Page 159 - Formation Damage during Improved Oil Recovery Fundamentals and Applications
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Formation Damage by Fines Migration: Mathematical and Laboratory Modeling, Field Cases 137
where U m (γ) is the maximum velocity for which no particles can be held
on the grain surface.
Fig. 3.23A shows impedance curves for different injection rates that
vary from 50 to 200 bbl/day/m and under the formation water salinity
that is equal to that of the high-salinity water injected. After injection of
5.5
5
4.5
4
Impedance 3.5 3
2.5
2 50 bbl/day/m
100 bbl/day/m
1.5
200 bbl/day/m
0
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1
(A) PVI ×10 –3
7
6
5
Impedance 4
3
High salinity water
2 Low salinity water
Deionized water
1
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1
(B) PVI ×10 –3
Figure 3.23 Well impedance J(T) increases as (A) injection rate increases; (B) salinity
decreases (PVI: number of pore volumes injected).
