Difference between revisions of "Mobility Ratio"

Revision as of 14:03, 25 March 2022

Mobility Ratio determines the relative rate of one fluid to another (etc. water to oil).

M \le 1

oil is dominant flowing phase, stable flow.

M > 1

water preferentially floes in the reservoir, unstable flow, fingering.

M = \frac{k_w/ \mu_w}{k_o/ \mu_o}=\frac{k_{rw}/ \mu_w}{k_{ro}/ \mu_o}=\frac{q_w B_w}{q_o B_o}

where^[1]

A

= Area, m2

B_{wi}

= Injected water formation oil factor, m3/m3

h

= Net pay, oil saturated thickness, m

HCPV

= Hydrocarbon pore volume, m3

HCPV_{inj}

= Injected hydrocarbon pore volumes, fraction

W_i

= Cumulative water injection volume, m3

\phi

= Porosity, fraction

S_o

= Oil saturation, fraction

Dimensionless injected pore volume:

W_{iD} = \frac{W_i * B_{wi}}{PV} = \frac{W_i * B_{wi}}{A * h * \phi}

Injected movable pore volume:

MOPV_{inj} = \frac{W_i * B_{wi}}{MOPV} = \frac{W_i * B_{wi}}{A * h * \phi *(1-S_{wc}-S_{orw})}

where

S_{wc}

= Connate water saturation, fraction

S_{orw}

= Residual oil saturation to water, fraction

↑ Wolcott, Don (2009). Applied Waterflood Field Development. Houston: Energy Tribune Publishing Inc.

@@ Line 4: / Line 4: @@
 [[Mobility Ratio]] determines the relative rate of one fluid to another (etc. water to oil).
-:<math> M \le 1</math> stable flow.
+:<math> M \le 1</math> oil is dominant flowing phase, stable flow.
-:<math> M > 1</math> unstable flow, fingering.
+:<math> M > 1</math> water preferentially floes in the reservoir, unstable flow, fingering.