## 1 Introduction  
CO\({}_{2}\) emissions from the combustion of fuels and their impact on the environment are among the greatest global concerns of our time. Maintaining continuous economic growth while reducing emissions has been a challenging goal for decades [1]. Carbon capture and storage (CCS) is critical to achieve the target of 26 Gton of CO\({}_{2}\) per year by 2030 [2]. Within this context, CCS has been raising well-deserved attention in recent years. According to a recent publication [3], CCS may account for up to 33% of the total carbon abatement by 2050. With the current global emissions of the order of 42 Gton of CO\({}_{2}\) per year, it is evident that research efforts to develop and deploy CCS technologies are a priority nowadays [4]. Different separation and storage processes have been used to reduce CO\({}_{2}\) emissions. A recently published review analyzed the state-of-the-art of the different CO\({}_{2}\) capture, storage, and utilization methods [5]. Capture can take place before (pre-combustion) or post-combustion. Pre-combustion methods consist of removing CO\({}_{2}\) from a stream rich in this gas prior to the combustion reaction. For example, low-temperature phase separation has been used to energy- and cost-efficiently remove CO\({}_{2}\) from pressurized syngas [6]. On the other hand, post-combustion methods are based on absorption, adsorption, or membranes. Chemical absorption with different solvents (mainly amine solutions) is a well-known process that is widely used in natural gas processing [7]. A recent study reviewed the status of different solvents for chemical absorption CCS at the industrial scale [8]. Moreover, adsorption of CO\({}_{2}\) in solid materials has been used for around 30 years [9]. The use of traditional adsorbents (such as alumina and zeolites) and newer structures (such as metal-organic frameworks and polymers) was reviewed elsewhere [10; 11; 12; 13; 14; 15]. Finally, the use of organic and inorganic membranes has been implemented for gas separation in both pre- and post-combustion processes [9; 16; 17; 18; 19]. After capture, CO\({}_{2}\) is injected in geological formations where it should be safely stored for at least 10,000 years [5]. According to [PERSON] et al. [9], enhanced oil recovery (EOR) [2] and injection in saline formations [20] are the only storage methods with ongoing onshore and offshore projects at the commercial scale. By contrast, other storage methods, such as injection in depleted locations [21], ocean storage [22], and mineralization [23], are promising alternatives still in the development stage. Furthermore, [PERSON] et al. [5] discussed other alternatives including enhanced gas recovery [24], enhanced coalbed methane recovery [25], and applications in shale formations [26]. CO\({}_{2}\) injection, a mature EOR method, can incrementally improve oil recovery from 5 to 20% of the original oil in place mainly through mechanisms such as viscosity reduction, oil swelling, and miscible displacement [27]. CO\({}_{2}\)-EOR accounts for an additional oil production of around 300,000 bbl per day [9]. Furthermore, the over 13 large-scale CO\({}_{2}\)-EOR projects active in 2018 represented a capture capacity of 26 Mtpa, and the number of active projects is expected to increase during the next several years [28]. Carbonated water injection (CWI) is an alternative CO\({}_{2}\)-EOR method that consists of injecting CO\({}_{2}\) dissolved in the injection water [29]. As carbonated brine has a higher viscosity than CO\({}_{2}\), CWI presents a more favorable mobility ratio that results in a greater sweeping efficiency compared to CO\({}_{2}\) injection [30]. In addition, the dissolution of CO\({}_{2}\) reduces the pH of the aqueous phase due to the formation of carbonic acid, and this reduction plays an important role in oil-brine-rock interactions. CO\({}_{2}\) dissolution was reported to shift the wettability of carbonate rocks toward more water-wet [31; 32; 33; 34; 35].