ANALISIS PENGARUH KONSENTRASI SURFAKTAN NON-IONIK TERHADAP PEROLEHAN MINYAK PADA KASUS HEAVY OIL DI RESERVOIR SANDSTONE DAN CARBONATE MELALUI PROSES IMBIBISI SPONTAN (STUDI LABORATORIUM)

• Main Author: Halim, Ismail
• Format: Final Project
• Language: Indonesia
• Subjects: Pertambangan dan operasi berkaitan
• Online Access: https://digilib.itb.ac.id/gdl/view/54679
• Institution: Institut Teknologi Bandung

Sandstone and carbonate are commonly used reservoir rock. Each of these rocks has different characteristics as reservoir rock. Sandstone contains silica that has negative charge while carbonate contains calcium that has positive charge. It means that sandstone and carbonate both need different wetting agents. Carbonic sandstone that is the combination of these two kinds of rock also has different characteristics. The difference in the composition of reservoir rocks affects the choice of surfactant that can treat the difference in rocks composition in the reservoir when the surfactant is injected to increase oil gain. Based on this fact, the writer conducts the study to determine the kind of non-ionic surfactant that can give maximum recovery factor with concentration variable to sandstone reservoir and carbonate reservoir in heavy oil case. This laboratory study consists of three main processes, which are the fabrication of sandstone and carbonate artificial core, spontaneous imbibition test, and contact angle test. In the fabrication of sandstone artificial core, the writer made an artificial sandstone reservoir by mixing quartz sand and cement with the composition of 50% of quartz sand and 50% of cement, and carbonate artificial core by mixing quartz sand, cement, and carbonate (calcite/CaCO3) with the composition of 40% of quartz sand, 30% of cement, and 30% of carbonate. Imbibition test was done by using five kinds of solution, which are formation water, surfactant F1.1, surfactant F5.X, surfactant F5.T, and surfactant G5.1.1. The surfactant solution that was used consisted of two variants of concentration, which are 1% and 2%. The formation water was also used in imbibition test to compare the test result. From this spontaneous imbibition experiment, it is concluded that surfactant F5.X with 2% concentration yield the biggest and fastest oil gain. Meanwhile the contact angle test from artificial core was performed to understand the wetness of each core to the oil of X field and surfactant solution.