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In tectonically influenced regions, potential hydrocarbon traps are subject to complex states of stress. This paper presents a coupled 3D fluid-flow and geomechanics simulator developed to model induced seismicity resulting from wastewater injection. Knowing which horizon crude oil flows from and in what proportions has been a major challenge for shale producers. Increasingly, they are turning to new technology to find the answer. Seismic imaging provides vital tools for the exploration of potential hydrocarbon reserves and subsequent production-planning activities.
Wells in deepwater reservoirs show significant rate decline with time as the result of various causes. A diagnostic tool for quantification of factors influencing well-productivity decline is presented in this paper. One of the frustrating aspects of well-productivity analysis is identifying the causes of lower-than-expected production/injection during initial well lifetime. Our task is to evaluate the multivariate aspects of well design. The success of water-conformance operations often depends on clear identification of the water-production mechanism.
This paper presents a new approach for more-accurate modeling of liquid blockage in tight oil and gas reservoirs and investigates the use of solvents for blockage removal. This paper provides a more straightforward method for estimating stress-dependent permeability and capillary pressure in rock fractures.
Faster, lower-cost measures of multiphase permeability of conventional reservoirs are promised by a digital rock analysis method developed by BP and Exa, which is marketing software to measure relative permeability. This paper describes the development of “digital-rocks” technology, in which high-resolution 3D image data are used in conjunction with advanced modeling and simulation methods to measure petrophysical rock properties.
The complete paper presents a new three-phase relative permeability model for use in chemical-flooding simulators. Faster, lower-cost measures of multiphase permeability of conventional reservoirs are promised by a digital rock analysis method developed by BP and Exa, which is marketing software to measure relative permeability. In this study, the authors use measured CO2/brine relative permeability data available in the literature to study the behavior of the data obtained for various rocks.
The author writes that the generally accepted Knudsen diffusion in shales is based on a mistranslation of the flow physics and may give theoretically unsound predictions of the increased permeability of shales to gas flow. An extensive laboratory study was carried out with two objectives: to evaluate the effect of water quality on injectivity of disposal wells with reservoir core plugs and to restore injectivity of damaged wells. The F field in the Middle East currently has more than 40 producing wells in the center of the structure. The uneven well distribution limits the understanding of 3D reservoir characterization, particularly in the flank areas.
This course covers reservoir simulation theory using the Steam Assisted Gravity Drainage (SAGD) process. It includes a discussion of major engineering concepts such as thief zones, overlying water and gas, and water legs. About one third of the class time is spent on a series of practical examples that give participants hands-on experience using STARS and Exotherm thermal simulation software. Input data and perform thermal reservoir simulations with consistent results Discuss basic simulation theory and perform simple heat flow calculations Understand use of K values, viscosity data, stream properties, and reservoir properties such as permeability, relative permeability, operation conditions and controls. There is almost no material about SAGD in conventional reservoir simulation texts, since the technology is so new.
This course teaches field-scale reservoir characterization to evaluate heterogeneity and well-to-well communication. Class discussion includes single- and multiphase properties, standard measures of heterogeneity, such as the Dykstra-Parson coefficient, as well as newer methods to analyze inter-well communication. Where possible, we compare results with geological and seismic information to better understand which heterogeneities control injector-producer interactions. Statistical behavior of reservoir properties Flow-storage (Lorenz) curves Koval's method of water flood prediction Permeability and percolation Flow rate analysis to predict injector-producer communication Managing water floods involves determining which injectors are in communication with which producers. Communication is influenced by the heterogeneity, so that we can improve our understanding of the reservoir and which characteristics are controlling the well-to-well communications.
This course teaches integrated reservoir characterization, from basic petrophysics through geostatistics. The emphasis is on porosity, permeability, capillary pressure and relative permeability as they relate to flow. The course also covers the statistics of the spatial distribution of these properties and illustrates the benefits of using them. This class will quickly bring you up to speed on the characterization of oil and gas reservoirs. This course is designed for engineers with at least a bachelor's degree in petroleum or chemical engineering.
This course teaches an integrated version of the basics of waterflooding and enhanced oil recovery (EOR), illustrating the connection of each process to a few fundamental principles. It reviews the specifics of thermal and solvent EOR by relating basic principles to the results of cases from the field. Every oilfield eventually relies on some form of enhanced oil recovery. Some require it from the start. This information can be crucial for continued productivity.