REDA Multiphase HPS
Horizontal multistage surface pump
Handles up to 90% gas volume fraction; used for zero-flaring well tests, well cleanup, and production boosting.
High-GOR, high-gas environments are now common electric submersible pump (ESP) applications, but to produce at full potential, main production pumps need the support of reliable gas handling technology.
The MGH multiphase gas-handling system is designed to manage this issue. The specially designed axial-flow stages of the MGH system provide a more efficient energy transfer than centrifugal stages, avoiding gas locking at high gas-volume fractions (GVFs). The system efficiently manages higher percentages of free gas in gassy wells and achieves much higher drawdowns in subsea wells and wells with nonvented packers, resulting in trouble-free operations and increased production from reservoirs.
MGH system pumps are available in many series options, with gas and liquid downhole flow rates from 800 to 47,000 bbl/d [127 to 7,472 m3/d].
Standard gas handling systems rely on centrifugal force to transfer energy to the liquid or gas mixture. Even with a free gas content of 10% to 20% in the pump, the liquid and gas will separate, and energy transfer efficiency will decrease. If enough gas accumulates, the pump will gas lock and prevent fluid movement.
The MGH system's helicoaxial flow stage ensures a good mix between the gas and liquid. It breaks up large gas bubbles, reduces the gas volume, and primes the main production pump. The system can successfully operate at lower intake pressures with GVF in the pump up to 75%, far exceeding the 40% to 45% GVF limits of conventional gas-handling devices.
The field-proven system can be installed in conjunction with a gas separator or a standard intake, depending on the application.
Integrated approach addresses multiple risks of unconventional environment.
Reduced time required to unload the well despite multiple challenges to ESP operation.
A step forward to reduce well intervention expenditure.
New integrated, solutions-based web platform takes artificial lift to the next level.
Flexible ESP technology and Lift IQ service increase run life by 181% despite solids, high gas ratio, and declining production in Oklahoma field.
Artificial lift has long proved to boost production in the vast majority of wells worldwide; however, pump systems must be carefully managed, especially in unconventional reservoirs characterized by rapid pressure changes and production declines.