Analysis of oil recovery by spontaneous imbibition of surfactant solution

Analysis of Oil Recovery by Spontaneous Imbibition of Surfactant Solution -Depending on rock and oil type, lowered interfacial tension (IFT) by the addition of surfactant to brine may contribute to capillary imbibition recovery with the support of gravity drainage in naturally fractured reservoirs (NFR). This paper aims at identifving and analyzing the recovery mechanisms and performing up-scaling exercises for oil recovery from different rock types by the capillary (spontaneous) imbibition of surfactant solution. Laboratoty tests were performed using four different rock types that could possibly be the reservoir rock matrix of the NFRs (sandstone, limestone, dolomitic limestone and chalk). The sandstone sample was surface-coated to create a boundary condition causing only counter-current interaction. Wide variety of oils (light and heavy-crude oils, kerosene, and engine oil) was selected as the oleic Phase. Diffierent types (non-ionic and anionic) and concentrations of surfactants were used as the aqueous phase as well as the brine as a base case. The samples fully saturated with oil (S-wi = 0) were exposed to static capillary imbibition and the recover was monitored against time. Some experiments on the chalks were repeated using pre-wet samples (S-wi > 0) to clarify the changes in the capillary imbibition characteristics of the rock. The changes (positive or negative) in the recovery rate and ultimate recovery compared to the brine imbibition were evaluated for the rock, stufactant and oil types. It was observed for some rock samples, that the imbibition recovery by surfactant solution was strictly controlled by the concentration of the surfactant. The difference in the recovery rate and ultimate recovery between high and low IFT could be due not only to change in the IFT but also the change in the ivettability and adsorption, which might vary with the rock type. This was also analyzed using the shape of the curves that indicates the strength of the capillarity on the recovery and the interaction type, i.e., co- or counter-current. In addition to the above-mentioned qualitative analysis, the recovery curves were evaluated for up-scaling. Existing dimensionless scaling groups were tested. The scaling exercise helped identify whether the recovery is driven by gravity or capillary forces and clarify the interaction type, i.e., co-or countercurrent or both. The ultimate recoveries were correlated to the Inverse Bond Number using twenty-five cases covering different combinations of four rock types,four oil and four surfactant samples.