FLEXPumpER technology increased production 20%, managed gas entrained in the production stream
An operator in East Texas had a well that experienced frequent electrical submersible pumping (ESP) system shutdowns, sometimes multiple times a day, as a result of gas slugs and elevated bottomhole temperatures. Gas/oil ratios (GOR) and water cut varied daily, which led to downthrust issues and poor reliability rates.
The operator approached Baker Hughes, a GE company (BHGE), for an ESP system solution to increase reliability and handle flexible flow rates with frequent gas slugs. BHGE installed a CENesis™ ESP system with FLEXPumpER™ technology, WellLIFT™ H sensor, MVP™ gas handling pump, Electrospeed Advantage™ variable speed drive, and vortex gas separator. Production rates began at 2,000 BFPD with 60% water cut. Reliable operations continued even when production dropped as low as 800 B/D. The ESP system maintained operations and provided superior downthrust-handling capabilities. Gas averaged 650 MCF with some significant slugging but operations continued. WellLIFT H sensor monitored discharge pressure as dynamic reservoir conditions changed frequently.
The CENesis ESP system with FLEXPumpER technology maintained steady drawdown while running at a slow speed of 46 Hz. Production averaged 1,034 BFPD, which represented a 20% production increase over the previous ESP system.
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