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1
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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Carr, Lidena, Russell Korsch, and Tehani Palu. "Australia's onshore basin inventory: volume I." APPEA Journal 56, no. 2 (2016): 591. http://dx.doi.org/10.1071/aj15097.
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Following the publication of Geoscience Australia Record 2014/09: Petroleum geology inventory of Australia’s offshore frontier basins by Totterdell et al (2014), the onshore petroleum section of Geoscience Australia embarked on a similar project for the onshore Australian basins. Volume I of this publication series contains inventories of the McArthur, South Nicholson, Georgina, Amadeus, Warburton, Wiso, Galilee, and Cooper basins. A comprehensive review of the geology, petroleum systems, exploration status, and data coverage for these eight Australian onshore basins was conducted, based on the results of Geoscience Australia’s precompetitive data programs, industry exploration results, and the geoscience literature. A petroleum prospectivity ranking was assigned to each basin, based on evidence for the existence of an active petroleum system. The availability of data and level of knowledge in each area was reflected in a confidence rating for that ranking. This extended abstract summarises the rankings assigned to each of these eight basins, and describes the type of information available for each of these basins in the publically available report by Carr et al (2016), available on the Geoscience Australia website. The record allocated a high prospectivity rating for the Amadeus and Cooper basins, a moderate rating for the Galilee, McArthur and Georgina basins, and a low rating for the South Nicholson, Warburton and Wiso basins. The record lists how best to access data for each basin, provides an assessment of issues and unanswered questions, and recommends future work directions to lessen the risk of these basins in terms of their petroleum prospectivity. Work is in progress to compile inventories on the next series of onshore basins.
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Bernecker, Thomas, Steve Abbott, George Bernardel, Megan Lech, Ryan Owens, Tegan Smith, and Jennifer Totterdell. "The 2017 offshore acreage release areas: petroleum geological overview." APPEA Journal 57, no. 2 (2017): 304. http://dx.doi.org/10.1071/aj16029.
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In 2017, 21 new offshore petroleum exploration areas have been released. The majority of the areas are located along the North West Shelf spanning the Westralian Superbasin from the Bonaparte Basin in the north-east to the Northern Carnarvon Basin in the south-west. New areas have been released in offshore south-eastern Australia with new opportunities provided in the Otway, Bass and Gippsland basins. Two large areas in the northern Perth Basin, an offshore frontier, complete the 2017 Acreage Release. All Release Areas are supported by industry nominations and one new cash bid area has been offered in the Dampier Sub-basin. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available as part of the agency’s regional petroleum geological studies. A new regional 2D seismic survey was acquired in the Houtman Sub-basin of the Perth Basin, forming the basis of the latest prospectivity study carried out by Geoscience Australia. The results of the study are presented in the technical program of the 2017 APPEA conference. A wealth of seismic and well data, submitted under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGSSA) are made available through the National Offshore Petroleum Information Management System (NOPIMS). Additional datasets are accessible through Geoscience Australia’s data repository.
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Henson, Paul, David Robinson, Lidena Carr, Dianne S. Edwards, Susannah K. MacFarlane, Amber J. M. Jarrett, and Adam H. E. Bailey. "Exploring for the Future—a new oil and gas frontier in northern Australia." APPEA Journal 60, no. 2 (2020): 703. http://dx.doi.org/10.1071/aj19080.
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Exploring for the Future (EFTF) is a four-year, AU$100.5 million initiative from the Australian Government conducted by Geoscience Australia in partnership with state and Northern Territory government agencies, CSIRO and universities to provide new geoscientific datasets for frontier regions. As part of this program, Geoscience Australia acquired two new seismic surveys that collectively extend across the South Nicholson Basin (L120 South Nicholson seismic line) and into the Beetaloo Sub-basin of the McArthur Basin (L212 Barkly seismic line). Interpretation of the seismic has resulted in the discovery of new basins that both contain a significant section of presumed Proterozoic strata. Integration of the seismic results with petroleum systems geochemistry, structural analyses, geochronology, rock properties and a petroleum systems model has expanded the knowledge of the region for energy exploration. These datasets are available through Geoscience Australia’s newly developed Data Discovery Portal: an online platform delivering digital geoscientific information, including seismic locations and cross-section images, and field site and well based sample data. Specifically for the EFTF energy project, a petroleum systems framework with supporting organic geochemical data has been built to access source rock, crude oil and natural gas datasets via interactive maps, graphs and analytical tools that enable the user to gain a better and faster understanding of a basin’s petroleum prospectivity.
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B., Elizabeth Chacon, Jorge A. Briones Carrillo, Carlos G. Aguilar-Madera, Nelson E. Barros-Galvis, and Sóstenes Méndez-Delgado. "Petroleum Engineering as a (still) Promising Career in Geosciences? An Empirical Example in Northeastern Mexico." International Journal of Education 9, no. 4 (December 13, 2017): 62. http://dx.doi.org/10.5296/ije.v9i4.12297.
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More than ever, it is the time to increase the number of engineering students applying to geosciences in order to satisfy the growing national challenges and administrate our natural resources in a responsible and sustainable manner. This work analyzes the petroleum engineer career at the UANL through an 8-yr experience in order to critically evaluate the current academic profile that Petroleum Engineers need within a global and shared world. This brief appraisal also presents an updated revision of all certified academic programs offering the Petroleum Engineering career in Mexico. At the same time, this work also proposes a modest but realistic academic modality for this particular career to better fulfill the actual academic and industrial demands on this area. Adjusting the academic geoscience workforce implies a redefinition of curricular programs, values and competences for this career in a synergic action with government policies and public and private employees worldwide. Certainly, the change should be the driving force to design modern up-to-date professional profiles and better oil professionals with a global perspective to take on alternative development.
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Bernecker, Thomas, Aaron Heugh, Karen Higgins, and Ryan Owens. "The hydrocarbon potential of the 2016 proposed Offshore Acreage Release Areas for petroleum exploration." APPEA Journal 56, no. 1 (2016): 451. http://dx.doi.org/10.1071/aj15033.
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The Australian Government usually releases new offshore exploration acreage once a year. The proposed 2016 Release Areas are located across various offshore hydrocarbon provinces and include mature basins with ongoing oil and gas production as well as exploration frontiers. In support of the annual acreage release, Geoscience Australia provides a variety of geological information with an emphasis on basin evolution, stratigraphic frameworks, and overviews of hydrocarbon prospectivity. Geoscience Australia’s petroleum geological studies are aimed at the evolution of hydrocarbon-bearing basins at a regional scale, and include a review of source rock occurrences, their distribution and geochemical characters. Following the recent oil discovery in the Roebuck Basin, a strong focus of Geoscience Australia’s work is being placed on the Triassic period, and any new findings will directly underpin the release of new exploration acreage. Recent updates to stratigraphic frameworks and new results from geochemical studies are regularly published, and are used by Geoscience Australia for prospectivity assessments. Furthermore, the Australian Government continues to assist offshore exploration activities by providing ready access to a wealth of geological and geophysical data.
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Burnett, T. L. "Petroleum Exploration Risk Reduction Using New Geoscience Technology." Energy Exploration & Exploitation 14, no. 6 (December 1996): 507–34. http://dx.doi.org/10.1177/014459879601400602.
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As economics of the oil and gas industry become more restrictive, the need for new means of improving exploration risks and reducing expenses is becoming more acute. Partnerships between industry and academia are making significant improvements in four general areas: Seismic acquisition, reservoir characterization, quantitative structural modeling, and geochemical inversion. In marine seismic acquisition the vertical cable concept utilizes hydrophones suspended at fixed locations vertically within the water column by buoys. There are numerous advantages of vertical cable technology over conventional 3-D seismic acquisition. In a related methodology, ‘Borehole Seismic,’ seismic energy is passed between wells and valuable information on reservoir geometry, porosity, lithology, and oil saturation is extracted from the P-wave and S-wave data. In association with seismic methods of determining the external geometry and the internal properties of a reservoir, 3-dimensional sedimentation-simulation models, based on physical, hydrologic, erosional and transport processes, are being utilized for stratigraphic analysis. In addition, powerful, 1-D, coupled reaction-transport models are being used to simulate diagenesis processes in reservoir rocks. At the regional scale, the bridging of quantitative structural concepts with seismic interpretation has lead to breakthroughs in structural analysis, particularly in complex terrains. Such analyses are becoming more accurate and cost effective when tied to highly advanced, remote-sensing, multi-spectral data acquisition and image processing technology. Emerging technology in petroleum geochemistry enables geoscientists to infer the character, age, maturity, identity and location of source rocks from crude oil characteristics (‘Geochemical Inversion’) and to better estimate hydrocarbon-supply volumetrics, which can be invaluable in understanding petroleum systems and in reducing exploration risks and associated expenses.
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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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Bernecker, Thomas, George Bernardel, Claire Orlov, and Nadège Rollet. "Petroleum geology of the 2018 offshore acreage release areas." APPEA Journal 58, no. 2 (2018): 437. http://dx.doi.org/10.1071/aj17056.
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A total of 21 areas were released in 2018 for offshore petroleum exploration. They are located in the Bonaparte, Browse, Northern Carnarvon, Bight, Otway and Gippsland basins. All release areas were supported by industry nominations, indicating that interest in exploring Australia’s offshore basins remains strong, despite the significant decrease in the number of exploration wells drilled in recent years. Sixteen areas are being released under the work program bidding system with two rounds, one closing on 18 October 2018 and the other on 21 March 2019. Five areas are being released for cash bidding and include the producible La Bella gas accumulation in the Otway Basin. Prequalification for participation in the cash-bid auction closes on 4 October 2018 with the auction scheduled for 7 February 2019. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available as part of the agency’s regional petroleum geological studies. The regional evaluation of the petroleum systems in the Browse Basin has been completed and work continues on assessing the distribution of Early Triassic source rocks and related petroleum occurrences across the North West Shelf. A wealth of seismic and well data, submitted under the Offshore Petroleum and Greenhouse Gas Storage Act 2006, are made available through the National Offshore Petroleum Information Management System. Additional datasets are accessible through Geoscience Australia’s data repository.
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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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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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Hartwell, John. "2010 Offshore petroleum exploration release." APPEA Journal 50, no. 1 (2010): 1. http://dx.doi.org/10.1071/aj09001.
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The sustainable annual release of quality petroleum exploration acreage, to provide the global petroleum exploration industry with a variety of investment opportunities in Australian waters, is a key objective of the Australian Government. The annual Offshore Petroleum Exploration Acreage Release (Acreage Release) is underpinned by Australia’s stable economic environment and well-established regulatory framework for offshore petroleum activities. The 2010 Acreage Release areas are located across five basins. Release areas have been carefully selected to offer a range of investment opportunities; areas vary in size, known prospectivity, water depth and level of existing geological data and knowledge. Areas are supported by pre-competitive geological and geophysical data and analysis undertaken by Geoscience Australia.
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Gibbs, James Alanson. "The American Association of Petroleum Geologists and Geoscience Education." Journal of Geological Education 39, no. 2 (March 1991): 118–20. http://dx.doi.org/10.5408/0022-1368-39.2.118.
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Williamson, P. E., and F. Kroh. "THE ROLE OF AMPLITUDE VERSUS OFFSET TECHNOLOGY IN PROMOTING OFFSHORE PETROLEUM EXPLORATION IN AUSTRALIA." APPEA Journal 47, no. 1 (2007): 163. http://dx.doi.org/10.1071/aj06009.
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Amplitude versus offset (AVO) technology has proved itself useful in petroleum exploration in various parts of the world, particularly for gas exploration. To determine if modern AVO compliant processing could identify potential anomalies for exploration of open acreage offshore Australia, Geoscience Australia reprocessed parts of four publicly available long cable lines. These lines cover two 2006 acreage release areas on the Exmouth Plateau and in the Browse Basin on the North West Shelf. An earlier study has also been done on two publicly available long cable lines from Geoscience Australia’s Bremer Basin study and cover areas from the 2005 frontier acreage release on the southern margin. The preliminary results from these three reprocessing efforts produced AVO anomalies and were made publicly available to assist companies interested in assessing the acreage. The results of the studies and associated data are available from Geoscience Australia at the cost of transfer.The AVO data from the Exmouth Plateau show AVO anomalies including one that appears to be at the Jurassic level of the reservoir in the Jansz/Io supergiant gas field in adjacent acreage to the north. The AVO data from the Caswell Sub-basin of the Browse Basin show an AVO anomaly at or near the stratigraphic zone of the Brecknock South–1 gas discovery to the north. The geological settings of strata possibly relating to two AVO anomalies in the undrilled Bremer Basin are in the Early Cretaceous section, where lacustrine sandstones are known to occur. The AVO anomalies from the three studies are kilometres in length along the seismic lines.These preliminary results from Geoscience Australiaand other AVO work that has been carried out by industry show promise that AVO compliant processing has value—particularly for gas exploration offshore Australia—and that publicly available long-cable data can be suitable for AVO analysis.
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Loutit, T. S. "AUSTRALIAN PETROLEUM RESEARCH AND DEVELOPMENT: AN EXAMPLE OF PROBLEM-DRIVEN GEOSCIENCE RESEARCH MANAGEMENT." APPEA Journal 36, no. 1 (1996): 500. http://dx.doi.org/10.1071/aj95028.
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The Australian petroleum exploration research program is customer-driven and reflects the balance between the need for the petroleum industry to reduce exploration risk in the short term and the government need to improve the perception of prospectivity in the longer term. Higher prospectivity will lead to greater exploration investment and competition, whereas risk-reduction will increase the efficiency and effectiveness of the exploration industry. Thus the objectives of the primary customers may be significantly different, with government intent on increasing the amount of investment and competition between explorers, whereas industry is intent on keeping expenditure to a minimum and maintaining competitive advantage. Despite the differences, collaboration between all groups involved in exploration and exploration-related research in Australia is essential to solve the range of exploration problems and generate new paradigms. Collaborative research ventures are most successful when new ideas stimulate explorer and researcher alike to focus resources on the key questions despite factors such as competitive advantage. Government geoscience researchers must play a significant role in generating and marketing new concepts to help maintain Australia's supply of domestic petroleum products.The scale of the petroleum research undertaken, and the degree of collaboration between industry and research groups in Australia, is remarkable. There is a productive balance between groups developing and applying new technology and those undertaking regional geological and petroleum systems research. This balance has been reached because of the long-term commitment by the Australian Government, via legislation and funding, to ensure the preservation of exploration data in national geoscience database systems, and that basic and applied research at all scales, from basins to wells, is undertaken in support of petroleum exploration and development.Despite the success of a number of collaborative research projects, research and development resources are still under-utilised by the Australian petroleum industry. Government research agencies must develop a higher marketing profile to ensure that the utilisation of the resources is at a maximum.
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Bernecker, Thomas, Ryan Owens, Andrew Kelman, and Kamal Khider. "Geological overview of the 2021 offshore acreage release areas." APPEA Journal 61, no. 2 (2021): 294. http://dx.doi.org/10.1071/aj20113.
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In 2021, a total of 21 areas were released for offshore petroleum exploration. They are located in the Bonaparte Basin, Browse Basin, Northern Carnarvon Basin, Otway Basin, Sorell Basin and Gippsland Basin. Despite COVID-19 negatively impacting the industry, participation in the acreage release nomination process was again robust. However, as has been the case in recent years, industry interest is focussed on those areas that are close to existing discoveries and related infrastructure. In tune with the Australian government’s resource development strategy, the areas being offered for exploration are likely to supply extra volumes of natural gas, both for export to Southeast Asian markets and domestically to meet the forecasted shortage in supply to eastern Australia. According to the 2019 implementation of a modified release process, only one period for work program bidding has been scheduled. The closing date for all submissions is Thursday, 3 March 2022. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available in the context of the agency’s regional petroleum geological studies. As part of a multidisciplinary study, new data, including regional seismic and petroleum systems modelling, for the Otway Basin are now available. Also, a stratigraphic/sedimentological review of the upper Permian to Early Triassic succession in the southern Bonaparte Basin has been completed, the results of which are being presented at this APPEA conference. Large seismic and well data sets, submitted under the Offshore Petroleum and Greenhouse Gas Storage Act 2006 (OPGSSA), are made available through the National Offshore Petroleum Information Management System (NOPIMS). Additional data and petroleum-related information can be accessed through Geoscience Australia’s data repository.
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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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Foster, Clinton. "GEOSCIENCE AUSTRALIA’S PETROLEUM PROGRAM—OUTCOMES AND FUTURE DIRECTIONS: 2003–2011." APPEA Journal 47, no. 2 (2007): 625. http://dx.doi.org/10.1071/aj06055.
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Dowey, Patrick J., Mark Osborne, and Herbert Volk. "Application of analytical techniques to petroleum systems: an introduction." Geological Society, London, Special Publications 484, no. 1 (2020): 1–7. http://dx.doi.org/10.1144/sp484-2020-57.
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AbstractCutting-edge techniques have always been utilized in petroleum exploration and production to reduce costs and improve efficiencies. Innovations in analytical methods will continue to play a key role in the industry moving forwards, as society shifts towards lower carbon energy systems. This volume brings together new analytical approaches and describes how they can be applied to the study of petroleum systems. The papers within this volume cover a wide range of topics and case studies, in the fields of fluid and isotope geochemistry, organic geochemistry, imaging and sediment provenance. The work illustrates how the current, state-of-the-art technology can be effectively utilized to address ongoing challenges in petroleum geoscience.
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Knight, Tony. "Approaches to data-driven exploration in Queensland." APPEA Journal 59, no. 2 (2019): 896. http://dx.doi.org/10.1071/aj18077.
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Queensland has a very significant petroleum resource endowment within 27 hydrocarbon basins spread across the state. Three of those basins already host Australia’s largest onshore gas supply industry, leaving significant opportunity to develop additional gas resources. To optimise the development of new resources, the Geological Survey of Queensland (GSQ) is implementing an integrated approach to exploration and appraisal called ‘data driven exploration’. Working in collaboration with industry, the research sector and relevant government agencies, GSQ is promoting data-driven exploration in four ways: by (1) optimising the type and quality of geoscience data collected and reported by industry; (2) improving data curation practices in government data repositories; (3) creating value-added opportunities for the use of geoscience data; and (4) improving industry capability and capacity through skills enhancement, collaborative mechanisms, and access to an expert capability network. The overarching objective of ‘data-driven exploration’ is to enable industry exploration and appraisal success by making best use of geoscience data coupled with supporting mechanisms to improve competency and capability to derive, interpret and employ geoscience information. The expression of success will vary depending on individual circumstances, but is intended to encompass a range of outcomes including improvements in the rate, cost and efficiency of discovery and appraisal.
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Dawe, Richard A., Brent Wilson, and Winston Rajpaulsingh. "A Professional Engineering Degree in Petroleum Geoscience to Satisfy Caribbean Industry." Journal of Geoscience Education 55, no. 2 (March 2007): 181–90. http://dx.doi.org/10.5408/1089-9995-55.2.181.
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Haile, N. S. "Units of measurement in petroleum geoscience: towards the elimination of ambiguity." Bulletin of the Geological Society of Malaysia 28 (November 30, 1991): 51–61. http://dx.doi.org/10.7186/bgsm28199103.
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Dowey, Patrick J., Mark Osborne, and Herbert Volk. "About this title - Application of Analytical Techniques to Petroleum Systems." Geological Society, London, Special Publications 484, no. 1 (2020): NP. http://dx.doi.org/10.1144/sp484.
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Cutting-edge techniques have always been utilized in petroleum exploration and production to reduce costs and improve efficiencies. The demand for petroleum in the form of oil and gas is expected to increase for electricity production, transport and chemical production, largely driven by an increase in energy consumption in the developing world. Innovations in analytical methods will continue to play a key role in the industry moving forwards as society shifts towards lower carbon energy systems and more advantaged oil and gas resources are targeted. This volume brings together new analytical approaches and describes how they can be applied to the study of petroleum systems. The papers within this volume cover a wide range of topics and case studies, in the fields of fluid and isotope geochemistry, organic geochemistry, imaging and sediment provenance. The work illustrates how the current, state-of-the-art technology can be effectively utilised to address ongoing challenges in petroleum geoscience.
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Bradshaw, Marita, Dianne Edwards, Chris Boreham, Emmanuelle Grosjean, Jennifer Totterdell, Thomas Bernecker, and Andrew Heap. "Geochemical underpinnings of Australia's offshore hydrocarbon prospectivity." APPEA Journal 54, no. 1 (2014): 415. http://dx.doi.org/10.1071/aj13041.
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Molecular and isotopic analyses of oils and gases can provide information on the depositional environment, maturation and age of their source rocks, and the post expulsion history of the hydrocarbons generated. Source rock analyses can determine their potential to generate hydrocarbons of varying type over specific thermal ranges, as well as demonstrating the strength of oil- or gas-to-source correlations. Together, this geochemical interpretation can provide insights about the extent of petroleum systems and can help delineate the relationships between hydrocarbon occurrences in a basin and across the continent. Oils that do not fit the well-established framework of oil families and Australian petroleum systems point to new source rock fairways. Examples include vagrant oils with lacustrine affinities found at various locations on the western Australian margin. Other examples are oil occurrences in the Gippsland Basin whose geochemical signatures contrast with the dominant non-marine oils, supporting the existence of a viable marine source rock facies. In under-explored and frontier basins, geochemical analyses of potential source rocks can provide key evidence to underpin new exploration efforts. For example, the recent acreage uptake in the Bight Basin was supported by Geoscience Australia’s recovery and analysis of oil-prone marine source rocks, and in the northern Perth Basin by new geochemical analysis extending the distribution of Lower Triassic Hovea marine source rocks offshore. Geoscience Australia has now embarked on a regional petroleum geological program that includes a national source rock study aimed at identifying and characterising Australia’s hydrocarbon sources, families and systems.
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Fleming, Robert S., James C. Janssen, and Thomas Woolley. "Technology Utilisation at Oryx Energy." Energy Exploration & Exploitation 10, no. 4-5 (September 1992): 223–29. http://dx.doi.org/10.1177/014459879201000403.
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The petroleum industry has achieved major improvements in recent years in finding, developing and producing oil and gas. These improvements have been through advances in all facets of technology including computer and workstation technologies as well as horizontal drilling. Oryx Energy has aggressively applied these new techniques to improve its competitive edge. The company uses the Unix workstation systems which allow simultaneous multiple processing and improved performance and graphics. The company's Amdahl mainframe is the hub of a worldwide network of business and scientific computers. These computers use advanced geoscience and engineering software. For example, geoscience software allows sophisticated analysis and interpretation of 2D and 3D seismic data. Oryx Energy's worldwide network also allows different specialist teams of engineers, geologists and geophysicists in different locations to provide more effective, integrated evaluations of data resulting in increased success rates.
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Hall, Lisa S., Meredith L. Orr, Megan E. Lech, Steven Lewis, Adam H. E. Bailey, Ryan Owens, Barry E. Bradshaw, and George Bernardel. "Geological and Bioregional Assessments: assessing the prospectivity for tight, shale and deep-coal resources in the Cooper Basin, Beetaloo Subbasin and Isa Superbasin." APPEA Journal 61, no. 2 (2021): 477. http://dx.doi.org/10.1071/aj20035.
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The Geological and Bioregional Assessment Program is a series of independent scientific studies undertaken by Geoscience Australia and the CSIRO, supported by the Bureau of Meteorology, and managed by the Department of Agriculture, Water and the Environment. The program consists of three stages across three regions with potential to deliver gas to the East Coast Gas Market. Stage 1 was a rapid regional prioritisation conducted by Geoscience Australia, to identify those sedimentary basins with the greatest potential to deliver shale and/or tight gas to the East Coast Gas Market within the next 5–10 years. This prioritisation process assessed 27 onshore eastern and northern Australian basins with shale and/or tight gas potential. Further screening reduced this to a shortlist of nine basins where exploration was underway. The shortlisted basins were ranked on a number of criteria. The Cooper Basin, the Beetaloo Subbasin and the Isa Superbasin were selected for more detailed assessment. Stage 2 of the program involved establishing a baseline understanding of the identified regions. Geoscience Australia produced regional geological evaluations and conceptualisations that informed the assessment of shale and/or tight gas prospectivity, ground- and surface-water impacts and hydraulic fracturing models. Geoscience Australia’s relative prospectivity assessments provide an indication of where viable petroleum plays are most likely to be present. These data indicate areal and stratigraphic constraints that support the program’s further work in Stage 3, on understanding likely development scenarios, impact assessments and causal pathways.
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Behrenbruch, P. "MANAGEMENT OF UNCERTAINTY AND RISK IN OFFSHORE PETROLEUM DEVELOPMENT." APPEA Journal 42, no. 1 (2002): 113. http://dx.doi.org/10.1071/aj01007.
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Uncertainty in petroleum development projects is most often associated with petroleum reserves. It is the limited amount of subsurface data typically available during the time of development planning that creates this situation. Risks are associated not only with reservoir uncertainty but also with wells and production facilities. Risks for offshore projects, as compared to those onshore, are further compounded by very large capital expenditures and less flexibility in catering for subsurface surprises, or remedial action in case of engineering blunders.These concepts are illustrated using case histories of successful and failed projects. Lessons learned from these and other projects are then summarised and processes for uncertainty and risk management are outlined. Risk and uncertainty cover a wide range of issues, and relate to geoscience, reservoir engineering, well technology, facilities engineering, operations, and project planning and evaluation.
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Haggart, James W. "New contributions in Baffin Bay/Labrador Sea petroleum exploration and development geoscience." Bulletin of Canadian Petroleum Geology 62, no. 4 (December 1, 2014): 213–16. http://dx.doi.org/10.2113/gscpgbull.62.4.213.
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Struckmeyer, Heike I. M. "THE NORTHERN ARAFURA BASIN—EXPLORATION OPPORTUNITIES FROM GEOSCIENCE AUSTRALIA’S NEW PETROLEUM PROGRAM." APPEA Journal 46, no. 2 (2006): 143. http://dx.doi.org/10.1071/aj05064.
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Burnett, T. L. "NEW DIRECTIONS IN GEOSCIENCE TECHNOLOGY FOR PETROLEUM EXPLORATION IN THE NEW AGE." APPEA Journal 34, no. 1 (1994): 189. http://dx.doi.org/10.1071/aj93019.
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As economics of the oil and gas industry become more restrictive, the need for new means of improving exploration risks and reducing expenses is becoming more acute. Partnerships between industry and academia are making significant improvements in four general areas: Seismic acquisition, reservoir characterisation, quantitative structural modelling, and geochemical inversion.In marine seismic acquisition the vertical cable concept utilises hydrophones suspended at fixed locations vertically within the water column by buoys. There are numerous advantages of vertical cable technology over conventional 3-D seismic acquisition. In a related methodology, 'Borehole Seismic', seismic energy is passed between wells and valuable information on reservoir geometry, porosity, lithology, and oil saturation is extracted from the P-wave and S-wave data.In association with seismic methods of determining the external geometry and the internal properties of a reservoir, 3-dimensional sedimentation-simulation models, based on physical, hydrologic, erosional and transport processes, are being utilised for stratigraphic analysis. In addition, powerful, 1-D, coupled reaction-transport models are being used to simulate diagenesis processes in reservoir rocks.At the regional scale, the bridging of quantitative structural concepts with seismic interpretation has led to breakthroughs in structural analysis, particularly in complex terrains. Such analyses are becoming more accurate and cost effective when tied to highly advanced, remote-sensing, multi-spectral data acquisition and image processing technology. Emerging technology in petroleum geochemistry, enables geoscientists to infer the character, age, maturity, identity and location of source rocks from crude oil characteristics ('Geochemical Inversion') and to better estimate hydrocarbon-supply volumetrics. This can be invaluable in understanding petroleum systems and in reducing exploration risks and associated expenses.
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Thorning, Leif, Lisbeth Aa Christensen, Bo Møller Nielsen, Frands Schjøth, and Henrik Stendal. "On-line presentation of mineral occurrences in Greenland." Geological Survey of Denmark and Greenland (GEUS) Bulletin 7 (July 29, 2005): 57–60. http://dx.doi.org/10.34194/geusb.v7.4839.
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The Geological Survey of Denmark and Greenland (GEUS) and the Bureau of Minerals and Petroleum (BMP, under the Government of Greenland) have co-operated on the international promotion of the mineral resources of Greenland for more than ten years. The Government of Greenland follows a strategy aimed at the development of a mining and petroleum sector in Greenland capable of yielding a significant proportion of the national income. To reach this goal it is necessary to attract international investment. In respect of mineral exploration, many parts of Greenland can still be considered virgin territory and it is therefore vital that all data relevant for the identification of possible exploration targets are available to the international mining industry. GEUS has produced many compilations of geoscience data for that purpose in traditional reports, on CD-ROMs and in scientific journals. In 2004, a new source of geoscience information was developed based on an interactive GIS facility on the Internet, and mineral exploration data and information from a region in central West Greenland are now accessible at the Greenland Mineral Occurrence Map (GMOM) website at GEUS (Fig. 1; www.geus.dk/gmom). Technically, this new facility will be maintained and developed in accordance with general principles for Internet services adopted by GEUS (e.g. Tulstrup 2004). New information from other regions of Greenland will gradually be added.
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Nicholson, Chris, Steve Abbott, George Bernardel, and Merrie-Ellen Gunning. "Stratigraphic framework and structural architecture of the Upper Cretaceous in the deep-water Otway Basin – implications for frontier hydrocarbon prospectivity." APPEA Journal 62, no. 2 (May 13, 2022): S467—S473. http://dx.doi.org/10.1071/aj21072.
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Geoscience Australia has undertaken a regional seismic mapping study that extends into the frontier deep-water region of the offshore Otway Basin. This work builds on seismic mapping and petroleum systems modelling published in the 2021 Otway Basin Regional Study. Seismic interpretation spans over 18 000 line-km of new and reprocessed data collected in the 2020 Otway Basin seismic program and over 40 000 line-km of legacy 2D seismic data. Fault mapping has resulted in refinement and reinterpretation of regional structural elements, particularly in the deep-water areas. Structure surfaces and isochron maps highlight Shipwreck (Turonian–Santonian) and Sherbrook (Campanian–Maastrichtian) supersequence depocentres across the deep-water part of the basin. These observations will inform the characterisation of petroleum systems within the Upper Cretaceous succession, especially in the underexplored deep-water region.
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Bailey, Adam H. E., Amber J. M. Jarrett, Liuqi Wang, David N. Dewhurst, Lionel Esteban, Shane Kager, Ludwig Monmusson, Lidena K. Carr, and Paul A. Henson. "Exploring for the Future geomechanics: breaking down barriers to exploration." APPEA Journal 61, no. 2 (2021): 579. http://dx.doi.org/10.1071/aj20039.
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Exploring for the Future (EFTF) is an Australian Government initiative focused on gathering new data and information about potential mineral, energy and groundwater resources across Australia. The energy component of EFTF, initially focussed on northern Australia, aims to improve our understanding of the petroleum potential of frontier Australian basins. Building an understanding of geomechanical rock properties is key to understanding both conventional and unconventional petroleum systems as well as carbon storage and sedimentary geothermal systems. Under EFTF, Geoscience Australia has undertaken geomechanical work including stress modelling, shale brittleness studies and the acquisition of new rock property data through extensive testing on samples from the Paleo- to Mesoproterozoic South Nicholson region of Queensland and the Northern Territory, and the Paleozoic Kidson Sub-basin of Western Australia. Work in these regions demonstrates regional stress orientations in broad agreement with previously modelled, continent-scale stress orientations and stress magnitudes that vary through the basin with depth and by lithology. Rock testing highlights potentially brittle shales and demonstrates variable rock properties in line with lithology. These analyses are summarised herein. Providing baseline geomechanical data in frontier basins is essential as legacy data coverage can often be inadequate for making investment decisions, particularly where unconventional plays are a primary exploration target. As EFTF increases in scope, Geoscience Australia anticipates expanding these studies to encompass further underexplored regions throughout Australia, lowering the barrier to entry and encouraging greenfield exploration.
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Larsen, Eirik, S. J. Purves, D. Economou, and B. Alaei. "Is Machine Learning taking productivity in petroleum geoscience on a Moore’s Law trajectory?" First Break 36, no. 12 (December 1, 2018): 135–41. http://dx.doi.org/10.3997/1365-2397.n0145.
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Bradshaw, Marita. "Review of the 2008 offshore petroleum exploration release areas." APPEA Journal 48, no. 1 (2008): 359. http://dx.doi.org/10.1071/aj07025.
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Each year the Australian Government releases new offshore opportunities for petroleum exploration. Thirty-five new exploration areas located across five of Australia’s offshore sedimentary basins are offered in the 2008 Release. All the areas are available through a work program bidding system with closing dates for bids at six and 12 months from the date of release. Acreage in the first round closes on 9 October 2008 and includes the more explored areas. The second closing round on 9 April 2009 comprises acreage located in less well explored and frontier regions. The 2008 exploration areas are in Commonwealth waters offshore of Western Australia and the Northern Territory, and in the Territory of the Ashmore and Cartier Islands adjacent area. The 2008 Release focusses on the North West Shelf, as well as offering two new exploration areas in the Vlaming Sub-basin in the offshore Perth Basin. Seven of the new release areas are located in Australia’s major hydrocarbon producing province, the Carnarvon Basin. They include a shallow water area in the western Barrow Sub-basin and another on the Rankin Platform, three areas in deeper water in the Exmouth Sub-basin and two on the deepwater Exmouth Plateau. Six areas are available for bidding in the Browse Basin and another five in the Bedout Sub-basin of the Roebuck Basin. In the Bonaparte Basin, the 15 Release areas are located in shallow water and represent a range of geological settings, including the Vulcan and Petrel sub-basins, Ashmore Platform and Londonderry High. The 2008 Offshore Petroleum Exploration Release of 35 areas in five basins covers a wide range in size, water depth and exploration maturity to provide investment opportunities suited to both small and large explorers. The Release areas are selected from nominations from industry, the States and Territory, and Geoscience Australia. The focus of the 2008 Release is on the North West Shelf where there is strong industry interest in the producing Carnarvon and Bonaparte basins and in the Browse Basin, the home of super-giant gas fields under active consideration for development. Also included in the 2008 Release is the Bedout Sub-basin, in the Roebuck Basin, located on the central North West Shelf, between the hotly contested Carnarvon and Browse basins. In addition, the Release show-cases the southern Vlaming Sub-basin, Perth Basin, where recent studies by Geoscience Australia provide a new understanding of petroleum potential (Nicholson et al, this volume).
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Troup, Alison, Melanie Fitzell, Sally Edwards, Owen Dixon, and Gopalakrishnan Suraj. "Unconventional petroleum resource evaluation in Queensland." APPEA Journal 53, no. 2 (2013): 471. http://dx.doi.org/10.1071/aj12082.
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The search for unconventional petroleum resources requires a shift in the way the petroleum potential of sedimentary basins is assessed. Gas in source rocks and tight reservoirs has largely been ignored in preference for traditional conventional gas plays. Recent developments in technology now allow for the extraction of gas trapped in low-permeability reservoirs. Assessments of the unconventional petroleum potential of basins, including estimates of the potential resource are required to guide future exploration. The Geological Survey of Queensland is collaborating with Geoscience Australia (GA) and other state agencies to undertake regional assessments of several basins with potential for unconventional petroleum resources in Queensland. The United States Geological Survey methodology for assessment of continuous petroleum resources is being adopted to estimate total undiscovered oil and gas resources. Assessments are being undertaken to evaluate the potential of key formations as shale oil and gas and tight-gas plays. The assessments focus on mapping key attributes including depth, thickness, maturity, total organic carbon (TOC), porosity, gas content, reservoir pressure, mineralogy and regional facies patterns using data from stratigraphic bores and petroleum wells to determine play fairways or areas of greatest potential. More detailed formation evaluation is being undertaken for a regional framework of wells using conventional log suites and mudlogs to calculate porosity, TOC, maturity, oil and gas saturations, and gas composition. HyLoggerTM data is being used to determine its validity to estimate bulk mineralogy (clay-carbonate-quartz) compared with traditional x-ray diffraction methods. These methods are being applied to key formations with unconventional potential in the Georgina and Eromanga basins in Queensland.
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Harris, P. T., A. Heap, A. Post, T. Whiteway, A. Potter, and M. Bradshaw. "MARINE ZONE MANAGEMENT AND THE EPBC ACT—HOW ENVIRONMENTAL MARINE GEOLOGICAL INFORMATION PROVIDES CERTAINTY FOR PETROLEUM EXPLORATION." APPEA Journal 47, no. 1 (2007): 329. http://dx.doi.org/10.1071/aj06024.
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To protect the diversity of marine life in Australia’s Exclusive Economic Zone (EEZ), the federal parliament has passed the Environmental Protection and Biodiversity Conservation (EPBC) Act 1999. The Act is being implemented through the design of a national representative system of marine protected areas (MPAs) that will place under protection a representative portion of Australia’s EEZ by 2012. There have already been 13 MPAs nominated for the southeast region in 2006.Limited biological data in Australia’s EEZ has resulted in biophysical information compiled by Geoscience Australia being used as a proxy for seabed biodiversity in support of marine conservation planning. Information we use to characterise the seabed includes bathymetry, geomorphology, acoustic properties, sediment properties, and slope and sediment mobilisation due to waves and tides. To better characterise habitats on the Australian continental shelf, Geoscience Australia is creating seascape maps (similar to geological facies maps) that integrate these multiple layers of spatial data, and which are useful for the prediction of the distribution of biodiversity in Australia’s EEZ. This information provides 100% spatial coverage based on objective, multivariate statistical methods and offers certainty for managers and stakeholders including the oil and gas industry, who are involved with designing Australia’s national MPA system. Certainty for industries operating in the EEZ is enhanced by a reproducible, science-based approach for identifying conservation priorities and the classification of sea floor types within multiple use areas.
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Bradshaw, Barry. "BREMER AND VLAMING RELEASE AREAS: NEW EXPLORATION OPPORTUNITIES FROM GEOSCIENCE AUSTRALIA’S NEW PETROLEUM PROGRAM." APPEA Journal 45, no. 2 (2005): 111. http://dx.doi.org/10.1071/aj04065.
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Ishutov, Sergey, T. Dawn Jobe, Shuo Zhang, Miguel Gonzalez, Susan M. Agar, Franciszek J. Hasiuk, Francesca Watson, Sebastian Geiger, Eric Mackay, and Richard Chalaturnyk. "Three-dimensional printing for geoscience: Fundamental research, education, and applications for the petroleum industry." AAPG Bulletin 102, no. 01 (January 2018): 1–26. http://dx.doi.org/10.1306/0329171621117056.
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Borissova, Irina, and Gabriel Nelson. "Petroleum potential of the offshore southern Carnarvon Basin—insights from new Geoscience Australia data." APPEA Journal 51, no. 2 (2011): 746. http://dx.doi.org/10.1071/aj10126.
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In 2008–9, under the Offshore Energy Security Program, Geoscience Australia (GA) acquired 650 km of seismic data, more than 3,000 km of gravity and magnetic data, and, dredge samples in the southern Carnarvon Basin. This area comprises the Paleozoic Bernier Platform and southern part of the Mesozoic Exmouth Sub-basin. The new seismic and potential field data provide a new insight into the structure and sediment thickness of the deepwater southernmost part of the Exmouth Sub-basin. Mesozoic depocentres correspond to a linear gravity low, in water depths between 1,000–2,000 m and contain between 2–3 sec (TWT) of sediments. They form a string of en-echelon northeast-southwest oriented depressions bounded by shallow-dipping faults. Seismic data indicates that these depocentres extend south to at least 24°S, where they become more shallow and overprinted by volcanics. Potential plays in this part of the Exmouth Sub-basin may include fluvio-deltaic Triassic sandstone and Lower–Middle Jurassic claystone source rocks sealed by the regional Early Cretaceous Muderong shale. On the adjoining Bernier Platform, minor oil shows in the Silurian and Devonian intervals at Pendock–1a indicate the presence of a Paleozoic petroleum system. Ordovician fluvio-deltaic sandstones sealed by the Silurian age marine shales, Devonian reef complexes and Miocene inversion anticlines are identified as potential plays. Long-distance migration may contribute to the formation of additional plays close to the boundary between the two provinces. With a range of both Mesozoic and Paleozoic plays, this under-explored region may have a significant hydrocarbon potential.
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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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Danabalan, Diveena, Jon G. Gluyas, Colin G. Macpherson, Thomas H. Abraham-James, Josh J. Bluett, Peter H. Barry, and Chris J. Ballentine. "The principles of helium exploration." Petroleum Geoscience 28, no. 2 (January 11, 2022): petgeo2021–029. http://dx.doi.org/10.1144/petgeo2021-029.
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Commercial helium systems have been found to date as a serendipitous by-product of petroleum exploration. There are nevertheless significant differences in the source and migration properties of helium compared with petroleum. An understanding of these differences enables prospects for helium gas accumulations to be identified in regions where petroleum exploration would not be tenable. Here we show how the basic petroleum exploration playbook (source, primary migration from the source rock, secondary longer distance migration, trapping) can be modified to identify helium plays. Plays are the areas occupied by a prospective reservoir and overlying seal associated with a mature helium source. This is the first step in identifying the detail of helium prospects (discrete pools of trapped helium). We show how these principles, adapted for helium, can be applied using the Rukwa Basin in the Tanzanian section of the East African Rift as a case study. A thermal hiatus caused by rifting of the continental basement has resulted in a surface expression of deep crustal gas release in the form of high-nitrogen gas seeps containing up to 10% 4He. We calculate the total likely regional source-rock helium generative capacity, identify the role of the Rungwe volcanic province in releasing the accumulated crustal helium and show the spatial control of helium concentration dilution by the associated volcanic CO2. Nitrogen, both dissolved and as a free-gas phase, plays a key role in the primary and secondary migration of crustal helium and its accumulation into what might become a commercially viable gas pool. This too is examined. We identify and discuss evidence that structures and seals suitable for trapping hydrocarbon and CO2 gases will likely also be efficient for helium accumulation on the timescale of the Rukwa Basin activity. The Rukwa Basin prospective recoverable P50 resources of helium have been independently estimated to be about 138 BSCF (billion standard cubic ft: 2.78 × 109 m3 at STP). If this volume is confirmed it would represent about 25% of the current global helium reserve. Two exploration wells, Tai 1 and Tai 2, completed by August 2021 have proved the presence of seal and reservoir horizons with the reservoirs containing significant helium shows.This article is part of the Energy Geoscience Series available at https://www.lyellcollection.org/cc/energy-geoscience-series
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Hutton, Laurie, Melanie Fitzell, Kinta Hoffmann, Ian Withnall, Bernie Stockill, Ben Jupp, and Paul Donchak. "The Millungera Basin—new geoscience supporting exploration." APPEA Journal 50, no. 2 (2010): 727. http://dx.doi.org/10.1071/aj09091.
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An unknown sedimentary sequence was first recorded during a Geoscience Australia/ Geological Survey of Queensland/ pmd*CRC deep seismic reflection survey in the Mount Isa Inlier and adjacent undercover terrains, during 2006/07. The sequence occurs unconformably underneath the Carpentaria Basin succession in the Julia Creek area, east of Cloncurry in north Queensland, and is named the Millungera Basin. A section through the basin is recorded along seismic line 07GA–IG1, recorded between north of Cloncurry to east of Croydon. In this section three internal sequences are noted—with two strongly reflective units separated by a poorly reflective unit. As well as deep crustal seismic reflection profiles, magnetotelluric profiles were collected along the same traverse. These data show a moderately conductive Millungera Basin underlying the strongly conductive Carpentaria Basin. Zones of limited reflectors beneath the basin in the seismic sections have been interpreted as granites, raising the possibility of raised geothermal gradients. The Millungera Basin may comprise a potential geothermal target. The Millungera Basin sequence is interpreted to overlie granites. Adjacent Proterozoic granites of the Williams Batholith are known to be high heat producing granites, containing high levels of potassium thorium and uranium. The hydrocarbon potential of the basin is similarly uncertain. Strong reflectors in the seismic sections may be coal beds. Although the depth of the basin in the seismic section is insufficient to have reached the oil window, interpretation of gravity profiles by Geoscience Australia suggest the basin deepens to the south, possibly reaching 4,000 m. If fertile beds have reached the oil window, the structurally more complex eastern side of the basin may contain petroleum traps. The age of the rocks in the Millungera Basin is not known. Constraints from the seismic suggest between the early Mesoproterozoic and the Middle Jurassic. Investigations into the nature of the basin are continuing. A more detailed magnetotellurc survey is being undertaken to better define the shape of the basin. In order to reliably describe the basins components, a deep drilling program is required.
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Smith, Tegan, John Laurie, Lisa Hall, Robert Nicoll, Andrew Kelman, and James Ogg. "The times they are a-changin': Australian biozones, petroleum basins, and the international geologic time scale (GTS) 2012." APPEA Journal 54, no. 2 (2014): 473. http://dx.doi.org/10.1071/aj13046.
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The international Geologic Time Scale (GTS) continually evolves due to refinements in age dating and the addition of more defined stages. The GTS 2012 has replaced GTS 2004 as the global standard timescale, resulting in changes to the age and duration of most chronological stages. These revisions have implications for interpreted ages and durations of sedimentary rocks in Australian basins, with ramifications for petroleum systems modelling. Accurate stratigraphic ages are required to reliably model the burial history of a basin, hence kerogen maturation and hydrocarbon expulsion and migration. When the resolution of the time scale is increased, models that utilise updated ages will better reflect the true basin history. The international GTS is largely built around northern hemisphere datasets. At APPEA 2009, Laurie et al. announced a program to tie Australian biozones to GTS 2004. Now, with the implementation of GTS 2012, these ties are being updated and refined, requiring a comprehensive review of the correlations between Australian and International biozonation schemes. The use of Geoscience Australia’s Timescales Database and a customised ‘Australian Datapack’ for the visualisation software package TimeScale Creator has greatly facilitated the transition from GTS 2004 to GTS 2012, as anticipated in the design of the program in 2009. Geoscience Australia’s basin biozonation and stratigraphy charts (e.g. Northern Carnarvon and Browse basins) are being reproduced to reflect the GTS 2012 and modified stratigraphic ages. Additionally, new charts are being added to the series, including a set of onshore basin charts, such as the Georgina and Canning basins.
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Edwards, Sally, and Behnam Talebi. "New deep crustal seismic data acquisition program for NWQ's frontier petroleum basins." APPEA Journal 59, no. 2 (2019): 869. http://dx.doi.org/10.1071/aj18084.
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The Georgina and South Nicholson basins and the Isa Superbasin of North West Queensland (NWQ), represent frontier basins earmarked for examination of resource potential under the Strategic Resources Exploration Program. Little exploration has occurred for petroleum resources in these basins although a proven petroleum system exists in both the Isa Superbasin and the Georgina Basin with demonstrated flow at sub-commercial rates. To increase knowledge of the petroleum system, define the extent of the South Nicholson Basin and examine basin architecture, Geoscience Australia acquired deep (to 20-s listening time) seismic data across the South Nicholson Basin and northern Isa Superbasin area in 2017. However, this survey focused on broader structural architecture definition across the Proterozoic Isa Superbasin and South Nicholson and McArthur basins. Little is understood of the petroleum system in the southern Isa Superbasin, or even if this structure is part of the Isa Superbasin, where Proterozoic gas is inferred from mineral boreholes and oil stained Cambrian-aged carbonates exist. To increase understanding of this southern region, the Queensland Government acquired a new NWQ SEEBASE® (depth to basement) model in 2018, and will be undertaking a 2D deep seismic survey within the Camooweal region to better understand the structural architecture, sediment thicknesses and seismic characteristic of packages of this southern area. The seismic survey is centred on the Georgina Basin and will tie into the South Nicholson survey – extending knowledge further south across major structures featured in the SEEBASE® model.
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Penner, L. A., and J. D. Mollard. "Correlated Photolineament and Geoscience Data on Eight Petroleum and Potash Study Projects in Southern Saskatchewan." Canadian Journal of Remote Sensing 17, no. 2 (April 1991): 174–84. http://dx.doi.org/10.1080/07038992.1991.10855290.
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Jones, Andrew. "New exploration opportunities in the offshore northern Perth Basin." APPEA Journal 51, no. 1 (2011): 45. http://dx.doi.org/10.1071/aj10003.
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The petroleum prospectivity of the northern Perth Basin has been assessed by Geoscience Australia (GA) as part of the Australian Government’s Offshore Energy Security Program, in support of the 2011 offshore acreage release. This assessment includes the first published synthesis of data from fourteen new field wildcat wells drilled in this part of the basin since the Cliff Head 1 discovery (2001), and the interpretation of new regional 2D seismic data acquired during GA survey 310. Most petroleum accumulations in the northern Perth Basin are associated with Permian and Triassic source and reservoir intervals, and are found onshore and nearshore (ie. Cliff Head, Frankland, Dunsborough and Perseverance discoveries). In addition to the technical and commercial successes, numerous wells in the offshore part of the basin have intersected residual oil columns indicative of trap breach. New and legacy palynological data from Permian to Cretaceous strata in offshore wells have been used to provide age constraints for a sequence stratigraphic framework for this part of the basin. New seismic data show Permo-Triassic strata that are stratigraphic equivalents of the productive onshore and nearshore Perth Basin petroleum system, also occur within Permian half-graben in the outer Abrolhos and Houtman sub-basins. Source rock, oil stain and fluid inclusion sampling from this interval suggest that the proven onshore petroleum system is also effective in the offshore. A refined tectono-stratigraphic model for the offshore basin provides insights into basin evolution, prospectivity and contributing factors driving trap breach. Geochemical sampling in the context of the new detailed sequence framework, including from recently dredged rock samples from incised canyons, has also provided insight into the potential effectiveness of a Jurassic/Cretaceous petroleum system in the Houtman and Zeewyck sub-basins.
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Christiansen, Flemming G. "Colophon, contents and introduction." Geological Survey of Denmark and Greenland (GEUS) Bulletin 15 (July 10, 2008): 1–7. http://dx.doi.org/10.34194/geusb.v15.5030.
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This Review of Survey activities presents a selection of 22 papers reflecting the wide spectrum of activities of the Geological Survey of Denmark and Greenland, from the microscopic to the plate-tectonic level.The Survey's activities in Denmark are illustrated by 13 articles. Five of them deal with petroleum-related topics and two others with groundwater-related topics. Four others describe raw material activities and environmental change, one paper presents a new Base Quaternary map of Denmark and one paper describes the deep structure below Denmark.Activities in Greenland are covered by five papers. Three of these address mineral and petroleum exploration, one concerns monitoring of the Greenland ice sheet and one focuses on historic investigations of Hans Ø, a small island in Nares Strait between Greenland and Canada.International projects and two new geoscientific methods: The survey also carries out many projects outside Denmark, Greenland and the Faroe Islands. This bulletin includes descriptions of a coastal protection project in Kenya and a multinational project dealing with the implementation of the European Union's Water Framework Directive. Finally, two examples of new developments in instrumental geoscience are presented.
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Bradshaw, Marita, Chris Boreham, Lidena Carr, John Laurie, Lisa Hall, Dianne Edwards, Tegan Smith, and Andrew Stacey. "Unconventional hydrocarbons: Australia's old rocks prove their worth." APPEA Journal 53, no. 2 (2013): 472. http://dx.doi.org/10.1071/aj12083.
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Australia’s search for petroleum began in the onshore basins where extensive areas of Paleozoic marine sequences, with some high-quality source rock intervals and spectacular outcrop, encouraged sporadic exploration for many decades. For these efforts, there were some rewards, including the discovery of the Mereenie oil field in Ordovician rocks, the Amadeus Basin in 1960s, and the Blina discovery in Devonian carbonates in the Canning Basin during the early 1980s. Since the late 1980s, however, the focus of exploration has shifted offshore where more and larger discoveries were made in the Mesozoic marginal basins, which today contain about 90% or more of Australia’s conventional oil and gas. Now, however, the focus has shifted back to the onshore, recognising the potential for shale and tight gas and oil in these older rocks. The onshore basin area under exploration license has nearly doubled from 2010–12; several major international companies have joined local explorers in testing the worth of Australia’s lower Paleozoic and Proterozoic petroleum systems, and new discoveries have been made in several basins. Geoscience Australia and its partners in the state and NT surveys are undertaking new assessments and studies across a number of these basins.
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Bernecker, Thomas, Dianne Edwards, Tehani Kuske, Bridgette Lewis, and Tegan Smith. "Prospectivity of the 2014 offshore acreage release areas for petroleum exploration." APPEA Journal 54, no. 1 (2014): 383. http://dx.doi.org/10.1071/aj13040.
Full textAbstract:
The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. Industry nominations provided guidance for the selection of gazettal areas, and in 2014 all 30 areas are supported by such nominations. The release areas are located across various offshore hydrocarbon provinces ranging from mature basins with ongoing oil and gas production to exploration frontiers. Work program bids are invited for two rounds closing on 2 October 2014 and 2 April 2015, while the closing date for four cash bid areas is 5 February 2015. Twenty-nine of the 2014 Release Areas are located along Australia’s northern margin within the Westralian Superbasin, which encompasses the rift-basins that extend from the Northern Carnarvon Basin to the Bonaparte Basin. Evolution during Gondwana break-up established a series of petroleum systems, many of which have been successfully explored, while others remain untapped. Only one area was nominated and approved for release on Australia’s southern margin. The 220 graticular blocks cover almost the entire Eyre Sub-basin of the Bight Basin. In the context of the recent commencement of large-scale exploration programs in the Ceduna and Duntroon sub-basins, this release area provides additional opportunities to explore an offshore frontier. Geoscience Australia’s new long-term petroleum program supports industry activities by engaging in petroleum geological studies that are aimed at the establishment of margin to basin-scale structural frameworks and comprehensive assessments of Australian source rocks underpinning all hydrocarbon prospectivity studies.