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This paper presents the performance results from one of the waterflood pilots in the Viewfield Bakken. An 18-well numerical-simulation model was built to represent an operator’s Lower Shaunavon waterflood-pilot area. Numerical simulation was used, and a history match on the pilot area was performed.
Ten years ago, news reports frequently cited peak oil as a looming problem facing our world. Technology and innovation has since been developed that allows us to tap into rocks that were previously deemed impossible to extract oil from, reversing this trend. The Western Canadian Sedimentary Basin has been a leader in this movement with entrepreneurs using new technology to develop our resources in a safe and reliable way. Ten years ago, news reports frequently cited peak oil as a looming problem facing our world. Technology and innovation has since been developed that allows us to tap into rocks that were previously deemed impossible to extract oil from, reversing this trend.
The current presentation date and time shown is a TENTATIVE schedule. The final/confirmed presentation schedule will be notified/available middle of October 2019. If we have learned anything from the North American experience, unconventional resources cannot be exploited by small incremental projects. If we are to be successful in developing these types of reservoirs, we have to make project scale operations work to bring these resources to market in a timely manner. A number of Eastern Hemisphere unconventional gas projects have raised interest, neared completion or are commencing deliveries.
This paper presents a state-of-the-art review of scale-inhibitor-analysis techniques and describes how these techniques can be used to provide cost-effective scale management. Calcium sulfate (CaSO4) in the form of gypsum and anhydrite is one of the more prevalent evaporite minerals typically found in the carbonate rocks of the western Canadian sedimentary basin (WCSB).
An independent study pegged the cost of the project at about $2.6 billion, 80% of which Norway’s government planned to fund. The ministry said there is uncertainty about Northern Lights’ benefits and that it could prove to be unprofitable. Write-offs include billions for early-exploration-stage projects that the company will now cut. Phase 1 is expected to be operational in 2024. BP says it is firmly committed to achieving the ambitious target of net-zero greenhouse gas emissions over the next 30 years—even if that means producing less oil and gas.
The complete paper discusses the importance of adequate preparation and the approaches used to overcome challenges of EOR operations, including handling back-produced polymer. Several well-stimulation products and techniques have been seen to benefit well productivity from recent field trials and implementations in carbonate reservoirs, including simpler acid fluid systems, integrated work flows, and coiled-tubing bottomhole assemblies. Researchers use novel methodology to measure the thermo-electric properties of native crude. Business Development VP Kirstie Boyle joins The SPE Podcast to talk startups. Recently part of a $4.5-million funding round, Kirstie shares what makes Interface Fluidics flow.
This comprehensive course is an introduction or refresher for the techniques of evaluating Canadian oil and gas properties, but the techniques used in this course also apply to oil and gas properties elsewhere in the world. There is ample opportunity to work problems in class. By the end of this course, participants will be able to evaluate an oil and gas property and interpret evaluations done by others. The material in the course is very practical, with many tips and insights in evaluating wells, groups of wells, properties and companies. This course is for engineers, geologists, geophysicists, land negotiators, accountants, technologists, and anyone who wants to understand the process and results of evaluating Canadian oil and gas properties.
This course will provide a general overview of current and emerging heavy oil recovery methods with emphasis on field experiences in Alberta and steam assisted gravity drainage (SAGD). Participants will learn about the concepts, field development, reservoir performances, applicability, challenges, and issues of the various in-situ recovery methods. Discussions in this session focus on carbonate reservoir recovery processes and mechanisms, from field experiences to laboratory observations. Topics include thermal casing and cement, Sand control, well intervention, and wellbore simulations. This session addresses the fundamentals and tools for predicting benefits of and usage of solvent for enhanced recovery.Â Topics include both water-soluble solvents and the more traditional hydrocarbon solventsâ€™ viscosity, relative permeability, heat and mass transfer, sampling, and reservoir performance prediction.
Achieving high hydrocarbon recovery is challenging in unconventional tight and shale reservoirs. Although EOR/EGR processes could potentially improve the recovery factor beyond the primary depletion, large-scale field application of these processes are not yet established in these reservoirs. This session will focus on the latest research trends, modelling and experimental work to better understand issues involved in improved economic recovery from such reservoirs.