Simulation of Scale Inhibitor Squeeze Treatments in a Polymer Flooded Reservoir

Alan Beteta, Oscar Vazquez, Munther Mohammed Al Kalbani, Faith Eze

Research output: Chapter in Book/Report/Conference proceedingConference contribution


This study aims to demonstrate the changes to scale inhibitor squeeze lifetimes in a polymer flooded reservoir versus a water flooded reservoir. A squeeze campaign was designed for the base water flood system, then injection was switched to polymer flooding at early and late field life. The squeeze design strategy was adapted to maintain full scale protection under the new system.

During the field life, the production of water is a constant challenge. Both in terms of water handling, but also the associated risk of mineral scale deposition. Squeeze treatment is a common technique, where a scale inhibitor is injected to prevent the formation of scale. The squeeze lifetime is dictated by the adsorption/desorption properties of the inhibitor chemical, along with the water rate at the production well. The impact on the adsorption properties and changes to water rate on squeeze lifetime during polymer flooding are studied using reservoir simulation.

A two-dimensional 5-spot model was used in this study, considered a reasonable representation of a field scenario, where it was observed that when applying polymer (HPAM) flooding, with either a constant viscosity or with polymer degradation, the number of squeeze treatments was significantly reduced as compared to the water flood case. This is due to the significant delay in water production induced by the polymer flood. When the polymer flood was initiated later in field life, 0.5PV (reservoir pore volumes) of water injection, water cut approximately 70%, the number of squeeze treatments required was still lower than the water flood base case. However, it was also observed that in all cases, at later stages of field life the positive impacts of polymer flooding on squeeze lifetime begin to diminish, due in part to the high viscosity fluid now present in the production near-wellbore region.

This study represents the first coupled reservoir simulation/squeeze treatment design for a polymer flooded reservoir. It has been demonstrated that in over the course of a field lifetime, polymer flooding will in fact reduce the number of squeeze treatments required even with a potential reduction in inhibitor adsorption. This highlights an opportunity for further optimization and a key benefit of polymer flooding in terms of scale management, aside from the enhanced oil recovery.
Original languageEnglish
Title of host publicationSPE International Conference on Oilfield Chemistry 2021
PublisherSociety of Petroleum Engineers
ISBN (Electronic)978-1-61399-746-8
Publication statusPublished - 6 Dec 2021
EventSPE International Conference on Oilfield Chemistry 2021 - Virtual, United States
Duration: 6 Dec 20217 Dec 2021


ConferenceSPE International Conference on Oilfield Chemistry 2021
Country/TerritoryUnited States


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