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Atmosphere
Special Issues
CO2 Geological Storage and Utilization
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CO2 Geological Storage and Utilization

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

Deadline for manuscript submissions: closed (3 July 2023) | Viewed by 11784

Special Issue Editors

Prof. Dr. Liang Huang

E-Mail Website
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
Prof. Dr. Yu Yang

E-Mail Website
Guest Editor
College of Energy, Chengdu University of Technology, Chengdu 610059, China
Interests: sealing capacity; CO2 injectivity; leakage risk; numerical modeling

Special Issue Information

Dear Colleagues,

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 various CCUS technologies, CO2 geological storage and utilization has become one major development orientation due to its huge storage scales and potential economic benefits with enhanced oil/gas recovery.

CO2 geological storage and utilization is correlated with multi-disciplinary porous media research, which involves the complex physicochemical interactions of multiphase fluids with 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 entitled CO2 Geological Storage and Utilization. Paper topics may relate 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): 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
Prof. Dr. Dali Hou
Prof. Dr. Qian Sun
Prof. Dr. Yu Yang
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 (7 papers)

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Editorial

Jump to: Research, Review

3 pages, 167 KiB  
Editorial
CO2 Geological Storage and Utilization
by Liang Huang
Atmosphere 2023, 14(7), 1166; https://doi.org/10.3390/atmos14071166 - 19 Jul 2023
Cited by 2 | Viewed by 853
Abstract
With increasing greenhouse gas emissions caused by human activities, climate change is affecting the survival and development of human society [...] Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization)

Research

Jump to: Editorial, Review

11 pages, 1823 KiB  
Article
CO2 Corrosion Rate Prediction for Submarine Multiphase Flow Pipelines Based on Multi-Layer Perceptron
by Guoqing Wang, Changquan Wang and Lihong Shi
Atmosphere 2022, 13(11), 1833; https://doi.org/10.3390/atmos13111833 - 03 Nov 2022
Cited by 5 | Viewed by 1221
Abstract
The implementation of corrosion detection in submarine pipelines is difficult, and a combined PCA-MLP prediction model is proposed to improve the accuracy of corrosion prediction in submarine pipelines. Firstly, the corrosion rate of a submarine multiphase flow pipeline in the South China Sea [...] Read more.
The implementation of corrosion detection in submarine pipelines is difficult, and a combined PCA-MLP prediction model is proposed to improve the accuracy of corrosion prediction in submarine pipelines. Firstly, the corrosion rate of a submarine multiphase flow pipeline in the South China Sea is simulated by the De Waard 95 model in the multiphase flow transient simulation software OLGA and compared with the actual corrosion rate; then, according to the corrosion data simulated by OLGA, principal component analysis (PCA) is used to reduce the dimensionality of the corrosion factors in the pipeline, and the multiple linear regression model (MLR), multi-layer perceptron neural network (MLPNN), and radial basis function neural network (RBFNN) were optimized. The PCA-MLPNN model has an average relative error of 3.318%, an average absolute error of 0.0034, a root mean square error of 0.0082, a residual sum of squares of 0.0020, and a coefficient of determination of 0.8609. Compared with five models, including MLR, MLPNN, RBFNN, PCA-MLR, PCA-MLPNN, and PCA-RBFNN, PCA-MLPNN has higher prediction accuracy and better prediction performance. The above results indicate that the combined PCA-MLPNN model has a more reliable application capability in CO2 corrosion prediction of submarine pipelines. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization)
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13 pages, 6995 KiB  
Article
Factors Influencing the CO2 Corrosion Pattern of Oil–Water Mixed Transmission Pipeline during High Water Content Period
by Zhonghua Yang, Lihong Shi, Minghua Zou and Changquan Wang
Atmosphere 2022, 13(10), 1687; https://doi.org/10.3390/atmos13101687 - 14 Oct 2022
Cited by 2 | Viewed by 1984
Abstract
After the oil field enters the high water content period, the oil–water mixed fluid in the mixing system will gradually change into the water-in-oil mixed fluid, while the dissolved CO2 causes the pH value of the mixed fluid to decrease. There is [...] Read more.
After the oil field enters the high water content period, the oil–water mixed fluid in the mixing system will gradually change into the water-in-oil mixed fluid, while the dissolved CO2 causes the pH value of the mixed fluid to decrease. There is also a certain amount of bacteria in the output fluid, with many factors leading to the intensification in the corrosion of the oil–water mixed system pipeline in the high water content period. To clarify its corrosion law, through the mixed transmission pipeline material, 20# carbon steel, in high water conditions under the action of different single factor dynamic corrosion rate experiments, along with the use of the SPSS method, were used to determine the corrosion of the main control factors. The results show that in the high water content period, the corrosion rate of the mixed pipeline 20# steel gradually increases with the increase in temperature pressure, CO2 partial pressure, SRB content, Ca2+ + Mg2+ content, and Cl− content. The corrosion rate with the CO2 partial pressure and SRB content changes show a strong multiplicative power relationship; with Ca2+ + Mg2+ content, Cl− content changes show a logarithmic relationship, the relationship degree R2 is above 0.98. Through SPSS data analysis software combined with experimental data for correlation degree analysis, it is concluded that the correlation magnitude relationship between each factor and corrosion rate is CO2 partial pressure > SRB content > Cl− content > Ca2+ + Mg2+ content > temperature pressure, which provides a theoretical basis for the corrosion protection of an oil gathering pipeline. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization)
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11 pages, 7522 KiB  
Article
Molecule Simulation of CH4/CO2 Competitive Adsorption and CO2 Storage in Shale Montmorillonite
by Dali Hou, Fengming Gong, Hongming Tang, Jianchun Guo, Xianyu Qiang and Lei Sun
Atmosphere 2022, 13(10), 1565; https://doi.org/10.3390/atmos13101565 - 25 Sep 2022
Cited by 1 | Viewed by 1661
Abstract
The main source of production in the middle and late stages of shale gas extraction is the adsorbed gas in shale, and the adsorbed gas in shale mainly comes from organic matter casein and clay minerals in shale; therefore, this paper uses sodium-based [...] Read more.
The main source of production in the middle and late stages of shale gas extraction is the adsorbed gas in shale, and the adsorbed gas in shale mainly comes from organic matter casein and clay minerals in shale; therefore, this paper uses sodium-based montmorillonite to characterize the clay minerals in shale and study the CH4 adsorption law in clay minerals, and this study has certain guiding significance for shale gas extraction. In addition, this paper also conducts a study on the competitive adsorption law of CH4 and CO2, and at the same time, predicts the theoretical sequestration of CO2 in shale clay minerals, which is a reference value for the study of CO2 burial in shale and is beneficial to the early realization of carbon neutral. In this paper, the slit model of sodium-based montmorillonite and the fluid model of CH4 and CO2 were constructed using Materials Studio software, and the following two aspects were studied based on the Monte Carlo method: Firstly, the microscopic adsorption behavior of CH4 in sodium-based montmorillonite was studied, and the simulations showed that the adsorption capacity of montmorillonite decreases with increasing temperature, increases and then decreases with increasing pressure, and decreases with increasing pore size. CH4 has two states of adsorption and free state in the slit. The adsorption type of CH4 in montmorillonite is physical adsorption. Secondly, the competitive adsorption of CH4 and CO2 in sodium-based montmorillonite was studied, and the simulations showed that the CO2 repulsion efficiency increased with increasing CO2 injection pressure, and the CO2/CH4 competitive adsorption ratio decreased with increasing pressure. The amount of CO2 storage decreased with increasing temperature and increased with increasing CO2 injection pressure. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization)
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14 pages, 4013 KiB  
Article
Study on Enhancing Shale Oil Recovery by CO2 Pre-Pad Energized Fracturing in A83 Block, Ordos Basin
by Yang Xiao, Zhigang Li, Jiahao Wang, Jinyuan Yang, Zhonghui Ma, Shuyun Liu and Chenhui Han
Atmosphere 2022, 13(9), 1509; https://doi.org/10.3390/atmos13091509 - 15 Sep 2022
Cited by 3 | Viewed by 1404
Abstract
The Ordos Basin is rich in shale oil resources. The main targeted layers of blocks A83 and X233 are the Chang 7 member of the Yanchang Formation. Due to extremely low permeability, a fracturing technique was required to enhance oil recovery. However, after [...] Read more.
The Ordos Basin is rich in shale oil resources. The main targeted layers of blocks A83 and X233 are the Chang 7 member of the Yanchang Formation. Due to extremely low permeability, a fracturing technique was required to enhance oil recovery. However, after adopting the stimulated reservoir volume-fracturing technology, the post-fracturing production of the A83 block is significantly lower than that of the X233 block. For this problem, the dominating factors of productivity of the two blocks were analyzed using the Pearson correlation coefficient (PCC) and the Spearman rank correlation coefficient (SRCC), showing that the main reason for the lower production of the A83 block is its insufficient formation energy. To solve this problem, the CO2 pre-pad energized fracturing method was proposed. To study the feasibility of CO2 pre-pad energized fracturing in the A83 block, an integrated reservoir numerical simulation model of well A83-1 was established based on the idea of integration of geology and engineering. Additionally, the productions within five years after conventional volume fracturing and CO2 pre-pad energized fracturing were compared. The results show that compared with conventional volume fracturing, the cumulative oil production of CO2 pre-pad energized fracturing increases by 11.8%, and the water cut decreases by 16.5%. The research results can guide the subsequent reservoir reconstruction operation in the A83 block and provide new ideas for fracturing in the future. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization)
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Review

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9 pages, 1050 KiB  
Review
Application and Development Countermeasures of CCUS Technology in China’s Petroleum Industry
by Xingxiang Che, Xiangyi Yi, Zhaohui Dai, Ziwei Zhang and Yun Zhang
Atmosphere 2022, 13(11), 1757; https://doi.org/10.3390/atmos13111757 - 25 Oct 2022
Cited by 3 | Viewed by 1333
Abstract
Greenhouse gas emissions cause many global problems. Under the strong promotion of the government’s two-carbon goals policy, China’s petroleum industry is actively carrying out the application of carbon capture, utilization, and storage (CCUS). The energy consumption and carbon emissions in China are reviewed, [...] Read more.
Greenhouse gas emissions cause many global problems. Under the strong promotion of the government’s two-carbon goals policy, China’s petroleum industry is actively carrying out the application of carbon capture, utilization, and storage (CCUS). The energy consumption and carbon emissions in China are reviewed, and the importance of the petroleum industry in the process of carbon emission reduction is clarified. The applications, advantages, and disadvantages of carbon capture, carbon utilization, and carbon sequestration technologies in China’s petroleum industry are summarized, respectively. The current challenges and risks faced by China’s petroleum industry in the operation of CCUS projects are analyzed, and corresponding suggestions are provided. This article aims to systematically provide references and help for the application of CCUS in China’s petroleum industry. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization)
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16 pages, 2108 KiB  
Review
Feasibility Analyses and Prospects of CO2 Geological Storage by Using Abandoned Shale Gas Wells in the Sichuan Basin, China
by Xiaopeng Lai, Xingyi Chen, Yunhan Wang, Dengjin Dai, Jie Dong and Wei Liu
Atmosphere 2022, 13(10), 1698; https://doi.org/10.3390/atmos13101698 - 17 Oct 2022
Cited by 7 | Viewed by 2314
Abstract
The geological storage of CO2 is a critical technique for reducing emissions, which significantly contributes to the mitigation of the greenhouse effect. Currently, CO2 is often geologically stored in coal seams, hydrocarbon reservoirs, and saline aquifers in order to store CO [...] Read more.
The geological storage of CO2 is a critical technique for reducing emissions, which significantly contributes to the mitigation of the greenhouse effect. Currently, CO2 is often geologically stored in coal seams, hydrocarbon reservoirs, and saline aquifers in order to store CO2 and improve the oil and gas recovery simultaneously. Shale formations, as candidates for CO2 storage, are drawing more attention because of their rich volumes. CO2 storage through shale formations in the Sichuan Basin, China, has tremendous potential because of the readily available CO2 injection equipment, such as abandoned shale gas wells. Therefore, we review the potential of using these wells to store CO2 in this paper. Firstly, we review the status of the geological storage of CO2 and discuss the features and filed applications for the most studied storage techniques. Secondly, we investigate the formation properties, shale gas field development process, and characteristics of the abandoned wells in the Sichuan Basin. Additionally, after carefully studying the mechanism and theoretical storage capacity, we evaluate the potential of using these abandoned wells to store CO2. Lastly, recommendations are proposed based on the current technologies and government policies. We hope this paper may provide some insights into the development of geological CO2 storage using unconventional reservoirs. Full article
(This article belongs to the Special Issue CO2 Geological Storage and Utilization)
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