Atwood Semisubs Win Apache Work in AU

- Atwood Semisubs Win Apache Work in AU

Thursday, September 01, 2011
Atwood Oceanics Inc.

Atwood Oceanics announced that one of its subsidiaries has been awarded two contracts by Apache Energy Ltd for work in Australia for the Atwood Eagle and the Atwood Falcon with durations of 18 months and 30 months, respectively. With these contracts, Atwood's total revenue backlog increases from approximately $990 million to $1.55 billion.

The Atwood Eagle is expected to commence its contract in July 2012 in direct continuation of its prior contract. The Atwood Falcon will undergo approximately 90 days of planned maintenance and contract preparation work prior to transiting to Australia to commence operations expected in May 2012. The firm contractual commitments for the Atwood Eagle and the Atwood Falcon are expected to extend to January 2014 and November 2014, respectively.

"We are very pleased to be providing deepwater drilling services to Apache with these two longer-term agreements," commented Rob Saltiel, Atwood President & CEO. "Atwood has been active in Australia for over 35 years, and we look forward to increasing our presence further in this growing and strategic market."

Oil & Gas Post

Promote Your Page Too
LINK

Senex to Divest Stakes in AU Cooper Basin

- Senex to Divest Stakes in AU Cooper Basin

Thursday, August 18, 2011
Senex Energy Ltd.

Senex announced the farm-out of southern Cooper Basin conventional oil exploration licenses to Ambassador Exploration Pty Limited (Ambassador).

Senex is farming out a 60% interest in PEL 516 Mudlalee Block, a 60 %interest in PEL 516 Rowley Block and a 50% interest in PEL 113 Zulu Block to Ambassador. Notwithstanding the farm-outs, Senex retains 100% of the rights to "unconventional hydrocarbon production" within the Zulu Block and to any petroleum recovered from the Mudlalee and Rowley Blocks from beneath the Poolowanna horizon. Senex will retain Operatorship of each of these licenses.

The Farm-out Agreements have been executed and are subject to specific Conditions Precedent which are in the process of being completed. Details of the farm-out terms follow:

South Australian Cooper Basin License PEL 113 Zulu Block

Ambassador to pay 100% of the drilling cost of one well within the license area and 100% of the cost of acquiring, processing and interpreting 100 square kilometers of 3D seismic over the license area subject to agreed cost limits. On completion of the program, Senex will retain a 50% interest and Ambassador will have earned a 50% interest in Zulu Block production other than unconventional hydrocarbon production from the shale and coal deposits in the Permian sequence. Senex retains the rights to 100% of any unconventional hydrocarbon production from the Permian sequence.

South Australian Cooper Basin License PEL 516 Mudlalee Block

Ambassador to pay 100% of the drilling cost of one well within the license area subject to an agreed cost limit. On completion of the program, Senex will retain a 40% interest and Ambassador will have earned a 60% interest in the Mudlalee Block other than production from deposits that extend beneath the Poolowanna horizon. Senex retains the rights to 100% of any petroleum recovered from deposits beneath the Poolowanna horizon, being the unconventional hydrocarbon zones.

South Australian Cooper Basin License PEL 516 Rowley Block

Ambassador to pay 100% of the drilling cost of one well within the license area subject to an agreed cost limit. On completion of the program, Senex will retain a 40% interest and Ambassador will have earned a 60% interest in the Rowley Block other than production from deposits that extend beneath the Poolowanna horizon. Senex retains the rights to 100% of any petroleum recovered from beneath the Poolowanna horizon, being the unconventional hydrocarbon zones.

Oil & Gas Post

Promote Your Page Too
LINK

CB&I Awarded Contract for AU Arrow LNG Proj.

- CB&I Awarded Contract for AU Arrow LNG Proj.

Tuesday, August 16, 2011
CB&I

CB&I has been awarded, through its joint venture with Chiyoda Corporation and Saipem S.p.A., the Preparation and Supply of the Project Specification contract for the Arrow LNG Plant Project in Australia.

Arrow Energy Pty Ltd., the project operator, is a 50/50 joint venture partnered by Royal Dutch Shell and PetroChina.

The project, which will be designed with a production capacity of 8 million tonnes per annum (4.0 MTPA x 2 trains), is planned to be constructed on Curtis Island, off the coast of Gladstone, on the east coast of Queensland, Australia. The project plans to expand its capacity up to 16 MTPA in the future. The LNG plant will be supplied with coal seam gas from the Surat and Bowen basins in Queensland and will process, treat and liquefy the gas for export.

"We are pleased to be selected for this significant project, which will help meet the world's demand for clean energy," said Philip K. Asherman, President and CEO. "This award builds on our proven worldwide LNG technical expertise and our 75-year history in Australia."

Oil & Gas Post

Promote Your Page Too
LINK

Sentry Updates Appraisal Work at AU Wells

- Sentry Updates Appraisal Work at AU Wells

Tuesday, August 09, 2011
Sentry Petroleum Ltd.

Sentry provided the following update on its drilling exploration and appraisal work on ATP 862 and ATP 864 in Queensland Australia.

Sentry Petroleum has now completed the drilling of two Coal Seam Gas wells on ATP 862. The wells, Talundilly_CSG1 and Albilbah_CSG1 reached depths of 1,430 feet and 1,555 feet, respectively. In Talundilly_CSG1, 833 feet of core were cut, out of which 51 feet of coal and carbonaceous rock were canistered for gas desorption in 21 samples. Gas desorption is still ongoing as gas was found in all the canistered core samples. The Company expects this process to be completed for the Talundilly_CSG1 during the coming week. The Company further advises that isotherms will be obtained on selected coal and shale samples.

In Albilbah_CSG1, 472 feet of core were cut, out of which 35 feet of gaseous coal and carbonaceous rock were sealed in 20 canisters for desorption measurement. In addition, the lower Winton Sandstones were found to contain free gas and 20 feet of these cores were also canistered and evolved gas is being measured. Once these measurements are completed during the coming weeks the cores will be sealed and sent to a laboratory for routine core analysis to measure porosity, permeability and residual fluid saturation. The wireline logs from the previously drilled Albilbah-1 also indicate the presence of gas in these sands over a 128 feet interval starting beneath the last coal.

The Company's coalbed gas content measurements are using the direct method which is the preferred method in coalbed methane and gas shale resource assessment. The direct method physically measures the volume of gas released over time from a core sample sealed into a desorption canister—termed the measured gas content. Adjustments are made to the measured gas content to account for gas lost prior to the core being placed in the desorption canister and for residual gas remaining in the core at the completion of the desorption period. The process of acquiring the measured gas content generally requires four to five weeks. Upon completion of the gas desorption results will be forwarded for independent certification.

Oil & Gas Post

Promote Your Page Too
LINK

UTEC Mobilizes MV Calypso Star Offshore AU

- UTEC Mobilizes MV Calypso Star Offshore AU

Friday, August 05, 2011
UTEC Survey Australia Pty Ltd.

UTEC Survey Australia has mobilized the 24-meter geophysical survey catamaran, MV Calypso Star, on a long term basis to support geophysical survey operations in North and North West Australia.

The vessel is currently performing survey operations to Oil & Gas clients in the Timor Sea with expected completion in late August 2011 in Exmouth.

The Calypso Star is equipped with an array of geophysical survey equipment, including a high resolution R2Sonics multibeam echo sounder coupled with a DMS3-05 motion sensor, Edgetech 4200 Digital Side scan sonar, reflection seismic and onboard processing capabilities.

Oil & Gas Post

Promote Your Page Too
LINK

Beach Makes Oil Discovery at AU Western Flank

- Beach Makes Oil Discovery at AU Western Flank

Monday, August 01, 2011
Beach Energy Ltd.

Beach Energy announced two new field oil discoveries at Bauer-1, the third successful well in a five well exploration drilling campaign in PEL 91, and at Rincon-1, the final exploration well of the initial eleven well program for PEL 92. The commencement of the FY12 Joint Venture approved nine well exploration and development program, set down for PEL 92, will now follow this program.

The Bauer-1 well (Beach (Operator) - 40%, Drillsearch Energy Ltd - 60%) encountered a gross oil column of fifteen meters, with thirteen meters of net pay, in the McKinlay/Namur Sandstone section of the well. Preliminary volumetric assessment indicates the potential of the discovery could be in the order of two million barrels of recoverable oil (gross).

Following the completion of the evaluation program, the Ensign#18 rig will be moved to the Searcy-1 exploration well which is located approximately eight and a half kilometers to the north-east of Bauer-1. Bauer-1 is expected to be on-line in the fourth quarter of 2011.

The Rincon-1 well (Beach (Operator) - 75%, Cooper Energy Ltd - 25%) encountered a gross oil column of five meters, with four and a half meters of net pay, in the McKinlay/Namur Sandstone section of the well. Beach’s preliminary volumetric assessment suggests up to five hundred thousand barrels of recoverable oil (gross).

Following the completion of the evaluation program, the Ensign#30 rig will be moved to the Elliston-1 exploration well which is located approximately 25 kilometers to the south of Rincon-1. Options to bring Rincon-1 on-line are currently being assessed.

Oil & Gas Post

Promote Your Page Too
LINK

T.D. Williamson Sets Up Shop in Western AU

- T.D. Williamson Sets Up Shop in Western AU

Wednesday, July 20, 2011
T.D. Williamson Inc.

T.D. Williamson has opened a new office in Perth, Western Australia, in a strategic move to offer customers its full range of products and services. Located on St. George's Terrace in the heart of downtown Perth, it serves as the administrative and engineering services center for all offshore operations currently being conducted in Western Australia and Victoria, and for supporting future operations in Papua New Guinea and New Zealand.

Operations carried out offshore, particularly on the gas-rich province of the North West Shelf, are managed from the new Perth office. To ensure that customers receive superior service, TDW draws personnel and equipment support from TDW's operational facilities in Melbourne, Singapore and Norway. By establishing a dedicated team of engineering and technical specialists in Perth, TDW offers enhanced service and prompt, professional customer service.

Gearing up in Western Australia

Since 2004, TDW has been active in the Western Australia market, completing numerous SmartPlug® pipeline pressure isolation operations offshore on the North West Shelf and in the Bass Strait in southeast Australia. Recently, the company completed a successful pipeline pressure isolation operation to facilitate a valve change-out at a metering station where gas is exported to the domestic consumer market. TDW has also been retained to carry out several high level engineering studies for future pipeline isolations and to provide Emergency Pipeline Repair Systems (EPRS) for new major gas pipeline networks. Engineering studies are often completed several months - or years - before the actual offshore execution. Customers will benefit from the fact that engineers are based locally and readily accessible to meet to discuss solutions.

"With the number of new field developments in the Australian market, we are aware that the demand for SmartPlug pressure isolation services and other services we offer will continue to rise, and that we must be prepared to meet that demand," said Tony Hawkins, Country Manager – Australia for TDW." Our pipeline pressure isolation services are ideally suited to help pipeline operators maintain existing pipeline networks, and to service developments that are currently under construction and following completion. With the combined efforts of our permanent teams in Perth, Melbourne and New Zealand, supported by the offshore team in Norway, we are fully prepared to meet the offshore pipeline pressure isolation needs of operators throughout the region," he added.

Expanding network in Asia Pacific

The new Perth office is the latest addition to TDW's network of facilities in the Asia Pacific region. Last fall TDW opened a 7,500-square-meter Engineering and Manufacturing Center in Savli near Vadodara, India. The new center was established to support India’s pipeline network, which is expected to double during the next three or four years as gas finds and the expansion of the energy market drive infrastructure growth.

Oil & Gas Post

Promote Your Page Too
LINK

Beach Begins Gas Flow at AU's First Shale Well

- Beach Begins Gas Flow at AU's First Shale Well

Tuesday, July 12, 2011
Beach Energy Ltd.

A significant gas flow of up to 2 million standard cubic feet per day (MMscf/d) has been achieved from Beach's Holdfast-1 exploratory shale gas well in the Cooper Basin. Holdfast-1, the first well drilled to examine the shale gas potential of the thick Roseneath-Epsilon-Murteree shale sequence in the Cooper Basin, is a vertical data gathering well that was recently flow stimulated in seven stages.

Hot water, steam and low levels of gas started to flow from the well on 1 July upon the commencement of post-stimulation clean-up activities. Late on Friday 8 July the flow was diverted through on-site separation equipment to more reliably measure the gas and stimulation fluid rates. With separation of the gas from the returning stimulation fluid the gas flare was successfully ignited. The gas flow rates, now measured, have remained steady at around 1.8 MMscf/d.

Beach regards the flow rates as significant, given the potential for higher flow rates from future horizontal wells. Follow up wells are planned to be drilled to target the optimal producing zone identified by the extensive coring, stimulation and testing program which has been undertaken by Beach in the Nappamerri Trough.

Beach Managing Director, Reg Nelson, said, "We are delighted and excited by this initial flow rate from Holdfast-1. So far the results give us confidence that these shale target zones, which underlie the conventional oil and gas bearing formations in the Cooper Basin, will significantly increase the natural gas potential of this area. It is still early days but this flow rate looks to be very significant."

Mr. Nelson added, "While these results are preliminary at this stage, it does suggest that significantly larger flow rates may be achievable in an optimally designed, pilot horizontal well. Holdfast-1 was deliberately designed to allow us to experiment with different stimulation techniques and to test different zones within a thick sequence of shales and other lithologies to determine which approach could be applied for the best results when designing a pilot production well."

Beach previously reported the flow stimulation of the Holdfast-1 well had been completed successfully with the various selected target zones fracturing vertically, in line with expectations. The vertical nature of the induced fracturing augurs well for future horizontal production wells.

A variety of well perforation techniques, fluid viscosity and proppant sizes was used in the stimulation of Holdfast-1 to provide a range of information on the response and performance of the different shale and tight rock zones intersected in the Permian aged section of the well. This approach is intended to identify which techniques are best suited to the pilot production program set down for 2012. This program will consist of two horizontal wells, one at each location.

The flow stimulation of Holdfast-1 was undertaken in seven stages, targeting the primary target zones of the Roseneath Shale (two stages), the Epsilon Formation (three stages) and the Murteree Shale (one stage), as well as a deeper secondary zone, the Patchawarra Formation (one stage).

Mr. Nelson said, "While we are greatly excited by the results from the Holdfast-1 well to date, we are not surprised by them. Beach has applied an extremely thorough and detailed technical approach over the past few years to its shale gas research, which identified the Cooper Basin, and more particularly the Nappamerri Trough, as one of the most prospective shale gas provinces in Australia. Beach has been a pioneer of shale gas exploration in Australia and is now best placed to lead the development of the shale gas industry through its accumulated expertise, its acknowledged competence as an operator and the fact that the Cooper Basin has well established infrastructure in place to assist in commercialization of this opportunity."

Participants in PEL 218 (Permian JV) are:

• Beach (Operator) 90%
• Adelaide Energy Ltd 10%

The Cooper Basin is the most prolific onshore petroleum province in Australia, having produced approximately 6 Tcf of gas to date, and is ideally situated as it has the necessary infrastructure for the delivery of oil and gas to the Eastern Australian markets. Within the Cooper Basin, Beach currently holds interests of approximately 20% of the SACB JV (Santos operated), this includes infrastructure such as the Moomba production facility, approximately 23% of the SWQ JV (Santos operated) as well as various oil interests of between 40-75% on the Western Flank of the Cooper Basin.

Oil & Gas Post

Promote Your Page Too
LINK

Kea Disappointed by AU Drilling Results

- Kea Disappointed by AU Drilling Results

Monday, July 11, 2011
Kea Petroleum plc

Kea Petroleum expects to terminate the initial flow test program on Wingrove-2 in the coming week.

Several intervals of thin sands within the Upper Miocene Urenui Formation at depths of 1100 to 1300 m were simultaneously tested, and flowed oil and gas at low rates, together with considerable amounts of water It is considered that economically viable oil flow rates will not be achieved in this well.

The Mount Messenger Sands, typically several hundred meters deeper than the Urenui Sands, were not flow tested, as earlier log analysis had indicated they are water bearing in Wingrove-2. However, these remain as prime exploration targets in this area, as they are typically thicker and better reservoir quality. They will be the target of further drilling later this year.

Surat Basin, Australia

The Hoadleys-1 exploration well has been terminated at a depth of 2149m, after intersecting the target Precipice Sands, which were water bearing with no oil shows. The well is now being cased and suspended, in order that consideration can be given to drilling the deeper South Cabawin target with a heavier duty rig at a future date. A rig is presently being assessed for the drilling of Nangwarry-1 in the Otway Basin in South Australia, and may be suitable for South Cabawin also.

South Cabawin is defined on 3D seismic as a similar structure to the Cabawin Field, 20 km north along trend where the discovery well averaged 120 barrels of oil and one million cubic feet of gas per day in a 22 day flow test. The present rig is not considered capable of drilling to beyond 3000m to test the Permian coal measures in which the Cabawin discovery was made. Another rig is presently being assessed for this drilling operation.

David Bennet, Chief Executive, said, "It is disappointing that the secondary target Urenui Sands in Wingrove-2 have not produced oil at economically viable rates in this test. The primary target of Mt Messenger sands are proving to be very commercial oil producers elsewhere in this same basin; and our forward drilling program will be targeting Mt Messenger sands on our other prospects.

"Hoadleys was a relatively inexpensive exploration well with all the incumbent risks associated therein. The deeper South Cabawin target remains an attractive target yet to be drilled."

Oil & Gas Post

Promote Your Page Too
LINK

Inpex Gets AU Govt OK for Ichthys Project

- Inpex Gets AU Govt OK for Ichthys Project

Tuesday, June 28, 2011
Inpex Corp.

The Australian Government's decision to grant environmental approval to the Ichthys Project is a welcome step forward and helps pave the way for a final investment decision in the fourth quarter of 2011.

INPEX President Director Australia Seiya Ito said Federal environmental approval represents a significant milestone for the project following a rigorous three year assessment process, comprehensive environmental studies and extensive engagement with the community and other stakeholders.

"We are committed to developing and operating the Ichthys Project in an environmentally and socially responsible manner and will continue to work closely with the government and community as we progress the project," Mr. Ito said.

The decision today by the Minister for Sustainability, Environment, Water, Population and Communities, the Hon. Tony Burke, follows the Northern Territory Government's announcement in May that the environmental impacts of the planned Ichthys development in Darwin can be managed within acceptable limits.

"I would like to acknowledge both the Australian and Northern Territory governments for their thorough environmental assessment process," Mr. Ito said. "The input we received from government and the community during the process resulted in improved outcomes for all stakeholders."

The proposed Ichthys Project includes a subsea production system, semi-submersible central processing facility, a floating production, storage and offtake vessel located at the Ichthys Field in the Browse Basin, approximately 200 kilometers off the northwest coast of Western Australia, and onshore gas processing facilities at Blaydin Point, Darwin, Northern Territory. An 885km subsea gas pipeline will link the offshore and onshore facilities.

Oil & Gas Post

Promote Your Page Too

Fluor Bags EPCM Services Contract for Woodside's AU Gas Assets

- Fluor Bags EPCM Services Contract for Woodside's AU Gas Assets

Tuesday, June 28, 2011
Fluor Corp.

Fluor has finalized a major services agreement with Woodside Energy Limited to provide engineering, procurement and construction management (EPCM) services for Woodside's operating assets. Fluor's initial contract term is for three years, with the option of three one-year extensions available. The undisclosed value will be booked in the second quarter of 2011.

The contract allows Fluor to perform sustaining capital projects for Woodside's Production Projects Group. The EPCM scope of services includes all activities that may be undertaken throughout the project life cycle. The engineering services will be performed in Fluor's Perth, Australia, office with implementation and construction related work at the respective Woodside asset.

"Fluor looks forward to delivering engineering and support services to the rapidly growing liquefied natural gas industry," said Kirk Grimes, president of Fluor's Global Services Group. "This opportunity allows us to expand our range of services to Woodside, for whom we are currently providing engineering and design services at the Browse Basin off the coast of Australia."

"This is the culmination of a relationship-building process our account team began with Woodside two years ago," said Bill Wasilewski, vice president of Fluor's Global Services Group. "The agreement enables us to leverage the expertise of Fluor's oil and gas business with our ongoing operations and maintenance services expertise."

Through its Fluor Offshore Solutions unit, Fluor is currently providing front-end engineering and design (FEED) to Woodside for the Browse LNG Development, which is located about 425 kilometers north of Broome off the northwest coast of Australia.

Oil & Gas Post

Promote Your Page Too

Clough Wins Construction Work at AU Macedon Proj.

- Clough Wins Construction Work at AU Macedon Proj.

Friday, June 24, 2011
Clough Ltd.

Clough announced the award of a circa A$45 million contract to the STREICHER-Clough Joint Venture (SCJV) for pipeline construction work on the Macedon Project.

SCJV is a 50/50% joint venture between Clough and Germany's pipeline engineering and construction specialists, STREICHER Group.

The scope of work includes horizontal directional drilling, construction of an onshore wet gas pipeline and sales gas pipeline and umbilical installation. Work is due to commence in June 2011 with completion anticipated in May 2012.

"We are delighted to be working on this important Western Australian project," said Clough's CEO John Smith.

"We will utilize resources and expertise from our Clough Seam Gas division and partner STREICHER to deliver the best possible project outcomes."

Oil & Gas Post

Promote Your Page Too

AGR Awarded Subsea Inspection Contract Offshore AU

- AGR Awarded Subsea Inspection Contract Offshore AU

Thursday, June 23, 2011
GR Group ASA

AGR Field Operations has been awarded a major contract to perform a subsea inspection of offshore facilities in the Bass Strait of Australia. This significant scope of work involves an ROV based general visual inspection and a cathodic protection survey as well as installation work.

The facilities to be inspected include two offshore platforms and their associated pipelines.

AGR Field Operations will be providing Project Management, HSEQ interfaces, Inspection engineers and coordination of the sub-contractors including vessels, ROV and positioning services.

The final report will become part of an inspection database being commissioned by AGR Field Operations which will integrate legacy inspection data, reports and drawings for the assets.

Oil & Gas Post

Promote Your Page Too

Chevron Strengthens Portfolio Offshore AU with Arrival of Semisub Osprey

- Chevron Strengthens Portfolio Offshore AU with Arrival of Semisub Osprey

Friday, June 03, 2011
Chevron Corp.

The Atwood Osprey, Chevron's newly contracted ultra-deepwater semisubmersible drilling rig, has arrived in the waters off northwest Australia. Constructed in the Jurong Shipyard in Singapore, the rig will commence operations drilling and complete a queue of development wells as part of the Gorgon Project. The development drilling program scheduled for 2011 and 2012 represents the most significant investments Chevron has made in development drilling offshore Western Australia.

Chevron Australia managing director Roy Krzywosinski said Western Australia is pivotal to the company's strategy of building an internationally competitive gas business in the Asia-Pacific region. He said the company expects the Atwood Osprey to play a key role in strengthening Chevron's growing exploration, appraisal and development portfolio for at least the next three years.

"Chevron continues to make significant investments in developing Australia's natural gas resources," Krzywosinski said. "The arrival of this newly contracted rig represents our ongoing long-term commitment to grow our natural gas business in Western Australia."
Safety First

To ensure a safe startup and a strong safety culture is in place, the Australasia business unit's (ABU) drilling and completions team held three engagements with the Atwood Osprey crew to ensure Atwood's safety management system and those of our business partners were fully aligned with Chevron's expectations for operational excellence.

ABU Drilling and Completions manager Kent Springer said that through these engagements he was confident that Atwood Oceanics and its crew would achieve their vision statement of "always exceeding your expectations" and continue their commitment to safety, personal health, environmental stewardship, efficiency and reliability.

"Both Chevron and Atwood have systems in place to make the rigs as safe as possible. However, these systems are ineffective without the commitment of all our personnel, both rig- and office-based, adhering to them," Springer said. "Therefore, having members of the ABU management team—including Roy Krzywosinski—come along and tell the crew that they have their personal backing to use stop-work authority if they see an unsafe risk or behavior is a powerful message."

The Atwood Osprey can accommodate as many as 200 people, is 426 feet (130 m) tall and 377 feet (115 m) long. When moored, it will be capable of drilling as far as 31,988 feet (9,753 m). With its own mooring equipment, it can operate in water as deep as 5,905 feet (1,800 m), or 8,202 feet (2,500 m) with pre-laid mooring.

Oil & Gas Post

Promote Your Page Too

Apache Begins Gas Flow Offshore AU

- Apache Begins Gas Flow Offshore AU

Thursday, June 02, 2011
Apache Corp.

Apache said that a subsidiary's Halyard-1 discovery well has commenced producing gas and condensate for delivery into the Western Australian domestic market.

Production from the well, drilled in 2008 in production license WA-13-L, will be transported to market via an existing pipeline to the East Spar field facilities and from there to Apache's Varanus Island processing and transportation hub.

Development of the Spar field, located in adjacent License WA-4-R, is expected to follow in late 2012 as additional capacity becomes available at Varanus Island. The fields are both controlled from Apache's John Brookes platform. Apache's subsidiary owns a 55-percent interest in both WA-13-L and WA-4-R. Santos owns the remaining interests.

Oil & Gas Post

Promote Your Page Too

KBR Clinches Engineering Design Services Contract in AU

- KBR Clinches Engineering Design Services Contract in AU

Wednesday, June 01, 2011
KBR Inc.

KBR has been selected to execute engineering design services for three coal seam gas (CSG) pipelines designed to carry CSG from gasfields in central Queensland, Australia to an export facility on Curtis Island. The project will be executed for the McConnell Dowell/CCC joint venture (MCJV) on behalf of clients Queensland Curtis LNG (QCLNG) and Asia Pacific LNG (APLNG).

KBR will execute engineering design services including pipeline design, process, civil and structural, mechanical and electrical engineering and instrument controls for the three CSG pipelines. For QCLNG, KBR will design a pipeline from central Queensland to the coast that consists of more than 580 kilometers (360 miles) of pipelines, including: a 42-inch diameter coal seam gas (CSG) pipeline (approximately 374 kilometers/232 miles); a 42-inch diameter CSG collection header pipeline (approx 169 kilometers/105 miles); and six collection laterals of 12-24 inch diameter (5.4 kilometers/3.4 miles).

A second pipeline for QCLNG and a third pipeline for APLNG will both consist of a 42-inch diameter high pressure transmission pipeline from the main line valve on the Queensland mainland, across the Narrows to the Curtis Island delivery station. The shared design for the Narrows pipelines is the result of an agreement between QCLNG and APLNG to jointly contract to design build and deliver the two coastal pipelines.

"This contract award demonstrates KBR's commitment to be involved in delivering pipelines and associated infrastructure in the important and emerging coal seam gas industry," said Colin Elliott, President, KBR Infrastructure and Minerals. "The expertise we've developed in the gas pipeline sector in Australia to date will be integral to the successful execution for MCJV, QCLNG and APLNG and add to our capabilities in this rapidly growing market."

Oil & Gas Post

Promote Your Page Too

PetroFrontier Updates Ops in AU

- PetroFrontier Updates Ops in AU

Tuesday, May 17, 2011
PetroFrontier Corp.

PetroFrontier reported an update on its general operations in the Georgina Basin, Northern Territory, Australia.

2011 Drilling Update

The first two wells to be drilled by PetroFrontier will be horizontal wells ("Baldwin-2" and "MacIntyre-2") on EP 103 and EP 127 respectively in the South Georgina Basin in the Northern Territory. Both wells will be twins to existing wells ("Baldwin-1" and "MacIntyre-1"). The existing wells will be used as pilot holes for the horizontal leg into the Basal Arthur Creek shale zone. Baldwin-2 and MacIntyre-2 include conventional targets above the Basal Arthur Creek shale zone.

As a result of the significant flooding in the area, the creek crossing between the two drilling locations is impassable and is currently being upgraded by constructing a new road on a different alignment that has adequate drainage to permit the rig to access the MacIntyre-2 location even in the event of further moderate rain events. The rig is also undergoing additional modification to comply with Australian regulations and is expected to be mobilizing to the Georgina Basin near the end of May. The rig will travel over 3,000 kilometers from Brisbane in Queensland to the Baldwin-2 well site. PetroFrontier will provide a further update once rig mobilization has been confirmed.

2011 Seismic Program

PetroFrontier has planned approximately 1,800 kilometers of additional 2D seismic as a further delineation to the approximately 550 kilometers of 2D seismic PetroFrontier acquired during 4Q 2010. The mandatory sacred sites cultural clearance process is underway with the local Traditional Owners and is expected to be completed by mid June. Seismic land operations are expected to commence in late June following the completion of the cultural clearance process. The initial focus of the program is to refine prospects already identified in the greater Ross area. The balance of the program is regional seismic designed to identify possible targets in the other licensed areas.

Oil & Gas Post

Promote Your Page Too

Apache Plugs, Abandons Zola Well Offshore AU

Apache Plugs, Abandons Zola Well Offshore AU

Wednesday, April 20, 2011
Tap Oil Ltd.

Tap Oil provided the following update on the Zola-1 exploration well, offshore Carnarvon Basin, Western Australia.

The Zola-1/Zola-1 ST1 well is located in permit WA-290-P, immediately south of the giant Gorgon gas field in the Carnarvon Basin, Western Australia. The well is being drilled in 285m of water.

Data gathered to date in Zola-1 and Zola-1 ST1 has confirmed a significant gas discovery in the Mungaroo formation. The well results indicate that volumetrically the greater Zola structure could be at the upper end of Tap's pre drill estimates of 1 – 2 Tcf.

Progress

During the period from 06:00 hours WST on April 13, 2011 to 06:00 hours WST on April 20, 2011 the wireline logging program was completed and the well is currently being plugged and abandoned as planned.

Forward Plan

Complete the plugging and abandonment of the well as planned and release the rig.

Barring any unforeseen circumstances, this will be the last Zola-1 Well Drilling Update.

Background

The Zola prospect is a very large Triassic tilted fault block on trend with the giant Gorgon gas field and was one of the largest undrilled structural features in the Carnarvon Basin. The well is testing the gas potential of several top and intra Mungaroo formation sands – the primary reservoir at Gorgon.

Located close to existing and developing gas infrastructure, Zola could have multiple potential development options. Any development at Zola could also encompass the overlying Antiope gas discovery (estimated at ~120 Bcf).

WA-290-P Joint Venture Participants

• Tap (Shelfal) Pty Ltd 10.00%
• Apache Northwest Pty Ltd (Operator) 30.25%
• Santos Offshore Pty Ltd 24.75%
• OMV Australia Pty Ltd 20.00%
• Nippon Oil Exploration (Dampier) Pty Ltd 15.00%