The July 2011 data update is now available ...
2012 Industry Area Nominations
Industry stakeholders are invited to nominate vacant offshore areas to be considered for release in 2012 ...
Santos is pleased to announce that it has reached binding agreements to give effect to the acquisition of 100% of the outstanding ordinary shares in Eastern Star Gas Ltd ...
Permit Updates and Changes
In the Gloucester Basin, PSPAPP 53 was withdrawn at the request of Pangaea Oil & Gas ...
2011 data update is now available.
The following change was made to the GPinfo data structure in June -
Layer Wells (table PDWells)
New fields -
Basin at Surface - basin that is at the surface
Basin Lower - basin that is below the basin at the surface
Basin Lowest - basin that is below both of the above basins
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2012 Industry Area Nominations
Industry stakeholders are invited to nominate vacant offshore areas to be considered for release in 2012. The sustainable annual release of quality petroleum exploration acreage, to provide the global petroleum exploration industry with a variety of investment opportunities in Australian waters, is a key objective of the Australian Government. Noting the Australian Government’s objective of a sustainable, annual petroleum exploration acreage release offering quality exploration investment opportunities it is possible that not all nominated areas will be included in the 2012 Acreage Release. For further details on the nomination process, please visit -
(Source: Australian Petroleum News, Department of Resources Energy and Tourism, July 2011).
Summary of Areas Available for Bidding
Release/Round Areas Bid Closing Date
2010 Acreage re-release W 10-7, W10-21, W10-22 13/10/2011
2011 Acreage Release AC 11-1 & AC 11-2 13/10/2011
First Round W 11-1, W 11-10 to W11-15
V 11-1 to V 11-6 & T 11-1
2011 Acreage Release NT 11-1 and NT 11-2 12/04/2012
Second Round W 11-2 to W 11-9
W 11-16 to W 11-18
(Source: Australian Petroleum News, Department of Resources Energy and Tourism, July 2011).
Pursuant to these transactions, Santos will assume operatorship and own 80% of ESG’s coal seam gas permits with TRUenergy owning the remaining 20%. The acquisition of Eastern Star Gas will be conducted via a recommended scheme of arrangement under which ESG shareholders will receive 0.06803 Santos shares for every 1 ESG share held. (Source: Santos Ltd, 18/07/2011).
Consistent with ConocoPhillips’ previously stated strategies and focus on value creation for its shareholders, ConocoPhillips’ board of directors has approved pursuing the separation of the company’s Refining & Marketing and Exploration & Production businesses into two stand-alone, publicly trade corporations via a tax-free spin-off of the refining and marketing business to ConocoPhillips shareholders. The separation of the companies is expected to be completed in the first half of 2012. (Source: ConocoPhillips announcement, 14/07/2011).
APA Group says a long-term gas transportation agreement with Power and Water Corp underpins the $63 million purchase of the Amadeus gas pipeline in the Northern Territory. The 1,630km pipeline was commissioned in 1986 and transports gas to Darwin, Katherine and other locations to fuel power generation in the territory. Since 1986, the Amadeus Gas Trust has leased the pipeline from a consortium of financial institutions and NT Gas as trustee for the Amadeus Gas Trust has managed and operated the pipeline. APA holds a 96% stake in the NT Gas and the Amadeus Gas Trust. APA said the acquisition of the pipeline was supported by the long-term contract with the NT government-owned electricity provider, and complements its interest in the Bonaparte and Wickham Point pipelines. (Source: Energy News Premium, 17/06/2011).
Sentry Petroleum has signed memorandum of understanding with Ergon Energy that could potentially lead to the sale of gas from its Queensland coal seam gas tenements. Under the the non-binding MoU, the two companies have agreed to enter negotiations for the purchase and sale of potential gas for use in Ergon’s Barcaldine power generation station. The power station is immediately north of Sentry’s permits ATP 862P and ATP 865P, where the company has kicked off a CSG drilling campaign. (Source: Energy New Premium, 17/06/2011).
Metgasco has signed a memorandum of understanding with Richmond Dairies in Casino, NSW, to supply it with gas, the first such supply deal for the company. The company expects a final sales agreement to be signed by the end of this year with first sales to the Richmond Dairies plant starting in the third quarter of 2012. (Source: Energy News Premium, 17/06/2011).
Metgasco advises that coal seam gas drilling and testing results from PEL 13 have been assessed by independent reserve certifiers, MHA Petroleum Consultants (Denver), resulting in a significant increase in Metgasco’s overall gas reserves. PEL 13 reserves have been certified as 31.2 petajoules proved and probable, 302.4 petajoules of proved, probable and possible and 1334.1 petajoules of 2C continent resource. (Source: Metgasco announcement, 14/07/2011).
Following final compilation and submission of the dataset developed from the 2010 drilling campaign in the Galilee Basin to Netherland, Sewell and Associates, the independent Dallas-based resource assessment specialist has assessed that the wells drilled to date by Blue Energy in ATP 813P have delineated 554 petajoules of 3C contingent resource (recoverable) together with a further 1,142 petajoules of prospective resource (recoverable). The contingent resources have been identified principally around the existing five wells drilled by Blue Energy, whilst the prospective source relates to some of the inter-well areas, but does not include the majority of the permit area. This resource assessment relates to approximately 25% of the ATP 813P permit area. (Source: Blue Energy announcement, 29/06/2011).
As a direct result of a data sharing agreement between Blue Energy, Netherland, Sewell and Associates and several other coal seam gas operators in Queensland, NSAI has revised its assessment of the Sapphire Block in ATP 814P. Based on adjacent well and production data from the data sharing arrangement, together with Blue Energy’s Sapphire 1, 2 and 3 coreholes, NSAI has identified 39 petajoules of proved, probable and possible reserves within the Fort Cooper and Rangal Coal Measures in the Sapphire Block. The recent assessment of reserves in the Sapphire Block is comprised of Possible reserves only. (Source: Blue Energy announcement, 21/07/2011).
Arrow Energy has secured full ownership of the coal seam gas-fired Braemar-2 power station near Dalby after buying ERM Power’s 25.1% stake. The equal joint venture between Shell and PetroChina has been producing domestic gas for almost a decade and currently provides about 20% of Queensland’s gas supply. (Source: Energy News Premium, 04/07/2011).
Galilee Energy Ltd today announced that the operator of the Galilee Gas Project has completed the project’s first coal seam gas resource estimation. The Contingent Resource estimation of 259 petajoules of 2C and 1,090 petajoules of 3C resources covers 450 sq km of ATP 529P held in 50/50 joint venture with the operator, AGL Energy Ltd. (Source: Galilee Energy announcement, 30/06/2011).
Bow Energy Ltd has obtained further proved and probable certified reserves in the Blackwater CSG field (ATP 1025P) increasing Bow’s total certified reserves to 238 petajoules of proved and probable and 2,752 petajoules of proved, probable and possible reserves. Based on the data from pilot production wells adjacent to Bow’s Blackwater CSG field, along with Bow’s previous core hole data, MHA Petroleum Consultants Inc have certified within the Rangal coal measures of Bow’s Blackwater field (ATP 1025P) a further 89 petajoules of proved and probable and 13 petajoules of proved, probable and possible. (Source: Bow Energy Announcement, 19/07/2011).
Advent Energy could be sitting on a 18.4 BCF gas resource in the Weaber gas field in RL 1, Western Australia, according to an independent assessment carried out by Resource Investment Strategy Consultants. As part of its plan to commercialise its gas assets in the Bonaparte Basin, Advent handed over all available well data and seismic to RISC, which calculated a 2C (best case) continent resource of 11.5 BCF. The 18.4 BCF figure is the audited mean resource based on the data supplied to RISC. (Source: Energy News Premium, 24/06/2011).
Fluor Corp has landed a major three-year contract with Woodside Petroleum to provide engineering, procurement and construction services. Under the contract, which includes the option of three one-year extensions, Fluor will carry out capital projects for all activities that may be undertaken through project lifecycles for Woodside’s production projects group. (Source: Energy News Premium, 29/06/2011).
ConocoPhillips and Origin Energy have provided further confidence with a final investment decision on the Australia Pacific liquefied natural gas project will be made soon with the award of a $US45 million ($A42 million) pipe coating contract. Malaysia’s Wah Seong Corp secured the contract to provide coating for more than 700k of pipes. The APLNG joint venture plans to make a final investment decision on the project mid-year. (Source: Energy News Premium, 05/07/2011).
Germany-based consultant GL Noble Denton has secured a contract to provide verification services for BG Group’s Queensland Curtis liquefied natural gas project. Under the two-year contract, GL Noble will inspect the installation of the 540k underground pipeline between fields in the Surat Basin to the QCLNG plant on Curtis Island, near Gladstone. (Source: Energy News Premium, 13/07/2011).
Inpex’s Ichthys liquefied natural gas project has been given the green light by Federal Environment Minister Tony Burke, removing one of the last hurdles for the project. Burke said the approval for the 8.4 million tonne per annum plant, which includes strict environmental conditions, was made after a thorough assessment, including expert advice and consideration of public submissions. Inpex must develop a greenhouse gas management strategy outlining the measures and offsets it proposes to reduce greenhouse gas emissions before production can commence. It must also put in place measures to minimise waste and noise impacts, including noise generated from pile driving and blasting. There will be conditions imposed on the dredging and spoil disposal to ensure it is managed to world’s best practice to protect marine life, including dolphins, dugongs and turtles. With the help form an expert panel, the company must develop and implement a rigorous management plan including measures to prevent, detect and respond to impacts on marine life and to allow dredging methods and mitigation measures to be changed to adapt to new information. Inpex will be required to permanently protect and manage around 20,000 hectares of vegetation as well as marine habitat for inshore dolphins, marine turtles and dugongs. Ichthys is planned to deliver 8.4 million tonnes per annum of LNG and 1.6 million tonnes of liquefied petroleum gas per year as well as 100,000 bbls of condensate per day at peak. First gas is expected in 2016. (Source: Energy News Premium, 28/06/2011).
PTTEP Australasia has joined the race to develop the world’s first floating liquefied natural gas facility, confirming it is planning a FLNG project in the Timor Sea that could beat Shell’s Prelude project to production. In documents submitted to the Federal Department of Environment, PTTEP said it proposed to develop a FLNG facility that would produce gas from the Cash-Maple field in AC/RL 7, the southern group of fields in AC/L7 including the Montara field, and the Oliver field in AC/P33. Front-end engineering and design work is expected to start in the fourth quarter and a final investment decision on the 2 million tonne per annum project is target for the fourth quarter of next year. Following FID, the vessel is expected to be ready for start-up in late 2016. (Source: Energy News Premium, 06/07/2011).
Following its submission last week for environmental approval to develop a floating liquefied natural gas project in the Timor Sea, PTTEP Australasia has teamed up with SBM Offshore and Linde Group. The three companies have signed a partnership agreement for the project, which would produce gas from the Cash-Maple field in AC/RL 7, the southern group of fields in AC/L 7 including the Montara field and the Oliver field in AC/P33. Netherlands-based SBM Offshore will contribute its mooring system technology, marine expertise and be involved in the gas processing on the FLNG topsides. Germany’s Linde Group will build the topside of the floating, production, storage and offloading units, based on its natural gas liquefaction technology. A final investment decision is expected towards the end of 2012 with production target to start up in late 2016. (Source: Energy News Premium, 11/07/2011).
The Federal Government has expressed confidence in Shell’s Prelude floating liquefied natural gas project with the grant of major project facilitation. Shell made a final investment decision on the project, which would take gas from the Prelude and Concerto fields in WA-371-P permit in May. Prelude will be capable of producing 3.6 million tonnes of LNG per annum, 1.3 million tonnes of condensate per annum and 400,000 tonnes of LPG per annum. (Source: Energy News Premium, 11/07/2011).
FMC Technologies is the latest company to win a contract with Shell following its final investment decision on the Prelude floating liquefied natural gas project to supply subsea production and associated topside systems. The companies also announced an aftermarket agreement whereby FMC Technologies Australia will perform installation and commissioning services for the project. (Source: Energy News Premium, 29/06/2011).
Air Products has become the latest supplier to win a contract for Shell’s floating liquefied natural gas facility, with the company to supply its proprietary coil wound LNG heat exchanger. (Source: Energy News Premium, 01/07/2011).
Western Australia industry had a big win with Chevron awarding the largest local contract, valued at US$2.3 billion (A$2.1 billion) for its Gorgon liquefied natural gas project. The Australian operating unit of Kentz and CBI & I secured the mechanical, electrical and instrumentation contract that is expected to create more than 1,500 jobs over four years at Barrow Island and another 150 at the Australian Marine Complex at Henderson, south of Perth. The joint venture will provide the structural, mechanical pipping, electrical, instrumentation and commissioning support for the construction of three LNG trains, including associated utilities and a domestic gas processing and compression giant. (Source: Energy News Premium, 15/07/2011).
AGC Industries has won a second Gorgon contract, this time tying up a $12 million deal to fabricate and supply the adjustable pipe support structures for the massive project. The contract scope includes the fabrication, supply, testing, inspection, storage and delivery of adjustable pipe support structures weighing more than 900 tonnes. (Source: Energy News Premium, 30/06/2011).
Subsea 7 has become the latest company to secure a contract for Chevron’s Gorgon project, winning the US$80 million (A$75.4 million) subsea umbilicals contract. The Norwegian seabed-to-surface engineering, construction and services provider will transport and install subsea umbilicals and structures from Barrow Island to the Gorgon and Jansz fields. (Source: Energy News Premium, 19/07/2011).
Woodside’s plans for the Browse liquefied natural gas project at James Price Point in Western Australia’s Kimberley region seem to be falling into place with a landmark native title agreement to be signed today. The native title agreement will be signed by the WA Government, Woodside and traditional owners, allowing Woodside to proceed with initial works. The agreement will include a $1.5 billion compensation package to be delivered over 30 years to the traditional owners and an initial commitment of 300 jobs for Aboriginal people during construction. The agreement also guarantees traditional owners are involved in “all phases of the gas precinct development and precinct management”. Source: Energy News Premium, 30/06/2011).
Woodside advises that it has revised the expected cost and schedule of the Pluto LNG Project following its regular review of the progress of the project. The first LNG cargo is now estimated for March 2012. The revised estimate is attributable to slower than expected progress on the commissioning of the onshore gas plant, seven weeks for direct weather delays and an allowance for an increased contingency. The revised estimate is expected to result in a A$900 million increase in cost to a total of A$14.9 billion. (Source: Oil Voice, 22/06/2011).
Apache Energy is pushing ahead with plans to make full use of the production capacity of the Ningaloo Vision floating production storage and offloading vessel through the development of the Coniston and Novara oil fields. The company lodged an application for environmental approval of the development on the North West Shelf as a tie-back to the existing Van Gogh oil project late last week. The Ningaloo Vision, which normally produces up to 40,000 bopd from Van Gogh, Apache’s first oil development with an FPSO, has a production capacity of up to 63,000 bopd. That leaves just slightly more than enough capacity for the Coniston and Novara development, which is expected to produce an average 22,000 bopd during its first year of production. Apache plans to develop the fields which span WA-35-L and WA-225-P by drilling six subsea production wells from the Coniston field and one subsea production well from the Novara field. Drilling is scheduled to start in March next year and continue for about nine months to December 2012. The development is expected to have a production life of around 20 years. (Source: Energy News Premium, 22/06/2011).
Empire Oil & Gas has moved a step closer to commercialising its Gingin West and Red Gully gas fields in the Perth Basin, with a gas sales agreement expected within the next three months. The company said it had signed a non-binding term sheet with Alcoa of Australia that provided a 90-day period to finalise a gas sales agreement for the supply of gas from the two fields in EP 389. The term sheet also includes a pre-payment for a portion of the gas sales, with the funds to be used to construction and commission the Red Gully gas and condensate plant, including condensate storage tanks and road tanker load out along with the construction of the flow line from the plant to existing natural gas pipeline infrastructure. The final design is dependent upon whether gas is transported in the Parmelia or Dampier to Bunbury National Gas pipelines, both 288km away. The condensate will be sold to BP for its Kwinana refinery. (Source: Energy News Premium, 17/06/2011).
Partners in the Cuisinier oil field in the Cooper Basin, Queensland, are poised to enjoy greater production. Bow Energy said both the Cuisinier 2 and Cuisinier 3 appraisal wells had produced oil during testing and would be placed on pump, with oil pumped to the Cuisinier 1 site. Cuisinier 1 itself has been producing more than 350 bopd since it started production in May 2010. (Source: Energy News Premium, 04/07/2011).
New South Wales
Papua New Guinea
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