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Journal articles on the topic 'Oil fields Australia'

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Published: 4 June 2021

Last updated: 28 January 2023

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1

Kalinowski, Aleksandra, Eric Tenthorey, Mojtaba Seyyedi, and Michael Ben Clennell. "The search for new oil and CO." APPEA Journal 62, no. 1 (May 13, 2022): 281–93. http://dx.doi.org/10.1071/aj21077.

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Residual oil zones (ROZs) could present a new, potentially large and commercially viable oil resource for Australia and provide an avenue for geological storage of carbon dioxide (CO2) through CO2 enhanced oil recovery (CO2-EOR). These reservoirs, which can contain a moderate amount of residual oil and resemble water-flooded oil fields, can be associated with conventional fields (brownfields) or occur with no associated main pay zone (greenfields). Both types of ROZ are currently produced commercially through CO2-EOR in the Permian Basin, USA, and are of growing interest internationally, but o

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2

Loro, Richard, Robin Hill, Mark Jackson, and Tony Slate. "Technologies that have transformed the Exmouth into Australia." APPEA Journal 55, no. 1 (2015): 233. http://dx.doi.org/10.1071/aj14018.

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The oil and gas fields of the Exmouth Sub-basin, offshore WA, have presented a number of significant challenges to their exploitation since the first discoveries of heavy oil and lean gas were made in the late 1980s and early 1990s. Presently, some 20 oil and gas fields have been discovered in a variety of Late Jurassic to Cretaceous clastic reservoirs from slope turbidites to deltaic sands. Discovered oils are typically heavily biodegraded with densities ranging from 14–23° API and moderate viscosity. Seismic imaging is challenging across some areas due to pervasive multiples and gas escape f

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3

Slate, Tony, Ralf Napalowski, Steve Pastor, Kevin Black, and Robert Stomp. "The Pyrenees development: a new oil development for Western Australia." APPEA Journal 50, no. 1 (2010): 241. http://dx.doi.org/10.1071/aj09014.

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The Pyrenees development comprises the concurrent development of three oil and gas fields: Ravensworth, Crosby and Stickle. The fields are located in production licenses WA-42-L and WA-43-L, offshore Western Australia, in the Exmouth Sub-basin. The development will be one of the largest offshore oil developments in Australia for some time. It is a complex subsea development consisting of a series of manifolds, control umbilicals and flexible flowlines tied back to a disconnectable floating production, storage and offloading (FPSO) vessel. The development involves the construction of 17 subsea

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Miyazaki, S. "CHARACTERISATION OF AUSTRALIA'S OIL FIELDS BY FLUID AND RESERVOIR PROPERTIES AND CONDITIONS." APPEA Journal 29, no. 1 (1989): 287. http://dx.doi.org/10.1071/aj88025.

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An extensive data compilation of reservoir rock and fluid properties, and temperature and pressure conditions, in Australia's oil fields, has provided regional information on the nature of crude oil accumulations. It has also allowed the determination of systematic trends and regional variations. These trends and variations are depicted in cross- plots of porosity against depth, porosity against permeability, temperature against depth, pressure against depth, oil gravity against depth, and formation- water salinity against depth.Offshore oil reservoirs, principally based on Gippsland Basin dat

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5

Craig, Adam, Stephen Newman, Peter Stephenson, Chris Evans, Shaun Yancazos, and Simon Barber. "Hydrogen storage potential of depleted oil and gas fields in Western Australia." APPEA Journal 62, no. 1 (May 13, 2022): 185–95. http://dx.doi.org/10.1071/aj21146.

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The global subsurface hydrogen storage industry is at an embryonic stage and is currently dominated by a handful of manufactured salt caverns worldwide. There are currently no known depleted oil or gas fields used to store pure hydrogen, although there are examples of hydrogen and natural gas mixtures. The Government of Western Australia has developed a renewable hydrogen strategy with a vision for Western Australia becoming a significant producer, exporter and user of renewable hydrogen. An element of the strategy and roadmap includes the possibility of utilising depleted oil and gas fields f

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6

Ronalds, B. F. "SHARED INFRASTRUCTURE: A COST-EFFECTIVE DEVELOPMENT STRATEGY FOR SMALLER FIELDS OFFSHORE AUSTRALIA?" APPEA Journal 44, no. 1 (2004): 569. http://dx.doi.org/10.1071/aj03025.

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B.F. RonaldsFuture oil discoveries offshore Australia are unlikely to be large fields that can support the development of a one-off self-sufficient facility. Fixed platforms are generally only feasible in shallow water when the water depth (in metres) to well count ratio d/w The construction and ongoing re-use of a generic FPSO suited to Australasian field conditions might be of considerable assistance in monetising small oil fields in deeper water. Similarly, aptly located, designed and operated gas hubs could open up large areas for satellite gas development long into the future, aided by ne

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7

Wilmshurst, Jan. "USE OF DRAG REDUCER CHEMICAL IN THE BASS STRAIT CRUDE OIL PRODUCING SYSTEM." APPEA Journal 25, no. 1 (1985): 119. http://dx.doi.org/10.1071/aj84010.

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Esso Australia Ltd (on behalf of the Esso/BHP joint venture) operates a crude oil and natural gas processing system based on the offshore fields in Bass Strait.Crude oil is discharged from the offshore fields via a 132-km pipeline to the crude stabilization plant at Longford. A 187-km pipeline is then used to transfer stabilized crude to Long Island Point, where the oil is held in storage prior to discharge to Australian refineries and to export.Without the use of drag reducer chemical, Bass Strait crude production is limited by pipeline hydraulic capacity. Since the last quarter of 1983, drag

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8

Powell, T. G. "UNDERSTANDING AUSTRALIA’S PETROLEUM RESOURCES, FUTURE PRODUCTION TRENDS AND THE ROLE OF THE FRONTIERS." APPEA Journal 41, no. 1 (2001): 273. http://dx.doi.org/10.1071/aj00013.

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Relative to its needs over the last 30 years, Australia has enjoyed a high level of self-sufficiency. Whilst the overall remaining reserves of oil have been relatively constant, reserves of condensate have grown substantially as major reserves of natural gas have been added to Australia’s resource inventory. Oil and condensate reserves stand at 3.43 billion barrels (505 GL), of which 50% is condensate in gas fields. Australia’s undiscovered oil potential in its major offshore hydrocarbon producing basins has been upgraded to an indicative 5 billion barrels (800 GL) at the average expectation,

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9

Bagheri, Mohammad B., Matthew Wallace, Vello Kuuskraa, Hadi Nourollah, Matthias Raab, and Tim Duff. "CO." APPEA Journal 62, no. 2 (May 13, 2022): S372—S377. http://dx.doi.org/10.1071/aj21144.

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This paper discusses the potential for storing CO2 and producing lower carbon intensity oil from onshore oil fields in the Cooper and Surat basins of South Australia and Queensland. A comprehensive database was compiled for the oil fields in the basins above, including the key required data to assess the potential of the basins for CO2 enhanced oil recovery (EOR). The South Australia and Queensland oil field databases contain 140 reservoirs with a combined original oil in-place of 1497 million barrels. These reservoirs have, to date, produced a total of 382 million barrels, with 458 million ba

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10

Tucker, David H., Ross Franklin, N. Sampath, and Stan Ozimic. "Review of airborne magnetic surveys over oil and gas fields in Australia." Exploration Geophysics 16, no. 2-3 (June 1985): 300–302. http://dx.doi.org/10.1071/eg985300.

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11

Farrell, Bradley. "Remote Operations Centres – what next?" APPEA Journal 57, no. 2 (2017): 440. http://dx.doi.org/10.1071/aj16115.

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Integrated Operations (IO) is a well-established concept in oil and gas. In Australia, upstream oil & gas operators have made significant investments in their local IO capability. For many operators this has meant the creation of a dedicated Remote Operations Centre for their new LNG production assets. By ‘Remote Operations Centre’ (or ‘ROC’) we mean a purpose-built facility where multi-disciplinary teams work together to monitor, support or control production fields and/or assets; with the ROC being geographically distant from those fields/assets. For operators with new LNG facilities, a

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12

McNicoll, Russell. "HORIZONTAL DRILLING IN AUSTRALIA: THREE CASE HISTORIES." APPEA Journal 31, no. 1 (1991): 354. http://dx.doi.org/10.1071/aj90027.

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Three horizontal wells with horizontal sections of up to 331 m were drilled successfully during the development of the marginal North Herald and South Pepper oil and gas fields, which have relatively thin oil columns (6 to 12 m) at a depth of some 1200 m sub-sea. A steerable motor system was used to maintain directional control within the design parameters. This system proved to be successful from the start and no major changes to the bottom hole assembly design were required to drill all the wells. Average drilling time including running and setting the seven inch liner amounted to 12 days. T

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13

Bint, A. N. "DISCOVERY OF THE WANAEA AND COSSACK OIL FIELDS." APPEA Journal 31, no. 1 (1991): 22. http://dx.doi.org/10.1071/aj90003.

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Exploration of the Dampier Sub-basin on the North West Shelf of Australia commenced with a reconnaissance seismic survey in 1965. In 1969 Madeleine-1, the first well drilled on the Madeleine Trend, encountered water bearing Upper Jurassic sandstones. Following acquisition of a regional grid of modern seismic in 1985 and 1986, and comprehensive hydrocarbon habitat studies, the Wanaea and Cossack prospects were matured updip from Madeleine 1. They were proposed to have improved reservoir development and an oil charge.The Wanaea Oil Field was discovered in 1989 when Wanaea-1 encountered a gross o

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14

Hunter, P. C. "PREPARATION AND IMPLEMENTATION OF A SAFETY MANAGEMENT SYSTEM IN BHPP." APPEA Journal 37, no. 1 (1997): 657. http://dx.doi.org/10.1071/aj96046.

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BHP is a leading global resources company which comprises four main business groups: BHP Copper, BHP Minerals, BHP Steel and BHP Petroleum. BHP Petroleum (BHPP) global operations are divided into four Regions and Australia/Asia Region is responsible for exploration, production, field development and joint ventures in the Asia-Pacific region. In Australia, the Company's largest producing assets are its shares of the Gippsland oil and gas fields in Bass Strait and the North West Shelf project in Western Australia.BHPP operates three Floating Production, Storage and Offloading (FPSO) vessels-Jabi

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15

Evans, P. R. "Australia's Potential for Petroleum." Energy Exploration & Exploitation 4, no. 4 (August 1986): 255–83. http://dx.doi.org/10.1177/014459878600400402.

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The viability and direction of future exploration for petroleum in Australia appear to have been set, particularly by the results of the petroleum industry's endeavours over the past four years. The limited local markets for the abundance of natural gas, with which Australian basins are characterised, will control the direction and rate of exploration for many years. Even so, the local markets for petroleum should provide a continued incentive to search for oil. The Gippsland Basin is at a mature stage of exploration, and a replacement for it is still required in order that Australia maintain

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16

Williams, R. C. "THE CREATION AND FLOTATION OF NOVUS PETROLEUM LTD." APPEA Journal 36, no. 1 (1996): 706. http://dx.doi.org/10.1071/aj95050.

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Novus Petroleum Ltd listed on the Australian Stock Exchange on 24 May 1995 having raised $157.5 million of equity. It was the largest initial public offering (IPO) of an oil company ever undertaken in Australia, and the third largest equity-raising on the Australian market during financial year 1994-5.The creation of Novus involved the creation of a team of professional advisers comprising ANZ McCaughan (broker), Indosuez Australia (financial adviser), Ernst and Young (accounting and taxation adviser), Phillips Fox (legal adviser) and Fern Consultants (technical adviser). During the period fro

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Robertson, C. S. "AUSTRALIA'S PETROLEUM PROSPECTS: CHANGING PERCEPTIONS SINCE THE BEGINNING OF THE CENTURY." APPEA Journal 28, no. 1 (1988): 190. http://dx.doi.org/10.1071/aj87016.

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Perceptions of Australia's petroleum prospectivity, both by the general public and by professional explorationists, have changed considerably over the years. By the 1920s there had already been a considerable change from the optimism of the early part of the century, engendered largely by gas and condensate indications in water bores drilled in the Roma area, to a comparatively pessimistic view due to the failure of numerous small drilling ventures, and to the published opinions of some overseas experts.The public then remained generally apathetic or pessimistic about Australia's petroleum fut

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18

van Merwyk, A. M., and A. L. Disney. "ENVIRONMENTAL UPDATE 2004." APPEA Journal 45, no. 2 (2005): 157. http://dx.doi.org/10.1071/aj04069.

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This paper presents the highlights of development activity of 2004 for the petroleum industry within Australia. In the face of declining oil production within Australia there were few new oil field developments in 2004 (Exeter- Mutineer; Jingemia). The start up of liquids stripping at Bayu-Undan in the Timor Sea and other gas/condensate fields such as Apache’s Linda, however, helped to arrest the declining trend. The first oil fields that define a new oil province in the Exmouth Sub-basin were the subject of extensive appraisal programs and Woodside gave the green light for start of the A$1.48

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19

Davidson, John K. "TECTONIC CONTROL OF WORLD OIL RESERVES: AUSTRALIA'S POSITION." APPEA Journal 32, no. 1 (1992): 183. http://dx.doi.org/10.1071/aj91015.

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Although simple extensional clay models may be representative of grabens tens of kilometres in length, rotational divergence of continents on a sphere produces very different structures. Repeated periods of compression during separation result in wrench faults and compressional anticlines developing along major crustal fractures as a consequence of changes in momentum between a continent and adjacent smaller continental blocks along its rifted margin.The global distribution of rotationally divergent continental margins can be accounted for by asymmetric expansion of the earth. The southern bul

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20

Hansen, Lein Mann. "Australia well positioned to become a CCUS leader." APPEA Journal 62, no. 2 (May 13, 2022): S25—S28. http://dx.doi.org/10.1071/aj21107.

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Australia’s carbon capture, utilisation and storage (CCUS) sector could be set for fresh boost as oil and gas players are investing heavily in large-scale projects. In 2020, Australia emitted around 499 million tonnes of CO2-equivalent (CO2e). Country-wide, only 2.5 million tonnes of CO2 is captured and stored annually in the Gorgon CCUS project. Starting its CCUS journey on the wrong foot, Australia’s ambitious Gorgon project suffered from cost overruns, delays and much lower capture rates than planned. Nevertheless, 3 years after startup we now see renewed momentum on the back of significant

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21

Saunders, Donald F., K. Ray Burson, Jim F. Branch, and C. Keith Thompson. "Relation of thorium‐normalized surface and aerial radiometric data to subsurface petroleum accumulations." GEOPHYSICS 58, no. 10 (October 1993): 1417–27. http://dx.doi.org/10.1190/1.1443357.

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A new exploration method has been developed using surface and aerial gamma‐ray spectral measurements in prospecting for petroleum in stratigraphic and structural traps. Formerly troublesome lithologic and environmental variables are suppressed by correcting potassium and uranium readings using a new process of thorium normalization. Normalized potassium shows characteristic low concentrations above petroleum deposits. Normalized uranium shows higher values than normalized potassium over petroleum and generally lower values elsewhere. We attribute these anomalies to effects of microbial consump

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Smith, Peter, and Iain Paton. "From wells to decisions—data management for coal seam gas operators in Australia as compared to conventional oil and gas operators." APPEA Journal 51, no. 2 (2011): 716. http://dx.doi.org/10.1071/aj10096.

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The large number of wells associated with typical coal seam gas (CSG) developments in Australia has changed the paradigm for field management and optimisation. Real time data access, automation and optimisation—which have been previously considered luxuries in conventional resources—are key to the development and operation of fields, which can easily reach more than 1,000 wells. The particular issue in Australia of the shortage of skilled labour and operators has increased pressure to automate field operations. This extended abstract outlines established best practices for gathering the numero

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Crowley, A. J. "THE M. AUSTRALIS SANDSTONES, DAMPIER SUB-BASIN, AUSTRALIA." APPEA Journal 39, no. 1 (1999): 104. http://dx.doi.org/10.1071/aj98007.

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Three independent Barremian sandstone units that are characterised by the M. australis palynozone have been identified in the Lewis Trough and Enderby Terrace of the southeastern Dampier Sub-Basin, offshore Western Australia. They constitute a basin-floor fan unit and shelfal transgressive unit that are characterised by the lower Af. australis sub-zone, a shelfal marine to fluvial unit that is characterised by the middle M. australis sub- zone and a shelfal marine unit that is characterised by the upper M. australis sub-zone. The M. australis sandstones are characterised by their excellent res

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Mensah, RK, W. Liang, D. Gibbs, R. Coates, and D. Johnson. "Evaluation ofnC27 petroleum spray oil for activity againstHelicoverpaspp. on commercial cotton fields in Australia." International Journal of Pest Management 51, no. 1 (March 2005): 63–70. http://dx.doi.org/10.1080/09670870400028300.

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Tenthorey, Eric, Ian Taggart, Aleksandra Kalinowski, and Jason McKenna. "CO2-EOR+ in Australia: achieving low-emissions oil and unlocking residual oil resources." APPEA Journal 61, no. 1 (2021): 118. http://dx.doi.org/10.1071/aj20076.

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The petroleum industry, through the production and consumption of oil and gas, contributes to global greenhouse gas emissions. However, the industry’s leadership and experience in underground injection and storage of CO2, especially through CO2 enhanced oil recovery (CO2-EOR), which has been proposed as a possible solution to reducing atmospheric CO2 levels, has not been well acknowledged. Unlike traditional CO2-EOR, which tends to be a net carbon emitter due to the use of predominantly natural CO2, rather than anthropogenic, CO2-EOR+ focuses on storing a larger volume of CO2. Thus CO2-EOR+ no

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Foster, M. T. Bradshaw C. B., M. E. Fellows, and D. C. Rowland. "THE AUSTRALIAN SEARCH FOR PETROLEUM: PATTERNS OF DISCOVERY." APPEA Journal 39, no. 1 (1999): 12. http://dx.doi.org/10.1071/aj98001.

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Three cycles of successful commercial hydrocarbon exploration and discovery have occurred in Australia since 1960, although sporadic efforts to locate oil accumulations have occurred since 1860. The first cycle of successful exploration, from 1960 to 1972, revealed most of the productive basins and all of the giant oil fields found to date. After an interval of very low drilling rates between 1973 and 1978, exploration activity returned to strong levels for a second cycle of discovery between 1978 and 1988. A third cycle commenced in 1989 when there was an increase in exploration activity and

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Carpenter, Chris. "Technical Solution Improves Safety, Efficiency of Well Construction Offshore Australia." Journal of Petroleum Technology 73, no. 10 (October 1, 2021): 46–48. http://dx.doi.org/10.2118/1021-0046-jpt.

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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 202353, “Drilling-Performance and Risk-Management Optimization Offshore Australia: Improving Overall Safety and Efficiency of the Well-Construction Process,” by Chandrasekhar Kirthi Singam, Farshid Hafezi, and Clyde Rebello, Schlumberger, et al., prepared for the 2020 SPE Asia Pacific Oil and Gas Conference and Exhibition, originally scheduled to be held in Perth, Australia, 20–22 October. The paper has not been peer reviewed. The emergence of real-time well construction performance-monitoring cent

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Williamson, P. E., and C. B. Foster. "ACCESS TO AUSTRALIAN EXPLORATION AND PRODUCTION DATA: A CRITICAL FACTOR IN ATTRACTING INVESTMENT." APPEA Journal 43, no. 1 (2003): 693. http://dx.doi.org/10.1071/aj02040.

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During the past 10 years, Australia has maintained 65– 85% self-sufficiency in oil and better than 100% sufficiency in gas. This has generated significant societal benefits in terms of employment, balance of payments, and revenue. The decline of the super-giant Gippsland fields, discovery of smaller oil pools on the North West Shelf, and the increasing reliance on condensate to sustain our liquids supply, however, sharpens the focus on Australia’s need to increase exploration and discover more oil. Australia is competing in the global market place for exploration funds, but as it is relatively

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Saraceni, Pat, and Keely Liddle. "Decommissioning – What's the fuss about?" APPEA Journal 58, no. 2 (2018): 748. http://dx.doi.org/10.1071/aj17223.

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Offshore decommissioning is complex, challenging (both legally and operationally) and costly. With the rise in the number of fields approaching end of life (or economic viability), the interest in decommissioning in and around Australian waters is set to increase in the near to medium future. The lack of established federal laws regulating all aspects of decommissioning opens the door for Australia to show innovative leadership in how best to tackle end of life asset management in the oil and gas sector. Australia’s learning in this area will be aided by the laws of jurisdictions that are bett

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Passmore, V., and R. Towner. "A History of Geological Exploration in the Canning Basin, Western Australia." Earth Sciences History 6, no. 2 (January 1, 1987): 159–77. http://dx.doi.org/10.17704/eshi.6.2.jm774585j6382583.

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The Canning Basin in northern Western Australia is a large, relatively remote, mainly desert-covered Phanerozoic basin covering 595 000 sq km. Aborigines probably first entered the basin area 30-40 000 years ago, but the main European expeditions were not until the nineteenth and twentieth centuries. Geological exploration in the basin has been largely devoted to the discovery and exploitation of natural resources, primarily oil. Earliest geological traverses were conducted by geologists of the Geological Survey of Western Australia (GSWA). The accidental discovery of traces of oil in a water

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McLerie, M. K., A. M. Tait, and M. J. Sayers. "THE YAMMADERRY, COWLE AND ROLLER DISCOVERIES IN THE BARROW SUB-BASIN, WESTERN AUSTRALIA." APPEA Journal 31, no. 1 (1991): 32. http://dx.doi.org/10.1071/aj90004.

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The TP/3 Part I permit in the Barrow Sub-basin has been held by WAPET since 1952. Improvements in seismic quality and oilfield economics in the early 1980s resulted in the 1985 Saladin oil discovery, which subsequently led to the Yammaderry, Cowle and Roller discoveries.Yammaderry-1, drilled in 1988, encountered 16.5 m of gas capping a nine metre oil column. In 1989, Cowle-1 penetrated a 14 m oil column and tested at 1016 m3 (6390 BBL) of oil per day. Roller-1, drilled in 1990, encountered six metres of gas capping nine metres of oil and tested at 866 m3 (5450 BBL) of oil per day. Roller-2, de

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Baronie, F. M., M. Fenton, G. Harman, and M. Jury. "CAN SUSTAINABLE DEVELOPMENT THINKING BE APPLIED TO NEW OILFIELDS? A CASE STUDY OF THE EARLY STAGES OF THE ENFIELD AREA DEVELOPMENT IN AN ENVIRONMENTALLY AND SOCIALLY SENSITIVE AREA." APPEA Journal 43, no. 1 (2003): 753. http://dx.doi.org/10.1071/aj02045.

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Can development of a finite resource, such as oil, be consistent with sustainable development? Sustainable development involves meeting the needs of current and future generations through simultaneous consideration of environmental, social and economic aspects (referred to as the triple bottom line).Since 1998, Woodside Energy Ltd (Woodside) has discovered three oil fields in the WA-271-P Permit area offshore North West Cape, northern Western Australia. The fields are some 20 km from the boundary of the Ningaloo Marine Park.The first part of this paper presents a case study of the Enfield Area

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Edwardes, A. K. Khurana R. J. "NEW DEVELOPMENTS IN BASS — STRAIT THE LOW- COST CHALLENGE." APPEA Journal 29, no. 1 (1989): 1. http://dx.doi.org/10.1071/aj88001.

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Esso Australia, with its co- venturer BHP Petroleum, is planning to bring five new fields into production in 1989. These fields are relatively small, with total reserves of approximately 50 million barrels (7950 ML). Development concepts new to Bass Strait have been identified to make them economically attractive.The significant change made to the fiscal environment of Bass Strait in June 1987, when the Government provided an exemption from excise for the first 30 million barrels (4770 ML) of oil production for certain offshore projects, has played a key role in the economic viability of these

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Arouri, Khaled R., David M. McKirdy, Lorenz Schwark, Detlev Leythaeuser, and Peter J. Boult. "Accumulation and mixing of hydrocarbons in oil fields along the Murteree Ridge, Eromanga Basin, South Australia." Organic Geochemistry 35, no. 11-12 (November 2004): 1597–618. http://dx.doi.org/10.1016/j.orggeochem.2004.04.008.

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Zannetos, Andy, Will Leonard, Grant Clements, Dean Grant, Andrew Miatello, Anna Galloway, Abdul Aziz Rahim, and Julien Celerier. "Making the most of mature field opportunities—2009 Cobia infill drilling campaign." APPEA Journal 50, no. 2 (2010): 703. http://dx.doi.org/10.1071/aj09067.

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The Halibut and Fortescue oil fields are located in the Gippsland Basin, offshore Australia, and have produced 1.3 billion barrels of oil since the 1970s. The fields have been developed from three platforms—Cobia, Halibut and Fortescue—using multiple infill drilling campaigns post initial development. A strong emphasis has been placed on leveraging the latest technology to optimise development of these fields. The advent of high resolution 3D seismic surveys and improved processing techniques have proved invaluable in recent programs. This is illustrated by the 2009 Cobia infill program where

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Bernecker, T., M. A. Woollands, D. Wong, D. H. Moore, and M. A. Smith. "HYDROCARBON PROSPECTIVITY OF THE DEEPWATER GIPPSLAND BASIN, VICTORIA, AUSTRALIA." APPEA Journal 41, no. 1 (2001): 91. http://dx.doi.org/10.1071/aj00005.

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After 35 years of successful exploration and development, the Gippsland Basin is perceived as a mature basin. Several world class fields have produced 3.6 billion (109) BBL (569 GL) oil and 5.2 TCF (148 Gm3) gas. Without additional discoveries, it is predicted that further significant decline in production will occur in the next decade.However, the Gippsland Basin is still relatively underexplored when compared to other prolific hydrocarbon provinces. Large areas are undrilled, particularly in the eastern deepwater part of the basin. Here, an interpretation of new regional aeromagnetic and dee

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Hyden, A. M. "OFFSHORE FACILITIES REMOVAL — A MAJOR ISSUE NOW AND FOR THE FUTURE." APPEA Journal 29, no. 1 (1989): 6. http://dx.doi.org/10.1071/aj88002.

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The costs associated with removal of offshore production facilities can have a serious impact on project economics, especially for the shorter- life marginal fields. The requirements for removal of offshore facilities are set out in the Petroleum (Submerged Lands) Act and the guidelines prepared by the International Maritime Organisation, a United Nations agency. Esso Australia Limited has completed a major study of the removal of Bass Strait platforms and has evaluated the costs of platform removal by various methods. Environmental considerations, the needs and safety of other users of the se

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Souter, David, Steve Rogers, and Jamie Oliver. "An operational and scientific monitoring program (OSMP) for the Prelude and Ichthys fields: a case study from the Browse Basin." APPEA Journal 54, no. 2 (2014): 480. http://dx.doi.org/10.1071/aj13053.

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An OSMP is the principle tool for determining the extent, severity, and persistence of environmental impacts from an oil spill. The OSMP developed for the Shell Prelude and Inpex Ichthys gas fields has 13 operational monitoring programs (OMPs) and 12 scientific monitoring programs (SMPs) reflecting the complexity of the environment in which the developments are located. A partnership of organisations led by the Australian Institute of Marine Science (AIMS) will provide specialist expertise to help implement the OSMP. This unique multi-disciplinary partnership, comprising AIMS, CSIRO, Universit

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Boreham, C. J., J. E. Blevin, A. P. Radlinski, and K. R. Trigg. "COAL AS A SOURCE OF OIL AND GAS: A CASE STUDY FROM THE BASS BASIN, AUSTRALIA." APPEA Journal 43, no. 1 (2003): 117. http://dx.doi.org/10.1071/aj02006.

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Only a few published geochemical studies have demonstrated that coals have sourced significant volumes of oil, while none have clearly implicated coals in the Australian context. As part of a broader collaborative project with Mineral Resources Tasmania on the petroleum prospectivity of the Bass Basin, this geochemical study has yielded strong evidence that Paleocene–Eocene coals have sourced the oil and gas in the Yolla, Pelican and Cormorant accumulations in the Bass Basin.Potential oil-prone source rocks in the Bass Basin have Hydrogen Indices (HIs) greater than 300 mg HC/g TOC. The coals w

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Dean, John, Garry Wall, and Kate Parker. "Australia's resource sector supply chain: prospects and policy." APPEA Journal 53, no. 2 (2013): 434. http://dx.doi.org/10.1071/aj12045.

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This extended abstract identifies potential strengths in the resources sector supply chain, with particular reference to the oil and gas sector. It identifies areas of strength in the supply chain, particularly in fields such as geotechnical services, software, instrumentation, electrical engineering, project management, consultancy, and so on. It argues for a consistent policy approach across the many policy- and service-provision actors involved to maximise industry-development chances in the medium and long term. The economic benefits of the price, investment, and volume impacts of the pres

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Baillie, P. W., and E. P. Jacobson. "PROSPECTIVITY AND EXPLORATION HISTORY OF THE BARROW SUB-BASIN, WESTERN AUSTRALIA." APPEA Journal 37, no. 1 (1997): 117. http://dx.doi.org/10.1071/aj96007.

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The Carnarvon Basin is Australia's leading producer of both liquid hydrocarbons and gas. Most oil production to date has come from the Barrow Sub-basin. The success of the Sub-basin is due to a fortuitous combination of good Mesozoic source rocks which have been generating over a long period of time, Lower Cretaceous reservoir rocks with excellent porosity and permeability, and a thick and effective regional seal.A feature of Barrow Sub-basin fields is that they generally produce far more petroleum than is initially estimated and booked, a result of the excellent reservoir quality of the princ

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Preston, J. C., and D. S. Edwards. "THE PETROLEUM GEOCHEMISTRY OF OILS AND SOURCE ROCKS FROM THE NORTHERN BONAPARTE BASIN, OFFSHORE NORTHERN AUSTRALIA." APPEA Journal 40, no. 1 (2000): 257. http://dx.doi.org/10.1071/aj99014.

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Geochemical data from oils and source rock extracts have been used to delineate the active petroleum systems of the Northern Bonaparte Basin. The study area comprises the northeastern portion of the Territory of Ashmore and Cartier Islands, and the western part of the Zone of Co-operation Area A, and is specifically concerned with the wells located on and between the Laminaria and Flamingo highs. The oils and condensates from this region can be divided into two distinct chemical groups which correspond with the reservoir types, namely, a smaller group recovered from fracture porosity within th

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Potter, Trent, Wayne Burton, Jan Edwards, Neil Wratten, Rod Mailer, Phil Salisbury, and Amanda Pearce. "Assessing progress in breeding to improve grain yield, quality and blackleg (Leptosphaeria maculans) resistance in selected Australian canola cultivars (1978–2012)." Crop and Pasture Science 67, no. 4 (2016): 308. http://dx.doi.org/10.1071/cp15290.

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Canola breeding in Australia began in the early 1970s with the first cultivars being released in the late 1970s. Thirty-four non-herbicide-tolerant canola cultivars, released in Australia between 1978 and 2012, were evaluated for improvements in yield, quality, blackleg resistance and adaptation to Australian environments. The cultivars were sown at three sites in 2008 and one site in 2014. In addition, blackleg susceptibility was assessed in two independent blackleg experiments in 2008. Yield improvement averaged 21.8 kg ha–1 year–1 (1.25% year–1) but ranged from 8 to 39.1 kg ha–1 year–1 at t

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Rezaee, Reza. "Nuclear Magnetic Resonance (NMR) Outputs Generation for Clastic Rocks Using Multi Regression Analysis, Examples from Offshore Western Australia." Fuels 3, no. 2 (May 17, 2022): 316–25. http://dx.doi.org/10.3390/fuels3020019.

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A large database of nuclear magnetic resonance (NMR) logging data from clastic rocks of offshore oil and gas fields of Western Australia was used to assess the performance of multi regression analysis (MRA) to calculate NMR log outputs from conventional well logs. This short paper introduces a set of MRA equations for the calculation of the NMR log outputs using conventional well logs as inputs. This study shows that unlike machine learning methods the MRA approach fails to predict most of the NMR log outputs with acceptable accuracy but can provide Coates and SDR permeabilities with R2 of mor

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Pegum, D., and M. Loeliger. "THE LANDER TROUGH—A CENTRAL AUSTRALIAN FRONTIER EXPLORATION AREA." APPEA Journal 30, no. 1 (1990): 128. http://dx.doi.org/10.1071/aj89007.

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The Lander Trough is an almost unexplored area of 30 000 square kilometres in the central western Northern Territory. It has very similar stratigraphy and structural features to the nearby Amadeus, Ngalia and southern Georgina Basins. They all contain fluvio-deltaic to marine sediments of Late Proterozoic to Carboniferous age and were subjected to deformation during several major periods of folding and overthrusting. They are remnants of one depositional basin which covered much of Northern Australia in the Late Proterozoic and Early Palaeozoic Eras. Producing oil and gas fields occur in the A

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Allen, J., and M. Williamson. "LEGAL AND TAXATION IMPLICATIONS FOR THE ACQUISITION AND DISPOSAL OF OFFSHORE PETROLEUM PRODUCTION AND EXPLORATION TENEMENTS—A PRACTICAL VIEW AND UPDATE." APPEA Journal 26, no. 1 (1986): 7. http://dx.doi.org/10.1071/aj85001.

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The administrative aspects of petroleum mining and exploration companies have become more complex of recent years. One area where this is particularly so is in relation to the livelihood of the industry, i.e. access to tenements.While exploration and development activity onshore has hotted up in particular, offshore activity has been fervent but limited largely to bringing into production fields on the North West Shelf, at Jabiru and new areas in Bass Strait. Generally it is held that the likelihood for discoveries of large fields will be offshore Australia rather than onshore and that present

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Lavin, C. J. "A REVIEW OF THE PROSPECTIVITY OF THE CRAYFISH GROUP IN THE VICTORIAN OTWAY BASIN." APPEA Journal 37, no. 1 (1997): 232. http://dx.doi.org/10.1071/aj96014.

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One of two major play fairways investigated by explorationists in the Otway Basin is the Crayfish Group system. This Tithonian-Barremian aged succession of syn-rift, continental siliciclastics was deposited in gra- ben distributed across the basin. All of the elements of a prospective petroleum province are present: lacustrine source rocks, high-quality quartzose sandstone reservoirs, and thick regional seals that are structured by both syn and post-rift tectonic events setting up a variety of play types.There has been a resurgence of drilling of Crayfish Group prospects in South Australia in

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O'Brien, Geoff, Monica Campi, and Graeme Bethune. "2013 PESA production and development review." APPEA Journal 54, no. 1 (2014): 451. http://dx.doi.org/10.1071/aj13044.

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The boom in Australian oil and gas development continued in 2013, with record overall investment of $60 billion. This investment resulted from spending on the seven LNG projects under development, together with that on numerous other oil and gas developments. These projects are expected to collectively contribute up to 665 million barrels of oil equivalent (MMboe) to Australia’s oil and gas production, which totaled 513.8 MMboe in 2013. LNG, presently Australia’s seventh largest export, is likely to soon rival the nation’s largest export, iron ore. By the end of 2013, three of the LNG projects

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Xia, Jinzhu. "Development planning of deepwater gas fields: the application of floating production platforms." APPEA Journal 54, no. 2 (2014): 512. http://dx.doi.org/10.1071/aj13085.

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Producing North West Australia (NWA) deepwater hydrocarbon reserves, particularly gas reserves to LNG plants, poses unique challenges. These include extreme metocean conditions, unique geotechnical conditions, long distances to infrastructure and LNG plants, as well as high reliability/availability of supply. This extended abstract addresses important technical, commercial, and regulatory factors that drive the field development planning, including the selection of suitable production facilities for these deepwater hydrocarbon developments off NWA. While all-subsea developments have been an in

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Belgarde, Catherine, Gianreto Manatschal, Nick Kusznir, Sonia Scarselli, and Michal Ruder. "Rift processes in the Westralian Superbasin, North West Shelf, Australia: insights from 2D deep reflection seismic interpretation and potential fields modelling." APPEA Journal 55, no. 2 (2015): 400. http://dx.doi.org/10.1071/aj14035.

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Acquisition of long-offset (8–10 km), long-record length (12–18 sec), 2D reflection seismic and ship-borne potential fields data (WestraliaSpan by Ion/GXT and New Dawn by PGS) on the North West Shelf of Australia provide the opportunity to study rift processes in the context of modern models for rifted margins (Manatschal, 2004). Basement and Moho surfaces were interpreted on seismic reflection data. Refraction models from Geoscience Australia constrain Moho depth and initial densities for gravity modelling through standard velocity-density transformation. 2D joint inversion of seismic reflect

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