Integrated Gas Processor Performance in low flow high GLR Wells.
Extract's electrical submersible pump with an IGP outperforms the conventional ESP gas handling systems in a multi-well second and third run ESP field study by increasing uptime, drawdown and production. Positively impacting the operator's bottom line.
THE PROBLEM:
A Permian operator operating wells in the Midland Basin,Howard County, Texas was seeking a solution to produce their second and third run ESPs in depleted Wolfcamp A & B applications.
The three IGP wells produced 50% more fluid on average at an incrementally lower intake pressure than the six wells with conventionalESP gas handling equipment.
The problem was the gas to liquid ratios had increased to a point where industry standard ESP gas handling solutions were less than desirable.
THE PROCESS:
Similar wells were used for comparison in this study: three wells with IGPs and six wells with conventional ESP equipment. Conventional systems utilized tandem gas separators and a gas handling type pump. The three IGP wells produced 50% more fluid on average at an incrementally lower intake pressure than the six wells with conventionalESP gas handling equipment. This is attributed to the IGP’s ability to both handle and separate gas more efficiently than conventional ESP gas handling systems used today.
Conclusion
The average runtime of the second and third run of the conventional ESP gas handling system in this field was 214 days. The current average runtime of wells with IGPs installed now exceeds wells with conventional equipment in the same field. The improved gas handling of the IGP is enabling the ESP equipment to produce more fluid, while also increasing the longevity of the ESP. As more and more unconventional wells that are produced with ESPs dewater and gas rates increase, an ESP solution is needed to continue to produce these wells effectively. The IGP does exactly that.
