Nurullitawati, Rahmi (2023) Analisis Pengaruh Salinitas Pada Kinerja Surfaktan Untuk Reservoir Batu Pasir. Other thesis, Universitas Islam Riau.

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Abstract

The decreasing national oil production by around 3-5% over the past decade has introduced surfactant flooding as one of the Chemical Enhanced Oil Recovery (CEOR) methods that play a role in reducing the Interfacial Tension (IFT) value. This helps in displacing trapped oil within the reservoir due to capillary pressure towards the production well. Most surfactant flooding implementations focus on sandstone reservoirs. However, surfactant retention within sandstone reservoirs can be influenced by several factors such as surfactant concentration, salinity, and cosurfactant, making it a complex phenomenon where surfactant adsorption during injection can impact its economic value. In this research, the researcher aims to analyze the influence of salinity on surfactant performance in sandstone reservoirs using samples of anionic surfactant solutions with varying concentrations (0.1% - 1%) and salinity levels (5000 ppm - 30,000 ppm) on sandstone reservoir fluids consisting of medium oil (API 32) and light oil (API 40). The testing involves 6 stages, including compatibility testing, interfacial tension, filtration, phase behavior, spontaneous imbibition, and thermal stability. The research results will reveal the impact of salinity on surfactant performance in these 6 testing stages. The findings indicate that variations in salinity concentration, ranging from 5000 ppm to 30,000 ppm of NaCl, have an impact on the performance of anionic surfactants. Higher salinity concentrations hinder the surfactant's effectiveness, but it performs well at the optimum salinity concentration. There is a gradient in the IFT value, increasing from 4.46E-03 dyne/cm to 5.39E-02 dyne/cm for light oil (API 40) and from 4.46E-03 dyne/cm to 3.24E-02 dyne/cm for medium oil (API 32). In the imbibition test conducted over 72 hours using a 0.5% concentration of anionic surfactant with 5000 ppm NaCl salinity, oil recovery reached 82.3% for core sandstone with a permeability of 760 mD and 73.3% for core sandstone with a permeability of 95 mD. Keyword : Surfactant Flooding, Salinity, Sandstone reservoir, Screening Criteria

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