• 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

Case study details

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.

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