Our analysis identified specific best practices to help Production Engineers improve the performance of the ESP system. We demonstrated how, by closely monitoring the interactions between injected chemicals and pump control parameters, the ESP run life can be increased and total cost of ownership reduced. ESP are used in depleted reservoirs, but failure rate poses economical limitations when rig availability is low and workover costs are high. To minimize the deferred production, we devised a comprehensive strategy for de-risking ESP operations with ad-hoc chemical treatment. Many variables are analyzed in literature to increase ESP run life. However, they are often treated standalone. We evaluated previous studies conducted in this field, both at downhole level and surface production facilities. We focused our quantitative analysis on the interaction between reservoir fluids and ESP system to identify detectable signatures on pump control parameters. We continuously monitored operation of pumps at field level through real time data and identified distinctive anomalies in specific wells. We ran software simulations to evaluate likelihood and type of scale deposition downhole. We selected ad-hoc chemical treatment and accurately measured impact on ESP control parameters. Initially we observed a decrease in delta pressure (pump intake vs. pump discharge) in a well, a trend that was determined by possible pump plugging. The team decided to collect field samples of the produced fluids. A chemical downhole model was calculated through software simulation, then an ad-hoc chemical treatment was selected for the specific application. The team then iterated the solution in the field using additives for: i) inhibiting formation of further deposits; ii) removing existing scale deposits at ESP level. With rigorous evaluation of the new pump conditions through remote live monitoring and continuous adjustment of chemical treatment, the well showed a positive gain of delta pressure indicating the effectiveness of the solution. In the following months, well tests were conducted on site with test separators to collect actual data on the additives used. This allowed the team to fine-tune the long-term treatment program after further reducing the chemical dosage to optimize OPEX. Our study identified specific variables that Production Engineers must analyze when operating ESP in high-risk/high-return projects. Also, we identify a general methodology to promptly intervene in case of erratic pump behavior. The paper describes for the first time what a comprehensive production solution can do in increasing ESP run life while restoring production in complex wells prone to scale deposition. Software analysis and continuous data collection/interpretation from downhole pumps were key aspects to mitigate risk

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