energy said. This represents a 40% increase in production since the company took over operatorship of the field in July this year. Jadestone bought 100% of the field from the Quadrant Energy-Santos Ltd joint venture for $10 million cash. Jadestone says it has been 12 months since the field achieved this level of average production over a 10-day period. It also exceeds the company’s forward production guidance for the second half that was 3000-3500 bopd. Jadestone Chairman and Chief Executive Officer Paul Blakeley said the company expects to continue maintaining production in the 3000-3500 bopd range for the rest of this year. An infill drilling program is planned for 2018 with the intention of testing the capacity of the reservoir and further increase production volumes. (Source: Oil & Gas Journal, 18/10/2017).

 

Senex Energy has brought online the first of 30 appraisal wells at the Western Surat Gas Project (WSGP) directly north of Gladstone LNG’s producing Roma fields, and is on track to complete Phase 2 on time and budget. Senex has brought the first pod of Phase 2 wells online, with all 30 wells to be producing by the end of 2017, with 24 wells drilled in the Phase 2 program with the rest to be completed in coming months. The WSGP, which involves delivering CSG from about 915 sq km of acreage in Queensland's Surat Basin, should support up to 425 wells over its life, and Senex has already teed up a gas sales agreement with GLNG to supply up to 50 TJ/d over 20 years. (Source: Senex Energy Ltd announcement, 23/10/2017).

 

Chevron Australia has shipped its first cargo of LNG from the Wheatstone natural gas project in Western Australia. The cargo will be delivered to Japanese buyer JERA - a joint venture of Chubu Electric Power and Tokyo Electric Power - one of the project’s foundation customers. A second LNG train at the facility is expected to come on line in about 6-8 months. At full capacity, the two-train project will produce 8.9 mtpa of LNG. The associated domestic gas plant has capacity to produce 200 TJ/day of gas for Western Australia. (Source: Oil & Gas Journal, 01/11/2017).

 

The Federal Government has announced that ACIL Allen, in conjunction with GHD, as the successful tenderer to conduct a pre-feasibility study on the West-East Gas Pipeline. The West-East Gas Pipeline pre-feasibility study is the first Commonwealth investigation of the potential for constructing a gas pipeline from Western Australia to link up to the east coast gas market. The findings from the study may inform a full feasibility study to test the viability of constructing a natural gas pipeline to provide additional gas supplies and increase competition in the east coast gas market. ACIL Allen will be involved in the market and analysis component of the study, while GHD will take on the pipeline engineering and pipeline route assessment component. ACIL Allen and GHD are due to provide the pre-feasibility report in March 2018. (Source: Energy News, 30/10/2017).

 


 

Discoveries

 

AWE Ltd has commenced flow testing of the Waitsia 3 well to further appraise the conventional Waitsia gas discovery in Production Licences L1/L2 in the onshore Perth Basin, Western Australia. The zone being flow tested is the Kingia Sandstone, where a 42m interval (3,248 m to 3,290 m measured depth below rotary table) has been perforated. The well flowed gas at an instantaneous maximum rate of 50 mmscfd and an average of 49.5 mmscfd on an 80/64-inch choke at ~1,929 psig flowing well head pressure over a 2.6 hour period. The well will now be shut in for a brief pressure build-up survey prior to a series of flow tests at various choke settings. (Source: AWE Ltd announcement, 23/10/2017).

 

Norwest Energy expects an active programme in the first half of 2018 to define the size of the Xanadu 1 oil discovery. The first phase of analysis on the discovery has been completed showing a yield of 34.7 degrees API crude oil with no hydrogen sulphide and extremely low levels of carbon dioxide, at 0.02%. These initial results suggest the crude has similarities with the Cliff Head oil field could fetch the same market price. Key initial findings indicate that in addition to the potential of the up-dip structure, there is now evidence that “down” structure volumes are also present within the currently mapped Xanadu prospect. All available reservoir, pressure and fluid data is being utilised to update the pre-drill structure and better estimate the in-place volumes of oil. A work program for the first half of next year is being prepared. (Source: Norwest Energy announcement, 24/10/2017).

 

Beach Energy’s Lowry 1 exploration well has confirmed a new discovery and validates for the approved expansion of the Middleton gas facility from 25 mmscfd to 40 mmscfd.  Lowry 1 is located in the Southwest Patchawarra play fairway approximately four kilometres northwest of the Middleton gas facility. The well intersected 3.3m of net pay and was cased and suspended as a future producer. A two-hour drill stem test was conducted over the interval 2,586 – 2,593m and flowed at 9.4 mmscfd on a 48/64” choke at 955 psi flowing pressure. Approximately 34 bbls of condensate was recovered and 400 bopd. (Source: Beach Energy announcement, 01/11/2017).

 

Beach Energy’s Crawford 1, located approximately two kilometres northwest of the Middleton gas facility and proximal to the Brownlow, Middleton and Udacha fields, has confirmed the extension of the Brownlow Field. Crawford 1 intersected 4.1m of net gas pay in the Mid-Patchawarra Formation and was cased and suspended as a future producer. Reservoir pressure information indicated good permeability and connection to the Brownlow Field, which is expected to enable incremental reserves to be booked and produced. (Source: Beach Energy announcement, 01/11/2017).



 Permit Changes                                                                

Northern Territory

 

Bonaparte Basin

Sinopec O&G Australia (NT) P/L and OPIC Australia P/L have entered a withdrawal agreement under which SIPC and OPIC will assign their respective 30% interests in AC/P21 to Eni Australia Ltd. In a separate agreement, Eni Australia Ltd and Murphy Australia Oil P/L have entered a farmin agreement under which Eni will assign 40% of its interest in AC/P21 to Murphy.

 

AC/P62 was granted to Carnarvon Petroleum Ltd 100% on 02/11/2017. The licence will expire on 01/11/2023. Work program is as follows -

Year 1-3: license 682 sq km MC3D PSDM seismic data, seismic inversion and interpretation, studies $6.55m
Year 4: well planning $0.25
Year 5: 1 well-$30m; Y6-post-well G&G studies $0.25m

 

Gazettal areas AC17-3 and NT17-1 closed on 19/10/2017 and are under consideration.

 

NT/RL5 has been renewed to 26/10/2022. Work program is as follows –

Year 1: continue & complete pre-FEED work program
Year 2: undertake FEED
Year 3-5: continue work to commercialise the Barossa field

Total estimated expenditure $16-32m.

 

A change to the work program for NT/RL7 has been approved -

Year 1-5: integrated reservoir modelling, seismic interpretation, technical studies, concept engineering studies, well engineering studies, greenhouse gas management, commercial & marketing, 1530 sq km 3D broadband seismic reprocessing $12.5m

Vulcan Sub Basin

Gazettal AC17-2 closed on 19/10/2017 and is under consideration.

Queensland

 

 

Resources companies are encouraged to request an area of Queensland be considered in future releases of land available for exploration.  Expressions of Interest for exploration areas can be lodged with the Department of Natural Resources and Mines until the close of submissions on 01/12/2017. 

Expressions of Interest can be submitted here.  

For further information visit the Queensland Government website or email.

Bowen Basin

ATP 693 has been relinquished and now reverts to vacant acreage.

 

ATP 1177 was renewed to 30/11/2021.

 

Westside ATP 769P P/L 75.5% and Mitsui E&P Australia P/L 24.5% have applied for PCA 196 over 234 sq km.

 

Eureka Petroleum Ltd 100% has applied for production licences PL 1036 over 240 sq km over the Monslatt field and PL 1038 over 160 sq km.

 

Beach has reached an agreement to sell its interest in PL 184 to Australian Gasfields Ltd. Completion is due January 2018 and is subject to the satisfaction of various conditions.

 

PL 203 has been replaced by PL 268. PL 268 was granted on 28/09/2017. The licence will expire on 27/09/2047.

Clarence Moreton Basin

BNG P/L 70% and Arrow CSG (Australia) P/L 30% have applied for potential commercial area PCA 197 over 227 sq km over the Mt Lindsay South field.

 

BNG P/L 70% and Arrow CSG (Australia) P/L 30% have applied for potential commercial area PCA 198 over 152 sq km over the Mt Lindsay North field.

Cooper Basin

Beach has reached an agreement to sell its 100% interest in ATP 932 to Australian Gasfields Ltd. Completion is due January 2018 and is subject to satisfaction of various conditions.

 

ATP 940 has been renewed to 06/11/2023 over a reduced area of 1676 sq km.

 

Production licence PL 105 over the Roti field has been replaced with PL 287. PL 287 was granted on 12/10/2017. The licence will expire on 11/10/2027.

Eromanga Basin

ATP 560 has been relinquished and now reverts to vacant acreage.

 

ATP 633 has been relinquished and now reverts to vacant acreage.

 

ATP 665 has been relinquished and now reverts to vacant acreage.

 

ATP 794 Barcoo Block, Regleigh Block and Springfield Block expired on 31/10/2017 and now revert to vacant acreage.

 

Victoria Oil Exploration (1977) P/L 60% and Bridgeport Energy (QLD) P/L 40% have applied for potential commercial area PCA 190 over 233 sq km.

 

Geothermal applications EPGs 90, 92, 93, 94, 95, 96 and 99 have been refused.

Galilee Basin

Comet Ridge has reached agreement to farm-out the Sandstone Reservoir sequence (Deeps) of ATP 743, ATP 744 and ATP 1015 to Vintage Energy P/L. Vintage will fund approximately $8.5 million to earn a 30% interest.  Comet Ridge will continue to hold 100% of the CSG resource (Shallows). If Comet elects not to participate in Stage 2, and Vintage decides to do so, the cost of Stage 2 will be met by Vintage at 100%, entitling it to increase its participating interest in the Deeps to 48.5%. The agreement is subject to several conditions that are due to be satisfied in 12 weeks. One principle condition is the confirmation by Vintage that it has raised the funds for its Stage 1 farm-in obligations. 

Stage 1a requires the drilling of a conventional gas appraisal well on the Albany sandstone structure.  Vintage will fund the first $3.35 million of Stage 1a to earn 15% in the Deeps across the three permits. 

Stage 1b provides well stimulation and production testing of Albany 1. The decision to proceed with this stage will be determined by the gas flow rate of Albany 1 once completed.  If both Vintage and Comet proceed with Stage 1b, the cost will be shared 25% (Vintage) and 75% (Comet).  If Comet elects not to participate, Vintage can carry out Stage 1b at sole cost which will entitle it to a further 3.5% interest in the Deeps, bringing its total to 18.5%.

Stage 2 requires Comet Ridge and Vintage Energy to spend up to $5 million each for Vintage to earn a further 15%, raising its equity to 30%. Stage 2 includes further drilling on the Albany structure, focusing on increasing resources and reserves and 2D and 3D seismic acquisition.  If both parties elect to proceed, Vintage Energy will acquire another 15% increasing its total holding to 30% (or 33.5% if it carried out Stage 1b by itself). If Comet Ridge elects to participate in Stage 2, Vintage may fund 100% to earn an extra 15%, for a total interest of 48.5%.

 

Geothermal application EPG 100 has been refused.

Surat Bowen Basin

ATP 795 is in the process of being renewed.

 

Applications for potential commercial areas PCA 5, PCA 6 and PCA 7 have been withdrawn.

 

Production licence applications PL 311 and PL 312 have been withdrawn.

Surat Basin

A later work program has been submitted for ATP 754. Under the HOA, Armour will fund 2D/3D seismic if required to further image the Mardi Prospect, as well as having an option to drill an exploration well.

 

ATP 805 was renewed to 31/08/2022.

 

ATP 2028 is an application by Ausam Resources P/L 50% and Armour Energy (Surat Basin) P/L 50% over 638 sq km of ATP 754.

 

ATP 2029 is an application by Ausam Resources P/L 100% over 153 sq km of ATP 754.

 

Senex was announced as preferred tenderer of gazettal area PLR 2016/17-1-3. Subsequently, Senex Assets P/L 100% applied for production licence PL 1037 over the area.

 

Bounty Oil/Ausam has relinquished its interest in the Exploration Rights of PL 71 and Armour Energy (Surat Basin) now holds 100%.

 

Production licence application PL 240 has been withdrawn.

 

Armour Energy Ltd has been announced as preferred tenderer for gazettal area PLR2016/2017-1-2 which closed on 20/04/2017.

South Australia

 

Cooper Basin

Geothermal applications GELA 655, GELA 656 and GELA 658 have been varied and now cover 2955 sq km, 2433 sq km and 2694 sq km respectively.

 

PEL 182 is being renewed.

 

Retention leases have been granted over the entire area of PEL 637 and PEL 638.

 

PRL 210 – PRL 220 were granted to Stuart Petroleum P/L 60% and Lattice Energy Ltd 40% on 25/10/2017. The licenses will expire on 24/10/2022.

 

PRL 221 – 230 were granted on 25/10/2017. The licenses will expire on 24/10/2022. Shallows interests are Stuart Petroleum Cooper Basin Oil P/L 80% and Planet Cooper Basin P/L 20%. Deeps interests are Cooper Basin Oil P/L 53.75%, Lattice Energy Ltd 33.75% and Planet Cooper Basin P/L 12.5%.

Otway Basin

Geothermal licence GEL 223 has been renewed to 23/07/2022 over a reduced area of 153 sq km.

Tasmania

 

Bass Basin

Work program gazettal areas T17-1 and T17-2 closed on 19/10/2017 and are under consideration.

Otway Basin

Years 5 and 6 of the work program for T/49P have been varied -

Year 5: 750 sq km 3D seismic acquisition, processing, interpretation and prospect maturation $10m
Year 6: 1 exploration well $20m

Victoria

 

Gippsland Basin

Work program gazettal area V17-1 closed on 19/10/2017 and is under consideration.

Otway Basin

Work program gazettal areas V17-2 and V17-3 closed on 19/10/2017 and are under consideration.

 

Mawson Petroleum P/L and Bass Oil Ltd are withdrawing from PEP150. On completion, interests will be Somerton Energy P/L 50% and Bridgeport (Eromanga) P/L 50% with Bridgeport operating.

Western Australia

 

Barrow Sub Basin

The year 4 work program for TP/8 has been extended by 12 months from 06/09/2017 to 06/09/2018.  The licence has had its expiry date extended to 06/09/2019. A location application was lodged on 03/10/2017.

 

WA-320-P expired on 20/10/2017. The area reverts to vacant acreage.

Browse Basin

Gazettal area W16-5 closed on 19/10/2017 and is under consideration.

 

The year 4 work program for WA-281-P has been suspended for 6 months from 30/11/2017 to 30/05/2018. The licence has had its expiry date extended to 30/05/2019.

 

The year 4 work program for WA-371-P has been extended by 12 months from 18/07/2018 to 17/07/2019.  The licence has had its expiry date extended to 17/07/2020. A change to work program has been approved –

Year 4: licence 102 sq km multi-client broadband 3D seismic, geotechnical studies $0.85m

 

WA-532-P was granted to INPEX Browse E&P P/L 100% on 02/11/2017. The licence will expire on 01/11/2023. Work program is as follows –

Year 1-3: 2000 km 2D seismic reprocessing, 7185 km 2D seismic, 9185 km 2D seismic AVO analysis & seismic inversion, 600 sq km 3D seismic, 600 sq km 3D seismic AVO analysis & seismic inversion, G&G studies $23.61m
Year 4: G&G studies $2.3m
Year 5: G&G studies, 1 well $31m
Year 6: G&G studies $1m

 

WA-83-R was granted to Chevron Australia (WA-383-P) P/L 50% and Shell Australia P/L 50% on 12/10/2017. The licence will expire on 11/10/2022. Work program is as follows –

Year 1: broadband reprocessing & PSDM $0.25
Year 2: seismic interpretation, subsurface & technical studies $0.15m
Year 3: subsurface, engineering & technical studies $0.2m
Year 4: subsurface, engineering & technical studies $0.05m
Year 5: gas market/cost review $0.05m

Canning Basin

Gazettal area W16-6 closed on 19/10/2017 and is under consideration.

Carnarvon Basin

Gazettal areas W16-24, W16-9 and W17-8 closed on 19/10/2017 and are under consideration.

 

WA-155-P (2) is being relinquished.

 

A retention lease application was lodged over the Sappho Extension Location WA-205-P LS on 23/10/2017.

 

A suspension and extension for WA-323-P was lodged on 13/10/2017.

 

Western Gas Corporation has acquired 100% of the Equus gas project from Hess Corporation, which comprises four exploration permits WA-390-P, WA-474-P, WA-518-P, WA-519-P and a retention lease WA-70-R.

 

WA-439-P has been renewed to 19/10/2022. Work program is as follows –

Year 1-3: G&G studies, 200 sq km 3D PSDM reprocessing $0.75m
Year 4: G&G studies $0.2m
Year 5: 200 sq km 3D seismic $2.5m

 

A change to the WA-496-P work program has been approved –

Year 5: 1300 sq km 3D seismic reprocessing, geotechnical studies $0.8m
Year 6: 1 well, G&G studies $41m

 

Pilot Energy and Black Swan Resources have commenced a sale process for 100% of WA-507-P.

 

Chevron Australia New Ventures P/L has transferred 50% interest in WA-526-P to Chevron Australia (WA-526-P) P/L and 50% of its interest to Woodside Energy Ltd.

Dampier Basin

Gazettal area W17-5 closed on 19/10/2017 and is under consideration.

Perth Basin

A suspension and extension for EP 321 was lodged on 25/10/2017.

 

AWE has increased its interest to 100% in EP 455 after its joint venture partner, Global Energy Ventures Ltd, withdrew from the permit.

 

EP 496 was granted to Bunbury Energy P/L 100% on 09/10/2017. The licence will expire on 08/10/2023. Work program is as follows –

Year 1: 150 km 2D seismic survey, G&G studies $1.8m
Year 2: 50 km 2D seismic survey, G&G studies $0.8m
Year 3: G&G studies $0.3m
Year 4: 1 well, G&G studies $5.3m
Year 5: G&G studies $0.3m
Year 6: 1 well, G&G studies $5.3m

 

Suspension and extensions for R 6 and R 7 were lodged on 25/10/2017.

Roebuck Basin

Gazettal W17-4 closed on 19/10/2017 and is under consideration.

New Zealand

 

Taranaki Basin

Horizon Oil has entered into an agreement with Todd Maari Ltd to acquire its 16% interest in PMP 38160 for a consideration of US$17.6m. The transaction is subject to New Zealand Government Ministerial approval, approval of the Overseas Investment Office, joint venture consent and other customary conditions. The transaction has an effective date of 31/12/2017.

Papua New Guinea

 

Papuan Basin

PPL 287 was relinquished in September 2017.

 

ExxonMobil PNG Lark Ltd acquired 50% of PPL 395 from Oil Search (PNG) Ltd.

 

Santos is in the process of acquiring 20% of PPL 395, PPL 464, PPL 487, PPL 507 and PPL 545.

 

Twinza Oil (PNG) Ltd has applied for production licence APDL 14 over the Pasca A discovery.   APDL 14 will replace PPL 328.

 

                                                                                                                                  

To unsubscribe click here.

For more information please contact GPinfo support on +61 3 8594 3607 or by e-mail.

Datamine Software, Suite 5, 1153-1157 Burke Road, West Kew VIC 3101, Australia.