| dc.description.abstract | Water production is the primary obstacle for oil recovery with water injection from heterogeneous reservoirs with high-permeability streaks and fractures. The practical approach to solve the adverse effects of water flooding and better nanoparticle gel treatments intended for use as an ultimate objective of this research. Various concentrations of Laponite clay and HPAM interactions with different shut-in periods are simulated to examine the gel-forming.
Both laboratory experiments and simulations were carried out. First, three different gels were created by changing the concentration of gel components. Then, based on laboratory experiments and the literature, four different gel systems were acquired and used as the basis for the simulations.
The results showed that 2 % Laponite and 0.3 % HPAM interaction is a promising option for gel treatment. Gelation time was calculated for all cases, and it concluded that gelation time is high at low Laponite clay concentration. Gelation time should be less than the shut-in period; thus, gelation happens in the core plug. According to this research, gel treatment with a concentration of 2 % clay and 0.3 % polymer showed promise results of increasing oil recovery.
Laponite-HPAM interaction in fractured core plugs can be simulated using IORCoreSim. It concluded that the shut-in period should be more than gelation time to form a gel.
De-ionized water was used as the base for gel components in this thesis, and the further test could be carried out to see the effectiveness of seawater for gel-forming. | |
