## Materials and Methods  
The composition of the formation brine characteristic from a Pre-salt field is displayed in Table 1. Brine samples were prepared by dissolution of salts (Sigma Aldrich, St. Louis, MO, USA, purity over 99.9%) in deionized water. In addition, CO\({}_{2}\)-saturated fluids were produced by injecting the required mass of CO\({}_{2}\) (Praxair, Sao Paulo, Brazil, 99.9% purity) in oil or brine in a high-pressure Hastelloy cell. Table 2 shows the main properties of the dead oil sample for crude oil used in this work. SARA (saturates, aromatics, resins, and asphaltenes) analysis was performed by the IP 143 n-heptane precipitation method (asphaltenes) and medium-pressure liquid chromatography (saturates, resins, and aromatics). Besides, the total acid number (TAN) and total base number (TBN) were calculated using the American Society for Testing and Materials (ASTM) D664 procedures. A full characterization of this Pre-salt oil is presented elsewhere [43]. Moreover, the rock material used in this work was a carbonate rock from Morro do Chaves Formation, Sergipe-Alagoas Basin. The Morro do Chaves Formation is located in the Northeast region of Brazil. This Formation is composed of coquinas and shales [44]. Coquina is a carbonate rock composed of cemented shell debris and sediments. The shells and shell debris were mechanically sorted and were deposited by a transport agent [45; 46]. The studied rock was collected from an outcrop at the Atol quarry, located in Alagoas state in Brazil. This outcrop has been geologically well-studied and -classified in the literature [47; 48; 49; 50; 51]. The coquina from this region of Morro do Chaves Formation is composed mainly of whole and fragmented bivalve shells, with a low occurrence of ostracods, and gastropods. The rock matrix is composed of siliciclastic components [48; 50]. The pore system of the coquinas from Morro do Chaves Formation was strongly influenced by the diagenetic process, which affected the connectivity of the pores, having a significant influence on \begin{table}
\begin{tabular}{c c} \hline
**Ions** & **Concentration [mg/L]** \\ \hline Na\({}^{+}\) & 57,580 \\ Ca\({}^{2+}\) & 24,250 \\ Mg\({}^{2+}\) & 2120 \\ K\({}^{+}\) & 1200 \\ Ba\({}^{2+}\) & 24 \\ Sr\({}^{2+}\) & 1260 \\ SO\({}_{4}\)\({}^{2-}\) & 54 \\ Cl\({}^{+}\) & 139,900 \\ \hline TDS & 226,388 \\ \hline \end{tabular}
\end{table} 
Table 1: Formation brine composition and total dissolved solids (TDS). \begin{table}
\begin{tabular}{c c} \hline
**Crude Oil Properties** & \\ \hline Saturates (wt.\%) & 64.06 \\ Aromatics (wt.\%) & 25.98 \\ Resins (wt.\%) & 8.46 \\ Asphaltenes (wt.\%) & 1.50 \\ Total Acid Number (mg KOH/g) & 0.37 \\ Total Base Number (mg KOH/g) & 4.00 \\ \hline \end{tabular}
\end{table} 
Table 2: Crude oil characterization. permeability but low impact on porosity [48; 49]. Previous works [51; 52] studied the pore geometry and highlighted the irregularity of pore shapes and sizes. Coquinas can have unimodal or bimodal pore size distribution systems. Pores can vary from micro to meso-pores within the same sample. In addition, there is no linearity in the relation between porosity and permeability of the coquinas from this formation [52]. This heterogeneity makes coquinas challenging rocks for both experimental analysis and computational simulation. The coquina sample was 3.6 cm in length and 3.5 cm in diameter. The sample was cleaned with methanol and toluene to remove any residual oil or salt that could have been in its porous system. After the sample was cleaned and dried, it was characterized by geological petrographic description, routine petrophysics, microCT, and nuclear magnetic resonance (NMR). The geological characterization was done with a rock thin section with dimensions of \(7.0\text{ cm}\times 4.5\text{ cm}\) and a thickness of 30 microns. This analysis was done with a Zeiss Axioskop 40 microscope. The routine petrophysics was done using the Advanced Automated Porosimeter-Permeameter DV-4000, from CSL Capital Management, L.P (Houston, TX, USA).