In a geometric completion with perforation clusters every 23.5 ft, long drilling fluid channels behind the casing would enable fracturing fluid and energy to migrate far from the intended cluster, reducing fracturing efficiency, reservoir contact, and well production potential.
Industry-accepted cementing best practices including running centralizers.
Add Fulcrum technology to the cement in four wells on the pad to react with leftover drilling fluid and cement the other two pad wells conventionally. Then assess the cementing performance with the USI ultrasonic imager and, after multistage fracture stimulation, monitor and compare well production.
Logs indicated a well cemented conventionally had long channels behind the casing, where the well cemented with Fulcrum technology had small pockets of lower-quality cement but no long channels that would permit fracturing fluid migration between stages.
After 10 months of production, average cumulative oil production was 16% higher and gas production was 37% higher for the wells cemented with Fulcrum as compared with those cemented conventionally. The increase amounted to more than 50,500 bbl of incremental oil and 238 million scf of gas.
