How do you optimize well performance and recovery using artificial lift methods?

Optimizing well performance and recovery with artificial lift involves selecting appropriate lift methods like rod pumps, gas lift, or electric submersible pumps, based on well characteristics and production needs.

Pumps become inefficient and malfunction with additional gas production. Gas lift is aided by additional gas production. This makes gas lift a good choice for many reservoirs that have expanding gas caps. Gas lift is dependent on an investment in compressors and gas lift distribution pipework, upfront capital costs. Thereafter, the operating cost is low, with maintenance and optimization consisting of placing and replacing gas lift valves. In most places this is accomplished with inexpensive slickline units in wells utilizing side-pocket gas lift mandresl. In other places, hoists may be used to replace the conventional mandrels with valves by pulling and re-running the tubing string.

Optimizing well performance and recovery using artificial lift methods involves selecting the appropriate artificial lift technique based on well and reservoir characteristics, continuously monitoring and adjusting lift operations, implementing efficiency measures such as optimizing pump settings, and integrating real-time data for informed decision-making. Regular well performance assessments and adjustments to artificial lift strategies contribute to maximizing recovery and overall well efficiency.

Experience suggests that ESPs do not handle high GORs well, or solids which may be scales or sand production. Downhole gas separation, whereby gas is produced separately via the annulus, can help in high GOR wells. High rate ESPs’ longevity may benefit from the use of variable speed drives to provide soft starts and optimal loading.

ESP is a system consisting of pump, motor, electrical cable, and surface electrical equipment such as a Variable Speed Drive (VSD). Any part of this system can cause a massive failure. ESP pumps, motors, and cables are generally not repairable. The systems are relatively expensive. The experience of Operations staff is a major determinant in the life of the system. Operator error can wreck a system quickly. Therefore, ESPs are better suited for systems with dozens of pumps, rather than only a few.

Hydraulic pumps using water as a power fluid make accurately measuring water cut impossible. Same thing measuring oil cut and oil rate in systems that use oil as a power fluid. Do not use hydraulic pumps where the measurements are important to reservoir and well management. Piston-type pumps tend to have very short run lives. In one field with hundreds of these pumps, and attempts to improve run lives, the life span was a few months. Jet pumps do not have this problem.

Progressing Cavity Pumps with elastomeric stators cannot be used with lighter crude due to swelling of the stators. PCPs are able to pump extremely viscous and sand-laden fluids, unlike any other artificial lift systems.

Artificial lift methods help maximize oil well performance and recovery. By selecting the most suitable method and monitoring operations closely, we can optimize efficiency and extraction rates.