A Numerical Study of Tertiary Oil Recovery by Injection of Low-Salinity Water

ahmed radhi wattan; Mohammed S. aljwad; Usama S. Alameedy

doi:10.52716/jprs.v13i1.674

Authors

ahmed radhi wattan Petroleum department, College of Engineering, University of Baghdad, Baghdad, Iraq
Mohammed S. aljwad Petroleum department, College of Engineering, University of Baghdad, Baghdad, Iraq
Usama S. Alameedy Petroleum department, College of Engineering, University of Baghdad, Baghdad, Iraq

DOI:

https://doi.org/10.52716/jprs.v13i1.674

Keywords:

secondary oil recovery, low salinity injection, tertiary oil recovery, recovery factor

Abstract

The injection of Low Salinity Water (LSWI) as an Enhanced Oil Recovery (EOR) method has recently attracted a lot of attention. Extensive research has been conducted to investigate and identify the positive effects of LSWI on oil recovery.

In order to demonstrate the impact of introducing low salinity water into a reservoir, simulations on the ECLIPSE 100 simulator are being done in this work. To simulate an actual reservoir, an easy static model was made. In order to replicate the effects of injecting low salinity water and normal salinity, or seawater, the reservoir is three-phase with oil, gas, and water. It has one injector and one producer.

Five cases were suggested to investigate the effect of low salinity water injection with different concentrations and the period of injection.

The low salinity injection period varied from twenty-five years in case one and reduced five years in each case until reached to five years in final case.

Higher oil recovery factor obtained in case one with injection time twenty-five years and lower recovery factor for case five with injection time of low salinity water injection five years.

Lower water concentration gives higher oil recovery for all cases where this study investigated the effect of low-salinity water flooding as slug injection.

From the five cases presented, field oil recovery factor (FOE), field oil production rate (FOPR), field oil production total (FOPT), field pressure (FP), and field water cut (FWCT) were observed. Oil recovery is 56.6 percent in high salinity water flooding (HSWF), and 71.8 percent in low salinity water flooding (LSWF) for 0 percent salt concentration and 62.40 percent for 20 percent salt concentration as in case one.

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