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A key operator in the Delaware basin was producing from the Bone Spring reservoir using a competitor’s electrical submersible pumping (ESP) system, but the ESP failed after just 273 days. The unconventional horizontal well had higher gas content in the fluid steam compared to offset wells.

The operator contacted Baker Hughes, a GE Company (BHGE), for a solution to improve ESP performance in the well. After reviewing the historical production data, BHGE Artificial Lift Systems engineers proposed installing the patented* CENesis™ PHASE multiphase encapsulated production solution in the well to handle the high gasto-liquid ratio (GLR) versus the competitor’s conventional tapered pump design.

The CENesis PHASE solution was also ideally suited to handle the anticipated higher gas production as the oil production rate rapidly declined. The CENesis PHASE solution fully encapsulates the ESP system to naturally separate gas from the fluid stream, preventing the majority of the gas from entering the ESP. The design creates a reservoir of fluid to keep the ESP system primed when gas slugs displace fluid in the well and a recirculation pump keeps fluid flowing past the motor to prevent overheating.

The CENesis PHASE solution featured a FLEXPump™ 10 production pump and a GI™ gas insurance pump as the recirculation pump. A WellLift™ downhole gauge, combined with a BHGE ESP production surveillance service, was installed to monitor the ESP system and the well’s performance.

Download the PDF to read the full case study.

Challenges & Results


  • Rapid production decline
  • High gas-to-liquid ratio
  • High free gas at the pump intake
  • Anticipated low production and higher GLR


  • Eliminated gas-related shutdowns
  • Enabled the well to produce with higher gas-to-liquid ratio and low production
  • Increased ESP run life by 107 days to date
  • Reduced OPEX