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Processes
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Recent Advances in Carbon Capture, Utilisation and Storage Technologies
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Recent Advances in Carbon Capture, Utilisation and Storage Technologies

A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Chemical Processes and Systems".

Deadline for manuscript submissions: 28 February 2025 | Viewed by 5400

Special Issue Editors

Dr. Run Chen

E-Mail Website
Guest Editor
1. Jiangsu Key Laboratory of Coal-Based Greenhouse Gas Control and Utilization, Xuzhou 221008, China
2. Carbon Neutrality Institute, China University of Mining and Technology, Xuzhou 221008, China
Interests: unconventional natural gas; CCUS; carbon neutrality; underground coal gasification, CO2 mineralization
Special Issues, Collections and Topics in MDPI journals
Dr. Sijian Zheng

E-Mail Website
Guest Editor
1. Carbon Neutrality Institute, China University of Mining and Technology, Xuzhou 221008, China
2. The Key Laboratory of Coal-Based CO2 Capture and Geological Storage, China University of Mining and Technology, Xuzhou 221116, China
Interests: CO2 geologic storage; CO2-enhanced coalbed methane; coalbed methane geology and engineering

Special Issue Information

Dear Colleagues,

To combat the detrimental impacts of climate change and meet the obligations outlined in the 2015 Paris Agreement, CO2 Capture, Utilisation, and Storage (CCUS) has emerged as a crucial technology with significant potential for achieving climate targets. CCUS technology achieves the resource utilization of captured CO2 and stores it in strata such as oil/gas reservoirs and salinity aquifers. However, there are still many challenges involved in several key parts of CCUS, including low-cost carbon capture, long-distance pipeline transport, CO2-EOR, CO2-ECBM/shale gas, and long-term safe storage. There is an urgent need for research and development in order that we implement CCUS-related technologies.

In this Special Issue, contributions to recent advances in CCUS technologies are welcome. Topics include, but are not limited to

  • New theories and methods for CCUS;
  • Laboratory experiments and numerical modelling of CCUS;
  • Economic evaluation and field practices of CCUS;
  • The environmental impact of CCUS projects;
  • CO2 monitoring

Dr. Run Chen
Dr. Sijian Zheng
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. Processes 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 capture
  • CO2 storage
  • CO2-EOR
  • CO2-ECBM/shale gas
  • CO2 mineralization
  • CO2 monitoring
  • source–sink matching for CCUS
  • carbon accounting

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Published Papers (7 papers)

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Research

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11 pages, 3140 KiB  
Article
Rational Fabrication of Polyhedral Oligomeric Silsesquioxane-Based Porous Organic Polymers Sustainably Used for Selective CO2 Adsorption
by Tiantian Li, Guodong Kang, Mengqi Liu, Congcong Sun, Jie Li, Yang Meng and Dingming Xue
Processes 2024, 12(11), 2604; https://doi.org/10.3390/pr12112604 - 20 Nov 2024
Viewed by 341
Abstract
Different types of porous materials have been developed for the efficient separation of CO2 from mixtures of gases. Nevertheless, the most porous materials cannot be used for extensive industrial applications due to their non-negligible disadvantages, such as complex synthesis routes, expensive monomers, [...] Read more.
Different types of porous materials have been developed for the efficient separation of CO2 from mixtures of gases. Nevertheless, the most porous materials cannot be used for extensive industrial applications due to their non-negligible disadvantages, such as complex synthesis routes, expensive monomers, and/or costly catalysts. Therefore, a strategy for fabricating a series of polyhedral oligomeric silsesquioxane (POSS)-based porous organic polymer materials (PBPOPs) was developed through the simple condensation reaction of octaphenylsilsesquioxane and different bromine-containing monomers. It was found that PBPOP-2 exhibits the best CO2 adsorption amount of 41 cm3·g−1 at 273 K and 760 mmHg based on the accessible specific surface area, large pore volumes, and accessible pore sizes. Furthermore, PBPOP-2 exhibits efficient CO2/N2 selectivity and complete regeneration under mild conditions, which demonstrates the potential for the selective separation of CO2 from gas mixtures. This work provides a new route to developing POSS-based POPs for CO2-capture applications. Full article
(This article belongs to the Special Issue Recent Advances in Carbon Capture, Utilisation and Storage Technologies)
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13 pages, 3714 KiB  
Article
Study on Thermal Chamber Expansion of VH-SAGD Process Using CO2-Inducing Effect for Heavy Oil Reservoirs
by Haojun Xie, Shiming Zhang, Guanghuan Wu and Wei Li
Processes 2024, 12(10), 2260; https://doi.org/10.3390/pr12102260 - 16 Oct 2024
Viewed by 678
Abstract
In heavy oil thermal recovery processes, higher pressure usually leads to low dryness and expansion difficulty for the injected steam in thermal recovery processes, which will result in lower oil recovery and more carbon emissions. This paper proposed a new CO2-inducing [...] Read more.
In heavy oil thermal recovery processes, higher pressure usually leads to low dryness and expansion difficulty for the injected steam in thermal recovery processes, which will result in lower oil recovery and more carbon emissions. This paper proposed a new CO2-inducing method to accelerate the steam chamber expansion, based on a core flooding experiment and numerical simulation. First, the CO2 showed significant viscosity reduction at high pressure in the PVT test. In the core flooding experiment, the CO2 provided strong flow conductivity in porous media for the thermal flooding, as the CO2 pre-injection restrained the steam condensation. Using the CO2-inducing method, CO2 pre-injection before steam built a fast flow channel in a relatively higher permeability layer and reduced the thermal injection pressure by about 1.0~2.4 MPa. As a result, the steam overlap around the injection wells became slower and the gravity drainage process was able to heat and displace the heavy oil above the channel. Furthermore, the CO2 gas trapped at the top reduced heat loss by about 12.4%. The field numerical simulation showed that this new method improved thermal recovery by 7.5% and reduced CO2 emissions by about 18 million kg/unit for the whole process. This method changes the conventional thermal expansion direction by CO2 inducing effect and fundamentally reduces heat loss, which provides significant advantages in low-carbon EOR. Full article
(This article belongs to the Special Issue Recent Advances in Carbon Capture, Utilisation and Storage Technologies)
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11 pages, 3538 KiB  
Article
Evaluation of Caprock Sealing Performance for CO2 Saline Aquifer Storage: A Numerical Study
by Xiaohan Shu, Lijun Zhang, Lei Zhang, Xiabin Wang, Xiaofeng Tian and Lingdong Meng
Processes 2024, 12(8), 1727; https://doi.org/10.3390/pr12081727 - 16 Aug 2024
Viewed by 755
Abstract
The integrity of caprock sealing is a crucial factor in guaranteeing the safety and long-term feasibility of CO2 saline aquifer storage. In this study, we identified three principal mechanisms that give rise to topseal failure: (1) gradual CO2 seepage through the [...] Read more.
The integrity of caprock sealing is a crucial factor in guaranteeing the safety and long-term feasibility of CO2 saline aquifer storage. In this study, we identified three principal mechanisms that give rise to topseal failure: (1) gradual CO2 seepage through the upper cap, (2) capillary seal failure resulting from the pressure increment due to CO2 injection, and (3) localized overpressure causing cap rupture. Through the integration of numerical simulation and geomechanics, this study offers a sealing assessment for the caprock. The thorough analysis of the sealing performance of the Guantao formation reveals that after 2000 years of CO2 injection, the caprock would undergo intrusion by 35 m without any leakage risk. Moreover, investigations into CO2–water–rock interactions suggest that precipitation reactions outweigh dissolution reactions, leading to a decreased permeability and an enhanced sealing performance. The most likely fracture mode identified is shear fracture with a critical caprock fracture pressure of 36.48 MPa. In addition to these discoveries, it is significant to consider ongoing research aimed at enhancing our ability to predict and manage potential risks associated with carbon capture and storage technologies. Full article
(This article belongs to the Special Issue Recent Advances in Carbon Capture, Utilisation and Storage Technologies)
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11 pages, 2506 KiB  
Article
Impacts of CO2-CH4 Mixed Gas on Property of Formation Oil from the Bohai Oilfield
by Renfeng Yang, Lijun Zhang, Xianhong Tan, Xiaofeng Tian, Xugang Yang, Xiaohan Shu, Guodong Zou, Erlong Yang, Changdong Jiang and Shaobin Hu
Processes 2024, 12(7), 1480; https://doi.org/10.3390/pr12071480 - 15 Jul 2024
Viewed by 679
Abstract
Mechanism analysis and technical scheme optimization on CO2 displacement and CO2 storage are based on the high-pressure physical properties of CO2-added formation oil. Oil and natural gas samples from the BZ25-1 block in the Bohai oilfield were used to [...] Read more.
Mechanism analysis and technical scheme optimization on CO2 displacement and CO2 storage are based on the high-pressure physical properties of CO2-added formation oil. Oil and natural gas samples from the BZ25-1 block in the Bohai oilfield were used to conduct high-pressure physical property experiments to explore the impacts of CO2-CH4 mixed gas on the properties of formation oil. After injecting different amounts of mixed gas, the saturated pressure was measured by constant mass expansion test, the viscosity was measured by falling ball method, the expansion coefficient was measured by gas injection expansion test, and the gas–oil ratio and volume coefficient were obtained by single degassing test. The results show that with gas injection, the saturation pressure and dissolved gas–oil ratio of formation oil increase, the volume coefficient and expansion factor go up, while the oil viscosity reduces. With the increase in gas addition, the properties of formation oil continue to improve, but the increase in improvement becomes flat. With the increase in pressure, the amount of dissolved gas in the formation oil will also increase. High-purity CO2 is more helpful to change the properties of formation oil, while the gas mixed with CH4 is more beneficial to elevate the formation energy. For the BZ 25-1 block, the gas injection amount of about 80 mol% is appropriate and the CO2 purity of 60% can well balance the oil properties improvement and the formation pressure elevation. Full article
(This article belongs to the Special Issue Recent Advances in Carbon Capture, Utilisation and Storage Technologies)
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12 pages, 5966 KiB  
Article
Study on the Thermal Expansion Characteristics of Coal during CO2 Adsorption
by Jinxing Song, Yajie Sun and Yufang Liu
Processes 2024, 12(6), 1229; https://doi.org/10.3390/pr12061229 - 15 Jun 2024
Viewed by 574
Abstract
The adsorption of CO2 fracturing fluid into coal reservoirs causes the expansion of the coal matrix volume, resulting in changes in the fracture opening, which alters the permeability of the coal reservoir. However, it is not yet clear whether thermal expansion during [...] Read more.
The adsorption of CO2 fracturing fluid into coal reservoirs causes the expansion of the coal matrix volume, resulting in changes in the fracture opening, which alters the permeability of the coal reservoir. However, it is not yet clear whether thermal expansion during CO2 adsorption on coal is the main cause of coal adsorption expansion. Therefore, by testing the thermal properties, expansion coefficient, and adsorption heat of the three coal samples, the adsorption thermal expansion characteristics of coal and their impact on the permeability of coal reservoirs are clarified. The results reveal the following: (1) Under the same conditions, the adsorption heat increases with increasing pressure, while it decreases with increasing temperature. The relationship between adsorption heat and pressure conforms to the Langmuir equation before 40 °C, and it follows a second-order equation beyond 40 °C. At 100 °C, the adsorption heat of coal samples to CO2 is primarily determined by temperature. (2) The maximum temperature variation in coal samples from Xinjiang, Liulin, and Zhaozhuang during CO2 adsorption is 95.767 °C, 87.463 °C, and 97.8 °C, respectively. The maximum thermal expansion rates are 12.66%, 5.74%, and 14.37%, and the maximum permeability loss rates are 16.16%, 7.51%, and 18.24%, respectively, indicating that thermal expansion is the main reason for coal adsorption expansion. (3) This research can elucidate the impact of CO2 fracturing fluid on coal reservoirs and its potential application value, thus providing theoretical support for coalbed methane development and CO2 geological storage. Full article
(This article belongs to the Special Issue Recent Advances in Carbon Capture, Utilisation and Storage Technologies)
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20 pages, 27270 KiB  
Article
Evaluation of the Potential for CO2 Storage and Saline Water Displacement in Huaiyin Sag, Subei Basin, East China
by Chenglong Zhang, Yujie Diao, Lei Fu, Xin Ma, Siyuan Wang and Ting Liu
Processes 2024, 12(3), 547; https://doi.org/10.3390/pr12030547 - 11 Mar 2024
Cited by 1 | Viewed by 1276
Abstract
CO2 geological storage combined with deep saline water recovery technology (CO2-EWR) is one of the most effective ways to reduce carbon emissions. Due to the complex structural features, it is difficult to use CO2-EWR technology in Huaiyin Sag, [...] Read more.
CO2 geological storage combined with deep saline water recovery technology (CO2-EWR) is one of the most effective ways to reduce carbon emissions. Due to the complex structural features, it is difficult to use CO2-EWR technology in Huaiyin Sag, Subei basin, East China. In this study, the multi-source information superposition evaluation technology of GIS was utilized for the selection of CO2 storage sites and water displacement potential target areas in this area, which mainly focused on the sandstone reservoirs of Cretaceous Pukou Formation. Based on the results, a three-dimensional injection–extraction model was established. Various scenarios with different production/injection well ratios (PIR) were simulated. Research has shown that the suitability of the surrounding site of Huaiyin Power Plant can be divided into two levels: relatively suitable and generally suitable; the area in the generally suitable level accounts for more than 80%. At a PIR of 1, CO2 is distributed asymmetrically, whereas at PIRs of 2 or 4, CO2 is distributed symmetrically. When the number of production wells is constant, a higher injection rate results in a faster expansion rate of the CO2 plume. This means that the time taken for the CO2 plume to reach the production wells is shorter. Reservoir pressure increases rapidly after more than 60 years of CO2 injection at lower PIR values, while at higher PIRs, reservoir pressure eventually stabilizes. Higher PIR values correspond to higher gas saturation, indicating a greater capacity for CO2 sequestration with more producing wells. When PIR = 4, the total CO2 injection increased by 55.73% compared to PIR = 1. However, the extraction of saline decreases with an increase in the number of producing wells, resulting in a decrease in replacement efficiency. This study provides a theoretical basis and technical support for the implementation of large-scale CO2-EWR engineering and technology demonstration in this region. Full article
(This article belongs to the Special Issue Recent Advances in Carbon Capture, Utilisation and Storage Technologies)
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Review

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22 pages, 6301 KiB  
Review
Typical Case Studies and Classification with Evaluation of Carbon Dioxide Geological Sequestration in Saline Aquifers
by Lihua Ping, Huijun Wang, Yuchen Tian, Helong Zhang, Xiuping Wu, Shiheng Chen, Yinghai Liu, Yanzhi Liu, Shiqi Liu, Shuxun Sang and Sijian Zheng
Processes 2024, 12(11), 2562; https://doi.org/10.3390/pr12112562 - 16 Nov 2024
Viewed by 325
Abstract
To achieve carbon neutrality in China’s fossil energy sector, saline aquifer CO2 geological storage has become a critical strategy. As research into carbon reduction and storage potential evaluation advances across various geological scales, the need arises for consolidating key CO2 storage [...] Read more.
To achieve carbon neutrality in China’s fossil energy sector, saline aquifer CO2 geological storage has become a critical strategy. As research into carbon reduction and storage potential evaluation advances across various geological scales, the need arises for consolidating key CO2 storage cases and establishing a standardized classification system and evaluation methodology. This paper provides a comprehensive review of notable CO2 storage projects in saline aquifers, covering aspects such as project overviews, structural and reservoir characteristics, caprock integrity, and seismic monitoring protocols. Drawing on insights from mineral and oil and gas exploration, as well as international methods, this paper outlines the stages and potential levels of saline aquifer storage in China. It proposes an evaluation framework with formulas and reference values for key coefficients. The study includes successful global projects, such as Sleipner and Snøhvit in Norway, In Salah in Algeria, and Shenhua in China’s Ordos Basin, which provide valuable insights for long-term carbon capture and storage (CCS). By examining geological characteristics, injection, and monitoring protocols in these projects, this paper analyzes how geological features impact CO2 storage outcomes. For example, the Sleipner project’s success is linked to its straightforward structure, favorable reservoir properties, and stable caprock, while Snøhvit illustrates diverse structural suitability, and In Salah demonstrates the influence of fractures on storage efficacy. CO2 storage activities are segmented into four stages—survey, investigation, exploration, and injection—and are further categorized by storage potential: geological, technical, techno-economic, and engineering capacities. This study also presents evaluation levels (prediction, control, technically recoverable, and engineering) that support effective reservoir selection, potential classification, and calculations considering factors like reservoir stability and sealing efficacy. Depending on application needs, volumetric or mechanistic methods are recommended, with precise determination of geological, displacement, and cost coefficients. For China, a dynamic evaluation mechanism characterized by multi-scale, tiered approaches and increasing precision over time is essential for robust storage potential assessment. The levels and methods outlined here serve as a scientific foundation for regional and stage-based comparisons, guiding engineering approvals and underground space management. To align with practical engineering demands, ongoing innovation through laboratory experiments, simulations, and field practice is crucial, supporting continual refinement of formulas and key parameter determinations. Full article
(This article belongs to the Special Issue Recent Advances in Carbon Capture, Utilisation and Storage Technologies)
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