Electric Submersible Pump

Sand production remains a challenge in ESP applications because uncontrolled solids can cause erosion, abrasion, vibration, plugging, premature equipment failure, and increased lifting costs. Conventional sand-control solutions rely on filtration; however, screens with smaller slot sizes may experience plugging under variable sand production and high-viscosity fluid conditions. This paper presents...

OBJECTIVES/SCOPE
Unconventional wells with moderate-to-high gas-liquid ratios can experience gas interference that limits electrical submersible pump (ESP) drawdown and creates unstable operating conditions. This paper presents a Permian Basin field case where an alternative gas-handling configuration was implemented to improve gas separation, stabilize ESP operation, and increase production under...

High Gas-Liquid Ratio (GLR) conditions present significant challenges for Electric Submersible Pump (ESP) systems, as free gas and slug flow can reduce hydraulic efficiency, increase motor temperature and electrical instability, promote gas interference and gas locking, and shorten ESP run life. This paper presents the application of the Gas Release System Bypass (GRSB), an advanced downhole flow...

Production challenges associated with high gas-liquid ratios (GLR) and severe gas interference are frequently encountered in gassy wells, limiting artificial lift performance and preventing operators from achieving desired drawdown levels. The CENesis PHASE™ system fully encapsulates the Electric Submersible Pump (ESP) and uses density-driven separation of free gas upstream of the pump intake...

Electric Submersible Systems in the oil and gas industry have long relied on PLC control loops as well as Supervisory Control and Data Acquisition (SCADA) technology for monitoring and control. However, as the digital landscape continues to evolve, artificial lift systems must adapt to more dynamic and autonomous operations. Leveraging cloud-native edge computing, microservices, and the Industrial...

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...

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...

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...

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. Recently an operating...