The September 2013 GPinfo update is now available.
New Standard Energy
has increased its stake in Elixir Petroleum following successful
equity raising. New Standard purchased shares at a total cost of $1
million, taking New Standard’s interest in Elixir from 13.7% to 28.2%.
The shares were issued at a price of 1.2c per share. (Source: New
Standard Energy announcement, 13/08/2013).
Ochre Group Holdings
has entered into an implementation deed to acquire Emerald Oil and
Gas NL to create a diversified natural resources development and
holding company. Under the scheme, Ochre will offer Emerald shareholders
one share for every 2.75 shares in Emerald. Following completion,
Emerald will be a wholly-owned subsidiary of Ochre and will cease to be
a listed entity. (Source: Ochre Group Holdings announcement,
is pleased to announce a significant increase of 157% in the Company’s
2P reserves to 28.5 mmboe and a 41% increase in its 2C contingent
resources to 14.8 mmboe. The assessment by RISC and DeGoyler and
MacNaughton lifted reserve numbers in the company’s Western Flank,
Western Cooper Wet Gas and Eastern Cooper oil permits. (Source:
Drillsearch Energy announcement, 15/08/2013).
South Australian Government
have agreed for a 15 year petroleum retention licence scheme across all
of the company’s operated oil permits in the Cooper-Eromanga Basin. The
deal covers about 10,000sq km of oil exploration permits and allows
Senex to convert its petroleum exploration licences to petroleum
retention licences with special conditions. Furthermore, the company’s
western flank acreage will not be caught by the relinquishment rules in
SA, which require one third to one half of the original area to be
surrendered after five years. The 15 year scheme applies for an initial
five year term and can be renewed for two further five year periods.
The agreement comes with a term of $200 million in exploration and
appraisal expenditure as part of the 15 year exploration program.
(Source: Senex Energy announcement, 19/08/2013, Energy News Premium,
has completed its initial assessment of prospects and leads in AC/P 50
and AC/P 51 and has identified the Ramble On prospect, incorporating
proven reservoir, seal and source intervals as a new structural play for
the basin. MEO estimates Ramble On could contain mean prospective
resources of 56 mmstb oil. MEO has commenced a partial sale process
ahead of 2014/2015 drilling. (Source: MEO Australia announcement,
has booked significant contingent resources at ATP 855P, with the areas
around Halifax 1 showing 318 bcf to 1.15 tcf of gas. The joint venture
engaged an unnamed resource evaluation company to undertake a report on
the Contingent Resources around the Halifax 1 well and came up with the
2C figure of 629 bcf. The consultants used core, log and flow test data
to come up with the numbers. (Source: Icon Energy announcement,
Loyal Strategic Investment
will make a proportional takeover offer for 75% of each Coalbank
shareholder’s ordinary shares in Coalbank at an offer price of 1 cent
per share. The Coalbank board supports the bid and unanimously
recommends the offer to its shareholders, in the absence of a superior
proposal. The offer is expected to close in October 2013. (Source:
Coalbank announcement, 27/08/2013).
Esso Highlands Ltd, operator of the PNG LNG project, has advised
that the project is more than 90% complete and is on schedule for first
LNG delivery during the second half of 2014. The commissioning phase of
the project has recently commenced in preparation for the first LNG
production in 2014. As forecast last year, the projects estimated cost
remains unchanged at $US19. (Source: ExxonMobil announcement,
The Cornea joint venture has completed its determination of the
contingent resources within the oil and gas accumulations of the
Cornea field located within WA-342-P. On the oil side, it said the
best estimate on a P50 basis held the potential for 411.7 mmbbls in
place and a contingent 28.8 mmbbls. For gas, it said that it could be
sitting on a best estimate on a P50 basis of 118 bcf of gas in place and
a contingent 67.1 bcf. The determination of the contingent resources
forms part of the work necessary to complete the application for a
retention lease over the Cornea field, Focus field and Sparkle oil
fields, collectively known as the greater Cornea field. (Source: Moby
Oil & Gas announcement, 19/08/2013).
Woodside has announced that the Browse joint venture participants
have selected the use of FLNG technology as the development concept to
commercialise the three Browse gas fields. The joint venture
partners have agreed to progress the basis of design (BOD) work on a
concept using Shell’s FLNG technology. The BOD will determine the major
design parameters for the front engineering and design (FEED) phase of
the project. Work on the design will start immediately in order to hit a
FEED target of 2014. (Source: Woodside announcement, 02/09/2013).
The Chief Justice of Western Australia has labelled the decision to
give environmental approval to a gas hub at James Price Point
near Broome as “invalid” because of conflicts of interest among the
Environmental Protection Agency board members.
The Wilderness Society had argued conflicts of interest in the
Environmental Protection Authority assessment process,
four members of that board were forced to step aside from the
decision-making portion and
resulted in just one EPA board member - chairman Paul Vogel - making the
In a decision handed down this morning, the chief justice found that the
four members of the EPA who had stood aside had enough of an influence
to call into question the ultimate decision.
The EPA said it would consider the ruling. The state government is
seeking advice from the State Solicitor's office.
(Source: Energy News Premium, 19/08/2013).
BHP has commenced gas production sales at the Macedon project in
Western Australia. BHP also told investors that sales from the 200
million cubic feet per day project had started in August. The Macedon
project production wells supply a wet gas pipeline to the onshore gas
treatment plant in Ashburton North, 17km southwest of Onslow.
(Source: Energy News Premium, 21/08/2013).
The Queensland Government has granted environmental approval for
Arrow’s $15 billion LNG project on Curtis Island. The project
will be the fourth LNG development on Curtis Island, the plant will be
capable of producing 18 million tonnes of LNG per year. The project will
include construction of a gas pipeline from Bruce Highway to Curtis
Island, a liquefaction facility, construction of marine facilities,
construction of jetties and potential localised dredging. The project
must now get Federal Government approval to consider potential impacts
to the Great Barrier Reef and other matters of national significant
within the statutory 30 days. The decision is currently due on
23/10/2013. (Source: Energy News Premium, 11/09/2013).
Senex Energy has delivered a significant oil discovery with the
Burruna 2 exploration well in the southern Cooper-Eromanga Basin
permit PEL 115. Wireline logs have confirmed a net pay interval in the
mid Namur Formation of 5.3 metres with 750 bopd flowing to surface. The
well will be cased as suspended as a future oil producer. (Source:
Senex Energy announcement, 23/08/2013).
Multiple gas charged reservoirs have been intersected and an 87m gross
interval with high net pay was intersected during drilling of the
Proteus 1/ST2 well in the Browse Basin. The ConocoPhillips-operated
well has shown the presence of movable hydrocarbons in good quality
Jurassic reservoir units, supported by logging, formation pressure
gradients and gas samples. Wireline logging of the well is nearing
completion and the joint venture will be undertaking a production test
over the coming weeks. (Source: Karoon Gas Australia announcement,
Bounty Oil and Gas is pleased to announce that the Irtalie East 4
development well has been successfully cased as a potential oil
producer. The well encountered good oil shows and between 6 and 8.5
metres of net oil pay in the primary target, the Basal Birkhead and
Hutton Formations. (Source: Bounty Oil & Gas announcement,
Beach Energy has had success at Chiton 2 in PEL 91. The well
was drilled to appraise the field structure, 270 metres north west of
the location where Chiton 1 produces oil from the Namur sandstone
reservoir. Chiton 2 intersected a 5.5 metre gross oil column and has
been cased and suspended as a future Namur oil producer. (Source:
Beach Energy announcement, 04/09/2013)
Permit Updates and Changes
New South Wales
In the Darling Basin, renewal applications for PEL 422, PEL
424 and PEL 471 were withdrawn on 14/08/2013 and these
licences have now expired.
The following applications were withdrawn at the request of Acer
Energy Ltd on 14/08/2013 - PELA 139, PELA 140, PELA 141,
PELA 142 and PELA 143.
In the Vulcan Basin, MEO has commenced a partial sale process of AC/P
51 ahead of 2014/15 drilling.
In the Browse Basin, Finder Exploration has entered into a farm-out
agreement which provides for Shell Development (Australia) P/L to earn
50% and operatorship in AC/P 52. Shell will earn its interest
through cash payments and funding a percentage of drilling costs of the
Cronus 1 exploratory well up to an agreed cap.
In the Petrel Sub Basin, NT/P 79 was surrendered on 02/09/2013.
In the Petrel Sub Basin, the year 2 work program for NT/P 81
program is now - 1 well, 250 sq km 3D seismic $15m.
In the Money Shoal Basin, an application has been lodged with NOPTA to
surrender NT/P 83.
In the Georgina Basin, Statoil was transferred 80% of PetroFrontier's
interest in EP 103, EP 104, EP 127, EP 128,
EP(A) 213 and EP(A) 252 as part of the amended farm-in
agreement. On 01/09/2013 Statoil assumed operatorship.
In the Pedirka Basin, EP 107 is in the process of being renewed.
In the Amadeus Basin, EP 118 was surrendered on 20/08/2013.
In the Ngalia Basin, EP 164 and EP 166 were granted to
Tamboran Resources P/L on 23/08/2013. The licenses will expire on
In the McArthur Basin, EP 184 was granted to Imperial Oil & Gas
P/L on 21/08/2013. The licence will expire on 20/08/2018.
In the Georgina Basin, application EP(A) 229 was withdrawn with
effect from 19/08/2013.
In the Eromanga Basin, ATP 267P was renewed to 30/11/2015. Work
program is as follows -
G&G studies, 50 km 2D seismic, 1 well (to 1158m)
(30/11/2011 to 30/11/2015)
In the Surat Basin, ATP 470P was renewed to 28/02/2015. Work
program is as follows -
seismic reprocessing, 60 km 2D seismic, technical studies, 1 well (to
(01/03/2011 to 28/2/2015)
Also in the Surat Basin, ATP 471P was renewed to 28/02/2015.
Work program is as follows -
250 km seismic reprocessing, interpret seismic data
Year 2: 1 well (to 2200m)
Year 3: 50 km seismic
Year 4: 1 well (to 2200m)
(01/03/211 to 28/2/2015)
In the Galilee Basin, ATP 743P has undergone a partial
relinquishment and now covers a reduced area of 4,320 sq km.
In the Eromanga Basin, Santos and Bengal have exercised their
pre-emptive rights on the sale of Senex’s interest in ATP 752P Barta,
ATP 752P Wompi and PL 303 and now hold the following
ATP 752P Barta
& PL 303 - Santos QNT P/L 54.643%, Bengal Energy (Australia)
ATP 752P Wompi
- Santos QNT P/L 44.423%, Bengal Energy (Australia) 38.077%
In the Surat Basin, ATP 754P has undergone a partial
relinquishment and now covers 833 sq km.
In the Eromanga Basin, application ATP 766P was withdrawn on
In the Surat Basin, ATP 805P has undergone a partial
relinquishment and now covers a reduced area of 229 sq km.
In the Cooper Basin, ATP 809P has been relinquished and now
reverts to vacant acreage.
In the Surat Basin, ATP 849P has been relinquished and now
reverts to vacant acreage.
In the Surat/Bowen Basin, ATP 852P was renewed to 30/04/2019.
Work program is as follows -
20 CSG wells (330m to 700m)
(01/05/2011 to 30/04/2015)
In the Eromanga and Cooper Basins, Drillsearch’s interests in ATP
917P, ATP 920P, ATP 924P and ATP 932P are held
by Drillsearch Energy 50% and Circumpacific Energy (Australia) 50%.
In the Eromanga Basin, ATP 1005P has undergone a partial
relinquishment and now covers a reduced area of 4,364 sq km.
In the Galilee Basin, ATP 1008P has undergone a partial
relinquishment and now covers a reduced area of 3,077 sq km.
Also in the Galilee Basin, ATP 1070P was granted to Seymour
Energy P/L 100% on 30/08/2013. The licence will expire on 31/08/2017.
Overlapping application ATP 1071P was refused. Work program is as
100 km 2D seismic reprocessing, reprocess 5400 km airborne geophysical
Year 2: 100 km 2D seismic, seismic interpretation, 2 CSG wells
Year 3: 5 partly cored CSG wells (to 1500m)
Year 4: 10 CSG appraisal wells (to 1500m)
(30/08/2013 to 30/08/2017)
In the Surat Basin, work program for ATP 972P is as follows -
Year 2: technical studies, 1 well
Year 3: technical studies, 1 well, 1 monitoring well
Year 4: technical studies
(2704/2011 to 30/04/2015)
In the Galilee Basin, the following licences have undergone partial
relinquishments and now cover reduced areas: ATP 984P (3,442 sq
km), ATP 991P (3,904 sq km) and ATP 996P (3,261 sq km).
In the Eromanga Basin, ATP 999P has undergone a partial
relinquishment and now covers a reduced area of 4,106 sq km.
In the Surat Basin, ATP 1074P was granted to Seymour Energy P/L
100% on 30/08/2013. The licence will expire on 31/08/2017. Overlapping
application ATP 1073P was refused. Work program is as follows -
reprocess 70 km 2D seismic, reprocess 2900 sq km airborne geophysical
Year 2: 150 km 2D seismic, 3 CSG wells (to 1000m)
Year 3: 8 partly cored CSG wells (to 1000m)
Year 4: 3x5-spot CSG appraisal wells (15 wells to 1000m)
(30/08/2013 to 31/08/2017)
A number of new applications have been made for Potential Commercial
PCA 135, PCA 136 and PCA 138 by AGL Energy 99%, CH4
Gas P/L 0.7% and Arrow CSG (ATP 364) 0.3%
by Oil Investments 50% and Starzap 50%
In the Surat Basin, PL 64 expired on 19/08/2013.
In the Galilee Basin, EPG 11 and EPG 13 expired on
31/08/2013 and now revert to vacant acreage.
In the Eromanga Basin, EPG 37 expired on 31/08/2013 and now
reverts to vacant acreage.
In the Ceduna Basin, Statoil’s interest in EPP 37, EPP 38,
EPP 39 and EPP 40 is held by Statoil Australia Theta BV.
In the Cooper Basin, Acer Energy acquired 20% from Mid Continent
Equipment (Australia) P/L under the PEL 101 farm-in agreement
dated 06/05/2013. The farm-in was completed in July 2013.
In the Cooper Basin, Tellus Resources will transfer a 50% interest in
PEL 105 to Senex Energy for a total of $3.5 million in two tranches
to partially fund the drilling of Pirie 1. After rig release of Pirie 1
the permit will be operated by Senex. Senex has the option for a further
20% interest should it fund another well on or before 30/06/2014.
In the Cooper Basin, the year 5 work program for PEL 114 has been
extended by 8 months from 05/07/2013 to 05/03/2014. The licence has had
its expiry date extended to 21/07/2014.
In the Cooper Basin, Orca shareholder approval was received on
07/08/2013 for the acquisition by Senex of a 20% interest in PEL 115.
The transaction remains subject to regulatory and third party approvals
and is expected to complete in the 2013-14 year.
In the Cooper Basin, the sale of Strategic Energy Resources 5% interest
in PEL 182 to Senex was completed.
In the Cooper Basin, due to the original Planet Gas ASX announcement
being incorrect the interests in PEL 514 N and PEL 514 S have been
corrected. As of 16/07/2013 interests in PEL 514 N and PEL 514
S should be Stuart Petroleum Cooper Basin Oil P/L 80% and Planet
Cooper Basin P/L 20%. Planet Cooper Basin P/L has a 2% ORR on both
In the Adelaide Fold, PEL 606 was granted to SAPEX Ltd on
29/08/2013. The licence will expire on 28/08/2018. Work program is as
Year 2: G&G studies
Year 3: G&G studies
Year 4: G&G studies
Year 5: 2 wells
In the Otway Basin, PEL 629 was granted to Ouro Preto Resources
P/L on 02/09/2013. The licence will expire on 01/09/2018. Work program
is as follows -
1000 km seismic reprocessing
Year 2: 250 sq km 3D seismic, 2000 km seismic reprocessing, 500
sq km gravity gradiometry survey
Year 3: 1 well
Year 4: 3 wells
Year 5: 3 wells
In the Cooper Basin, Beach has withdrawn from PEL 90 C as of
In the Eromanga Basin, the year 5 work programs for GEL 191,
GEL 192 and GEL 193 have been extended by 6 months from
01/06/2013 to 31/12/2013. The licenses have had their expiry dates
extended to 03/05/2014.
In the Cooper Basin, Origin has withdrawn from both the Innamincka Deeps
and Shallows joint ventures. Geodynamics now holds 100% in GEL 211,
GRL 3, GRL 4, GRL 5, GRL 6, GRL 7,
GRL 8, GRL 9, GRL 10, GRL 11, GRL 12,
GRL 20, GRL 21, GRL 22, GRL 23 and GRL 24.
In the Cooper Basin, GEL 352 expired on 24/08/2013.
In the Officer Basin, the year 1 work program for GSEL 576,
GSEL 577, GSEL 578, GSEL 579, GSEL 580, GSEL
581, GSEL 582 and GSEL 583 have been extended by 12
months from 22/08/2013 to 21/08/2014. The licenses have had their expiry
dates extended to 28/07/2019.
Offshore in the Gippsland Basin, an application to surrender T/46P was lodged with NOPTA on
Onshore Tasmania, EL 14/2009 has been refused by the DIER and is
now deemed to be non-current.
Onshore Tasmania, SEL 9/2009 was relinquished on 15/08/2013.
Offshore in the Gippsland Basin, gazettal area V 11-6 which
closed on 08/11/2012 has not been granted and now reverts to vacant
In the Gippsland Basin, VIC/P 54 has had its Year 4 and Year 5
work programs varied -
Year 4: G&G studies $0.4m
Year 5: 1 exploration well, G&G studies $20m
Also in the Gippsland Basin, an application to surrender VIC/P 63 was lodged with NOPTA on
In the Otway Basin, AWE (through subsidiary Peedamullah Petroleum P/L)
will acquire 60% of VIC/P 67 from WHL Energy by paying 75% of the
cost of an 811 sq km 3D seismic survey over La Bella and surrounding
exploration targets (up to a cap of US$9 million). Following the review
of the seismic data, AWE can surrender its interest or commit to
drilling two exploration wells at either 50% or 60% working interest.
AWE will assume operatorship if they elect to enter the drilling phase.
The transfer of interest is subject to normal regulatory approvals.
Onshore in the Otway Basin, PEP 150 was granted on 26/08/2013.
The licence will expire on 25/08/2018. Work program is as follows -
50 km 2D seismic, PSDM studies
Year 2: 1 well
Year 3: G&G studies
Year 4: 50 km 2D seismic
Year 5: 1 well
Also in the Otway Basin, Bridgeport (Eromanga) P/L now operates PEP
151 following the resignation of Somerton Energy (Cooper Energy) as
In the Otway Basin, PEP 171 was granted on 26/08/2013. The
licence will expire on 25/08/2018.
In the Gippsland Basin, Beach Energy and Somerton Energy have withdrawn
from PRL 2 and interests have been re-assigned to Petro Tech
(Lakes). Potential farminee Armour Energy has a period of 6 months to
match any other farm-in proposal from a third party or to match the
previous agreement with Beach and Somerton.
In the Canning Basin, gazettal L 12-16 is under application as
STP-EPA-94 by Goshawk Oil & Gas P/L.
In the Carnarvon Basin, WA-214-P was renewed over a reduced area
of 322 sq km. The licence will expire on 03/09/2018. Work program is as
1 well $10m
Year 2: rock physics, 3D inversion & QI Study $0.25m
Year 3: geotechnical studies $0.25m
Year 4: geotechnical studies $0.15m
Year 5: geotechnical studies $0.15m
In the Browse Basin, the expiry date for the Argus location WA-274-P
LA has been extended to 24/10/2015.
In the Browse Basin, ConocoPhillips (Browse Basin) P/L has completed the
farm-out agreement with PetroChina and transferred 20% interest in
WA-315-P and WA-398-P to PetroChina.
In the Browse Basin, the year 5 work program for WA-344-P is now
- geotechnical & engineering studies - $0.15m.
In the Carnarvon Basin, the expiry date for the Achilles/Satyr Location
WA-374-P LA has been extended to 03/11/2015.
In the Carnarvon Basin, the year 6 work program for WA-390-P has
been extended by 12 months from 05/08/2013 to 05/08/2014. The licence
has had its expiry date extended to 05/08/2014.
In the Bonaparte Basin, the year 6 work program for WA-402-P has
been extended by 6 months from 11/07/2013 to 11/01/2014. The licence has
had its expiry date extended to 11/01/2014.
In the Canning Basin, WA-415-P, WA-416-P and WA-417-P
were surrendered on 16/08/2013.
In the Carnarvon Basin, the year 5 and 6 work programs for WA-434-P
are now -
Year 5 - geotechnical studies $0.57m
Year 6 - 1 exploration well $22.86m
In the Perth Basin, Murphy Australia Oil P/L has transferred their
interest in WA-481-P to Murphy Australia WA-481-P Oil P/L and
KUFPEC Australia P/L has transferred their interest to KUFPEC (Perth)
In the Carnarvon Basin, Apache Northwest has transferred their interest
in WA-35-L to Apache PVG P/L.
In the Carnarvon Basin, WA-36-R has been renewed to 14/08/2018.
Work program is as follows -
studies, analysis of Macedon oil reservoirs $16.8m
Year 2: geotechnical & geophysical studies, FEED $0.5m
Year 3: FEED, gas sales agreement, field development plan $0.5m
Year 4: apply for production licence, FID $0.2m
Year 5: development wells, studies $0.1m
In the Carnarvon Basin, Black Fire Minerals has sold its 10% interest
and Australian Oil Company has sold its 17% interest in EP 435
and L 16 to Rough Range Oil.
In the Carnarvon Basin, Green Rock Energy has pulled out of a deal with
Palatine Energy to acquire a 50% interest in SPA 9 AO. Palatine
will now receive 30 million Green Rock shares in return for being
allowed to pull out of its work program commitment.
In the Canning Basin, SPA 2 AO is under application as
In the Scadden Embayment, GEP 37 and GEP 38 are being
In the West Coast Basin, PEP 38517 expired 12/08/2013.
In the Taranaki Basin, PEP 38614 expired 17/08/2013.
In the Taranaki Basin, PEP 51152 and PEP 51154 are being
In the Taranaki Basin, Kea has elected not to renew PEP 51155.
The licence will expire on 22/09/2013.
In the Taranaki Basin, New Zealand Energy Corp and Origin Energy have
agreed to extend meeting the financing condition precedent for the NZEC
acquisition of PML 38138, PML 38140 and PML 38141
from 14/08/2013 to 30/09/2013 and the government approval condition from
13/09/2013 to 14/10/2013. In consideration for the extension, NZEC will
increase the non-refundable deposit to be applied to the purchase price
from CDN$5 million to CDN$6 million.
Papua New Guinea
LNG Energy Ltd has acquired Enterprise Energy Resources Ltd. Enterprise
Energy’s 50% subsidiary EERL (BVI) Holdings Ltd holds 31.5% of Telemu No
18 Ltd, with the remaining 68.5% of Telemu being held directly by LNG
Energy Ltd. Following this transaction, LNG Energy Ltd holds net
interests of 16.85% in PPL 319 and 84.25% in PPL 320,
PPL 321 and PPL 322.
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