Modeling Time-Dependent Pore Pressure Due to Capillary and Chemical Potential Effects and Resulting Wellbore Stability in Shales

[+] Author and Article Information
M. K. Rahman, Zhixi Chen, Sheik S. Rahman

J. Energy Resour. Technol 125(3), 169-176 (Aug 29, 2003) (8 pages) doi:10.1115/1.1595111 History: Received June 01, 2000; Revised April 01, 2003; Online August 29, 2003
Copyright © 2003 by ASME
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Capillary pressure versus percentage saturation curve for Pierre shale-Ester based mud system
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Best-fit curve to the measured capillary pressure for Pierre shale.
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Relative permeability versus normalized saturation curves for Pierre shale-Ester based mud system
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Schematic diagram of mud pressure penetration test equipment.
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Mud pressure penetration due to capillary effect in Johnstone-I shale exposed to ester based mud
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Mud pressure penetration due to capillary effect in Johnstone-II shale exposed to ester based mud
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Mud pressure penetration due to capillary effect in Johnstone-II shale exposed to ester based mud after forced permeability calibration
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A schematic diagram of the tri-axial chemical potential cell
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Osmotic pressure development across Pierre shale sample separating pore fluid and 30% CaCl2 solutions under different confining pressures
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Effect of confining pressure on experimentally measured reflection coefficient of Pierre shale
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Flow-chart for overall time-dependent wellbore stability analysis model
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Comparison of safe mud weight windows for a vertical well drilled with Ester based and water based muds at the depth of 1525m in a normal fault stress regime



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