## 1 Introduction  
The use of fossil fuels as the dominant energy source in today's energy mix has raised concerns about the impact of human-generated CO\({}_{2}\) emissions on global warming. If not addressed, these concerns could lead to irreversible consequences. Carbon Capture and Storage (CCS) has emerged as a potential solution to mitigate these concerns [1]. The ideal scenario for CO\({}_{2}\) sequestration would involve a large storage area and effective trapping mechanisms to prevent the migration of injected CO\({}_{2}\) back to the surface. This approach should also be cost effective and have minimal environmental impacts [2]. Numerical simulation is commonly used to study the CO\({}_{2}\) storage process in porous media as it can model various trapping mechanisms and estimate the capacity of subsurface CO\({}_{2}\) retention. The numerical simulation models can accurately capture the various complex physicochemical phenomena, including the effects of multiphase flow, rock-fluid interactions, CO2 solubility and diffusion in water, relative permeabilities, capillary pressure hysteresis, mineralization, and acidic reactions, all of which are crucial for CO2 trapping in porous media during CCS simulation. The rates of geochemical reactions play a crucial role in the dissolution and mineralization of injected CO2, which is essential to permanently trap the CO2 and reduce the chances of leakage into the atmosphere. These reactions can occur shortly after injection and persist over time scales ranging from hundreds to thousands of years [3,4]. In order to ensure the long-term environmental sustainability of a CCS project, it is mandatory to have a comprehensive understanding of the rates and mechanisms of key geochemical reactions and their impacts on the performance of CO2 storage and petrophysical properties of the reservoir. The absence of in situ conditions in laboratory experiments, specifically the lack of pore structure contributions, as seen in real storage projects, also contributes to potential inaccuracies when measuring the kinetic parameters of mineral reactions. Overall, predicting in situ reaction rates remains highly complex [5, 6, 7, 8, 9] and has prompted researchers to use proxy [10,11] and batch models [12] or analytical approaches [13] to evaluate the geochemical impact. In the realm of geochemical models coupled with flow models in porous media, the Transition State Theory (TST) [14] is frequently employed to simulate CO2 mineralization [15, 16, 17, 18, 19, 20, 21, 22]. However, the impact of kinetic parameters of TST on simulation outcomes has not been sufficiently researched, particularly when considering the potential influence of lithology on carbonate mineral dissolution and mineralization associated with CO2 injection. Limited research has been conducted on the role of lithology in CO2 storage, likely due to insufficient data related to mineral reactions for CO2 sequestration. The data scarcity complicates the numerical assessment of sequestration and increases uncertainty [1,12]. The evaluation of the uncertainty involved is crucial for developing and implementing effective CCS strategies in geological formations that are not typically prioritized for carbon storage, such as carbonate rocks. Therefore, this study aims to contribute to the understanding of carbonate reactions during CO2 injection using robust reactive-transport models based on the reported geochemical data and on the TST geochemical model. Consequently, gaining a deeper understanding of the factors that influence carbonate reactions will facilitate the identification of appropriate storage targets based on rock mineralogy and key kinetic parameters. The proxy model and the workflow presented here will help optimize decision parameters (e.g., injection rate) based on uncertain parameters (e.g., rock mineralogy).