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Permanent link (DOI): https://doi.org/10.7939/R3912R

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An Experimental Study of Spontaneous Imbibition in Horn River Shales Open Access

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Other title
Subject/Keyword
Horn River Shale
Spontaneous Imbibition
Hydraulic Fracturing
Type of item
Thesis
Degree grantor
University of Alberta
Author or creator
Makhanov, Kaiyrzhan Kh
Supervisor and department
Dehghanpour, Hassan (Department of Civil and Environmental Engineering, Petroleum Engineering)
Kuru, Ergun (Department of Civil and Environmental Engineering, Petroleum Engineering)
Examining committee member and department
Trivedi, Japan (Department of Civil and Environmental Engineering, Petroleum Engineering)
Kuru, Ergun (Department of Civil and Environmental Engineering, Petroleum Engineering)
Potter, David (IPG program, EAS/Physics)
Dehghanpour, Hassan (Department of Civil and Environmental Engineering, Petroleum Engineering)
Department
Department of Civil and Environmental Engineering
Specialization
Petroleum Engineering
Date accepted
2013-08-13T11:33:17Z
Graduation date
2013-11
Degree
Master of Science
Degree level
Master's
Abstract
Massive hydraulic fracturing operations conducted in shale reservoirs create extensive fracture networks to enhance recovery of hydrocarbons from low permeability shale reservoirs. Fluid invasion into the shale matrix is identified as one of the possible mechanisms leading to low fracturing fluid recovery after the fracturing operations. Studying the mechanisms of liquid imbibition into shale matrix is essential for understanding the fate of non-recovered fracturing fluid that can eventually lead to better utilization of water resources by reducing cost and environmental impact. This study aims to investigate effects of base fluid type (aqueous vs. oleic phase), polymer enhanced viscosity, salinity and surfactants in aqueous solutions on the imbibition rate in actual shale samples. The shale samples were collected from Fort Simpson, Muskwa and Otter Park formations, all belong to greater Horn River Basin. The samples were characterised by measuring porosity, wettability (through contact angle measurements), mineralogy (through XRD analysis), TOC, and interpreting wire line log data. We find that imbibition rate of aqueous phase is higher than that of oleic phase. Moreover, we find that imbibition rates of KCl brine, surfactants and viscous polymer solutions are lower than that of fresh water. We find that dimensionless time used to model spontaneous imbibition in conventional rocks requires specific adjustments for application in shales. Based on applied upscaling method, it was found that spontaneous imbibition can cause significant water loss at the field scale during shut-in period after hydraulic fracturing.
Language
English
DOI
doi:10.7939/R3912R
Rights
Permission is hereby granted to the University of Alberta Libraries to reproduce single copies of this thesis and to lend or sell such copies for private, scholarly or scientific research purposes only. Where the thesis is converted to, or otherwise made available in digital form, the University of Alberta will advise potential users of the thesis of these terms. The author reserves all other publication and other rights in association with the copyright in the thesis and, except as herein before provided, neither the thesis nor any substantial portion thereof may be printed or otherwise reproduced in any material form whatsoever without the author's prior written permission.
Citation for previous publication
Makhanov, K., Dehghanpour, H., & Kuru, E. 2012. An Experimental Study of Spontaneous Imbibition in Horn River Shales. In SPE Canadian Unconventional Resources Conference.

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