CENesis PHASE system increased run life 440% in unconventional well
An operator in Kansas completed a well using 7-½ in. casing and in the first year of production installed two separate standard electrical submersible pumping (ESP) systems and a gas lift system in an effort to maximize production. However, each form of artificial lift produced disappointing results. Gas lift was unable to draw down the bottomhole pressure, which limited production, and the standard ESPs experienced frequent shutdowns and high motor temperatures, resulting in deferred production and reliability issues.
Each conventional ESP system produced for several months but began to have gas interference when the pressure in the wells declined, leading to an increased number of gas slugging incidents. The increased gas volume in the wellbore resulted in frequent gas locking of the ESP, which resulted in little to no liquid flowing past the motor and through the pump. Fluid flow is necessary to maintain an adequate operating temperature. Gas-locking events eventually led to short runs of 144 days and 102 days respectively, for the first two ESP installations.
Following the short runs, the operator decided to try a gas lift solution. The gas lift system eliminated shutdowns due to gas interference, but production was extremely constrained. Production with the gas lift system never exceeded 4 BOPD versus an average of 66 and 59 BOPD for the two ESP systems. The limited oil production achievable with gas lift made the well uneconomical and the operator approached Baker Hughes, a GE company (BHGE), for an alternative ESP solution.
After evaluating the performance of previous artificial lift methods, BHGE suggested the 5½-in. patented* CENesis™ PHASE multiphase encapsulated production solution for 7-in. casing. This was the best option to decrease non-productive time (NPT) and increase the reliability and run life of the ESP system.
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