Electric Submersible Pump

(2024014) A New Concept of Downhole Gas Slug Mitigation in Unconventional Wells

In gas slugging conditions, conventional gas separators struggle to process and deliver liquid to the pump due to extremely high concentrations of gas within the separator. A prototype slug mitigation system replaced a conventional, high flow, tandem gas separator system in a slugging well. The initial field trial results are discussed in this paper.

(2024016) Extending The Life of An ESP While Maintaining the Ability to Inject

The purpose of this paper is to present a solution to the adverse impact of fallback sand and debris on ESPs (Electrical Submersible Pumps). When these solids accumulate on an ESP during operational shutdowns, it poses a significant risk of damage and subsequent failures upon restarting the system. The problem arises when the friction force that the motor is required to overcome exceeds the material strength of the motor shaft. This large increase in amperage damages the motor and drive shaft of the ESP.

(2024015) Gas Flow Management Technology Designed to Decrease Downtime and Improve ESP Efficiency – Lessons Learned and Case Studies

This paper builds upon last year's presentation, which featured a case study showcasing the application of gas handling technology in the Midland Basin. With over 200 installations in the Permian Basin, this document expands on the insights gained from various applications, providing additional data that reinforces the operational principles and results presented in the previous year. In this paper, we delve into the intricate physical principles governing the gas handler's functionality in regulating free gas flow before reaching the ESP intake.

(2024017) Successful ESP Optimization With Machine Learning Deployed At Scale In The Permian Basin – A Case Study

Many oil and gas companies rely on natural intelligence, resident knowledge, and rules-based logic to optimize production. This is especially true for fields where electric submersible pumps (ESPs) make up a considerable proportion of production on artificial lift. The nature of ESP artificial lift systems makes them well suited for greater remote monitoring, enhanced automation, and implementation of machine learning for autonomous optimization.

(2022029) A Review of Heat-Related ESP Studies

Due to the ESP motor’s inefficiencies, heat is produced when converting power from electrical to shaft power. This generated heat is either transferred to the surroundings (i.e., through the producing fluids) or absorbed by the motor. In the absence of proper cooling, the motor temperature keeps increasing until either the motor fails or it reaches a temperature high enough to transfer the generated heat to its surroundings. According to the Arrhenius rule, equipment life is expected to reduce in half for every 18°C increase.

(2022014) Management of Gas Slugging Along with Sand Handling to Improve ESP Performance and Efficiency

A dual purpose design is presented in this paper to face high gas presence and sand production conditions in petroleum wells with an Electric Submersible Pump (ESP) system installed. The results of this design’s application in severely problematic wells, due to high gas and sand production, will confirm the importance of conditioning the fluid before it gets to the pump intake.

(2022003) Impact from Analyzing The Run Life Statistics Using Survivability Curves Methodology On ESP Key Performance Indicators

Managing extensive Electrical Submersible Pump (ESP) operations and evaluating their performance can be a challenging task, especially in unconventional reservoirs. Varied operational environments, expansive geographical areas, large ESP populations, different declination patterns, diverse fluid properties and well designs and different service providers are some of the complications that operators face every day.

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