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Advanced Technologies for Carbon Capture, Utilization, and Storage (CCUS)
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Advanced Technologies for Carbon Capture, Utilization, and Storage (CCUS)

A special issue of Applied Sciences (ISSN 2076-3417). This special issue belongs to the section "Environmental Sciences".

Deadline for manuscript submissions: closed (31 December 2022) | Viewed by 11254

Special Issue Editors

Prof. Dr. Kun Sang Lee

E-Mail Website
Guest Editor
Department of Earth Resources and Environmental Engineering, Hanyang University, Seoul 04763, Republic of Korea
Interests: reservoir simulation; enhanced oil recovery; shale reservoir; CO2 storage
Special Issues, Collections and Topics in MDPI journals
Prof. Dr. Jihoon Wang

E-Mail Website
Guest Editor
Department of Earth Resources and Environmental Engineering, Hanyang University, 222 Wangsimni-ro, Seoul, Korea
Interests: rock mechanics; geomechanics; petrophysics; reservoir characterization; reservoir engineering

Special Issue Information

Dear Colleagues,

Carbon capture and storage (CCS) has become well-known as a technology for reducing the emission of greenhouse gases from fossil fuels during power generation and industrial processes. The main drawback of CO2 storage in an aquifer is lack of commercial value, so it is necessary to consider utilization of cost-effective options for the reduction of CO2 emissions. For example, CO2-enhanced oil recovery (EOR) could be one of those options. As part of the carbon capture, utilization, and storage (CCUS) processes, CO2 EOR can propose commercial opportunities for oil producers and ensure the geological storage of large quantities of CO2 that can consider energy security and environment simultaneously. The global hydrogen generation market is also increasing, and lots of countries are implementing policies to transition to a hydrogen economy due to environmental issues. Because of its economic feasibility, 98% of worldwide hydrogen demand was supplied by a fossil fuel production method, grey and blue hydrogen in 2019. However, the grey hydrogen system cannot consider climate change because the CO2 generated after hydrogen production is released into the air directly. Therefore, because of economic and environmental issues, blue hydrogen technology is getting the most attention. To complete a successful blue hydrogen system, CCUS technology is essential because we can store CO2, which is a secondary product of hydrogen.

The issue covers all experiments or simulation studies related to CCUS technology, such as carbon capture, transportation, fluid modeling, reservoir simulation, mineralization, artificial intelligence, blue hydrogen, etc.

Prof. Dr. Kun Sang Lee
Prof. Dr. Jihoon Wang
Guest Editors

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Keywords

  • carbon capture, utilization, and storage (CCUS)
  • blue hydrogen
  • CO2 enhanced oil recovery (EOR)
  • data science
  • economic feasibility

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Published Papers (4 papers)

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Research

9 pages, 2618 KiB  
Article
CO2 Adsorption Reactions of Synthetic Calcium Aluminum Ferrite (CAF)
by Woong-Geol Lee and Myong-Shin Song
Appl. Sci. 2022, 12(13), 6677; https://doi.org/10.3390/app12136677 - 1 Jul 2022
Cited by 3 | Viewed by 1678
Abstract
In this study, we investigated a mechanism of carbonation reaction by CO2 capture through synthesis of ternary (CaO-Al2O3-Fe2O3) compounds. As for the composition of the sintered calcium aluminum ferrite (SCAF), the proportions of CF-based [...] Read more.
In this study, we investigated a mechanism of carbonation reaction by CO2 capture through synthesis of ternary (CaO-Al2O3-Fe2O3) compounds. As for the composition of the sintered calcium aluminum ferrite (SCAF), the proportions of CF-based product and CA-based product were high, at 87.3% and 64.6%, at sintering temperatures of 1000 °C and 1100 °C, respectively. In addition, in the process of both dry and wet carbonation, the carbonation reaction occurred in the synthetic SCAF regardless of the sintering temperature conditions. In particular, in the carbonation with the wet method, CAH and CAFH, which are hydrates, were produced in up to 1 h of the reaction time with CO2, but from 3 h of reaction time, carbo compounds such as calcium carbo aluminate and calcium carbo alumino-ferrite compounds were produced. That is, with increasing reaction time, the carbo reaction becomes more active in the process. Therefore, SCAF synthesized in this study easily produced carbo compounds through carbonation reactions and formed carbonates by reaction with CO2. Thus, it is expected that the compounds can be effectively utilized as an excellent material for CO2 capture capable of CO2 absorption and fixation. Full article
(This article belongs to the Special Issue Advanced Technologies for Carbon Capture, Utilization, and Storage (CCUS))
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9 pages, 2675 KiB  
Article
CO2 Sorption and Regeneration Properties of K2CO3/Al2O3-Based Sorbent at High Pressure and Moderate Temperature
by Do-Yeong Ryu, Seongbin Jo, Tae-Young Kim, Soo-Yeong In, Jin-Hyeok Woo, Jong-Heon Lee, Ho-Jin Chae, Jae-Kuk Kim, Jae-Eun Hwang, Jae-Chang Kim and Soo-Chool Lee
Appl. Sci. 2022, 12(6), 2989; https://doi.org/10.3390/app12062989 - 15 Mar 2022
Cited by 3 | Viewed by 2481
Abstract
In this study, the CO2 sorption mechanisms and regeneration properties of alumina-based sorbent using K2CO3 loading under high-pressure and moderate temperature conditions were examined. To investigate the mechanism of CO2 sorption, a zirconium-based sorbent was compared with an [...] Read more.
In this study, the CO2 sorption mechanisms and regeneration properties of alumina-based sorbent using K2CO3 loading under high-pressure and moderate temperature conditions were examined. To investigate the mechanism of CO2 sorption, a zirconium-based sorbent was compared with an alumina-based sorbent. The CO2 capture capacities of the PAI10, 20, 30, and 40 were 32.3, 63.0, 95.4, and 124.5 mg CO2/g sorbent, respectively. To investigate the CO2 sorption mechanism of an alumina-based sorbent, we performed XRD, TG/DTG, and FTIR analyses after CO2 sorption in the presence of 10 vol% CO2 and H2O each at 200 °C and 20 atm. For PAI10–40 sorbents, KHCO3 and KAl(CO3)(OH)2 phases were observed by TG/DTG and FTIR analysis. For PAI-x sorbents, it was confirmed that the captured CO2 is desorbed completely at a temperature below 400 °C at 20 atm. Full article
(This article belongs to the Special Issue Advanced Technologies for Carbon Capture, Utilization, and Storage (CCUS))
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14 pages, 22021 KiB  
Article
Compositional Modeling of Impure CO2 Injection for Enhanced Oil Recovery and CO2 Storage
by Hye-Seung Lee, Jinhyung Cho, Young-Woo Lee and Kun-Sang Lee
Appl. Sci. 2021, 11(17), 7907; https://doi.org/10.3390/app11177907 - 27 Aug 2021
Cited by 8 | Viewed by 3012
Abstract
Injecting CO2, a greenhouse gas, into the reservoir could be beneficial economically, by extracting remaining oil, and environmentally, by storing CO2 in the reservoir. CO2 captured from various sources always contains various impurities that affect the gas–oil system in [...] Read more.
Injecting CO2, a greenhouse gas, into the reservoir could be beneficial economically, by extracting remaining oil, and environmentally, by storing CO2 in the reservoir. CO2 captured from various sources always contains various impurities that affect the gas–oil system in the reservoir, changing oil productivity and CO2 geological storage performance. Therefore, it is necessary to examine the effect of impurities on both enhanced oil recovery (EOR) and carbon capture and storage (CCS) performance. For Canada Weyburn W3 fluid, a 2D compositional simulation of water-alternating-gas (WAG) injection was conducted to analyze the effect of impure CO2 on EOR and CCS performance. Most components in the CO2 stream such as CH4, H2, N2, O2, and Ar can unfavorably increase the MMP between the oil and gas mixture, while H2S decreased the MMP. MMP changed according to the type and concentration of impurity in the CO2 stream. Impurities in the CO2 stream also decreased both sweep efficiency and displacement efficiency, increased the IFT between gas and reservoir fluid, and hindered oil density reduction. The viscous gravity number increased by 59.6%, resulting in a decrease in vertical sweep efficiency. In the case of carbon storage, impurities decreased the performance of residual trapping by 4.1% and solubility trapping by 5.6% compared with pure CO2 WAG. As a result, impurities in CO2 reduced oil recovery by 9.2% and total CCS performance by 4.3%. Full article
(This article belongs to the Special Issue Advanced Technologies for Carbon Capture, Utilization, and Storage (CCUS))
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26 pages, 13908 KiB  
Article
Optimization of Relief Well Design Using Artificial Neural Network during Geological CO2 Storage in Pohang Basin, South Korea
by Youngsoo Song and Jihoon Wang
Appl. Sci. 2021, 11(15), 6996; https://doi.org/10.3390/app11156996 - 29 Jul 2021
Cited by 12 | Viewed by 3129
Abstract
This study aims at the development of an artificial neural network (ANN) model to optimize relief well design in Pohang Basin, South Korea. Relief well design in carbon capture and geological storage (CCS) requires complex processes and excessive iterative procedures to obtain optimal [...] Read more.
This study aims at the development of an artificial neural network (ANN) model to optimize relief well design in Pohang Basin, South Korea. Relief well design in carbon capture and geological storage (CCS) requires complex processes and excessive iterative procedures to obtain optimal operating parameters, such as CO2 injection rate, water production rate, distance between the wells, and pressure at the wells. To generate training and testing datasets for ANN model development, optimization processes for a relief well with various injection scenarios were performed. Training and testing were conducted, where the best iteration and regression were considered based on the calculated coefficient of determination (R2) and root mean square error (RMSE) values. According to validation with a 20-year injection scenario, which was not included in the training datasets, the model showed great performance with R2 values of 0.96 or higher for all the output parameters. In addition, the RMSE values for the BHP and the trapping mechanisms were lower than 0.04. Moreover, the location of the relief well was reliably predicted with a distance difference of only 20.1 m. The ANN model can be robust tool to optimize relief well design without a time-consuming reservoir simulations. Full article
(This article belongs to the Special Issue Advanced Technologies for Carbon Capture, Utilization, and Storage (CCUS))
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