| Abstrakt: |
There can be too much formation water produced on the surface. When it happens, a company must find the best solution because formation water is dangerous for the environment. One of the solutions is to re-inject water into the reservoir. Before that, there are several things that need to be considered, which are identification of characteristics of rocks and compatibility of injection water against the rocks. This is completed in order to make the injection process successful and does not cause a problem in rock formation. This identification can be done with return permeability test that involves the core and the injection fluids. This case used two core samples, synthetic oil with 6.0827 cp of viscosities, and two salinity variations of water injections with 13,996.69 ppm and 50,000 ppm. The oil permeability of the core that was injected by water with 13,996.69 ppm decreased by 8.46%, while other cores that were injected by water with 50,000 ppm only decreased by 2,55 %. It means that the injection that used high salinity water can make the clay less reactive, and then the permeability will drop slowly. [ABSTRACT FROM AUTHOR] |
