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1
Dong, Zhenzhen, Stephen Holditch, Duane McVay, and Walter B. Ayers. "Global Unconventional Gas Resource Assessment." SPE Economics & Management 4, no. 04 (October 1, 2012): 222–34. http://dx.doi.org/10.2118/148365-pa.
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Liu, De Xun, Hong Yan Wang, Qun Zhao, and De Lai Liu. "Unconventional Gas Resource and Developing Technology in China." Advanced Materials Research 807-809 (September 2013): 2115–19. http://dx.doi.org/10.4028/www.scientific.net/amr.807-809.2115.
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Many countries in the world begin to attach great importance to the utilization of the unconventional gas. The unconventional gas resources are very abundant in China. The development of Unconventional Gas is still in the early stage. Tight gas enters large scale and commercializing stage. Coalbed methane (CBM) is in the initial stage of commercialization, and shale gas is in the stage of resource evaluation and technology study. There are mainly three challenges need to confront, uncertainties of unconventional gas resources, key technology with low cost and environmental pollution. So in the future, resource evaluation, engineering technologies and environmental technologies in China need to be strengthened.
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Cockerill, Ian, Joe Collins, and Zain Rasheed. "East coast gas: resource potential at different gas price scenarios (Part 1: quantification of unconventional gas resource potential)." APPEA Journal 59, no. 2 (2019): 860. http://dx.doi.org/10.1071/aj18060.
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A qualitative ranking of the remaining gas potential of Australian east coast basins was undertaken using a spatial analysis methodology of play fairway sweet-spot mapping. Play components considered important for the presence and recovery of unconventional gas were mapped across the plays of interest in Australian east coast basins. Modelled horizontal well type curves and development plans from North American analogues for unconventional gas production were used to quantify the sweet-spot mapping using a methodology we developed called common recovery segment mapping. A range of potential resource numbers were calculated for each play, leading to a quantification of the potential resource across the entire area of interest. Part 2 of this paper will show how these undeveloped unconventional gas resources may ultimately contribute to the east coast Australia energy mix.
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Collins, Joe, Ian Cockerill, and Zain Rasheed. "East coast gas: resource potential at different gas price scenarios (Part 2: commercialisation of unconventional gas resources)." APPEA Journal 59, no. 2 (2019): 542. http://dx.doi.org/10.1071/aj18199.
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Rising gas prices in the eastern Australian gas market, as well as forecast supply shortages in years to come, are driving speculation about LNG import requirements for the market. There are significant similarities with the gas market experience in the USA in the early 2000s which led to the construction of many LNG import terminals, the parallel rise of unconventional gas production and the subsequent mothballing of the LNG import facilities at huge economic cost. A comprehensive east coast gas market study has been carried out based on the 2P reserves positions for domestic gas producers. This data has been paired with a range of gas demand forecasts to identify the probable supply gap on the east coast over the next 10 years. A market response to the high gas pricing in the form of new developments is already underway. In a separate paper (Part 1) all potential domestic sources of unconventional gas to fill that gap were analysed to determine likely gas supply rates, development schedules and breakeven supply costs for each of the major demand centres. This paper (Part 2) illustrates the required gas prices to drive unconventional gas development in Australia, the subsequent scale of new unconventional gas supplies to the forecast gaps in the market and describes how those developments can reverse the trend of rising prices over time.
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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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Liu, De Xun, Hong Yan Wang, Qun Zhao, Ying Liu, and Lei Dong. "Unconventional Gas Development and Prospect in China." Applied Mechanics and Materials 675-677 (October 2014): 1546–50. http://dx.doi.org/10.4028/www.scientific.net/amm.675-677.1546.
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Many countries in the world begin to attach great importance to the utilization of the unconventional gas. The resources of unconventional gas in China are abundant. The development of unconventional gas is still in the early stage. Tight gas enters large scale and commercializing stage. Shale gas is in the initial stage of commercialization. There are mainly three challenges need to confront, uncertainties of unconventional gas resources, key technology with low cost and environmental pollution. So in the future, resource evaluation, engineering technologies and environmental technologies need to be strengthened in China. Tight gas is the most realistic resources to develop in China and the development and utilization of shale gas is the most anticipated. In the next ten or twenty years, the production of unconventional gas in China will increase considerably and play a major role in national hydrocarbon resources.
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Medvedeva, O. E., and S. V. Makar. "PERSPECTIVE OF DEVELOPMENT OF UNCONVENTIONAL GAS RESOURCES IN THE WORLD AND IN RUSSIA." Scientific bulletin of the Southern Institute of Management, no. 1 (March 30, 2018): 49–51. http://dx.doi.org/10.31775/2305-3100-2018-1-49-51.
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The article deals with legal and economic issues of development of unconventional and hard-to-recover gas resources of Russia in comparison with other countries of the world. The emphasis is made on this type of resource due to its growing environmental relevance and technological capabilities. The following categories of this type of resource (hard-to-recover gas resources) are considered: shale gas, coal bed methane, gas hydrates. The Russian modern experience of their involvement in the economy is evaluated. The most perspective country regions in terms of reserves and their exploration are highlighted. Today development of unconventional gas resources is one of strategic objectives ofperspective national and regional sustainable resource supply. The transition moment from traditional resources to «unconventional» is determined not only by the comparability of the costs of their involvement in the economy, but also by the environmental needs of the world, national and regional level.
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Liu, Ded Xun Liu, Hong Yan Wang, Qun Zhao, and Hong Lin Liu. "Development Trend of Unconventional Gas Resources in China." Advanced Materials Research 616-618 (December 2012): 250–56. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.250.
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Many countries in the world begin to attach great importance to the utilization of the unconventional gas. In some areas, tight gas, Coalbed methane (CBM) and shale gas have came into commercial development. The unconventional gas resources are very abundant in China. They developed rapidly in recent years, and some progress has been made. CBM in Qinshui Basin has been commercially developed successfully. Shale gas resource is also very abundant and has a good development prospect. Besides, the gas hydrate has a great potential in resources.
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MATSUMOTO, Ryo. "Methane Hydrate as an Unconventional Natural Gas Resource." Shigen-to-Sozai 108, no. 7 (1992): 511–20. http://dx.doi.org/10.2473/shigentosozai.108.511.
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Hui, Guan Zhou. "The Research of Reservoir Forming Characteristics of Tight Sand Gas." Advanced Materials Research 998-999 (July 2014): 1483–86. http://dx.doi.org/10.4028/www.scientific.net/amr.998-999.1483.
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Tight sand gas is one of unconventional gas. Under the condition of the gradual depletion of conventional resources, unconventional resource is gradually paid more attention. Tight sand gas is divided into two types: pre-exiting deep gas and subsequent tight sand gas on the foundation of current research. Different types of accumulations having various characteristics, so describing and contrasting reservoir forming characteristics of two types of tight sand gas, analyze reservoir forming rules, can guide the future work of tight sand gas exploration.
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Gautier, Donald, and Peter McCabe. "Probabilistic resource/cost appraisals for evaluation of petroleum resources." APPEA Journal 55, no. 2 (2015): 451. http://dx.doi.org/10.1071/aj14086.
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In the increasingly open global marketplace, unconventional resources such as coal seam methane, shale gas and shale oil are now the marginal (highest cost) sources of supply in some regions and are seen as potential important components of energy policy for many nations, including Australia. Large in-place hydrocarbon volumes, low-recovery efficiency, and slim profit margins characterise the development of most of these resources around the world. Although they contribute a relatively small percentage of global petroleum production, they greatly influence world commodity prices and pose challenges to developers, investors and policy makers. Traditional assessments of in-place or technically recoverable hydrocarbon volumes alone are inadequate for evaluating the economic viability of these unconventional resources. By integrating probabilistic geology-based assessments with estimates of undiscounted life-cycle capital and operating expenditures, however, single parameter resource assessments become two-parameter resource cost appraisals, which can be used to: benchmark alternative oil or gas technologies; quantify the effects of technological change on high-cost developments; and, compare alternative resource development opportunities. The integration of geological and technological information thus provides an important tool for the effective evaluation of potential projects and for setting energy policy.
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Crisp, Gary, John Walsh, Mark Shaw, and Chris Hertle. "The role of water management in unlocking unconventional resources." APPEA Journal 54, no. 2 (2014): 481. http://dx.doi.org/10.1071/aj13054.
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Water management for unconventional resources is a complex, multidisciplinary subject that cannot be overlooked. Traditional oilfield development strategies view water as an afterthought that must be dealt with once the field matures and water cut begins to escalate. When this strategy is employed for shale gas developments, water usage is higher than necessary, trucking costs become high, and site remediation becomes time consuming and costly. For shale gas developments, the high-volume and high-quality requirements of water during the lifecycle of field development are a game changer. Water management for unconventional resources requires logistics planning, engagement of field services providers, and technology selection. Each of these issues need to be addressed in the early planning stages and must be tailored for the location and water types involved. This extended abstract takes a holistic view of water management for unconventional resource development across Australia. Management strategies are compared and contrasted for the different unconventional resource types, across different locations, considering all of the factors mentioned above, together with an understanding of regulatory differences, water source options, disposal options, and the different types of water involved. These factors are compared (in the context of North American developments) for CSG in Queensland, tight gas, and unconventional shale gas developments in the Cooper Basin and WA. As these different resources are developed, it is important to understand why the water management strategies are, and must be, different (as discussed in this extended abstract).
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McMahon, Craig. "Unconventional gas: local supply, global implications." APPEA Journal 51, no. 2 (2011): 679. http://dx.doi.org/10.1071/aj10059.
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The sharp growth in unconventional gas production in North America has turned the gas market on its head. Unconventional gas (coal bed methane, tight gas and shale gas) is present in large volumes throughout the world—it offers the potential to continue to reshape global gas dynamics. Many expect the North America experience of sharp unconventional gas growth to be repeated elsewhere and are forecasting the perpetuation of a global gas surplus. Is this likely? We consider the impact of its development, identify some of the issues that will constrain its growth and address some of the implications for upstream suppliers, resource holders, buyers and policy makers. No post-Conference paper or slides are available for this presentation.
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Johnson, R. L., Jr, C. W. Hopkins, and M. D. Zuber. "TECHNICAL CHALLENGES IN THE DEVELOPMENT OF UNCONVENTIONAL GAS RESOURCES IN AUSTRALIA." APPEA Journal 40, no. 1 (2000): 450. http://dx.doi.org/10.1071/aj99026.
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Unconventional gas resources, defined as low- permeability sandstone, coal seam and naturally- fractured shale gas reservoirs, represent a huge potential resource for future natural gas supply in Australia and around the world. Because low individual well-production rates are often the norm, unconventional reservoir development may involve the drilling of hundreds of wells to make the economics attractive. Thus, careful planning, sound development strategies and cost control are critical for project success.Virtually all unconventional gas resources must be stimulated to be economic; stimulation costs are often the most significant amount of the total well expenditure. Thus, a cost-effective method for reservoir characterisation and fracture treatment optimisation is required. Because of marginal economics, techniques used to analyse the process and results are often oversimplified; this can lead to confusing or inadequate descriptions of the complex behavior of a hydraulically-fractured, low- permeability reservoir and in some cases bad development decisions. Detailed data collection programs and fracture treatment optimisation strategies are essential to adequately address the technical issues involved in unconventional reservoir development.Besides the technical challenges associated with unconventional gas development, good forethought is necessary as to the planning and execution of the overall project. The development scenarios for coal seam and low-permeability sandstone gas resources are highly statistical and succeed or fail based on the average performance of the group of wells within the project. Following proven guidelines and methods during development while integrating key technologies into the planning and optimisation process are essential for success in unconventional reservoir development.
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Peacock, Douglas. "Unconventional reserves and resources in the Petroleum Resource Management System (PRMS): a square peg in a round hole?" APPEA Journal 54, no. 2 (2014): 518. http://dx.doi.org/10.1071/aj13091.
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Estimation and reporting of unconventional hydrocarbon reserves and resources have been a subject of intense focus in recent years. As unconventional hydrocarbons become increasingly important, it is essential that practices keep pace with a rapidly changing industry. The PRMS was primarily developed for conventional hydrocarbons although it is applicable to all accumulations, including unconventional. Force-fitting the PRMS for use in unconventional reservoirs is problematic. Many key areas would benefit from better definition and guidance. These areas include: assessment and reporting of prospective resources, definition of a prospect, risk assessment, definition of a discovery, extent of discovery, and linkage of reserves to the definition of project. Unconventional gas developments for LNG export present particular challenges. One primary purpose of reserves and resources definitions is to provide consistency of terminology and reporting for all parties involved including operators, investors, governments, and regulatory bodies. Within the industry, there is widespread acceptance that unconventional hydrocarbons are different, not only in how they are developed but also in how reserves and resources are evaluated and reported. Present practices may not fit neatly into the PRMS requirements, so compromises must be made. In particular, the PRMS axes of risk and uncertainty become blurred with present unconventional practices. This extended abstract highlights the many issues that make estimation and reporting of unconventional resources problematic within the PRMS and it suggests possible solutions to enable a more appropriate set of definitions and guidelines to be prepared.
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Chew, Kenneth J. "The future of oil: unconventional fossil fuels." Philosophical Transactions of the Royal Society A: Mathematical, Physical and Engineering Sciences 372, no. 2006 (January 13, 2014): 20120324. http://dx.doi.org/10.1098/rsta.2012.0324.
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Unconventional fossil hydrocarbons fall into two categories: resource plays and conversion-sourced hydrocarbons. Resource plays involve the production of accumulations of solid, liquid or gaseous hydro-carbons that have been generated over geological time from organic matter in source rocks. The character of these hydrocarbons may have been modified subsequently, especially in the case of solids and extra-heavy liquids. These unconventional hydrocarbons therefore comprise accumulations of hydrocarbons that are trapped in an unconventional manner and/or whose economic exploitation requires complex and technically advanced production methods. This review focuses primarily on unconventional liquid hydro-carbons. The future potential of unconventional gas, especially shale gas, is also discussed, as it is revolutionizing the energy outlook in North America and elsewhere.
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Krasnova, Elizaveta A., Antonina V. Stoupakova, Aleksander N. Stafeev, Anna A. Suslova, Roman S. Sautkin, Mikhail E. Voronin, Petr B. Stepanov, Andrey A. Knipper, and Yana A. Shitova. "Geological structure and paleogeographic zoning of the Khadum formation in Pre‑Caucasus." Georesursy 23, no. 2 (May 25, 2021): 99–109. http://dx.doi.org/10.18599/grs.2021.2.9.
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Unconventional oil and gas resource development and exploration is the one of the most prospective concept in petroleum geology. High carbon Khadum facies are investigated as unconventional resources in the Precaucas basin and contain gas, gas condensate and oil accumulations. Oligocene and Lower Miocene structure, prospectivity and fields distribution are the one of the most relevant subjects nowadays. This study is focused on the main stages Late Eocene and Early Oligocene deposits formation and the paleogeography of the Khadum formation in the Precaucas oil and gas basin. The new prospective zones are developed in Khadum formation based on the complex analysis of seismic, paleogeography and lithofacies analysis.
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Holditch, Stephen A. "Unconventional oil and gas resource development – Let’s do it right." Journal of Unconventional Oil and Gas Resources 1-2 (June 2013): 2–8. http://dx.doi.org/10.1016/j.juogr.2013.05.001.
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McGlade, Christophe, Jamie Speirs, and Steve Sorrell. "Unconventional gas – A review of regional and global resource estimates." Energy 55 (June 2013): 571–84. http://dx.doi.org/10.1016/j.energy.2013.01.048.
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Grimes, Carrie, Geoffrey Cann, and Christopher Margarido. "One well, 30,000 times: Australia's workforce transition to a gas factory." APPEA Journal 55, no. 2 (2015): 486. http://dx.doi.org/10.1071/aj14121.
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Australia’s oil and gas resources are becoming more unconventional, and the workforce management approaches to exploit these resources must also become more unconventional. The shift from conventional to unconventional resource plays, beginning with coal seam gas and now including shale resources, has had a major impact on every aspect of the upstream process. This entails the delivery of upstream gas capacity and on-going gas delivery for thousands of wells across several years, which is much more like a manufacturing process rather than one-off projects—compared to conventional gas where only a few wells are drilled per year. Perfecting the gas factory concept is still in its early days in Australia, with more focus remaining on the work than the workforce. As equipment and infrastructure support the work to be delivered, culture and workforce structures (organisational structures, performance plans and people strategies, etc) support the workforce that will execute the work. The ability to establish a factory-like culture will drive a workforce with a manufacturing mindset and if supported by the right workforce structures will encourage behaviour needed to be successful in the manufacturing environment. The companies and suppliers that are able to reinvent themselves as manufacturers, both in what they do and how they think, will realise the highest returns. This extended abstract explores the changes needed in workforce structures through examples in oil and gas (shale developments and coal bed methane, etc), manufacturing drawing lessons and insights for Australia’s growing unconventional oil and gas sectors.
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Sivapalan, Mayuran. "US experiences in sustainable development of unconventional resources, appraisal phase approaches for addressing non-technical development risks." APPEA Journal 54, no. 2 (2014): 485. http://dx.doi.org/10.1071/aj13058.
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The global development of unconventional gas resources is progressing at a remarkable pace, owing to technology advancements, supportive regulatory environments, and expectations of favourable long-term market conditions. In Australia, the sheer scale of the resource potential, the increase in political and public will towards CO2 emissions reduction, and an immediate desire for greater local economic production suggests that exploration and production activity is likely to accelerate in the coming years. The unconventional gas sector, however, has been affected by negative publicity, with attention drawn to the potential environmental impacts and public burden associated with development practices—especially hydraulic fracturing. Stakeholder concerns regarding the significant water requirements, emissions footprint, and infrastructure impacts across the development lifecycle represent significant challenges. This extended abstract focuses on the use of structured decision-making approaches used in the appraisal phase of unconventional gas developments in the US to identify and manage the technical and especially non-technical risks that impact a development’s cost, schedule, and profitability across its lifecycle. An unconventional gas development from the US is presented, where a framework for integrating commercial, public, and environmental concerns from corporate and external stakeholders into field concept development and selection has been successfully applied. The development, which faces resource and regulatory challenges related to water management, air emissions, and local infrastructure impacts, employed fit-for-purpose decision-making tools that quantified non-technical development risks to inform the evaluation and selection of concepts that best met economic, corporate, and stakeholder expectations.
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Greenstreet, Carl. "From play to production: the Cooper unconventional story—20 years in the making." APPEA Journal 55, no. 2 (2015): 407. http://dx.doi.org/10.1071/aj14042.
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The Cooper Basin is Australia’s leading onshore producing hydrocarbon province, having produced more than 6 Tcf of natural gas since 1969. The basin is undergoing renewal 45 years later, driven by the emerging growth of east coast LNG export-driven demand. Following North America’s shale gas revolution, the Cooper Basin’s unconventional potential is now widely appreciated and it is believed to hold more than 100 Tcf of recoverable gas. This resource potential is held in four stacked target unconventional lithotypes, each having demonstrated gas flows: tight sands—heterogeneous stacked fluvial sands; deep coal—porous dry coals, oversaturated with gas; shales—thick, regionally extensive lacustrine shales; and, hybrid shales—mixed lithotype containing interbedded tight sandstones, shales and coals. Industry activity initially focused on the Nappamerri Trough, where more than 25 contemporary exploration wells have been drilled, proving up an extensive basin-centred gas play with >1,000 m of continuous overpressured gas saturated section outside of structural closure. Santos has had a team focused on unconventional resources for nearly 20 years and successful results have been quickly tied into the producing infrastructure. This has been demonstrated with the Moomba–191 REM shale success, Moomba–194 and the recent Moomba–193H connection, one of the basin’s first fracture-stimulated horizontal wells. Prospective geology, existing infrastructure and market access makes the Cooper Basin well positioned for unconventional success. Each resource play is unique and commercial success requires considered adaptation of established technologies and workflows, based on a understanding of local geological and reservoir conditions. Commercialisation activity now seeks to define play fairways, characterise and prioritise reservoir targets and determine appropriate drilling and completion approaches.
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Pang, Xiong-Qi, Zhuo-Heng Chen, Cheng-Zao Jia, En-Ze Wang, He-Sheng Shi, Zhuo-Ya Wu, Tao Hu, et al. "Evaluation and re-understanding of the global natural gas hydrate resources." Petroleum Science 18, no. 2 (March 26, 2021): 323–38. http://dx.doi.org/10.1007/s12182-021-00568-9.
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AbstractNatural gas hydrate (NGH) has been widely considered as an alternative to conventional oil and gas resources in the future energy resource supply since Trofimuk’s first resource assessment in 1973. At least 29 global estimates have been published from various studies so far, among which 24 estimates are greater than the total conventional gas resources. If drawn in chronological order, the 29 historical resource estimates show a clear downward trend, reflecting the changes in our perception with respect to its resource potential with increasing our knowledge on the NGH with time. A time series of the 29 estimates was used to establish a statistical model for predict the future trend. The model produces an expected resource value of 41.46 × 1012 m3 at the year of 2050. The statistical trend projected future gas hydrate resource is only about 10% of total natural gas resource in conventional reservoir, consistent with estimates of global technically recoverable resources (TRR) in gas hydrate from Monte Carlo technique based on volumetric and material balance approaches. Considering the technical challenges and high cost in commercial production and the lack of competitive advantages compared with rapid growing unconventional and renewable resources, only those on the very top of the gas hydrate resource pyramid will be added to future energy supply. It is unlikely that the NGH will be the major energy source in the future.
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Cook, P. G., A. Miller, M. Shanafield, and C. T. Simmons. "Predicting Water Resource Impacts of Unconventional Gas Using Simple Analytical Equations." Groundwater 55, no. 3 (December 12, 2016): 387–98. http://dx.doi.org/10.1111/gwat.12489.
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Komarek, Timothy M. "Crime and natural resource booms: evidence from unconventional natural gas production." Annals of Regional Science 61, no. 1 (January 25, 2018): 113–37. http://dx.doi.org/10.1007/s00168-018-0861-x.
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Brantley, Susan L., Dave Yoxtheimer, Sina Arjmand, Paul Grieve, Radisav Vidic, Jon Pollak, Garth T. Llewellyn, Jorge Abad, and Cesar Simon. "Water resource impacts during unconventional shale gas development: The Pennsylvania experience." International Journal of Coal Geology 126 (June 2014): 140–56. http://dx.doi.org/10.1016/j.coal.2013.12.017.
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Bista, Sangita, Philip Jennings, and Martin Anda. "Carbon footprint management of unconventional natural gas development in the export scenario." Renewable Energy and Environmental Sustainability 4 (2019): 3. http://dx.doi.org/10.1051/rees/2018008.
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In Australia, exploitation of shale gas is at an early stage. Western Australia has estimated its technically recoverable gas resources at 235 trillion cubic feet (tcf). It is viewed as an exciting economic prospect and decarbonising option for transition to climate change mitigation. The central focus of this paper is to estimate the climate impacts of Australian shale gas fracking and compare with other energy sources. Electricity generation has been considered as end use of gas in export scenarios to Japan and China. Analysis has been done for resource development periods of 20 and 40 years. Carbon footprints of shale gas range from 604MtCO2e to 543 MtCO2e per annum for China and Japan export cases, respectively, for 20 years field lifetime, if 66 tcf of shale gas is exploited and used. This result is roughly equivalent to 115% of Australia's total national emissions for the year 2014. If all technically recoverable shale gas (235tcf) from the Canning Basin in the Kimberley is exploited and exported to China and Japan over 40 years, the annual emissions are double the total Australian national emissions. The result suggests that shale gas has low carbon intensity compared to coal and oil but solar PV and wind are much cleaner energy options for GHG mitigation. The solar PV and wind electricity would produce 8% and 5% of the shale gas electricity emissions, respectively. Unless accompanied by stringent regulation and compliance on the upstream resource development, stage shale gas cannot be an appropriate energy source for sustainable development as opposed to renewable energy sources.
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McMillan, Don. "Gauging the confidence in publicly reported oil and gas reserves: introducing the Reserves Confidence Metric (RCM)." APPEA Journal 57, no. 1 (2017): 88. http://dx.doi.org/10.1071/aj16050.
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Confidence in publicly disclosed reserves and resources is critical to the investment community and the reputation of the oil and gas industry. This paper introduces a commonly utilised industry concept for reviewing reserve estimates in a format that non-professionals can use with confidence. Surveys (McMillan 2014) have indicated a perception that the Society of Petroleum Engineers – Petroleum Resources Management System (SPE-PRMS) lacks consistency and repeatability and treats conventional and unconventional resources differently. This is discussed in detail in this paper, along with an explanation of the confusion caused by these differences. The oil and gas industry is still endeavouring to understand how to treat unconventional resource estimations and this paper endeavours to capture areas of contention and risks in relation to reported reserves. Reserves Confidence Metric (RCM) is presented as a method for rating confidence in publicly disclosed reserves. RCM, which is derived from the reserves to production ratio, can be used for any reserves standard or guideline. It is a simple metric, which any organisation or individual with limited knowledge of reserves can apply to identify reserves that require further information or should be used with caution. As an example, RCM is applied to Queensland’s publicly disclosed 2P reserves for all conventional and unconventional Coal Seam Gas (CSG) resources.
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Birky, Alicia K., John D. Maples, James S. Moore, and Philip D. Patterson. "Future World Oil Prices and the Potential for New Transportation Fuels." Transportation Research Record: Journal of the Transportation Research Board 1738, no. 1 (January 2000): 94–99. http://dx.doi.org/10.3141/1738-11.
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World petroleum demand is projected to continue increasing after the world enters the 21st century. The Energy Information Administration (EIA) forecasts low world oil prices for the indefinite future despite an expected 54 percent rise in consumption by the year 2020. In its reference case, EIA also assumes an 80 percent increase in Organization of the Petroleum Exporting Countries (OPEC) oil production over the same time period. In contrast to this, a popular world oil market projection model demonstrates that OPEC could increase its production profitability significantly by substantially slowing the rate of its expanded production. However, OPEC’s potential market control also is influenced by the prospective availability of fuels produced from natural gas, especially remote unconventional natural gas resources. The unconventional natural gas resource is potentially enormous compared with all other fossil fuels combined. Considerations of energy security, greenhouse gas curtailment, emissions control, and cost will act to dictate widespread production and use of these unconventional reserves. Estimates are provided for the amount of alternatives that might be available at various oil prices. Because of cost considerations, much of this added production is likely to occur outside the United States.
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Shanafield, Margaret, Peter G. Cook, and Craig T. Simmons. "Towards Quantifying the Likelihood of Water Resource Impacts from Unconventional Gas Development." Groundwater 57, no. 4 (September 25, 2018): 547–61. http://dx.doi.org/10.1111/gwat.12825.
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Sidiq, Hiwa, Eli Silalahi, Grant Skinner, and Perdana Noverda Pamurty. "The role of reservoir modelling in unlocking unconventional (resource) plays." APPEA Journal 53, no. 2 (2013): 440. http://dx.doi.org/10.1071/aj12051.
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There has been a recent focus on the insight that reservoir modelling provides into devising the best workflows and its ability to include reservoir attributes that affect recovery factors in shale. This extended abstract examines recent technical developments in reservoir modelling and how such modelling can identify sweet spots in shale reservoirs. An accurate characterisation of a pre-existing fracture network and its structural complexities, however, requires the gathering of a large amount of data. In addition, investigating sweet spots at the presently low gas prices sometimes prevents the acquisition of such data that is essential as an input to drilling strategies, fracture program design, well spacing, and understanding stimulated reservoir volumes (SRV) in shale. The pre-existing fractures may also have a limited impact on recovery rates. The transport along a wellbore is mainly controlled by the drained volume, not only by the fractures around the well. In such cases, the pre-existing fractures and their reactivation during the fracturing stage are not sufficient to determine the amount of gas that can be recovered during production. This volume is effectively not only a function of the fracture density, but also of the propped fractures. The challenge, therefore, becomes the ability to have a good estimation of the size of the SRV and be able to calibrate this volume using relevant data such as micro-seismic data and the recovery from previous fraccing stages. This extended abstract also discusses how reservoir modelling can play a key role in this area.
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Piragine, Milagros Arengo, Satya Shah, and Alec Coutroubis. "Study of Potentials and Challenges in Unconventional Oil and Gas Industry: An Argentinian Case Study." MATEC Web of Conferences 210 (2018): 02007. http://dx.doi.org/10.1051/matecconf/201821002007.
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The aim of this paper is to analyse literature studies towards the potential of Vaca Muerta Field in the Neuquén Basin, its current development situation and the country’s and Oil & Gas Industry background. Argentina is the second largest country in South America, which highly depends on its service and agricultural industries, been one of the major exporters of beef and soybean products. Strongly dependent on hydrocarbons, which account for 86.1% of its energy consumption, the country lost energy self-sufficiency in 2007, when it became a net importer of oil and gas. Concerns around the world about future shortages of energy were partially alleviated by the developments of commercially feasible techniques to extract oil and gas from unconventional resources, which are hard to extract due to the low porosity of the generating rock. Argentina turned to be the third and fourth larger holder of technically recoverable unconventional gas and oil respectively, mainly in the Neuquén Basin, were the second largest unconventional formation worldwide is located: Vaca Muerta is considered a world class resource, especially for its size, hydrocarbons content and thickness. It has been developed for seven years, achieving increasing production of oil and gas and improvements regarding costs, time and resources invested. As a conclusion, Argentina has vast and high-quality hydrocarbon reserves, what represents a huge opportunity for the country to recover energy self-sufficiency and its exporter position. New technologies and techniques are improving times and costs involved in the extraction of unconventional hydrocarbons in the country. In addition, the new government is taking action to improve reliability and encourage investments. All these should enhance Vaca Muerta’s development.
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Close, David. "Why the wait? Shale gas exploration review and look ahead." APPEA Journal 55, no. 2 (2015): 404. http://dx.doi.org/10.1071/aj14039.
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Despite unconventional targets being recognised across many Australian sedimentary basins and the Energy Information Administration (EIA), estimating a technically recoverable shale gas resource of >400 tcf in Australia, there have been no definitive tests that prove that any of these potential plays will flow gas at commercial rates. There has, however, been a number of technical successes reported from both shale gas and basin centred gas plays. This extended abstract reviews select plays from both frontier and mature basins across Australia, including basins where Origin is actively exploring or appraising unconventional gas plays—the Perth, Cooper and Beetaloo basins. The technical challenges vary from play to play, but many of the above ground challenges are not play specific. To advance the industry, Origin and other companies will have to demonstrate a resource sufficiency that is economic in a high cost environment like Australia, while maintaining a positive relationship with communities. In its expansion into the NT, through its interest in the Beetaloo Basin, Origin has the benefit of 20 years' experience dealing with complex stakeholders and environmental challenges through its CSG development projects in Queensland. This experience is invaluable in advising best practices for engaging with local communities, landholders, traditional owners, and regulatory and government bodies. For the technically-minded asset development teams charged with exploring unconventional plays in frontier basins, where stakeholders are unfamiliar with oil and gas development projects, new skills are required that need deep organisational support.
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McManus, Andrew. "The outlook for Australia's emerging unconventional plays." APPEA Journal 52, no. 2 (2012): 646. http://dx.doi.org/10.1071/aj11060.
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Australia’s world-class CSG resource has seen the country emerge as a global unconventional gas player. Three LNG plants are being constructed, with more than US$50 billion committed to be spent in the sector before 2020. Australia’s unconventional gas story does not stop there. Operators now have shale and tight gas potential, where exploration is now underway in a number of basins across the country. As with CSG, the initial steps are being taken by the industries’ smaller companies; however, established players like Mitsubishi, Hess, BG and ConocoPhillips have been quick to buy into the opportunity—and at a fraction of the cost of the proven CSG plays. So can shale or tight gas emerge as Australia next major play? This presentation summarises activity levels and discusses which basins present the greatest potential. It also considers the challenges that lie in wait to commercialise new discoveries and the case studies of the US shale and Australian CSG plays to identify key success factors. This short abstract contains only presentation slides.
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Luo, Xiaoqin, Ganlu Wang, Yuliang Mou, Ruiying Liu, Hao Zhou, Hanying Si, and Qinggang Chen. "The Analysis of the Water Resource Carrying Capacity in the Shale and Gas Exploration Area, Southwest China Karst Region ‒ A Case Study from Cenggong County." Open Civil Engineering Journal 11, no. 1 (June 19, 2017): 258–69. http://dx.doi.org/10.2174/1874149501711010258.
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Introduction: As an unconventional natural gas resource, shale gas is the current hot topic in the oil and gas industry. China is rich in shale gas resource, most of which lies in the Southwest Karst Area with its fragile ecological environment. Discussion: The following questions must be studied before exploration thereof: on one hand, shale gas mining requires a lot of water, on the other hand, if the karst region water resources can support shale gas mining over a large area, and if the consequent water/environmental pollution problems will bring more severe challenges to the sustainable development of society and the economy in the southwest karst area, there is a potential conflict requiring a research-based resolution. The water resource carrying capacity is an important measure of the potential sustainable development of a karst region, with its unique geological structure and fragile natural landscape. Therefore, the study of karst water resource carrying capacity is of great significance. Conclusion: This essay is based on Cenggong County, one of the five key shale gas exploration areas in Guizhou at the end of 2012. By calculating the water resource carrying capacity in the studied area with the help of the ecological footprint method, it is concluded that the existing water resources in the studied area can support shale gas exploration. However, shale gas mining will cause a change in the industrial structure within the region. In addition, it has significant effects on the bearing capacity of water resources in the ecological environment.
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Kuczyński, Szymon. "Analysis of Vapour Liquid Equilibria in Unconventional Rich Liquid Gas Condensate Reservoirs." ACTA Universitatis Cibiniensis 65, no. 1 (December 1, 2014): 46–51. http://dx.doi.org/10.1515/aucts-2015-0008.
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Abstract At the beginning of 21st century, natural gas from conventional and unconventional reservoirs has become important fossil energy resource and its role as energy fuel has increased. The exploration of unconventional gas reservoirs has been discussed recently in many conferences and journals. The paper presents considerations which will be used to build the thermodynamic model that will describe the phenomenon of vapour - liquid equilibrium (VLE) in the retrograde condensation in rocks of ultra-low permeability and in the nanopores. The research will be limited to "tight gas" reservoirs (TGR) and "shale gas" reservoirs (SGR). Constructed models will take into account the phenomenon of capillary condensation and adsorption. These studies will be the base for modifications of existing compositional simulators
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Whitford, D. J., and J. Pullar. "AUSTRALIA’S GAS FUTURE—A RESEARCH AND DEVELOPMENT PERSPECTIVE." APPEA Journal 47, no. 1 (2007): 251. http://dx.doi.org/10.1071/aj06016.
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Australia’s large natural gas resource offers the prospect of a secure and competitive supply of transport, domestic and industrial fuels, lower emissions and an opportunity for significant wealth generation. Although the use of gas is growing fast, there remain significant technological hurdles that must be overcome before its full potential is realised. Many of the technical issues have a distinctive Australian dimension that demand local solutions—we cannot necessarily rely on imported technology.In consultation with industry, government and other research and development providers, CSIRO has developed a gas technology roadmap that provides the basis for an integrated research program in support of the Australian gas industry. The roadmap addresses the needs of both the conventional and unconventional gas industries and covers the value chain from exploration, production and processing, to utilisation and end use.In the context of ensuring a reliable and secure supply of competitively priced gas, two research streams have been identified, focussing on accessing remote conventional gas that is economically stranded, and unlocking Australia’s large unconventional gas resources to supply the southeast quadrant. Gas is an intrinsically cleaner fuel than oil or coal in terms of CO2 emissions and specific research opportunities in geosequestration, gas-based alternative fuels and distributed energy have been identified.Gas in the form of LNG is a fast-growing export industry enhancing Australia’s position as a leading energy exporter. There are opportunities for research and development to contribute to LNG, gas-to-liquids (GTL) fuel conversion as well as the greater use of gas for large-scale resource developments. Given the diversity and range of research opportunities, Australia has the potential to become a global leader in gas technologies with the chance to grow knowledge-based exports in addition to the export of rawfuels and embedded-energy products.
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Gerami, Shahab, and Mehran Pooladi-Darvish. "An Early-Time Model for Drawdown Testing of a Hydrate-Capped Gas Reservoir." SPE Reservoir Evaluation & Engineering 12, no. 04 (July 19, 2009): 595–609. http://dx.doi.org/10.2118/108971-pa.
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Summary Development of natural gas hydrates as an energy resource has gained significant interest during the past decade. Hydrate reservoirs may be found in different geologic settings including deep ocean sediments and arctic areas. Some reservoirs include a free-gas zone beneath the hydrate and such a situation is referred to as a hydrate-capped gas reservoir. Gas production from such a reservoir could result in pressure reduction in the hydrate cap and endothermic decomposition of hydrates. Well testing in conventional reservoirs is used for estimation of reservoir and near-wellbore properties. Drawdown testing in a hydrate-capped gas reservoir needs to account for the effect of gas from decomposing hydrates. This paper presents a 2D (r,z) mathematical model for a constant-rate drawdown test performed in a well completed in the free-gas zone of a hydrate-capped gas reservoir during the earlytime production. Using energy and material balance equations, the effect of endothermic hydrate decomposition appears as an increased compressibility in the resulting governing equation. The solution for the dimensionless wellbore pressure is derived using Laplace and finite Fourier cosine transforms. The solution to the analytical model was compared with a numerical hydrate reservoir simulator across some range of hydrate reservoir parameters. The use of this solution for determination of reservoir properties is demonstrated using a synthetic example. Furthermore, the solution may be used to quantify the contribution of hydrate decomposition on production performance. Introduction In recent years, demands for energy have stimulated the development of unconventional gas resources, which are available in enormous quantities around the world. Gas hydrate as an unconventional gas resource may be found in two geologic settings (Sloan 1991):on land in permafrost regions, andin the ocean sediments of continental margins. During the last decade, extensive efforts consisting of detection of the hydrate-bearing areas, drilling, logging, coring of the intervals, production pilot-testing, and mathematical modeling of hydrate reservoirs have been pursued to evaluate the potential of gas production from these gas-hydrate resources.
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Castro, Carlos, Francesca Verga, and Dario Viberti. "Global Energy Demand and Its Geopolitical and Socioeconomic Implications: Which Role Would Shale Resources Have?" Open Petroleum Engineering Journal 9, no. 1 (June 30, 2016): 47–54. http://dx.doi.org/10.2174/1874834101609010047.
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This paper discusses the geopolitical and socioeconomic implications the development of shale gas (& oil) has had in the US. The approach has been that of placing shale gas under erasure (or sous rature). In other words, the assumption that shale is currently both present/absent was made to answer the question of whether it can actually be considered as a resource. Moreover, the success of the “shale revolution” in the US has not only had an impact on the International Oil & Gas, Petrochemical, natural resource and renewable markets, but it has also triggered certain geopolitical events which are modifying the role played by nations globally. Finally, it is suggested that under the prevailing circumstances these unconventional resources appear to still be more of a challenge than part of the solution to the ever growing energy demand, and production of goods associated with societal needs/aspirations worldwide.
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Squire, Warwick, and Julie-Anne Braithwaite. "Ahead of the game: working with local communities in frontier resource basins." APPEA Journal 59, no. 2 (2019): 728. http://dx.doi.org/10.1071/aj18097.
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From frontier gas basins in North West Queensland to potential unconventional gas reserves in the far south-west, several areas in Queensland have potential for new or expanded resource activity over the coming decade. Lessons of the past have highlighted the importance of early engagement, by industry and government, in building and maintaining constructive relationships with local communities and achieving successful coexistence. The way in which local communities are introduced to new resource activity, and their first impressions, contribute to future attitudes and expectations. In some cases, the Department of Natural Resources, Mines and Energy (DNRME) is taking a lead on early activities to facilitate resource exploration and development, such as pre-competitive exploration and release of tender areas for potential exploration. DNRME’s approach for engaging with resource communities involves developing robust relationships with local stakeholders, namely local government, landholders, Traditional Owners and local organisations, and a deep understanding of their interests and the local context. Second, it focuses on providing information to local communities about resource activity and ensuring that they have a channel for raising questions and concerns.
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Singleton, Scott. "Introduction to this special section: Unconventional case studies." Leading Edge 38, no. 2 (February 2019): 92–95. http://dx.doi.org/10.1190/tle38020092.1.
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The technology behind unconventional resource assessment and extraction has morphed considerably in the past few years, likely exacerbated by the extreme downturn in the oil and gas industry and everyone's fight for survival. Those of us who were around during the downturn in the 1980s remember a similar sense of desperation that led to the widespread use of 3D data, along with the commensurate advancement of processing techniques that could handle massive amounts of data as well as the evolution of 3D visualization and interpretation.
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Davies, Richard J., Sam Almond, Robert S. Ward, Robert B. Jackson, Charlotte Adams, Fred Worrall, Liam G. Herringshaw, Jon G. Gluyas, and Mark A. Whitehead. "Oil and gas wells and their integrity: Implications for shale and unconventional resource exploitation." Marine and Petroleum Geology 56 (September 2014): 239–54. http://dx.doi.org/10.1016/j.marpetgeo.2014.03.001.
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Huddlestone-Holmes, Cameron R., Kate Holland, and Luk J. M. Peeters. "Geological and Bioregional Assessments: a tale of two basins." APPEA Journal 61, no. 2 (2021): 491. http://dx.doi.org/10.1071/aj20036.
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The Australian Government’s $35.4 million Geological and Bioregional Assessment (GBA) Program is assessing the potential impacts of shale, tight and deep coal gas development on water and the environment in the Beetaloo, Isa and Cooper GBA regions. This paper compares the outcomes of impact assessments for the Beetaloo and Cooper GBA regions, highlighting the role that local geology, hydrogeology, ecology and regulatory regimes play when assessing potential impacts of unconventional gas development. Unconventional gas development activities between basins are broadly consistent, involving drilling, stimulation of the reservoir (typically through hydraulic fracturing), production and processing of hydrocarbons, export to market and decommissioning and rehabilitation. The characteristics of these activities and their potential impacts are strongly influenced by local factors including the geology, environment, industry practices and regulatory regimes. While subsurface impacts associated with hydraulic fracturing and well integrity are considered unlikely in both regions, regional geology means there is greater stratigraphic separation between target resources and overlying aquifers in the Beetaloo Sub-basin than in the Cooper Basin. Local ecological conditions and species influence the nature of potential impacts on protected matters in the two basins, which are mostly associated with surface disturbance and spills or accidental release of fluids. A key similarity between the two regions is the broadly consistent regulation and management of potential impacts in the two basins. Preliminary results of the causal network analysis indicate that mitigation measures are available for all pathways in which unconventional gas resource development activities may have the potential to impact on endpoints.
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Guo, Jigang, Xiongqi Pang, Fengtao Guo, Xulong Wang, Caifu Xiang, Fujie Jiang, Pengwei Wang, Jing Xu, Tao Hu, and Weilong Peng. "Petroleum generation and expulsion characteristics of Lower and Middle Jurassic source rocks on the southern margin of Junggar Basin, northwest China: implications for unconventional gas potential." Canadian Journal of Earth Sciences 51, no. 6 (June 2014): 537–57. http://dx.doi.org/10.1139/cjes-2013-0200.
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Jurassic strata along the southern margin of Junggar Basin are important petroleum system elements for exploration in northwest China. The Lower and Middle Jurassic source rock effectiveness has been questioned as exploration progresses deeper into the basin. These source rocks are very thick and are distributed widely. They contain a high total organic carbon composed predominantly of Type III kerogen, with some Type II kerogen. Our evaluation of source rock petroleum generation characteristics and expulsion history, including one-dimensional basin modeling, indicates that Jurassic source rocks are gas prone at deeper depths. They reached peak oil generation during the Early Cretaceous and began to generate gas in the Late Cretaceous. Gas generation peaked in the Paleogene–Neogene. Source rock shales and coals reached petroleum expulsion thresholds at thermal maturities of 0.8% and 0.75% vitrinite reflectance, respectively, when the petroleum expulsion efficiency was ∼40%. The petroleum generated and expelled from these source rocks are 3788.75 × 108 and 1507.55 × 108 t, respectively, with a residual 2281.20 × 108 t retained in the source rocks. In these tight reservoirs, a favorable stratigraphic relationship (where tight sandstone reservoirs directly overlie the source rocks) indicates short vertical and horizontal migration distances. This indicates the potential for a large, continuous, tight-sand gas resource in the Lower and Middle Jurassic strata. The in-place natural gas resources in the Jurassic reservoirs are up to 5.68 × 1012 − 15.14 × 1012 m3. Jurassic Badaowan and Xishanyao coals have geological characteristics that are favorable for coal-bed methane resources, which have an in-place resource potential between 3.60 × 1012 and 11.67 × 1012 m3. These Lower and Middle Jurassic strata have good shale gas potential compared with active US shale gas, and the inferred in-place shale gas resources in Junggar Basin are between 20.73 × 1012 and 113.89 × 1012 m3. This rich inferred conventional and unconventional petroleum resource in tight-sand, coal-bed, and shale gas reservoirs makes the deeper Jurassic strata along the southern margin of Junggar Basin a prospective target for future exploration.
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Trembath, Carrie, Lindsay Elliott, and Mark Pitkin. "The Nappamerri Trough, Cooper Basin unconventional plays: proving a hypothesis." APPEA Journal 52, no. 2 (2012): 662. http://dx.doi.org/10.1071/aj11076.
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Beach Energy has started exploring unconventional gas in the Nappamerri Trough, the central trough within the Cooper Basin, where the Permian section has long been regarded as the primary source for most of the conventional hydrocarbons found within the basin. This extended abstract discusses the data used to identify the unconventional play and the exploration program carried out to date. Mud weights, drill stem test (DST) pressures and log data from early exploration wells identified the Permian formations as overpressured. This with geochemical and mineralogy analyses indicated that the Roseneath and Murteree Shales had potential similar to successful shale gas plays being developed in the USA. The quartz and siderite content within both shale sections indicated sufficient brittleness for successful fracture stimulation. In addition, the Nappamerri Trough Permian section showed low permeabilities, which, when combined with overpressure, suggested a basin-centred style play within the Epsilon and Patchawarra sandstones and possibly the Toolachee Formation sandstones. During 2010–11, Beach drilled two exploration wells sited outside structural closure to test both the shale gas and basin centred gas system. Both wells have now been fracture stimulated, with very encouraging gas flows from the Roseneath to Patchawarra section. The latest geological data confirms the pre-drill potential for both gas flow from the shales and the presence and production of gas from sandstones outside structural closure, resulting in a significant shale and tight gas resource booking. Ongoing exploration and development will target a potential 300 Tcf gas in place in PEL 218.
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Smith, Ryan, Tapan Mukerji, and Tony Lupo. "Correlating geologic and seismic data with unconventional resource production curves using machine learning." GEOPHYSICS 84, no. 2 (March 1, 2019): O39—O47. http://dx.doi.org/10.1190/geo2018-0202.1.
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Predicting well production in unconventional oil and gas settings is challenging due to the combined influence of engineering, geologic, and geophysical inputs on well productivity. We have developed a machine-learning workflow that incorporates geophysical and geologic data, as well as engineering completion parameters, into a model for predicting well production. The study area is in southwest Texas in the lower Eagle Ford Group. We make use of a time-series method known as functional principal component analysis to summarize the well-production time series. Next, we use random forests, a machine-learning regression technique, in combination with our summarized well data to predict the full time series of well production. The inputs to this model are geologic, geophysical, and engineering data. We are then able to predict the well-production time series, with 65%–76% accuracy. This method incorporates disparate data types into a robust, predictive model that predicts well production in unconventional resources.
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Karpenko, О., V. Mikhailov, and I. Karpenko. "RESOURCE ASSESSMENT FEATURES OF NON-TRADITIONAL RESERVOIRS BY THE WELL-LOGGING DATA." Visnyk of Taras Shevchenko National University of Kyiv. Geology, no. 2 (89) (2020): 59–64. http://dx.doi.org/10.17721/1728-2713.89.08.
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Possibilities of estimation of shale gas resource and gas of tight reservoirs with the use of the well-logging data on the example of typical gascondensate field in the southern side of the Dnieper-Donetsk Depression are considered. The peculiarity of such works at this stage of studying the prospects of unconventional hydrocarbon resources in Ukraine is the shortage of factual material regarding special geochemical analysis of the core from perspective intervals of well sections. Emphasis is placed on the application of data from the standard set of well-logging methods. Using the method of Q. Passy, the content of organic carbon (TOC) in the rocks within the intervals of drilled wells was estimated. The characteristics of the lithological composition of rocks and the gas saturation of the traditional type of reservoirs were taken into account in the well-logging data. In the absence of available core data on thermal maturity of the rocks within the identified promising thicknesses, gas resources were estimated in several scenarios. The peculiarities of the well-logging data interpretation in the case of cross sections of wells of gas-saturated rocks with capacitance characteristics below the limit are given. Dependencies of the type "porosity - permeability", "porosity - residual water saturation" should be used to establish a lower porosity and gas saturation limit for tight reservoirs. At the end of the article, recommendations for calculating of gas resources in non-conventional reservoirs are provided.
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Yuan, Shukun, Michael V. DeAngelo, and Bob A. Hardage. "Interpretation of fractures and joint inversion using multicomponent seismic data — Marcellus Shale example." Interpretation 2, no. 2 (May 1, 2014): SE55—SE62. http://dx.doi.org/10.1190/int-2013-0146.1.
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Evaluating and exploiting unconventional complex oil and gas reservoirs such as the Marcellus Shale gas reservoirs within the Appalachian Basin in Pennsylvania, USA, have gained considerable interest in recent years. Technologies such as conventional 3D seismic, horizontal drilling, and hydraulic fracturing have been at the forefront of the effort to exploit these resources. Recently, multicomponent seismic technologies have been integrated into some resource evaluation and reservoir characterization activities of low-permeability rock systems. We evaluated how multicomponent seismic technology provides value to reservoir characterization in shale gas exploration. We improved fault interpretations and natural fracture identifications by means of [Formula: see text] and [Formula: see text] integrated interpretation. In addition, using P-P-/P-SV-joint inversion, we extracted key parameters, such as [Formula: see text] ratio and density, that improve stratigraphic interpretation and rock-property descriptions of shale gas reservoirs.
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Cheng, Li Jun, Hong Yu Du, Zhi Guo Xie, Pei Wu Liu, and Shuai Huang. "The Practice and Cognition of Hydraulic Fracturing Technique for Shale Gas Reservoir in Southeast Chongqing." Advanced Materials Research 706-708 (June 2013): 416–19. http://dx.doi.org/10.4028/www.scientific.net/amr.706-708.416.
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Shale gas is an important unconventional energy resource. However its only achieved successful commercial exploitation in the United States and Canada. Shale gas well QY1 was carried out in southeast Chongqing.Taking this well as a case, the fracturing design optimization workflow and its practice are described in this paper. The fracturing feasibility of well QY1 was firstly determined by referencing all the physical parameters of target formation. Then the reservoir stress model was revised and reservoir stress profile was established as well. The reservoir simulation software (Eclipse) was applied to build reservoir geological model for predicting the gas production and determine the optimized permeability enhanced area (PEA). The unconventional fracturing model (UFM) was used to optimize the fluid volume and fracturing scale. And the final fracturing plan was made based on the optimized conclusions. This optimization workflow and the good result provide reliable technique support for the development of the shale gas reservoir in this area. Key Words: Shale gas, PEA, Fracture propagation model, UFM, Production predicting model, Optimization
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Davies, Richard J., Sam Almond, Robert S. Ward, Robert B. Jackson, Charlotte Adams, Fred Worrall, Liam G. Herringshaw, Jon G. Gluyas, and Mark A. Whitehead. "Reply: “Oil and gas wells and their integrity: Implications for shale and unconventional resource exploitation”." Marine and Petroleum Geology 59 (January 2015): 674–75. http://dx.doi.org/10.1016/j.marpetgeo.2014.07.014.
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