• Low-flowing well
  • ESP failures and deferred production due to system downtime
  • High gas-to-liquid ratio from 3,000 to 5,000 SCF/STB
  • 5-1⁄2 in. 20 lb casing, which limited artificial lift options
  • Increased ESP system uptime and drawdown
  • Eliminated gas lock shutdowns due to gas slugs

Case study details

A major operator in the Permian basin’s Wolfcamp formation had a problem horizontal well where two conventional electrical submersible pumping (ESP) systems had failed within eight months. The failures were related to handling gas-to-liquid ratio as high as 5,000 SCF/STB. The production rates were too high for conversion to a rod lift system and the operator wanted an alternative solution in order to operate in the high gas rate environment.

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