Submit to Energies Review for Energies Propose a Special Issue

Journal Browser

► Journal Browser

Advances in Carbon Capture, Utilization and Storage Technologies (CCUS)

Print Special Issue Flyer
Special Issue Editors
Special Issue Information
Keywords
Published Papers

A special issue of Energies (ISSN 1996-1073). This special issue belongs to the section "H: Geo-Energy".

Deadline for manuscript submissions: closed (23 March 2024) | Viewed by 9456

Share This Special Issue

Special Issue Editors

Dr. Weifeng Lv

E-Mail Website
Guest Editor

Institute of Porous Flow and Fluid Mechanics, University of Chinese Academy of Sciences, Langfang 065007, China
Interests: CCUS; CCS; EOR; CO₂ flooding and storage
Special Issues, Collections and Topics in MDPI journals

Dr. Tiyao Zhou

E-Mail Website
Guest Editor

Research Institute of Petroleum Exploration and Development, PetroChina, Beijing 100083, China
Interests: CCUS; CO₂-EOR

Dr. Yongbin Wu

E-Mail Website
Guest Editor

Research Institute of Petroleum Exploration and Development, PetroChina, Beijing 100083, China
Interests: heavy oil; foamy oil; EOR; electrical heating
Special Issues, Collections and Topics in MDPI journals

Prof. Dr. Xiaoqing Lu

E-Mail Website
Guest Editor

School of Materials Science and Engineering, China University of Petroleum (East China), Qingdao 266580, China
Interests: CCUS; porous materials
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

Carbon neutrality is a major measure to effectively address global climate change. CCUS (Carbon Capture, Utilization and Storage) is the world's recognized technology to achieve the goal of carbon neutrality. CCUS technology realizes the resource utilization of the captured wasted CO₂ emissions and effectively stores them in geological bodies such as oil reservoirs, gas reservoirs and saltwater aquifers, by which both social and economic benefits can be obtained. However, at present, there are still many challenges in several key parts of CCUS, including low-cost carbon capture, long-distance pipeline transport, CO₂-EOR and long-term safe storage. There is an urgent need for research and development to deliver CCUS-related technologies.

For example, low-cost chemical absorbent for low concentration CO₂, related advanced storage equipment, Influence of impurity gas on the supercritical phase properties of CO₂ in long-distance pipeline transport, precise and detailed characterization of the dominant channel of CO₂ flooding, layer combination and well pattern reconstruction from water flooding to CO₂ flooding, multimedia composite sweep volume expansion of CO₂ flooding in heterogeneous reservoirs, characterization and screening of CO₂ geological storage site, monitoring and safety evaluation of long-term CO₂ storage, stratified gas injection and efficient lifting technologies in field practice, related anti-corrosive material, produced gas recycling, numerical simulation and laboratory experiment technologies of CO₂ flooding and storage, economic evaluation of CCUS project, etc., are the key technologies of CCUS field with significant research value in the future.

This Special Issue will focus on the application of the core technologies in all aspects associated with CCUS, covering theoretical research, laboratory experiment, numerical modelling, economic evaluation and field practice in CO₂ capture, transport, utilization and storage. All papers related to CCUS technologies are welcome to submit.

Topics include but are not limited to:

Low-cost and efficient capture of low-concentration CO₂
Long-distance pipeline transport of supercritical CO₂
Detailed reservoir characterization of low-permeability heterogeneous reservoirs
Sweep volume expansion of CO₂ flooding in multi-layer heterogeneous reservoirs
Low-cost CO₂ injection and production technologies in field practice
Monitoring and safety evaluation of long-term CO₂ storage
Numerical simulation and laboratory experiment technologies of CO₂ flooding and storage
Economic evaluation in the whole industrial chain of CCUS

Dr. Weifeng Lv
Dr. Tiyao Zhou
Dr. Yongbin Wu
Prof. Dr. Xiaoqing Lu
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. 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

CCUS
CO₂ capture
CO₂ transport
CO₂-EOR
CO₂ storage

Published Papers (10 papers)

Download All Papers

Research

Jump to: Review

23 pages, 1874 KiB

Open AccessArticle

Research and Application of Carbon Capture, Utilization, and Storage–Enhanced Oil Recovery Reservoir Screening Criteria and Method for Continental Reservoirs in China

by Jinhong Cao, Ming Gao, Zhaoxia Liu, Hongwei Yu, Wanlu Liu and Hengfei Yin

Energies 2024, 17(5), 1143; https://doi.org/10.3390/en17051143 - 28 Feb 2024

Viewed by 454

Abstract

CCUS-EOR is a crucial technology for reducing carbon emissions and enhancing reservoir recovery. It enables the achievement of dual objectives: improving economic efficiency and protecting the environment. To explore a set of CCUS-EOR reservoir screening criteria suitable for continental reservoirs in China, this study investigated and compared the CCUS-EOR reservoir screening criteria outside and in China, sorted out the main reservoir parameters that affect CO₂ flooding, and optimized the indices and scope of CCUS-EOR reservoir screening criteria in China. The weights of parameters with respect to their influences on CCUS-EOR were determined through principal component analysis. The results show that there are 14 key parameters affecting CO₂ flooding, which can be categorized into four levels. For the first level, the crude oil-CO₂ miscibility index holds the greatest weight of 0.479. It encompasses seven parameters: initial formation pressure, current formation pressure, temperature, depth, C₂–C₁₅ molar content, residual oil saturation, and minimum miscibility pressure. The second level consists of the crude oil mobility index, which has a weight of 0.249. This index includes four parameters: porosity, permeability, density, and viscosity. The third level pertains to the index of reservoir tectonic characteristics, with a weight of 0.141. It comprises two parameters: permeability variation coefficient and average effective thickness. Lastly, the fourth level focuses on the index of reservoir property change, with a weight of 0.131, which solely considers the pressure maintenance level. Based on the CCUS-EOR reservoir screening criteria and index weights established in this study, comprehensive scores for CCUS-EOR were calculated for six blocks in China. Among these, five blocks are deemed suitable for CCUS-EOR. Based on the comprehensive scoring results, a planning for field application of CCUS-EOR is proposed. The study provides a rational method to evaluate the CCUS-EOR reservoir screening and field application in continental reservoirs in China. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

21 pages, 6680 KiB

Open AccessArticle

Simulations of CO₂ Dissolution in Porous Media Using the Volume-of-Fluid Method

by Mohammad Hossein Golestan and Carl Fredrik Berg

Energies 2024, 17(3), 629; https://doi.org/10.3390/en17030629 - 28 Jan 2024

Viewed by 802

Abstract

Traditional investigations of fluid flow in porous media often rely on a continuum approach, but this method has limitations as it does not account for microscale details. However, recent progress in imaging technology allows us to visualize structures within the porous medium directly. This capability provides a means to confirm and validate continuum relationships. In this study, we present a detailed analysis of the dissolution trapping dynamics that take place when supercritical CO₂ (scCO₂) is injected into a heterogeneous porous medium saturated with brine. We present simulations based on the volume-of-fluid (VOF) method to model the combined behavior of two-phase fluid flow and mass transfer at the pore scale. These simulations are designed to capture the dynamic dissolution of scCO₂ in a brine solution. Based on our simulation results, we have revised the Sherwood correlations: We expanded the correlation between Sherwood and Peclet numbers, revealing how the mobility ratio affects the equation. The expanded correlation gave improved correlations built on the underlying displacement patterns at different mobility ratios. Further, we analyzed the relationship between the Sherwood number, which is based on the Reynolds number, and the Schmidt number. Our regression on free parameters yielded constants similar to those previously reported. Our mass transfer model was compared to experimental models in the literature, showing good agreement for interfacial mass transfer of CO₂ into water. The results of this study provide new perspectives on the application of non-dimensional numbers in large-scale (field-scale) applications, with implications for continuum scale modeling, e.g., in the field of geological storage of CO₂ in saline aquifers. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

13 pages, 2326 KiB

Open AccessArticle

Experimental Study on Carbon Dioxide Flooding Technology in the Lunnan Oilfield, Tarim Basin

by Zangyuan Wu, Qihong Feng, Yongliang Tang, Daiyu Zhou and Liming Lian

Energies 2024, 17(2), 386; https://doi.org/10.3390/en17020386 - 12 Jan 2024

Viewed by 538

Abstract

The Lunnan Oilfield in the Tarim Basin is known for its abundant oil and gas resources. However, the marine clastic reservoir in this oilfield poses challenges due to its tightness and difficulty in development using conventional water drive methods. To improve the recovery rate, this study focuses on the application of carbon dioxide flooding after a water drive. Indoor experiments were conducted on the formation fluids of the Lunnan Oil Formation, specifically investigating gas injection expansion, thin tube, long core displacement, oil and gas phase permeability, and solubility. By injecting carbon dioxide under the current formation pressure, the study explores the impact of varying amounts of carbon dioxide on crude oil extraction capacity, high-pressure physical parameters of crude oil, and phase characteristics of formation fluids. Additionally, the maximum dissolution capacity of carbon dioxide in formation water is analyzed under different formation temperatures and pressures. The research findings indicate that the crude oil extracted from the Lunnan Oilfield exhibits specific characteristics such as low viscosity, low freezing point, low-medium sulfur content, high wax content, and medium colloid asphaltene. The measured density of carbon dioxide under the conditions of the oil group is 0.74 g/cm³, which closely matches the density of crude oil. Additionally, the viscosity of carbon dioxide is 0.0681 mPa·s, making it well-suited for carbon dioxide flooding. With an increase in the amount of injected carbon dioxide, the saturation pressure and gas-oil ratio of the crude oil also increase. As the pressure rises, carbon dioxide dissolves rapidly into the crude oil, resulting in a gradual increase in the gas-oil ratio, expansion coefficient, and saturation pressure. As the displacement pressure decreases, the degree of carbon dioxide displacement initially decreases slowly, followed by a rapid decrease. Moreover, an increase in the injection rate of carbon dioxide pore volume leads to a rapid initial improvement in oil-displacement efficiency, followed by a slower increase. Simultaneously, the gas-oil ratio exhibits a slow increase initially, followed by a rapid rise. Furthermore, as the displacement pressure increases, the solubility of carbon dioxide in water demonstrates a linear increase. These research findings provide valuable theoretical data to support the use of carbon dioxide flooding techniques for enhancing oil recovery. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

24 pages, 5737 KiB

Open AccessArticle

Front Movement and Sweeping Rules of CO₂ Flooding under Different Oil Displacement Patterns

by Xiang Qi, Tiyao Zhou, Weifeng Lyu, Dongbo He, Yingying Sun, Meng Du, Mingyuan Wang and Zheng Li

Energies 2024, 17(1), 15; https://doi.org/10.3390/en17010015 - 19 Dec 2023

Viewed by 699

Abstract

CO₂ flooding is a pivotal technique for significantly enhancing oil recovery in low-permeability reservoirs. The movement and sweeping rules at the front of CO₂ flooding play a critical role in oil recovery; yet, a comprehensive quantitative analysis remains an area in need of refinement. In this study, we developed 1-D and 2-D numerical simulation models to explore the sweeping behavior of miscible, immiscible, and partly miscible CO₂ flooding patterns. The front position and movement rules of the three CO₂ flooding patterns were determined. A novel approach to the contour area calculation method was introduced to quantitatively characterize the sweep coefficients, and the sweeping rules are discussed regarding the geological parameters, oil viscosity, and injection–production parameters. Furthermore, the Random Forest (RF) algorithm was employed to identify the controlling factor of the sweep coefficient, as determined through the use of out-of-bag (OOB) data permutation analysis. The results showed that the miscible front was located at the point of maximum CO₂ content in the oil phase. The immiscible front occurred at the point of maximum interfacial tension near the production well. Remarkably, the immiscible front moved at a faster rate compared with the miscible front. Geological parameters, including porosity, permeability, and reservoir thickness, significantly impacted the gravity segregation effect, thereby influencing the CO₂ sweep coefficient. Immiscible flooding exhibited the highest degree of gravity segregation, with a maximum gravity segregation degree (GSD) reaching 78.1. The permeability ratio was a crucial factor, with a lower limit of approximately 5.0 for reservoirs suitable for CO₂ flooding. Injection–production parameters also played a pivotal role in terms of the sweep coefficient. Decreased well spacing and increased gas injection rates were found to enhance sweep coefficients by suppressing gravity segregation. Additionally, higher gas injection rates could improve the miscibility degree of partly miscible flooding from 0.69 to 1.0. Oil viscosity proved to be a significant factor influencing the sweep coefficients, with high seepage resistance due to increasing oil viscosity dominating the miscible and partly miscible flooding patterns. Conversely, gravity segregation primarily governed the sweep coefficient in immiscible flooding. In terms of controlling factors, the permeability ratio emerged as a paramount influence, with a factor importance value (FI) reaching 1.04. The findings of this study can help for a better understanding of sweeping rules of CO₂ flooding and providing valuable insights for optimizing oil recovery strategies in the field applications of CO₂ flooding. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

23 pages, 5750 KiB

Open AccessArticle

Mechanism and Quantitative Characterization of Wettability on Shale Surfaces: An Experimental Study Based on Atomic Force Microscopy (AFM)

by Xu Huo, Linghui Sun, Zhengming Yang, Junqian Li, Chun Feng, Zhirong Zhang, Xiuxiu Pan and Meng Du

Energies 2023, 16(22), 7527; https://doi.org/10.3390/en16227527 - 10 Nov 2023

Viewed by 875

Abstract

Wettability, as a vital tool for analyzing and describing oil flow, plays a significant role in determining oil/water relative permeability, residual oil distribution, and on–site recovery efficiency. Although the contact angle method is widely used for measuring wetting behavior, it is susceptible to the effects of surface roughness, oil–water saturation, and the distribution of mixed wetting within the range of droplet sizes. Additionally, millimeter–scale droplets fail to accurately represent the wetting distribution and the influencing factors at the micro/nano–scale. Therefore, this study presents a comprehensive investigation of the microstructure and wettability of shale samples. The characterization of the samples was performed using scanning electron microscopy (SEM) and atomic force microscopy (AFM) techniques to gain insights into their microscopic features, surface properties, and wettability. Results demonstrate the following: (1) Quartz and clay minerals tended to exhibit rough surface topography, appearing as darker areas (DA) under scanning electron microscopy (SEM). It is worth noting that plagioclase minerals exhibited brighter areas (BA) under SEM. (2) An increase in the content of minerals such as quartz and clay minerals was observed to decrease the surface oil wetting behavior. In contrast, plagioclase feldspar exhibited an opposite trend. (3) Based on the adhesive forces of the samples towards oil or water, a wetting index, I, was established to evaluate the wettability of shale at a microscale. The dimensionless contact angle W, obtained by normalizing the contact angle measurement, also consistently indicated oil wetting behavior. (4) By comparing the differences between I and W, it was observed that surface roughness significantly affected the behavior of water droplets. The presence of roughness impeded the contact between the solid and liquid phases, thus influencing the accuracy of the wetting results. Organic matter also plays a significant role in influencing surface wettability, and its distribution within the shale samples can lead to localized variations in wettability. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

21 pages, 10028 KiB

Open AccessArticle

Machine-Learning-Based Approach to Optimize CO₂-WAG Flooding in Low Permeability Oil Reservoirs

by Ming Gao, Zhaoxia Liu, Shihao Qian, Wanlu Liu, Weirong Li, Hengfei Yin and Jinhong Cao

Energies 2023, 16(17), 6149; https://doi.org/10.3390/en16176149 - 24 Aug 2023

Cited by 3 | Viewed by 1257

Abstract

One of the main applications of carbon capture, utilization, and storage (CCUS) technology in the industry is carbon-dioxide-enhanced oil recovery (CO₂-EOR). However, accurately and rapidly assessing their application potential remains a major challenge. In this study, a numerical model of the CO₂-WAG technique was developed using the reservoir numerical simulation software CMG (Version 2021), which is widely used in the field of reservoir engineering. Then, 10,000 different reservoir models were randomly generated using the Monte Carlo method for numerical simulations, with each having different formation physical parameters, fluid parameters, initial conditions, and injection and production parameters. Among them, 70% were used as the training set and 30% as the test set. A comprehensive analysis was conducted using eight different machine learning regression methods to train and evaluate the dataset. After evaluation, the XGBoost algorithm emerged as the top-performing method and was selected as the optimal approach for the prediction and optimization. By integrating the production prediction model with a particle swarm optimizer (PSO), a workflow for optimizing the CO₂-EOR parameters was developed. This process enables the rapid optimization of the CO₂-EOR parameters and the prediction of the production for each period based on cumulative production under different geological conditions. The proposed XGBoost-PSO proxy model accurately, reliably, and efficiently predicts production, thereby making it an important tool for optimizing CO₂-EOR design. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

13 pages, 3209 KiB

Open AccessArticle

Effect of H₂O Content on the Corrosion Behavior of X52 Steel in Supercritical CO₂ Streams Containing O₂, H₂S, SO₂ and NO₂ Impurities

by Jia Liu, Dengzun Yao, Kai Chen, Chao Wang, Chong Sun, Huailiang Pan, Fanpeng Meng, Bin Chen and Lili Wang

Energies 2023, 16(17), 6119; https://doi.org/10.3390/en16176119 - 22 Aug 2023

Cited by 2 | Viewed by 806

Abstract

In this study, the corrosion behavior of X52 pipeline steel affected by H₂O content in supercritical CO₂ streams containing O₂, H₂S, SO₂ and NO₂ impurities was investigated by the weight loss test and surface characterization. The corrosion differences of the steel in impure supercritical CO₂ streams containing different H₂O contents were analyzed. The influence of the variation of H₂O content on the corrosion mechanism of steel in the complex impurity-containing supercritical CO₂ streams was discussed. The results show that the H₂O content limit is 100 ppmv in supercritical CO₂ streams containing 200 ppmv O₂, 200 ppmv H₂S, 200 ppmv SO₂ and 200 ppmv NO₂ at 10 MPa and 50 °C. The impurities and their interactions significantly promote the formation of corrosive aqueous phase, thereby exacerbating the corrosion of X52 steel. The corrosion process of X52 steel in the environment with a low H₂O content is controlled by the products of impurity reactions, whereas the impurities and the products of impurity reactions jointly control the corrosion process of the steel in the environment with a high H₂O content. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

Review

Jump to: Research

24 pages, 1003 KiB

Open AccessReview

Carbon Capture and Storage in Depleted Oil and Gas Reservoirs: The Viewpoint of Wellbore Injectivity

by Reyhaneh Ghorbani Heidarabad and Kyuchul Shin

Energies 2024, 17(5), 1201; https://doi.org/10.3390/en17051201 - 2 Mar 2024

Viewed by 798

Abstract

Recently, there has been a growing interest in utilizing depleted gas and oil reservoirs for carbon capture and storage. This interest arises from the fact that numerous reservoirs have either been depleted or necessitate enhanced oil and gas recovery (EOR/EGR). The sequestration of CO₂ in subsurface repositories emerges as a highly effective approach for achieving carbon neutrality. This process serves a dual purpose by facilitating EOR/EGR, thereby aiding in the retrieval of residual oil and gas, and concurrently ensuring the secure and permanent storage of CO₂ without the risk of leakage. Injectivity is defined as the fluid’s ability to be introduced into the reservoir without causing rock fracturing. This research aimed to fill the gap in carbon capture and storage (CCS) literature by examining the limited consideration of injectivity, specifically in depleted underground reservoirs. It reviewed critical factors that impact the injectivity of CO₂ and also some field case data in such reservoirs. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

18 pages, 3991 KiB

Open AccessReview

Research Progress on CO₂ Capture, Utilization, and Storage (CCUS) Based on Micro-Nano Fluidics Technology

by Xiuxiu Pan, Linghui Sun, Xu Huo, Chun Feng and Zhirong Zhang

Energies 2023, 16(23), 7846; https://doi.org/10.3390/en16237846 - 29 Nov 2023

Cited by 1 | Viewed by 920

Abstract

The research and application of CO₂ storage and enhanced oil recovery (EOR) have gradually emerged in China. However, the vast unconventional oil and gas resources are stored in reservoir pores ranging from several nanometers to several hundred micrometers in size. Additionally, CO₂ geological sequestration involves the migration of fluids in tight caprock and target layers, which directly alters the transport and phase behavior of reservoir fluids at different scales. Micro- and nanoscale fluidics technology, with their advantages of in situ visualization, high temperature and pressure resistance, and rapid response, have become a new technical approach to investigate gas–liquid interactions in confined domains and an effective supplement to traditional core displacement experiments. The research progress of micro–nano fluidics visualization technology in various aspects, such as CO₂ capture, utilization, and storage, is summarized in this paper, and the future development trends and research directions of micro–nano fluidics technology in the field of carbon capture, utilization, and storage (CCUS) are predicted. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures

Figure 1

24 pages, 11614 KiB

Open AccessReview

CO₂ Mineralized Sequestration and Assistance by Microorganisms in Reservoirs: Development and Outlook

by Shumin Ni, Weifeng Lv, Zemin Ji and Kai Wang

Energies 2023, 16(22), 7571; https://doi.org/10.3390/en16227571 - 14 Nov 2023

Cited by 1 | Viewed by 998

Abstract

The goals of carbon neutrality and peak carbon have officially been proposed; consequently, carbon dioxide utilization and sequestration technology are now in the limelight. Injecting carbon dioxide into reservoirs and solidifying and sequestering it in the form of carbonates after a series of geochemical reactions not only reduces carbon emissions but also prevents carbon dioxide from leaking out of the formation. Carbon dioxide mineralization sequestration, which has good stability, has been considered the best choice for large-scale underground CO₂ sequestration. To provide a comprehensive exploration of the research and prospective advancements in CO₂ mineralization sequestration within Chinese oil and gas reservoirs, this paper undertakes a thorough review of the mechanisms involved in CO₂ mineralization and sequestration. Special attention is given to the advancing front of carbon dioxide mineralization, which is driven by microbial metabolic activities and the presence of carbonic anhydrase within oil and gas reservoirs. The paper presents an in-depth analysis of the catalytic mechanisms, site locations, and structural attributes of carbonic anhydrase that are crucial to the mineralization processes of carbon dioxide. Particular emphasis is placed on delineating the pivotal role of this enzyme in the catalysis of carbon dioxide hydration and the promotion of carbonate mineralization and, ultimately, in the facilitation of efficient, stable sequestration. Full article

(This article belongs to the Special Issue Advances in Carbon Capture, Utilization and Storage Technologies (CCUS))

► Show Figures