Gas Science and Engineering最新文献

{"title":"Energy and economic analysis of natural gas storage methods: insights into liquefied, compressed and solidified forms","authors":"Sowjanya Kandadai ,&nbsp;Beatrice Castellani","doi":"10.1016/j.jgsce.2026.205848","DOIUrl":"10.1016/j.jgsce.2026.205848","url":null,"abstract":"<div><div>The efficient storage of methane is a critical factor in meeting the growing global energy demand and ensuring energy security. LNG and CNG are the most commonly used storage methods for natural gas. Some countries across the world are also practising the underground natural gas storage method (UNGS). SNG (Solidified natural gas) is another promising technology to store the natural gas. This study conducts a comprehensive energy and economic analysis of various methane storage technologies, including underground gas storage (UNGS), compressed natural gas (CNG), liquefied natural gas (LNG), and solidified natural gas (SNG) utilizing hydrates. Specific energy consumption, energy density, and total costs were the key performance metrics evaluated. Results highlight that while CNG and UNGS demonstrate the lowest energy consumption, LNG offers the highest volumetric energy density (up to 17.1 GJ/m³), with SNG presenting a safer alternative with moderate costs. SNG achieves storage through hydrate formation under moderate conditions (35–100 bar, 274–287 K), but energy demands for compression and cooling remain significant. The techno-economic analysis reveals that CNG has the lowest total costs (0.175 $/kg), while LNG exhibits significant cost variability ($0.169–0.434/kg) due to diverse process technologies. SNG's cost-effectiveness is competitive with lower-end LNG and UNGS values (0.184 $/kg), especially considering its safety and environmental advantages. The findings support the tailored application of storage methods based on priorities like safety, geographical feasibility, and energy efficiency.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"147 ","pages":"Article 205848"},"PeriodicalIF":5.5,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"146038355","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Advancing seismic facies analysis and reservoir characterization: A synthetic data-augmented CNN and transfer learning workflow integrated with real seismic data","authors":"Muhammad Ali ,&nbsp;Ning Wei ,&nbsp;He Changxingyue ,&nbsp;Keyao Lin ,&nbsp;Wendong Wang ,&nbsp;Muhsan Ehsan ,&nbsp;Ren Jiang ,&nbsp;Wakeel Hussain ,&nbsp;Umar Ashraf","doi":"10.1016/j.jgsce.2025.205831","DOIUrl":"10.1016/j.jgsce.2025.205831","url":null,"abstract":"<div><div>Seismic reservoir characterization in data-limited settings is often hindered by sparse wells, limited resolution, and ambiguous facies delineation. This study develops a convolutional neural network seismic (CNNS) workflow that combines rock-physics-driven synthetic data and transfer learning to improve prediction of elastic properties and lithofacies. Pseudo-wells generated from rock physics models and nearby wells are used to simulate AVO gathers and multi-attribute seismic volumes, which are first used to pre-train the CNNS; the fully connected layers are then fine-tuned with real seismic and well-log data. Elastic property prediction (P-impedance, porosity, and density) is systematically benchmarked against conventional pre-stack seismic inversion (PSSI), a Fully Connected deep neural network (DNN), and a DNN trained with synthetic data (DNNS). Quantitative comparison shows that CNNS yields the most reliable elastic property volumes, with overall R² values of 0.9655 for P-impedance (0.9749 at a blind well), 0.9644 for density, and 0.9695 for porosity. Variogram and spatial autocorrelation analyses demonstrate that CNNS best preserves vertical resolution and anisotropic lateral continuity, whereas DNNS tends to over-smooth and PSSI/DNN exhibit higher short-wavelength noise. Based on these CNNS-derived P-impedance, porosity, and density volumes selected because they provide the most geologically consistent elastic fields lithofacies prediction is performed exclusively with CNNS, without direct facies comparison to PSSI, DNN, or DNNS. Facies are classified into four categories: non-reservoir mudstone and low, medium, and high porosity sandstone. The CNNS-based facies model shows excellent agreement with well-log interpretations and channel architecture, achieving classification accuracies of 91.02 % (mudstone), 97.05 % (low-porosity sand), 100 % (medium-porosity sand), and 98.80 % (high-porosity sand. The resulting 3D facies distribution delineates laterally continuous high-quality sandstone bodies and discontinuous injectites, providing a robust basis for targeting sweet spots and optimizing drilling strategies in complex reservoirs.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"147 ","pages":"Article 205831"},"PeriodicalIF":5.5,"publicationDate":"2026-03-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145895885","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Modeling phase behavior of nanoconfined fluids with a multi-mechanism modified Peng–Robinson equation","authors":"Kai Du ,&nbsp;Zhenhua Rui ,&nbsp;Yueliang Liu ,&nbsp;Cheng Qian ,&nbsp;Kaihu Zhou ,&nbsp;Siwei Chen ,&nbsp;Xin Wen ,&nbsp;Fanhua Zeng","doi":"10.1016/j.jgsce.2025.205830","DOIUrl":"10.1016/j.jgsce.2025.205830","url":null,"abstract":"<div><div>Understanding fluid phase behavior in nanoporous geological formations is fundamental to improving subsurface energy storage efficiency and enhancing CO₂ sequestration performance. In such confined environments, the interplay between pore scale confinement and fluid rock interactions leads to significant deviations from bulk phase thermodynamics. These deviations pose critical challenges to conventional phase equilibrium models, particularly for CO₂ hydrocarbon systems in shale reservoirs and storage formations, underscoring the need for equations of state that explicitly account for nanoscale effects. Nanoconfinement significantly alters fluid behavior by intensifying molecular interactions, introducing adsorption layers, and shifting critical properties. This work introduces a modified Peng–Robinson equation of state that incorporates three confinement related mechanisms within a unified framework, including adsorption layer thickness, confinement induced critical property shifts, and a density correction term. The density correction, which is often neglected in traditional confinement models, is shown to improve the accuracy of predicted liquid densities and interfacial tension by mitigating liquid density underestimation inherent in equation of state calculations. Experimental and molecular simulation evidence validates the proposed model for CO₂ hydrocarbon systems across nanopore sizes ranging from a few nanometers to several tens of nanometers. A one factor robustness assessment further demonstrates that interfacial tension predictions remain stable under moderate perturbations of key model parameters. The results indicate that confinement compresses phase envelopes, reduces interfacial tension, and shifts critical points toward lower pressures and temperatures, with the density correction mechanism contributing an additional reduction of approximately 8 % in interfacial tension. Furthermore, during CO₂ extraction, compositional partitioning analysis shows that lighter components preferentially enter the gas phase in smaller pores, while heavier components remain in the liquid phase, emphasizing the critical role of nanopore structure in controlling recovery efficiency. The proposed model provides a physically grounded approach for capturing confined fluid behavior and offers valuable insights for optimizing CO₂ enhanced oil recovery and subsurface carbon storage in shale and other nanoporous formations.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205830"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145840552","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Hydraulic fracturing in natural gas hydrate-bearing sediments: A coupled hydro-mechanical phase-field model with nonlinear permeability","authors":"Huangwu Lyu ,&nbsp;Xiang Sun ,&nbsp;Fanbao Cheng ,&nbsp;Sining Dai ,&nbsp;Zeshao You ,&nbsp;Zhirun Xia ,&nbsp;Yanghui Li","doi":"10.1016/j.jgsce.2025.205817","DOIUrl":"10.1016/j.jgsce.2025.205817","url":null,"abstract":"<div><div>Natural gas hydrate (NGH), a promising clean energy source, faces gas recovery challenges due to the low permeability of host sediments, which hydraulic fracturing aims to overcome. However, fracture propagation mechanisms in NGH sediments remain unclear, particularly under the combined influence of solid hydrate, stress anisotropy, and natural fractures. Therefore, we develop a nonlinear permeability model that accounts for hydrate saturation, volumetric strain, and a phase-field variable representing fractures. This model is integrated into a coupled hydro-mechanical phase-field framework and validated against experiments and numerical simulations. Results indicate that hydrates primarily facilitate fracture propagation by reducing permeability, which limits fluid leak-off and increases pressure concentration near the fracture tip, leading to earlier initiation. In addition, the increased sediment rigidity and decreased porosity caused by hydrate presence lead to higher fracture pressure and a larger fracture area under identical injection rates. In-situ stress contrast strongly influences fracture morphology and area, with higher contrast reducing initiation time and promoting faster propagation. Furthermore, natural fractures influence fracture propagation by perturbing the local principal stress field, producing branched patterns under low stress anisotropy and strip-shaped fractures under high anisotropy. These findings enhance the understanding of fracture mechanisms and help optimize fracturing strategies in NGH sediments under complex geological environments.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205817"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145738459","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Ni/γ-Al2O3 sorbents for oxygen removal from associated petroleum gas streams: selection of thermal treatment technique for the synthesis","authors":"Maxim M. Borodaevskiy,&nbsp;Yury V. Dubinin,&nbsp;Petr M. Yeletsky,&nbsp;Vadim A. Yakovlev","doi":"10.1016/j.jgsce.2025.205835","DOIUrl":"10.1016/j.jgsce.2025.205835","url":null,"abstract":"<div><div>Oxygen removal is an important step during hydrocarbon gas extraction and transportation. A promising oxygen sorbent in the form of Ni/γ-Al₂O₃ has previously been proposed due to its high availability, low cost, high oxygen removal rate and room temperature adsorption capabilities. However, to create an effective reusable sorbent, the proposed material must have a substantial capacity and be easily reducible. The main goal of this work is to assess an effect of such basic synthesis parameters as nickel loading (5–15 wt %) and thermal treatment (air calcination or direct hydrogen reduction) on the characteristics of Ni/γ-Al₂O₃ oxygen sorbents. For this, a series of sorbents was prepared by incipient wetness impregnation and characterized by XRD, TEM, low-temperature nitrogen adsorption, temperature programmed reduction in hydrogen (TPR-H₂), H₂ and O₂ pulse chemisorption as well as tested in the oxygen removal from the mixture with methane under breakthrough conditions. The resulting materials showed an oxygen uptake capacity up to 7 ml_O2·g_sorb⁻¹ and a low dispersion (4–10 %). It was noted that direct hydrogen reduction led to the formation of smaller and more easily reduced surface particles of NiO, as compared to pre-calcination, which resulted in the formation of more inert Ni-containing spinel particles. During multiple oxygen sorption tests, it was also observed that pre-calcined sample noticeably increased their oxygen uptake capacity after the first oxidation-reduction cycle, which may be related to the nickel redispersion.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205835"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145884261","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Lattice Boltzmann simulation of CO2 mineral dissolution mechanisms in heterogeneous shale pore structures","authors":"Wei Zhao ,&nbsp;Liang Luo ,&nbsp;Han Wang ,&nbsp;Jiacheng Dai ,&nbsp;Yuxuan Xia ,&nbsp;Stefan Iglauer ,&nbsp;Jianchao Cai","doi":"10.1016/j.jgsce.2025.205823","DOIUrl":"10.1016/j.jgsce.2025.205823","url":null,"abstract":"<div><div>Carbon dioxide mineral dissolution in shale formations represents a promising mechanism for enhancing hydrocarbon recovery and achieving CO₂ geological storage. However, the strong heterogeneity of shale reservoirs renders this process highly complex. To address this, this investigation incorporates shale heterogeneity by constructing three distinct pore types: dissolution pores, intergranular pores, and fracture pores. Furthermore, a coupled multi-relaxation-time lattice Boltzmann model is developed to simulate the associated CO₂-mineral dissolution dynamics. The results demonstrate that in homogeneous models, dissolution intensifies with increasing Péclet and Damköhler numbers, revealing a positive feedback loop among mineral dissolution, channel expansion, and flow focusing. In heterogeneous models, however, this positive feedback is suppressed. It is observed that pore space complexity increases while heterogeneity decreases during dissolution, along with significant improvements in flow velocity, porosity, and permeability. These findings provide novel insights into the dissolution patterns governing CO₂-shale interactions. This study therefore enhances CO₂ storage efficiency, and improves oil recovery, assisting in the generation of cleaner energy and higher energy security.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205823"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145884325","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Underground hydrogen storage monitoring by a nuclear borehole geophysical method – a modeling study","authors":"József Gábor Szűcs ,&nbsp;Attila Galsa ,&nbsp;László Balázs","doi":"10.1016/j.jgsce.2025.205816","DOIUrl":"10.1016/j.jgsce.2025.205816","url":null,"abstract":"<div><div>Underground Hydrogen Storage (UHS) is a promising technology to store the excess energy produced by renewable energy sources such as wind turbines or solar panels, however the storing of hydrogen in a geological reservoir is a challenging task. Due to its small molecule size and higher mobility, there is a risk of leakage through the capstones (usually shale) or faults and fractures higher than that of gas, or even CO₂. This means that a complex monitoring system needs to be established. An important part of such a system could be borehole geophysical measurements. The aim of the study is to investigate the efficiency of a nuclear borehole geophysical method for monitoring hydrogen saturation in sandstone aquifers in the presence of casing and to optimize the method for hydrogen saturation estimation. Therefore, systematic Monte Carlo simulations were completed using MCNP (Monte Carlo N–Particle) code in a realistic 3D borehole model environment. Crucial reservoir and technical model parameters, such as hydrogen saturation, porosity, borehole diameter and lithology were studied. Finally, a method based on the energy selective gamma measurement of a pulsed neutron tool is suggested showing a nonlinear sensitivity to the hydrogen saturation of the rock. Based on the simulation results, the method is the most effective in high porosity reservoirs (≥20 %), when the sandstone content of the rock reaches 50 %, and it is still viable in greater borehole diameters. The developed method can be an important building block of a UHS monitoring system to keep hydrogen saturation under observation.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205816"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145738335","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Experimental investigation of characteristic frequency of intermittent gas-liquid vertical downward flow","authors":"Abderraouf Arabi ,&nbsp;Abdelhak Lakehal ,&nbsp;Ronaldo Luis Höhn ,&nbsp;Abdelwahid Azzi ,&nbsp;Jordi Pallares ,&nbsp;Youssef Stiriba","doi":"10.1016/j.jgsce.2025.205827","DOIUrl":"10.1016/j.jgsce.2025.205827","url":null,"abstract":"<div><div>The estimation and prediction of the characteristic frequency of intermittent structures present in intermittent vertical downward two-phase flow is of primary importance for the design and operations of systems involving this kind of flow. This paper aims to present, for the first time, a detailed quantitative analysis of the characteristic frequencies of intermittent flows in this flow configuration. The study was conducted through a series of experiments in a 30 mm ID pipe using an air–water mixture. Absolute pressure time series were acquired at three axial locations and analyzed using the Welch's method to extract the characteristic frequencies.</div><div>Visual observations using a high-speed camera enabled the identification and discussion of the distinct structures present in the three flow regimes (cap bubble, slug and churn) of intermittent flow. Based on an analysis of the forces acting during transitions between the different flow regimes, the dimensionless mixture Froude number and the modified Lockhart–Martinelli parameter were employed for mapping the three flow regimes, demonstrating high predictive capabilities. In addition, the analysis of the measured characteristic frequencies showed that they increase during the flow development, reaching a fully developed value at 56.33 <em>L/D</em>. These frequencies are strongly influenced by the gas superficial velocity. Interestingly, the measured total pressure drops were found to be directly related to both the characteristic frequencies and the flow regime type. Finally, a new empirical correlation was introduced, outperforming the existing one.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205827"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145840553","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Investigating the capability of CO2 absorption via arginine and histidine amino acid salt solutions at high pressures","authors":"Yasaman Enjavi,&nbsp;Mohammad Khorram,&nbsp;Peyman Keshavarz","doi":"10.1016/j.jgsce.2025.205824","DOIUrl":"10.1016/j.jgsce.2025.205824","url":null,"abstract":"<div><div>As global energy consumption rises, CO₂ emissions have become a critical concern, prompting extensive research into capture technologies. Conventional aqueous amine solvents face challenges due to the high energy required for regeneration, limiting large-scale applications. To overcome this, novel phase-change solvents, particularly water–amino acid systems, have been proposed to reduce regeneration energy. This study investigated the CO₂ absorption performance of amino acid salts synthesized from arginine and histidine with potassium hydroxide in aqueous N,N-dimethylformamide (DMF). CO₂ absorption capacity was measured under pressures between 5 and 30 bar, reflecting operational conditions of gas sweetening units, and at varying DMF concentrations. Results showed that higher pressure and DMF content enhanced absorption capacity, attributed to simultaneous increases in physical and chemical absorption. Phase analysis using 13C NMR revealed CO₂-related carbon bonds in the solid phase but not in the upper liquid phase, indicating that the liquid phase can be directly recovered without regeneration. Since most CO₂ resides in the solid phase, regenerating only this fraction significantly reduces energy demand. Among the tested solvents, arginine-based solutions displayed the highest absorption capacity, while histidine-based solutions showed the lowest, a trend linked to differences in amine group numbers. Absorption stability was assessed over three absorption–regeneration cycles. Across all amino acid salts, capacity declined only 6–8 % after three cycles, confirming their potential for efficient and energy-saving CO₂ capture.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205824"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145840554","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Performance of PEI-modified fumed silica monoliths with honeycomb structure for direct air capture of CO2","authors":"Chenyang Lin ,&nbsp;Yijun Wang ,&nbsp;Yihang Liu ,&nbsp;Takeshi Hagio ,&nbsp;Baowen Zhou ,&nbsp;Xinling Li ,&nbsp;Zhen Huang","doi":"10.1016/j.jgsce.2025.205836","DOIUrl":"10.1016/j.jgsce.2025.205836","url":null,"abstract":"<div><div>Direct air capture (DAC) is a technology that captures low concentrations of CO₂ directly from the air. In recent years, amine-modified solid adsorbents have been widely utilized to facilitate an efficient CO₂ capture process. In industrial applications, the significant pressure drop reduced by powder accumulation results in economic losses for fans. However, previous studies on monoliths have failed to simultaneously satisfy the industrial requirements for both adsorption capacity and mechanical strength. In this work, a novel honeycomb monolith was proposed to address this issue. The seven uniformly distributed channels effectively reduced pressure drop, while the wall thickness satisfied the mechanical strength requirements under industrial application conditions. And the structure was optimized by using activated carbon. After high-temperature treatment, the new pore formed in the space previously occupied by the activated carbon. Through the secondary loading approach, the amine loading was comparable to the powder. Compared with the monoliths without activated carbon, the pore volume significantly increased (from 5.31 % to 96.26 %). The pore volume of 20AC-SiO₂-M reached 0.84 cm³ g⁻¹. At 35 °C and 400 ppm, 20AC-SiO₂-M exhibited the best CO₂ adsorption capacity (1.94 mmol/g) and the fastest CO₂ adsorption rate (0.0395 mmol/(g.min)). Additionally, the structure strength (1.46 MPa) and pressure drop losses (0.002 psi) were tested, and both parameters met the requirements for industrial applications.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"146 ","pages":"Article 205836"},"PeriodicalIF":5.5,"publicationDate":"2026-02-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"145884259","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}