Greenhouse Gases: Science and Technology最新文献

During CO₂ storage in deep saline aquifers, the presence of residual water has an important influence on the storage efficiency and safety. In this study, natural rock cores taken from deep reservoirs in the Ordos Basin and Fukang, Xinjiang are used as research objects. Nine groups of core-flooding experiments are performed under different CO₂/N₂ gas mixture ratios to study the influence of rock properties (mineral composition, permeability, porosity and pore structure) on the residual water. Furthermore, the geophysical and chemical properties of rock cores are analyzed by X-ray diffraction, electron microscopy, field emission scanning electron microscopy and piezoelectric mercury method. The results show that residual water saturation is a quantitative power function of drainage time. The residual water saturation is positively correlated with the total amount of quartz and feldspar and increases with increasing permeability. Moreover, both the average and median pore throat radius show a strong inverse correlation with irreducible residual water saturation; as these radius increase, the residual water saturation decreases. In contrast, the porosity and maximum pore throat radius display a weaker correlation with irreducible residual water saturation. This study is of great value for engineering practices such as the site selection of CO₂ storage projects in saline aquifer and improvement of CO₂ storage efficiency. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

Membrane contactor has emerged as a promising technology for flue gas carbon capture as it integrates the advantages of high capture efficiency of absorption technology and compact design of membrane technology. However, the integration performance could be affected by the presence of minor components such as water vapor and residual oxygen in real gas conditions, owing to vapor condensation and dynamic oxidation in gas-liquid transfer interface. Therefore, it remains a need to develop a model that enables the prediction of CO₂ removal performance of membrane contactor under industrial real gas conditions. In the present study, a multicomponent model considering the impact of water vapor and oxygen on CO₂ removal in membrane contactors was developed. The model, based on mass transfer equilibrium, gas reaction kinetics, and diffusion coefficients, describes the transport and reaction dynamics of multicomponent gases within the gas, liquid, and membrane phases. Utilizing the finite element method (FEM) for solution, the model was demonstrated with a case study of CO₂ separation from a quaternary gas mixture by a hollow fiber membrane contactor (HFMC). The results highlight the importance of considering water vapor and oxygen in the design and evaluation of industrial membrane contactor systems, offering valuable insights for enhancing CO₂ separation efficiency in practical applications. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

During the early screening phase of Carbon Capture and Storage (CCS) site evaluations limited time and data are available and hence CO₂ plume evaluations using time and data intensive reservoir simulations are almost never performed. However, there is still a need for early plume evaluations to risk and rank injection sites relative to each other. Therefore, an alternative fluid migration method called invasion percolation is adopted for the CCS screening phase to predict the extent and location of CO₂ plumes in the subsurface. Invasion percolation as part of basin modeling is a rapid method, which requires limited data and is ideal for the early screening phase. Invasion percolation results are compared to uncalibrated reservoir models, typical for the screening phase, revealing that plume location shape and size are very reasonable especially when compared to seismic observed plume outlines. It can be concluded that invasion percolation as part of basin modeling is a fit for purpose method, which can assess multiple opportunities rapidly during the early intake screening phase to risk and rank opportunities relative to each other and to build a CCS injection site portfolio. In addition to the plume evaluation, basin models can provide useful basin-scale or injection site specific pressure and temperature predictions as well as CO₂ density estimates for static volume calculations before detailed reservoir and stratigraphic models are available. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

We have previously proposed amino acid salts solutions as potential absorption liquids for direct air capture (DAC) of CO₂ from the atmosphere. However, little is known about their relevant CO₂ solubilities, CO₂ mass transfer rates, and susceptibility to oxidative and thermal degradation under conditions relevant to DAC. We report here on the overall solubility of CO₂ and CO₂ mass transfer rates into a series of amino acid salts solutions. Additionally, the robustness of various amino acid salt solutions to thermal and oxidative degradation has been assessed.

CO₂ absorption rates into the amino acid salts solutions were observed to be in the same order of magnitude as aqueous monoethanolamine (MEA), with sarcosinate and lysinate solutions providing the fastest and slowest CO₂ mass transfer rates at 25°C, respectively. Degradation data revealed that all amino acid salt solutions investigated in this study displayed elevated rates of thermal degradation at both 120 and 150°C relative to MEA. The opposite trend was observed with respect to oxidative degradation where all amino acid salt solutions showed a greater resistance to oxidative degradation than that observed for MEA under the conditions investigated here. Considering the degradation, CO₂ absorption capacity, and CO₂ mass transfer rate data, we propose the potassium salts of proline and sarcosine as the most promising amino acid salts (of those considered here) for further evaluation in DAC processes. Overall, this study provides valuable insight into the suitability of various amino acid salt solutions as absorption liquid for DAC. © 2024 The Author(s). Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons Ltd.

The transportation of CO₂ from the capture site to the storage location is a crucial phase in carbon capture, utilisation and storage (CCUS) process. For offshore operations, ship transportation is considered a viable alternative, and this would entail operations at low temperatures (down to 223.15 K). A review of the literature revealed that there is limited experimental data on CO₂-rich systems at low temperatures, thus, the need to investigate the phase behaviour of CO₂-rich systems at these conditions. This study validated and compared the accuracies of Peng–Robinson (PR) equation of state (EoS) with three different mixing rules (the classical with original and adjusted binary interaction parameters, the Wong–Sandler, and the Orbey–Wong–Sandler mixing rules) against the multi-fluid helmholtz energy approximation (MFHEA - with original and adjusted binary-specific reducing parameters) EoS in the prediction of bubble points of CO₂-rich binary systems (CO₂-CH₄, CO₂–O₂, CO₂–Ar, and CO₂–N₂) for CCUS applications. The experimental studies used for the validation of the models were conducted at low temperatures (228.15–273.15 K with overall uncertainties of 0.14 K) and for five different CO₂ mole ratios (99.5, 99, 98.5, 98 and 95% with overall uncertainties of 0.032%) using the constant composition expansion method. The overall uncertainty of the pressure measurements was 0.03 MPa. From the study, it was observed that there was a significant effect of binary interaction parameters (BIP) adjustment on the performance of PR-EoS with classical mixing rule, especially for the CO₂–N₂ system. For all the systems, the predictions of PR-EoS with the classical mixing rules and the adjusted BIPs were the most accurate in terms of the average absolute deviations from the experimental data. The model also predicted the literature data well in comparison with the other models (with less than 5% deviations for all the data points). Further analysis also proved that the model dew point predictions were in reasonable agreement with the available literature data at the considered conditions. As a result, the model could be adopted to fill the existing knowledge gaps of the studied systems at conditions (143.15–223.15 K) where experimental studies were not feasible. © 2024 The Author(s). Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons Ltd.

The persistent increase in atmospheric carbon dioxide (CO₂) concentration poses a significant contemporary challenge. Contemporary chemistry is heavily focused on sustainable solutions, particularly the photo-/electrocatalytic reduction of CO₂ and its utilization for energy storage. Despite promising prospects, efficient chemical CO₂ conversion faces obstacles such as ineffective CO₂ uptake/activation and catalyst mass transport. Covalent organic frameworks (COFs) have emerged as potential catalysts due to their precise structural design, functionalizable chemical environments, and robust architectures. COF-based materials, especially those incorporating diverse active sites like single metal sites, metal nanoparticles, and metal oxides, hold promise for CO₂ conversion and energy storage. This review sheds light on CO₂ photoreduction/electroreduction and storage in Li-CO₂ batteries catalyzed by COF-based composites, focusing on recent advancements in integrating COFs with nanoparticles for CO₂ reduction. It discusses design principles, synthesis methods, and catalytic mechanisms driving the enhanced performance of COF-based nanocomposites across various applications, including electrochemical reduction, photocatalysis, and lithium CO₂ batteries. The review also addresses challenges and prospects of COF-based catalysts for efficient CO₂ utilization, aiming to steer the development of innovative COF-based nanocomposites, thus advancing sustainable energy technologies and environmental stewardship. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

The geological storage of carbon dioxide (CO₂) represents a promising strategy for mitigating climate change by securely sequestering CO₂ emissions. This review article aims to provide a comprehensive overview of the current state of research and development in the field of geological carbon dioxide (CO₂) sequestration. We systematically examined a wide range of recent literature, focusing on advancements in numerical simulations, experimental studies, risk assessments, and monitoring techniques related to CO₂ sequestration. Literature was selected based on relevance, recency, and contribution to the understanding of key challenges and solutions in CO₂ storage, with sources spanning peer-reviewed journals, conference proceedings, and significant technical reports. Our review highlights several key themes: the integration of machine learning and advanced numerical models in predicting CO₂ behavior in subsurface formations; innovative experimental approaches to understanding the physicochemical interactions between CO₂, brine, and geological substrates; and the development of robust risk assessment frameworks to address potential leakage and induced seismicity. We also explore recent advancements in monitoring technologies, emphasizing their critical role in ensuring the long-term integrity and effectiveness of CO₂ storage sites. Overall, this review synthesizes the latest findings and identifies gaps in current knowledge, providing a roadmap for future research directions. Our aim is to enhance the understanding of CO₂ sequestration processes, support the development of safer and more efficient storage methods, and contribute to the global effort in mitigating climate change through effective carbon management strategies. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

Geological sequestration of carbon dioxide (CO₂) is an effective method to reduce greenhouse gases and an important technology for carbon neutralization. Among all geological sequestration sites, coal reservoirs are potentially effective and practicable. The Xiangzhong Depression of Hunan Province of China is selected as the research area, and the coal seam of Longtan Formation is the target reservoir in this paper. CO₂-enhanced coalbed methane (CO₂-ECBM) and CO₂ sequestration capacity are both simulated according to the laboratory experiments on reservoir parameters. During simulation, four production wells and one injection well were designed, and the simulation process can be divided into two stages: CO₂-ECBM and CO₂ geological storage. The CO₂-ECBM stage refers to CO₂ injection for increasing methane production, and the CO₂ geological storage stage aims to predict the CO₂ sequestration capacity. After that, sensitivity analyses of sequestration effect are carried out. During the simulation, when maintaining a constant pressure injection of CO₂ under the original conditions of 0.01 mD permeability, 9% porosity, and 1.47 MPa reservoir methane pressure, the total storage amount is only 0.14 × 10⁶ m³. However, the storage amount increases significantly to 6.62 × 10⁶ m³ if the permeability increases to 1.5 mD. Orthogonal simulation indicates that permeability has the greatest impact on CO₂ sequestration. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

Carbon capture and storage technologies play crucial roles in mitigating atmospheric greenhouse gases (GHGs). Pipeline transportation is the primary method of CO₂ transportation, making pipeline safety a priority. In this study, Fluent software was used to create a model for annular edge leakage flanges, which significantly differs from the traditional pinhole leakage model. This study aims to examine the impact of CO₂ pipeline flow and pressure on the diffusion of gas leaking from the flange and to develop a precise correlation between the diffusion distance and substance concentration. The results indicate that an increase in flow and pressure intensifies the diffusion of the flange leakage. Specifically, for a leakage lasting 96 s at flow rates of 0.7 and 10 m³/h, the diffusion ranges for the 5% concentration alarm threshold are 0.47 and 2.86 m, respectively. Furthermore, at a speed of 10 m/s and a pressure of 0.4 MPa, the diffusion ranges for 5 and 2% alarms are similar, spanning from 0.33 to 0.35 m. This study provides theoretical support and technical improvements to ensure the safe operation of pipelines. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

There are many economic obstacles and complex engineering problems associated with CO₂ capture and storage in saline aquifers that need to be addressed. Overcoming such challenges requires precise knowledge on the fluid phase equilibria of CO_2-brine systems. Having accurate CO₂ solubility data over a wide range of temperature and pressure can greatly assist in resolving these obstacles by improving the performance and accuracy of the thermodynamic modeling and subsequent CCS engineering success.

CO₂ solubility in pure water and NaCl solutions has been widely studied in the literature, however, there is a lack of data on CO₂ solubility at lower temperatures (below 298 K). Furthermore, limited phase equilibria data are available for CO₂ solubility in CaCl₂, MgCl₂, and KCl solutions at elevated temperatures (i.e., T > 323.15 K).

In this work, the phase equilibria of CO₂ and brine systems are investigated experimentally and theoretically. In this study, solubilities of CO₂ in pure water and various concentrations of NaCl (10, 15, 20, and 22 wt%), KCl (10, 15, and 22 wt%), CaCl₂ (7.5, 10, 15.7, and 23.4 wt%), and MgCl₂ (6.7, 11, 18, and 29 wt%) aqueous solutions are reported. All CO₂ solubilities were measures at 323.15, 373.15, and 423.15 K and over various pressure ranges, while solubilities in 10 and 20 wt% NaCl aqueous solutions were also measured over the temperature range of 263 to 298 K and pressures up to the hydrate dissociation pressure of each system. Equation of state modelling using the PC-SAFT and the Cubic Plus Association equations of state, is performed in the theoretical part of the study to validate the measured solubility data. © 2024 The Author(s). Greenhouse Gases: Science and Technology published by Society of Chemical Industry and John Wiley & Sons Ltd.