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Feature Papers in Carbon Capture, Utilization, and Storage

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A topical collection in Energies (ISSN 1996-1073). This collection belongs to the section "B3: Carbon Emission and Utilization".

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Dr. Qi Liu

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Unconventional Petroleum Research Institute, China University of Petroleum, Beijing 102249, China
Interests: carbon capture, utilization and storage; enhanced oil recovery

Dr. Hailong Tian

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Key Laboratory of Groundwater Resources and Environment, Ministry of Education, Jilin University, Changchun 130021, China
Interests: reactive transport modeling; geologic carbon dioxide sequestration; natural gas hydrate accumulation
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Prof. Dr. Liwei Zhang

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State Key Laboratory of Geomechanics and Geotechnical Engineering, Institute of Rock and Soil Mechanics, Chinese Academy of Sciences, Wuhan 430071, China
Interests: CO₂ storage; wellbore cement; risk assessment; reactive transport
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Dr. Fei Jiang

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Department of Mechanical Engineering, Graduate School of Sciences and Technology for Innovation, Yamaguchi University, 2-16-1 Tokiwadai, Ube, Yamaguchi 755-8611, Japan
Interests: carbon capture and storage; multiphase multi-component and turbulence flow; computational fluid dynamics; lattice boltzmann method (LBM); high-performance computing (GPU computing); rock physics

Dr. Zhijie Yang

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School of Environment and Resources, Jilin University, Changchun 130015, China
Interests: carbon capture, utilization, and storage

Topical Collection Information

Dear Colleagues,

Carbon capture, utilization, and storage (CCUS) is a promising way to mitigate CO₂emissions from centralized sources (e.g., power generation and industrial facilities), or directly from the atmosphere. Due to the accelerated pace of industrialization and the aggravation of global warming, more and more countries have attached importance to CO₂ capture projects. The earliest large-scale CCUS project is the Terrel project implemented in the United States in 1972. The United States, Canada, Australia, Japan, and the United Arab Emirates have accelerated the industrialization of CO₂ capture projects. There are many sources of CO₂ emissions in modern industrial production, such as cement, iron and steel, electric power, coal chemical and refining plants, etc. In view of CO₂ emissions, various industries have carried out important research centered around CO₂ capture, utilization, and storage. According to the characteristics of each industry, a variety of technologies and methods for CO₂ capture, utilization, and storage have been formed. In order to exchange recent advances and lessons learned nationally and internationally, and to explore scientific and technological issues related to CCUS breakthrough, Energies plans to publish a collection on “Carbon Capture, Utilization, and Storage (CCUS)”. This Topical Collection aims to present and disseminate the most recent advances related to science and technologies related to CO₂ capture, utilization, and storage.

Interested topics include but not limited to: (1) thermal–hydrological–mechanical–chemical (THMC) coupling processes in CCUS; (2) numerical modelling and simulation; (3) containment and environmental impact; (4) regulatory framework, financing, economical, and social issues related to CCUS; (5) subsurface flow and transport; (6) pore-scale modelling of CCUS; (7) computational methods for flow in porous media; and (8) CO₂ separation systems

Dr. Qi Liu
Dr. Hailong Tian
Prof. Dr. Liwei Zhang
Dr. Fei Jiang
Dr. Zhijie Yang
Collection Editors

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Keywords

carbon capture, utilization, and storage (CCUS)
CO₂ geological storage (CGS)
CO₂-enhanced oil recovery (CO₂-EOR)
flow and transport in porous systems
pore-scale modelling of CCUS

Published Papers (11 papers)

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2024

Jump to: 2023

19 pages, 9395 KiB

Open AccessArticle

Numerical Simulation Study of Salt Cavern CO₂ Storage in Power-to-Gas System

by Weizheng Bai, Jun Lu, Jian Wang, Xinghui Fu, Yaping Fu, Yashuai Huang, Xiao Wang and Xilin Shi

Energies 2024, 17(22), 5786; https://doi.org/10.3390/en17225786 - 20 Nov 2024

Viewed by 326

Abstract

China’s renewable energy sector is experiencing rapid growth, yet its inherent intermittency is creating significant challenges for balancing power supply and demand. Power-to-gas (PtG) technology, which converts surplus electricity into combustible gas, offers a promising solution. Salt caverns, due to their favorable geological properties, are among the best choices for large-scale underground energy storage in PtG systems. CO₂ leakage along the interlayer and salt rock–interlayer interfaces is a key constraint on the CO₂ tightness of subsurface salt caverns. This paper focuses on the critical issue of tightness within salt cavern CO₂ storage, particularly in the Jintan region. A coupled hydro-mechanics mathematical model is developed to investigate CO₂ transportation and leakage in bedded salt caverns, with key variables such as permeability range, pore pressure evolution, and permeability changes being analyzed. The results reveal that permeability plays a decisive role in determining the CO₂ transportation rate and leakage extent within the salt rock layer. Notably, the CO₂ transportation rate and influence range in the mudstone interlayer are significantly larger than those in the salt rock over the same period. However, with prolonged storage time, the CO₂ transportation rate and pressure increase in both salt rock and mudstone interlayer exhibit a decreasing trend, eventually stabilizing as the CO₂ pressure front reaches the boundary of the simulation domain. Furthermore, elevated operating pressure markedly expands the permeability range and results in higher cumulative leakage. For a specific salt cavern, the CO₂ leakage range can reach up to 142 m, and the leakage volume can reach 522.5 tonnes with the increase in operating pressure during 35 years of operation. Therefore, the setting of operational pressure should fully consider the influence of permeability and mechanical strength of the salt rock and mudstone interlayer. These findings provide valuable insights into optimizing the sealing performance of salt cavern CO₂ storage systems under varying conditions. Full article

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19 pages, 16459 KiB

Open AccessArticle

Characterization of Stages of CO₂-Enhanced Oil Recovery Process in Low-Permeability Oil Reservoirs Based on Core Flooding Experiments

by Yutong Zhu, Xinwen Wang, Yulong Kang, Chaobin Guo, Qingcheng He and Cai Li

Energies 2024, 17(21), 5469; https://doi.org/10.3390/en17215469 - 31 Oct 2024

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Abstract

Understanding the CO₂ displacement mechanism in ultra-low-permeability reservoirs is essential for improving oil recovery. In this research, a series of displacement experiments were conducted on sandstone core samples from the Chang 6 reservoir in the Huaziping area using a multifunctional core displacement apparatus and Nuclear Magnetic Resonance (NMR) technology. The experiments were designed under conditions of constant pressure, variable pressure, and constant effective confining stress to simulate various reservoir scenarios. The results indicated that the distribution characteristics of the pore structure in the rock samples significantly influenced the CO₂ displacement efficiency. Specifically, under identical conditions, rock cores with a higher macropore ratio exhibited a significantly enhanced recovery rate, reaching 68.21%, which represents a maximum increase of 31.97% compared to cores with a lower macropore ratio. Though fractures can facilitate CO₂ flowing through pores, the confining pressure applied during displacement caused a partial closure of fractures, resulting in reduced rock permeability. Based on the oil-to-gas ratio and oil recovery in the outlet section of the fractured rock samples, the CO₂ displacement process exhibited five stages of no gas, a small amount of gas, gas breakthrough, large gas channeling, and gas fluctuation. Although the displacement stage of different cores varies, the breakthrough stage consistently occurs within the range of 2 PV. These insights not only enhance our understanding of CO₂ displacement mechanisms in low-permeability reservoirs but also provide actionable data to inform the development of more effective CO₂-EOR strategies, significantly impacting industrial practices. Full article

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35 pages, 2134 KiB

Open AccessFeature PaperReview

Geochemistry in Geological CO₂ Sequestration: A Comprehensive Review

by Jemal Worku Fentaw, Hossein Emadi, Athar Hussain, Diana Maury Fernandez and Sugan Raj Thiyagarajan

Energies 2024, 17(19), 5000; https://doi.org/10.3390/en17195000 - 8 Oct 2024

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Abstract

The increasing level of anthropogenic CO₂ in the atmosphere has made it imperative to investigate an efficient method for carbon sequestration. Geological carbon sequestration presents a viable path to mitigate greenhouse gas emissions by sequestering the captured CO₂ deep underground in rock formations to store it permanently. Geochemistry, as the cornerstone of geological CO₂ sequestration (GCS), plays an indispensable role. Therefore, it is not just timely but also urgent to undertake a comprehensive review of studies conducted in this area, articulate gaps and findings, and give directions for future research areas. This paper reviews geochemistry in terms of the sequestration of CO₂ in geological formations, addressing mechanisms of trapping, challenges, and ways of mitigating challenges in trapping mechanisms; mineralization and methods of accelerating mineralization; and the interaction between rock, brine, and CO₂ for the long-term containment and storage of CO₂. Mixing CO₂ with brine before or during injection, using microbes, selecting sedimentary reservoirs with reactive minerals, co-injection of carbonate anhydrase, and enhancing the surface area of reactive minerals are some of the mechanisms used to enhance mineral trapping in GCS applications. This review also addresses the potential challenges and opportunities associated with geological CO₂ storage. Challenges include caprock integrity, understanding the lasting effects of storing CO₂ on geological formations, developing reliable models for monitoring CO₂–brine–rock interactions, CO₂ impurities, and addressing public concerns about safety and environmental impacts. Conversely, opportunities in the sequestration of CO₂ lie in the vast potential for storing CO₂ in geological formations like depleted oil and gas reservoirs, saline aquifers, coal seams, and enhanced oil recovery (EOR) sites. Opportunities include improved geochemical trapping of CO₂, optimized storage capacity, improved sealing integrity, managed wellbore leakage risk, and use of sealant materials to reduce leakage risk. Furthermore, the potential impact of advancements in geochemical research, understanding geochemical reactions, addressing the challenges, and leveraging the opportunities in GCS are crucial for achieving sustainable carbon mitigation and combating global warming effectively. Full article

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15 pages, 3644 KiB

Open AccessArticle

Hybrid Advanced Control Strategy for Post-Combustion Carbon Capture Plant by Integrating PI and Model-Based Approaches

by Flavia-Maria Ilea, Ana-Maria Cormos, Vasile Mircea Cristea and Calin-Cristian Cormos

Energies 2024, 17(12), 2886; https://doi.org/10.3390/en17122886 - 12 Jun 2024

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Abstract

Even though the energy penalties and solvent regeneration costs associated with amine-based absorption/stripping systems are important challenges, this technology remains highly recommended for post-combustion decarbonization systems given its proven capture efficacy and technical maturity. This study introduces a novel centralized and decentralized hybrid control strategy for the post-combustion carbon capture plant, aimed at mitigating main disturbances and sustaining high system performance. The strategy is rooted in a comprehensive mathematical model encompassing absorption and desorption columns, heat exchangers and a buffer tank, ensuring smooth operation and energy efficiency. The buffer tank is equipped with three control loops to finely regulate absorber inlet solvent solution parameters, preventing disturbance recirculation from the desorber. Additionally, a model-based controller, utilizing the model predictive control (MPC) algorithm, maintains a carbon capture yield of 90% and stabilizes the reboiler liquid temperature at 394.5 K by manipulating the influent flue gas to the lean solvent flowrates ratio and the heat duty of the reboiler. The hybrid MPC approach reveals efficiency in simultaneously managing targeted variables and handling complex input–output interactions. It consistently maintains the controlled variables at desired setpoints despite CO₂ flue gas flow disturbances, achieving reduced settling time and low overshoot results. The hybrid control strategy, benefitting from the constraint handling ability of MPC, succeeds in keeping the carbon capture yield above the preset minimum value of 86% at all times, while the energy performance index remains below the favorable value of 3.1 MJ/kgCO₂. Full article

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11 pages, 2147 KiB

Open AccessArticle

Mitigating Asphaltene Deposition in CO₂ Flooding with Carbon Quantum Dots

by Qi Liu, Yangwen Zhu, Hang Ye, Haiying Liao, Quanqi Dai, Michelle Tiong, Chenggang Xian and Dan Luo

Energies 2024, 17(11), 2758; https://doi.org/10.3390/en17112758 - 5 Jun 2024

Cited by 1 | Viewed by 721

Abstract

Carbon capture, utilization, and storage (CCUS) technology has emerged as a pivotal measure in mitigating global climate change. Notably, CO₂-EOR is esteemed for its dual function of sequestering CO₂ and enhancing oil recovery. However, this process presents challenges related to asphaltene deposition during CO₂ flooding, leading to reservoir damage, such as pore plugging. This study systematically manipulated the factors inducing CO₂-induced asphaltene deposition, elucidating the mechanisms and magnitudes of asphaltene precipitation. Additionally, the study investigated the efficacy of carbon quantum dots (CQDs) in mitigating asphaltene deposition. Experimental findings indicated a positive correlation between asphaltene deposition and level of asphaltene content, CO₂ injection ratio, and temperature. Moreover, with an increase in experimental pressure, the asphaltene deposition rate demonstrated an initial increase followed by a subsequent decline. Leveraging their favorable compatibility with asphaltene, CQDs effectively suppressed the aggregation behavior of asphaltene. In the presence of CQDs, the onset of asphaltene precipitation was delayed from 45 V% to 55 V%, with the highest inhibition rate reaching approximately 36% at an optimal CQD concentration of 20 mg/L. This study proposes a novel approach to address asphaltene deposition issues in CO₂-EOR processes, contributing to the enhancement of recovery rates in low-permeability reservoirs. Full article

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30 pages, 4051 KiB

Open AccessEditor’s ChoiceArticle

Integrated Black Oil Modeling for Efficient Simulation and Optimization of Carbon Storage in Saline Aquifers

by Ismail Ismail, Sofianos Panagiotis Fotias, Dimitris Avgoulas and Vassilis Gaganis

Energies 2024, 17(8), 1914; https://doi.org/10.3390/en17081914 - 17 Apr 2024

Cited by 2 | Viewed by 1250

Abstract

Carbon capture and storage technologies play a crucial role in mitigating climate change by capturing and storing carbon dioxide emissions underground. Saline aquifers, among other geological formations, hold promise for long-term CO₂ storage. However, accurately assessing their storage capacity and CO₂ behavior underground necessitates advanced numerical simulation and modeling techniques. In this study, we introduce an approach based on a solubility thermodynamic model that leverages cubic equations of state offline from the simulator. This approach enables the precise prediction of CO₂–brine equilibrium properties and facilitates the conversion of compositional data into black oil PVT data suitable for black oil simulations. By incorporating industry-scale saline aquifer properties, we simulate a carbon storage scheme using the black oil model technique, significantly reducing computation time by at least four times while preserving the essential physical phenomena observed in underground carbon storage operations. A comparative analysis between black oil and compositional simulations reveals consistent results for reservoir pressure, CO₂ saturation distributions, and mass fraction of trapping mechanisms, with differences of less than 4%. This validation underscores the reliability and efficiency of integrating the black oil model technique into carbon storage simulations in saline aquifer formations, offering tangible benefits to industry operators and regulators by striking a balance between accuracy and efficiency. The capability of this approach to extend to temperatures of up to 300 °C and pressures of up to 600 bars broadens its applicability beyond conventional CCS applications, serving as a valuable tool for optimizing decision-making processes in CCS projects, particularly in scenarios where profitability may be marginal. Full article

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13 pages, 2228 KiB

Open AccessEditor’s ChoiceArticle

Thermodynamic Feasibility Evaluation of Alkaline Thermal Treatment Process for Hydrogen Production and Carbon Capture from Biomass by Process Modeling

by Yujung Jung and Sanghun Lee

Energies 2024, 17(7), 1661; https://doi.org/10.3390/en17071661 - 30 Mar 2024

Viewed by 1045

Abstract

Hydrogen is attracting attention as a low-carbon fuel. In particular, economical hydrogen production technologies without carbon emissions are gaining increasing attention. Recently, alkaline thermal treatment (ATT) has been proposed to reduce carbon emissions by capturing carbon in its solid phase during hydrogen production. By adding an alkali catalyst to the conventional thermochemical hydrogen production reaction, ATT enables carbon capture through the reaction of an alkali catalyst and carbon. In this study, a thermodynamic feasibility evaluation was carried out, and the effects of the process conditions for ATT with wheat straw grass (WSG) as biomass were investigated using Aspen Plus software V12.1. First, an ATT process model was developed, and basic thermodynamic equilibrium compositions were obtained in various conditions. Then, the effects of the process parameters of the reactor temperature and the mass ratio of NaOH/WSG (alkali/biomass, A/B value) were analyzed. Finally, the product gas compositions, process efficiency, and amount of carbon capture were evaluated. The results showed that the ATT process could be an efficient hydrogen production process with carbon capture, and the optimal process conditions were a reactor temperature of 800 °C, an A/B value of three, and a flow rate of steam of 6.9 × 10⁻⁵ L/min. Under these conditions, the maximum efficiency and the amount of carbon dioxide captured were 56.9% and 28.41 mmol/g WSG, respectively. Full article

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26 pages, 2536 KiB

Open AccessArticle

An Assessment of CO₂ Capture Technologies towards Global Carbon Net Neutrality

by Amith Karayil, Ahmed Elseragy and Aliyu M. Aliyu

Energies 2024, 17(6), 1460; https://doi.org/10.3390/en17061460 - 18 Mar 2024

Cited by 3 | Viewed by 2156

Abstract

Carbon dioxide, the leading contributor to anthropogenic climate change, is released mainly via fossil fuel combustion, mostly for energy generation. Carbon capture technologies are employed for reducing the emissions from existing huge point sources, along with capturing them from direct air, to reduce the existing concentration. This paper provides a quantitative analysis of the various subtypes of carbon capture technologies with the aim of providing an assessment of each from technological, social, geo-political, economic, and environmental perspectives. Since the emissions intensity and quantity, along with the social–political–economic conditions, vary in different geographic regions, prioritising and finding the right type of technology is critical for achieving ambitious net-zero targets. Four main types of carbon capture technology were analysed (adsorption, absorption, membrane, and cryogenic) under four scenarios depending on the jurisdiction. The Technique for Order of Preference by Similarity to Ideal Solution (also known as the TOPSIS method) was used to establish a quantitative ranking of each, where weightages were allocated according to the emissions status and economics of each depending on the jurisdiction. Furthermore, forecasting the trends for technology types vis à vis carbon neutral targets between 2040 and 2050 was carried out by applying regression analysis on existing data and the emissions footprint of major contributing countries. The study found the membrane score to be the highest in the TOPSIS analysis in three of the four scenarios analysed. However, absorption remains the most popular for post-combustion capture despite having the highest energy penalty per ton of CO₂ capture. Overall, capture rates are well short of projections for carbon neutrality; the methodology put forward for prioritising and aligning appropriate technologies and the region-by-region analysis will help highlight to technocrats, governments, and policymakers the state of the art and how to best utilise them to mitigate carbon emissions—critical in achieving the net-zero goals set at various international agreements on climate change. Full article

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2023

Jump to: 2024

22 pages, 12577 KiB

Open AccessReview

Storage Sites for Carbon Dioxide in the North Sea and Their Particular Characteristics

by Sean P. Rigby and Ali Alsayah

Energies 2024, 17(1), 211; https://doi.org/10.3390/en17010211 - 30 Dec 2023

Cited by 4 | Viewed by 1666

Abstract

This paper reviews and evaluates work on the structural complexity of the potential carbon dioxide storage sites in the North Sea, including the nature of the reservoir structures, the reservoir rocks, the presence of inter-layers, faults, and fractures, and how these factors influence carbon dioxide capacity. In particular, the review emphasises the significance of studying caprocks in detail, not just the reservoir rock’s carbon dioxide storage capacity. This work also particularly considers reservoir simulation work on North Sea sites and illustrates the importance of using fully coupled flow–geomechanical–geochemical modelling to ensure that complex feedback and synergistic effects are not missed. It includes comparisons with other sites where relevant. It also discusses recent challenges and controversies that have arisen from simulations of sequestration in North Sea reservoirs and the need for comprehensive field data to resolve these issues. Full article

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32 pages, 14293 KiB

Open AccessArticle

CO₂ Injection via a Horizontal Well into the Coal Seam at the Experimental Mine Barbara in Poland

by Kamil Stańczyk, Robert Hildebrandt, Jarosław Chećko, Tomasz Urych, Marian Wiatowski, Shakil Masum, Sivachidambaram Sadasivam, Thomas Kempka, Christopher Otto, Priscilla Ernst and Hywel Rhys Thomas

Energies 2023, 16(20), 7217; https://doi.org/10.3390/en16207217 - 23 Oct 2023

Cited by 1 | Viewed by 1383

Abstract

This study, conducted as part of the ROCCS project, investigates the potential of coal seams for CO₂ sequestration through in situ tests. The in situ tests, performed at Experimental Mine Barbara in Mikołów, Poland, involved injecting CO₂ through a horizontal well into a coal seam, with variable well lengths and injection parameters. The experiments included monitoring for CO₂ leakage and migration within the coal seam. The objective was to examine the correlation between the CO₂ injection rate and the coal–CO₂ contact area, monitoring for any potential leakage. The total mass of CO₂ injected was about 7700 kg. Significant leakage, probably due to the formation of preferential pathways, prevented pressure buildup in the injection well. The results provide insights into challenges regarding CO₂ injection into coal seams, with implications for the design of commercial-scale CO₂ storage installations. Full article

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19 pages, 2926 KiB

Open AccessArticle

Development and Application of a Simulator for Simulating the Behaviors of a Geological System When Replacing CH₄ from Hydrate-Bearing Reservoirs by CO₂

by Yan Li and Hailong Tian

Energies 2023, 16(8), 3342; https://doi.org/10.3390/en16083342 - 10 Apr 2023

Cited by 1 | Viewed by 1405

Abstract

Conventional techniques for hydrate production may cause the deconstruction of hydrate, changing the geomechanical stresses of the reservoir, which could trigger the subsidence of the seafloor. A new method for replacing CH₄ from the hydrate lattice by CO₂, without damaging the mechanical structure of sediment, has been proposed. This approach can achieve both the objectives of long-term CO₂ sequestration and the safe production of CH₄ from hydrates. By coupling the Chen-Guo model into Tough+Hydrate V1.5, an updated simulator CO₂-EGHRSim V.10 (CO₂ Enhanced Gas Hydrate Recovery simulator) was developed in this work to describe the replacing processes of CH₄ from the hydrate lattice by CO₂ and to evaluate the storage potential of CO₂ and the recovery efficiency of CH₄ from the hydrate-bearing reservoirs. The developed simulator was verified using measured data obtained from laboratory experiments. The verification suggested that CO₂-EGHRSim performed well in predicting the replacing processes of CH₄ with CO₂. The simulator was applied to calculate the CO₂ storage potential combined with the CH₄ recovery from hydrates at the site of Iġnik Sikumi on the North Slope of Alaska. The simulated results indicated that the CO₂–CH₄ exchange mostly occurred inside the gas plume, and the CO₂ hydrate was only present around the production well. The simulated CO₂ storage ratio was 0.58, and the CH₄ recovery efficiency was 25.95%. Full article

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Feature Papers in Carbon Capture, Utilization, and Storage

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Published Papers (11 papers)

2024

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2023

Jump to: 2024

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