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CO2 Capture, Utilization and Storage
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CO2 Capture, Utilization and Storage

A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "B3: Carbon Emission and Utilization".

Deadline for manuscript submissions: 30 January 2026 | Viewed by 4322

Special Issue Editor

Prof. Dr. Shijian Lu

E-Mail Website
Guest Editor
Carbon Neutrality Institute, China University of Mining and Technology, Xuzhou 221008, China
Interests: carbon capture; CCUS; modelling; optimization
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Carbon dioxide (CO2) emissions and increasing CO2 concentration in the atmosphere are global hot topics as they are among the main contributors to climate change and environmental problems. The most sustainable strategies to limit these CO2 emissions are carbon capture, utilization and storage (CCUS). CCUS is gaining increased interest as a technology to effectively reduce greenhouse gas emissions from the power and industrial sectors. There are many research works and great progress on this aspect. This Special Issue, entitled “CO2 Capture, Utilization and Storage”, aims to present the most recent technologies, materials and applications related to carbon capture, utilization and storage.

Prof. Dr. Shijian Lu
Guest Editor

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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. Energies is an international peer-reviewed open access semimonthly 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 2600 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 technology
  • CO2 utilization technology
  • CO2 storage technology
  • Combined CO2 capture and conversion technology
  • CCUS chain

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Published Papers (3 papers)

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Research

18 pages, 1177 KB  
Article
Supercritical CO2 Foam Stability in the Presence of Oil
by Hilde Halsøy, Arne Graue and Zachary Paul Alcorn
Energies 2025, 18(23), 6227; https://doi.org/10.3390/en18236227 - 27 Nov 2025
Viewed by 208
Abstract
Foam is a field-proven technique to reduce CO2 mobility and mitigate the impacts of reservoir heterogeneity in CO2-enhanced oil recovery (CO2-EOR). However, foams are unstable and tend to break down in the presence of oil. Screening foam generation [...] Read more.
Foam is a field-proven technique to reduce CO2 mobility and mitigate the impacts of reservoir heterogeneity in CO2-enhanced oil recovery (CO2-EOR). However, foams are unstable and tend to break down in the presence of oil. Screening foam generation and stability in the presence of oil, at representative reservoir pressure and temperature, at core-scale is critical for successful upscaling. This study investigates the effect of oil on foam generation and stability across a range of foam qualities (fg = 0.30 to 1.0) and injection velocities (4 ft/day to 16 ft/day). Foam quality and rate scans using Bentheimer sandstone cores were conducted in presence/absence of oil (n-decane and Troll crude) at reservoir conditions (60 °C and 180 bar). Foam quality scans co-injected supercritical CO2 and foaming solutions with increasing foam quality (fg = 0.30 to 1.0) to determine the optimal foam quality (highest apparent viscosity foam). T optimal foam quality was then used in rate scans to determine the effect of injection velocity on foam strength. In addition, two separate core floods at two fixed foam qualities (fg = 0.30 and 0.70) were performed to determine the oil recovery factor during foam injection. Strong foam was generated, in both the presence and absence of oil, but oil significantly reduced foam strength. The foam apparent viscosity was reduced by ~93% (Troll crude) and ~90% (n-decane) compared to foam in the absence of oil. Increasing the surfactant concentration from 0.10 wt.% to 1.0 wt.% significantly enhanced the foam mobility control, with the apparent viscosity in the presence of oil increasing from 7.9 cP to 25.9 cP. The optimal foam quality in the presence of both oils ranged from fg = 0.60 to 0.70. Foam rate scans revealed shear-thinning rheology (foam viscosity decreased at higher flow rates), which is beneficial for maintaining field-scale injectivity. This study provides critical insights into how oil impacts supercritical CO2 foam strength, stability mechanisms, and oil recovery at reservoir conditions, crucial for field-scale implementation in CO2-EOR and CO2 storage projects. Full article
(This article belongs to the Special Issue CO2 Capture, Utilization and Storage)
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20 pages, 2596 KB  
Article
Adsorption Equilibria and Systematic Thermodynamics Analysis of Carbon Dioxide Sequestration on South African Coals Using Nonlinear Three-Parameter Models: Sips, Tóth, and Dubinin–Astakhov
by Major Melusi Mabuza and Mandlenkosi George Robert Mahlobo
Energies 2025, 18(10), 2646; https://doi.org/10.3390/en18102646 - 20 May 2025
Cited by 3 | Viewed by 1979
Abstract
Carbon dioxide (CO2) injection into geologic formations has gained global traction, including in South Africa, to mitigate anthropogenic emissions through carbon capture, utilisation, and storage technology. These technological and technical developments require a comprehensive and reliable study of CO2 sorption [...] Read more.
Carbon dioxide (CO2) injection into geologic formations has gained global traction, including in South Africa, to mitigate anthropogenic emissions through carbon capture, utilisation, and storage technology. These technological and technical developments require a comprehensive and reliable study of CO2 sorption equilibria under in situ unmineable coal reservoir conditions. This paper presents novel findings on the study of the equilibrium adsorption of CO2 on two South African coals measured at four temperatures between 30 and 60 °C and pressures up to 9.0 MPa using the volumetric technique. Additionally, the sorption mechanism and thermodynamic nature of the process were studied by fitting the experimental data into Langmuir–Freundlich (Sips), Tóth, and Dubinin–Astakhov (DA) isotherm models, and the Clausius–Clapeyron equation. The findings indicate that the sorption process is highly exothermic, as presented by a negative temperature effect, with the maximum working capacity estimated to range between 3.46 and 4.16 mmol/g, which is also rank- and maceral composition-dependent, with high-rank vitrinite-rich coal yielding more sorption capacity than low-rank inertinite-rich coal. The experimental data fit well in Sips and Tóth models, confirming their applicability in describing the CO2 sorption behaviour of the coals under the considered conditions. The isosteric heat of adsorption varied from 7.518 to 37.408 kJ/mol for adsorbate loading ranging from 0.4 to 3.6 mmol/g. Overall, the coals studied demonstrate well-developed sorption properties that characteristically make them viable candidates for CO2 sequestration applications for environmental sustainability. Full article
(This article belongs to the Special Issue CO2 Capture, Utilization and Storage)
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17 pages, 3965 KB  
Article
Investigation into Enhancing Methane Recovery and Sequestration Mechanism in Deep Coal Seams by CO2 Injection
by Xiongwei Sun, Hongya Wang, Bin Gong, Heng Zhao, Haoqiang Wu, Nan Wu, Wei Sun, Shizhao Zhang and Ke Jiang
Energies 2024, 17(22), 5659; https://doi.org/10.3390/en17225659 - 13 Nov 2024
Cited by 2 | Viewed by 1553
Abstract
Injecting CO2 into coal seams to enhance coal bed methane (ECBM) recovery has been identified as a viable method for increasing methane extraction. This process also has significant potential for sequestering large volumes of CO2, thereby reducing the concentration of [...] Read more.
Injecting CO2 into coal seams to enhance coal bed methane (ECBM) recovery has been identified as a viable method for increasing methane extraction. This process also has significant potential for sequestering large volumes of CO2, thereby reducing the concentration of greenhouse gases in the atmosphere. However, for deep coal seams where formation pressure is relatively high, there is limited research on CO2 injection into systems with higher methane adsorption equilibrium pressure. Existing studies, mostly confined to the low-pressure stage, fail to effectively reveal the impact of factors such as temperature, high-pressure CO2 injection, and coal types on enhancing the recovery and sequestration of CO2-displaced methane. Thus, this study aims to investigate the influence of temperature, pressure, and coal types on ECBM recovery and CO2 sequestration in deep coal seams. A series of CO2 core flooding tests were conducted on various coal cores, with CO2 injection pressures ranging from 8 to 18 MPa. The CO2 and methane adsorption rates, as well as methane displacement efficiency, were calculated and recorded to facilitate result interpretation. Based on the results of these physical experiments, numerical simulation was conducted to study multi-component competitive adsorption, desorption, and seepage flow under high temperature and high pressure in a deep coal seam’s horizontal well. Finally, the optimization of the total injection amount (0.7 PV) and injection pressure (approximately 15.0 MPa) was carried out for the plan of CO2 displacement of methane in a single well in the later stage. Full article
(This article belongs to the Special Issue CO2 Capture, Utilization and Storage)
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