HPump system extends run life and reduces maintenance costs 90%

Overview

Challenges
                  Elevated downhole temperature
Low production rate
High amount of free gas
Sand production
Recurring rod lift failures
Chemical treatment required

                 

Results
                  Maintained production
Reduced maintenance costs 90%
Increased run time
Lowered operating cost
Eliminated frequent shutdowns
Reduced intervention costs
Eliminated efficiency loss due to recirculation

                 

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Case study details

An oil producer in Brazos County, Texas was struggling to stabilize production from an Eagle Ford well. Initially a rod lift system was installed, but due to high amounts of gas, rod failures occurred monthly. Baker Hughes offered two different electrical submersible pumping (ESP) systems, but severe downhole conditions such as low inflow, high gas content, gas slugging, and high downhole temperature caused short ESP runs.

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