Page 254 - Reservoir Formation Damage
P. 254
234 Reservoir Formation Damage
80
0.29
~ M
E
a.
E 40
100 200 300 400 500 600 700 800 900 1000 1100
PORE VOLUMES
Figure 10-28. Effect of fluid velocity on the entrainment and redeposition of
fines in a 3.81 cm diameter and 3.0 cm long Berea core during a 2% KCI
solution injection (after Gruesbeck and Collins, ©1982 SPE; reprinted by
permission of the Society of Petroleum Engineers).
30
2% KCI BRINE
25
20 1SOPAR M
- 2.6 mPa s
10
ISOPARM
AT CONNATE
2% Kd BRINE
SATURATION
.02 .04 .06 .OB .10 .12 .14 .16 .18
INTERSTITIAL VELOCITY. u/</> j; CM/S
Figure 10-29. Permeability reduction as a function of the interstitial velocity
determined using the Figure 10-28 data (after Gruesbeck and Collins, ©1982
SPE; reprinted by permission of the Society of Petroleum Engineers).
The results presented in Figures 10-29 and 10-30 indicate that the
indigeneous particles of Berea and field cores are water wet. This is
apparent by the effect of the two phases on the critical velocity values
required to initiate particle mobilization. The implication of this is that
variation of the fluid system from oil to oil/water can reduce the critical
