Gas Science and Engineering最新文献

{"title":"CO2 hydrate sequestration in unsealed submarine sediments: A 4D pore-scale experimental investigation","authors":"Yanfang Li ,&nbsp;Tong Zhang ,&nbsp;Liang Yuan ,&nbsp;Ming Tang ,&nbsp;Ruilong Li ,&nbsp;Yongqiang Chen ,&nbsp;Wen Luo ,&nbsp;Chuanjiu Zhang","doi":"10.1016/j.jgsce.2025.205734","DOIUrl":"10.1016/j.jgsce.2025.205734","url":null,"abstract":"<div><div>CO₂ hydrate sequestration in marine sediments has been identified as a safe, large-scale, long-term carbon removal method. Influenced by the high pressure and low temperature, the dynamic formation of CO₂ hydrate has not been fully investigated. We thus design and construct a low-field nuclear magnetic resonance (LF-NMR) apparatus to investigate the <em>in-situ</em> dynamic process of CO₂ hydrate formation. The temporal-spatial evolution of CO₂ hydrate formation is analyzed to reveal the generation and distribution of CO₂ hydrate as a function of pressure and initial water saturation. The results reveal that CO₂ hydrate mainly forms in macropores, where water-to-hydrate conversion rate exceeds 81 %, while the conversion rate is below 27 % in micropores. The spatial distribution of CO₂ hydrate exhibits strong heterogeneity, and the hydrate formation preferentially occurs where the ratio of gas-water volume is 0.2–0.8. Increased injection pressure improved the heterogeneity, as evidenced by the increased heterogeneity index from 6.18 to 12.8. The increased injection pressure cannot enhance CO₂-to-hydrate conversion at similar water saturation levels although improving the conversion rate of water-to-hydrate. Regardless of the initial water saturation, lower injection pressure has a higher CO₂-to-hydrate conversion, approximately 95.2 % (3 MPa) and 86.5 % (4 MPa), respectively. This study advances the understanding of CO₂ hydrate formation dynamics and demonstrates that lower injection pressure is more favorable for hydrate-based marine CO₂ sequestration strategies.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205734"},"PeriodicalIF":0.0,"publicationDate":"2025-07-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144672687","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":"A novel fully coupled thermal-hydraulic-mechanical model for hydrogen storage in depleted gas reservoirs","authors":"Jing Fu ,&nbsp;Keni Zhang ,&nbsp;Hongjun Yin ,&nbsp;Philip H. Winterfeld ,&nbsp;Yu-Shu Wu","doi":"10.1016/j.jgsce.2025.205733","DOIUrl":"10.1016/j.jgsce.2025.205733","url":null,"abstract":"<div><div>Underground hydrogen storage (UHS) in depleted gas reservoirs provides a scalable solution for addressing energy supply-demand imbalances across short- and long-term operational horizons. Reliable prediction of hydrogen storage performance in depleted gas reservoirs requires accurate representation of coupled thermal, hydraulic, and mechanical processes. In this study, we introduce a new, fully coupled THM simulation capability for UHS by directly modifying the source code of the TOUGH2-CSM simulator. TOUGH2-CSM was originally designed for modeling CO₂ sequestration in saline aquifers and lacked support for hydrogen-specific thermophysical behavior. We extend its functionality through the development and integration of a new equation-of-state (EOS) module for multicomponent hydrogen storage systems, enabling modeling of multicomponent mixtures in multiphase, non-isothermal flow conditions. The geomechanical coupling distinguishes it from hydrogen-enabled TOUGH family EOS modules, which does not account for stress-strain interactions, addressing a critical gap and enhancing its relevance for practical UHS applications.</div><div>Model validation was performed using thermophysical property data from the National Institute of Standards and Technology (NIST), ensuring accurate prediction of gas behavior across a wide range of pressure-temperature conditions. The model achieves an average deviation of less than 5 % in thermophysical property predictions compared to NIST reference values. Experimental datasets further confirm its accuracy, with simulation results aligning within 5 % of measured data. Benchmark tests with existing simulator ensured consistency in pure hydrogen storage. Geomechanical consistency is validated via analytical verification against Terzaghi's one-dimensional consolidation theory, with an error of less than 1 %, confirming proper coupling of fluid flow and stress evolution. Additionally, the model's applicability is illustrated through a preliminary application case study of hydrogen storage in a depleted gas field, highlighting its potential for real-world implementation.</div><div>Future work will focus on applying the developed model to real field scenarios for the design of injection and production strategies. The framework will also be extended to incorporate chemical reactions relevant to underground hydrogen storage.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205733"},"PeriodicalIF":0.0,"publicationDate":"2025-07-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144653853","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":"Proxy model-driven optimization of CO2 operating condition and hydraulic fracturing design for maximizing EGR-CCS performance in the Duvernay shale formation, Canada","authors":"Inwook Baek ,&nbsp;Le Viet Nguyen ,&nbsp;Namhwa Kim ,&nbsp;Hyundon Shin ,&nbsp;Thotsaphon Chaianansutcharit","doi":"10.1016/j.jgsce.2025.205731","DOIUrl":"10.1016/j.jgsce.2025.205731","url":null,"abstract":"<div><div>Shale gas is a prominent unconventional resource because of the advances in horizontal drilling and hydraulic fracturing, especially in North America. Shale gas reservoirs have also been considered for carbon capture and storage (CCS) to help mitigate CO₂ emissions and allow additional gas production. Enhanced gas recovery with CCS (EGR-CCS) injects CO₂ to displace methane (CH₄), leveraging the higher adsorption capacity of CO₂ in shale. On the other hand, cumulative CH₄ production and CO₂ stored amount depend heavily on the timing of the injection, while economic factors such as natural gas prices and CO₂ tax credits also play a role—often overlooked in previous studies. This study developed a machine learning-based proxy model to predict the net present value (NPV) of an EGR-CCS project by integrating the CO₂ operating conditions, hydraulic fracturing designs, and economic factors. Based on data from the Duvernay shale reservoir, 200 scenarios were simulated to generate a training dataset. Five regression algorithms were tested. Of these five, extreme gradient boosting (XGB) yielded the highest accuracy, predicting CO₂ stored amount, cumulative CH₄ production, and NPV with R² &gt; 0.9. A complete factorial design was then implemented to optimize the EGR-CCS process under varying economic conditions. This comprehensive framework aids decision-making to maximize the economics of EGR-CCS, highlighting the potential of the Duvernay shale formation as a geological carbon storage target.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205731"},"PeriodicalIF":0.0,"publicationDate":"2025-07-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144632105","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":"Investigation of synergy between extended oil recovery and hydrogen storage in a producing field using the Norne reservoir model","authors":"Behzad Amiri ,&nbsp;Pål Østebø Andersen ,&nbsp;Mojtaba Ghaedi ,&nbsp;Xiaodong Luo","doi":"10.1016/j.jgsce.2025.205729","DOIUrl":"10.1016/j.jgsce.2025.205729","url":null,"abstract":"<div><div>This research investigates the feasibility and effectiveness of combining Underground Hydrogen Storage (UHS) with enhanced oil recovery (EOR) and carbon dioxide (CO₂) sequestration in an active oil reservoir, utilizing the Norne field as a case study.</div><div>CO₂-water-alternating-gas (CO₂-WAG), continuous gas (CO₂) and water flooding (CGWF), and water flooding (WF) are utilized for oil extraction. UHS is executed in six scenarios: three during oil extraction and three post-depletions. The UHS efficiency, oil recovery, and H₂ recovery efficiency in the two UHS systems are first examined by employing an EOR well converted into a UHS well. Subsequent examination of UHS during oil production utilizing CO₂-WAG investigates the impacts of elevated UHS well rates, well positioning, prior well applications, and the use of smart wells to limit H₂ breakthrough.</div><div>The low rate UHS cases with H₂ constraint did not adversely impact oil recovery. CO₂-WAG had the highest efficacy in EOR and could store around 60 % of the injected CO₂, and resulted in the maximum efficiency for UHS during oil production, as CO₂ reduced H₂ dissolution in oil and residual trapping. Conversely, the WF method yielded the highest H₂ recovery for storing H₂ in the depleted reservoir, owing to a lower pressure near the H₂ well and higher pressure in distant areas compared to the two other cases. Additionally, 22 % of H₂ was produced by the oil wells. Smart oil wells, constraining H₂ production, improved UHS well H₂ recovery from 73.6 % to 80.2 %. The efficiency of oil recovery and UHS is contingent upon the interplay of well location and H₂ injection and production rate. Implementing UHS during oil production with CO₂-WAG could boost oil recovery, UHS, and CO₂ sequestration. The optimization of H₂ injection and production rates, H₂ well placement, and cushion gas volume is essential, alongside proper monitoring of the oil production stream.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205729"},"PeriodicalIF":0.0,"publicationDate":"2025-07-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144662580","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":"CO2-enhanced methane recovery in deep coalbeds: Displacement and diffusion/pressure-driven behaviors","authors":"Yaning Liu ,&nbsp;Xiaoxiao Sun ,&nbsp;Yanbin Yao ,&nbsp;Dameng Liu ,&nbsp;Yongkai Qiu","doi":"10.1016/j.jgsce.2025.205730","DOIUrl":"10.1016/j.jgsce.2025.205730","url":null,"abstract":"<div><div>With the development and production breakthrough of deep coalbed methane (CBM), research on CO₂ enhanced methane (CO₂-ECBM) under high temperature and pressure in deep coal seams is gaining increasing attention. In this study, molecular dynamic simulation (MD) are employed to investigate the occurrence of methane and CO₂ in pores of various sizes of deep coal bed, considering both adsorption and pore-bound states. Furthermore, CO₂-ECBM CH₄ is simulated, with three distinct mechanisms-displacement, diffusion-driven displacement, and pressure-driven displacement-analyzed at different burial depths. The results show that, the adsorption density of CH₄ increases and then stabilizes with burial depth, while the adsorption density of CO₂ first increases and then slightly decreases. The self-diffusion of methane decreases and eventually stabilizes, while the self-diffusion coefficient of CO₂ initially decreases and then increases. The turning depth for both processes is at 1200 m. The displacement of methane by CO₂ increases with CO₂ pressure and decreases with smaller pore sizes. For CO₂ diffusion-driven methane displacement, elevated temperatures promote CO₂ diffusion, enhancing CO₂-ECBM below 1200 m. The greater the injected CO₂ pressure, the stronger the pressure-driven displacement. However, in small pores, the displacement process is less sensitive to pressure differences. Therefore, in deep coal seams, high temperatures favor CO₂-ECBM, meanwhile, coal beds with well-developed micropores are not conducive to CO₂-ECBM.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205730"},"PeriodicalIF":0.0,"publicationDate":"2025-07-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144653851","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":"A unified volume translation model in SRK EOS for dry gas constituents","authors":"Changxu Wu ,&nbsp;Jialin Shi ,&nbsp;Huazhou Li","doi":"10.1016/j.jgsce.2025.205732","DOIUrl":"10.1016/j.jgsce.2025.205732","url":null,"abstract":"<div><div>Dry gas, mainly made of light hydrocarbons (such as methane and ethane), is an important type of natural gases. The PVT properties of dry gas constituents (e.g., compressibility factor) play an important role in the various stages of dry gas recovery. In this study, we develop an improved distance-function-based volume translation model in Soave-Redlich-Kwong equation of state (SRK EOS) for dry gas constituents (including carbon dioxide, nitrogen, methane, ethane, propane, n-butane, isobutane, n-pentane, isopentane, and neopentane). This model not only accurately replicates the critical compressibility factor for a specific dry gas component but also maintains strong performance across a broad range of pressures and temperatures (i.e., pressure range: from triple-point pressure to 300 MPa; temperature range: from triple-point temperature to 600 K). For the 10 dry gas constituents considered in this study, the new volume-translated SRK EOS yields an %AAD of 1.27 in reproducing saturation pressure, while it yields %AADs of 0.73, 0.38, 0.69, 1.72, and 1.55 in reproducing the liquid-phase, vapor-phase, saturated-liquid-phase, saturated-vapor-phase, and supercritical-phase compressibility factors, respectively. Moreover, the new volume-translated rescaled SRK EOS (VTR-SRK EOS) does not lead to crossover of pressure-volume isotherms within the tested pressure/temperature ranges.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205732"},"PeriodicalIF":0.0,"publicationDate":"2025-07-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144653852","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":"Geophysical monitoring technology and simulation in CO2 geological storage: A comprehensive review","authors":"Wenke Tang ,&nbsp;Wuqin Li ,&nbsp;Zitian Lin ,&nbsp;Jun Zhu ,&nbsp;Siyao Zhou ,&nbsp;Yangmin Kuang ,&nbsp;Yanpeng Zheng","doi":"10.1016/j.jgsce.2025.205725","DOIUrl":"10.1016/j.jgsce.2025.205725","url":null,"abstract":"<div><div>Carbon capture, utilization, and storage (CCUS) is a promising method for carbon emission reduction, but safe and efficient storage remains challenging. Geophysical methods can monitor CO₂ storage, yet face issues like technical obstacles, data complexity, environmental impact and cost. This review summarizes CCUS projects, geophysical principles, forward and inverse methods. It is proposed to construct an integrated carbon storage monitoring network based on seismic, electromagnetic, and gravimetric monitoring. Additionally, by establishing an optical fiber data transmission platform and leveraging artificial intelligence, data collection efficiency and algorithm accuracy can be improved, thereby optimizing the overall monitoring system.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205725"},"PeriodicalIF":0.0,"publicationDate":"2025-07-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144679264","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":"Impacts of permeability heterogeneities on foam flow in porous media: Uncertainty quantification and sensitivity analysis","authors":"Berilo de Oliveira Santos ,&nbsp;Rodrigo Weber dos Santos ,&nbsp;Iury Igreja ,&nbsp;Grigori Chapiro ,&nbsp;Bernardo Martins Rocha","doi":"10.1016/j.jgsce.2025.205710","DOIUrl":"10.1016/j.jgsce.2025.205710","url":null,"abstract":"<div><div>Foam injection in porous media has been extensively studied for its ability to improve sweep efficiency by mitigating nonlinear phenomena such as gravitational segregation and viscous fingering. However, modeling foam flow remains a significant challenge, mainly due to the complex interactions between foam and heterogeneous geological formations, which are often difficult to characterize. In particular, the spatial distribution of absolute permeability is difficult to obtain, due to scarce data and strong heterogeneity. These challenges introduce uncertainties into predictive models. In particular, the relationship between foam flow and uncertainties related to absolute permeability fields remains underexplored in the literature. This work performs uncertainty propagation studies to investigate the influence of permeability heterogeneity on foam flow in porous media. This is achieved by coupling the Karhunen-Loève expansion (KLE), which generates Gaussian random permeability fields, with Polynomial Chaos Expansion (PCE), a method for propagating uncertainties in a computationally efficient manner. This approach allows for the evaluation of permeability variations impact on key quantities of interest (QoIs) related to flow performance. The results, derived from uncertainty quantification (UQ) and sensitivity analysis (SA), reveal that foam behavior is highly sensitive to the spatial correlation structures of permeability, with important implications for optimizing foam flow processes. The integration of KLE and PCE provides the first systematic framework for uncertainty propagation in foam flow analysis, unveiling previously unexplored correlations and behaviors. These findings highlight the importance of incorporating permeability uncertainties into modeling to improve the reliability and efficiency of both subsurface flow applications, including resource recovery and carbon sequestration efforts. The proposed methodology can be particularly beneficial in practical scenarios such as enhanced oil recovery or CO<span><math><msub><mrow></mrow><mrow><mn>2</mn></mrow></msub></math></span> sequestration, where foam is used to improve mobility control in complex formations.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205710"},"PeriodicalIF":0.0,"publicationDate":"2025-07-04","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144557219","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":"Dynamic characterize of interface and mass transfer of CO2-brine during CO2 storage in saline aquifer","authors":"Shaohua Li ,&nbsp;Xin Wang ,&nbsp;Lanlan Jiang ,&nbsp;Lei Wang ,&nbsp;Yi Zhang ,&nbsp;Bohao Wu ,&nbsp;Yongchen Song","doi":"10.1016/j.jgsce.2025.205717","DOIUrl":"10.1016/j.jgsce.2025.205717","url":null,"abstract":"<div><div>Understanding the mass transfer characteristics between CO₂ and brine is essential for advancing CO₂ saline aquifer storage technology. The study visualizes supercritical CO₂ (scCO₂) dissolution into brine in porous media under high temperature and pressure by using micro-computed tomography. The dynamic evolution of interphase interface of CO₂-brine was innovatively investigated in three dimensions and quantified over time. The conclusions showed that the residual saturation of CO₂ was negatively correlated with the flow rate. Five distinct forms of CO₂ cluster evolution were identified, resulting in the non-uniform spatial distribution of the CO₂-brine interface. Then a novel classification of four interface types between CO₂ and brine was proposed and it exhibits non-monotonic evolution due to the combined effects of pore filling and snap-off events. Both local and spatial mass transfer coefficients (MTC) were calculated based on the quantified interfacial area, showing strong heterogeneity along porous media. Additionally, the local MTC of scCO₂ was found to be from 10⁻¹⁰ to 10⁻⁶ m/s, with a broader range of magnitudes compared to its gaseous state (10⁻⁹ to 10⁻⁸ m/s). Finally, the mass transfer model for trapped-phase dissolution in porous media is extended on the basis of the Sherwood number, Reynolds number and Schmidt number. Understanding the evolution of these interfaces and models of dissolution mass transfer of trapped phase can aid in predicting CO₂ behavior in saline aquifers, optimizing storage strategies, and ensuring CO₂ dissolution trapping and long-term storage stability.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"143 ","pages":"Article 205717"},"PeriodicalIF":0.0,"publicationDate":"2025-07-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144587709","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":"Date palm leaves-derived activated carbon as a sustainable support for catalytic methane dry reforming","authors":"Nada Abounahia ,&nbsp;Alessandro Sinopoli ,&nbsp;Yongfeng Tong ,&nbsp;Abdulaziz Al-Emadi ,&nbsp;Ahmed Abotaleb","doi":"10.1016/j.jgsce.2025.205716","DOIUrl":"10.1016/j.jgsce.2025.205716","url":null,"abstract":"<div><div>The increasing global demand for energy and the necessity to mitigate greenhouse gas emissions have intensified research into alternative energy sources and environmentally benign chemical processes. One promising approach is the dry reforming of methane (DRM), which converts methane (CH₄) and carbon dioxide (CO₂)—both major greenhouse gases—into valuable syngas (a mixture of hydrogen and carbon monoxide). However, the development of cost-effective and sustainable catalysts that can operate efficiently while utilizing biomass waste remains a significant challenge. This study investigates the development of cost-effective and durable nickel-based catalysts supported on activated carbon derived from date palm leaves biomass waste. The catalysts were synthesized via a wet impregnation method and characterized using various techniques including XRD, BET, SEM, TEM, FT-IR, H₂-TPR, CO₂-TPD, NH₃-TPD, TGA, Raman analysis and XPS. The catalytic performance of the synthesized catalysts for DRM was evaluated at a temperature of 750 °C for 12 h using fixed-bed reactor. Results demonstrate that the activated carbon support significantly influences the catalysts' activity and stability. In particular, Ni-doped modified activated carbon from date palm leaves exhibited superior performance, achieving high CH₄ (41 %) and CO₂ (75 %) conversion, compared to commercial activated carbon derived from coconut shell. The catalyst also showed good resistance to coking and sintering, making it a promising candidate for DRM. This study highlights the viability of using sustainable biomass sources for the development of effective DRM catalysts, contributing to waste management and environmental sustainability.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205716"},"PeriodicalIF":0.0,"publicationDate":"2025-07-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144557218","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}