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A Simulation Study on Evaluating the Influence of Impurities on Hydrogen Production in Geological Carbon Dioxide Storage

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  • Seungmo Ko

    (Department of Energy and Mineral Resources Engineering, Kangwon National University, Samcheok 25913, Republic of Korea)

  • Sung-Min Kim

    (Department of Energy Resources and Chemical Engineering, Kangwon National University, Samcheok 25913, Republic of Korea)

  • Hochang Jang

    (Department of Energy Resources and Chemical Engineering, Kangwon National University, Samcheok 25913, Republic of Korea)

Abstract

In this study, we examined the effect of CO 2 injection into deep saline aquifers, considering impurities present in blue hydrogen production. A fluid model was designed for reservoir conditions with impurity concentrations of 3.5 and 20%. The results showed that methane caused density decreases of 95.16 and 76.16% at 3.5 and 20%, respectively, whereas H 2 S caused decreases of 99.56 and 98.77%, respectively. Viscosity decreased from 0.045 to 0.037 cp with increasing methane content up to 20%; however, H 2 S did not affect the viscosity. Notably, CO 2 with H 2 S impacted these properties less than methane. Our simulation model was based on the Gorae-V properties and simulated injections for 10 years, followed by 100 years of monitoring. Compared with the pure CO 2 injection, methane reached its maximum pressure after eight years and eleven months at 3.5% and eight years at 20%, whereas H 2 S reached maximum pressure after nine years and two months and nine years and six months, respectively. These timings affected the amount of CO 2 injected. With methane as an impurity, injection efficiency decreased up to 73.16%, whereas with H 2 S, it decreased up to 81.99% with increasing impurity concentration. The efficiency of CO 2 storage in the dissolution and residual traps was analyzed to examine the impact of impurities. The residual trap efficiency consistently decreased with methane but increased with H 2 S. At 20% concentration, the methane trap exhibited higher efficiency at the end of injection; however, H 2 S had a higher efficiency at the monitoring endpoint. In carbon capture and storage projects, methane impurities require removal, whereas H 2 S may not necessitate desulfurization due to its minimal impact on CO 2 storage efficiency. Thus, the application of carbon capture and storage (CCS) to CO 2 emissions containing H 2 S as an impurity may enable economically viable operations by reducing additional costs.

Suggested Citation

  • Seungmo Ko & Sung-Min Kim & Hochang Jang, 2023. "A Simulation Study on Evaluating the Influence of Impurities on Hydrogen Production in Geological Carbon Dioxide Storage," Sustainability, MDPI, vol. 15(18), pages 1-19, September.
    • Handle: RePEc:gam:jsusta:v:15:y:2023:i:18:p:13620-:d:1238163
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    References listed on IDEAS

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    1. Wang, Zhiyu & Wang, Jinsheng & Lan, Christopher & He, Ian & Ko, Vivien & Ryan, David & Wigston, Andrew, 2016. "A study on the impact of SO2 on CO2 injectivity for CO2 storage in a Canadian saline aquifer," Applied Energy, Elsevier, vol. 184(C), pages 329-336.
    2. Li, Didi & He, Yao & Zhang, Hongcheng & Xu, Wenbin & Jiang, Xi, 2017. "A numerical study of the impurity effects on CO2 geological storage in layered formation," Applied Energy, Elsevier, vol. 199(C), pages 107-120.
    3. Kim, Youngmin & Jang, Hochang & Kim, Junggyun & Lee, Jeonghwan, 2017. "Prediction of storage efficiency on CO2 sequestration in deep saline aquifers using artificial neural network," Applied Energy, Elsevier, vol. 185(P1), pages 916-928.
    4. Wiesław Szott & Piotr Łętkowski & Andrzej Gołąbek & Krzysztof Miłek, 2020. "Modelling of the Long-Term Acid Gas Sequestration and Its Prediction: A Unique Case Study," Energies, MDPI, vol. 13(18), pages 1-24, September.
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