Smart waterflooding is one of the most practical emerging
methods
of enhanced oil recovery in carbonate reservoirs. In this study, the
effect of salt type and its concentration in smart water on oil recovery
from a carbonate reservoir rock is investigated. A series of experimental
measurements, including zeta potential (ZP), interfacial tension (IFT),
and contact angle (CA), were conducted to examine the effect of ions
on the oil/brine/rock interaction. IFT, ZP, and CA were also used
as screening methods to select effective solutions for flooding experiments.
The results of the study show that synthesized brines containing sodium
acetate and potassium acetate salts have a significant effect on the
reduction of IFT; however, rock surface wettability due to such brines
is insignificant. The presence of organic salts in the injected water
can alter the properties of the fluid and rock surface, leading to
improved oil recovery. The salts can reduce the interfacial tension
between the oil and water phases, making it easier for the water to
displace and mobilize trapped oil. This effect is particularly beneficial
in reservoirs with high oil–water interfacial tension as it
enhances the capillary forces and improves the sweep efficiency. Smart
water with sodium acetate (MSW.NaOAc) caused a 7% increase in oil
production in the tertiary injection process due to IFT and CA reduction.
The secondary injection of MSW.NaOAc led to an oil production efficiency
of 76%, which is 10% higher than that of the secondary injection of
seawater (SW), confirming the effectiveness of acetate ions in enhancing
oil recovery. Doubling the concentration of sulfate ions in modified
SW (MSW.NaOAc.2S) caused a 19% increase in oil production in tertiary
injections after SW flooding. The secondary injection of MSW.NaOAc.2S
produced a 13% increase in the recovery factor compared to SW flooding
in the secondary mode. The main driving mechanism for oil mobilization
was found to be wettability alteration, which is supported by the
analyses of CA and ZP. This study confirms that the salt type and
concentration present in a brine solution play a vital role in the
movement of trapped oil in carbonate reservoirs.