Project updates—North West Shelf Joint Venture Partnership

2011 ◽  
Vol 51 (3) ◽  
Author(s):  
Kevin Gallagher
Keyword(s):  
Joint Venture ◽  
North West

PETROLEUM POTENTIAL OF THE CEDUNA SUB-BASIN: IMPACT OF GNARLYKNOTS–1A

2005 ◽  
Vol 45 (1) ◽  
pp. 365 ◽  
Author(s):  
D. Tapley ◽  
B.C. Mee ◽  
S.J. King ◽  
R.C. Davis ◽  
K.R. Leischner
Keyword(s):  
Joint Venture ◽  
Hanging Wall ◽  
Seismic Survey ◽  
Wall Structure ◽  
Shelf Area ◽  
Hydrocarbon Source Rock ◽  
Petroleum Potential ◽  
North West ◽  
Hydrocarbon Charge ◽  
Play Elements

The Ceduna Sub-basin, located in the eastern Bight Basin, is one of the few frontier deepwater provinces in Australia whose hydrocarbon potential remains largely untested. The sediments of the sub-basin span an area of over 95,000 km2—comparable to the combined area of the Exmouth, Barrow and Dampier sub-basins on Australia’s North West Shelf. Prior to 2003, exploration wells had been drilled only on the present day shelf area of the sub-basin. The recent Gnarlyknots–1A well, drilled in May 2003 by the Woodside operated joint venture in EPP29, has provided the first calibration point in the under-explored deepwater area of the sub-basin.The well was the culmination of a basin analysis project that integrated results from prior drilling in adjacent areas, existing seismic surveys, regional gravity and magnetics interpretations, and a newly acquired 16,000 line km 2D seismic survey. Individual play elements of reservoir, seal, and hydrocarbon charge were analysed and combined to form play maps for key stratigraphic intervals. The Gnarlyknots prospect was chosen from more than 40 leads as the best location to test multiple play levels in an area interpreted pre-drill to be favourable for reservoir, seal, and charge.Gnarlyknots–1A confirmed the presence of several favourable play elements but failed to encounter commercial hydrocarbons. Excellent quality sandstone reservoirs, marine shale top seals and thermogenic hydrocarbon shows—indicating the presence of a hydrocarbon source rock in a mature kitchen area downdip—were all encountered in the well. The failure of the well is attributed to the absence of fault seal on the updip bounding fault of the drilled hanging wall structure. The implications of this well result for the prospectivity of the Ceduna Sub-basin have been analysed, and provide encouragement for Woodside to pursue future exploration programs in the region.

NORTH WEST SHELF 3-D SEISMIC—A DECADE OF DEVELOPMENTS

1993 ◽  
Vol 33 (1) ◽  
pp. 315
Author(s):  
P.S. Vaughan
Keyword(s):  
Joint Venture ◽  
Spatial Sampling ◽  
Seismic Surveys ◽  
North West ◽  
The North ◽  
Technological Developments

Woodside as Operator, on behalf of three Joint Venture groups, over the last decade has acquired eight 3-D seismic surveys covering some 4 600 km2 over the Rankin Trend and Dampier Sub-Basin Production Licences and Exploration Permits on the North West Shelf of Australia. This area represents approximately 45 per cent coverage of the present Woodside operated acreage in the area. The acquisition, processing and interpretation technology and also the benefits derived from the 3-D technique have changed remarkably since the first North West Shelf 3-D survey in 1981. This paper focusses on the main technological developments in 3-D seismic, particularly involving multi-source and streamer technology, increased spatial sampling and interpretation techniques which have changed the role of 3-D seismic in Exploration strategies through the 1980s and into the 1990s.

A NEW TECTONO-STRATIGRAPHIC SYNTHESIS OF THE NORTH WEST CAPE AREA

1991 ◽  
Vol 31 (1) ◽  
pp. 154 ◽  
Author(s):  
R.J. Malcolm ◽  
M.C. Pott ◽  
E. Delfos
Keyword(s):  
Seismic Data ◽  
Joint Venture ◽  
Lateral Displacement ◽  
Landsat Imagery ◽  
Block Rotation ◽  
Surface Mapping ◽  
North West ◽  
The North ◽  
Oil Flow ◽  
Transfer Faults

The North West Cape area in the Exmouth Sub-basin was the site of the first onshore oil flow in Australia at Rough Range-1 in 1953. Subsequently, exploration focused on two large surface anticlines, Cape Range and Rough Range. By 1984, 30 unsuccessful wells had made it clear that the subsurface was far more complex than indicated by the surface mapping and limited seismic data. A detailed reappraisal of the subsurface structure and stratigraphy was needed.A joint venture group operated by Ampol Exploration began a new phase of exploration by recording over 1200 km of seismic data, both regional and detailed, between 1985 and 1989. An integrated interpretation of seismic data, well information and Landsat imagery has improved the understanding of structural and stratigraphic complexities and has given direction to the current exploration effort.Five of the most significant tectonic episodes to affect the North West Cape area have been recognised. They are Late Carboniferous and Early Jurassic (Sinemurian) rifting phases, Callovian-Oxfordian and Berriasian-Valanginian syn-rift pulses related to break-up and, finally, structural inversion in the Late Miocene. Each of these episodes is associated with characteristic structural styles and stratigraphic sequences.Significant lateral displacement along transfer faults during Sinemurian rifting and again during the Berriasian- Valanginian syn-rift pulse has resulted in the formation of tear faults that swing westward and merge with the plane of the transfer faults. Fault-block rotation and uplift associated with these tear faults provide potential structural and stratigraphic traps. The influence that transfer faults have on the hydrocarbon prospectivity of the North West Cape area has been recognised, including their role in the distribution of reservoir and source rocks.These tectono-stratigraphic concepts have provided a sound framework for future exploration in the North West Cape area, and may have implications for hydrocarbon prospectivity in other parts of the North West Shelf and on passive margins elsewhere.

A TECHNICAL APPRAISAL OF STORAGE OF GORGON CO2 AT BARROW ISLAND, NORTH WEST SHELF

2004 ◽  
Vol 44 (1) ◽  
pp. 639 ◽  
Author(s):  
R. Malek ◽  
R. Bartlett ◽  
B. Evans
Keyword(s):  
Joint Venture ◽  
Phase 1 ◽  
Co2 Storage ◽  
Earth Model ◽  
Second Phase ◽  
Due Diligence ◽  
Gas Field ◽  
Technical Feasibility ◽  
North West ◽  
Monitoring Technologies

The Gorgon gas field lies 70 km west of Barrow Island in 200 m of water. The field is jointly owned by ChevronTexaco Australia, Shell Development Australia and Mobil Exploration and Producing Australia and has certified proven hydrocarbon gas reserves of 272.69 Giga cubic metres (Gm3) (9.63 trillion cubic feet (Tcf)). Carbon dioxide (CO2) comprises about 14 mole % of the raw gas resource.The Gorgon joint venture is committed to the responsible management of greenhouse gas emissions and this ongoing commitment is reflected in the plan to inject Gorgon CO2 into the Dupuy Formation beneath Barrow Island, unless it is cost prohibitive or technically unfeasible.This paper summarises the Phase 1 assessment made by the Western Australian Department of Industry and Resources (DoIR) into the technical feasibility of the Gorgon CO2 storage project. Technical feasibility is defined as the ability to inject CO2 in a manner that has acceptable safety, environmental and reservoir risks based on assessments made by both the Gorgon joint venture and regulatory bodies.DoIR and ChevronTexaco Australia agreed to regularly review the technical work for due diligence purposes. To assist in the assessment, DoIR engaged the services of Curtin University. The Phase 1 review was completed in June 2003 and provided technical assurance on the feasibility of CO2 storage beneath Barrow Island. This provided one of the criteria for the WA State Government’s decision to grant in-principle access to Barrow Island for the project.The Phase 1 review provided a comparative risk analysis and recommendations related to improving the sub-surface definition of the earth model, further assessment of seal and fault integrity, injectivity, near-well bore reactions and CO2 surveillance and monitoring technologies. Key DoIR recommendations included the need for additional geological data and a long-term monitoring strategy for reservoir management and contingency planning. The second Phase of due diligence commenced in February 2004.

THE GOLDFIELDS GAS PIPELINE: 'OPENING A NEW FRONTIER'

1996 ◽  
Vol 36 (1) ◽  
pp. 599
Author(s):  
B.M. Ride
Keyword(s):  
Joint Venture ◽  
Major Effect ◽  
Gas Pipeline ◽  
Liquid Fuels ◽  
Mining Operations ◽  
Simple Method ◽  
North West ◽  
Demand Growth ◽  
The North ◽  
New Frontier

Gas exploration and development in the northwest Pilbara in WA has increased due to the commitment of the Goldfields Gas Transmission Joint Venture to a 1,380 km gas pipeline linking the north west Pilbara to the east Pilbara iron ore region and the northern and central Goldfields. Construction of the GGT pipeline was approved in January 1995 and it is expected the pipeline will be servicing major mining operations in Newman, Mt Keith, Leinster and Kalgoorlie by August 1996. Other existing mining operations located near the pipeline are expected to convert from distillate for power station fuel to gas in 1996-97. Major new mining prospects in these highly prospective minerals provinces also offer potential for increased gas demand and GGT Pipeline throughput.The commercial arrangements for GGT Pipeline services are the first in Australia to be offered under the open access arrangements espoused by the Federal and WA Governments, and have set a benchmark for other pipelines in Australia. The innovative distance related pipeline tariff arrangements offer prospective gas shippers a simple method for evaluating use of the GGT pipeline and securing gas transmission services.The GGT Pipeline has had and will continue to have a major effect on the WA gas scene, stimulating gas exploration by capturing an established base load energy market currently dependent on liquid fuels and stimulating further WA gas demand growth.

THE DEVELOPMENT OF GORGON AREA GAS

2002 ◽  
Vol 42 (2) ◽  
pp. 113
Author(s):  
I.J. Grose
Keyword(s):  
Natural Gas ◽  
Environmental Performance ◽  
Joint Venture ◽  
Unit Cost ◽  
Clean Energy ◽  
North West ◽  
Design Concepts ◽  
The North ◽  
Competitive Prices ◽  
Exxon Mobil

Australia will increasingly need to turn to natural gas to offset declining oil production and meet an expanding global need for clean energy. The Gorgon Development Joint Venture Participants, (ChevronTexaco/Exxon- Mobil/Shell), are poised to develop the significant Gorgon gas reserves located 130 km offshore the North West Australian coast to help fulfil this need.The Gorgon Development has access to extensive proved reserves of 13.8 Tcf and a development plan that can supply gas to a Barrow Island landfall at world competitive prices. Several concepts are being considered for development of the Gorgon reserves.Technology will play a key role, with the extensive use of subsea production facilities and innovative LNG design concepts being considered.The focus is on a design that would have a low unit cost and also provide new benchmarks in safety and environmental performance. The development of the Gorgon reserves could also facilitate the establishment of other gas-based industries in Western Australia and offers the opportunity for new gas-to-liquid (GTL) plants to lead Australia’s transition to a gas-based economy.The Gorgon Development is expected to attract nearly A$4 billion investment for an LNG development and a further A$2 billion for a major industrial gas consumer. Total export income could reach A$2,500 million per year for 30 years.

LEGENDRE: MATURATION OF A MARGINAL OFFSHORE OIL DISCOVERY TO DEVELOPMENT PROJECT

1999 ◽  
Vol 39 (1) ◽  
pp. 504
Author(s):  
J.M. Willetts ◽  
D.J. Mason ◽  
L. Guerrera ◽  
P. Ryles
Keyword(s):  
Joint Venture ◽  
Development Planning ◽  
Development Project ◽  
Horizontal Drilling ◽  
North West ◽  
The North ◽  
Simulation Techniques ◽  
Production Wells ◽  
Light Oil ◽  
Offshore Oil

Commercialisation of the Legendre hydrocarbon resources represents the culmination of over 30 years of exploration and appraisal and more recent development planning, following the discovery by the first well to be flow-tested on the North West Shelf, Legendre–1, in 1968. By application of 3D seismic, reservoir modelling and simulation techniques, horizontal drilling and innovative development options, the WA-l-P Joint Venture is confident of achieving an economic return on a relatively small resource base.The two separate accumulations, Legendre North and Legendre South, are together expected to contain some 14 million m3 (90 MMSTB) of oil-in-place. The oil column in the northern accumulation is 45 m at its maximum, whilst a 20 m column is present in the southern accumulation. Reservoir quality is generally very good with mostly massive sandstones with little or no internal stratification. The reservoir contains a light oil and aquifer support is expected from communication with the underlying Angel Formation sandstones.The subsurface development plan has been designed to optimise the recovery of the oil in place in the two accumulations. Production wells with horizontal sections of 750 m will be used to minimise drawdown and ensure good sweep. Production is expected at a plateau rate of 4,800 to 6,400 m3/d (30−40,000 BOPD). Produced gas will be disposed of by means of a re-injection well downdip of the producers.

Field experiences with virtual metering technology

2010 ◽  
Vol 50 (1) ◽  
pp. 163 ◽  
Author(s):  
Prashant Haldipur ◽  
Peter Chow
Keyword(s):  
Real Time ◽  
Flow Rate ◽  
Joint Venture ◽  
Field Experiences ◽  
Hydrate Formation ◽  
Cost Effective ◽  
Advanced Technology ◽  
Acceptance Testing ◽  
North West ◽  
Time Flow

This paper presents field experiences with the implementation of virtual well metering technology on the North West Shelf (NWS) of Western Australia. This technology is used to obtain well-by-well flow rate estimates using conventional pressure and temperature instrumentation in a wellbore and Christmas tree without the need for expensive multiphase flow meters. Best practices in project execution—including specifications, acceptance testing and commissioning procedures—are presented for deploying this advanced technology. The paper focusses on two NWS gas-condensate developments operated by Woodside Energy Ltd (WEL) on behalf of the NWS joint venture partners: the Perseus over Goodwyn (PoG) project, which is a four well subsea development of the Perseus and Searipple fields that tie back to the Goodwyn A platform; and a three well subsea development for the Angel field. The PoG virtual metering system (VMS) was commissioned in October 2007 and the Angel VMS more recently in February 2009. The paper compares field data and shows that this technology has provided very reliable and accurate flow rate predictions; historical data suggests that monthly reconciliation factors as low as 3–5% can be achieved. Virtual metering systems are a cost effective and reliable means to obtain well-by-well flow rates. Besides enabling better reservoir management, these well metering systems are easily integrated with real-time pipeline monitoring systems to enable reliable subsea operations. An integrated virtual metering and pipeline management system that includes look-ahead forecasting capabilities and guidance for real-time flow assurance on operational issues, such as hydrate formation and detection of restriction, is being developed for the Pluto field.

EAST SPAR FIELD—FROM DISCOVERY TO SALES

1996 ◽  
Vol 36 (1) ◽  
pp. 30
Author(s):  
G. M. Pitt ◽  
L. E. Kuryiowicz ◽  
IP. F. Campbell
Keyword(s):  
Joint Venture ◽  
Gas Pipeline ◽  
Window Of Opportunity ◽  
Engineering Construction ◽  
North West ◽  
The North ◽  
Wet Gas ◽  
Development Concept ◽  
Gas Market ◽  
Geotechnical Studies

The East Spar field is located 40 km west of Barrow Island on the North West Shelf, offshore WA, and con­tains 23.6 G.m3 (834 Bscf) of proven and probable wet gas in-place in the Early Cretaceous Barrow Group. The trap is structural, but with negligible time closure.At the time of the discovery and early appraisal of East Spar in late 1993, a rapid deregulation of the gas market was taking place. In combination with the concept of a gas pipeline to the central WA Goldfields region, a marketing 'window of opportunity' was created for the East Spar field, if the development could be crystallised in the available period of 9 months. This required ap­praisal drilling, geotechnical studies, reservoir engineer­ing and facilities engineering to be advanced on parallel fronts, with close co-ordination and communication be tween all disciplines.The concept of an alliance between the East Spar Joint Venture and the engineering/construction contractors was identified as a way of retaining flexibility to alter the development concept during this period, and provide other benefits during the subsequent construction phase. This alliance was ultimately formed to include represen­tatives from WMC (on behalf of the East Spar Joint Venture (ESJV)), Kvaerner-R J Brown and dough Engi­neering.The East Spar facilities will comprise a subsea comple­tion and gathering system, with all produced fluids being piped to processing facilities on Varanus Island. The treated gas will then be transported to the mainland via the existing sales gas pipeline to the onshore Dampier to Bunbury pipeline, which connects with the Goldfields Gas pipeline. The condensate will be exported from Varanus Island by tanker. First sales are expected in October 1996

Electron Microscopic Examination of a Transplantable Rat Mammary Carcinoma

1968 ◽  
Vol 26 ◽  
pp. 20-21
Author(s):  
S. Shirahama ◽  
G. C. Engle ◽  
R. M. Dutcher
Keyword(s):  
Electron Microscope ◽  
Osmium Tetroxide ◽  
Electron Microscopic Examination ◽  
Undifferentiated Carcinoma ◽  
Uranyl Acetate ◽  
Sprague Dawley ◽  
Electron Microscopic ◽  
North West ◽  
X Irradiation ◽  
Tissue Specimens

A transplantable carcinoma was established in North West Sprague Dawley (NWSD) rats by use of X-irradiation by Engle and Spencer. The tumor was passaged through 63 generations over a period of 32 months. The original tumor, an adenocarcinoma, changed into an undifferentiated carcinoma following the 19th transplant. The tumor grew well in NWSD rats of either sex at various ages. It was invariably fatal, causing death of the host within 15 to 35 days following transplantation.Tumor, thymus, spleen, and plasma from 7 rats receiving transplants of tumor at 3 to 9 weeks of age were examined with an electron microscope at intervals of 8, 15, 22 and 30 days after transplantation. Four normal control rats of the same age were also examined. The tissues were fixed in glutaraldehyde, postfixed in osmium tetroxide and embedded in Epon. The plasma was separated from heparanized blood and processed as previously described for the tissue specimens. Sections were stained with uranyl acetate followed by lead citrate and examined with an RCA EMU-3G electron microscope.

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