• Large gas slugs in the fluid stream caused gas-locking conditions in the ESP system
  • Frequent gas slugs caused ESP motor overheating
  • Frequent shutdowns followed overheating events
  • Stabilized ESP system operating conditions
  • Increased run life from 144 days to over 790 days
  • Increased production 346% vs. gas lift

Case study details

An operator in Kansas completed a well using 7-1⁄2 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.

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