Journal articles on the topic 'Petroleum refineries South Australia'
To see the other types of publications on this topic, follow the link: Petroleum refineries South Australia.
Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles
Consult the top 50 journal articles for your research on the topic 'Petroleum refineries South Australia.'
Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.
You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.
Browse journal articles on a wide variety of disciplines and organise your bibliography correctly.
1
Murray, J. H., and E. A. Burns. "GREENHOUSE GAS ISSUES—ONE FOR THE AUSTRALIAN TAXATION OFFICE?" APPEA Journal 45, no. 1 (2005): 623. http://dx.doi.org/10.1071/aj04046.
Full textAbstract:
In the 21st century we are constantly bombarded with issues on the need to do more to protect the environment and deal with greenhouse gas issues. The petroleum industry world-wide has come under fire for the emissions produced as a by-product of the petroleum refining industry and all primary producers and refiners must develop strategies to reduce atmospheric carbon dioxide emissions. While it is probably fair to say Australia’s appetite for production and consumption of natural gas or LNG is much more environmentally friendly than the days of fossil fuel sources such as coal, there is still a long way to go to minimise emissions in the industry.Global oil and gas companies operating in Australia are leading the way to develop ways to reduce greenhouse emissions. Two examples are Gorgon joint venture plans for carbon dioxide sequestration for its gas development project and perhaps BHP Billiton’s comments that it sees potential for similar sequestration into coal seams onshore Australia in Queensland, South Australia or New South Wales.The costs of projects to re-use or re-inject or sequestrate greenhouse gases are likely to be significant. But are these operating costs of the taxpaying entities in question and would they qualify for tax relief for income tax or petroleum resource rent tax purposes? This paper looks at some of the projects now underway in Australia to reduce greenhouse emissions in the petroleum sector and assesses whether the type of costs likely to be incurred in such projects might qualify for tax relief under existing legislation.
2
Kayal, S. I., and D. W. Connell. "Polycyclic Aromatic Hydrocarbons (PAHs) in Sediments of the Brisbane River (Australia) – Preliminary Results." Water Science and Technology 21, no. 2 (February 1, 1989): 161–65. http://dx.doi.org/10.2166/wst.1989.0044.
Full textAbstract:
Results of the analysis of twenty-three composite sediment samples revealed that PAHs are widely distributed in the Brisbane River estuary. Mean concentrations for individual compounds, on a dry weight basis, ranged from 0.03 µg/g for dibenz [ah] anthracene to 2.34 µg/g for fluoranthene. Observed PAH assemblages were rich in compounds having pyrolytic origins. However, the presence of petroleum derived compounds was indicative of the importance of petroleum as a PAH source in the estuary. Petroleum refineries, a coal loading terminal and a major treated sewage outfall located at the mouth were not indicated as major contributing sources of PAH pollution in the estuary.
3
Frears, R. "PETROLEUM EXPLORATION AND EVELOPMENT IN SOUTH AUSTRALIA." APPEA Journal 26, no. 2 (1986): 77. http://dx.doi.org/10.1071/aj85055.
Full text
4
Winters, Jeffrey. "A Case of the Vapors." Mechanical Engineering 126, no. 12 (December 1, 2004): 28–31. http://dx.doi.org/10.1115/1.2004-dec-1.
Full textAbstract:
With domestic refining capacity falling behind domestic demand, imports have taken on a new role: smoothing out any mismatches between gasoline supply and demand. Gasoline is sold on a worldwide spot market, and international refiners know that every gallon of gasoline will be bought by someone, somewhere. Some 40 percent of American gas imports now come from Western Europe. European refiners are looking to solve this problem by switching refining technologies. Hydrocracking, which is a high-pressure process that relies on hydrogen to saturate various products, will enable them to make more diesel from a given barrel of petroleum, and less gasoline. The change in American fuel standards has tilted the playing field for would-be exporters. The reduction in sulfur content has taken many refineries in South America out of the running as suppliers of gasoline to the United States. Until these refineries make the necessary upgrade, imports may be restricted to advanced, First World refineries, such as Total’s and Irving’s facilities. The EIA projects that Western Europe will remain a dominant exporter of gasoline to the United States for at least another decade due to its high-tech refineries and its proximity to East Coast ports.
5
Popovic, Zoran, Ivan Soucek, Nickolay Ostrovskii, and Ozren Ocic. "Whether integrating refining and petrochemical business can provide opportunities for development of petrochemical industry in Serbia." Chemical Industry 70, no. 3 (2016): 307–18. http://dx.doi.org/10.2298/hemind150122037p.
Full textAbstract:
Since the beginning of 90s of last century both the petroleum industry and petrochemical industry have operated in difficult circumstances. In particularly, margins of petroleum and petrochemical industry were exacerbated during global economic crisis in 2008-2009 years. At that time, as one option that could be the solution, the global analysts had started to more intense investigate the benefits of Refining-Petrochemical Integration. Shortly afterwards, more and more petroleum refineries and petrochemical manufacturers began to see the future in this kind of operational, managerial, marketing and commercial connection. This paper evaluates, in particular, the achieved level of integration of refinery and petrochemical businesses in Central and South-Eastern Europe. And specifically, the paper identifies current capabilities and future chances of linking this kind of integration between Serbian refining and petrochemical players. The viability of integration between possible actors and benefits of every single refining-petrochemical interface in Serbia depend on many factors, and therefore each integrated system is unique and requires prior serious Cost Benefit Analysis.
6
Laws, R. A., T. Aust, and M. Malavazos. "ENVIRONMENTAL REGULATION OF THE UPSTREAM PETROLEUM INDUSTRY IN SOUTH AUSTRALIA." APPEA Journal 42, no. 1 (2002): 683. http://dx.doi.org/10.1071/aj01045.
Full textAbstract:
South Australia has adopted a regulatory framework for the upstream petroleum industry within which environmental objectives are established through a consultative process. A principal focus of the new regime is the building of community confidence in the environmental performance of the industry and the capability of its regulator. Without such confidence, restrictions on access to land can be expected to grow. Denial of access will result in resources lying undiscovered and undeveloped to the economic detriment of the industry and the community.The development of the new legislative framework was underpinned by modern regulatory principles and practices with particular regard to applying the principles of certainty, openness, transparency, flexibility, practicability and efficiency. Transparency and consultative processes were considered particularly important in addressing concerns of conflict of interest and the risk of regulator capture.The new Act provides that no activity can occur unless it is covered by a statement of environmental objectives (SEO), developed on the basis of an environmental impact report (EIR). SEOs also contain the methodology by which compliance with achievement of objectives is assessed. Once an SEO is in place, it can be used throughout the industry for like activities. Compliance costs for both government and industry will be reduced as a result. Approval time frames and the potential for delays will also be significantly improved. SEOs are now in place for all normal Cooper and Otway Basin seismic, drilling, pipelining and production activities, although some are in interim form and are under review.Public consultation on the EIR and draft SEO is undertaken for significant activities. Criteria to assist determination of the degree of significance of proposed activities have been established. Based on the degree of predicability and manageability of the likely impacts of the activity, these criteria provide a useful framework within which the necessary value judgements can be made.Consultation is confined within government for non significant activity proposals. Inter-agency agreements have been put in place to facilitate this process.Copies of all EIRs, SEOs and significance assessments are made available via the World Wide Web. Company annual licence environmental compliance reports plus summaries of results of audits by inspectors are also made public in the same way.The Act includes the concept of the enforcement pyramid in which a range of actions escalating in severity can be applied to suit any degree of non-compliance. In addition, companies who exhibit a history of compliance, plus a capacity to comply in the future, are rewarded by up to a 50% reduction in licence fees and do not need to seek approval for routine activities.
7
Hill, A. J., and A. J. Mauger. "HyLogging unconventional petroleum core from the Cooper Basin, South Australia." Australian Journal of Earth Sciences 63, no. 8 (November 16, 2016): 1087–97. http://dx.doi.org/10.1080/08120099.2016.1261369.
Full text
8
Al-Mazidi, Salah M., and Omar Samhan. "OIL SPILL INCIDENTS AND DISPERSANT APPLICATIONS IN KUWAIT." International Oil Spill Conference Proceedings 1987, no. 1 (April 1, 1987): 247–53. http://dx.doi.org/10.7901/2169-3358-1987-1-247.
Full textAbstract:
ABSTRACT Since the discovery of oil in Kuwait, most oil-related activities have been located along the coastline 50 km south of Kuwait City. Other related industrial activities have been developed in this area apart from oil and petroleum products export in order to diversify the national sources of income. For these reasons, the potential for large oil spills in Kuwait's marine environment is highest along the south coast, where oil refineries and exporting facilities are located. An average of 219 barrels of oil were spilled annually between 1979 and 1985, and 2,100 gallons of dispersants were used in cleanup operations. The majority of incidents involved less than 5 barrels of oil and 500 gallons of dispersants. Incidents involving more than 100 barrels of oil and 5,000 gallons of dispersants were confined to the Sea Island and Mina Al-Ahmadi North and South Piers. This distribution undoubtedly affects the concentration of petroleum residues in various components of the marine environment, resulting in an increase in tar ball density along this coast, reaching a maximum at Ras Az-Zor, and significantly higher levels of vanadium and petroleum hydrocarbons in sediments and oysters collected south of Mina Al-Ahmadi. The objective of this paper is to report on the number, volume, and frequency distribution of oil spill incidents in Kuwait and the usage of dispersants in cleanup operations. Vanadium and petroleum hydrocarbon concentrations also are described as is the sensitivity of the southern coastal environment to oil spills. Recommendations have been made on how to conduct cleanup operations for any future oil spill incidents along the southern shoreline of Kuwait.
9
Jury, M. "AN AIRCRAFT OBSERVED THERMAL INTERNAL BOUNDARY LAYER ALONG THE CAPE SOUTH COAST." Clean Air Journal 8, no. 1 (June 3, 1990): 6–8. http://dx.doi.org/10.17159/caj/1990/8/1.7192.
Full textAbstract:
Aircraft observations offer a unique meteorological perspective of coastal internal boundary layers along the Cape south coast. One case study near the Gourits River mouth on 22 June 1989 is analysed using aircraft-derived wind, temperature and turbulence data collected every 800 m over a 25 km cross section. A weak coastal low pressure cell imposed a shallow easterly flow and weather conditions were stable and humid. The speed of surface easterly winds halved from the coast to the river under the influence of surface friction. Surface temperatures, measured by an infrared sensor, increased from ITC at the sea to 250C over the River valley. Upward sensible heat fluxes caused a westward tilted thermal internal boundary layer in the first 100 m. Convergence and river channelling forced the thermal internal boundary layer to become vertically aligned above 100 m. Vertical velocity fluctuations were more vigourous in the internal boundary layer. Implications for the dispersion of air pollutants from proposed petroleum refineries and nuclear power stations ate discussed.
10
Mazourenko, E. V. "VALUING THE ENVIRONMENTAL COSTS OF VEGETATION REMOVAL AND ECOSYSTEM DISTURBANCE ASSOCIATED WITH PETROLEUM OPERATIONS, COOPER BASIN, SOUTH AUSTRALIA." APPEA Journal 46, no. 1 (2006): 625. http://dx.doi.org/10.1071/aj05043.
Full textAbstract:
This paper describes the results of a small-scale study that looked at an alternative way of managing the environmental impacts of petroleum developments. The study was based on a contention that an application of the contingent valuation method (CVM) in the context of petroleum developments might assist the petroleum industry in achieving the goals of ecologically sustainable development (ESD), while contributing to the change of the community’s attitude towards the industry. CVM, based on direct community involvement in determining the environmental costs of the native vegetation removal associated with the petroleum developments in the South Australian Cooper Basin, was applied to the selected ‘groups of interest’. The collected data were analysed and discussed in light of the feasibility of a full-scale CVM study, and its potential practical value both for the petroleum companies operating in the Cooper Basin and the regulatory state government authorities. The results of this study showed that the application of CVM in the context of the petroleum industry might yield significant benefits for the industry in terms of ESD. In the long term, it may assist in changing the community’s perception of the petroleum industry. This approach does not intend to contradict, but to complement, the current environmental management practices of the petroleum developers.
11
Bernecker, Thomas. "Petroleum geological summary of the 2012 offshore acreage release for petroleum exploration." APPEA Journal 52, no. 1 (2012): 7. http://dx.doi.org/10.1071/aj11002.
Full textAbstract:
The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. In 2012, 27 areas in nine offshore basins are being released for work program bidding. Closing dates for bid submissions are either six or twelve months after the release date, i.e. 8 November 2012 or 9 May 2013, depending on the exploration status in these areas and on data availability. As was the case in 2011, this year’s Release again covers a total offshore area of about 200,000 km2. The Release Areas are located in Commonwealth waters offshore Northern Territory, Western Australia, South Australia, Victoria and Tasmania (Fig. 1). Areas on the North West Shelf feature prominently again and include under-explored shallow water areas in the Arafura and Money Shoal basins and rank frontier deep water areas in the outer Browse and Roebuck basins as well as on the outer Exmouth Plateau. Following the recent uptake of exploration permits in the Bight Basin (Ceduna and Duntroon sub-basins), Australia’s southern margin is well represented in the 2012 Acreage Release. Three new areas in the Ceduna Sub-basin, four areas in the Otway Basin, one large area in the Sorell Basin and two areas in the eastern Gippsland Basin are on offer. Multiple industry nominations for this Acreage Release were received, confirming the healthy status of exploration activity in Australia. The Australian government continues to support these activities by providing free access to a wealth of geological and geophysical data.
12
Saeed, Talat, Hosny Khordagui, and Amal Al-Bloushi. "Distribution of Volatile Liquid Hydrocarbons in the Vicinity of Power/Desalination Plants in Kuwait." Water Science and Technology 40, no. 7 (October 1, 1999): 99–107. http://dx.doi.org/10.2166/wst.1999.0338.
Full textAbstract:
Volatile liquid hydrocarbons (VLHs) represent some 40% of crude oil and are considered to be the most toxic compounds of petroleum other than the carcinogenic polycyclic aromatic hydrocarbons. The distribution of these compounds in Kuwait's coastal waters in the vicinity and at the inlets of power plants was assessed. About 200 samples were collected from selected sampling stations over the four seasons. The VLHs in the samples were concentrated using Grob's closed-loop technique and analyzed by GC using FID and confirmed by GC/MS. The results showed that VLHs were ubiquitous in the coastal water of Kuwait. The detected levels (ranged from 307 to 7882 ng/l in Kuwait Bay and from 331 to 5017 ng/l in the south) were comparable to the levels found in other parts of the world and were not alarming. However, the spotty higher levels encountered gave reason for some concern. Benzenoids (originating from petroleum) predominated, representing roughly 70% of the total VLHs. The levels were relatively low at the intake of the power plant located in the Kuwait Bay (annual average 677 ng/l) while higher levels (annual average 3006 ng/l) were encountered at the intake of the plant located at the south of oil the loading terminals and refineries.
13
Bethune, Graeme. "Australian petroleum production and development 2018." APPEA Journal 59, no. 2 (2019): 482. http://dx.doi.org/10.1071/aj18285.
Full textAbstract:
This Petroleum Exploration Society of Australia review looks in detail at the trends and highlights for oil and gas production and development both onshore and offshore Australia during 2018. Total petroleum production climbed strongly for the third consecutive year, driven by LNG. A highlight is the start-up of the INPEX Ichthys project. Production is set for further growth in 2019 with the ramp-up of this project and the start-up of Shell’s Prelude floating LNG project. Prelude and Ichthys are the last projects to be commissioned in a wave of seven new LNG projects that are making Australia the world’s largest LNG exporter and a crucial supplier of gas to Asia, including the largest source of LNG for Japan and China and the second-largest source for South Korea. By contrast, Australian oil production continued to fall rapidly and is now easily surpassed by rising condensate production from new LNG projects. There were stark contrasts between domestic gas on the west and east coasts. On the west coast, prices remain low and supply relatively plentiful. The east coast domestic market was tighter and LNG producers responded by diverting gas supplies to the domestic market. This paper canvasses these trends and makes conclusions about the condition of the oil and gas industry in Australia. This paper relies primarily on production and reserves data compiled by EnergyQuest and published in its EnergyQuarterly reports.
14
Bernecker, Thomas, Steve Abbott, George Bernardel, Megan Lech, Ryan Owens, Tegan Smith, and Jennifer Totterdell. "The 2017 offshore acreage release areas: petroleum geological overview." APPEA Journal 57, no. 2 (2017): 304. http://dx.doi.org/10.1071/aj16029.
Full textAbstract:
In 2017, 21 new offshore petroleum exploration areas have been released. The majority of the areas are located along the North West Shelf spanning the Westralian Superbasin from the Bonaparte Basin in the north-east to the Northern Carnarvon Basin in the south-west. New areas have been released in offshore south-eastern Australia with new opportunities provided in the Otway, Bass and Gippsland basins. Two large areas in the northern Perth Basin, an offshore frontier, complete the 2017 Acreage Release. All Release Areas are supported by industry nominations and one new cash bid area has been offered in the Dampier Sub-basin. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available as part of the agency’s regional petroleum geological studies. A new regional 2D seismic survey was acquired in the Houtman Sub-basin of the Perth Basin, forming the basis of the latest prospectivity study carried out by Geoscience Australia. The results of the study are presented in the technical program of the 2017 APPEA conference. A wealth of seismic and well data, submitted under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGSSA) are made available through the National Offshore Petroleum Information Management System (NOPIMS). Additional datasets are accessible through Geoscience Australia’s data repository.
15
Henson, Paul, David Robinson, Lidena Carr, Dianne S. Edwards, Susannah K. MacFarlane, Amber J. M. Jarrett, and Adam H. E. Bailey. "Exploring for the Future—a new oil and gas frontier in northern Australia." APPEA Journal 60, no. 2 (2020): 703. http://dx.doi.org/10.1071/aj19080.
Full textAbstract:
Exploring for the Future (EFTF) is a four-year, AU$100.5 million initiative from the Australian Government conducted by Geoscience Australia in partnership with state and Northern Territory government agencies, CSIRO and universities to provide new geoscientific datasets for frontier regions. As part of this program, Geoscience Australia acquired two new seismic surveys that collectively extend across the South Nicholson Basin (L120 South Nicholson seismic line) and into the Beetaloo Sub-basin of the McArthur Basin (L212 Barkly seismic line). Interpretation of the seismic has resulted in the discovery of new basins that both contain a significant section of presumed Proterozoic strata. Integration of the seismic results with petroleum systems geochemistry, structural analyses, geochronology, rock properties and a petroleum systems model has expanded the knowledge of the region for energy exploration. These datasets are available through Geoscience Australia’s newly developed Data Discovery Portal: an online platform delivering digital geoscientific information, including seismic locations and cross-section images, and field site and well based sample data. Specifically for the EFTF energy project, a petroleum systems framework with supporting organic geochemical data has been built to access source rock, crude oil and natural gas datasets via interactive maps, graphs and analytical tools that enable the user to gain a better and faster understanding of a basin’s petroleum prospectivity.
16
Carr, Lidena, Russell Korsch, and Tehani Palu. "Australia's onshore basin inventory: volume I." APPEA Journal 56, no. 2 (2016): 591. http://dx.doi.org/10.1071/aj15097.
Full textAbstract:
Following the publication of Geoscience Australia Record 2014/09: Petroleum geology inventory of Australia’s offshore frontier basins by Totterdell et al (2014), the onshore petroleum section of Geoscience Australia embarked on a similar project for the onshore Australian basins. Volume I of this publication series contains inventories of the McArthur, South Nicholson, Georgina, Amadeus, Warburton, Wiso, Galilee, and Cooper basins. A comprehensive review of the geology, petroleum systems, exploration status, and data coverage for these eight Australian onshore basins was conducted, based on the results of Geoscience Australia’s precompetitive data programs, industry exploration results, and the geoscience literature. A petroleum prospectivity ranking was assigned to each basin, based on evidence for the existence of an active petroleum system. The availability of data and level of knowledge in each area was reflected in a confidence rating for that ranking. This extended abstract summarises the rankings assigned to each of these eight basins, and describes the type of information available for each of these basins in the publically available report by Carr et al (2016), available on the Geoscience Australia website. The record allocated a high prospectivity rating for the Amadeus and Cooper basins, a moderate rating for the Galilee, McArthur and Georgina basins, and a low rating for the South Nicholson, Warburton and Wiso basins. The record lists how best to access data for each basin, provides an assessment of issues and unanswered questions, and recommends future work directions to lessen the risk of these basins in terms of their petroleum prospectivity. Work is in progress to compile inventories on the next series of onshore basins.
17
Morozow, O. "ACCESS TO LAND FOR EXPLORATION — THE ADOPTION OF MULTIPLE LAND USE PRINCIPLES IN SOUTH AUSTRALIA." APPEA Journal 28, no. 1 (1988): 325. http://dx.doi.org/10.1071/aj87025.
Full textAbstract:
The continued access to land for exploration by the petroleum and mineral industries in Australia has been increasingly impeded by State and Commonwealth legislation aimed at dedicating Crown Land for single land uses.In September 1986, South Australia's Minister for Mines and Energy, Ron Payne, announced a Cabinet decision for 'a package of recommendations designed to foster multiple land-use concepts and to ensure that no land is alienated from exploration without careful consideration of the sub-surface mineral/petroleum potential, relevant economic factors and the existing and potential sub-surface rights'.In this one innovative and potentially far-reaching move, the South Australian Government has:provided a framework to reconcile conflicting interests;indicated a willingness to listen and act upon the expressed legitimate concerns of industries of vital economic importance to the State;made it necessary for the proponents of reserve areas such as National Parks to be more accountable and to provide balanced, scientific substantiation;indicated its intention to make legislative changes to allow for the adoption of multiple land-use principles; andredressed the imbalance where, in the words of the Minister, 'Legislation providing for Aboriginal land rights, the creation of national and conservation parks, and State Government heritage areas have, to varying degrees, created unforeseen consequences for the resources industry'.The first practical test of this new Government policy is the proposed declaration of the Innamincka Regional Reserve, currently a 14 000 sq km pastoral lease within some of the most productive areas of PELs 5 & 6 held jointly by Santos Ltd. and Delhi Petroleum Pty. Ltd.It is intended that this new form of reserve will allow for the protection of specific areas of environmental sensitivity and of cultural, scientific and historic value, while still allowing for the continuation of pastoral, tourist and petroleum exploration/ production activity within the major part of the reserve area.
18
Schofield, Lisa. "2018 offshore petroleum exploration acreage release." APPEA Journal 58, no. 2 (2018): 465. http://dx.doi.org/10.1071/aj17103.
Full textAbstract:
The Australian Government’s 2018 offshore petroleum exploration acreage release was announced by the Commonwealth Minister for Resources and Northern Australia, Senator the Hon Matthew Canavan at the 2018 APPEA conference. This paper provides insights into the processes that the Australian Government has undertaken to select the final release areas and goes into detail on the ongoing petroleum related activities of the Department of Industry, Innovation and Science (the Department). The annual acreage release is a central component of ensuring ongoing, sustainable and responsible investment in Australia’s offshore petroleum sector. The annual acreage release remains the primary mechanism for securing investment in offshore oil and gas exploration in areas of known petroleum potential and new geological frontiers. Continued exploration for oil and gas in Commonwealth waters is a central component of ensuring Australia’s future energy security. Australia’s well established and independent environmental regulator, NOPSEMA (the National Offshore Petroleum Safety and Environmental Management Authority), ensures all petroleum activities in Commonwealth waters are performed safely and in an environmentally responsible manner. Combined with NOPTA’s (National Offshore Petroleum Titles Administrator) leading practice titles administration, Australia remains an attractive investment destination while offering industry leading environmental protections and ensuring safe working conditions industry-wide. Australia offers investors access to data, secure tenure, a stable economic environment and a well-established transparent regulatory system for offshore petroleum activities. A key driver for sustainable activity in Australia is the acceptance of multiple use access to Australia’s marine resources. Recognising this, the department consults with a range of stakeholders on the areas it proposes to release for petroleum exploration. This consultation process provides an opportunity for all interested parties to provide comments and feedback on the areas proposed and in particular highlight how interested parties or the areas might be impacted by exploration activities. The 21 areas in the 2018 offshore petroleum exploration acreage release are located in the offshore areas of Western Australia, South Australia, Victoria and the Ashmore-Cartier Islands. These areas will enable the next wave of investment in the Australian resources sector, and the prospect of new oil, gas and condensate production.
19
Bernecker, Tom. "The 2010 Australian offshore release for petroleum exploration." APPEA Journal 50, no. 1 (2010): 5. http://dx.doi.org/10.1071/aj09002.
Full textAbstract:
The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. In 2010, thirty-one areas in five offshore basins are being released for work program bidding. Closing dates for bid submissions are either six or twelve months after the release date—i.e. 11 November 2010 and 12 May 2011—depending on the exploration status in these areas and on data availability. The 2010 release areas are located in Commonwealth waters offshore Northern Territory, Western Australia and South Australia, comprising intensively explored areas close to existing production as well as new frontiers. The Westralian Superbasin along the North West Shelf continues to feature prominently, and is complimented by a new frontier area in offshore SW Australia (Mentelle Basin), as well as two areas in the Ceduna/Duntroon sub-basins in the eastern part of the Bight Basin. The Bonaparte Basin is represented by three areas in the Petrel Sub-basin and two areas in the Vulcan Sub-basin. Further southwest, four large areas are being released in the outer Roebuck Basin—a significantly under-explored region. This year, the Carnarvon Basin provides 16 release areas of which three are located in the Beagle Sub-basin, five in the Dampier Sub-basin, five in the Barrow Sub-basin, three on the Exmouth Plateau and three in the Exmouth Sub-basin. The largest singular release area covers much of the Mentelle Basin in offshore SW Australia, and two areas are available in the Ceduna and Duntroon sub-basins as part of South Australia’s easternmost section of the Bight Basin. The 2010 Offshore Acreage Release offers a wide variety of block sizes in shallow as well as deep water environments. Area selection has been undertaken in consultation with industry, the States and the Northern Territory. As part of Geoscience Australia’s Offshore Energy Security Program, new data has been acquired in offshore frontier regions parts of which are being published on the Mentelle Basin (Borissova et al, this volume).
20
Plummer, Phillip S. "The Neoproterozoic Gillen Formation, Amadeus Basin, central Australia: an intra-salt petroleum system and viable exploration target?" APPEA Journal 61, no. 1 (2021): 236. http://dx.doi.org/10.1071/aj20040.
Full textAbstract:
The Gillen Formation, the basal component of the lower Neoproterozoic Bitter Springs Group, occurs throughout the Amadeus Basin of central Australia and comprises a basal sequence of black shales and stromatolitic dolostones overlain by an evaporitic sequence of a thick halite sandwiched between two anhydrite/dolomite units. These Gillen lithologies include potential source, reservoir and seal units for petroleum, suggesting an analogy could be drawn with the prolific evaporitic Ara Group Petroleum System of South Oman. Although well data penetrating the Gillen Formation are very limited, organic-rich shales have been penetrated in both the north and south of the basin, while both well and seismic data indicate the ubiquitous presence of sealing evaporites across the basin. The Ara Group Petroleum System spans the Neoproterozoic–Cambrian boundary and is blessed with carbonate reservoirs composed of metazoan ‘reefs’ comprising Cloudina and Namacalathus, which provide an open framework porosity approaching 50%. By contrast, the Gillen Formation was deposited during the Tonian Period of the Neoproterozoic, some 300–350 million years older than the Ara Group, and has reservoir facies limited to stromatolitic carbonates with fenestral to vuggy porosities that are typically less than 15%. Nevertheless, seismic data reveal numerous intra-evaporite opportunities within the Gillen Formation that, seismically, are virtually indistinguishable from those being exploited in South Oman, suggesting that a Gillen Intra-Salt Petroleum System is a viable exploration target throughout a majority of the Amadeus Basin.
21
Gately, D. J. "QUEENSLAND PETROLEUM ACT REVIEW AND REFORM." APPEA Journal 29, no. 1 (1989): 72. http://dx.doi.org/10.1071/aj88011.
Full textAbstract:
On 12 May 1988 amendments to the Queensland Petroleum Act of 1923 came into force. These empower the Governor- in- Council to appoint a Pipelines Tribunal to inquire into the operations of any existing or proposed pipeline. The Act now affirms the existence of the Secretary of Mines as a Corporation which can undertake all the aspects of an oil company from exploration to distribution of refined products. In particular, this corporation now has the sole right to construct and operate any pipeline in Queensland which extends beyond the boundaries of a lease. There was little or no dialogue with industry prior to the proclamation of these amendments.In comparison with the Petroleum Acts of South Australia, Western Australia and the Northern Territory, the Queensland Petroleum Act contains many areas subject to ministerial discretion or which are no longer relevant to present- day administrative practices. The Queensland Government's proposal to issue a green paper discussing amendments to the Act, based on submissions from interested parties, is welcomed since it is in the interests of management of the exploratory oil industry to strive for uniformity of administration in each state.
22
Grosjean, Emmanuelle, Dianne S. Edwards, Nadege Rollet, Christopher J. Boreham, Duy Nguyen, and Tamara Buckler. "Geochemical evidence for a new Triassic petroleum system on the western margin of Australia." APPEA Journal 61, no. 2 (2021): 616. http://dx.doi.org/10.1071/aj20027.
Full textAbstract:
The unexpected discovery of oil in Triassic sedimentary rocks of the Phoenix South 1 well on Australia’s North West Shelf (NWS) has catalysed exploration interest in pre-Jurassic plays in the region. Subsequent neighbouring wells Roc 1–2, Phoenix South 2–3 and Dorado 1–3 drilled between 2015 and 2019 penetrated gas and/or oil columns, with the Dorado field containing one of the largest oil resources found in Australia in three decades. This study aims to understand the source of the oils and gases of the greater Phoenix area, Bedout Sub-basin using a multiparameter geochemical approach. Isotopic analyses combined with biomarker data confirm that these fluids represent a new Triassic petroleum system on the NWS unrelated to the Lower Triassic Hovea Member petroleum system of the Perth Basin. The Bedout Sub-basin fluids were generated from source rocks deposited in paralic environments with mixed type II/III kerogen, with lagoonal organofacies exhibiting excellent liquids potential. The Roc 1–2 gases and the Phoenix South 1 oil are likely sourced proximally by Lower–Middle Triassic TR10–TR15 sequences. Loss of gas within the Phoenix South 1 fluid due to potential trap breach has resulted in the formation of in-place oil. These discoveries are testament to new hydrocarbon plays within the Lower–Middle Triassic succession on the NWS.
23
Mazzone, J. A. "SCHOOL-INDUSTRY LINKS: A VALUE ADDING PROCESS." APPEA Journal 35, no. 1 (1995): 836. http://dx.doi.org/10.1071/aj94061.
Full textAbstract:
The establishment of links between SAGASCO Resources Limited (SAGASCO) and secondary schools in the city and country regions of South Australia has provided benefits to both the petroleum industry and to the students and teachers at the schools. Links between Penola High School in the southeast of South Australia and Hamilton Secondary School in Adelaide began in 1993 and have continued to the present. Feedback from the schools has been positive and significant. The two schools have overwhelmingly endorsed the links and have benefited both in curriculum development and in gaining a glimpse of industry operations that is not found in textbooks. The benefits from the link process has also revealed a cascade effect in which students and teachers have utilised information on the petroleum industry and incorporated it into reports, publications and texts that have been further used by the schools and the community, thus enhancing the original link process. Links with schools require stronger support by the petroleum industry to meet the needs of schools and to provide balance to the often negative profile of our industry in the community both in the immediate and longer term.
24
Menpes, Sandra. "Proven and possible petroleum plays of the northern Cooper and Eromanga basins, South Australia." ASEG Extended Abstracts 2010, no. 1 (December 2010): 1–3. http://dx.doi.org/10.1081/22020586.2010.12042050.
Full text
25
Williams, M. L., A. J. Boulton, M. Hyde, A. J. Kinnear, and C. D. Cockshell. "ENVIRONMENTAL IMPACT OF SEISMIC OPERATIONS IN THE OTWAY BASIN, SOUTH AUSTRALIA." APPEA Journal 34, no. 1 (1994): 741. http://dx.doi.org/10.1071/aj93054.
Full textAbstract:
The Department of Mines and Energy, South Australia (DME) contracted Michael Williams and Associates Pty Ltd to audit the environmental management of seismic exploration operations in the South Australian Otway Basin. The audit was carried out in early 1992 and covered petroleum exploration operators and DME environmental management systems. An innovative field sampling technique was developed to compare the environmental impact of two different seismic line clearing techniques. Recovery of native vegetation as measured by vegetation structure was also quantified.The audit found DME to have a dynamic and integrated environmental management system while company systems varied in standard. Wide consultation assisted the audit process.As a result of clearing for agriculture, native vegetation covers only six per cent of the Otway Basin. With the strict limitations to broad-scale vegetation clearance since the mid-1980s and the cessation since 1991, the greatest environmental impact of seismic exploration is the clearance of native vegetation for access by seismic vehicles. Native vegetation structure and associated abiotic variables on seismic lines and adjacent control sites, were subject to a classification and ordination analysis which compared the impact of seismic lines constructed by bulldozer or Hydro-ax (industrial slasher). Post-seismic recovery rates of three different vegetation associations were also determined. This analytical technique permits the effects of seismic line clearance to be compared with the natural variability of specific vegetation associations within a region. In interpreting the results however, there is a confounding effect of line type and year as most of the more recent seismic lines were constructed using a Hydro-ax. Results indicate that Hydro-ax clearing affects vegetation structure less than bulldozing. Most Hydro-ax sites recovered within a few years whereas some sites, bulldozed as early as 1971, particularly tussock grasslands, have not yet recovered.This study provides a significant break-through in the debate about the persistence of seismic impacts on native vegetation. As a rapid preliminary assessment, sampling vegetation structure rather than floristics, provides a cost-effective audit and monitoring technique which can be used by non-specialists in a range of petroleum exploration environments. Any significant structural differences may require more detailed analysis to determine if floristic composition also differed.
26
Somerville, D. C. "Lipid content of honey bee-collected pollen from south-east Australia." Australian Journal of Experimental Agriculture 45, no. 12 (2005): 1659. http://dx.doi.org/10.1071/ea03190.
Full textAbstract:
The use of solvent extraction or petroleum spirits to extract lipids (fats) from 172 samples of honey bee-collected pollens provided a range of lipid contents from 0% for Eucalyptus macrorhyncha to 11.2% for Hypochoeris radicata. The mean for all 172 samples, representing 61 species, was 2.52%. The mean from 31 endemic species was 1.78%, whereas the mean for 30 exotic species was 4.13%. When pollens from 1 species, Echium plantagineum, were extensively surveyed, the lipid levels could be predictably estimated, falling within a range of 0.6 to 2.46% and a mean of 1.6%. A number of pollens from particular species consistently showed high levels of lipids, which were observed to be highly favoured by foraging honey bees. The pollens noted to be particularly attractive to foraging honey bees included Brassica napus (mean 7.1%), Sisymbrium officinale (mean 5.8%), Rapistrum rugosum (mean 6%) and Hypochoeris radicata (mean 7.2%).
27
Mokoena, JKJ, and PJD Lloyd. "A business model to overcome barriers to entry in the South African downstream petroleum industry." Journal of Energy in Southern Africa 16, no. 2 (May 1, 2005): 4–13. http://dx.doi.org/10.17159/2413-3051/2005/v16i2a3182.
Full textAbstract:
The South African downstream petroleum industry was in the hands of Whites and Multinational Oil Companies during the apartheid era. Many Historically Disadvantaged South Africans (HDSA’s) were excluded from the mainstream industry through, among other instruments, laws passed by the government such as the Petroleum Products Act 120 of 1977. Against this background, the newly elected democratic government instituted a policy process aimed at restructuring and transforming the petroleum industry to allow HDSA’s to enter the industry, in order to achieve sustainable presence, ownership and control of approximately a quarter of the industry by previously disadvantaged individuals. Since the introduction of this process, which culminated in the release of the White Paper on the Energy Policy of the Republic of South Africa (1998), little progress has been made towards achieving this government’s key policy objective. Instead, there is still little entry into the industry by HDSA’s, and the Black Oil Companies (BOC’s) that are in the industry continue to struggle to increase their market share. This paper discusses the possible constraints on achieving the objective, by looking at barriers that impede HDSA’s from entering the industry and BOC’s from increasing their market share significantly. There are three possible categories of barriers in the downstream petroleum industry, namely, economic barriers to entry, noneconomic barriers, and cross-sectoral barriers to entry, which are discussed in this paper. These categories of barriers prevent entry by HDSA’s into the industry and hinder BOC’s from increasing their market share. To circumvent these barriers, and in order to make progress towards achieving the government’s key policy objective of control by approximately a quarter of the HDSA’s, a black economic empowerment model was developed. This model seeks to increase the market share of the BOC’s and the presence of the HDSA’s in the industry in a sustainable way without significantly harming the multinational oil companies. It foresees Government licensing BOC’s to purchase up to 5% of the existing South African fuel demand at an Import Parity Price (IPP) that is significantly less than the Basic Fuel Price (BFP). The reason for this difference is that the BFP is based upon the supply of the totality of South Africa’s needs from elsewhere, whereas the IPP merely supplies up to 5% of South Africa’s needs, and can therefore source the product from refineries that are closer, so reducing the transport component. The impact of the loss of 5% of the internal market for petrol and diesel on the revenues of the MOC’s is less than 0.5%, because the difference between the IPP and BFP is a small fraction of the BFP.
28
Edwards, Sally, and Behnam Talebi. "New deep crustal seismic data acquisition program for NWQ's frontier petroleum basins." APPEA Journal 59, no. 2 (2019): 869. http://dx.doi.org/10.1071/aj18084.
Full textAbstract:
The Georgina and South Nicholson basins and the Isa Superbasin of North West Queensland (NWQ), represent frontier basins earmarked for examination of resource potential under the Strategic Resources Exploration Program. Little exploration has occurred for petroleum resources in these basins although a proven petroleum system exists in both the Isa Superbasin and the Georgina Basin with demonstrated flow at sub-commercial rates. To increase knowledge of the petroleum system, define the extent of the South Nicholson Basin and examine basin architecture, Geoscience Australia acquired deep (to 20-s listening time) seismic data across the South Nicholson Basin and northern Isa Superbasin area in 2017. However, this survey focused on broader structural architecture definition across the Proterozoic Isa Superbasin and South Nicholson and McArthur basins. Little is understood of the petroleum system in the southern Isa Superbasin, or even if this structure is part of the Isa Superbasin, where Proterozoic gas is inferred from mineral boreholes and oil stained Cambrian-aged carbonates exist. To increase understanding of this southern region, the Queensland Government acquired a new NWQ SEEBASE® (depth to basement) model in 2018, and will be undertaking a 2D deep seismic survey within the Camooweal region to better understand the structural architecture, sediment thicknesses and seismic characteristic of packages of this southern area. The seismic survey is centred on the Georgina Basin and will tie into the South Nicholson survey – extending knowledge further south across major structures featured in the SEEBASE® model.
29
Savage, T. M. "CRUDE OIL MARKETING DEREGULATION." APPEA Journal 28, no. 1 (1988): 366. http://dx.doi.org/10.1071/aj87031.
Full textAbstract:
The Australian Government's decision to deregulate indigenous crude oil marketing from 1 January 1988 brings to an end the period of the Government's involvement in this area of the petroleum industry. The determination of price, the development and monitoring of administrative procedures to ensure equitable allocation of indigenous crude, and the resolution of differing views between producers, refiners and marketers were all areas where Government was actively involved. While the extent of future involvement is uncertain, the policy changes put a different dimension on exploration and production efforts for all companies and on their relationship with the marketplace, both locally and overseas.The move to deregulation widens the available options for all parties - producers, refiner/ marketers and international traders. WTiile these options exist, the most probable situation in 1988 is not expected to be greatly different from that which has existed in the last couple of years. No refineries will be shut down; product imports will increase slightly but not significantly enough to affect total demand on Australian refineries. A reduced level of indigenous crude should be run to enable greater flexibility in crude/feedstock selection for optimising refinery profitability. However, at least 75 per cent of indigenous production should be continued to be absorbed within Australia with the bulk of the exports being made from Gippsland and Jabiru areas.The change in emphasis towards product excise has ensured that the Australian Government has the mechanism to sustain revenue, essentially independent of the prices obtained for indigenous crude. As such, the Government's involvement in crude oil marketing, if at all, will be significantly reduced.Factors affecting negotiations between producers and other interested parties have been explored. It is considered that, although it is highly unlikely that firm markets will have been established by early 1988, a workable set of arrangements will have been developed to ensure that crude oil production is moved. As many uncertainties will exist on the validity of these arrangements for the long term, there will be a tendency towards spot or short-term sales agreements so that the options are left open. The key pricing points are seen to be the value BP Australia is prepared to pay for Western Australia and Queensland production, at Kwinana and Brisbane respectively, and the prices being obtained by Esso/BHP for Gippsland crude in the export market.
30
Muzzammel, Raheel, and Rabia Arshad. "Comprehensive analysis and design of furnace oil-based power station using ETAP." International Journal of Applied Power Engineering (IJAPE) 11, no. 1 (March 1, 2022): 33. http://dx.doi.org/10.11591/ijape.v11.i1.pp33-51.
Full textAbstract:
High standards of living are linked with the availability of energy. Therefore, there is always a requirement to modify existing power generating systems or to add new systems to fulfill the increasing demands of energy. It is becoming a core issue in the South Asian region so that at least current standards of living could be maintained by controlling growing energy rates and shortening the availability of conventional sources. Furnace oil is a residue obtained in the process of distillation of crude oil in the petroleum industry. This furnace oil is applicable for power generation plants allied with the petroleum industry so that residue of oil refineries could be utilized. In this research, a furnace oil-based power plant is designed in electrical transient and analysis program (ETAP) software. Moreover, steady-state and transient analysis of the proposed design of the power plant are conducted to increase practical viability of model. Load flow is analyzed to depict the performance of the power plant model under load conditions. This model is further tested under the motor starting event to analyze the current drawn by the motor. This event helps to determine the permissible values of protective equipment installed in power plants. In the last, economic dispatch analysis is conducted to find the relative minima of generation cost of furnace oil-based power plant with respect to coal and hydel generation
31
Nelson, E., R. Hillis, M. Sandiford, S. Reynolds, and S. Mildren. "PRESENT-DAY STATE-OF-STRESS OF SOUTHEAST AUSTRALIA." APPEA Journal 46, no. 1 (2006): 283. http://dx.doi.org/10.1071/aj05016.
Full textAbstract:
There have been several studies, both published and unpublished, of the present-day state-of-stress of southeast Australia that address a variety of geomechanical issues related to the petroleum industry. This paper combines present-day stress data from those studies with new data to provide an overview of the present-day state-of-stress from the Otway Basin to the Gippsland Basin. This overview provides valuable baseline data for further geomechanical studies in southeast Australia and helps explain the regional controls on the state-of-stress in the area.Analysis of existing and new data from petroleum wells reveals broadly northwest–southeast oriented, maximum horizontal stress with an anticlockwise rotation of about 15° from the Otway Basin to the Gippsland Basin. A general increase in minimum horizontal stress magnitude from the Otway Basin towards the Gippsland Basin is also observed. The present-day state-of-stress has been interpreted as strike-slip in the South Australian (SA) Otway Basin, strike-slip trending towards reverse in the Victorian Otway Basin and borderline strike-slip/reverse in the Gippsland Basin. The present-day stress states and the orientation of the maximum horizontal stress are consistent with previously published earthquake focal mechanism solutions and the neotectonic record for the region. The consistency between measured present-day stress in the basement (from focal mechanism solutions) and the sedimentary basin cover (from petroleum well data) suggests a dominantly tectonic far-field control on the present-day stress distribution of southeast Australia. The rotation of the maximum horizontal stress and the increase in magnitude of the minimum horizontal stress from west to east across southeast Australia may be due to the relative proximity of the New Zealand segment of the plate boundary.
32
Moore, R. K., and R. M. Willcocks. "SOME COMMERCIAL ASPECTS OF PETROLEUM EXPLORATION AND MINING." APPEA Journal 25, no. 1 (1985): 143. http://dx.doi.org/10.1071/aj84014.
Full textAbstract:
The petroleum industry in Australia is at the centre of a web of complex laws. In addition to the legislation under which petroleum exploration and production tenements are granted there is a multiplicity of statutes and regulations, Commonwealth and State, which have a direct bearing on the conduct of those involved in exploring for or exploiting Australia's petroleum reserves. For example, the level of participation by foreigners is governed by the Commonwealth Foreign Investment Guidelines and the Foreign Takeovers Act 1975; the Commonwealth has control over the export of petroleum under the Customs (Prohibited Exports) Regulations and domestic markets are subject to the operation of the Crude Oil Allocation Scheme. The Commonwealth continues to have the right to regulate the transfer of funds to and from Australia under the Banking (Foreign Exchange) Regulations. Certain States such as South Australia and New South Wales have their own foreign investment guidelines.Not only this, there are revenue laws which govern very much the way in which petroleum projects are organised, interests transferred and otherwise dealt with and finance made available, such as State stamp duty legislation, Commonwealth income tax laws, and Commonwealth legislation imposing registration fees on dealings in exploration permits and production licences. A new tax, Resource Rent Tax, is to be introduced.Then there are laws which have an indirect bearing on petroleum activities such as the Companies Code which, in addition to governing the administration and organisation of companies, controls the way funds can be raised.The statutory and regulatory framework is only part of the picture. The rights and obligations of participants in petroleum projects as between themselves are almost always set out in a joint venture or joint operating agreement, the combination between the participants being known as an unincorporated joint venture. This form of business organisation is not a partnership; it is not the creature of legislation. Indeed it has been rarely referred to in Acts of Parliament. Problems arising under the joint venture agreement will be considered against the backdrop of the general law which unfortunately has seldom been called upon to resolve disputes between participants in joint ventures. An illustration of one of these rare instances is Brian Pty Ltd v United Dominions Corporation Ltd (1983), where the New South Wales Court of Appeal considered the fiduciary relationship of joint venturers.Despite this legislative and regulatory' backdrop and the uncertainties as to the true effect of joint venture agreements, the industry up until quite recently has survived with little litigation. This is no longer the case. Recent and pending litigation shows that there is no reluctance on the part of participants to take their disputes to court, often at great expense and with unfortunate results for previously close relationships. It must now be said that money spent to achieve proper and clear agreement on organisational and legal matters at the earliest stage of a project is money just as well spent as that on drilling and other operational activities.
33
Willcocks, R. M. "COMMERCIAL ASPECTS OF UNDERGROUND GAS STORAGE IN AUSTRALIA." APPEA Journal 27, no. 1 (1987): 28. http://dx.doi.org/10.1071/aj86003.
Full textAbstract:
Underground gas storage is becoming increasingly important in Australia with the discovery of significant gas reserves, mostly in places distant from the expanding markets for gas.Gas has been stored in the offshore Barracouta Field since 1971 and storage projects are either being considered or underway in New South Wales, South Australia, Western Australia and the Northern Territory.Although not a great deal of attention has been paid to the legal, tax and administrative aspects of underground gas storage, the position is likely to change the more it becomes apparent that such storage is commercially and technically viable.The applicable legal regime will depend on the location of the storage. Offshore gas storage on the continental shelf beyond the coastal waters of a state is subject to Commonwealth jurisdiction. In state coastal waters, it is subject to state laws. Onshore, it is subject to the jurisdiction of the state or territory in which the storage occurs.Offshore beyond state coastal waters the Australian government has sovereign rights over the continental shelf for the purposes of exploring the continental shelf and exploiting its natural resources.There are a number of legal uncertainties which arise from gas storage which will be of concern to financiers as well as gas storers. With certain exceptions, there is doubt as to ownership of stored gas, and the right to inject and store gas. The right of withdrawal however would appear to fall under the right which normally exists under a production lease to 'mine' petroleum, or to conduct 'petroleum mining operations'. Except in Victoria, and to a significantly lesser extent South Australia, there is very little legislative guidance on the topic and related issues.The question whether stored gas is trading stock is the subject of Income Tax Ruling 2190 of 10 September 1985. This puts at rest, in practical terms, in any event, some of the doubts which existed as to the characterisation for income tax purposes of gas stored near the place of original extraction — the ruling concluded that 'reinjected processed gas should not be treated as trading stock for income tax purposes'.It is concluded that there is a good case for those Australian jurisdictions in which gas storage is occurring, or is about to occur, to provide legislation to eliminate the uncertainties.
34
Craig, Adam. "Exploration and appraisal year in review 2021." APPEA Journal 62, no. 2 (May 13, 2022): S527—S536. http://dx.doi.org/10.1071/aj21222.
Full textAbstract:
Petroleum exploration and appraisal activity increased in 2021. Exploration spend increased for the year, continuing a positive trend. Onshore exploration and appraisal activity continues to dominate the petroleum exploration scene in Australia. Positive indications of increased work program bids (wells, seismic and spend) are, however, tempered by the downward trend of total exploration acreage (by area) and new acreage awards. In addition to petroleum exploration acreage, greenhouse gas sequestration acreage was released across Australia in 2021. Twenty-nine exploration wells were drilled in the year compared to twenty-five in the previous year. Eight conventional petroleum discoveries were reported, with the Artisan-1 discovery in the Otway Basin being the only offshore discovery. The Lockyer Deep-1 gas discovery in the Northern Perth Basin continues the exploration success of the Permian Kingia and High Cliff Sandstone play. The Cooper–Eromanga Basin continues to yield discoveries with the Odin-1, Rosebay-1, Lowry South, Liger-1 and Chimera-1 discoveries reported for the year. Thirty-one appraisal wells were drilled for the year with significant activity in the Northern Perth Basin, Cooper-Eromanga Basin and Bowen-Surat Basins. Exploration and appraisal drilling also continued in the Beetaloo Sub-basin with the drilling of the Tanumbirini-2H, Tanumbirini-3H and Carpentaria-2/2H wells during the year.
35
Bendall, Betina, Anne Forbes, Dan Revie, Rami Eid, Shannon Herley, and Tony Hill. "New insights into the stratigraphy of the Otway Basin." APPEA Journal 60, no. 2 (2020): 691. http://dx.doi.org/10.1071/aj19035.
Full textAbstract:
The Otway Basin is one of the best known and most actively explored of a series of Mesozoic basins formed along the southern coastline of Australia by the rifting of the Antarctic and Australian plates during the Cretaceous. The basin offers a diversity of play types, with at least three major sedimentary sequences forming conventional targets for petroleum exploration in the onshore basin. The Penola Trough in South Australia has enjoyed over 20 years of commercial hydrocarbon production from the sandstones of the Early Cretaceous Otway Group comprising the Crayfish Subgroup (Pretty Hill Formation and Katnook sandstones) and Eumeralla Formation (Windermere Sandstone Member). Lithostratigraphic characterisation and nomenclature for these sequences are poorly constrained, challenging correlation across the border into the potentially petroleum prospective Victorian Penola Trough region. The Geological Survey of Victoria (GSV), as part of the Victorian Gas Program, commissioned Chemostrat Australia to undertake an 11-well chemostratigraphic study of the Victorian Otway Basin. The South Australia Department for Energy and Mining, GSV and Chemostrat Australia are working collaboratively to develop a consistent, basin-wide schema for the stratigraphic nomenclature of the Otway Basin within a chemostratigraphic framework. Variability in the mineralogy and hence inorganic geochemistry of sediments reflects changes in provenance, lithic composition, facies changes, weathering and diagenesis. This geochemical variation enables the differentiation of apparently uniform sedimentary successions into unique sequences and packages, aiding in the resolution of complex structural relationships and facies changes. In this paper, we present the preliminary results of detailed geochemical analyses and interpretation of 15 wells from across the Otway Basin and the potential impacts on hydrocarbon prospectivity.
36
Warris, B. J., T. Grocke, and A. Lane. "PETROLEUM OPERATIONS IN THE ENVIRONMENTALLY SENSITIVE NORTHERN PERTH BASIN, WESTERN AUSTRALIA." APPEA Journal 30, no. 1 (1990): 428. http://dx.doi.org/10.1071/aj89031.
Full textAbstract:
Barrack Energy Limited is an Australian company involved in the search for petroleum in Australia. The company's principal area of exploration and production is the northern portion of the onshore Perth Basin in Western Australia. In this area, the company operates four permits and one production licence covering an area of almost 15 000 square kilometres (3.7 million acres).For the period 1987 to 1989, Barrack Energy Limited acquired 1238 line km of seismic in the northern Perth Basin. This was conducted in fourteen surveys extending from Lancelin in the south to Dongara in the north.Petroleum exploration and production operations in the northern Perth Basin are highly visible and require painstaking and careful planning, permitting and negotiation to achieve the multiple land use goals of minimum disturbance to private landowners and minimum impact and zero long term effects on the environment.Due to the large areas of Vacant Crown Land and flora and fauna reserves in the northern Perth Basin, the impact of seismic line clearance upon the terrain was a major consideration. Barrack Energy Limited decided to experiment with various mechanical systems to clear seismic lines in order to determine the optimum operational and environmental technique. The bulldozer/ grader combination proved to be the most practical line clearance method available. The dozer need not be a tool of destruction and when operated correctly does no more damage than other methods tried.At all times Barrack Energy Limited has striven to ensure that the impact on the surrounding countryside by its exploration and production activity is kept to an absolute minimum. The company works closely with the local community to ensure that the local residents are comfortable at all times with the company's operating methods.
37
Hartwell, John. "2009 Release of offshore petroleum exploration acreage." APPEA Journal 49, no. 1 (2009): 463. http://dx.doi.org/10.1071/aj08030.
Full textAbstract:
John Hartwell is Head of the Resources Division in the Department of Resources, Energy and Tourism, Canberra Australia. The Resources Division provides advice to the Australian Government on policy issues, legislative changes and administrative matters related to the petroleum industry, upstream and downstream and the coal and minerals industries. In addition to his divisional responsibilities, he is the Australian Commissioner for the Australia/East Timor Joint Petroleum Development Area and Chairman of the National Oil and Gas Safety Advisory Committee. He also chairs two of the taskforces, Clean Fossil Energy and Aluminium, under the Asia Pacific Partnership for Clean Development and Climate (AP6). He serves on two industry and government leadership groups delivering reports to the Australian Government, strategies for the oil and gas industry and framework for the uranium industry. More recently he led a team charged with responsibility for taking forward the Australian Government’s proposal to establish a global carbon capture and storage institute. He is involved in the implementation of a range of resource related initiatives under the Government’s Industry Action Agenda process, including mining and technology services, minerals exploration and light metals. Previously he served as Deputy Chairman of the Snowy Mountains Council and the Commonwealth representative to the Natural Gas Pipelines Advisory Committee. He has occupied a wide range of positions in the Australian Government dealing with trade, commodity, and energy and resource issues. He has worked in Treasury, the Department of Trade, Department of Foreign Affairs and Trade and the Department of Primary Industries and Energy before the Department of Industry, Science and Resources. From 1992–96 he was a Minister Counsellor in the Australian Embassy, Washington, with responsibility for agriculture and resource issues and also served in the Australian High Commission, London (1981–84) as the Counsellor/senior trade relations officer. He holds a MComm in economics, and Honours in economics from the University of New South Wales, Australia. Prior to joining the Australian Government, worked as a bank economist. He was awarded a public service medal in 2005 for his work on resources issues for the Australian Government.
38
Alexander, E., and J. Morton. "SELECTING THE WINNING BID." APPEA Journal 42, no. 1 (2002): 523. http://dx.doi.org/10.1071/aj01029.
Full textAbstract:
Work program bidding is established as the favoured method of allocating petroleum exploration tenements in offshore Australian waters and most of onshore Australia. However, the selection of winning bids can be complicated by the ranking of 2D versus 3D seismic, seismic versus drilling, program timing issues etc. On occasion the selection of the winning bids has been contentious. This paper summarises the process developed by the Petroleum Group in South Australia to select the winning work program bids for prospective onshore blocks for which bids have been gazetted. No other Australian jurisdiction has yet publicly released their detailed bid assessment processes.Onshore acreage releases with work program bidding have been used in South Australia since the 1980s by Petroleum Group to:focus industry onto specific prospective areas of the State (e.g. the Cooper Basin post expiry of PELs 5 and 6 in 1999); maximise exploration commitments; and achieve competition policy.The South Australian Petroleum Act 2000 allows cash or work program bidding to be used depending on the acreage. Acreage releases are announced by Ministerial press release. Associated clear bid assessment criteria are published together with promotional material to aid applicants. The date and time for close of bidding are also established, usually allowing a 6–9 month acreage evaluation period, the timeframe depending on the volume of data involved, i.e. the exploration maturity of the area.Applications received as a result of a gazettal process (i.e. competing bids) are assessed by a process designed to ensure probity and to achieve the over-arching aim of the bidding process i.e. the suitability of the applicants proposed work program for evaluating the prospectivity of the licence area and discovering petroleum.A scoring system has been developed which establishes, for each bid what is effectively a risked net present value in well equivalents. In this system, guaranteed work scores higher than non-guaranteed work; early work scores higher than later work; wells with multiple targets are scored higher than single target wells; 2D and 3D seismic and other exploration activity is converted into well equivalents; and loading of the later, non-guaranteed years of work programs are heavily discounted.The scoring system may also take into account differences in the amount and density of exploration data and minor variations may be made to the system to take this into account. It is intended that details of the scoring system to be used in bid assessment will be published each time bids are sought to ensure transparency and a level playing field.Comparisons are made with acreage management philosophy and processes used by other regulatory regimes in Australia and internationally.
39
Ambrose, G. J., K. Liu, I. Deighton, P. J. Eadington, and C. J. Boreham. "NEW PETROLEUM MODELS IN THE PEDIRKA BASIN, NORTHERN TERRITORY, AUSTRALIA." APPEA Journal 42, no. 1 (2002): 259. http://dx.doi.org/10.1071/aj01015.
Full textAbstract:
The northern Pedirka Basin in the Northern Territory is sparsely explored compared with its southern counterpart in South Australia. Only seven wells and 2,500 km of seismic data occur over a prospective area of 73,000 km2 which comprises three stacked sedimentary basins of Palaeozoic to Mesozoic age. In this area three petroleum systems have potential related to important source intervals in the Early Jurassic Eromanga Basin (Poolowanna Formation), the Triassic Simpson Basin (Peera Peera Formation) and Early Permian Pedirka Basin (Purni Formation). They are variably developed in three prospective depocentres, the Eringa Trough, the Madigan Trough and the northern Poolowanna Trough. Basin modelling using modern techniques indicate oil and gas expulsion responded to increasing early Late Cretaceous temperatures in part due to sediment loading (Winton Formation). Using a composite kinetic model, oil and gas expulsion from coal rich source rocks were largely coincident at this time, when source rocks entered the wet gas maturation window.The Purni Formation coals provide the richest source rocks and equate to the lower Patchawarra Formation in the Cooper Basin. Widespread well intersections indicate that glacial outwash sandstones at the base of the Purni Formation, herein referred to as the Tirrawarra Sandstone equivalent, have regional extent and are an important exploration target as well as providing a direct correlation with the prolific Patchawarra/Tirrawarra petroleum system found in the Cooper Basin.An integrated investigation into the hydrocarbon charge and migration history of Colson–1 was carried out using CSIRO Petroleum’s OMI (Oil Migration Intervals), QGF (Quantitative Grain Fluorescence) and GOI (Grains with Oil Inclusions) technologies. In the Early Jurassic Poolowanna Formation between 1984 and 2054 mRT, elevated QGF intensities, evidence of oil inclusions and abundant fluorescing material trapped in quartz grains and low displacement pressure measurements collectively indicate the presence of palaeo-oil and gas accumulation over this 70 m interval. This is consistent with the current oil show indications such as staining, cut fluorescence, mud gas and surface solvent extraction within this reservoir interval. Multiple hydrocarbon migration pathways are also indicated in sandstones of the lower Algebuckina Sandstone, basal Poolowanna Formation and Tirrawarra Sandstone equivalent. This is a significant upgrade in hydrocarbon prospectivity, given previous perceptions of relatively poor quality and largely immature source rocks in the Basin.Conventional structural targets are numerous, but the timing of hydrocarbon expulsion dictates that those with an older drape and compaction component will be more prospective than those dominated by Tertiary reactivation which may have resulted in remigration or leakage. Preference should also apply to those structures adjacent to generative source kitchens on relatively short migration pathways. Early formed stratigraphic traps at the level of the Tirrawarra Sandstone equivalent and Poolowanna Formation are also attractive targets. Cyclic sedimentation in the Poolowanna Formation results in two upward fining cycles which compartmentalise the sequence into two reservoir–seal configurations. Basal fluvial sandstone reservoirs grade upwards into topset shale/coal lithologies which form effective semi-regional seals. Onlap of the basal cycle onto the Late Triassic unconformity offers opportunities for stratigraphic entrapment.
40
Fahey, J., and D. Perks. "LEGAL DEVELOPMENTS IN 2000." APPEA Journal 41, no. 2 (2001): 73. http://dx.doi.org/10.1071/aj00054.
Full textAbstract:
This paper briefly describes a number of legal developments in 2000 which may be of significance to participants in the petroleum exploration and production industry.There has been a number of varied legal developments in this field during the past year, and this paper is not an exhaustive account of all of them. Instead, an attempt has been made to provide an overview of selected developments during 2000 which are noteworthy. With this mind, this paper deals with the following matters:prospective East Timorese independence and the Timor Gap Treaty (focussing on practical arrangements);changes to the work program bidding system;commencement of the Petroleum (Submerged Lands) Legislation Amendment Act No 1 2000 (Cth);review of federal and state petroleum (submerged lands) legislation against competition policy principles;commencement of the Environment Protection and Biodiversity Conservation Act 1999 (Cth);reform of petroleum legislation in South Australia and Queensland; andgreenhouse reforms.In respect of the matters noted above, we have attempted to outline the implications for participants in the petroleum exploration and production industry.
41
Bailey, Adam H. E., Amber J. M. Jarrett, Liuqi Wang, David N. Dewhurst, Lionel Esteban, Shane Kager, Ludwig Monmusson, Lidena K. Carr, and Paul A. Henson. "Exploring for the Future geomechanics: breaking down barriers to exploration." APPEA Journal 61, no. 2 (2021): 579. http://dx.doi.org/10.1071/aj20039.
Full textAbstract:
Exploring for the Future (EFTF) is an Australian Government initiative focused on gathering new data and information about potential mineral, energy and groundwater resources across Australia. The energy component of EFTF, initially focussed on northern Australia, aims to improve our understanding of the petroleum potential of frontier Australian basins. Building an understanding of geomechanical rock properties is key to understanding both conventional and unconventional petroleum systems as well as carbon storage and sedimentary geothermal systems. Under EFTF, Geoscience Australia has undertaken geomechanical work including stress modelling, shale brittleness studies and the acquisition of new rock property data through extensive testing on samples from the Paleo- to Mesoproterozoic South Nicholson region of Queensland and the Northern Territory, and the Paleozoic Kidson Sub-basin of Western Australia. Work in these regions demonstrates regional stress orientations in broad agreement with previously modelled, continent-scale stress orientations and stress magnitudes that vary through the basin with depth and by lithology. Rock testing highlights potentially brittle shales and demonstrates variable rock properties in line with lithology. These analyses are summarised herein. Providing baseline geomechanical data in frontier basins is essential as legacy data coverage can often be inadequate for making investment decisions, particularly where unconventional plays are a primary exploration target. As EFTF increases in scope, Geoscience Australia anticipates expanding these studies to encompass further underexplored regions throughout Australia, lowering the barrier to entry and encouraging greenfield exploration.
42
Cockshell, C. D., and M. Malavazos. "ASSESSMENT FOR ENVIRONMENTAL SIGNIFICANCE OF PETROLEUM ACTIVITY IMPACTS: COONGIE LAKES CASE STUDY." APPEA Journal 38, no. 1 (1998): 584. http://dx.doi.org/10.1071/aj97034.
Full textAbstract:
The introduction of changes to petroleum regulation in South Australia will, and have, resulted in some concern by industry, particularly in the area of public consultation. Primary Industry and Resources South Australia (PIRSA)-Petroleum Group's development of a set of guidelines for determination of project environmental significance is aimed to give a clearer indication of the level of consultation, documentation and assessment appropriate for each project. The Coongie Lakes assessment case study gives an indication of how these concepts can be applied in a practical sense.The assessment process establishes scales for the level of certainty (predictability) of the potential environmental impacts and the degree to which the consequences of the potential impacts can be managed or avoided (manageability). This process was undertaken for the seismic proposal in the Coongie Lakes area and provides an innovative approach to project assessment. The predictability and manageability charts prepared for all potential impacts provides a method of presenting a vast amount of information very concisely. The definition of assessment guidelines allows potential environmental impacts to be expressed in a quantitative manner, and leads to evaluation of these impacts against a defined level of community acceptability. The approach also demonstrates a degree of rigour in the assessment process and is transparent to all stakeholders. In addition, the predictability and manageability charts focus attention to issues which have higher ratings, and thus a need for closer attention. The feedback from stakeholders on this innovative assessment technique indicates a general acceptance of the approach and the criteria definitions used, although some adjustment and refinement is required.
43
Norvick, M. S., and M. A. Smith. "MAPPING THE PLATE TECTONIC RECONSTRUCTION OF SOUTHERN AND SOUTHEASTERN AUSTRALIA AND IMPLICATIONS FOR PETROLEUM SYSTEMS." APPEA Journal 41, no. 1 (2001): 15. http://dx.doi.org/10.1071/aj00001.
Full textAbstract:
Southern Australian breakup history is divisible into three phases. The first phase began with Callovian (c.159–165 Ma) rifting in the western Bight Basin. During the Tithonian (c.142–146 Ma), rifting extended eastwards into the Duntroon, Otway and Gippsland Basins. By the Valanginian (c.130–135 Ma), ocean crust formed between India and western Australia. Structural style in the western Bight changed to thermal subsidence. However, fluvio-lacustrine rift sedimentation continued in Duntroon, Otway and Gippsland until the Barremian (c.115–123 Ma) when these basins also changed to thermal subsidence. The diachronous progression of basin fill types produces a progressive shift in ages of potential source, seal and reservoir intervals along the margin.The second phase began during the Cenomanian (c.92–97.5 Ma) with uplift in eastern Australia, stress reorganisation and divergence of basin development. The Otway, Sorell and Great South Basins formed in a transtensional regime. These tectonics resulted in trap generation through faulting, inversion and wrenching. During the Santonian, oceanic spreading began in the southern Tasman Sea (c.85 Ma). Slow extension caused thinning of continental crust in the Bight and Otway Basins and subsidence into deeper water. Ocean crust formed south of the Bight Basin in the Early Campanian (c.83 Ma) and also started extending up the eastern Australian coast.The third stage in development was caused by Eocene changes to fast spreading in the Southern Ocean (c.44 Ma), final separation of Australia and Antarctica, and cessation of Tasman Sea spreading. These events caused collapse of continental margins and widespread marine transgression. The resultant loading, maturation and marine seal deposition are critical to petroleum prospectivity in the Gippsland Basin.
44
Stalker, Linda, Dominique Van Gent, Sandeep Sharma, and Martin Burke. "South West Hub Project: appraising a carbon storage resource in Western Australia." APPEA Journal 55, no. 2 (2015): 472. http://dx.doi.org/10.1071/aj14107.
Full textAbstract:
The South West Hub Carbon Capture and Storage Project (SWH), managed by the WA Department of Mines and Petroleum (WA DMP), is evaluating the potential for a commercial-scale carbon storage site near major emissions sites in southwest WA. The area under investigation is in the southern Perth Basin, focusing on a 150 km2 area in the shires of Harvey and Waroona. WA DMP is conducting a major feasibility study and collecting pre-competitive data in partnership with the local community. The activities are done in a stage-gate model to obtain relevant information on the potential storage capacity, containment security and injectivity of the geology. Following a smaller 2D seismic survey and the drilling of the Harvey–1 stratigraphic well, a more complex 3D seismic survey was undertaken in February to March, 2014. These activities have confirmed the potential for commercial-scale CO2 storage. A new work package has been initiated with the drilling of three wells (Harvey–2, –3 and –4) underway and plans to drill a fifth well in the next 12 months. The stage-gate approach has been cost-effective, resulting in a carefully planned data acquisition and research program. The approach allows new results, information and potential future activities to be rolled out to stakeholders and the community in the area.
45
Webb, Ashley A., Georgina L. Kelly, and Warwick J. Dougherty. "Soil governance in the agricultural landscapes of New South Wales, Australia." International Journal of Rural Law and Policy, no. 1 (March 29, 2015): 1–16. http://dx.doi.org/10.5130/ijrlp.i1.2015.4169.
Full textAbstract:
Soil is a valuable natural resource. In the state of New South Wales, Australia, the governance of soil has evolved since Federation in 1901. Following rapid agricultural development, and in the face of widespread soil degradation, the establishment of the Soil Conservation Service marked a turning point in the management of soil. Throughout the 20th century, advances in knowledge were translated into evolving governance frameworks that were largely reactionary but saw progressive reforms such as water pollution legislation and case studies of catchment-scale land and vegetation management. In the 21st century, significant reforms have embedded sustainable use of agricultural soils within catchment- and landscape-scale legislative and institutional frameworks. What is clear, however, is that a multitude of governance strategies and models are utilised in NSW. No single governance model is applicable to all situations because it is necessary to combine elements of several different mechanisms or instruments to achieve the most desired outcomes. Where an industry, such as the sugar industry, has taken ownership of an issue such as acid sulfate soil management, self-regulation has proven to be extremely effective. In the case of co-managing agricultural soils with other landuses, such as mining, petroleum exploration and urban development, regulation, compliance and enforcement mechanisms have been preferred. Institutional arrangements in the form of independent commissioners have also played a role. At the landscape or total catchment level, it is clear that a mix of mechanisms is required. Fundamental, however, to the successful evolution of soil governance is strategic investment in soil research and development that informs the ongoing productive use of agricultural landscapes while preventing land degradation or adverse environmental effects.
46
Smith, Greg C., and Robert G. Cowley. "THE TECTONO-STRATIGRAPHY AND PETROLEUM POTENTIAL OF THE NORTHERN ABROLHOS SUB BASIN, WESTERN AUSTRALIA." APPEA Journal 27, no. 1 (1987): 112. http://dx.doi.org/10.1071/aj86012.
Full textAbstract:
The Abrolhos Sub-basin lies offshore in Western Australia to the west of Geraldton and has geological affinities with the northern Perth Basin and the southern Carnarvon Basin. Both of these basins contain commercial petroleum accumulations, whereas the Abrolhos Sub-basin is a frontier area which is largely unexplored. A moderate seismic coverage of the sub-basin now exists but only two wells have been drilled, both of which were dry.Four main tectono-stratigraphic sequences are recognisable above Precambrian basement:Lower Palaeozoic Pre Rift SequenceCarboniferous-Permian Synrift/Rift Sequence S Triassic-Jurassic Rift Sequence4 Cretaceous to Recent Drift Sequence.The Lower Palaeozoic is only known on the eastern basin margins where it mainly consists of Silurian fluvial and alluvial fan red beds. The Carboniferous-Permian marine and coal measure volcanogenic synrift and rift sequences are characterised by north-south, mainly east-dipping extensional faulting, followed by widespread erosion. The Triassic sequence is about 2 km thick and comprises a basal marine Kockatea Shale, overlain by the marginal marine Woodada Formation and the Lesueur Formation red bed sequence. Subsidence during the Triassic was rapid but controlled by large NNW-SSE trending, high angle west-dipping, planar normal faults with minor rotation and extension. The Jurassic is poorly known, being confined to structurally deep blocks along the Mesozoic basin axis to the south and west. A renewed phase of NNW-SSE west-dipping extensional faulting began during the Jurassic and resulted in the development of rollover anticlines. Considerable erosion and non-deposition occurred forming a regional Neocomian unconformity. The postrift or drift sequence consists of transgressive marine shelf carbonates dipping basinward without further significant structuring.The main prospect types in the sub-basin include base Triassic transgressive sandstones or top Permian sandstones sealed by the Kockatea Shale in tilted fault blocks, and Triassic-Jurassic sandstones within rollover anticlines sealed by intraformational shales or the middle Jurassic Cadda Formation. The main source rocks include the Woodada and Kockatea formations which are within the oil generative zone over much of the sub-basin. However, identification of areas with the required coincidence of source, reservoir, seal and structural timing appears elusive.
47
Bernecker, Thomas. "Review of the 2009 offshore petroleum exploration release areas." APPEA Journal 49, no. 1 (2009): 465. http://dx.doi.org/10.1071/aj08031.
Full textAbstract:
The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. This year, 31 areas plus two special areas in five offshore basins are being released for work program bidding. Closing dates for bid submissions are either six or twelve months after the release date (i.e. 3 December 2009 and 29 April 2010), depending on the exploration status in these areas is and on data availability. The 2009 release areas are located in Commonwealth waters offshore Northern Territory, Western Australia, South Australia and Victoria, comprising intensively explored areas close to existing production as well as new frontiers. As usual, the North West Shelf features very prominently and is complimented by new areas along the southern margin, including frontier exploration areas in the Ceduna Sub-basin (Bight Basin) and the Otway Basin. The Bonaparte Basin is represented by one release area in the Malita Graben, while five areas are available in the Southern Browse Basin in an under-explored area of the basin. A total of 14 areas are being released in the Carnarvon Basin, with eight areas located in the Dampier Sub-basin, three small blocks in the Rankin Platform and three large blocks on the Northern Exmouth Plateau (these are considered a deep water frontier). In the south, six large areas are on offer in the Ceduna Sub-basin and five areas of varying sizes are being released in the Otway Basin, including a deep water frontier offshore Victoria. The special release areas are located in the Petrel Sub-basin, Bonaparte Basin offshore Northern Territory, and encompass the Turtle/Barnett oil discoveries. The 2009 offshore acreage release offers a wide variety of block sizes in shallow as well as deep water environments. Area selection has been undertaken in consultation with industry, the states and Territory. This year’s acreage release caters for the whole gamut of exploration companies given that many areas are close to existing infrastructure while others are located in frontier offshore regions. As part of Geoscience Australia’s Offshore Energy Security Program, new data has been acquired in offshore frontier regions and have yielded encouraging insights into the hydrocarbon prospectivity of the Ceduna-Sub-basin.
48
Moore, A. M. G., H. M. J. Stagg, and M. S. Norvick. "DEEP-WATER OTWAY BASIN: A NEW ASSESSMENT OF THE TECTONICS AND HYDROCARBON PROSPECTIVITY." APPEA Journal 40, no. 1 (2000): 66. http://dx.doi.org/10.1071/aj99005.
Full textAbstract:
The northwest-trending Otway Basin in southeast Australia formed during the separation of Australia and Antarctica between the latest Jurassic and the Early Cainozoic. A new, deep-seismic data set shows that the basin comprises two temporally and spatially overlapping rift components:the mainly Late Jurassic to mid-Cretaceous, east-west trending, inner Otway Basin—comprising the onshore basin and most of the continental shelf basin; andthe northwest–southeast to north–south trending depocentres beneath the outer shelf and continental slope, extending from eastern South Australia to the west coast of Tasmania, and a relatively minor and ill-defined sub-basin underlying the continental rise in water depths greater than about 4,500 m. This rift system was most active from the mid-Cretaceous to Palaeogene, and was strongly affected by sinistral strike-slip motion as Australia and Antarctica separated.The continental slope elements contain the bulk of the sediment volume in the basin. From northwest to southeast, these elements comprise the Beachport and Morum Sub-basins, the north-south trending Discovery Bay High, and the Nelson Sub-basin which appears to be structurally and stratigraphically continuous with the Sorell Basin off west Tasmania.The reflection character of the crust and upper mantle varies widely across the basin, and there is a strong correlation between that character and the basin configuration. It appears that accommodation space beneath the slope basin was created largely by extension and removal of most of the laminated deep continental crust.There is encouragement for hydrocarbon exploration in the deep-water basin. Firstly, there are indications of diagenesis related to fluid flow in and above the strongly faulted Cretaceous section in the Morum Sub-basin. As an Early Cretaceous petroleum system is already proven beneath the continental shelf, this suggests that the same system is also active in deep-water. Secondly, existing sample data suggest that a second, Late Cretaceous petroleum system could be active where any source rocks are sufficiently deeply buried; this condition would probably be met in the Nelson Sub-basin.
49
Jenkin, Thomas. "Exploitation or 'Wise Use' of the Coongie Lakes, South Australia: Issues arising from a petroleum exploration proposal." Australian Geographer 30, no. 3 (November 1999): 355–71. http://dx.doi.org/10.1080/00049189993639.
Full text
50
Carr, Lidena, Russell Korsch, Leonie Jones, and Josef Holzschuh. "The role of deep seismic reflection data in understanding the architecture and petroleum potential of Australia's onshore sedimentary basins." APPEA Journal 50, no. 2 (2010): 726. http://dx.doi.org/10.1071/aj09090.
Full textAbstract:
The onshore energy security program, funded by the Australian Government and conducted by Geoscience Australia, has acquired deep seismic reflection data across several frontier sedimentary basins to stimulate petroleum exploration in onshore Australia. Detailed interpretation of deep seismic reflection profiles from four onshore basins, focussing on overall basin geometry and internal sequence stratigraphy, will be presented here, with the aim of assessing the petroleum potential of the basins. At the southern end of the exposed part of the Mt Isa Province, northwest Queensland, a deep seismic line (06GA–M6) crosses the Burke River structural zone of the Georgina Basin. The basin here is >50 km wide, with a half graben geometry, and bounded in the west by a rift border fault. Given the overall architecture, this basin will be of interest for petroleum exploration. The Millungera Basin in northwest Queensland is completely covered by the thin Eromanga Basin and was unknown prior to being detected on two seismic lines (06GA–M4 and 06GA–M5) acquired in 2006. Following this, seismic line 07GA–IG1 imaged a 65 km wide section of the basin. The geometry of internal stratigraphic sequences and a post-depositional thrust margin indicate that the original succession was much thicker than preserved today and may have potential for a petroleum system. The Yathong Trough, in the southeast part of the Darling Basin in NSW, has been imaged in seismic line 08GA–RS2 and interpreted in detail using sequence stratigraphic principles, with several sequences being mapped. Previous studies indicate that the upper part of this basin consists of Devonian sedimentary rocks, with potential source rocks at depth. In eastern South Australia, seismic line 08GA–A1 crossed the Cambrian Arrowie Basin, which is underlain by a Neoproterozoic succession of the Adelaide Rift System. Stratigraphic sequences have been mapped and can be tied to recent drilling for mineral and geothermal exploration. Shallow drill holes from past petroleum exploration have aided the assessment of the petroleum potential of the Cambrian Hawker Group, which contains bitumen in the core, indicating the presence of source rocks in the basin system.