Wettability Alteration in Carbonate Reservoirs by Carbon Nanofluids

Abstract

Wetting phenomena play a significant role in oil recovery from complex carbonate reservoirs under harsh conditions. The potential to being able to alter the rock wettability from oil-wet to water- or neutral-wet is often considered the pre-requisite to a successful Enhanced Oil Recovery (EOR) process. Hence, there arises the importance of understanding the (static) wetting and (dynamic) wettability alteration of the reservoir rock when the rock comes in contact with injected modified brines, oilfield chemicals, and/or nanofluids. In this study, we investigate the effect of three Carbon nanodots in high salinity brines with and without surfactant on static wetting and dynamic wettability alteration of carbonate reservoirs. Outcrop Indiana limestone and reservoir crude oil samples were used in these tests. The contact angle of the rock-oil-brine system is measured as a function of the nanodot concentration, saturating fluid in the rock matrix and aging, surfactant concentration, temperature, pressure, and brine salinity. The upper limits for the values for temperature, pressure, and salinity are set to be representative of the Saudi Arabian harsh reservoir conditions. The use of Carbon nanofluids demonstrated a clear shift in both static and dynamic measurements towards a more favorable water-wet condition for EOR. Statically, the contact angle of an oil-saturated carbonate rock exhibited a change from a strongly oil-wet condition to slightly water wet (with more than 50 % drop in the contact angle value) in 200 ppm (0.02 wt/v%) solution of carbon nanodot (CND) in seawater (SW) over 24 hours. Dynamically, a smaller but still remarkable change (a shift in the order of 20 %) in the contact angle is noted for a sister rock sample over the same period when a solution at the same concentration of CND in SW is introduced to replace the SW base fluid. Nanofluid spreading experiments on oil-coated glass slides supported our dynamic wettability studies. The spreading efficiency of the Carbon nanofluid was analyzed using optical and confocal microscopy with a clear and remarkable oil dislodging effect. Zeta potential measurements of the different systems were made to aid in the interpretations. The combined mechanistic actions of the various factors, including reservoir environment, disjoining pressure, interfacial tension, capillary pressure alterations and nanodots interactions with the oil/water interface, contributed to this change in wettability. Our study supports a strong and favorable EOR impact of CND as an effective and economically viable additive to waterflood operations in carbonate reservoirs.