Difference between revisions of "Mobility Ratio"
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:<math> k_o </math> = relative oil phase permeability, function of the phase saturation, mD | :<math> k_o </math> = relative oil phase permeability, function of the phase saturation, mD | ||
:<math> k_w </math> = water phase permeability, function of the phase saturation, mD | :<math> k_w </math> = water phase permeability, function of the phase saturation, mD | ||
| − | :<math> M = mobility ratio, fraction | + | :<math> M </math>= mobility ratio, fraction |
:<math> \mu_o </math> = oil viscosity, cP | :<math> \mu_o </math> = oil viscosity, cP | ||
:<math> \mu_w </math> = water viscosity, cP | :<math> \mu_w </math> = water viscosity, cP | ||
Revision as of 14:26, 25 March 2022
Contents
Brief
Mobility Ratio determines the relative rate of one fluid to another (etc. water to oil).
oil is dominant flowing phase, stable flow.
water preferentially flows in the reservoir, unstable flow, fingering.
Equation
where
= oil formation volume factor, m3/m3
= water formation volume factor, m3/m3
= relative water phase permeability, function of the phase saturation, fraction
= oil phase permeability, function of the phase saturation, fraction- = relative oil phase permeability, function of the phase saturation, mD
= water phase permeability, function of the phase saturation, mD
= mobility ratio, fraction
= oil viscosity, cP
= water viscosity, cP
= oil rate, cc/sec
= water rate, cc/sec
Example
Determine Mobility Ratio using the following data[1]: Core is 70% water and 30% oil saturation. Water phase permeability is 248 mD, oil phase permeability is 50 mD. Water viscosity is 1cP, oil viscosity is 3cP.
Injected movable pore volume:
where
= Connate water saturation, fraction
= Residual oil saturation to water, fraction
See Also
References
- ↑
Wolcott, Don (2009). Applied Waterflood Field Development
. Houston: Energy Tribune Publishing Inc.
