On the prediction of gas solubility in brine solutions with single or mixed salts: Applications to gas injection and CO2 capture/sequestration

Ratnakar, Ram R.; Venkatraman, Ashwin; Kalra, Amrit; Dindoruk, Birol

doi:10.1016/j.jngse.2020.103450

Cited by 21 publications

(5 citation statements)

References 29 publications

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“…In order to make the SW model capable of predicting the solubility of CO 2 in real brines (mixed salt systems), correlations (Duhring lines) between the molality of the salts (CaCl 2 and KCl) and their NaCl equivalents were developed in this work. This was undertaken by an iterative (Newton-Raphson) approach of finding equal CO 2 solubilities in the different salts considering NaCl as reference salt (Markham and Kobe 1941 [76], Ratnakar et al, 2020 [77]). The data resulting from the search for equal solubilities have been correlated in the following equations (Equations ( 19) and ( 20)) to make the conversion from salt molality to NaCl equivalent molality straightforward.…”

Section: Resultsmentioning

confidence: 99%

Thermodynamic Modeling of Mutual Solubilities in Gas-Laden Brines Systems Containing CO2, CH4, N2, O2, H2, H2O, NaCl, CaCl2, and KCl: Application to Degassing in Geothermal Processes

et al. 2021

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With the growing interest in geothermal energy as a renewable and sustainable energy source, nowadays engineers and researchers are facing technological and environmental challenges during geothermal wells’ operation or energy recovery improvement by optimizing surface installations. One of the major problems encountered is the degassing of geothermal brines which are often loaded with dissolved gases, resulting in technical problems (scale formation, corrosion, reduced process efficiency, etc.) and environmental problems through the possible emission of greenhouse gases (CO2, CH4 and water vapor) into the atmosphere. In this work, a method to predict, from readily available information such as temperature and GLR, the bubble point pressure of geothermal fluids as well as the GHG emission rate depending on the surface conditions is presented. This method is based on an extended version of the Soreide and Whitson model with new parameters optimized on the solubility data of several gases (CO2, CH4, N2, O2 and H2) in brine (NaCl + CaCl2 + KCl). The developed approach has been successfully used for the prediction of water content of different gases and their solubilities in different types of brines over a wide temperature and pressure range, and has been applied for the prediction of bubble point pressure and GHG emissions by comparing the results with available industrial data of geothermal power plants including the Upper Rhine Graben sites.

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Section: Resultsmentioning

confidence: 99%

Thermodynamic Modeling of Mutual Solubilities in Gas-Laden Brines Systems Containing CO2, CH4, N2, O2, H2, H2O, NaCl, CaCl2, and KCl: Application to Degassing in Geothermal Processes

et al. 2021

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“…The rate of dissolution of CO 2 is therefore a critical parameter for effective CO 2 storage. Yan et al (2011), Ratnakar et al (2020) and Mohammadian et al (2015) provided solubility data of CO 2 in brine. It was seen that the solubility of CO 2 in brine depends on the temperature, pressure and molality of the brine.…”

Section: Introductionmentioning

confidence: 99%

Effect of CO2 Phase on Pore Geometry of Saline Reservoir Rock

et al. 2022

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The phase of CO2 present in a saline reservoir influences the change of the pore geometry properties of reservoir rocks and consequently the transport and storage integrity of the reservoir. In this study, digital rock physics was used to evaluate pore geometry properties of rocks saturated with the different phaseCO2-brine under reservoir conditions. The changes in the pore geometry properties due to the different phaseCO2-brine-rock interaction were quantified. In addition to compression, CO2-brine-rock interaction caused a further reduction in porosity by precipitation. Compared to the dry sample, the porosity of the gaseous CO2-br sample was reduced the most, and was lower by 15% after saturation and compression. There was reduction in the pre-compression porosity after compression for all the samples, however, the reduction was highest in the gaseous CO2-br-saturated sample (13%). The flatness of pore surfaces was reduced, and pores became less rounded after compression, especially in supercritical CO2-br-saturated rock. The results from this research provide a valuable input to guide a robust simulation of CO2 storage in reservoir rocks where different phases of CO2 could be present.

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“…Duan's model [122] was found to be broadly satisfactory for measuring the solubility of CO 2 in NaCl (aq) but performed poorly for assessing the solubility of CO 2 in KCl (aq). Ratnakar et al [123] developed a method that uses an ionic strength-based mixing rule and extended the well-known Setschenow relation to capture the impact of a mixture of salts containing mono-or multivalent ions to predict the gas solubility in brine solutions with single or mixed salts. Then, Zhao et al [124] used the Setschenow coefficient of ions to calculate the solubility of CO 2 in mixed salt solutions.…”

Section: The Mutual Solubility Between Co 2 and Water/brinementioning

confidence: 99%

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

Mutailipu,

Xue,

et al. 2023

Energies

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Emission reduction in the main greenhouse gas, CO2, can be achieved efficiently via CO2 geological storage and utilization (CCUS) methods such as the CO2 enhanced oil/water/gas recovery technique, which is considered to be an important strategic technology for the low-carbon development of China’s coal-based energy system. During the CCUS, the thermodynamic properties of the CO2–water–rock system, such as the interfacial tension (IFT) and wettability of the caprock, determine the injectability, sealing capacity, and safety of this scheme. Thus, researchers have been conducting laboratory experiments and modeling work on the interfacial tension between CO2 and the water/brine, wettability of caprocks, the solubility of gas–liquid binary systems, and the pH of CO2-saturated brine under reservoir temperature and pressure conditions. In this study, the literature related to the thermodynamic properties of the CO2–water–rock system is reviewed, and the main findings of previous studies are listed and discussed thoroughly. It is concluded that limited research is available on the pH of gas-saturated aqueous solutions under CO2 saline aquifer storage conditions, and less emphasis has been given to the wettability of the CO2–water/brine–rock system. Thus, further laboratory and modeling research on the wettability alternations of caprock in terms of molecular dynamics is required to simulate this phenomenon at the molecular level. Moreover, simplified IFT and solubility prediction models with thermodynamic significance and high integrity need to be developed. Furthermore, interaction mechanisms coupling with multi-factors associated with the gas–liquid–solid interface properties and the dissolution and acidification process need to be explored in future work.

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On the prediction of gas solubility in brine solutions with single or mixed salts: Applications to gas injection and CO2 capture/sequestration

Cited by 21 publications

References 29 publications

Thermodynamic Modeling of Mutual Solubilities in Gas-Laden Brines Systems Containing CO2, CH4, N2, O2, H2, H2O, NaCl, CaCl2, and KCl: Application to Degassing in Geothermal Processes

Thermodynamic Modeling of Mutual Solubilities in Gas-Laden Brines Systems Containing CO2, CH4, N2, O2, H2, H2O, NaCl, CaCl2, and KCl: Application to Degassing in Geothermal Processes

Effect of CO2 Phase on Pore Geometry of Saline Reservoir Rock

Thermodynamic Properties of a Gas–Liquid–Solid System during the CO2 Geological Storage and Utilization Process: A Review

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