Готові списки джерел за темами / Petroleum refineries South Australia

Добірка наукової літератури з теми "Petroleum refineries South Australia"

Автор: Grafiati
Опубліковано: 10 грудня 2022
Оновлено: 29 січня 2023

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Статті в журналах з теми "Petroleum refineries South Australia"

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.

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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.
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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.

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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.
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3

Frears, R. "PETROLEUM EXPLORATION AND EVELOPMENT IN SOUTH AUSTRALIA." APPEA Journal 26, no. 2 (1986): 77. http://dx.doi.org/10.1071/aj85055.

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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.

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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.
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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.

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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.
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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.

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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.
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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.

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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.

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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.
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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.

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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.
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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.

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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.
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Більше джерел

Дисертації з теми "Petroleum refineries South Australia"

1

Mithamo, Peter Ng'ang'a. "Use of high efficient motors for DSM in South Africa's petroleum refineries." Thesis, Cape Peninsula University of Technology, 2012. http://hdl.handle.net/20.500.11838/2212.

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Thesis (MTech (Electrical Engineering))--Cape Peninsula University of Technology, 2012.
Electric motors consume over 60% of the world's generated electricity. In South Africa approximately 65% of the energy generated is consumed by electric motors (Niekerk, 2009). About 95% of motors in use in South Africa are Standard-Efficient Motors (SE-motors) that operate at an average efficiency of 84% to 90%, depending on the size of the motor and the load driven by them. High-Efficient motors (HE-motor) run at an efficiency of 2% to 8% higher than that of SE-motors. In recent years, a drive to replace SE-motors with HE-motors has been promoted for the purpose of Demand Side Management (DSM). The rationale of using HE-motors as a tool of DSM is to harness a small difference in operating efficiency per motor, which can result in a huge reduction in electricity consumption, depending on the number of HE-motors that will replace SE-motors. Reducing the demand for electricity is the key driving factor for DSM in South Africa, so as to relieve the already stressed power generation capacity. Other consequential factors of DSM are to reduce the amount of pollutant gases emitted into the atmosphere. To the electricity users DSM will be a great incentive, as reduced consumption of electricity will decrease the amount of money spent on electricity. Much has been written on the ability of HE-motors to reduce electricity consumption, cost of electricity and global pollution. ESKOM has even demonstrated the faith they have in these motors by giving rebates to motor users who are willing to exchange their existing SE-motors with new HE-motors. The rebates are paid by ESKOM through a newly established DSM program. However, it must be mentioned that savings through HE-motors is not a perfect guarantee. HE-motors have inherent design limitations that may inhibit the saving of energy. To achieve higher efficiency, HE-motors are designed to operate on a smaller slip that consequently increases their speed compared to that of SE-motors (Cheek et al., 1995). Higher rotor speed impacts energy saving abilities of HE-motors when they are used to drive fans, pumps and compressors, normally referred to as centrifugal loads. An increase in speed results in a proportional increase in flow. Power consumed by a motor goes up as a cube of the speed, and the flow rate increases linearly with speed. Motor loads in the petrochemical industry are generally centrifugal, and that is why this thesis focuses on refineries.
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2

Van, Ruth Peter John. "Overpressure in the Cooper and Carnarvon Basins, Australia /." Title page, abstract and table of contents only, 2003. http://web4.library.adelaide.edu.au/theses/09PH/09phv275.pdf.

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3

Williams, Richard G. "Floristic recovery of native vegetation after petroleum exploration in the Otway Basin, S.E. South Australia /." Title page, contents and abstract only, 1997. http://web4.library.adelaide.edu.au/theses/09SM/09smw7259.pdf.

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4

Kramer, Liz. "Monitoring petroleum migration from Permian coal sequences in the Patchawarra Formation, southwest Cooper Basin, South Australia /." Title page, abstract and contents only, 2000. http://web4.library.adelaide.edu.au/theses/09SB/09sbk88.pdf.

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5

Michaelsen, Bernd Heinrich. "Organic facies and petroleum-generative potential of the Murta Member (Mooga Formation), in the Eromanga Basin, South Australia /." Title page, contents and abstract only, 1986. http://web4.library.adelaide.edu.au/theses/09SB/09sbm621.pdf.

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6

McGregor, James Royston. "Investigation into the economic feasibility of the continued existence of the PetroSA Mossel Bay refinery." Thesis, Stellenbosch : Stellenbosch University, 2005. http://hdl.handle.net/10019.1/50377.

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Thesis (MBA)--Stellenbosch University, 2005.
ENGLISH ABSTRACT: South Africa's main requirements for power are in the form of electricity and liquid fuels The country's electricity is generated mainly from coal while the liquid fuels requirement is mainly from crude oil. Both coal and crude oil use are coming under increasing pressure locally because of pollution and accompanying environmental awareness. Internationally both energy sources are also increasingly being abandoned as preferred energy sources, in first world countries, in favour of cleaner energy sources.ln view of these developments in the macro environment South Africa's gas to liquids refinery built in the early 1990's seems a well placed past investment ahead of its time. This study project looks at the economic feasibility of the continued existence of the PetroSA gas to liquid plant in Mossel Bay.The study looks at South Africa as well as Southern Africa's energy resources , the effect of changing legislation on the future use of energy resources and the economics of the Mossel Bay facility. The study finds that South Africa's abundance of coal reserves, its lack of oil and gas reserves and the slow pace of environmental legislation delivery means that gas is unlikely to become a major source of energy in South Africa.The Mossel Bay gas to liquids plant is profitable but its high fixed costs and certain growth of this cost component means that the continued feasibility of operations is dependant on favourable movements in the exchange rate and oil price. To answer the question about whether to continue operating or close down the analysis found that although although early closure would provide a return of more than 15 percent it would be even more viable financially to make an investment for more gas and continue operations.The main reason for the better than average projected returns is the high oil price .The decision to close down the Mossel Bay plant is not likely to be based on financial considerations alone. The recommendation is thus to continue operations untill 2016.The investment required to secure more gas would , even in the worst case scenario, provide a satisfactory return on investment.
AFRIKAANSE OPSOMMING: Suid Afrika se energie behoeftes is hoofsaaklik vir elektrisiteit en brandstof. Die meerderheid van die land se elektristeit word deur middel van steenkool opgewek terwyl ru-olie gebruik word om brandstof te vervaardig. Beide steenkool en ru-olie word al hoe meer onder druk geplaas as gevolg van besoedeling en 'n meer omgewing bewuste publiek. Op internasionale vlak , in eerste wereld lande word die gebruik van steenkool en ru-olie al hoe meer afgeskaf ten gunsle van skoner kragbronne. In die lig van hierdie verwikkeling in die makro omgewing mag dit op die oog af Iyk of PetroSA se gas na vloeistof aanleg in Mosselbaai, wat reeds in die vroee 1990's gebou is, as 'n goeie destydse strategiese belegging voorkom. Hierdie studie projek ondersoek die ekonomiese lewensvatbaarheid van die voorgesette bestaan van die PetroSA se Mosselbaai gas na vloeislof aanleg. Die studie kyk na Suid-Afrika sowel as die groter Suider Afrika se natuurlike energiebronne, die invloed van verandering in wetgewing op die toekomstige gebruik van energiebronne en die ekonomiese kenmerke van die aanleg in Mosselbaai. Die bevinding van die studie is dat Suid-Afrika se oorvloed van steenkool, sy tekort aan natuurlike gas en die stadige pas waarteen omgewings-wetgewing ontwikkel word, daartoe lei dat gas nie 'n volmatige energiebron in Suid Afrika sal word nie. Die aanleg in Mosselbaai is huidiglik winsgewind maar sy hoe vastekoste en groei hiervan belemmer sy vooruitsigte vanuit 'n finansiele oogpunt. Die winsgewindheid van die aanleg is afhanklik van 'n verswakkende Suid Afrikaanse geldeenheid en verhogende ru-olie pryse. Die vraag onstaan dus of die aanleg moet toemaak en of produksie moet voortgaan. Die ondersoek vind dat alhoewel die sluiting van die aanleg 'n opbrengs van meer as 15 persent sal lewer dit selfs meer finansieel aantreklik is on te belê in meer gas sodat produksie kan voortgaan. Die hoofrede vir die bogemiddelde opbrengs is die hoe oilieprys. Dit is onwaarskynlik dat die oorweging om die Mosselbaaise aanleg sluit suiwer op finansieele oorwegings sal rus. Die aanbeveling is dus om voort te gaan met produksie tot 2016. Die belegging wat nodig is vir meer gas sal selfs onder die mees pessimistiese omstandighede steeds 'n bevredigende opbrengs lewer.
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7

Davey, Alistair Colin. "Refinery exchange agreements : pro-competitive, anti-competitive or benign?" Phd thesis, 2007. http://hdl.handle.net/1885/148216.

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8

Lyon, Paul John. "A systematic assessment of fault seal risk to hydrocarbon exploration in the Penola Trough, Otway Basin, South Australia." 2008. http://hdl.handle.net/2440/49488.

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Анотація:
A new depth-based method of seismic imaging is used to provide insights into the 3D structural geometry of faults, and to facilitate a detailed structural interpretation of the Penola Trough, Otway Basin, South Australia. The structural interpretation is used to assess fault kinematics through geological time and to evaluate across-fault juxtaposition, shale gouge and fault reactivation potential for three selected traps (Zema, Pyrus and Ladbroke Grove) thus providing a full and systematic assessment of fault seal risk for the area. Paper 1 demonstrates how a depth-conversion method was applied to two-way time seismic data in order to redisplay the seismic in a form more closely representative of true depth, here termed ‘pseudo-depth’. Some apparently listric faults in two-way time are demonstrated to be planar and easily distinguishable from genuine listric faults on pseudo-depth sections. The insights into fault geometry provided by pseudo-depth sections have had a significant impact on the new structural interpretation of the area. Paper 2 presents the new 3D structural interpretation of the area. The geometry of faulting is complex and reflects variable stress regimes throughout structural development and the strong influence of pre-existing basement fabrics. Some basement-rooted faults show evidence of continual reactivation throughout their structural history up to very recent times. Structural analysis of all the live and breached traps of the area demonstrate that traps associated with a basement rooted bounding fault host breached or partially breached accumulations, whereas non-basement rooted faults are associated with live hydrocarbon columns. Papers 3 and 4 demonstrate that for all the traps analysed (Zema, Pyrus and Ladbroke Grove), initial in-place seal integrity was good. The initial seal integrity was provided by a combination of both favourable across fault juxtaposition (Ladbroke Grove) and/or sufficiently well developed shale gouge over potential leaky sand on sand juxtaposition windows to retain significant hydrocarbon columns (Zema, Pyrus). The palaeocolumns observed at Zema and Pyrus indicate that there has been subsequent post-charge breach of seal integrity of these traps while Ladbroke Grove retains a live hydrocarbon column. Evidence of open, permeable fracture networks within the Zema Fault Zone suggest that it is likely to have recently reactivated, thus breaching the original hydrocarbon column. Analysis of the in-situ stress tensor and fault geometry demonstrates that most of the bounding faults to the selected traps are at or near optimal orientations for reactivation in the in-situ stress tensor. The main exception being the Ladbroke Grove Fault which has a NW-SE trending segment (associated with a relatively high risk of fault reactivation and possible leakage at the surface) and an E-W trending segment (associated with a relatively low risk of fault reactivation and a present day live column). The free water level of the Ladbroke Grove accumulation coincides with this change in fault orientation.
http://proxy.library.adelaide.edu.au/login?url= http://library.adelaide.edu.au/cgi-bin/Pwebrecon.cgi?BBID=1339545
Thesis (Ph.D.) - University of Adelaide, Australian School of Petroleum, 2008
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9

Lyon, Paul John. "A systematic assessment of fault seal risk to hydrocarbon exploration in the Penola Trough, Otway Basin, South Australia." Thesis, 2008. http://hdl.handle.net/2440/49488.

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Анотація:
A new depth-based method of seismic imaging is used to provide insights into the 3D structural geometry of faults, and to facilitate a detailed structural interpretation of the Penola Trough, Otway Basin, South Australia. The structural interpretation is used to assess fault kinematics through geological time and to evaluate across-fault juxtaposition, shale gouge and fault reactivation potential for three selected traps (Zema, Pyrus and Ladbroke Grove) thus providing a full and systematic assessment of fault seal risk for the area. Paper 1 demonstrates how a depth-conversion method was applied to two-way time seismic data in order to redisplay the seismic in a form more closely representative of true depth, here termed ‘pseudo-depth’. Some apparently listric faults in two-way time are demonstrated to be planar and easily distinguishable from genuine listric faults on pseudo-depth sections. The insights into fault geometry provided by pseudo-depth sections have had a significant impact on the new structural interpretation of the area. Paper 2 presents the new 3D structural interpretation of the area. The geometry of faulting is complex and reflects variable stress regimes throughout structural development and the strong influence of pre-existing basement fabrics. Some basement-rooted faults show evidence of continual reactivation throughout their structural history up to very recent times. Structural analysis of all the live and breached traps of the area demonstrate that traps associated with a basement rooted bounding fault host breached or partially breached accumulations, whereas non-basement rooted faults are associated with live hydrocarbon columns. Papers 3 and 4 demonstrate that for all the traps analysed (Zema, Pyrus and Ladbroke Grove), initial in-place seal integrity was good. The initial seal integrity was provided by a combination of both favourable across fault juxtaposition (Ladbroke Grove) and/or sufficiently well developed shale gouge over potential leaky sand on sand juxtaposition windows to retain significant hydrocarbon columns (Zema, Pyrus). The palaeocolumns observed at Zema and Pyrus indicate that there has been subsequent post-charge breach of seal integrity of these traps while Ladbroke Grove retains a live hydrocarbon column. Evidence of open, permeable fracture networks within the Zema Fault Zone suggest that it is likely to have recently reactivated, thus breaching the original hydrocarbon column. Analysis of the in-situ stress tensor and fault geometry demonstrates that most of the bounding faults to the selected traps are at or near optimal orientations for reactivation in the in-situ stress tensor. The main exception being the Ladbroke Grove Fault which has a NW-SE trending segment (associated with a relatively high risk of fault reactivation and possible leakage at the surface) and an E-W trending segment (associated with a relatively low risk of fault reactivation and a present day live column). The free water level of the Ladbroke Grove accumulation coincides with this change in fault orientation.
Thesis (Ph.D.) - University of Adelaide, Australian School of Petroleum, 2008
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10

Van, Ruth Peter John. "Overpressure in the Cooper and Carnarvon Basins, Australia / Peter John van Ruth." Thesis, 2003. http://hdl.handle.net/2440/22125.

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Анотація:
"February 2003"
PhD (by publication).
Includes bibliographical references.
vii, 21, [49] leaves : ill. (some col.), maps, photos (some col.) ; 30 cm.
Title page, contents and abstract only. The complete thesis in print form is available from the University Library.
Thesis (Ph.D.)--University of Adelaide, Australian School of Petroleum (ASP), 2004
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Книги з теми "Petroleum refineries South Australia"

1

Mines and Energy Resources South Australia. Petroleum Division. Petroleum exploration and development in South Australia. Eastwood, S. Aust: Publications Section, Mines and Energy Resources South Australia, 1997.

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2

LSE, Inc. South Oily Sludge Pit closure plan, Conoco Billings Refinery. Billings, Mont: Conoco Billings Refinery, 1989.

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3

Colwell, James B. Rig seismic research cruise 13: Structure and stratigraphy of the northeast Gippsland Basin and southern New South Wales margin : initial report. Canberra: Australian Govt. Pub. Service, 1987.

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4

Colwell, James B. Rig seismic research cruise 13: Structure and stratigraphy of the northeast Gippsland Basin and southern New South Wales margin : initial report. Canberra: Australian Government Publishing Service, 1987.

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5

South-Eastern, Australia Oil Exploration Symposium (2nd 1985 Melbourne Vic ). Second South-Eastern Australia Oil Exploration Symposium: Technical papers presented at the PESA Symposium held in Melbourne on 14th and 15th November, 1985. Melbourne: The Petroleum Exploration Society of Australia, Victorian & Tasmanian Branch, 1986.

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6

Bohlmann, Heinrich, and Rod Crompton. The impact on the South African economy of alternative regulatory arrangements in the petroleum sector. UNU-WIDER, 2020. http://dx.doi.org/10.35188/unu-wider/2020/910-5.

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This paper adds quantitative analysis to the study by Crompton et al. (2020), in which various alternative regulatory arrangements regarding the petrol price in South Africa were explored. We use a multi-sector dynamic computable general equilibrium model for South Africa to conduct our economic impact analysis. Five scenarios are modelled, first individually to correctly calibrate the shocks, and then cumulatively to find the overall economy-wide effects of the proposed reforms. Under the most comprehensive set of reforms to the determination of petrol prices, which seeks to emulate market forces, the South African economy is seeing substantial benefits. GDP is expected to rise by 0.67 per cent and real wages by over 1.1 per cent relative to the baseline. Refineries are assumed to shrug off reforms targeted at removing pure profits earned via the import parity price (Basic Fuel Price) methodology by accepting a slightly lower rate of return, enabling them to meet the expected increase in demand for petrol on the back of the lower consumer prices achieved via the reforms. Whilst job losses at fuel service stations may be expected as a result of reduced revenues and margins, increased activity and job opportunities in the rest of the economy, facilitated through cheaper trade and transport margins, will more than offset those losses.
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Частини книг з теми "Petroleum refineries South Australia"

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Dyson, Ian A. "Evolution of Allochthonous Salt Systems During Development of a Divergent Margin: The Adelaide Geosyncline of South Australia." In Petroleum Systems of Divergent Continental Margin Basins: 25th Annual, 541–73. SOCIETY OF ECONOMIC PALEONTOLOGISTS AND MINERALOGISTS, 2005. http://dx.doi.org/10.5724/gcs.05.25.0541.

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Gannaway, C. E., K. A. Giles, R. A. Kernen, M. G. Rowan, and T. E. Hearon. "Comparison of the Depositional and Halokinetic History of Suprasalt and Subsalt Minibasins at Patawarta Diapir, Flinders Ranges, South Australia." In Sedimentary Basins: Origin, Depositional Histories, and Petroleum Systems. SEPM Society for Sedimentary Geology, 2014. http://dx.doi.org/10.5724/gcs.14.33.0428.

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Dyson, Ian A. "Formation of Submarine Unconformities in Halotectonic Mini-Basins During Passive Margin Development of the Adelaide Geosyncline, South Australia." In Petroleum Systems of Divergent Continental Margin Basins: 25th Annual, 679–721. SOCIETY OF ECONOMIC PALEONTOLOGISTS AND MINERALOGISTS, 2005. http://dx.doi.org/10.5724/gcs.05.25.0679.

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FRYBERGER, STEVEN G., BRETT WALKER, and ROB RUTHERFORD. "EOLIAN DEPOSITS OF THE YOUNGHUSBAND CARBONATE BARRIER, SOUTH AUSTRALIA: ANALOG FOR ANCIENT EOLIAN PETROLEUM RESERVOIRS." In Modern and Ancient Carbonate Eolianites, 117–38. SEPM (Society for Sedimentary Geology), 2001. http://dx.doi.org/10.2110/pec.01.71.0117.

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5

Gottschalk, Petter. "IS/IT Outsourcing." In E-Business Strategy, Sourcing and Governance, 159–70. IGI Global, 2006. http://dx.doi.org/10.4018/978-1-59904-004-2.ch009.

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Information technology outsourcing—the practice of transferring IT assets, leases, staff, and management responsibility for delivery of services from internal IT functions to third party vendors—has become an undeniable trend ever since Kodak’s 1989 landmark decision. In recent years, private and public sector organizations worldwide have outsourced significant portions of their IT functions, among them British Aerospace, British Petroleum, Canadian Post Office, Chase Manhattan Bank, Continental Airlines, Continental Bank, First City, General Dynamics, Inland Revenue, JP Morgan, Kodak, Lufthansa, McDonnell Douglas, South Australian Government, Swiss Bank, Xerox, and Commonwealth Bank of Australia (Hirsheim & Lacity, 2000). How should firms organize their enterprise-wide activities related to the acquisition, deployment, and management of information technology? During the 1980s, IT professionals devoted considerable attention to this issue, primarily debating the virtues of centralized, decentralized, and federal modes of governance. Throughout the 1980s and 1990s, IT researchers anticipated and followed these debates, eventually reaching considerable consensus regarding the influence of different contingency factors on an enterprise’s choice of a particular governance mode (Sambamurthy & Zmud, 2000).
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Hutchison, Charles S. "The Geological Framework." In The Physical Geography of Southeast Asia. Oxford University Press, 2005. http://dx.doi.org/10.1093/oso/9780199248025.003.0011.

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This chapter outlines the principal geological features of the region, extending from Myanmar and Taiwan in the north, southwards to include all the ASEAN countries, and extending as far as northern Australia. The present-day lithospheric plates and plate margins are described, and the Cenozoic evolution of the region discussed. Within a general framework of convergent plate tectonics, Southeast Asia is also characterized by important extensional tectonics, resulting in the world’s greatest concentration of deep-water marginal basins and Cenozoic sedimentary basins, which have become the focus of the petroleum industry. The pre-Cenozoic geology is too complex for an adequate analysis in this chapter and the reader is referred to Hutchison (1989) for further details. A chronological account summarizing the major geological changes in Southeast Asia is given in Figure 1.2. The main geographical features of the region were established in the Triassic, when the large lithospheric plate of Sinoburmalaya (also known as Sibumasu), which had earlier rifted from the Australian part of Gondwanaland, and collided with and became sutured onto South China and Indochina, together named Cathaysia. The result was a great mountain-building event known as the Indosinian orogeny. Major granites were emplaced during this orogeny, with which the tin and tungsten mineral deposits were genetically related. The orogeny resulted in general uplift and the formation of major new landmasses, which have predominantly persisted as the present-day regional physical geography of Southeast Asia. The Indo-Australian Plate is converging at an average rate of 70 mm a−1 in a 003° direction, pushed from the active South Indian Ocean spreading axis. For the most part it is composed of the Indian Ocean, formed of oceanic sea-floor basalt overlain by deep water. It forms a convergent plate margin with the continental Eurasian Plate, beneath which it subducts at the Sunda or Java Trench. The Eurasian continental plate protrudes as a peninsular extension (Sundaland) southwards as far as Singapore, continuing beneath the shallow Straits of Malacca and the Sunda Shelf as the island of Sumatra and the northwestern part of Borneo.
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Тези доповідей конференцій з теми "Petroleum refineries South Australia"

1

Smith, S., and V. Rasouli. "Torque and drag modelling for Redhill South-1 in the Northern Perth Basin, Australia." In PETROLEUM 2012. Southampton, UK: WIT Press, 2012. http://dx.doi.org/10.2495/pmr120091.

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Alexander, Elinor. "Natural hydrogen exploration in South Australia." In PESA Symposium Qld 2022. PESA, 2022. http://dx.doi.org/10.36404/putz2691.

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South Australia has taken the lead nationally in enabling exploration licences for natural hydrogen. On 11 February 2021 the Petroleum and Geothermal Energy Regulations 2013 were amended to declare hydrogen, hydrogen compounds and by-products from hydrogen production regulated substances under the Petroleum and Geothermal Energy Act 2000 (PGE Act). Companies are now able to apply to explore for natural hydrogen via a Petroleum Exploration Licence (PEL) and the transmission of hydrogen or compounds of hydrogen are now permissible under the transmission pipeline licencing provisions of the PGE Act. The maximum area of a PEL is 10,000 square kilometres so they provide a large acreage position for explorers. PEL applicants need to provide evidence of their technical and financial capacity as well as a 5-year work program which could include field sampling, geophysical surveys (e.g., aeromagnetics, gravity, seismic and MT) and exploration drilling to evaluate the prospectivity of the licence for natural hydrogen. Since February 2021, seven companies have lodged 35 applications for petroleum exploration licences (PELs), targeting natural hydrogen. The first of these licences (PEL 687) over Kangaroo Island and southern Yorke Peninsula was granted to Gold Hydrogen Pty Ltd on 22 July 2021. As well as issuing exploration licences, a key role of the South Australian Department for Energy and Mining is to provide easy access to comprehensive geoscientific data submitted by mineral and petroleum explorers and departmental geoscientists since the State was founded in 1836. Access to old 1920s and 1930s reports, together with modern geophysical and well data has underpinned the current interest in hydrogen exploration. Why the interest? 50-80% hydrogen content was measured in 1931 by the Mines Department in gas samples from wells on Kangaroo Island, Yorke Peninsula and the Otway Basin, potential evidence that the natural formation of hydrogen has occurred. Iron-rich cratons and uranium-rich basement (also a target for geothermal energy explorers) occur in the Archaean-Mesoproterozoic Gawler Craton, Curnamona and Musgrave provinces which are in places fractured and seismically active with deep-seated faults. Sedimentary cover ranges from Neoproterozoic-Recent in age, with thick clastic, carbonate and coal measure successions in hydrocarbon prospective basins and, in places, occurrences of mafic intrusives and extrusives, iron stones, salt and anhydrite which could also be potential sources of natural hydrogen.
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Thompson*, Melissa, Shona MacDonald, Dariusz Jablonski, Stephen Molyneux, Peter Purcell, Marcia Edgley, Mike Isherwood, Rebecca Ryan, and Damian Kelly. "Phoenix South: A New Petroleum System in the Bedout Sub-Basin." In International Conference and Exhibition, Melbourne, Australia 13-16 September 2015. Society of Exploration Geophysicists and American Association of Petroleum Geologists, 2015. http://dx.doi.org/10.1190/ice2015-2210048.

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4

Parker, Rob, and Nick Parkhurst. "Perth, Western Australia Regional Headquarters for Companies Servicing The Australian and South East Asian Petroleum Industry." In Offshore Technology Conference. Offshore Technology Conference, 1998. http://dx.doi.org/10.4043/8634-ms.

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5

Zhang, Hui, Jianfeng Yao, Xiang Li, and Kai Zhao. "Maximising the Value of Multi-Sensor Streamer Data via MAZ Processing." In International Petroleum Technology Conference. IPTC, 2021. http://dx.doi.org/10.2523/iptc-21435-ms.

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Abstract The North West Shelf of Australia contains a late Paleozoic to Cenozoic sedimentary succession, which attains a thickness of over 10 km and is dominated by Triassic to Lower Cretaceous sediments. The deeper plays exist at multiple stratigraphic levels including oil-prone Jurassic sediments and faulted gas-prone Triassic sediments. The area has been proven difficult as far as seismic imaging is concerned, particularly over the Madeline trend. The presence of a hard, rugose water bottom, strong reflectors beneath the water bottom, and shallow Tertiary carbonates make the Dampier Sub-basin vulnerable to multiple contamination, amplitude distortion, lower signal-to-noise ratio (S/N) and unreliable AVO response. Poor seismic quality in the data has been a significant barrier to reducing exploration risk. In the 1990s, East Dampier (1992, blue polygon in Figure 1) and Keast (1997, yellow polygon in Figure 1) seismic data were acquired in East-West and North-South directions respectively, in an effort to better understand the impact from the shallow complex overburden. To address these challenges, the Demeter survey was acquired in 2003 (black polygon in Figure 1) with a denser acquisition grid. The overall seismic quality was improved, but the results still contained a significant level of residual multiples. Later, the Fortuna survey, the most comprehensive multi-sensor seismic survey on the North West Shelf of Australia to date, was acquired in 2014 with the aim to provide better subsurface imaging (pink polygon in Figure 1) from different acquisition perspectives. The data was processed with advanced processing technology, including shallow water demultiple, deghosting and high definition tilted orthorhombic velocity model building (Birdus et al., 2017). However, the final results were still suffering from a number of challenges, specifically: 1) strong residual multiple in near offsets, 2) low S/N ratio, particularly at reservoir level, and 3) inconsistency from near to far stack resulting in unreliable AVO. In this paper, the Dixon area (green polygon), considered as the most challenging area in the Dampier Sub-basin, was chosen as the testing area for our work. By integrating high-end imaging technology, for example dual-sensor deghosting, multi-survey surface related multiple elimination (MAZ-SRME), and multi-azimuth processing (MAZ stack), we will illustrate how we have overcome many of these imaging challenges.
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Звіти організацій з теми "Petroleum refineries South Australia"

1

Munday, S., D. S. Edwards, J. Chandra, L. Wang, A. Forbes, D. Riley, J. Anderson, E. Grosjean, A. Bailey, and C. J. Boreham. Exploring for the Future: defining a chemostratigraphic framework for the Officer Basin: inorganic and stable isotopic analyses of ten petroleum wells from Western Australia and South Australia. Geoscience Australia, 2022. http://dx.doi.org/10.11636/record.2022.007.

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