New flowmeter combines downhole sensor, neural network
March 25, 2010
Baker Hughes announces a multiphase flowmeter that combines downhole sensor technology with neural network capabilities for real-time flow rate estimates from wells produced vai electrical submersible pumping (ESP) systems.
Offshore staff
HOUSTON -- Baker Hughes announces a multiphase flowmeter that combines downhole sensor technology with neural network capabilities for real-time flow rate estimates from wells produced vai electrical submersible pumping (ESP) systems. The Neuraflow multiphase flowmeter delivers flow rate estimates with a greater than 90% accuracy rate compared to actual flow rates, Baker Hughes says.
The Neuraflow device, which is installed in the ESP surface variable speed drive, uses existing standard downhole measurements coupled with additional system measurements and learning algorithms to infer a flow rate based on known reservoir and fluid properties. It measures flow at four separate downhole locations. The measurements are compared and then used to calibrate the model.
“Neuraflow meets a long-held customer need for accurate, affordable flow measurements,” says Neil Harrop, president of Baker Hughes’ completions and production business segment. “This complements our expanding digital oilfield capability with real-time measurements that can make a significant difference in optimizing production.”
