Water vapor increased 12% on steam assisted gravity drainage (SAGD) well for enhanced production
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Frequent gas slugging and extreme operating temperatures led to system overload
Canada
An operator faced difficulties producing a SAGD well, where steam injection is used to reduce the viscosity of heavy crude for production.
An operator encountered challenges in producing a SAGD well due to the complexity of SAGD operations. The existing electric submersible pump (ESP) system, comprising a gas avoider, gas handler, and production pump, struggled to overcome flow rate limitations and maintain stable operations. Frequent gas slugging and extreme operating temperatures resulted in system overload, shortened runtimes, and increased operating costs for the customer.
Halliburton recently installed an advanced triple-play slugger pump system. This system includes a Hydro-Helical gas separator, a slugger pump, and a rotating intake. By drawing fluid from the bottom of the wellbore, the intake directs it to an enhanced pump and a high-flow gas separator. The elongated space between the intake and exit ports efficiently manages gas by creating internal and external liquid reservoirs, ensuring a continuous liquid flow to the pump and maintaining cooler equipment operating temperatures.
The Hydro-Helical® Slugger HT pump design effectively addressed gas locking and enhanced system efficiency for longer and more stable production. Additionally, the system increased water vapor content by 12% over eight weeks, resulting in lower viscosity of the produced bitumen. This improved flow allowed for easier extraction from the production well, leading to cost savings in downtime and increased return on investment.
