Oil recovery from heavy oil resources has always been a challenging task. This work is aimed at investigating the recovery efficiency of polymer-augmented low salinity waterflooding in heavy oil reservoirs. The main recovery mechanism behind low salinity waterflooding is wettability alteration to more water-wet state. On the other hand, polymer flooding is performed to control fluids mobility and hence improve displacement efficiency. Combining both recovery methods is expected to add to recovery efficiency obtained by individual methods, and the aim of this work is to explore this experimentally. In this study, several laboratory experiments were conducted using Berea and Bentheimer sandstone cores starting with base runs of continuous secondary seawater and tertiary twice and 10 times diluted seawaterflooding (low salinity). Significant incremental oil recovery was obtained when flooded with low salinity water, and 10 times diluted seawater was determined to be used as low salinity water. Contact angle and Zeta potential measurements indicate wettability alteration due to clay detachment as the main recovery mechanism. Synergy of water secondary flooding and polymer tertiary flooding at different water salinity levels proved the efficiency of hybrid low salinity polymer flooding process in Berea sandstone. Low water salinity during secondary injection mode played a major role on ultimate recovery with less contribution to tertiary polymer slug injection. High salinity waterflooding provided lower secondary recovery leaving more residual oil for polymer slug to act on at that cycle. Smaller polymer slug of 0.1 pore volume was found to be sufficient in tertiary flooding with low salinity water but with slightly slower recovery rate. Bentheimer sandstones known for its low clay content were subjected to polymer-augmented waterflooding at high and low salinity levels. Close secondary and tertiary recoveries were obtained for the two salinity levels with slower recovery rate for low salinity run. Minute clay content and water-wet characteristic as determined by contact angle measurements may explain the lack of water salinity effect on recovery. The lack of salinity role and the two shock fronts with connate water bank in between known to exist during low salinity flooding may explain the slower recovery rate encountered. Comparison of both sandstones indicates that less ultimate recovery from Berea rocks, and this can be attributed to their initial intermediate wet state in contrast to the water-wet Bentheimer sandstone rocks.

Recovering oil from carbonate reservoirs by waterflooding is often ineffective due to the combination of ineffective sweep and the originally oil-wet nature of that rocks. Ionic liquid monomers and polymers have recently attracted attention as chemical agents for enhanced oil recovery. 2-acrylamido-2- methylpropane sulfonic acid copolymer with methacrylic acid (AMPSA/MAA) diluted in sea water at 3000 ppm was previously screened among other polyionic liquids (PILs) at different concentrations (Abdullah et. al, 2017) and proved to be the most effective enhanced oil recovery chemical. The PIL AMPSA/MAA was tested with sandstone and proved efficient on enhancing oil recovery. In this study, we extend the work to explore the efficiency of such PIL on carbonates. A post-secondary water flooding was conducted and an incremental tertiary recovery of 6% original oil in place (OOIP) corresponding to 12% residual oil in place (ROIP) was obtained indicating the efficiency of the AMPSA/MAA PIL. This carbonate recovery compares to 10% OOIP in sandstone as reported in previous study (Abdullah et. al, 2017). This difference can be attributed to the low permeability characterizing the carbonate sample used in this work in comparison to the sandstone tested earlier. Seawater-crude oil Interfacial tension and contact angle measurements on carbonate substrate were performed at elevated temperature and pressure to investigate the possible recovery mechanisms. Interfacial tension (IFT) resulted in insignificant IFT drop. On the other hand, contact angle measurements confirmed wettability alteration towards more water wet state indicating it as the main recovery mechanism in carbonates.

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