Advanced Electric Submersible Pump Technology Implementation in the Challenging Waterflood Field of Indonesia's Largest Oil Block

Abstract The primary objective of this paper is to evaluate the impact of advanced Electrical Submersible Pump (ESP) technologies on improving well performance in the BS Field, one of the most challenging operational environments in Indonesia's largest oil block. Specifically, the study aims to address the persistent issues of low permeability, poor sand connectivity, low reservoir pressure and high gas interference that have historically contributed to high failure rates and diminished oil recovery. Through the deployment of innovative ESP solutions tailored to these conditions, the research seeks to significantly enhance the operational efficiency and economic viability of the oil extraction processes. Our study employed a comprehensive approach to assess the efficacy of advanced ESP technologies in the BS Field. Initially, a detailed field analysis was conducted to identify specific operational challenges. Subsequently, we implemented three distinct ESP technologies: modern low-rate ESPs, wide-range ESPs, and slim ESPs with motor shrouds, tailored to meet the unique needs of the field. The performance of these technologies was monitored through continuous data collection, including well test, sonolog, amp chart readings, and sensor outputs for pressure and temperature. This data was analyzed to evaluate improvements in operational efficiency and reliability, correlating technology deployment with changes in oil and fluid production rates The implementation of advanced ESP technologies in the BS Field yielded significant improvements in well performance and operational efficiency. The deployment of modern low-rate ESPs extended the average run life of wells from 103 to 306 days, significantly reducing downtime and operational costs. Wide-range pumps demonstrated their efficacy in managing reservoir variability without the need for frequent resizing, thereby maintaining stable production rates and minimizing oil production losses. The slim ESP setups, equipped with motor shrouds and positioned below perforations, led to a notable increase in oil and fluid rates, achieving up to a 212% increase in oil production and increase more than 100% of fluid above pump (submergence fluid level). These setups also stabilized gas handling and maintained optimal motor temperatures, effectively mitigating risks such as gas locking and motor overheating. Our study concludes that these advanced ESP technologies are crucial for overcoming the unique challenges of high gas interference and poor sand connectivity in waterflood fields, offering significant operational and economic benefits to the oil extraction industry