Electric Submersible Pump

This case study presents a comprehensive evaluation of how the integration of advanced electric submersible pump (ESP) technologies, efficient gas handling devices, high-efficiency induction motors, and continuous real-time digital surveillance can drive both operational efficiency and sustainability in upstream oil production. The focus is on 22 wells operated by SOGC, Inc. in the Williston Basin, USA, between June 2024 and April 2025.

The thermal behavior of Electrical Submersible Pump (ESP) systems deployed in unconventional wells is poorly characterized, particularly when exposed to elevated gas volume fractions and transient flow regimes. Traditional point temperature measurements provide limited spatial resolution and do not capture how gas interference influences heat distribution along pump stages, seal sections, and motors.

Electric Submersible Pumps (ESPs) face significant performance challenges when free gas enters the system, and bubbles obstruct fluid flow through the pump impellers–a phenomenon known as gas locking, which can induce premature failure. This complication is amplified during gas slug events, which are inevitable in unconventional reservoirs common to the Permian Basin. This paper presents compelling results from real field deployments that highlight superior recovery capabilities achieved through the CENesis PHASE™ Multiphase Encapsulated System.

This study analyzes a comprehensive dataset of mid-to-late life Electric Submersible Pump (ESP) designs deployed in Delaware Basin wells to identify the most effective configurations for high Gas Volume Fraction (GVF) environments. Downhole GVFs are normalized across wells, and ESP designs are categorized by pump stage count, gas-handling pump type, gas separator configuration, and casing size.

Electric Submersible Pumps (ESPs) are commonly known in the Artificial Lift Systems for high flowrates capabilities; however, it’s been limited on tight casing application due to not only HP constrains, but also for presenting restriction in terms of chemical treatment all the way down to the bottom of the equipment and reliability concern on tandem motor applications.

Electric Submersible Pumps (ESPs) remain one of the most widely deployed artificial lift technologies for maximizing production from Permian wells. Operating companies often find themselves installing ESPs between multiple producing zones or even below the perforated intervals for several reasons, including the goal of maximizing production by setting the pump as deep as possible and increasing natural gas separation to help stabilize operating trends. 

This paper presents the Gas Release System Bypass, the latest advancement in gas regulation and separation technologies for Electric Submersible Pump systems operating in high-GLR and gas-slugging environments. The GRSB enhances conventional gas-handling methods by integrating the principles of gas regulation, pressurization, centrifugal dispersion, and controlled gas venting through a dedicated bypass system.

This paper presents the Gas Release System Bypass, the latest advancement in gas regulation and separation technologies for Electric Submersible Pump systems operating in high-GLR and gas-slugging environments. The GRSB enhances conventional gas-handling methods by integrating the principles of gas regulation, pressurization, centrifugal dispersion, and controlled gas venting through a dedicated bypass system.

ESP permanent magnet motors (PMMs) have been confirmed to conserve power when compared to conventional induction motors (IMs) in various industry papers and studies. However, most production comparisons comprise a snapshot in time or the partial life of a single ESP. This analysis is useful, but it doesn’t convey the full power-saving value of a PMM installation.

1. OBJECTIVES/SCOPE: Please list the objectives and scope of the proposed paper.