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• W4255087637 abstract "A Multiphase Model For Evaluation of Filtration During Drilling and Fracturing of Wells Faruk Civan Faruk Civan The University of Oklahoma Search for other works by this author on: This Site Google Scholar Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, September 2002. Paper Number: SPE-77599-MS https://doi.org/10.2118/77599-MS Published: September 29 2002 Cite View This Citation Add to Citation Manager Share Icon Share Twitter LinkedIn Get Permissions Search Site Citation Civan, Faruk. A Multiphase Model For Evaluation of Filtration During Drilling and Fracturing of Wells. Paper presented at the SPE Annual Technical Conference and Exhibition, San Antonio, Texas, September 2002. doi: https://doi.org/10.2118/77599-MS Download citation file: Ris (Zotero) Reference Manager EasyBib Bookends Mendeley Papers EndNote RefWorks BibTex Search Dropdown Menu toolbar search search input Search input auto suggest filter your search All ContentAll ProceedingsSociety of Petroleum Engineers (SPE)SPE Annual Technical Conference and Exhibition Search Advanced Search AbstractThe majority of the previous models have neglected the effect of the presence of multi-phase fluids in the near-wellbore formation during drilling and hydraulic fracturing. Consequently these studies have used single-phase filtration models leading to the analyses of experimental data with inherent errors. In this paper, a multi-phase fines migration and filtration model is developed and implemented for evaluation of the measures taken for filtration control associated with the completion and workover fluids. This model considers the transport of additives and fines, and their interactions with the filter cake and reservoir formation. The effects of the alteration of the permeability and porosity of the formation and cake matrix, petrophysical flow functions, including wettability, end-point saturations, relative permeability, and capillary pressure, as well as the characteristic parameters of the filtration fluids containing fines, such as non-Newtonian fluid behavior of the slurries and gels, are therefore included.IntroductionDuring over balanced drilling and hydraulic fracturing, fluids containing fine particles can invade reservoir formation and cause formation damage as a result of the interactions of fines and filtrate with the reservoir formation. The extent of these phenomena is controlled by the quality of the filter cake formed over the formation face. Accurate description of the flow distribution, and fluids and fines invasion over reservoir formation face is important for development of optimal strategies to prevent formation damage during drilling and hydraulic fracturing.The majority of the modeling efforts have been simplified approaches and considered a single-phase fluid in reservoir (Dewan and Chenevert1, and Bedrikovetsky et al. 2) and only a few efforts (Liu and Civan3, Phelps4, Fisher et al5, and Chin6) considered the multiphase fluids effects. However, complicated models describing the spatial and temporal distribution of multiphase fluid systems and fine particles in the near wellbore and hydraulically-created fracture regions including the alteration of the petropyhsical properties of reservoir formations are needed.The growth of filter cakes and invasion of filtrate and fines into reservoir formation near wells, perforations, and fractures, depend on the local flow distribution (Hofsass and Kleinitz7) and the injection fluid and reservoir formation conditions (Fisher et al.5, Phelps4). Hofsass and Kleinitz7 emphasize that uniform distribution of flow and fines deposition over formation face may only occur in rare idealized cases such as radial flow around open boreholes; whereas the flow distribution in perforations and hydraulic fractures is nonuniform and preferentially more deposition occurs at tips involving higher flow rates. Hence, the local flow distribution and fines deposition rates are interrelated and continuously vary as preferential deposition sites shift to regions of higher flow rates. Simultaneously, the other factors, such as gravity, inertial flow, and fluid loss additives may have profound effects on the filter cake characteristics, filtrate leak-off, and fines invasion. The gravity especially plays an important role in deviated wells and hydraulically created fractures of great heights (Civan8).In this paper, variable property filter cake models considering nonDarcian linear and radial flows are coupled with a two-phase formation damage model, and applied for estimation of the filter cake thickness, and fines invasion and fluid loss into reservoir formations, following Civan9–12. The linear model is intended for applications in the interpretation of laboratory filtration tests using core plugs. The radial model is intended for applications to filter cake formation over the wellbore. However, these models can be readily extended to other cases involving intricate formation surface shapes, such as hydraulically created irregular fractures. Keywords: upstream oil & gas, cake surface, porosity, civan, suspension, drilling fluid property, spe 77599, drilling fluid selection and formulation, deposition, drilling fluid chemistry Subjects: Drilling Fluids and Materials, Reservoir Fluid Dynamics, Formation Evaluation & Management, Drilling fluid selection and formulation (chemistry, properties), Flow in porous media This content is only available via PDF. 2002. Society of Petroleum Engineers You can access this article if you purchase or spend a download." @default.
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• W4255087637 title "A Multiphase Model For Evaluation of Filtration During Drilling and Fracturing of Wells" @default.
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