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Atmosphere
Special Issues
CO2 Geological Storage and Utilization (2nd Edition)
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CO2 Geological Storage and Utilization (2nd Edition)

A special issue of Atmosphere (ISSN 2073-4433). This special issue belongs to the section "Air Pollution Control".

Deadline for manuscript submissions: 31 July 2024 | Viewed by 1185

Special Issue Editors

Prof. Dr. Liang Huang

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Guest Editor
College of Energy, Chengdu University of Technology, Chengdu 610059, China
Interests: CO2 sequestration; enhanced gas recovery; adsorption/desorption; fluid-rock interaction
Special Issues, Collections and Topics in MDPI journals
Dr. Dali Hou

E-Mail Website
Guest Editor
College of Energy, Chengdu University of Technology, Chengdu 610059, China
Interests: phase behavior; CO2 flooding; CO2 storage; CO2 adsorption; molecular simulation
Special Issues, Collections and Topics in MDPI journals
Prof. Dr. Qian Sun

E-Mail Website
Guest Editor
College of Petroleum Engineering, Shandong Institute of Petroleum and Chemical Technology, Dongying 257000, China
Interests: CO2 foam flooding; EGR; shale oil recovery; CO2 huff-n-puff
Special Issues, Collections and Topics in MDPI journals
Dr. Lu Wang

E-Mail Website
Guest Editor
College of Energy, Chengdu University of Technology, Chengdu 610059, China
Interests: CO2 injection technology; CO2-EOR mechanism; complex mass transfer process

Special Issue Information

Dear Colleagues,

This Special Issue is a follow-up to the first Special Issue in this area titled “CO2 Geological Storage and Utilization” (https://www.mdpi.com/journal/atmosphere/special_issues/CO2_Geological_Storage_Utilization) published in Atmosphere in 2023, and will cover research related to CO2 geological storage, utilization, and monitoring.

Urbanization and industrialization boost the consumption of fossil fuels, which causes enormous CO2 emissions. Excessive CO2 in the air can intensify the greenhouse effect, deteriorating the global climate and ecological environment. Carbon capture, utilization, and storage (CCUS) is a kind of technology that can massively reduce CO2 emissions from industrial processes. Among the various CCUS technologies, CO2 geological storage and utilization has become one major development orientation due to its large storage scale and potential economic benefits, leading to enhanced oil/gas recovery.

CO2 geological storage and utilization are correlated with multi-disciplinary porous media research, which involves the complex physicochemical interactions between multiphase fluids and the intricate porous network at subsurface formations, and there are many challenges in terms of its fundamental theories and techniques that remain unsolved. Therefore, new understandings and advancements from multi-scale research are urgently needed to facilitate the commercial application of various technologies associated with CO2 geological storage and utilization.

We invite you to submit your original research and review manuscripts to this Special Issue titled “CO2 Geological Storage and Utilization”. Paper topics may be related to CO2 geological storage or utilization in shale oil/gas reservoirs, coalbed methane reservoirs, conventional oil/gas reservoirs, depleted oil/gas reservoirs, natural gas hydrate, saline aquifers, geothermal systems, etc. The subjects of the papers may include (but are not limited to) the following: CO2 injection technology (CO2 flooding, huff-n-puff, cyclic gas injection, etc.); CO2 physical/chemical interaction with rocks and other fluids; adsorption/desorption, diffusion, flow behavior, phase behavior of CO2 and fluids; mechanisms of enhanced oil/gas recovery by CO2; and CO2 leakage monitoring and evaluation. The research may involve laboratory experiments, theoretical modeling, multi-scale simulations (molecular simulation, Lattice Boltzmann simulation, pore network simulation, reservoir simulation, etc.), field tests, artificial intelligence, machine learning, and data science applications.

Prof. Dr. Liang Huang
Dr. Dali Hou
Prof. Dr. Qian Sun
Dr. Lu Wang
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Atmosphere is an international peer-reviewed open access monthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2400 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • CO2 geological storage
  • CO2 geological utilization
  • enhanced oil/gas recovery
  • CO2 injection technology
  • CO2-rock interaction
  • mineralization reaction
  • adsorption/desorption
  • transport behavior
  • phase behavior
  • CO2 monitoring

Published Papers (2 papers)

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Research

9 pages, 3254 KiB  
Communication
Application of Lattice Boltzmann Approach for Teaching a Rock Mass Seepage Mechanics Course
by Yanan Miao, Guangchuan Li, He Ma, Gang Zhou and Haoran Li
Atmosphere 2024, 15(4), 496; https://doi.org/10.3390/atmos15040496 - 18 Apr 2024
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Abstract
The technology of CO2 geological storage and CH4 intensive mining (CO2-ECBM) in coal seams integrates greenhouse gas emission reduction and new fossil energy development and has great development prospects. The CO2 injection, CO2 sequestration mechanism and storage [...] Read more.
The technology of CO2 geological storage and CH4 intensive mining (CO2-ECBM) in coal seams integrates greenhouse gas emission reduction and new fossil energy development and has great development prospects. The CO2 injection, CO2 sequestration mechanism and storage capacity, and CH4 stimulation effect constitute the core content of the effectiveness of CO2-ECBM, among which CO2 injection is the most critical. Traditional seepage analysis methods often struggle to tackle flow-related issues influenced by microscale effects and intricate channels. This paper highlights the advantages of employing lattice Boltzmann (LBM) numerical simulations to study CO2 seepage behaviors when teaching a Rock Mass Seepage Mechanics Course. This course primarily covers topics such as the pore structure of rock, unstable liquid seepage, gas seepage theory and related subjects. Its goal is to provide students with a solid theoretical foundation to address the complexities of fluid seepage in pours media encountered in practical scenarios. A novel LBM-based methodology was employed to estimate the CO2 seepage capacity by incorporating the effects of different concentrations of [Bmin]Cl solution (0 wt%, 1 wt%, 3 wt%, and 5 wt%). The CO2 velocity distribution cloud map of each coal sample was simulated; the average velocity distribution curve of each coal sample was obtained; and the velocity profile of the seepage channel of each coal sample was described. This study can provide theoretical guidance for the technology of CO2 geological storage and CH4 intensive mining in coal seams. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization (2nd Edition))
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21 pages, 7477 KiB  
Article
Analyzing the Microscopic Production Characteristics of CO2 Flooding after Water Flooding in Tight Oil Sandstone Reservoirs Utilizing NMR and Microscopic Visualization Apparatus
by Junjie Xue, Hui Gao, Zhanguo Ma, Huaqiang Shi, Xiaoling Li, Teng Li, Zhilin Cheng, Chen Wang, Pan Li and Nan Zhang
Atmosphere 2024, 15(4), 487; https://doi.org/10.3390/atmos15040487 - 15 Apr 2024
Viewed by 481
Abstract
The microscopic pore structure of tight sandstone reservoirs significantly influences the characteristics of CO2 flooding after water flooding. This research was conducted using various techniques such as casting thin sections, high-pressure mercury injection, scanning electron microscopy, nuclear magnetic resonance (NMR) testing, and [...] Read more.
The microscopic pore structure of tight sandstone reservoirs significantly influences the characteristics of CO2 flooding after water flooding. This research was conducted using various techniques such as casting thin sections, high-pressure mercury injection, scanning electron microscopy, nuclear magnetic resonance (NMR) testing, and a self-designed high-temperature and high-pressure microscopic visualization displacement system. Three types of cores with different pore structures were selected for the flooding experiments and the microscopic visualization displacement experiments, including CO2 immiscible flooding, near-miscible flooding, and miscible flooding after conventional water flooding. The characteristics of CO2 flooding and the residual oil distribution after water flooding were quantitatively analyzed and evaluated. The results show the following: (1) During the water flooding process, the oil produced from type I and type III samples mainly comes from large and some medium pores. Oil utilization of all pores is significant for type II samples. The physical properties and pore types have a greater impact on water flooding. Type I and II samples are more suitable for near-miscible flooding after water flooding. Type III samples are more suitable for miscible flooding after water flooding. (2) In CO2 flooding, oil recovery increases gradually with increasing pressure for all three types of samples. Type II core samples have the highest recovery. Before miscibility, the oil recovered from type I and type II samples is primarily from large pores; however, oil recovery mainly comes from medium pores when reaching miscibility. As for the type III samples, the oil produced in the immiscible state mainly comes from large and medium pores, and the enhanced oil recovery mainly comes from medium and small pores after reaching the near-miscible phase. (3) It can be seen from the microscopic residual oil distribution that oil recovery will increase as the petrophysical properties of the rock model improve. The oil recovery rate of near-miscible flooding after water flooding using the type II model is up to 68.11%. The oil recovery of miscible flooding after water flooding with the type III model is the highest at 74.57%. With increasing pressure, the proportion of flake residual oil gradually decreases, while the proportion of droplet-like and film-like residual oil gradually increases. Type II samples have a relatively large percentage of reticulated residual oil in the near-miscible stage. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization (2nd Edition))
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