#TITLE_ALTERNATIVE#

• Main Author: Fitriani (NIM 22204017), Ema
• Format: Theses
• Language: Indonesia
• Online Access: https://digilib.itb.ac.id/gdl/view/6047
• Institution: Institut Teknologi Bandung

ABSRACT: <br /> <br /> <br /> <br /> <br /> Surfactant polymer flooding as an alternative method for enhancing the oil recovery has been used in oil industry. The effectiveness of surfactant polymer flooding are depend on reservoir characteristics (rock heterogenity and fluid rock interaction) so reservoir modeling utilizes reservoir simulation software is the best method to evaluate suitability of this method in oil field. The purpose of our research is to find out the suitability of surfactant and polymers flooding in field X using ECLIPSE 100 Black Oil numeric simulator. <br /> <br /> <br /> <br /> <br /> Our research used several injections scenario sensitivity in the form of concentration and slug volume variation on surfactant, polymer flooding, and their combination. Sensitivity surfactant flooding is done at variation concentration 10 ppm, 25 ppm, 50 ppm, 75 ppm, 100 ppm, 200 ppm, 500 ppm and 1000 ppm. While concentration sensitivity polymer flooding used 100 ppm, 500 ppm, 700 ppm, 1000 ppm. Slug volume sensitivity represent with extended time process injecting that is 2, 3, 4, 6, 8 and 15 month. <br /> <br /> <br /> <br /> <br /> From the optimum polymer flooding is 700 ppm while surfactant flooding 200 ppm. Polymer surfactant flood conduct use constant polymer concentration at 100 ppm with various surfactant concentrations. The optimum oil recovery for field X resulted by injecting surfactant-polymer at 100 ppm polymer and 10 ppm surfactant concentration case.