Reduce cost of PCP deployment and retrieval
An operator has numerous marginal wells in South America that
produce fluids with high water and sand content. PCPs are used
for artificial lift, and minimizing their installation and operating
costs is key to the economics of these wells.
A conventional PCP stator is connected to the tubing string. Installing
or removing the stator requires retrieving all the tubing joints and
running them back in the well, an operation that was consuming
48–60 hours, depending on the well depth. The operator wanted
to minimize costs, NPT, and deferred production.
Eliminate the need to pull the tubing
Schlumberger recommended the KUDU insert system, which enables
PCP installation in (or removal from) the production tubing using a
sucker rodstring, eliminating the need to pull out the tubing and run
it back in. Moreover, the operation can be conducted with a flush-by
unit, which has a lower cost compared with that of a workover rig.
The net result is significant savings in time and costs.
Because the wells have a pump seating nipple (PSN) installed in the
tubing string, the Type B configuration was selected for the insert
system. It seals against the PSN, preventing pumped fluid from draining
back down the tubing. A bidirectional torque anchor prevents rotation
in any direction, protecting the seals and allowing the pump to operate.
Achieve 40% savings despite challenging conditions
The system was installed in 26 wells. Despite the challenges presented
by high sand content, installation costs decreased by about 40%.
The insert system has proved to be a robust, reliable, and