Journal articles on the topic 'Coal industry (Australia)'
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1
Walters, A. D. "Coal Preparation Developments in Indonesia and Australia." Energy Exploration & Exploitation 13, no. 4 (August 1995): 361–75. http://dx.doi.org/10.1177/014459879501300407.
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There is considerable development within the coal processing industries of both Indonesia and Australia. Indonesia is rapidly becoming a major coal producer of thermal coal and there is little need for conventional coal preparation of the generally low ash coal. However, much of Indonesia's lower grade coal is high moisture, high volatile sub-bituminous and new methods of thermal moisture reduction and briquetting will have to be used to increase quality, particularly for export. The coal briquetting industry in Indonesia is also planned to grow dramatically to some 4 M tpy to conserve Indonesia's oil products. Australia's mature coal industry has been carrying out a considerable amount of practical research and development with programmes that will result in improved process control and optimization resulting in increases in yield and better quality control.
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Sappal, Krishna K. "Geology and organic petrology of some selected Permian and Jurassic coals of Western Australia." Journal of Palaeosciences 45 (December 31, 1996): 33–40. http://dx.doi.org/10.54991/jop.1996.1216.
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The commercial coal resources of Western Australia occur in sediments ranging in age from Permian to Jurassic. The coal from each period has distinctive geographical, biological and geological characteristics which effects its utilization in industry and power generation. Currently the Permian intracratonic Collect Basin is the only producing coalfield in Western Australia. The annual production from this coalfield is approximately 6million tonnes, which is mostly used for power generation. Another Permian coal deposit in the Vasse Shelf, located in the southern part of the Perth Basin has potential for export to Asian markets. The Early Jurassic coal of the Hill River area in the northern Perth Basin has been fully explored and is ready for mining as a source for power generation. All three coal deposits represent a measured in situ resource in excess of 1500 million tonnes for Western Australia.
Similar to the Gondwana coals of Australia, the coals are finely banded and the dominant lithotypes are dull banded with minor bright and bright banded types. The maceral composition of the coal is variable, however, the macerals of vitrinite and inertinite groups dominate, and the exinite and mineral matter contents are low, particularly in the Permian coals. On the basis of petrology of coal and the inter-seam sediments the depositional environment for the Permian coal was braided fluvial and fluvio-lacustrine, with marked fluctuations in the water table. The low water table accounts for fusain and inertodetrinite in the coal. The depositional environment for the Jurassic coal was of a low delta with some marine influence, supported by the presence of framboidal pyrite and acritarchs in the coal measures.
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Dighton, P. F. "COAL SEAM METHANE—MEETING THE REQUIREMENTS OF BUYERS, FINANCIERS AND REGULATORS." APPEA Journal 40, no. 1 (2000): 751. http://dx.doi.org/10.1071/aj99053.
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Significant work is taking place in Queensland and New South Wales to make the recovery of natural gas from coal seams (Coal Seam Methane) a viable industry. At this stage there are still some daunting hurdles to overcome. Australian buyers and financiers remain sceptical on resource risk and continuity of supply issues. In the USA commercial production has been taking place for 20 years, but the industry was only able to achieve credibility and viability by relying on tax breaks. Unfortunately, the same type of government incentives are not present in Australia. Whether, in the absence of these incentives, Australian producers can harness the resource on an economic basis remains to be seen.
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Kassler, M. "Robots and mining: the implications for Australian industry in the 1980's." Robotica 3, no. 1 (January 1985): 13–19. http://dx.doi.org/10.1017/s0263574700001429.
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SummaryAfter elucidating the terms ‘mining’ and ‘robot’, a historical background to the problem of mining is described, with emphasis on the use of technology. Various reasons for the increasing utilisation of technology are discussed, as regards the mechanisation of existing operations and those unachievable without new technology. It is asserted that the mining industry has a number of particular features that make increasing mechanisation especially attractive. The point is made that the ultimate stage of the historical tendency towards the use of new technology is fully automatic mining, a goal that may not be realised, however, in the next decade.The above historical discussion is followed by a critical appraisal of the conservative nature of the Australian industry and the study of the various factors that contribute to the slow uptake of new technology in mining.Attention is then concentrated on the general problem of robots and mining. It is shown that worldwide there were no applications of robots to mining up to the end of 1981. A wide study has been carried out to identify some uses of robots in mining, but without success.The next topic to be discussed is the widespread confusion about robots and teleoperators. The fundamental difference between the two is underlined, and particular attention is paid to Thring's teleoperator mining concept (telechiric mining). It is emphasized that telechiric mining will have no significant impact upon Australian mining in this decade.These pessimistic asssessments are followed by claims that in some areas robotic concepts, though not robots themselves, could have a considerable effect on mining automation in the 1980's, both in Australia and elsewhere. The following projects are enumerated as possible candidates for applying robotic concepts: Surface mining; Mine development; Underground coal transport; Coal winning; Coal preparation. In order to make progress, it is recommended that a robotics expert ought to be included in the interdisciplinary teams studying the problem of mining automation.The last part of this paper is devoted to Australia's need for robotic mining. A list of systems involving robotic concepts is presented that may be realised in the current decade. It is maintained that Australia ought to develop a few of such systems for the domestic and international markets, and that the short-term needs of the Australian mining industry are fundamentally different from those of other Australian industries as regards robots. Hence, decisions regarding robots for mining should be made independently from those appertaining to automation problems of other industries.
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Lambourne, A. N., B. J. Evans, and P. J. Hatherly. "The application of the 3D seismic surveying technique to coal seam imaging: case histories from the Arckaringa and Sydney basins." Exploration Geophysics 20, no. 2 (1989): 137. http://dx.doi.org/10.1071/eg989137.
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Two dimensional seismic surveying is commonly used in the coal mining industry to assist the mining and development of coal deposits by seismically imaging coal seams. A specialised three dimensional seismic surveying technique has recently been performed over coal mining leases in South Australia and New South Wales, to trial its applicability to coal mine planning and extraction operations.The first two case histories of its trial in Australia are presented, and the conclusion drawn that the specialised three dimensional technique developed to date offers the ability to image coal seams in three dimensions and thereby improve mine planning in regions of complex faulting.
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Dello, Lou. "2011 PESA industry review: production and development." APPEA Journal 52, no. 1 (2012): 89. http://dx.doi.org/10.1071/aj11007.
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2011 was a lacklustre year for Australian hydrocarbon production, however a stellar year for LNG development. Domestic gas production was flat despite two new gas developments, Reindeer/Devil Creek and Halyard/Spar, which came into production during the year. Oil production fell, primarily due to the redevelopment of North West Shelf oil facilities, with Kitan in the Timor Sea being the only new offshore oil field that commenced production. LNG production was also flat however, Final Investment Decisions (FID) were announced for five new LNG projects, including Ichthys early in 2012, bringing the combined value of all eight sanctioned LNG projects to more than $180 billion. This is a huge volume of development, not only for the industry but for the whole Australian economy. Importantly, it has also moved Australia closer to becoming the world’s largest LNG producer. Increasing development costs and competition for skilled labour still remain the biggest challenges for the industry. Introduction of the carbon tax was also an important development in 2011, marking a significant step towards a low-carbon economy and increasing the opportunity for natural gas, but also burdening trade-exposed industries like LNG. The success of unconventional gas in the United States and CSG in Australia has sparked a step-change in exploration and development of unconventional gas in onshore Australia. Consolidation in coal seam gas sector continued on the east coast with the two acquisitions of Eastern Star Gas by Santos and Bow Energy by Arrow Energy. Continuing to effectively engage with the community will be central to the industry’s success.
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Azadi, Mehdi, Mansour Edraki, Faezeh Farhang, and Jiwhan Ahn. "Opportunities for Mineral Carbonation in Australia’s Mining Industry." Sustainability 11, no. 5 (February 27, 2019): 1250. http://dx.doi.org/10.3390/su11051250.
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Carbon capture, utilisation and storage (CCUS) via mineral carbonation is an effective method for long-term storage of carbon dioxide and combating climate change. Implemented at a large-scale, it provides a viable solution to harvesting and storing the modern crisis of GHGs emissions. To date, technological and economic barriers have inhibited broad-scale utilisation of mineral carbonation at industrial scales. This paper outlines the mineral carbonation process; discusses drivers and barriers of mineral carbonation deployment in Australian mining; and, finally, proposes a unique approach to commercially viable CCUS within the Australian mining industry by integrating mine waste management with mine site rehabilitation, and leveraging relationships with local coal-fired power station. This paper discusses using alkaline mine and coal-fired power station waste (fly ash, red mud, and ultramafic mine tailings, i.e., nickel, diamond, PGE (platinum group elements), and legacy asbestos mine tailings) as the feedstock for CCUS to produce environmentally benign materials, which can be used in mine reclamation. Geographical proximity of mining operations, mining waste storage facilities and coal-fired power stations in Australia are identified; and possible synergies between them are discussed. This paper demonstrates that large-scale alkaline waste production and mine site reclamation can become integrated to mechanise CCUS. Furthermore, financial liabilities associated with such waste management and site reclamation could overcome many of the current economic setbacks of retrofitting CCUS in the mining industry. An improved approach to commercially viable climate change mitigation strategies available to the mining industry is reviewed in this paper.
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Kondratiev, V. B. "Australian Mining Industry: Positions and Perspectives." Mining Industry Journal (Gornay Promishlennost), no. 1/2022 (March 15, 2022): 91–102. http://dx.doi.org/10.30686/1609-9192-2022-1-91-102.
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Australia has a world-leading mining industry as a producer for some 16 commodities including gold, bauxite, iron ore, rare earths, zinc, nickel and coal. In 2021, Australia’s mineral exports (excluding petroleum products) amounted to $200 billion which was 58% of all good’s export and 46% of all exported goods and services. In 2021, mining accounted for more than 10% of gross national product. In addition, the mining industry employed some 240 000 people, with many more employed by related industries. Australia is richly endowed with many minerals, that are regarded as critical, or strategic, minerals by many trading partners. Growing markets for these commodities, particularly for those associated with emerging technologies such as battery storage, renewable energy and electric vehicles have stimulated exploration and resource delineation in Australia in recent years
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Cooney, Phillip. "2011 PESA industry review: exploration." APPEA Journal 52, no. 1 (2012): 67. http://dx.doi.org/10.1071/aj11006.
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A continuing high and stable oil price through the latter part of 2011, oscillating around US$120 in the case of Tapis Crude, underpinned a small increase in exploration in 2011 in Australia compared with 2010, although there were marked regional differences between the northwest and southeast parts of the country. Exploration continued to be focused on the northwest offshore seeking incremental reserve additions of conventional gas to support planned and proposed liquid natural gas (LNG) projects and although information is hard to confirm, in general this program appears to have been successful with a number of relatively smaller discoveries and at least one major find, Zola–1. In the Cooper Basin exploration activity resumed after almost being shut down by floods in 2010, although flooding continued to be a problem in 2011. In the South Australian part, 27 new field wildcat (NFW) wells were drilled in 2011 compared with 8 in 2010. The program was also marked by a high rate of success. The other current major area of activity, the Queensland coal seam gas (CSG) program was also affected by flooding early in 2011 with 524 coal seam gas (CSG) wells drilled this year, compared with 648 in 2010 and more than 900 in 2009. In many jurisdictions shale gas or shale oil wells are not reported separately and are included in conventional petroleum wells in this report. Exploration for geothermal resources continued at a relatively low level with only 10 wells drilled in Australia in 2011, the most active state was Victoria with five wells. Despite the increase in activity, preliminary indications are that total exploration expenditure in 2011 will be less than in 2010. It is interesting to note that while the exploration effort in terms of wells and seismic has not changed much in the last few years the total expenditure has steadily increased in part reflecting the movement into deeper water drilling.
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Baker, G. L., and W. R. Skerman. "THE SIGNIFICANCE OF COAL SEAM GAS IN EASTERN QUEENSLAND." APPEA Journal 46, no. 1 (2006): 329. http://dx.doi.org/10.1071/aj05018.
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The commercial production of coal seam gas [CSG] in Australia is only a decade old. Over the last 10 years it has become a significant part of the Australian gas industry, particularly in Queensland where about 31 PJ or 30% of all natural gas used in the State was recovered from coal seams in eastern Queensland. In 2005 CSG was expected to have supplied 55 PJ or 44 % of the eastern Queensland gas demand. The mining, mineral processing and power generations in northwest Queensland, serviced by the Carpentaria Gas Pipeline, will continue to use gas from the Cooper-Eromanga Basin.The CSG industry is reaching a stage of maturity following the commissioning of a number of fields while some significant new projects are either in the commissioning phase or under development. By the end of 2008 CSG production in Queensland is expected to reach 150 PJ per year, the quantity needed to meet Gas Supply Agreements for CSG that are presently in place.Certified Proved and Probable (2P) gas reserves at 30 June 2005 in eastern Queensland were calculated to be 4,579 PJ, of which 4,283 PJ were CSG. Gas reserves (2P) for eastern Queensland a decade earlier were less than 100 PJ with those for CSG being less than 5 PJ.The coal seam gas industry in both the Bowen and Surat basins—which includes major gas producers such as Origin Energy Limited and Santos Limited along with smaller producers such as Arrow Energy NL, CH4 Gas Limited, Molopo Australia Limited and Queensland Gas Company Limited—is now accepted by major gas users as being suppliers of another reliable source of natural gas.
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Slater, Sue. "PESA industry review—2009 environmental update." APPEA Journal 50, no. 1 (2010): 143. http://dx.doi.org/10.1071/aj09010.
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This paper provides a brief update on some of the key environmental issues that arose during 2009. In Queensland, activity is dominated by coal seam gas projects and specifically coal seam gas (CSG) to liquefied natural gas (LNG) projects. Environmental milestones for these projects are discussed, and the State Government’s response policy and regulation development response is reviewed. The progress of the more conventional LNG projects in Western Australia and the Northern Territory is also discussed. The final report on the mandated ten year review of the Environment Protection and Biodiversity Conservation Act 1999 was released in December 2009. Seventy-one recommendations were made, and some key recommendations related to our industry are discussed here. Climate change has again dominated the media, with the United Nations Climate Change Conference held in Copenhagen in December 2009. In Queensland, the Government released a paper that presented a range of strategies and policies, building on a number of existing schemes and introducing new measures. Gas is identified as a key transitional fuel while low emission coal technology and emerging renewable energy sources are being developed. Greenhouse gas legislation is continuing to be developed across several states, but subordinate legislation is yet to be finalised. In Victoria, submissions on the Greenhouse Gas Geological Sequestration Regulations closed in October 2009, and the Greenhouse Gas Geological Sequestration Act 2008 came into effect on 1 December 2009. In March 2009, ten offshore acreage releases were made under the Commonwealth legislation; however, the closing date for submissions is dependent upon the development of the regulations. South Australia passed an Act amending the Petroleum and Geothermal Act 2000 on 1 October 2009 to allow geosequestration. A number of reviews of the regulatory framework or the administrative systems associated with the upstream oil and gas sector have been completed in the last decade. All these reviews make similar findings and recommendations, and most recently the Jones Report, tabled in Western Australian Parliament on 12 August 2009, found that most key recommendations from previous reports and reviews had not been addressed or properly implemented. There seems to be little point in undertaking regulatory and system reviews that consistently make similar findings, if these findings are never addressed. The hurdles to implementation of key recommendations need to be identified, so that progress can be made in improving the approvals processes for the industry, and improving the environmental outcomes.
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Sebire, Tamara. "PESA 2010 production and development review." APPEA Journal 51, no. 1 (2011): 167. http://dx.doi.org/10.1071/aj10011.
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2010 was another busy year for Australian hydrocarbon production and development. Natural gas production was the standout performer with both domestic gas and LNG production increasing by about 5% compared to 2009. Domestic gas output was strong with significant growth in production from the Gippsland Basin, coal seam methane in the Surat-Bowen Basin, and the start-up of the Blacktip gas project in WA. Domestic gas output is set to reach record levels again next year and has strong growth prospects in the future with final investment decisions being taken on coal seam gas projects in Queensland and the Macedon project in WA. Australian LNG production increased 4.5% in 2010 accounting for 34% of Australian hydrocarbon production. LNG production will grow further in 2011 with first gas expected from Pluto LNG project during the year. Oil production was steady in 2010; however, it is set to increase in 2011 with a full year of production from the Van Gogh and Pyrenees projects. Production levels only tell part of the Australian hydrocarbon story. In addition to the proposed domestic gas and oil projects, the combined value of committed and potential LNG projects in Australia has surpassed $100 billion. A highlight of 2010 was the final investment decision on the A$15 bn Queensland Curtis LNG Project (QCLNG). The first phase of QCLNG will consist of two LNG trains with a combined capacity of 8.5 million tonnes per annum, with first LNG exports expected in 2014. QCLNG is the first of many proposed coal seam gas to LNG (CSG-LNG) developments in Queensland. Other CSG-LNG projects reached significant milestones this year. Of particular note is the federal environmental approval of Gladstone LNG and state environmental approval of Australia Pacific LNG. In WA, the Browse LNG project complied with all Browse Basin retention lease conditions and remains on track for a targeted final investment decision in 2012. Other major LNG projects including Ichthys and Wheatstone also continue to make positive progress towards a final investment decision in the next 24 months. Sunrise, Prelude and Bonaparte LNG set a technology milestone in the industry with all three selecting floating LNG (FLNG) as their preferred development concept. 2010 has also seen the emergence of further new technologies in the form of small scale LNG projects for resources previously considered un-commercial. This has opened the door for South Australia and New South Wales to enter the LNG export market in the future. The Australian hydrocarbon industry continues to grow and its global importance, particularly in LNG, reflected by the increasing number of foreign companies entering Australia. In 2010, Shell and PetroChina increased their involvement in the Australian industry purchasing Arrow Energy for A$3.5 bn. CNOOC has increased its involvement in a number of areas, including purchasing a 5–10% stake in QCLNG and investment in CSM exploration through Exoma Energy. GDF Suez and Total have reinvigorated their interests in offshore WA and Petrobras made their first entry into Australia acquiring an interest in exploration acreage offshore WA. 2010 was an active year for Australian hydrocarbon production and development–continued success depends on the successful execution of committed and proposed projects. Escalation of development costs and a looming skills shortage remain the largest risks to the Australian hydrocarbon industry as multiple projects attempt to move forward simultaneously.
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Cottle, Drew, and Angela Keys. "Open-cut coal mining in Australia's Hunter Valley: Sustainability and the industry's economic, ecological and social implications." International Journal of Rural Law and Policy, no. 1 (September 10, 2014): 1–7. http://dx.doi.org/10.5130/ijrlp.i1.2014.3844.
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This article questions the sustainability of open-cut coal mining in the Hunter Valley region of Australia. The issue of sustainability is examined in relation to the economic, ecological and social implications of the Hunter Valley’s open-cut coal mining industry. The article demonstrates that critical social and ecological ramifications have been overshadowed by the open-cut coal mining industry’s importance to the economy of the Hunter region and of New South Wales.
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Petersen, Andrew, and Hugh McKerrow. "Coal seam gas in Australia's progression to a low carbon economy." APPEA Journal 49, no. 2 (2009): 577. http://dx.doi.org/10.1071/aj08050.
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The previous decade has witnessed an unprecedented increase in societal appreciation for the existence of climate change and its associated impacts. One need only look to the reports of the Intergovernmental Panel on Climate Change (IPCC) for evidence—between 1990 and 2007, scientific acceptance of the anthropogenic nature of climate change has risen from merely perhaps in 1990 to a certainty of 90% in 2007. As governments look to create imposts on the very emissions causing climate change, be it through emissions trading schemes (ETS) or through carbon taxes, an equally stark appreciation has occurred in relation to the need to switch to low emissions fuel source in the absence of carbon capture and storage. In contrast to the introduction of the EU ETS, fuel switching in Australia will be more problematic—now Australia sources only a small fraction of its energy supply from renewable energy sources and it will take some time for this to change. What is therefore needed, is a transition fuel—a fuel that will provide Australia with a stepping stone to a sustainable future while at the same time ensuring the security of our energy supply. Coal seam gas (CSG) could play an important part in this progression. Its role is not, however, without its complexities. In a world of daily regulatory and market developments, the CSG industry will need to incorporate both Australian and international climate change issues into its development plans - its physical, reputational, regulatory and market risks and opportunities. This extended abstract will examine the links between these exposures and the future growth potential of the industry.
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Sribna, Yevheniia, Olena Trokhymets, Ihor Nosatov, and Iryna Kriukova. "The globalization of the world coal market – contradictions and trends." E3S Web of Conferences 123 (2019): 01044. http://dx.doi.org/10.1051/e3sconf/201912301044.
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The article describes the global coal market as the ratio of demand and supply depending on the development of energy technologies in the historical section. The continental specificity of coal mining is given. The basic world exporters and importers of coal and their role in the sale of energy fuels are analyzed. The key coal producing countries are China, India, the USA, and Australia. The largest consumers of coal products are China, India, Japan and Korea. There are unconditional leaders in the export coal market: Indonesia and Australia. In addition, a comparison of large coal companies and their share in the world market is presented. The features of coal supplies are analyzed in accordance with international rules (Incoterms), which regulate the rights and obligations of the buyer when conducting international trade, as well as determine the moment of transfer of risks from the seller to the buyer. The following supply bases were characterized: FOB (Free On Board), FAS (Free Alongside Ship), CIF (Cost Insurance and Freight), DAP (Delivered At Place), FCA (Free Carrier) etc. Trends in the logistics component of the global coal industry are revealed. Logistic of coal supply chains in comparison with other energy fuels and their features are disclosed. The problem of profitability of mines and their effectiveness is presented. Assessment of the environmental components of coal use in industry and energy is analyzed. It was noted that on the background of the trend to protect the environment and promote renewable energy, coal is becoming less popular in developed countries. This trend is further exacerbated by state subsidies for green energy.
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Hartwell, John. "2009 Release of offshore petroleum exploration acreage." APPEA Journal 49, no. 1 (2009): 463. http://dx.doi.org/10.1071/aj08030.
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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.
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Miyazaki, S. "COAL SEAM GAS EXPLORATION, DEVELOPMENT AND RESOURCES IN AUSTRALIA: A NATIONAL PERSPECTIVE." APPEA Journal 45, no. 1 (2005): 131. http://dx.doi.org/10.1071/aj04011.
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A total of 2,223 PJ of proved plus probable gas reserves has been identified in coal seam gas fields and pilot production areas in Australia. The production of coal seam gas is rapidly growing, reaching about 40 PJ per year in 2003. A total of more than 108 PJ will be supplied annually by the end of 2007 under existing contracts, representing about 9% of Australia’s projected total primary consumption of natural gas. About two thirds of Queensland’s natural gas consumption will be met by coal seam gas by the end of 2007. Further expansion of the coal seam gas industry depends largely on the medium-term production performance of the pioneering production projects now in operation.The long-term production performance of a coal seam gas well is not well understood. Analogues of conventional natural gas have often been applied to the estimation process of coal seam gas reserves without proper consideration of the fundamental differences in trapping mechanisms and production techniques. Definitions of petroleum reserves recommended by various organisations are not always applicable to coal seam gas, and the inconsistent application of reserves definitions may have resulted in inconsistencies in reserves reporting in Australia.
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Baker, G., and S. Slater. "Coal seam gas—an increasingly significant source of natural gas in eastern Australia." APPEA Journal 49, no. 1 (2009): 79. http://dx.doi.org/10.1071/aj08007.
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The commercial production of coal seam gas (CSG) in Australia commenced in 1996. Since then its production has grown up significantly, particularly in the last five years, to become an integral part of the upstream gas industry in eastern Australia. The major growth in both CSG reserves and production has been in the Bowen and Surat basins in Queensland. Active exploration and appraisal programs with the first pilot operations were established in the Galilee Basin in 2008; however, an important reserve base has been built up in New South Wales in the Clarence-Moreton, Gloucester, Gunnedah and Sydney basins. There has been modest CSG production from the Sydney Basin for some years with commercial production expected to commence in the other three basins by or during 2010. Exploration for CSG has been undertaken in Victoria and Tasmania while programs are being developed in South Australia focussing on the Arckaringa Basin. Elsewhere in Australia planning is being undertaken for CSG exploration programs for the Pedirka Basin in the Northern Territory and the Perth Basin in Western Australia. CSG was being supplied into the eastern Australian natural gas market at 31 December 2008 at a rate of approximately 458 TJ per day (167 PJ per year). Queensland is currently producing 96.7% of this total. Approximately 88% of the natural gas used in Queensland is CSG. Currently, CSG accounts for nearly 25% of the eastern Australian natural gas market, estimated at 670 PJ per year. The production of CSG is now a mature activity that has achieved commercial acceptability, especially for coal seam derived gas from the Bowen and Surat basins. The recent proposals by a number of local CSG producers—in joint venture arrangements with major international groups—to produce liquefied natural gas (LNG) from CSG along with a number of merger and acquisition proposals, is testimony to the growing economic and commercial significance of the CSG sector. Should all of the proposed CSG based LNG projects eventuate, LNG output would be approximately 40 million tones per year. This will require raw CSG production to increase to approximately 2,600 PJ per year, resulting in a four fold increase from the present natural gas consumption in eastern Australia. The proved and probable (2P) reserves of CSG in eastern Australia at 31 December 2008 were 17,011 PJ or 60.2% of the total independently audited 2P natural gas reserves of 28,252 PJ. The Bowen and Surat basins with 16,120 PJ have the largest onshore gas reserves eastern Australia. In New South Wales, the 2P CSG reserves at the end of 2008 were 892 PJ, though this is expected to increase significantly over the next 12 months. Major upstream natural gas producers such as Origin Energy Limited and Santos Limited both hold over 50% of their Australian 2P gas reserves as CSG. The 1P reserves of CSG in eastern Australia at 31 December were reported as 4,197 PJ while the 3P reserves of CSG at the same date were 40,480 PJ. Most companies in the CSG sector are undertaking development work to upgrade their 3P reserves (and contingent resources) into the 2P category. The CSG resource in eastern Australia is very large. Companies with interests in CSG have reported in excess of 200,000 PJ as gas in place in the Bowen, Clarence-Moreton, Galilee, Gloucester, Gunnedah, Queensland Coastal, Surat and Sydney basins. The 2P reserves of CSG are expected to exceed 20,000 PJ by the end of 2009. A significant part of the expected large increase in 2P reserves of gas initially will be dedicated to the proposed LNG projects being considered for Gladstone. The major issues confronting the CSG industry and its rapid growth are concerned with land access, overlapping tenure (particularly in Queensland with underground coal gasification) the management and beneficial use of co-product formation water and gas production ramp up factors associated with the proposed LNG projects.
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Diniz Da Costa, J. C., P. Prasad, and R. J. Pagan. "Modern Environmental Improvement Pathways for the Coal Power Generation Industry in Australia." Process Safety and Environmental Protection 82, no. 3 (May 2004): 191–99. http://dx.doi.org/10.1205/095758204323065957.
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Beeson, Mark. "Australia-Japan Trade Relations: The Coal Industry as a Case in Point." Australian Quarterly 67, no. 3 (1995): 66. http://dx.doi.org/10.2307/20635828.
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GALIEV, Zhaken Kakitaevich, and Nadezhda Valentinovna GALIEVA. "Coal industry development strategy in domestic and foreign markets." NEWS of the Ural State Mining University, no. 4 (December 20, 2020): 212–17. http://dx.doi.org/10.21440/2307-2091-2020-4-212-217.
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Relevance. In the current context, the cost of coal products is growing. Labor productivity in coal mines and open-pit mines is significantly lower than the corresponding indicator in North America and Australia, a significant proportion of unprofitable enterprises, despite the fact that a third of the world’s coal resources and a fifth of the proven reserves are concentrated in the Russian Federation. In these circumstances, the substantiation of the strategic development of the coal industry on the basis of a SWOT analysis is of great importance. Purpose of the study is to substantiate the strategic vision for the development of the coal industry, priorities for the functioning of coal mining enterprises. Research methods are scientific generalization, method of system analysis and analogies. Results. In the course of the study, the possibilities of functioning of coal mining enterprises, threats to the coal industry, strengths and weaknesses of their activities were identified. The ability to function is determined by the presence of huge coal reserves in Russia, the leadership in its production and export, and a significant share of coking coal grades. The identified threats include: a significant decrease in prices on the world market and coal consumption in the domestic market, an increase in the average transportation distance and the risks of introducing environmental restrictions. The weaknesses in the activities of coal mining enterprises, requiring appropriate measures to be taken to liquidate them, come down to the following: increased operating costs, low labor productivity, a significant number of small mines and open-pit mines that hinder the effective development of the industry as a whole. At the same time, the strategy for further development should focus on the strengths of the coal mining enterprises. These include lower capital investments based on conventional fuel, significantly lower than in the oil and gas industry, therefore, during the period of ensuring sustainable development of the economy as a whole, the development of the coal industry will require lower costs, which creates conditions for the development of other related industries, the possibility of introducing an economic mechanism of inter-fuel competition, as well as the effective functioning of the market structure within the “free” oligopoly. Increasing the competitiveness of coal mining enterprises requires the use of accelerated depreciation methods at export-oriented enterprises, the introduction of problem-solving technology at large coal mining enterprises, the establishment of a rational ratio of the used imported and Russian equipment, and the containment of the growth in the cost of railway transport services. The focus on the implementation of the concept of creating a digital industrial enterprise in the industry plays a special role. A number of measures should be taken to improve financial stability. Conclusions. The identified opportunities and threats, as well as the strengths and weaknesses of the activities of coal mining enterprises, serve as the basis for substantiating the “Strategy for the development of the coal industry”, determine promising directions for the future of coal mining enterprises.
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Lavin, Ciaran, Terry Walker, and Yvette Knowles. "2010 PESA industry review–exploration." APPEA Journal 51, no. 1 (2011): 147. http://dx.doi.org/10.1071/aj10010.
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An uncertain global economy, offset by strong commodity prices, provided the backdrop to a subdued yet solid level of exploration activity in 2010. The major loci of activity in the Australian oil and gas industry were the Exmouth Plateau, where exploration for conventional gas in support of LNG projects was the primary driver, and the Bowen/Surat Basin, where coal seam gas (CSG) for LNG was the main target. Onshore permit awards dominated new licensing in 2010, with 31 exploration permits awarded over an area of 190,000 km2. The majority of these permits are focused on unconventional gas exploration. Conversely only 14 exploration permits (30,000 km) were awarded offshore, all in northwest Australia. This historically low level can be related to an already extensive coverage of existing permits in the offshore petroleum provinces and delays in the announcement of acreage awards from the 2009(II) acreage release. Twenty-nine 2D seismic surveys were started in 2010, with three still active at the end of the year. Once completed, the 2010 surveys will total nearly 37,000 km of data, with 76% offshore. Twenty-one 3D seismic surveys commenced in 2010, with six still active at year end. The 2010 surveys will ultimately comprise approximately 29,000 km2 of data, with 95% offshore. Northwest Australia dominated seismic activities. Exploration drilling for conventional hydrocarbon resources was relatively subdued in 2010, with 63 wells spudded, compared to 92 wells in 2008 and 74 in 2009. Of the 49 wildcat wells where results are known, 51% reported hydrocarbon discoveries. This was a little less than the 57% in 2009 and up on the 39% in 2008. The discoveries were distributed across most of the traditional petroleum provinces. High levels of CSG drilling continued in 2010, exceeding 2008 activity but less than that of 2009. At least 648 CSG wells were spudded in 2010, mostly in the new heartland plays of the Bowen/Surat, Gunnedah and Clarence-Moreton basins. This compares with more than 600 CSG wells drilled in 2008 and more than 900 in 2009. The first dedicated Australian shale gas exploration drilling took place in 2010. Emerging shale plays in the Cooper and Perth basins were tested.
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Neininger, Bruno G., Bryce F. J. Kelly, Jorg M. Hacker, Xinyi LU, and Stefan Schwietzke. "Coal seam gas industry methane emissions in the Surat Basin, Australia: comparing airborne measurements with inventories." Philosophical Transactions of the Royal Society A: Mathematical, Physical and Engineering Sciences 379, no. 2210 (September 27, 2021): 20200458. http://dx.doi.org/10.1098/rsta.2020.0458.
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Coal seam gas (CSG) accounts for about one-quarter of natural gas production in Australia and rapidly increasing amounts globally. This is the first study worldwide using airborne measurement techniques to quantify methane (CH 4 ) emissions from a producing CSG field: the Surat Basin, Queensland, Australia. Spatially resolved CH 4 emissions were quantified from all major sources based on top-down (TD) and bottom-up (BU) approaches, the latter using Australia's UNFCCC reporting workflow. Based on our TD-validated BU inventory, CSG sources emit about 0.4% of the produced gas, comparable to onshore dry gas fields in the USA and The Netherlands, but substantially smaller than in other onshore regions, especially those where oil is co-produced (wet gas). The CSG CH 4 emission per unit of gas production determined in this study is two to three times higher than existing inventories for the region. Our results indicate that the BU emission factors for feedlots and grazing cattle need review, possibly requiring an increase for Queensland's conditions. In some subregions, the BU estimate for gathering and boosting stations is potentially too high. The results from our iterative BU inventory process, which feeds into TD data, illustrate how global characterization of CH 4 emissions could be improved by incorporating empirical TD verification surveys into national reporting. This article is part of a discussion meeting issue ‘Rising methane: is warming feeding warming? (part 1)’.
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McMahon, Xavier T., and Jake D. Williams. "'Lawfare' in the oil and gas industry." APPEA Journal 59, no. 2 (2019): 651. http://dx.doi.org/10.1071/aj18251.
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There is a growing concern within the resources industry about activists’ use of the legal system to disrupt and delay major projects. Currently, referred to by many as ‘lawfare’, the tactic is not new. However, recent challenges to high profile cases, such as the Adani Carmichael Coal Project, has brought renewed focus to the tactics being used by activists to further their agendas, and a perception at least that the risk to the industry is ever increasing. This paper looks at trends and novel developments in national and international environmental law, and considers what implications this may have for the development of oil and gas projects in Australia.
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Post, D. A., and P. A. Baker. "Determining the impacts of coal seam gas extraction on water resources and water-dependent assets." APPEA Journal 57, no. 2 (2017): 519. http://dx.doi.org/10.1071/aj16194.
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As recently as two years ago, there were numerous proposals to develop coal seam gas projects across eastern Australia. Today the picture is very different. While significant coal seam gas development has occurred in the Surat Basin, Metgasco has surrendered their licences and AGL have indicated that they will not proceed in Gloucester. The only coal seam gas development that is still proceeding in NSW is Santos’s proposal in the Liverpool Plains (Namoi). However, recent developments in Australian Government policy to increase gas supply on the eastern seaboard means that the results of these assessments will inform future decisions. Research carried out as part of the Bioregional Assessment Programme (BAP) has shown some surprising results in the Richmond River (Clarence-Moreton bioregion) regarding the potential impacts of coal seam gas development on the water resources and water-dependent assets of that region. This study will show how we developed a groundwater and surface water cumulative impact model in the Clarence-Moreton bioregion, and present the key findings from that modelling. Similar cumulative impact assessments are currently underway in the Maranoa-Balonne-Condamine, Gloucester, Hunter, Galilee, and Namoi regions and we expect these to be published by late 2017. As part of a core tenet of transparency in the BAP, the data collected and models developed as part of these assessments will be freely available for Industry proponents, State regulators and other interested parties to access and utilise. The Surat cumulative management area in south-eastern Queensland has provided a structure for developing coal seam gas resources while protecting water resources via a cumulative approach to management. We propose that the models we have developed would provide the basis of a similar structure to assess and manage cumulative impacts in regions across Australia that may see coal seam gas or other forms of unconventional gas development.
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Grollman, N. G. "ENVIRONMENTALLY SUSTAINABLE ENERGY FOR THE EAST ASIA/PACIFIC REGION: IMPLICATIONS AND OPPORTUNITIES FOR AUSTRALIAN OIL AND GAS EXPLORERS AND PRODUCERS." APPEA Journal 37, no. 1 (1997): 722. http://dx.doi.org/10.1071/aj96055.
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The oil and gas reserves of Australia and the East Asian region fall well short of the region's long-term requirements, even for a scenario that phases out all fossil fuels by the end of the 21st century. There is, therefore, no contradiction between vigorous exploration for oil and gas and the process of transition to renewable energy sources. However, to be an independent player in environmental policy-making, the Australian petroleum exploration industry should focus on its particular role within the energy sector as a whole, whose nature will change radically over the next several decades. This role will combine concerns over long term oil supply security with, in particular, the objective of reducing greenhouse gas emissions from oil and gas consumption to levels commensurate with Australia's international obligations. The role extends to Australian involvement in the region as a whole through the accrual of emissions credits from projects implemented jointly with developing countries. It also envisages that Australian explorers, especially those focussed on gas, will form alliances with downstream companies, power generators, appliance manufacturers and energy marketers as links in an integrated chain of operations with value added and emissions reduced at each stage. This re-orientation should lead the industry to question the extent to which its interests correspond with those of the coal and mineral industries, which do not face the same resource limitations.
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Brooks, Deidre. "2012 PESA industry review—exploration." APPEA Journal 53, no. 1 (2013): 141. http://dx.doi.org/10.1071/aj12012.
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The Australian exploration landscape experienced an escalation of unconventional activity in 2012. Drilling targeting shale oil and gas, basin-centred tight gas, and coal gas is on the increase compared to previous years. Drilling for onshore oil and large offshore gas continued to be a staple activity for the year although, in general, offshore, the number of wells drilled is continuing to decline, in line with previous years. A number of very large 3D seismic surveys were acquired in 2012 and this is hoped to provide many future drilling targets. Within Australia, 19 new offshore conventional petroleum exploration permits were awarded within the Commonwealth jurisdiction (compared to 24 in 2011), of which 15 are located in WA, two in Victoria, one in NT, and one in the Territory of Ashmore and Cartier Islands (NT). Onshore exploration tenures awarded in 2012 included four in WA, 14 in NT, six in Queensland, and nine conventional and six geothermal in SA. At least 25 3D and six 2D seismic surveys were acquired offshore in 2012, including some very large 3D marine surveys, the largest covering an area of 12,417 km2. Onshore seismic activity was highest in Queensland and SA where 33 and 11 surveys were acquired, respectively. Offshore, 21 conventional petroleum exploration wells were drilled during the year, which resulted in 11 announced discoveries. Two exploration wells, which were spudded late in 2011, were announced as discoveries early in 2012. Five wells, which were spudded in 2012, were still drilling at year end. This equates to a better than 50% technical success rate for offshore exploration drilling for all well results known at year end. All but two of these wells were located in WA waters, the others being located in NT and Victoria. Australia-wide onshore drilling was more active than in 2011 and, as is reflected in the seismic activity, the most wells (1,048) were drilled in Queensland (dominated by CSG drilling), followed by SA (77).
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SLATTERY, CHRISTIAN HARRIS. "‘Fossil Fueling the Apocalypse’: Australian Coal Subsidies and the Agreement on Subsidies and Countervailing Measures." World Trade Review 18, no. 1 (March 12, 2018): 109–32. http://dx.doi.org/10.1017/s1474745618000022.
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AbstractGlobal fossil fuel subsidies are substantial and contribute to climate change. They also undermine the ambitions of the Paris Agreement. However, under the WTO, the international community's foremost economic institution, it is renewable energy subsidies, not fossil fuel subsidies, that have been subjected to litigation. To date, no fossil fuel subsidy has ever been brought before the WTO's Dispute Settlement Body (DSB). This paper makes a unique contribution to the literature on energy subsidies by applying the WTO covered Agreement on Subsidies and Countervailing Measures (1994) (SCM Agreement) to a specific government measure designed to support the coal export industry in Australia: namely, the proposed concessional loan for the construction of a rail line between the Carmichael coal mine and Abbot Point coal port by the Northern Australia Infrastructure Facility (NAIF). In finding that this measure is in breach of the SCM Agreement, this paper foreshadows future litigation and provides guidance to non-government organizations (NGOs) seeking to identify other unlawful fossil fuel subsidies.
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Demetrious, Kristin. "Contemporary Publics, Twitter and the Story of PR: Exploring Corporate Interventions to Promote “Clean Coal” in Australia." Journal of Public Interest Communications 1, no. 1 (April 28, 2017): 94. http://dx.doi.org/10.32473/jpic.v1.i1.p94.
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Peabody Energy’s Advanced Energy for Life (AEFL) comprehensive global public relations (PR) campaign promoted the idea of clean coal. It is part of a series of efforts deployed by the coal industry since the 1980s to influence the public’s willingness to accept or tolerate its processes and products. This paper will develop a greater understanding of how contemporary publics in a 21st century context react when targeted by the global PR industry. Specifically, it looks at the response to the AEFL campaign in Australia and in particular examines Twitter provocations from January 2014 to January 2016. In doing so, this paper contributes to our understanding of how communicative dynamics such as Twitter and PR may affect public debates. This is critical to helping resolve key policy settings around future energy usage and emissions reduction.
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Brockett, Richard. "Streamline, standardise, or specialise? Frameworks for regulation of unconventional resources in Australia." APPEA Journal 54, no. 1 (2014): 361. http://dx.doi.org/10.1071/aj13037.
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The growth in domestic and global demand for energy has encouraged the development of new and innovative sources of energy. In Australia, the coal seam gas (CSG) industry has been in the vanguard of these advances with significant investment already in place to develop major CSG projects in Queensland. This rapid rise has highlighted the potential for other unconventional resources with proponents now exploring for new resources, such as shale gas, across Australia. Governments have generally attempted to support the development of these new industries. Regulatory reform has addressed the bespoke regulatory issues presented by unconventional gas production particularly in respect of water, land access and co-existence with other industries. Despite this the onshore gas industry continues to face political uncertainty, community division and divergent regulatory responses. Industry has consistently called for regulatory reforms to address duplication, remove unnecessary costs and improve approval processes to speed project delivery and enhance project returns while maintaining robust environmental protection obligations. State and Federal governments have responded to these calls for action in varying ways. While there is much to approve of in each of these processes each presents specific issues and risks that must be considered before they are implemented or more broadly adopted. Therefore, the question arises: What is the best long-term regulatory approach for the sustainable development of Australia’s unconventional resources? This paper reviews existing Australian regulatory approaches and analyses how regulators, industry and the community can work together to develop and implement a regulatory framework that achieves their respective objectives.
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Dale, Allan P. "From conflict to collaboration: can better governance systems facilitate the sustainable development of the northern pastoral industry, communities and landscapes?" Rangeland Journal 40, no. 4 (2018): 331. http://dx.doi.org/10.1071/rj18010.
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The past decade has seen several high profile national policy conflicts related to sustainable development beset the northern Australian pastoral industry. Examples include the live cattle export ban, tree clearing legislation in Queensland and significant pastoral sector concerns about exploration and development of coal and gas reserves across the north. Although these are very legitimate cross-societal debates, the high levels of conflict associated with them impact on the willingness of corporate, family and Indigenous farming enterprises in northern Australia to invest in development. They also affect the willingness and capacities of pastoralists to cooperate with governments in various approaches to change management in northern landscapes. In the pursuit of a better pathway that might resolve policy problems while also delivering industry benefit, this paper analyses several high-profile industry and landscape scale conflicts from recent years, teasing out the key features of governance system dysfunction. At the same time, I also look at positive governance developments emerging in related contexts. Drawing on this analysis, I suggest the current system of governance affecting the northern Australian pastoral industry might have much to learn from the application of more evidence rich and engaging systems of co-management. I suggest that moving in this direction, however, would require Australian, state and Northern Territory (NT) governments to genuinely partner the industry, Traditional Owners and other key sectoral interests, leading to long-term vision building, strategy development and delivery partnerships that benefit industry and communities while resolving wider societal concerns.
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Bradshaw, Barry E., Meredith L. Orr, and Tom Bernecker. "Distribution and estimates of Australia's identified energy commodity resources." APPEA Journal 61, no. 2 (2021): 325. http://dx.doi.org/10.1071/aj20116.
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Australia is endowed with abundant, high-quality energy commodity resources, which provide reliable energy for domestic use and underpin our status as a major global energy provider. Australia has the world’s largest economic uranium resources, the third largest coal resources and substantial conventional and unconventional natural gas resources. Since 2015, Australia’s gas production has grown rapidly. This growth has been driven by a series of new liquefied natural gas (LNG) projects on the North West Shelf, together with established coal seam gas projects in Queensland. Results from Geoscience Australia’s 2021 edition of Australia’s energy commodity resources assessment highlight Australia’s endowment with abundant and widely distributed energy commodity resources. Knowledge of Australia’s existing and untapped energy resource potential provides industry and policy makers with a trusted source of data to compare and understand the value of these key energy commodities to domestic and world markets. A key component of Australia’s low emissions future will be the development of a hydrogen industry, with hydrogen being produced either through electrolysis of water using renewable energy resources (‘green’ hydrogen), or manufactured from natural gas or coal gasification, with carbon capture and storage of the co-produced carbon dioxide (‘blue’ hydrogen). Australia’s endowment with abundant natural gas resources will be a key enabler for our transition to a low emissions future through providing economically competitive feedstock for ‘blue’ hydrogen.
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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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Warner, David. "Shale gas in Australia: a great opportunity comes with significant challenges." APPEA Journal 53, no. 2 (2013): 476. http://dx.doi.org/10.1071/aj12087.
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Australia could have shale gas resources several times bigger than the existing conventional gas resource base, which is estimated at about 5,300 BCM (190 TCF) by Geoscience Australia (GA). The Australian Government has no estimate of potential shale gas resources. The US Department of Energy (EIA) in 2011 estimated Australian shale gas resources to be 400 TCF. The quantity of this estimate is supported by an Australian study—which estimates resources of 600 TCF—conducted by Advanced Well Technologies (AWT) in conjunction with DSWPET. While there are significant technical differences between the shale gas plays in the US and Australia, it is too early to tell if the technical differences are barriers. There are also significant differences in the commercial landscape. The lack of capacity in Australia has lead to much higher costs for drilling and fracture stimulation than in the US. The size of the domestic gas market is much greater in the US and its existing infrastructure allows for production to come onstream quickly. In Australia this infrastructure is not present in most areas and the domestic market cannot support another large gas development. Perhaps the greatest challenge to this great opportunity is politics. There is a public, hence political,perception that all gas sources have the same gasland problems. These perceptions can be changed. First, the petroleum industry and governments need to understand the potential size of the gas resource and the possible strategic opportunity for Australia. Also these parties need to recognise that the shale gas resources are often located away from areas of high social and environmental impact. Once these factors are understood by these parties, factual information about the environmental impact of shale gas plays in comparison with coal seam methane and other alternative gas supplies can be factored into gas resource planning.
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Kovalev, E. T. "PERSPECTIVES OF THE WORLD STEEL AND COKE MARKETS (on the materials of the international conference "EuroCoke Summit", Amsterdam, 2021)." Journal of Coal Chemistry 5 (2021): 4–12. http://dx.doi.org/10.31081/1681-309x-2021-0-5-4-12.
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The article is devoted to the review of the main materials of the international conference Eurocoke-2021, which took place on October 5-6 in Amsterdam, the Netherlands. Despite the fact that the conference is named as European, the representatives of the world's leading firms and research centers from the EU, England, Australia, India, USA, China, Ukraine and other countries took part in its work. The article summarizes the main results and conclusions of the reports and discussions. As the most of speakers noted, that despite the impact of the global recession and the logistical difficulties caused by the COVID-19 pandemic, as well as the China's ban to use Australian coal, a significant change in the global coal market is not expected in the near future. China's trade policy has led mainly to a redistribution of markets for Australian, American, Canadian and Russian coal. Technologies and researches to replace some of the components of the coking coal charge with a cheaper coal grades or carbonaceous materials of plant origin in order to reduce the cost of coke and steel are still relevant. The strict requirements for limiting greenhouse gas emissions are forcing coke and steel producers to modernize the existing traditional production facilities (including using integrated technologies) to reduce emissions and improve the efficiency of the CO2 capturing and utilization. In the world steel production in the next decade, a significant increase in the share of technologies focused on abandoning coke and blast furnace production is hardly possible due to the high cost and duration of the corresponding projects. Keywords: coke production, steel industry, world coking coal market, steel market, trends, recession, logistics, COVID-19, greenhouse gas emissions, decarbonization, direct iron reduction, integrated technologies, stamped charge coking, biomass, catalysis. Corresponding author E.T. Kovalev, e-mail: post@ukhin.org.ua
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Mills, Andrew, Kelly Reilly, Timothy Lim, and Glen Strike. "Maximising ROI through risk based inspection in the CSG industry." APPEA Journal 57, no. 2 (2017): 511. http://dx.doi.org/10.1071/aj16201.
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Australia is forecast to become the world’s largest exporter of liquefied natural gas (LNG) by 2018, and to date, $70 billion has been invested into the Queensland coal seam gas (CSG) industry. These projects consist of tens of thousands of wells, each with a local facility to separate water and gas. From the separation facility, CSG is transported to compression and dehydration stations and water treatment facilities through numerous networks. Spread over an extremely large geographical area, this huge asset count presents a significant challenge to operations and maintenance personnel. Within Australia, regulation requires operators to inspect new pressure containing assets within the first year of operation. Maintaining compliance with these regulations presents significant costs of finances, time and manpower for operators. Furthermore, travelling to these remote sites for inspection increases the risk of driving accidents, currently the number one safety risk for personnel. This paper will address these challenges and discuss potential strategies for the optimisation of plant inspection and maintenance management. We will discuss how Wood Group has delivered innovative solutions to operators utilising technical engineering expertise, operational experience, understanding business constraints and delivering maximum return on investment (ROI).
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Goode, Peter. "World trends and innovations in production asset management—case studies from Australia and North America." APPEA Journal 50, no. 2 (2010): 689. http://dx.doi.org/10.1071/aj09053.
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Australia is transitioning to become an energy superpower—the $43 billion Gorgon LNG project and the other comparably sized projects lining up behind the Gorgon project confirm this. There are predictions that around $80 billion of CAPEX on LNG projects will be approved for expenditure for the 2010 financial year with much more to be invested in the following years. And, we are on the cusp of further coal seam gas developments in Queensland, which could see annual production rise from 130 to more than 3,000 petajoules per annum once the infrastructure is in place. What are the skills needed to realise the true potential of these investments? An appropriate asset management plan is key. Asset management is more than the provision of maintenance services—it is about developing a systematic approach to managing an asset during its life and achieving the outputs required by the owner of the asset. Program and project management of brownfield capital works, maintenance services and infrastructure projects are also essential technical capabilities to help meet the demand of the burgeoning LNG and coal seam gas industries. These skills will determine who can deliver on schedule, or ahead of it. The other key capability will be mobilising, managing and retaining people. There is speculation that the Queensland coal seam gas industry alone will generate approximately 12,000 jobs. The industry needs to be prepared to be innovative in engaging, training and upskilling people. As the only true global resources and industrial provider in Australia, Transfield Services will share its key learnings on effectively managing assets, projects and people from its work with clients including Canada’s largest energy company, Suncor Energy.
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McQueenie, Jim. "Woodside and contractors—partnering for safety excellence." APPEA Journal 50, no. 2 (2010): 708. http://dx.doi.org/10.1071/aj09072.
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Oil and gas industry safety performance in Australia compares well with other industries. Performance of the Australian Oil and Gas Industry, however, as reported by APPEA, lags behind the average performance of the international industry, as reported by the International Association of Oil and Gas Producers (OGP). The improving trend in health and safety performance in Australia over the last ten years is continuing, but progress is slowing. This slow-down suggests that if we continue to work in the same manner as we have done in the past, we will not create the shift in performance required to match or better the international industry average. The current structure of the industry has a number of different operating companies supported by a broad base of contractors. In 2009, contractor exposure hours accounted for 88% of the total hours worked by Woodside. Each operator and contractor has their own approach to health and safety management. The industry backdrop is an increase in activity driven by coal seam gas (CSG) exploitation, a number of LNG megaprojects in development in Western Australia, a significant proportion of senior personnel retiring from the industry, and a significant influx of people new to the industry to support expansion and replace retirees. This will increase demands on existing, already stretched, industry resources and could reduce our ability to develop new approaches and effectively implement them. One of the actions taken to address this at Woodside has been to engage over 100 senior leaders in our company and the CEOs of all of our major contractors to build a commitment to change the basis upon which operator and contractor work together on health and safety issues. This has involved establishing industry sector focus groups for: drilling; exploration and geomatics; onshore project construction; offshore project construction; and, production. Each group is comprised of Woodside and contractor leadership. Given the success of these groups in formulating and driving their own agendas for improvement, and given the strong (and quite pleasing) contractor desire for ownership, Woodside sponsorship will cease at the end of 2010. The approach aims to create sustainable, self governed health and safety focus groups to develop industry solutions to our industry’s health and safety challenges. The groups operate on the premise that excellence in health and safety performance is of mutual benefit and is non-competitive.
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Fleming, David A., and Thomas G. Measham. "Local economic impacts of an unconventional energy boom: the coal seam gas industry in Australia." Australian Journal of Agricultural and Resource Economics 59, no. 1 (January 29, 2014): 78–94. http://dx.doi.org/10.1111/1467-8489.12043.
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Davies, Peter J., Damian B. Gore, and Stuart J. Khan. "Managing produced water from coal seam gas projects: implications for an emerging industry in Australia." Environmental Science and Pollution Research 22, no. 14 (March 19, 2015): 10981–1000. http://dx.doi.org/10.1007/s11356-015-4254-8.
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Sharp-Paul, Alastair, Alexandra Hare, Alice Turnbull, and Tara Halliday. "2010 environmental update." APPEA Journal 51, no. 1 (2011): 179. http://dx.doi.org/10.1071/aj10012.
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Focusing on Australian projects, this paper provides a summary of the key environmental challenges and developments that arose in 2010 and the industry’s response. The paper considers: developments in legislation and the regulatory environment relating to environmental approvals and management; major project approvals and their environmental requirements and implications; key environmental incidents; and reviews new environmental research and management initiatives that were introduced by the industry. A number of states have introduced changes to the way legislation and regulations are interpreted through changes to guidelines and administrative procedures. There has been a general increase in the standard and level of information that regulators expect proponents to provide and while generally these expectations are documented in guidelines and other documents, in some instances there has been a perceived ‘moving of the goal posts’ without clear guidance on what is expected and how the information will be considered once provided. There has been a number of major projects either commencing or gaining environmental approval in 2010. This includes major projects: in Western Australia, on the North West Shelf and in the Timor Sea/Browse Basin; onshore in Queensland in the coal-seam gas fields and continued exploration and development both onshore and offshore around Australia. One of the most significant approvals in 2010 was the Prelude LNG Project–the first approval in Australia of floating LNG technology. Major environmental incidents in 2009 (Montara in Australia and Macondo in the USA) continued to have repercussions in 2010 with the draft government response to the Report of the Montara Commission of Inquiry released in November. These incidents have put the oil and gas industry under the spotlight and this paper looks at some of the statistics on the frequency and severity of environmental incidents, albeit at a high level. Finally, the industry has continued to implement a number of environmentally related initiatives both in response to government policy and suggestion and independently through groups such as the APPEA environment committee.
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Shamsaei, Ezzatollah, Owen Bolt, Felipe Basquiroto de Souza, Emad Benhelal, Kwesi Sagoe-Crentsil, and Jay Sanjayan. "Pathways to Commercialisation for Brown Coal Fly Ash-Based Geopolymer Concrete in Australia." Sustainability 13, no. 8 (April 14, 2021): 4350. http://dx.doi.org/10.3390/su13084350.
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Utilising geopolymer as a construction material has gained institutional and commercial interest over the past decade, due to its favourable emissions profile as an alternative to carbon-intensive Ordinary Portland Cement-based concrete, which currently accounts for around 7% of global carbon emissions. While significant research has been performed into the material properties of geopolymer, the commercialisation of the technology is still in its infancy, and several key barriers require rectification to facilitate more widespread adoption. This article analyses the current state of geopolymer commercialisation, paying particular attention to its commercial application in Australia, and it suggests key research areas, in particular relating to the utilisation of abundant and cheap low-quality fly ash sources such as brown coal-based fly ash, to promote its adoption and build on the momentum gained from the small scale in situ pours of geopolymer concrete. Our analysis indicated that in addition to the barriers relating to material properties, economic, social, and regulatory issues also require further inquiry. Our review also indicated that it is critical to update and improve economic analysis of geopolymer utilisation to forecast future costs of both geopolymer and concrete mixes, which are especially critical in determining any potential financial incentives for the construction industry. Moreover, it is essential to study the social attitudes affecting future geopolymer consumption and to update the regulatory standards governing geopolymer utilisation in Australia, such as the initial steps undertaken by the Low Carbon Living Cooperative Research Centre. Based on this review, it is suggested that solving these key issues would help proliferate geopolymer technology and further aid efforts to create a more environmentally sustainable construction industry.
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Woodhams, Andrew, Ted Fletcher, Menno Weustink, and Miranda Taylor. "Empowering Australia in the global oil and gas standardisation initiative." APPEA Journal 58, no. 2 (2018): 655. http://dx.doi.org/10.1071/aj17151.
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The World Economic Forum has identified the oil and gas industry’s poor productivity performance as a significant barrier to the sanction of large capital projects. 75% of large exploration and production projects between 2010 and 2014 exceeded their budget by 50% on average and 50% of these projects exceeded schedule by almost 40%. A major cause of these poor productivity outcomes is the lack of standardisation. In Australia, the Productivity Commission raised similar concerns about Australian projects. In 2015, the government launched its competitiveness agenda that saw the formation of six industry growth centres, including National Energy Resources Australia (NERA) for oil and gas, coal and uranium. In 2017, NERA, as part of the global standardisation initiative being pursued through the International Oil and Gas Producers Association, successfully delivered a project to elevate Australia to full participating member status of the International Standards Organisation’s Technical Committee for oil and gas, petrochemicals and energy. Australia’s participation is coordinated through Standards Australia’s committee, ME-092, that also oversees several working groups progressing specific initiatives to enhance Australia’s competitiveness. This paper describes Australia’s position within the global oil and gas standardisation initiative, highlights the strategy being pursued to maximise productivity through the adoption of international standards and discusses areas being led by Australian initiatives as part of the international program. Information will be provided on how opportunities can be realised through this initiative and on the role of professionals in supporting Australia’s drive to build a regional oil and gas hub that will attract capital investment for decades to come.
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Konkes, Claire, Cynthia Nixon, Libby Lester, and Kathleen Williams. "Coal versus coral: Australian climate change politics sees the Great Barrier Reef in court." Queensland Review 28, no. 2 (December 2021): 132–46. http://dx.doi.org/10.1017/qre.2022.10.
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AbstractThe likelihood that climate change may destroy the Great Barrier Reef has been a central motif in Australia’s climate change politics for more than a decade as political ideologies and corporate and environmental activism draw or refute connections between the coal industry and climate change. The media fuel this debate because in this contest, as ever, the news media always do more than simply report the news. Given that the Reef has also been central to the evolution of Australia’s environmental laws since the 1960s, it is not surprising that the Reef is now a leading actor in efforts to test the capacity of our environmental laws to support action on climate change. In this contribution, we examine the news coverage of the Australian Conservation Foundation’s (ACF) 2015 challenge to Adani’s Carmichael coal mine to observe the discursive struggle between the supporters and opponents of the mine. Our analysis of the case shows that while the courts are arenas of material and symbolic contest in the politics of climate change in Australia, public interest environmental litigants struggle both inside and outside the courts to challenge the privileging of mining interests over the public interest.
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Wakelin-King, Gordon. "Highlights and trends in exploration 2009." APPEA Journal 50, no. 1 (2010): 113. http://dx.doi.org/10.1071/aj09008.
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2009 saw an overall decrease from high activity from 2008, levelling off in the December quarter as the economy stabilised. Unsurprisingly, most activity was in offshore Western Australia and on coal seam methane (CSM) in Queensland. Highlights include: good results in the Carnarvon and Browse basins for Western Australian operators, interest in Karoon and Conoco-Phillips’ enigmatic Poseidon project, over 180 CSM exploration wells in Queenslandd, and a relatively busy year for Tasmania. Western Australian seismic acquisition approached 10,000 km of 2D and 25,000 km2 of 3D for 38* wells and success rate around 50%. South Australia saw the highest conventional onshore drilling and seismic activity, with good results for 17 wells, while other states saw low activity in this sector. Victoria saw one offshore exploration well and no seismic. Tasmania also saw no new seismic, but saw four exploration wells and encouragement at Rockhopper–1. CSM is picking up in South Australia, and New South Wales saw continued high CSM activity in a historically low-activity region. High success rates suggest two trends: explorers finding value in 3D seismic, and a ‘flight to quality’ as operating costs and poorer access to capital reinforce risk aversion among operators. Elsewhere, geothermal energy helped small cap investors satisfy their appetite for risk outside of the petroleum industry, and results will be watched with great interest. *Numbers are from early public and departmental statistics and may be revised.
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Zoete, Toivo. "Biodiversity offsetting: implications for the oil and gas industry in Australia." APPEA Journal 50, no. 1 (2010): 187. http://dx.doi.org/10.1071/aj09012.
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Energy and infrastructure developments often involve or traverse extensive tracts of land that are frequently covered with stands of native vegetation, providing habitat to a range of different plant and animal species. The biodiversity (biological diversity) contained in these stands is the subject of several pieces of legislation in Australia that place restrictions and conditions on those whose activities interfere with this biodiversity. Social licence to operate is another motivation for development organisations to tread softly when it comes to preparing for activities within these zones. With sound and early planning, much interference can be prevented, but sometimes it is unavoidable and measures will need to be developed to address the resulting impacts. Offsetting is one form of measure available to conserve biodiversity when all other options fail, although it can also be used in addition to other measures. Offsetting allows for actions to be taken by developers to compensate for adverse impacts of their developments. Several policies have been released outlining State and Commonwealth positions on biodiversity offsetting in the last few years. When seeking approvals, energy and infrastructure development organisations need to plan ahead according to these policies. To this purpose, this paper outlines the various policy frameworks that exist for biodiversity offsetting across Australia. Implications for the oil and gas industry are provided. The industry has several characteristics that allow it to take advantage of the new policies, which are discussed. Among these are the ready access to land for offsets and, in the case of the coal seam gas industry, the availability of water to kick-start the creation or restoration of biodiversity on land that was previously cleared.
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Aboumahboub, Tino, Robert J. Brecha, Himalaya Bir Shrestha, Ursula Fuentes, Andreas Geiges, William Hare, Michiel Schaeffer, Lara Welder, and Matthew J. Gidden. "Decarbonization of Australia’s Energy System: Integrated Modeling of the Transformation of Electricity, Transportation, and Industrial Sectors." Energies 13, no. 15 (July 24, 2020): 3805. http://dx.doi.org/10.3390/en13153805.
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To achieve the Paris Agreement’s long-term temperature goal, current energy systems must be transformed. Australia represents an interesting case for energy system transformation modeling: with a power system dominated by fossil fuels and, specifically, with a heavy coal component, there is at the same time a vast potential for expansion and use of renewables. We used the multi-sectoral Australian Energy Modeling System (AUSeMOSYS) to perform an integrated analysis of implications for the electricity, transport, and selected industry sectors to the mid-century. The state-level resolution allows representation of regional discrepancies in renewable supply and the quantification of inter-regional grid extensions necessary for the physical integration of variable renewables. We investigated the impacts of different CO2 budgets and selected key factors on energy system transformation. Results indicate that coal-fired generation has to be phased out completely by 2030 and a fully renewable electricity supply achieved in the 2030s according to the cost-optimal pathway implied by the 1.5 °C Paris Agreement-compatible carbon budget. Wind and solar PV can play a dominant role in decarbonizing Australia’s energy system with continuous growth of demand due to the strong electrification of linked energy sectors.
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Su, Yang, and David Jones. "Healing the ‘Scar’ of the Landscape: Post-Mining Landscape in Anglesea." KnE Engineering 2, no. 2 (February 9, 2017): 182. http://dx.doi.org/10.18502/keg.v2i2.613.
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<p>The nexus between environmental bio-remediation and environmental design, as it pertains to disused coal mining sites in Australia, is little investigated. Increasingly, many of these open cut extraction holes around south-eastern Australia, are becoming redundant as their resources are exhausted or non-economic viability creeps into the industry or are becoming management ‘nightmares’. The recently announced March 2017 cessation of the Yallourn Power Station and associated brown coal Open Cut, and the recent fires and insurance liability legal determinations of the Yallourn Open Cut are exemplar of the former and latter respectively.</p>This paper surveys the deeper bio-remediation and ecological transformative issues directly associated with the Anglesea brown coal Open Cut, and offers an ecological design lens insight as to possible treatments and scenarios that can be offered to guide the future use and management of the site. The lens demonstrates the richness that interdisciplinary design and applied research offers in assisting the healing and mediation of sites. The extraordinary nature and scope of the Anglesea coal mine site provides an opportunity to create a range of cultural attractions, natural succession treatments, natural bio-remediation strategies and educational opportunities. One scenario, for an Anglesea Lake Eco-Resort, proposes to incorporate an integrated Aboriginal cultural destination, performance centre, art installations and recreational venues, engaging the Anglesea community, visitors, researchers and students towards creating a vibrant and unique environment.
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Baer, Hans A. "The nexus of the coal industry and the state in Australia: Historical dimensions and contemporary challenges." Energy Policy 99 (December 2016): 194–202. http://dx.doi.org/10.1016/j.enpol.2016.05.033.
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Demetrious, Kristin. "‘Energy wars’: Global PR and public debate in the 21st century." Public Relations Inquiry 8, no. 1 (January 2019): 7–22. http://dx.doi.org/10.1177/2046147x18804283.
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‘Hashtags’, ‘trending topics’, ‘mentions’ ‘likes, ‘retweets’: the 21st century is distinctive for a range of new communication technologies, social practices and discourses that have framed public debate as “authentic”, “participatory”, “empowering” and “organic”. In this article, I explore a 21st century public relations (PR) campaign that is promoting neoliberal “solutions” to complex social and environmental problems, namely Burson-Marsteller’s 2014 campaign for coal industry client, Peabody Energy. The ‘Advanced Energy for Life’ (AEFL) ‘comprehensive global campaign’ to promote the idea of ‘clean coal’ in the alleviation of ‘energy poverty’ is but one in a succession of campaigns deployed by the coal industry since the 1980s. This article examines the reception of the AEFL campaign in Australia from January 2014 to March 2017. In doing so, it traces the movement of campaign tropes in the public sphere as well as prominent Twitter activity. It asks what purpose did the tropes serve and how they propelled debate. It also asks if resistance on Twitter can disrupt the ‘long period of suspended animation’ in public debate on energy policy. In tackling these questions with a critical lens, it aims to develop a greater understanding of the influence of global PR campaigns such as Peabody’s AEFL in public debate in contemporary settings.