Estimation of Polymer Re-Gel Injection Time in Natural Fractured Reservoirs

Longinos, Sotirios
Soltanieh, Ashkan
Akın, Serhat
Hydrocarbon production is usually restricted by excess water production in naturally fractured reservoirs. Polymergel injection is an efficient method to shut-off fracture conduits in water bearing zones. Efficiency of water shut-offmay decrease in time due to several reasons. Well diagnostic methods such as recovery plot, production history plotand decline curve analysis can be used to identify necessity to re-gel the well. Both of the surveillance methods requiresome sort of analytical modeling and may not identify performance loss in due time. In this study, we propose theuse of pressure build up test analysis as diagnostic tool to optimize re-treatment time. To achieve this goal a highlyfractured heavy oil reservoir going through polymer injection is modeled using discrete fracture network (DFN)modelling approach where it is used as a tool for providing fracture properties to the dual-porosity fluid flow simulator.DFN model is created by using available fracture parameters. The model is then calibrated by conditioning it to welltest data obtained from a heavily fractured field located in South East Turkey. A CMG STARS single well/dualporositynumerical model whose fracture properties are populated by the DFN model results is used to model polymerinjection. Once the matches obtained with DFN populated dual porosity model were obtained, several syntheticpressure build up tests were conducted to estimate skin factor as well as permeability which are markers used for regeltreatment performance. It was concluded that well test analysis is an efficient tool to estimate the time of re-geloperation.
Citation Formats
S. Longinos, A. Soltanieh, and S. Akın, “Estimation of Polymer Re-Gel Injection Time in Natural Fractured Reservoirs,” presented at the 2nd International Discrete Fracture Network Engineering Conference, 2018, Accessed: 00, 2021. [Online]. Available: