In the Neuquén oil fields of Argentina, a major producer experienced calcium sulfate scale deposition in their electrical submersible pumps (ESPs). Scale deposits affected the cooling capacity of the ESP motors, resulting in higher-than-normal ESP operating temperatures. To address the scale problem, the producer used scale inhibitor additive; however, the operator continued to experience high operating temperatures equipment failures and shortened ESP operating lives. To mitigate the problem, the customer reduced the pump speed, which reduced the number of well interventions, but also reduced the productivity of the wells. A multidiscipline team with expertise in chemicals, artificial lift systems and operations analyzed the scaling problem and evaluated treatment alternatives. Appropriate modelling and performance tests identified an alternative inhibitor that effectively mitigated formation of calcium sulfate scale in the ESP pump systems. The selected scale inhibitor was used in the field in two critical wells selected from wells having a run life of 60 days or less. After two months of the field trial, ESP temperatures had stabilized within a safe operating range. The combination of scale inhibition program and maintaining ESP operating temperatures in a safe range produced savings in costs related to pump repairs, equipment rental, production loss, and chemical treatment. The field trial program was expanded and applied to 192 more wells.