Improve multistage fracturing efficiency by limiting stage-to-stage communication behind the casing.
Nonaqueous fluid (NAF)
Distance between stages
20 to 50 ft
Typical differential pressure during multistage fracturing
600 psi (up to 2,000 psi in some wells)
Cement placement challenges common to horizontal wells can lead to formation of mud channels behind the casing. During multistage stimulation treatments, these channels enable communication between stages, allowing fracturing fluids to reenter previously fractured stages while leaving some reservoir sections untreated. To resolve this problem, operators need a technology that can stop fluid movement through channels with differential pressures from 100 to approximately 2,000 psi.