Reference no: EM132258149
Use the following data to create wellbore stability modelling in petrel Geomechanical model
In-situ stress and geomechanical parameters for wellbore stability in Coopal Oil Field:
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Overburdern stress (Mpa)
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Maximum Horizonal Stress (Mpa)
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Minimum Horizonal Stress (Mpa)
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Cohesion (Mpa)
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Friction Angle (degree)
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Poison's ratio
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Young's Modulus (GPa)
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96.7
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59.4
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44.5
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27
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40
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0.3
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44
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Parameters of formation fluid:
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Pore Pressure (Mpa)
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Permeability(md)
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Porosity (%)
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Oil Density (gr/cm3)
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Fluid Modulus (GPa)
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31.1
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3
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8
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0.692
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0.63
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a) Determine the optimum mud and mud pressure at the onset of shear failure and plastic flow of rock.
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Formation
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Depth(m)
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Mud weight (pcf)
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Mud Pressure (Mpa)
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The onset of plastic flow of rock
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The onset of shear failure
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The onset of plastic flow of rock
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The onset of shear failure
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Limestone
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3791
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_____
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______
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____
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______
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*To determine the optimum mud weight, the analysis in should be initiated with mud weight higher than formation pore pressure, in order to reach plastic state around the wellbore, various mud pressures should be examined.
b) Determine the maximum displacement and the largest stress concentration in the drilling directions.
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Drilling Direction
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Maximum displacement in horizontal coordinate (m)
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The Largest Stress Concentration (Mpa)
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Vertical
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Minimum Horizontal stress
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Maximum horizontal stress
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Article - A wellbore stability model for formations with anisotropic rock strengths by Hikweon Lee, See Hong Ong, Mohammed Azeemuddin, and Harvey Goodman
Attachment:- Wellbore Stability Modeling.rar