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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.
Operators continue to look to prolific high-permeability, clastic reservoirs in basins around the world. The use of high-deviation and horizontal well trajectories in these fields improves productivity but increases the challenges of sand control. Although early inflow control devices and intelligent completions (ICs) were introduced almost 20 years ago, completion technology has not kept pace with advancements in drilling technology.
The complete paper describes an advanced Rankine cycle process-based system that converts waste heat into usable electrical power to improve the efficiency of gas-compression stations on gas-production platforms and pipelines. More gas is flowing from Egyptian waters and the Eastern Mediterranean with BP’s launch of its Atoll Phase One project. Production of low-viscosity liquids, including condensates, from tight reservoirs such as shales is severely restricted by the ultralow permeability of such formations, limiting production to a very small fraction, usually less than 5%, of the liquids in place.
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.
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.
Mature oil and gas wells will underperform due to different damage mechanisms and/or low permeability, and the unconventional oil and gas wells could not produce at economical rates unless stimulated successfully. The key is to understand and identify the damage mechanism and sources of low productivity in both conventional and unconventional reservoirs, and then to design economical and successful stimulation treatments. In this course, participants will first learn the fundamental science related to geosciences, rock mechanics, and fluid mechanics, and then gain know-how knowledge on the principles of well stimulations followed by practical skills related to design and evaluation of stimulation treatments. At the end of this course, participants will gain the ability and confidence in solving real-world problems by integrating physics, geology, rock mechanics, formation evaluation, production and reservoir engineering. Examples, case studies, and leading software demonstration/practices will further enhance participants' knowledge and skills acquired in this course.
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.