Effect of brine salinity on the geological sequestration of CO₂ in a deep saline carbonate formation

Abstract

When supercritical CO2 is injected into a deep saline aquifer, the salinity of the brine can influence both the solubility of the injected CO2 in the brine and the subsequent aqueous geochemical reactions that occur. The objective of this study is to assess the effect of brine salinity on CO2 storage in deep saline carbonate formations. Specifically, the study aims to quantitatively assess the effect of brine salinity on (a) the amount of CO2 that can be sequestered in the aqueous phase, (b) the storage efficiency of the repository, (c) the change in pH of the residual brine after dissolution of CO2, and (d) changes in the mineralogy and porosity of the rock matrix that result from mineral dissolution and precipitation reactions induced by CO2 injection. Injection of CO2 into a model layered carbonate formation was simulated using the reactive‐transport code TOUGHREACT 3.3. The simulations consisted of 50 years of injection into a partially completed injection well, followed by 50 years of equilibration (no injection). Salinity of the brine was varied between 1% and 15% to determine the effects of salinity. Because the solubility of CO2 decreases as the salinity of the brine increases, an increase in brine salinity from 1% to 15% resulted in a 19% decrease in storage efficiency and a 25% decrease in the mass of CO2 dissolved in the aqueous phase. However, despite the strong effect of brine salinity on CO2 dissolution, there was almost no effect of salinity on the pH change in the residual brine: the chemical activity coefficient of the dissolved CO2 increases with brine salinity, counteracting the effects of decreased solubility. Consequently, brine salinity had little effect on mineral dissolution or precipitation, or on changes in formation porosity. The study therefore helps to choose sequestration sites depending upon the salinity of the brine: lower salinity results in more solubility trapping and better storage efficiency without noticeable differences in pH drop or mineral dissolution. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd.

Advancements, Challenges, and Perspectives of Flue Gas Injection in Subsurface Formations: A Comprehensive Review

“…These aspects have been the subject of recent research investigations. For instance, Kumar’s study highlights that the coinjection of contaminant gases alongside CO 2 in the repository can have a notable influence on the geochemical processes at play . Furthermore, significant carbonate precipitation near the injection well can lead to a decrease in both porosity and permeability after a certain period …”

Influence of Caprock Morphology on Solubility Trapping during CO2 Geological Sequestration

“…In the gas reservoir, even at higher salinity of 10% weight percentage of NaCl, the trapped efficiency of solubility trapping was observed 63% [26]. In Kumar et al's [27] simulation analysis carried out in carbonate formation, an increase in salinity has no impact on the pH variation and has a meagre influence on mineral trapping [27]. In a study conducted by Zhao et al [28], the microbial-mediated process improved solubility trapping.…”

Physico-chemical and dielectric parameters for the monitoring of carbon sequestration in basalt and silica media

“…The major trapping mechanisms that take place during CO2 sequestration in saline aquifers are structural, residual, solubility and mineral trapping (Rabiu et al, 2017a;Metz et al, 2015). Previous studies have shown that salinity has a significant influence on CO2 trapping mechanisms (Al-Khdheeawi et al, 2017;Kumar et al, 2020). For example, lower salinity enhances residual and solubility trapping significantly and prevents the free mobility of CO2 in the aquifer.…”