Gas Science and Engineering最新文献

{"title":"Improving feasibility of underground hydrogen storage in aquifers: A case study based on the Mt. Simon sandstone formation in the Midwest United States","authors":"Tianjia Huang,&nbsp;George J. Moridis,&nbsp;Thomas A. Blasingame","doi":"10.1016/j.jgsce.2025.205706","DOIUrl":"10.1016/j.jgsce.2025.205706","url":null,"abstract":"<div><div>Underground hydrogen storage (UHS) in saline aquifers presents a promising solution for large-scale energy storage for the Midwestern United States because of the limit availability of depleted hydrocarbon reservoirs. This study focuses on the Manlove Field at the Mt. Simon sandstone formation, Illinois, a geological site with proven sealing capacity and known reservoir properties because of previous natural gas storage projects. We developed a three-dimensional numerical model, implemented using the TOUGH + RealGasBrine simulator, to investigate several key factors influencing UHS performance, including production strategies, well completion interval, and the cushion gas injection. The results show that the method of constant production rates can significantly reduce water production compared to constant bottom hole pressure, for the same amount of recovered H₂. Because of gravity separation effect, perforating wells in upper zones improves H₂ storage by reducing water production and achieving higher recovery efficiency. Cushion gas (nitrogen in this study) enhances recovery efficiency, mitigates H₂ leakage and dissolution, and delays water breakthrough, thereby improving the overall economic viability of UHS. However, gas mixing in both subsurface and produced stream necessitates the potential need for gas separation facilities, which remains an important consideration if large amounts of a cushion gas are injected. Lastly, the results show that the non-recoverable H₂, trapped by relative permeability hysteresis, may exceed 50 % of the injected total. This study provides insights into the design and optimization of UHS operations in aquifers using three-dimensional large-scale numerical simulations, emphasizing the key role of well completion interval and cushion gas in improving H₂ storage efficiency.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205706"},"PeriodicalIF":0.0,"publicationDate":"2025-06-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144338786","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":"Innovative assessment of CO2 storage potential in China's shale oil fracturing: A storage index-well layout approach","authors":"Wenrui Shi ,&nbsp;Meiyu Guo ,&nbsp;Jianfeng Li ,&nbsp;Zisang Huang ,&nbsp;Pu Hong ,&nbsp;Pengfei Wang ,&nbsp;Yijiang Feng ,&nbsp;Hongyan Zhao ,&nbsp;Hankui K. Zhang","doi":"10.1016/j.jgsce.2025.205702","DOIUrl":"10.1016/j.jgsce.2025.205702","url":null,"abstract":"<div><div>As global efforts to mitigate climate change intensify, CO₂ storage in shale oil reservoirs presents a promising avenue for reducing greenhouse gas emissions while enhancing oil recovery. However, accurate assessment of storage potential remains challenging, particularly in China's diverse shale oil basins. This study introduces the Storage Index-Well Layout (SI-WL) method, a novel approach for evaluating CO₂ storage potential in shale oil reservoirs, and applies it to 12 major basins in China. Comparing this method with traditional and improved US-DOE methods demonstrates its superior reliability in estimating storage capacity under current technological conditions. Our analysis reveals a cumulative CO₂ storage potential of 5.69 × 10⁸ t of liquid CO₂ across the studied basins, with the Bohai Bay Basin showing the highest capacity at 1.87 × 10⁸ t. Scenario analysis from 2025 to 2060 identifies key factors influencing storage potential, including the proportion of wells using CO₂ fracturing and fracturing fluid performance. While current practices in China's shale oil CO₂ fracturing achieve effective results, improving liquid CO₂'s viscosity and sand-carrying performance remains a significant challenge. This research provides valuable insights for shale oil CO₂ fracturing development and CO₂ emission reduction strategies, suggesting that technological advancements could significantly enhance CO₂ storage in the shale oil industry.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205702"},"PeriodicalIF":0.0,"publicationDate":"2025-06-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144338752","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 blockage detection model for subsea natural gas condensate pipelines considering fluid components and valve characteristics","authors":"Xiaoming Luo ,&nbsp;Zhenglai Tian ,&nbsp;Qihang Wu ,&nbsp;Haiyuan Yao ,&nbsp;Zhenqiang Xie","doi":"10.1016/j.jgsce.2025.205704","DOIUrl":"10.1016/j.jgsce.2025.205704","url":null,"abstract":"<div><div>Traditional pressure wave detection models for subsea natural gas condensate pipelines often overlook the dynamic flow and multiphase interactions under high-pressure and low-temperature conditions, and the pressure wave excitation methods are not suitable for subsea pipelines. To address these issues, this study proposes a multiphysics-coupled blockage detection method. By integrating the equation of state with multiphase flow regime discrimination criteria, a wave velocity calculation model with dynamic thermo-pressure corrections was developed, resolving prediction deviations in temperature-pressure gradient coupled fields. Pressure wave excitation is achieved through pressure relief operations of branch valves on offshore platforms. A coupled algorithm for pressure wave propagation and blockage feature inversion was developed by combining the method of characteristics with valve dynamic characteristic parameters. This algorithm quantifies the influence of valve operation time on excitation amplitude. Experimental validation demonstrated that the proposed model effectively integrates temperature-pressure coupled computations, pressure wave propagation analysis, and blockage detection, with wave velocity calculation errors below 2 %. The method successfully detects blockages with a minimum severity of 25 %, kilometer-scale blockage lengths, and multipoint blockage scenarios. This study provides a high-precision detection method for safe flow assurance of subsea pipelines.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205704"},"PeriodicalIF":0.0,"publicationDate":"2025-06-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144331378","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":"Effect of heterogeneous hydrate distribution on permeability: Pore filling hydrate presents high permeability","authors":"Hiroya Takahisa ,&nbsp;Yoshihiro Konno ,&nbsp;Yusuke Jin ,&nbsp;Norio Tenma","doi":"10.1016/j.jgsce.2025.205682","DOIUrl":"10.1016/j.jgsce.2025.205682","url":null,"abstract":"<div><div>To explore natural gas hydrate in sediment, the permeability plays a vital role in estimating fluid flows and production potential. Although natural gas hydrate exhibits a heterogeneous distribution with different pore habits, the combined effects of heterogeneity and pore characteristics have not been studied well. In this study, a two-dimensional homogeneous porous medium was constructed to simulate single-phase fluid flow with different sizes and number of grain coating (GC) or pore filling (PF) hydrate particles. The results showed that under the same saturation of PF hydrate, heterogeneous hydrate distributions exhibited higher permeability than homogeneous distributions. This higher permeability can be attributed to the critical pore radius of the preferential flow paths. The heterogeneous distribution left some pores unoccupied, not reducing the critical pore radius. In contrast, for GC hydrate, heterogeneous hydrate distributions exhibited lower permeability than homogeneous hydrate distributions. Despite the presence of preferential flow paths unoccupied by gas hydrate, the continuous blockage induced by GC hydrate decreased the permeability. Furthermore, we analyzed the tortuosity and heterogeneity degree of the hydrate-bearing sediment. GC hydrate exhibited higher tortuosity under heterogeneous distributions. A modified model based on a classic theory showed good correlations between permeability and tortuosity. The heterogeneity degree exhibited a negative correlation with both hydrate saturation and tortuosity. This study shows the importance of preferential flow paths in the permeability, explaining the high permeability characteristics of natural hydrate-bearing sediment.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205682"},"PeriodicalIF":0.0,"publicationDate":"2025-06-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144335766","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":"Characterizing pore structure and CO2 storage potential in Eocene Mirador Formation tight sandstones using X-ray micro-CT","authors":"Carlos A. Ríos ,&nbsp;Carlos A. Chacón ,&nbsp;Carlos Villarreal ,&nbsp;Leonardo Salazar ,&nbsp;Arash Aghaei ,&nbsp;Rengarajan Pelapur ,&nbsp;Arsalan Zolfaghari ,&nbsp;Tomas Silva Santisteban","doi":"10.1016/j.jgsce.2025.205699","DOIUrl":"10.1016/j.jgsce.2025.205699","url":null,"abstract":"<div><div>This study utilizes digital rock physics and X-ray micro-computed tomography (μCT) to comprehensively characterize the pore structure of the Eocene Mirador Formation tight sandstone from the NW Llanos Basin, Colombia. Petrographic analysis identifies the sandstone as predominantly quartz arenite with minimal clay content. Quantitative mineral mapping through scanning electron microscopy further elucidates key rock-forming minerals and their textural and microstructural characteristics. The analysis of petrophysical properties reveals low porosity (3.3 %) and high compressive strength due to significant secondary quartz cementation. Detailed 2D and 3D μCT imaging provides insights into pore structure, size distribution, and connectivity, highlighting a predominance of small pores that influence both porosity and permeability. The presence of fractures impacts fluid flow, while pore connectivity is crucial for reservoir quality assessment. The study underscores the importance of imaging resolution in accurately characterizing pore geometry and connectivity. A 3D digital core model, created with PerGeos software, offers a detailed representation of the pore structure. These insights enhance the understanding of the Eocene Mirador Formation's pore structure, contributing to CO₂ storage potential assessments and providing valuable information for hydrocarbon exploration, resource management, and geotechnical engineering.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205699"},"PeriodicalIF":0.0,"publicationDate":"2025-06-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144290451","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":"Coalbed methane extraction: Characteristics of damage-seepage evolution and dynamic response of methane transport in non-homogeneous coal seams under cavitation","authors":"Chao Xu ,&nbsp;Yongwang Yuan ,&nbsp;Kai Wang ,&nbsp;Yuanyuan Hu ,&nbsp;Zishuo Nie ,&nbsp;Yongbo Shi","doi":"10.1016/j.jgsce.2025.205689","DOIUrl":"10.1016/j.jgsce.2025.205689","url":null,"abstract":"<div><div>Mechanical cavitation has been widely researched and applied as a coal seam permeability enhancement and modification technology in coal CH₄ extraction and utilization. The non-homogeneous nature of coal seams in actual projects has a remarkable influence on the space-time distribution of coal seam damage and CH₄ transport. To clarify the damage-seepage synergistic evolution and the dynamic response of gas transport in non-homogeneous coal seams before and after cavitation. A coupled mechanics-damage-seepage model (MDS) considering the non-homogeneous characteristics of coal was constructed based on damage mechanics and geostatistical methods. Numerical simulations of coal bed cavitation gas extraction under different vertical loading conditions were conducted. The findings indicate that with the vertical load increase, coal seam damage gradually changes from mainly tensile damage to mainly shear damage. The damaged area gradually increases in size. The permeability of coal seams develops parallel with damage. When <em>t</em> = 0, a sudden rise in the permeability of the coal is consistent with the damage zone distributive pattern. As extraction time rises, the Klinken-Berg effect causes permeability to continue to rise. The increase in permeability changes the transportation path of CH₄ within the coal. The transport path is deflected from the low permeability region to the high permeability region. The inhomogeneity of gas transport path deflection is more pronounced in non-homogeneous coal seams. The CH₄ pressure in the coal seam declines with increasing extraction time. The effective extraction radius of non-homogeneous coal in the borehole before and after cavitation was 0.996 m and 1.661 m, which was improved by 66.7 %. The non-homogeneous nature of coal seams mainly affects the distribution characteristics of stress and damage. The coupled MDS model considering the non-homogeneous nature of coal seams can more accurately predict the damage-seepage evolution characteristics of coal seams and the dynamic gas transportation law after the creation of cavities.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205689"},"PeriodicalIF":0.0,"publicationDate":"2025-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144331379","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":"Helium diffusion experiments in effective helium source rocks: A case study involving coal, shale, and granite","authors":"Haosheng Song ,&nbsp;Bobo Li ,&nbsp;Chenlang Tang ,&nbsp;Jianhua Li ,&nbsp;Yunna Ding ,&nbsp;Xianwei Zeng","doi":"10.1016/j.jgsce.2025.205688","DOIUrl":"10.1016/j.jgsce.2025.205688","url":null,"abstract":"<div><div>Helium diffusion in geological media is critical for assessing the feasibility of helium resources. However, the impact of effective stress and temperature on helium diffusion behavior for effective helium source rocks remains underexplored. In this study, we measured the helium diffusion coefficients in coal, shale, and granite by using the counter-diffusion method, combining advanced techniques such as, Field Emission Scanning Electron Microscopy, Energy Dispersive Spectroscopy, and Low-Field Nuclear Magnetic Resonance. The findings revealed variations in helium diffusion coefficients across different geological media in response to changes in temperature and effective stress, identifying critical thresholds that significantly affected helium migration. Moreover, a distinct correlation between porosity and diffusion behavior was observed, thereby, highlighting the importance of microstructural characteristics in controlling helium transport processes within geological media. These findings have not only added to the understanding of helium diffusion mechanisms but have also provided valuable insights to enhance the accuracy of helium resource exploration and evaluation.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205688"},"PeriodicalIF":0.0,"publicationDate":"2025-06-11","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144264100","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":"Pressure-relief gas flow behavior in the hydraulic flushing coal mass considering creep effect: Theoretical modeling and numerical simulation","authors":"Lei Zhang ,&nbsp;Hao Zhang ,&nbsp;Jiamei Chang ,&nbsp;Fazhi Yan ,&nbsp;Ao Li ,&nbsp;Suifang Wang ,&nbsp;Junwei Guo ,&nbsp;Qianru Lei ,&nbsp;Shuqing Yang","doi":"10.1016/j.jgsce.2025.205691","DOIUrl":"10.1016/j.jgsce.2025.205691","url":null,"abstract":"<div><div>The hydraulic flushing coal mass is often under high in-situ stress and generally possesses low long-term strength, which endows it with significant creep properties. Under the effect of creep, the stress-strain of hydraulic flushing coal mass changes constantly over time, further affecting gas diffusion-seepage properties and gas flow within the coal. If the influence of creep is ignored, it is not only difficult to evaluate the gas migration ability, but also leads to a decrease in the stability of the extraction borehole, ultimately affecting the gas extraction efficiency. In response to this, a fractional visco-elastoplastic stress-strain analytical solution is first derived from the fractional Maxwell model for the hydraulic flushing coal mass. Volumetric strain is then taken as the bridge to quantitatively characterize the gas diffusion-seepage responses during gas drainage, thereby building a new pressure-relief gas flow model that considers the creep effect. On this basis, the rationality of the model is verified through numerical simulation, and the pressure-relief gas flow behavior and its influencing factors are analyzed. Based on the study findings, it is found that when the gas drainage time reaches 90 days, the pressure-relief range of the borehole extends to 2.2m, the volumetric strain of coal mass in the borehole wall increases by 1.43 times, the diffusion time ratio decreases to 0.01, and the permeability ratio increases to 1146.59. This model effectively describes the pressure-relief gas flow behavior, and ignoring the creep effect will lead to underestimating the gas flow in coal. The research provides a favorable support for further understanding of gas flow behavior in the hydraulic flushing coal mass.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205691"},"PeriodicalIF":0.0,"publicationDate":"2025-06-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144272404","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":"Advancement perspectives of CH4 recovery from methane hydrate reservoirs via N2/CO2-CH4 exchange: Experiments, simulations, and pilot test applications","authors":"Erasto E. Kasala ,&nbsp;Jinjie Wang ,&nbsp;Asia Majid ,&nbsp;Mbula Ngoy Nadege ,&nbsp;Cyril P. Makembe","doi":"10.1016/j.jgsce.2025.205685","DOIUrl":"10.1016/j.jgsce.2025.205685","url":null,"abstract":"&lt;div&gt;&lt;div&gt;Despite significant progress in CH&lt;sub&gt;4&lt;/sub&gt; recovery from CH&lt;sub&gt;4&lt;/sub&gt; hydrate reservoirs via N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt;-CH&lt;sub&gt;4&lt;/sub&gt; exchanges, critical research gaps persist, particularly in understanding the molecular mechanisms driving gas exchange under varying pressure and temperature conditions. Recent studies have focused on macroscopic outcomes, such as gas recovery rates, while neglecting the nanoscale interactions that govern these processes. In addition, there is a lack of integrated modeling frameworks that incorporate experimental data and simulation models to predict the mechanisms of N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt;-CH&lt;sub&gt;4&lt;/sub&gt; exchanges. On the other hand, field-scale pilot-test applications have been limited, with few studies exploring the scalability of laboratory findings to real-world conditions, particularly in diverse geological settings. This review synthesizes insights from recent laboratory experiments, molecular dynamics simulations, and field-scale pilot tests, offering a holistic view of the N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt;-CH&lt;sub&gt;4&lt;/sub&gt; exchange process. The findings revealed key factors influencing gas exchange efficiency, such as optimal gas mixtures, temperature, pressure, and sediment composition. Laboratory experiments have revealed that a balanced N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt; gas ratio of 1:4 N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt; can significantly enhance CH&lt;sub&gt;4&lt;/sub&gt; recovery and CO&lt;sub&gt;2&lt;/sub&gt; storage depending on the type and content of clay minerals present in sediments, particularly at temperatures around 274.2 K and pressures of approximately 10 MPa. However, other N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt; ratios exhibit favorable performance under specific reservoir conditions. Specifically, a 41:59 N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt; ratio achieves optimal results at slightly higher temperatures of 277 K–283 K and lower pressures of 7.1 MPa, 80:20 N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt; effective at temperatures of 274.2 K–284.2 K and pressures between 7.1 MPa and 10 MPa. Also, the ratio of 0.77:0.23 N&lt;sub&gt;2&lt;/sub&gt;/CO&lt;sub&gt;2&lt;/sub&gt; has been shown to enhance performance in conditions with lower temperatures of 261.2 K–284.2 K and moderate pressures of 3 MPa–7 MPa. Yet, challenges remain in optimizing these conditions for large-scale applications, particularly in heterogeneous geological settings. These findings highlight the need for further research to identify the optimal gas mixture ratio for different geological settings and operational conditions. Furthermore, advancing simulation models to capture complex gas dynamics in real-world reservoir conditions critical for refining predictions of gas exchange behavior were systematically presented in this research. The importance of pilot test deployments in fields such as Ignik Sikumi and Messoyakha was also discussed, showcasing the promise and challenges of scaling laboratory findings to real-world applications. Moreover, the potential for long-term CO&lt;sub&gt;2&lt;/sub&gt; storage in hyd","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205685"},"PeriodicalIF":0.0,"publicationDate":"2025-06-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144263929","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":"Techno-economic assessment of pressure swing adsorption tail gas decarbonisation for blue hydrogen production","authors":"Ayub Golmakani ,&nbsp;Navid Khallaghi ,&nbsp;Amirpiran Amiri ,&nbsp;Vasilije Manovic ,&nbsp;Seyed Ali Nabavi","doi":"10.1016/j.jgsce.2025.205683","DOIUrl":"10.1016/j.jgsce.2025.205683","url":null,"abstract":"<div><div>Steam methane reforming (SMR) is a leading technology for hydrogen production. However, this technology is still carbon-intensive since, in current SMR units, the PSA tail gas containing H₂, CO, and CH₄ is burned at the reformer with air and exits the stack at a CO₂ purity of less than 5 %, which is not feasible to capture. In this paper, we aim to either harness the energy content of this gas to generate power in a solid oxide fuel cell (SOFC) or burn it via chemical looping combustion (CLC) or oxy-combustion process to produce off-gas with high CO₂ purity ready to storage. Therefore, an industrial-scale PSA with 72,000 Nm³/h feed capacity was modelled to obtain the tail gas flow rate and composition. Then, CLC, SOFC, and oxy-combustion were modelled to use tail gas. Finally, a techno-economic analysis was conducted to calculate each technology's levelised cost of hydrogen (LCOH). It was observed that CO₂ purity for CLC meets the criteria for storage (&gt;95 %) without further purification. On the other hand, from the economic point of view, all three technologies show a promising performance with an LCOH of 1.9 €/kg.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"142 ","pages":"Article 205683"},"PeriodicalIF":0.0,"publicationDate":"2025-06-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"144313065","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}