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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 9809

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Prof. Dr. Kun Sang Lee

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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

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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 CO₂that 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

Published Papers (4 papers)

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Research

9 pages, 2618 KiB

Open AccessArticle

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 2 | Viewed by 1431

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 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

Open AccessArticle

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 2212

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 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

Open AccessFeature PaperArticle

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 5 | Viewed by 2514

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 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

Open AccessArticle

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 9 | Viewed by 2741

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 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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