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1
Merten, Rudolf. "Petroleum exploration and production in Spain." Zeitschrift der Deutschen Gesellschaft für Geowissenschaften 157, no. 4 (December 1, 2006): 717–32. http://dx.doi.org/10.1127/1860-1804/2006/0157-00717.
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Lamiraux, Charles, and Alain Mascle. "Petroleum exploration and production in France." First Break 16, no. 4 (April 1998): 109–17. http://dx.doi.org/10.1046/j.1365-2397.1998.00687.x.
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Freij-Ayoub, Reem, Cedric Griffiths, Beverley Ronalds, Geoff Weir, Raj Rajeswaran, and G. A. Mansoori. "Petroleum exploration and production research in Australia." Journal of Petroleum Science and Engineering 57, no. 1-2 (May 2007): 1–7. http://dx.doi.org/10.1016/j.petrol.2006.10.001.
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Constable, Tania. "2013 offshore petroleum exploration acreage release." APPEA Journal 53, no. 1 (2013): 63. http://dx.doi.org/10.1071/aj12006.
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Exploration is essential for the future of Australia’s resources sector, to enhance our international competitiveness and ensure the long-term growth of this important industry while maintaining Australian energy security and that of our major energy trading partners. Encouraging investment in offshore petroleum exploration is facilitated though the annual Offshore Petroleum Exploration Acreage Release prepared in collaboration between the Department of Resources, Energy and Tourism, and Geoscience Australia. The annual release is underpinned by a stable economic environment, and a regulatory framework that provides the industry with a variety of investment opportunities. Australia has abundant natural gas reserves and is experiencing a rapid expansion of its LNG production capacity. Today, Australia is the world’s fourth-largest exporter of LNG, with a total export capacity of 24.3 million tonnes per annum from its three operational projects. Capacity will further increase to around 80 million tonnes per annum in 2017 once the seven projects presently under construction come online. These projects represent more than US$175 billion in capital expenditure announced since mid-2007, and result in Australia becoming the only country to use three LNG production models: conventional offshore gas with onshore LNG production; FLNG production; and, CSG-based LNG production. This paper will provide detail about the acreage included in the 2013 Offshore Petroleum Exploration Acreage Release. Areas are carefully selected to offer the global petroleum industry a variety of investment opportunities. This paper will also discuss the supporting regulatory environment and new government initiatives, including the introduction of a five-year exploration strategy for acreage release and the introduction of a cash bidding system as part of future offshore petroleum acreage releases.
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Spencer, Anthony M., Per Ivar Briskeby, Lone Dyrmose Christensen, Rune Foyn, Marie Kjølleberg, Erling Kvadsheim, Ian Knight, Morten Rye-Larsen, and John Williams. "Petroleum geoscience in Norden – exploration, production and organization." Episodes 31, no. 1 (March 1, 2008): 115–24. http://dx.doi.org/10.18814/epiiugs/2008/v31i1/016.
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Kharaka, Yousif K., and Nancy S. Dorsey. "Environmental issues of petroleum exploration and production: Introduction." Environmental Geosciences 12, no. 2 (June 2005): 61–63. http://dx.doi.org/10.1306/eg.intro0605020205.
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Friess, Bernhard, Rupert J. Baumgartner, and Gerhard Bauer. "Success factors of petroleum exploration and production companies." International Journal of Services and Operations Management 4, no. 2 (2008): 145. http://dx.doi.org/10.1504/ijsom.2008.016608.
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Hunt, M. W. "NATIVE TITLE ISSUES AFFECTING PETROLEUM EXPLORATION AND PRODUCTION." APPEA Journal 39, no. 2 (1999): 107. http://dx.doi.org/10.1071/aj98065.
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This paper focusses on onshore exploration and production because the right to negotiate does not apply offshore. However, the Native Title Act can be relevant to offshore oil and gas explorers and producers. First, where their area of interest includes an island within the jurisdiction of Western Australia. Secondly, in respect of land required for the facilities to treat petroleum piped ashore.Under the original Native Title Act the right to negotiate proved unworkable, the expedited procedure failed to facilitate the grant of exploration titles and titles granted after 1 January 1994 were probably invalid.The paper examines the innovations introduced by the amended Native Title Act to consider whether it will be more 'workable' for petroleum explorers and producers. It examines some of categories of future acts in respect of which the right to negotiate does not apply (specifically indigenous land use agreements, renewals and extensions of titles, procedures for infrastructure titles, reserve land, water resources, low impact future acts, approved exploration etc acts and the expedited procedure).Other innovations include the new registration test for native title claims, the validation of pre-Wik titles, the amended right to negotiate procedure, the State implementation of the right of negotiate procedure and the objection and adjudication procedure for grants on pastoral land.The response of each state and territory parliament to the amended Act is considered, as is the Federal Court decision in the Miriuwung Gajerrong land claim (particularly the finding that native title includes resources, questioning whether these resources extend to petroleum).The paper observes that the full impact of the new Act cannot be determined until the states and territories have passed complementary legislation and it is all in operation. However, the paper's preliminary conclusion is that it does not provide a workable framework for the interaction between petroleum companies and native title claimants.The writer's view is that the right to negotiate procedure is unworkable if relied upon to obtain the grant of a title. If a proponent wishes to develop a project in any commercially acceptable timeframe, it will have to negotiate an agreement with native title claimants. The paper's conclusion is that a negotiated agreement is the only way to cope with native title issues.
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Miller, A. "Competition for Petroleum Exploration Capital in the Asia-Pacific Region – Implications for New Zealand and Austrialia." Energy Exploration & Exploitation 13, no. 2-3 (May 1995): 261–73. http://dx.doi.org/10.1177/0144598795013002-315.
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This paper examines the future energy production and demand profiles for the Asia Pacific region and the global allocation of exploration capital made by major international petroleum companies. The implications of these factors for future government petroleum exploration policies within the region are considered, in particular the Australian and New Zealand situations, together with likely effects of such measures on the ability of exploration and production companies to raise capital.
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Riazi, M. R., R. C. Merrill, and G. A. Mansoori. "Petroleum exploration and production research in the Middle East." Journal of Petroleum Science and Engineering 42, no. 2-4 (April 2004): 73–78. http://dx.doi.org/10.1016/j.petrol.2003.12.001.
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CONSTANTINOU, C. "Investments in Petroleum Exploration and Production in Developing Countries." Natural Resources Forum 12, no. 4 (November 1988): 403–7. http://dx.doi.org/10.1111/j.1477-8947.1988.tb00842.x.
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Montel, François. "Phase equilibria needs for petroleum exploration and production industry." Fluid Phase Equilibria 84 (April 1993): 343–67. http://dx.doi.org/10.1016/0378-3812(93)85132-6.
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Cullen, Frances, and Paul Webber. "Unlocking Australia's oil future—exploration to exploitation." APPEA Journal 50, no. 2 (2010): 742. http://dx.doi.org/10.1071/aj09106.
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Since 2000 Australia has ceased to be self-sufficient in terms of oil production and petroleum demand. As a net importer of crude oil it is expected that imports will continue to fulfil a growing percentage of the country’s liquid petroleum needs. Analysts are predicting a decline in oil production over the next decade with current producing fields and discovered resources failing to fill the gap created by rising consumption. In an increasingly gas focussed industry, oil is competing with both liquefied natural gas (LNG) and coal seam gas (CSG) projects for investment. As one of the top 20 oil consumers in the world, Australia’s growing demand for petroleum liquids continues to highlight the declining domestic supply. This poster will identify and review the various components that will play a role in arresting the predicted decline curve. Exploration success in frontier basins is crucial along with the development of discovered resources in mature regions. In addition, future near-field and satellite exploration, with developments using existing infrastructure, will be instrumental in the stabilisation of oil production. This poster will also highlight planned high-impact exploration wells and examine the effect that potential discoveries could have on the country’s petroleum resources. Australia’s oil future could see a reduced dependence on imported crude, resulting from frontier exploration success opening up new oil provinces. Future options for oil production also include a re-evaluation of oil prone regions using new technology to develop discovered reserves and target higher risk and overlooked plays.
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Green, Peter. "Australian States and Northern Territory acreage update at APPEA 2010." APPEA Journal 50, no. 1 (2010): 35. http://dx.doi.org/10.1071/aj09003.
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Peter Green is the Geoscience Manager: Energy Geoscience in the Geological Survey Queensland and has extensive experience in basin studies, geoscience and the development of petroleum regulation in Queensland. This paper provides a summary of the land releases for petroleum exploration for onshore areas and coastal waters of Australia for 2010. The summaries include upstream petroleum acreage opportunities for the states and the Northern Territory, and geothermal energy exploration opportunities. The rise in interest in export liquefied natural gas projects has ensured petroleum exploration and production has remained strong. Interest in acquiring petroleum acreage to explore for both conventional and non-conventional plays remains high. Australian state and the Northern Territory governments continue to provide access to land and promotional opportunities for companies to undertake exploration and development of our petroleum resources. Acreage on offer provides a mix of exploration opportunities from conventional oil and gas through to the unconventional plays such as shale gas and tight gas. This change in acreage on offer reflects the changing nature of the onshore petroleum industry in Australia.
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Constable, Tania. "2014 Offshore Petroleum Exploration Acreage Release." APPEA Journal 54, no. 1 (2014): 377. http://dx.doi.org/10.1071/aj13039.
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The potential for natural gas to fuel economic growth around the world is tremendous. Australia has a pivotal role to play with our abundant natural gas reserves and record levels of investment in LNG production capacity. Australia is presently the world’s third-largest exporter of LNG, with an export capacity of 24.3 million tonnes per annum (mtpa) from three operational projects. Capacity will increase to around 90 mtpa by 2018, once the seven projects being constructed come online. The Australian Government is committed to ensuring the long-term growth of the petroleum industry, and the promotion of competitive, sustainable and well-regulated markets operating in the best interests of the nation. Exploration is essential for the future of Australia’s resources sector to enhance our international competitiveness while maintaining Australian energy security and that of our energy trading partners. Investment in offshore petroleum exploration is facilitated though the annual Offshore Petroleum Exploration Acreage Release prepared by the Australian Government Department of Industry and Geoscience Australia. The Offshore Petroleum Exploration Acreage Release is underpinned by a stable economic environment and clear regulatory framework that provides investment certainty and security of title. This paper provides details about the acreage included in the 2014 Offshore Petroleum Exploration Acreage Release. All areas are supported by geological data and analysis from Geoscience Australia. This paper also discusses the introduction of cash bidding for mature areas and areas containing known petroleum accumulations, in addition to Australian Government initiatives in the offshore petroleum sphere.
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Gately, D. J. "COAL SEAM GAS—PETROLEUM OR MINERAL." APPEA Journal 37, no. 1 (1997): 589. http://dx.doi.org/10.1071/aj96038.
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1996 was a watershed year for gas exploration in Queensland: the increasing private sector investment in the search for and commercial use of methane gas from coal seams received legislative endorsement. Coal seam gas (CSG), also known as coalbed methane or CBM, was officially designated as petroleum, with exploration for and production of CSG to be administered under the Petroleum Act.The paper traces the history of exploration for CSG in Queensland since 1976, culminating in a policy shift in 1996. In Queensland there is now potential for overlapping titles and competitive resource development.
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Suslick, S. B., and D. J. Schiozer. "Risk analysis applied to petroleum exploration and production: an overview." Journal of Petroleum Science and Engineering 44, no. 1-2 (October 2004): 1–9. http://dx.doi.org/10.1016/j.petrol.2004.02.001.
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Al-Attar, Abdulaziz, and Osamah Alomair. "Evaluation of upstream petroleum agreements and exploration and production costs." OPEC Review 29, no. 4 (December 2005): 243–66. http://dx.doi.org/10.1111/j.1468-0076.2005.00154.x.
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Fraser, I. "PETROLEUM EXPLORATION, DEVELOPMENT, AND PRODUCTION IN WESTERN AUSTRALIA DURING 1985." APPEA Journal 26, no. 2 (1986): 89. http://dx.doi.org/10.1071/aj85056.
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Schofield, Lisa. "2018 offshore petroleum exploration acreage release." APPEA Journal 58, no. 2 (2018): 465. http://dx.doi.org/10.1071/aj17103.
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The Australian Government’s 2018 offshore petroleum exploration acreage release was announced by the Commonwealth Minister for Resources and Northern Australia, Senator the Hon Matthew Canavan at the 2018 APPEA conference. This paper provides insights into the processes that the Australian Government has undertaken to select the final release areas and goes into detail on the ongoing petroleum related activities of the Department of Industry, Innovation and Science (the Department). The annual acreage release is a central component of ensuring ongoing, sustainable and responsible investment in Australia’s offshore petroleum sector. The annual acreage release remains the primary mechanism for securing investment in offshore oil and gas exploration in areas of known petroleum potential and new geological frontiers. Continued exploration for oil and gas in Commonwealth waters is a central component of ensuring Australia’s future energy security. Australia’s well established and independent environmental regulator, NOPSEMA (the National Offshore Petroleum Safety and Environmental Management Authority), ensures all petroleum activities in Commonwealth waters are performed safely and in an environmentally responsible manner. Combined with NOPTA’s (National Offshore Petroleum Titles Administrator) leading practice titles administration, Australia remains an attractive investment destination while offering industry leading environmental protections and ensuring safe working conditions industry-wide. Australia offers investors access to data, secure tenure, a stable economic environment and a well-established transparent regulatory system for offshore petroleum activities. A key driver for sustainable activity in Australia is the acceptance of multiple use access to Australia’s marine resources. Recognising this, the department consults with a range of stakeholders on the areas it proposes to release for petroleum exploration. This consultation process provides an opportunity for all interested parties to provide comments and feedback on the areas proposed and in particular highlight how interested parties or the areas might be impacted by exploration activities. The 21 areas in the 2018 offshore petroleum exploration acreage release are located in the offshore areas of Western Australia, South Australia, Victoria and the Ashmore-Cartier Islands. These areas will enable the next wave of investment in the Australian resources sector, and the prospect of new oil, gas and condensate production.
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Constable, Tania. "2012 offshore petroleum exploration acreage release." APPEA Journal 52, no. 1 (2012): 1. http://dx.doi.org/10.1071/aj11001.
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Australia has abundant natural gas reserves and is experiencing a rapid expansion of its liquefied natural gas (LNG) production capacity. In 2011 alone, four Australian LNG projects received final investment decisions (FIDs) and another FID was made in the first weeks of 2012. These projects will add more than 33 million tonnes of new LNG capacity, represent more than $100 billion in investment, and will see Australia become the world’s second largest LNG exporter by 2015. These projects are underpinned by Australia’s stable economic environment and our effective and efficient legislative regime that provides the industry the confidence to pursue a variety of investment opportunities. The essential first step covered by this regime is exploration, which is supported by Australia’s annual Offshore Petroleum Exploration Acreage Release. Prepared by the Department of Resources, Energy and Tourism and Geoscience Australia, the annual Acreage Release is the key mechanism used by the Australian Government to encourage investment in petroleum exploration. The 2012 Acreage Release areas have been carefully selected to offer the global petroleum exploration industry a variety of investment opportunities. Areas vary in size, level of existing geological knowledge, and are located in a range of water depths. Selected areas are supported by pre-competitive geological and geophysical data and analysis undertaken by Geoscience Australia. The detailed Acreage Release information package is available at online at www.petroleum-acreage.gov.au or by visiting the Commonwealth Government’s booth at the APPEA conference.
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Keith, Joe. "Australia petroleum production and development – 2020." APPEA Journal 61, no. 2 (2021): 341. http://dx.doi.org/10.1071/aj21007.
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This Petroleum Exploration Society of Australia review considers the production and development of oil and gas in Australia over the year 2020. In a challenging year, which included commodity price wars and severe global impacts felt from the coronavirus disease 2019 (COVID-19), the Australian industry continued to produce high gas volumes due to sustained liquefied natural gas (LNG) output, and minimal decreases were seen in liquids production. Development approvals for large offshore projects did not materialise as expected in 2020 as operators reduced capital spend and focused on portfolio management in a year when oil prices fell by around USD 45bbl. Critically, all major projects with an financial investment decision (FID) target of 2020/21 were not cancelled, but development decisions were instead deferred. By the end of 2020, domestic-focused gas projects continued to be pursued for development with a target to support the declining resources for the Australian east coast domestic gas market.
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North, Roger. "A NEW PETROLEUM ACT FOR QUEENSLAND." APPEA Journal 31, no. 1 (1991): 475. http://dx.doi.org/10.1071/aj90042.
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Secure title is necessary for petroleum exploration and production. Without it, he who spends the risk money may not reap the rewards. The Petroleum Act 1923-1990 is the Queensland legislation under which exploration and production titles are granted. It is 1923 legislation which has been amended from time to time. It suffers from uncertainties in areas including application and granting procedures, and title transfer and administration procedures. The Petroleum Act by its terms requires the provisions of the Mineral Resources Act 1989-1990 to be read into it and this has emphasised the need for amendment and preferably replacement. There are indications that a review of the Petroleum Act will be carried out in the near future. To minimise the possibility of unfavourable replacement legislation, the industry must address and decide the principles it favours.
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Carpio, Lucio Guido Tapia, and Marcus Vinicius Margueron. "Decision-Making Process under Uncertainty in International Investments in Petroleum Exploration and Production: Multicriteria Approach." Energy Exploration & Exploitation 25, no. 5 (October 2007): 339–56. http://dx.doi.org/10.1260/014459807783528892.
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This paper intends to present a contribution to the development of techniques of decision-making in international projects of exploration and production of petroleum. A case study of the Multi-Attribute Utility Theory (MAUT) was developed and applied to define priorities among ten offshore exploration investment opportunities around the world offered to a Brazilian petroleum multinational company, according to decision-makers' preferences. The MAUT model proposed shows for the first time a combination of operational, political and technological risks, resulting in a quite complete formulation to describe quantitatively the decision-making process. It is important to emphasize that this paper presents an unpublished model to evaluate political risks whose detailed analysis is currently of extreme importance for international investments in petroleum projects.
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Cai, Jun, Xiuxiang Lü, and Ping Wang. "Secondary migration of petroleum along syncline axes: a case study of the southern Kuqa Foreland Basin." Canadian Journal of Earth Sciences 54, no. 7 (July 2017): 720–30. http://dx.doi.org/10.1139/cjes-2016-0108.
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Tracing petroleum migration pathways for petroleum exploration in a sedimentary basin is challenging. Paleo-uplifts are generally considered to represent the primary migration directions of petroleum. Here we propose a model for the Kuqa Foreland Basin, in which petroleum migrates along the axes of synclines between paleo-uplifts, based on an integrated analysis of seismic, geochemical, and production data. Interpretation of detailed seismic data indicates that petroleum is unlikely to migrate to the paleo-uplifts because of their relatively low positions, fault disruptions, or a lack of Mesozoic reservoirs. Geochemical parameters, including the ratios of alkyl dibenzothiophenes and the gas wetness parameter, show that petroleum maturity gradually decreases along the axes of synclines between paleo-uplifts from northeast to southwest. Petroleum production data and gas/oil ratios also show decreasing trends from northeast to southwest. This evidence suggests that petroleum is likely to migrate along the axes of the synclines between the paleo-uplifts from northeast to southwest. This study not only enhances the scientific understanding of secondary migration, but also may be useful to guide petroleum exploration in the southern Kuqa Foreland Basin.
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Nguyen, Chuc Dinh, Hiep Quoc Cao, Huy Nhu Tran, and Xuan Van Tran. "Oligocene stratigraphic traps at the SouthEastern, Cuu Long basin." Science and Technology Development Journal - Natural Sciences 1, T5 (November 29, 2018): 234–50. http://dx.doi.org/10.32508/stdjns.v1it5.557.
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Up to recent years, major targets of oil and gas exploration in Cuu Long basin have been carried ort at structural traps in anticlines or basement highs in PreTertiary basement, Oligocene / Miocene clastics. As petroleum resources from reservoirs of traditional types become exhausted after many years of production (the remaining unexplored potential targets do not have sufficient reserves for development and production), exploration activities in Cuu Long basin have being focused in Oligocene stratigraphic/combination traps that have been discovered in recent years. Since the 1980s, petroleum explorers have identified oil in pinchouts trap in the Southeastern Cuu Long basin. However, these prospects have been evaluated to be of low potential due to be concerned of poor reservoir quality or incomplete petroleum system (lacking of source rocks or seals). Recent exploration activities in the region have identified several stratigraphic/ combination traps not only as pinch-outs but also as traps formed by appropriate facies changes. This article discusses types of stratigraphic traps that have been recently discovered in the studied area as well as exploration methods for predicting the distribution of these traps.
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Katz, H. R. "A Historical Review of Petroleum Exploration in New Zealand." Energy Exploration & Exploitation 6, no. 2 (April 1988): 89–103. http://dx.doi.org/10.1177/014459878800600203.
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Active exploration for petroleum in New Zealand is over 120 years old. While some sporadic, commercial production was obtained already in the earliest part of this century, exploration until 1920 was entirely guided by the occurrence of natural seepages. 1925–1944 was the first period of scientifically-oriented exploration, spurred particularly by the requirements of the second World War. In 1955 began the present period of more intensified prospecting, which in 1965 extended to New Zealand's very large ofshore area. The onshore Kapuni gas/condensate field was discovered in 1959, and the giant offshore Maui field in 1969. Production started in 1970 and 1979, respectively. Exploration enormously increased and expanded all over the country in the late 1960's and early 1970's, with concession holdings reaching a record high in 1970/71:131,673 km2 onshore and 1,003,669 km2 offshore. But a sharp decline followed in the mid-late 1970's, which was partly Government-induced and political, partly due to a prolonged lack of success. A change of Government policy in 1980 started a new cycle of intense exploration, with enthusiasm rapidly fuelled by a string of new, though small discoveries in Taranaki onshore, and, in 1986/87, by what is believed to be a large oil and gas discovery in Taranki offshore. Drilling activity has reached record levels over the last years, while exploration in general is branching out again to many other areas and basins, outside Taranaki. Total production in 1986 amounted to 4,546 million m3 of gas (plus 744 million m3 re-injected), 1.208 million m3 of condensate, 186,700 m3 of LPG and smaller amounts of natural gasoline and butane, and 0.501 million m3 of oil.
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Gharbi, Ridha B. C., and G. Ali Mansoori. "An introduction to artificial intelligence applications in petroleum exploration and production." Journal of Petroleum Science and Engineering 49, no. 3-4 (December 2005): 93–96. http://dx.doi.org/10.1016/j.petrol.2005.09.001.
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Wawryk, Alexandra, and Katelijn van Hende. "The internationalisation of liability regimes for offshore petroleum exploration and production." APPEA Journal 54, no. 1 (2014): 209. http://dx.doi.org/10.1071/aj13022.
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The pollution caused by the explosion of the Deepwater Horizon oil rig in the Gulf of Mexico, and the Montara blowout in the Timor Sea, put the call for an international regulatory framework for oil pollution liability on the global agenda. Although international law regulates the prevention of offshore oil pollution and protection of the marine environment, certain activities do not fall inside the ambit of international regulations. For example, while new technology has made it possible for companies to drill to deeper depths and explore further away from the coastline, existing international conventions generally do not extend to liability for, and restoration of, damage caused by oil pollution from offshore installations. These issues are regulated by the national laws of the country that governs the continental shelf where the petroleum activities are conducted. Thus, from an international perspective, the legal regime is disperse and complex. The amount and complexity of claims arising from large-scale incidents has raised interest in creating a consistent international liability regime. This could be done through a multilateral treaty. Alternatively, the development and application of common principles across national and regional jurisdictions can lead to the increased internationalisation of liability regimes. This paper compares the laws of Australia, the USA and the UK to identify common principles for liability and environmental restoration. The authors argue that as the legal framework becomes internationalised, increasing pressure will be placed on companies to accept the highest standards of liability, rather than the lowest national standard.
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Bethune, Graeme, and Susan Bethune. "Petroleum production and development across Australia 2017." APPEA Journal 58, no. 2 (2018): 469. http://dx.doi.org/10.1071/aj18009.
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This Petroleum Exploration Society of Australia review looks in detail at the trends and highlights for oil and gas production and development both onshore and offshore Australia during 2017. Gas production soared while oil production plummeted yet again. Liquefied natural gas (LNG) did well; 2017 was a great year for LNG and 2018 should be even better. There are stark contrasts between domestic gas on the west and east coasts. On the west coast, prices are affordable and supply relatively plentiful. On the east, prices are high and gas is in short supply. This paper canvasses these trends and makes conclusions about the condition of the oil and gas industry in Australia. This paper relies primarily on production and reserves data compiled by EnergyQuest. In its latest review of Australian energy policy, the International Energy Agency comments yet again on the weaknesses of Australian oil and gas statistics. This paper also makes some observations on these weaknesses.
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Bethune, Graeme. "Australian petroleum production and development 2018." APPEA Journal 59, no. 2 (2019): 482. http://dx.doi.org/10.1071/aj18285.
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This Petroleum Exploration Society of Australia review looks in detail at the trends and highlights for oil and gas production and development both onshore and offshore Australia during 2018. Total petroleum production climbed strongly for the third consecutive year, driven by LNG. A highlight is the start-up of the INPEX Ichthys project. Production is set for further growth in 2019 with the ramp-up of this project and the start-up of Shell’s Prelude floating LNG project. Prelude and Ichthys are the last projects to be commissioned in a wave of seven new LNG projects that are making Australia the world’s largest LNG exporter and a crucial supplier of gas to Asia, including the largest source of LNG for Japan and China and the second-largest source for South Korea. By contrast, Australian oil production continued to fall rapidly and is now easily surpassed by rising condensate production from new LNG projects. There were stark contrasts between domestic gas on the west and east coasts. On the west coast, prices remain low and supply relatively plentiful. The east coast domestic market was tighter and LNG producers responded by diverting gas supplies to the domestic market. This paper canvasses these trends and makes conclusions about the condition of the oil and gas industry in Australia. This paper relies primarily on production and reserves data compiled by EnergyQuest and published in its EnergyQuarterly reports.
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Fahey, J., and D. Perks. "LEGAL DEVELOPMENTS IN 2000." APPEA Journal 41, no. 2 (2001): 73. http://dx.doi.org/10.1071/aj00054.
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This paper briefly describes a number of legal developments in 2000 which may be of significance to participants in the petroleum exploration and production industry.There has been a number of varied legal developments in this field during the past year, and this paper is not an exhaustive account of all of them. Instead, an attempt has been made to provide an overview of selected developments during 2000 which are noteworthy. With this mind, this paper deals with the following matters:prospective East Timorese independence and the Timor Gap Treaty (focussing on practical arrangements);changes to the work program bidding system;commencement of the Petroleum (Submerged Lands) Legislation Amendment Act No 1 2000 (Cth);review of federal and state petroleum (submerged lands) legislation against competition policy principles;commencement of the Environment Protection and Biodiversity Conservation Act 1999 (Cth);reform of petroleum legislation in South Australia and Queensland; andgreenhouse reforms.In respect of the matters noted above, we have attempted to outline the implications for participants in the petroleum exploration and production industry.
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Troup, Alison, and Peter Green. "The changing face of Queensland's petroleum industry." APPEA Journal 51, no. 1 (2011): 225. http://dx.doi.org/10.1071/aj10016.
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The cycles and related changes in exploration targets identified in this study show the evolution of the Queensland petroleum industry from conventional petroleum to coal seam gas dominance. Delineation of these cycles was undertaken using petroleum exploration well data, and production and reserves statistics. Although the cycles are defined on the basis of exploration activity, there is a very different history in the types of targets and commodities explored for in the Bowen-Surat and Cooper-Eromanga basins. Trends in exploration success have been influenced by technology improvements, better understanding of target reservoirs, proximity to infrastructure, government policy and world oil prices. Four distinct exploration cycles have been identified from the data. During the first cycle (1959–74) exploration focused predominantly on the shallower Jurassic-aged reservoirs in the Bowen-Surat basins resulting in the discovery of most of the major conventional oil and gas fields. The second cycle (1979–89) saw exploration begin in earnest in the Cooper-Eromanga basins and a switch to predominantly Triassic-aged reservoirs in the Bowen-Surat basins. The first coal seam gas exploration wells were drilled during this cycle. The third cycle (1990–99) shows a decrease in the number of conventional petroleum wells across both regions and the beginning of the switch to the present dominance of coal seam gas. The fourth cycle (2000–present) shows a significant decrease in the number of conventional exploration wells drilled across both regions, but an increase in the success rates. All conventional discoveries in the Bowen-Surat basins during cycle four have been in Permian-aged reservoirs, reflecting a change in the exploration focus to deeper parts of the Bowen Basin. Coal seam gas exploration has expanded significantly, with the Walloon Coal Measures being targeted, resulting in nearly four coal seam gas wells drilled for each conventional petroleum exploration well state-wide since 2000. Examination of coal seam gas exploration highlights the many false starts since the first well was drilled in 1980. Exploration has shifted from area to area as companies tested different exploration concepts and completion techniques. The most obvious shift has been from Permian-aged targets of the Bowen Basin into the Jurassic-aged Walloon Coal Measures in the Surat and Clarence-Moreton basins, as its prospectivity was realised.
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Francisco, Barbara Bruna A., Anderson A. Rocha, Patricia Grinberg, Ralph E. Sturgeon, and Ricardo J. Cassella. "Determination of inorganic mercury in petroleum production water by inductively coupled plasma optical emission spectrometry following photochemical vapor generation." Journal of Analytical Atomic Spectrometry 31, no. 3 (2016): 751–58. http://dx.doi.org/10.1039/c5ja00444f.
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Martin, J. H. "PETROLEUM EXPLORATION AND PRODUCTION- WHAT ARE THE ENVIRONMENTAL OBLIGATIONS OF JOINT VENTURE PARTICIPANTS?" APPEA Journal 37, no. 1 (1997): 738. http://dx.doi.org/10.1071/aj96056.
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Participants in joint venture operating agreements in Australia are potentially liable for environmental offences under State environmental statutes as well as Petroleum (Submerged Lands) Acts and State Petroleum Acts. In addition, adverse environmental impacts can affect an array of other commercial factors, including the future costs of obtaining finance, insurance cover and access to new acreage.The nature of potential risks and liabilities are such that environmental management must be regarded as an on-going risk management activity, integrated into all planning and day-to-day operations in the same way that health and safety management is now being widely incorporated in petroleum industry activities. Joint venture participants generally pay considerable attention to the calibre of the technical (geological and engineering) advice provided by the operator. It follows that they should also place considerable importance on the calibre of environmental management expertise provided by the operator and its contractors.A successful system of management should be modelled on a due diligence defence, which requires that those who are directing joint venture activities exercise due diligence, requiring the establishment of a proper system to prevent violations of the law and the effective operation of that system, including supervision, maintenance and improvements in business methods.
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Wyld, Irene, and Bruce Godfrey. "RESEARCH WITH A PURPOSE IN THE AUSTRALIAN PETROLEUM INDUSTRY." APPEA Journal 34, no. 1 (1994): 373. http://dx.doi.org/10.1071/aj93034.
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Research—defined broadly as any activity in the concept to delivery continuum—is critical to the success of the present thrust for development of a competitive Australia. It provides the key to maintenance of existing competitive advantages, and the development of new competitive advantages both within Australia and in export markets. Nowhere is this more important than in the Australian petroleum industry (oil and gas). This industry contributes in the order of $10 billion annually to Australia's balance of trade. Yet until recently little research has been undertaken by Australian petroleum companies to support their exploration and production activities here.There is now recognition by Australian petroleum companies that research must be undertaken by them to support access to prospective areas, enhance exploration success, maximise production and minimise environmental damage. The contribution which research can make to the growth of the industry will only accrue if that research is targeted on priorities which meet the short, medium, and long-term needs of the industry. To define these priorities APEA, working in conjunction with ERDC, has produced a research and development strategy for the Australian upstream petroleum industry.The priorities resulting from this process cover the areas of exploration, production efficiencies, reservoir management, environmental effects and safety. Implementation of the strategy is occurring via ajoint Petroleum R&D Committee. ERDC's role in this process is to manage its investment in the projects resulting from the strategy to maximise the chances of successful implementation of the outcomes for the benefit of the industry and Australia.
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Powell, Trevor G. "Discovering Australia's future petroleum resources: the strategic geoscience information role of government." APPEA Journal 48, no. 1 (2008): 299. http://dx.doi.org/10.1071/aj07020.
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Australia’s production of oil is in steady decline. Given the maturity of the oil producing areas, only the discovery of a significant new oil province can arrest the long-term decline in Australian production. Moreover, the increase in demand for clean energy and the location of Australia’s major gas reserves means additional gas resources are also desirable. Many sedimentary basins both onshore and offshore are under-explored and are classed as exploration frontiers. Only Australian national, State and Territory governments, acting jointly or severally in partnership with the private sector, can ensure that the petroleum resource endowment of these frontiers is appropriately explored and developed to the benefit of the nation. As a nation, Australia needs to know the extent of this resource endowment. A major barrier to the exploration of these frontier basins is the absence of sufficient basic geological information to allow exploration investors to make well-informed decisions. Understanding prospectivity is a primary consideration for explorationists, but such assessments are fundamentally dependent upon an infrastructure of geoscience data, concepts and knowledge which provide the framework of successful exploration. The absence of information means high risk and reduces the possibility of investment in exploration in frontier basins. For exploration frontiers the basic geological information collected by State and national geological surveys is fundamental to informed decision-making by exploration companies. Australia competes with other nations for global exploration investment. Given the sovereign rights to the resource and the importance of oil and gas to the nation’s economy and security, provision of pre-competitive geoscience information by government is an effective way of attracting exploration investment to Australia. However, the supply of pre-competitive geoscience data—which includes ready access to pre-existing industry data and information—is a strategic enterprise that must be maintained for many years if it is to serve the needs of the nation and the industry through the long lead and cycle times inherent in the exploration and production cycle. Promotion of successful exploration is dependent on the maintenance of a competitive exploration environment that includes the free flow of relevant information in forms that meet the need of all market players. Australia has excellent examples of strategies and case histories where provision and promotion of geoscience information has been effective in attracting significant exploration investment.
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Moore, R. K., and R. M. Willcocks. "SOME COMMERCIAL ASPECTS OF PETROLEUM EXPLORATION AND MINING." APPEA Journal 25, no. 1 (1985): 143. http://dx.doi.org/10.1071/aj84014.
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The petroleum industry in Australia is at the centre of a web of complex laws. In addition to the legislation under which petroleum exploration and production tenements are granted there is a multiplicity of statutes and regulations, Commonwealth and State, which have a direct bearing on the conduct of those involved in exploring for or exploiting Australia's petroleum reserves. For example, the level of participation by foreigners is governed by the Commonwealth Foreign Investment Guidelines and the Foreign Takeovers Act 1975; the Commonwealth has control over the export of petroleum under the Customs (Prohibited Exports) Regulations and domestic markets are subject to the operation of the Crude Oil Allocation Scheme. The Commonwealth continues to have the right to regulate the transfer of funds to and from Australia under the Banking (Foreign Exchange) Regulations. Certain States such as South Australia and New South Wales have their own foreign investment guidelines.Not only this, there are revenue laws which govern very much the way in which petroleum projects are organised, interests transferred and otherwise dealt with and finance made available, such as State stamp duty legislation, Commonwealth income tax laws, and Commonwealth legislation imposing registration fees on dealings in exploration permits and production licences. A new tax, Resource Rent Tax, is to be introduced.Then there are laws which have an indirect bearing on petroleum activities such as the Companies Code which, in addition to governing the administration and organisation of companies, controls the way funds can be raised.The statutory and regulatory framework is only part of the picture. The rights and obligations of participants in petroleum projects as between themselves are almost always set out in a joint venture or joint operating agreement, the combination between the participants being known as an unincorporated joint venture. This form of business organisation is not a partnership; it is not the creature of legislation. Indeed it has been rarely referred to in Acts of Parliament. Problems arising under the joint venture agreement will be considered against the backdrop of the general law which unfortunately has seldom been called upon to resolve disputes between participants in joint ventures. An illustration of one of these rare instances is Brian Pty Ltd v United Dominions Corporation Ltd (1983), where the New South Wales Court of Appeal considered the fiduciary relationship of joint venturers.Despite this legislative and regulatory' backdrop and the uncertainties as to the true effect of joint venture agreements, the industry up until quite recently has survived with little litigation. This is no longer the case. Recent and pending litigation shows that there is no reluctance on the part of participants to take their disputes to court, often at great expense and with unfortunate results for previously close relationships. It must now be said that money spent to achieve proper and clear agreement on organisational and legal matters at the earliest stage of a project is money just as well spent as that on drilling and other operational activities.
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Handeland, Tine S., and Oluf Langhelle. "A Petrostate’s Outlook on Low-Carbon Transitions: The Discursive Frames of Petroleum Policy in Norway." Energies 14, no. 17 (August 31, 2021): 5411. http://dx.doi.org/10.3390/en14175411.
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Norway is a petroleum exporting country that, simultaneously, is at the forefront of implementing ambitious climate policy measures. Through a discourse analysis of official documents that address petroleum policy, this article examines how the Norwegian government justifies a place for Norwegian petroleum in a low-carbon future. Our findings show that the frames used to justify continued petroleum production between 2011 and 2018 remains predominantly stable, despite the growing opposition to this official discourse in relation to climate change and the societal dependence on petroleum revenues. This article highlights the tension that Norway, as a petroleum-producing country, face in an increasingly carbon-constrained world, and how this is handled in the official petroleum discourse. It shows how the official discourse portrays continued petroleum production and exploration as both valid and necessary and how this framing is discursively linked to a strong commitment to mitigate climate change.
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Stickley, D. C. "An Enviromental Code of Practice for the New Zealand Petroleum Industry: Is One Needed?" Energy Exploration & Exploitation 13, no. 2-3 (May 1995): 199–205. http://dx.doi.org/10.1177/0144598795013002-310.
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All phases of the New Zealand petroleum industry (exploration, production, transportation, storage and distribution) are governed by various overlapping, if not conflicting, pieces of legislation. The separate treatment of petroleum under the Crown Minerals Act 1991 was a recognition that ownership and grants of right to mineral resources was a function of government that is distinct from protection of the environment. Nevertheless, the Resource Management Act 1991 is the central statute which co-ordinates conditions for prevention of marine pollution under the Marine Safety Authorities Act, Dangerous Goods Act, and the proposed Hazardous Substances and New Organisms legislation. On-the-ground compliance has largely been delegated to local authorities. The adoption of regional and district plans recognising petroleum exploration and production as a permitted activity subject to resource consent requirements presents the opportunity for the New Zealand petroleum industry to put forward a code of practice that integrates a system of compliance to meet many, if not all, statutory requirements and ease the administration of this legislation by local authorities.
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Randal, M. A. "PETROLEUM EXPLORATION AND DEVELOPMENTS IN QUEENSLAND DURING 1985." APPEA Journal 26, no. 2 (1986): 46. http://dx.doi.org/10.1071/aj85051.
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Petroleum exploration in Queensland during 1985 remained at the high levels that existed during 1984. Of the 115 wells spudded, 88 were wildcat exploration wells, 24 were appraisal wells, and three were development wells. New field discoveries numbered 23, being 16 oil and 7 of gas, the highest number ever recorded. All but two of the appraisal wells and all three development wells were successful. Seismic surveys totalled 23 158 km of subsurface section, 75 per cent in the western part of the state in the Eromanga/Cooper and Eromanga/Galilee basins and their environs, and the remainder in the Surat and Bowen basins. Similar levels of exploration are expected during 1986, although the amount of seismic surveying may decrease as much as 20 per cent. Exploration is expected to be in mostly the same basins as now over the next 15 years.Two liquefied petroleum gas (LPG) separating plants came on stream in 1985 in the Surat/Bowen Basin, one at Kincora and one near Wallumbilla, with a combined output capacity of 50 000 tonnes annually. At Eromanga a mini-refinery with a capacity of about 880 barrels of oil per day commenced operations producing mostly distillate. Petroleum Leases were granted during the year over the Tintaburra and Bodalla South oilfields near Eromanga, and over the Riverslea and Yapunyah oilfields in the Surat region.Queensland's petroleum reserves now stand at 66 million barrels remaining recoverable oil, 17 billion cu m gas, and 500 000 tonnes of LPG. Daily production is about 29 000 barrels of oil and condensate, about 1.2 million cu m of gas, and 97 tonnes of LPG.There is relatively little impact to petroleum exploration in Queenland through the setting aside of land for special purposes. Legislation and administrative arrangements allow exploration in National Parks and Forest Reserves under conditions set down by the controlling bodies.
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Williamson, P. E., and C. B. Foster. "ACCESS TO AUSTRALIAN EXPLORATION AND PRODUCTION DATA: A CRITICAL FACTOR IN ATTRACTING INVESTMENT." APPEA Journal 43, no. 1 (2003): 693. http://dx.doi.org/10.1071/aj02040.
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During the past 10 years, Australia has maintained 65– 85% self-sufficiency in oil and better than 100% sufficiency in gas. This has generated significant societal benefits in terms of employment, balance of payments, and revenue. The decline of the super-giant Gippsland fields, discovery of smaller oil pools on the North West Shelf, and the increasing reliance on condensate to sustain our liquids supply, however, sharpens the focus on Australia’s need to increase exploration and discover more oil. Australia is competing in the global market place for exploration funds, but as it is relatively underexplored there is a need to simulate interest through access to pre-competitive data and information. Public access to exploration and production data is a key plank in Australian promotion of petroleum exploration acreage. Access results from legislation that initially subsidised exploration in return for lodgement and public availability of exploration and production (E&P) data. Today publicly available E&P data ranges from digital seismic tapes, to core and cuttings samples from wells, and access to relational databases, including organic geochemistry, biostratigraphy, and reservoir and shows information. Seismic information is being progressively consolidated to high density media. Under the Commonwealth Government’s Spatial Information and Data Access Policy, announced in 2001, company data are publicly available at the cost of transfer, after a relatively brief confidentiality period. In addition, pre-competitive regional studies relating to petroleum prospectivity, undertaken by Government, and databases and spatial information are free over the Internet, further reducing the cost of exploration. In cooperation with the Australian States and the Northern Territory, we are working towards jointly presenting Australian opportunities through the Geoscience Portal (http:// www.geoscience.gov.au) and a virtual one-stop data repository. The challenge now is to translate data availability to increased exploration uptake, through client information, and through ever-improving on-line access.
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Araujo, Patricia Lopes Barros De, G. Ali Mansoori, and Elmo Silvano De Araujo. "Diamondoids: occurrence in fossil fuels, applications in petroleum exploration and fouling in petroleum production. A review paper." International Journal of Oil, Gas and Coal Technology 5, no. 4 (2012): 316. http://dx.doi.org/10.1504/ijogct.2012.048981.
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Prasad, Dr R. Giri. "Petroleum and Gas Exploration and Production by Extended Reach Drilling (ERD) Wells." International Journal for Research in Applied Science and Engineering Technology 6, no. 1 (January 31, 2018): 2130–37. http://dx.doi.org/10.22214/ijraset.2018.1334.
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Hawkins, Warren S. "Petroleum Engineers and Independent Exploration and Production Companies in the Year 2000." Journal of Petroleum Technology 39, no. 10 (October 1, 1987): 1243–46. http://dx.doi.org/10.2118/15348-pa.
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Ndi, George. "The Contractual and Legal Framework for Petroleum Exploration and Production in Cameroon." Journal of Energy & Natural Resources Law 10, no. 1-4 (January 1992): 267–78. http://dx.doi.org/10.1080/02646811.1992.11432930.
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Williamson, Professor Douglas. "THE IMPACT OF RECENT NATIVE TITLE DEVELOPMENTS UPON PETROLEUM EXPLORATION AND PRODUCTION." APPEA Journal 38, no. 2 (1998): 179. http://dx.doi.org/10.1071/aj97091.
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Native Title Act 1993 (Cth)—acknowledged defects-proposed amending legislation—right to negotiate process—offshore and onshore exploration and development distinguished—obligations other than under NTA not to interfere unduly with offshore native title rights—onshore right to negotiate process—criteria—availability of expedited procedure to enable proposed activity to proceed—recent decisions limiting practical availability of expedited procedure—Cox and Western Australia and Stirling Resources NL and others (NNTT, 27 October 1997)—proposed amendments to right to negotiate process—importance of amendments to petroleum explorers and developers.
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Bond, D., N. Brock, G. Chapman, K. Lay, and G. Wormald. "INTRODUCTION OF NEW TECHNOLOGY INTO TIMOR SEA OPERATIONS." APPEA Journal 30, no. 1 (1990): 290. http://dx.doi.org/10.1071/aj89018.
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The Timor Sea is the most remote and under-explored oil province in Australia. In order to compensate for the high exploration costs which result in frontier areas, new technology has been introduced by BHP Petroleum in order to increase drilling efficiency, assist in well evaluation and enhance the reliability of production technology. Examples of innovation and the importation of advanced techniques into the Timor Sea region are discussed. Advanced mud systems and PDC bit designs have been developed to aid the drilling of wells. Measurement While Drilling tools and tritium tracers have been used to enhance correlation and evaluation techniques. Equipment and procedures which emphasise the philosophy of reliability and longevity have been developed for sub-sea completions. These innovations have not only assisted with cost reduction, but have also enhanced BHP Petroleum's exploration and production success in the Timor Sea.
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Al-Shuhail, Abdullatif, Youcef Bouzidi, Saleh Al-Dossary, and Yongyi Li. "Introduction to this special section: Middle East." Leading Edge 39, no. 6 (June 2020): 381. http://dx.doi.org/10.1190/tle39060381.1.
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The Middle East is one of the world's most prolific regions in terms of petroleum reserves and production. It accounts for one-third of global oil production, one-sixth of gas production, about half of proved oil reserves, and two-fifths of proved gas reserves. Recent discoveries of unconventional resources have added even more reserves to the area's vast resources. Historically, many of the conventional fields in the Middle East were discovered by using conventional geophysical exploration methods. The continuing search for conventional and unconventional reservoirs has led to a rapid advancement of geophysical technologies in data acquisition, processing, and interpretation. These advanced technologies are aimed at solving region-specific challenges in defining the complexity of the near surface and subsurface. This is evidenced by the increasing activities in the development and application of new geophysical technologies in the exploration, development, and production of petroleum resources.
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Goldstein, B. A., E. Alexander, D. Cockshell, M. Malavazos, and J. Zabrowarny. "THE VIRTUOUS LIFE CYCLE FOR EXPLORATION AND PRODUCTION—LEAD AND LAG FACTORS." APPEA Journal 47, no. 1 (2007): 387. http://dx.doi.org/10.1071/aj06029.
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‘High-trust societies fare better than low-trust societies,’— Francis Fukuyama.1Trusted land access is both the first factor and the final outcome of a virtuous exploration and production life cycle. Key leading factors in the stewardship of trusted land access and a virtuous life cycle for exploration and production in South Australia include:evolutionary, best practice, objective-based legislation;transparent statements of environmental objectives (SEOs) that enable regulators to provide a one-stopshop for approvals and avoid capture;administrative arrangements between government agencies to foster expeditious co-regulatory work-flows;conjunctive native title land access agreements that are fair and sustainable in relation to development;prioritised, pre-competitive studies that reduce critical uncertainties; and,highly motivated government officers focussed on building trust and reducing uncertainties, so both the community and investors sustain positive expectations for outcomes from exploration and production investment.This paper characterises the South Australian Government’s roles and measures for success in the virtuous life cycle for petroleum and geothermal resource investment. The critical importance of local, leading actions will be demonstrated with examples, including: proposed enhancements to South Australia’s Petroleum Act 2000; streamlined but stringent project approvals; progressive achievements in native title land access agreements; the evolution of Australia’s geothermal energy sector; and, perception moulding research in the Cooper, Otway and Officer basins.