温室气体：科学与技术是一本新的在线科学期刊，致力于温室气体的管理。该杂志将重点关注碳捕获和储存 (CCS) 方法，以及利用二氧化碳 (CO2) 作为燃料和化学品的原料。 GHG 还将提供有关减少其他温室气体排放的战略的见解。将在评论性评论、评论文章和广泛感兴趣的简短交流中探索重大进展。此外，该期刊将提供对相关经济和政治问题、行业发展和案例研究的分析。温室气体：科学与技术是一本令人兴奋的新型在线期刊，作为 SCI（化学工业学会）的合作企业出版) 和约翰威利父子公司

Greenhouse Gases: Science and Technology is a new online scientific journal dedicated to the management of greenhouse gases. The journal focuses on carbon capture and storage (CCS) methods, as well as the utilization of carbon dioxide (CO2) as a feedstock for fuels and chemicals. Additionally, it provides insights into strategies for reducing emissions of other greenhouse gases. The content includes review articles, commentaries, and brief communications on significant advancements. The journal also analyzes relevant economic and political issues, industry developments, and case studies. Greenhouse Gases: Science and Technology is an exciting new online journal published in collaboration with the Society of Chemical Industry (SCI) and John Wiley & Sons.

《温室气体：科学与技术》是一本新的在线科学期刊，专注于温室气体的管理。该期刊将重点关注碳捕获与储存（CCS）技术，以及将二氧化碳（CO2）作为燃料和化学品原料的应用。此外，期刊还将提供关于减少其他温室气体排放的战略见解。期刊内容包括评论性文章、综述以及广泛关注的短篇交流，探讨重大进展。同时，期刊将分析相关的经济与政治问题、行业发展及案例研究。《温室气体：科学与技术》是一本令人兴奋的新型在线期刊，由化学工业学会（SCI）与约翰·威利父子公司共同出版。

Greenhouse Gases: Science and Technology

ABSTRACT This study outlines a comprehensive process design utilising glycerol‐steam reforming for an H 2 ‐enriched gas stream, coupled with carbon dioxide removal via a chemical absorption system, followed by a techno‐economic analysis. The Aspen Plus economic analyser assesses the developed model, incorporating simulation results and literature data. Initially, the CO 2 capture unit was planned with a standalone absorber and stripper, later integrated for solvent makeup calculation. Findings reveal that as catalyst loading increased from 5 to 50 kg, glycerol conversion and product molar fraction improved. For a targeted H 2 production of 10 t/day, optimal reactor dimensions are 3.2 m diameter and 30 m length, corresponding to a reactant flow of 105 t/day and a 2.52 MW heat duty at stoichiometry conditions. To capture 95% CO 2 from the reformed product stream, absorber and stripper packing heights of 12 and 7 m, respectively, with column diameters of 1.25 and 2.71 m are necessary. The production cost of H 2 is determined to be $3.8 per kg, as revealed by the techno‐economic analysis. Calculated values for net present value, discounted payback period, and internal rate of return stand at $30 million, 5 years, and 25.0%, respectively. © 2024 Society of Chemical Industry and John Wiley &amp; Sons, Ltd.

Pali Rosha

Mohammad Sajjadi

Hussameldin Ibrahim

Greenhouse Gases Science and Technology

Techno‐Economic Analysis of Glycerol Steam Reforming with Amine‐Based Carbon Capture for Blue Hydrogen Production: A Rate‐Based Kinetic Model Approach

甘油蒸汽重整与胺基碳捕集技术经济分析用于蓝氢生产：基于速率的动力学模型方法

Abstract Ammonia carbon capture is characterized by low corrosion, resistance to oxidation and degradation, and low energy consumption for regeneration. However, it also presents challenges such as a slow absorption rate and notable ammonia escape. Current ammonia decarbonization research primarily focuses on the flue gas from power plants, which differs in composition from ship exhaust gas. To address this, we constructed a small carbon absorption test bench and used a mixture of CO 2 and N 2 as the ship exhaust gas. Ammonia solution and alcohol served as absorbents and additives, respectively, to explore the effects of the additive hydroxyl number, the concentrations of the additive and ammonia solution, and the reaction temperature on carbon loading, absorption rate, and ammonia escape. Results indicated that n‐propanol was most effective in inhibiting ammonia escape, and a low concentration of ammonia solution was more suitable for absorbing CO 2 . Specifically, when the concentration of ammonia was 4% and the concentration of n‐propanol was 0.2 mol/L, the cumulative ammonia escape was reduced by 34% compared to the scenario without additives. Additionally, the carbon loading and average absorption rate reached 0.49 mol CO 2 /mol NH 3 and 2.33 × 10 −3 mol·kg −1 ·min −1 , respectively, representing increases of 34.2 and 60.7%. However, as the reaction temperature increased, the effectiveness of n‐propanol in enhancing ammonia absorption diminished. © 2024 Society of Chemical Industry and John Wiley &amp; Sons, Ltd.

Yu Bin Wang

Jie Rui Yu

Xiao Xian Zhang

Hao Chen

Han Bang Ruan

Guo Hua Yang

Study on the effect of alcohol additives on ammonia decarburization performance and ammonia escape

酒精添加剂对氨脱碳性能及氨逃逸影响的研究

Abstract The objective of this study was to investigate the transport and fate of CO 2 injected into a sandstone reservoir in the western Farnsworth Unit, a hydrocarbon field in northern Texas. The study employed three‐dimensional multifluid‐phase numerical reactive solute and heat transport modeling. Model inputs were obtained from previous field characterization studies and calibrated to 8 years of historical production data. The CO 2 in the models was injected through multiple wells for the first 25 years of the simulations according to a water‐alternating gas schedule. The simulations were carried out for a total of 1000 years in order to study the long‐term effects of CO 2 injection. The results show that the largest fraction of the injected CO 2 is stored in oil, followed by successively smaller amounts in the formation water, carbonate mineral phases, and as an immiscible gas phase. The small fraction of CO 2 present as an immiscible gas, the most mobile phase for CO 2 , aids in the long‐term sequestration security of the injected CO 2 . The injected CO 2 was found to migrate within a maximum radius of around 500 m of the injection wells. This means that changes in fluid pressure, temperature, composition, and reservoir mineralogy were also limited to occurring within this radius. This radius is very sensitive to model relative permeability and capillary pressure values, which were determined from history matching to the field production data. The models predicted dolomite to be the main mineral sink for the injected CO 2 . Quartz was another mineral predicted to precipitate, whereas calcite, albite, chlorite, illite, and kaolinite were predicted to dissolve. The changes in mineral abundance had minimal effect on porosity, implying that the permeability of the reservoir should also not change much because of CO 2 injection. © 2023 Society of Chemical Industry and John Wiley &amp; Sons, Ltd.

Eusebius J. Kutsienyo

Martin S. Appold

Mark D. White

William Ampomah

Field‐scale reactive transport assessment of CO<sub>2</sub> storage in the Farnsworth unit through enhanced oil recovery practices

通过提高采油率实践对Farnsworth单元二氧化碳储存的现场尺度反应输运评估

Abstract As energy demand continues to rise and conventional fuel sources dwindle, there is growing emphasis on previously overlooked reservoirs, such as tight reservoirs. Shale and coal formations have emerged as highly attractive options due to their substantial contributions to global gas reserves. Enhanced shale gas recovery (ESGR) and enhanced coalbed methane recovery (ECBM) based on gas injection are advanced techniques used to increase the extraction of gas from shale and coal formations. One of the key challenges associated with these formations and their enhanced recovery methods is accurately predicting the sorption process and its profile. This is crucial because it affects how methane (CH 4 ) and carbon dioxide (CO 2 ) are stored and released from the rock, and it significantly impacts the evaluation of gas content and the potential productivity of these formations. Due to the high cost of experimental procedures and the moderate accuracy of existing predictive approaches, this study proposes various cheap and consistent data‐driven schemes for predicting the sorption of CH 4 and CO 2 in shale and coal formations. In this regard, three intelligent models, including generalized regression neural network (GRNN), radial basis function neural network (RBFNN), and categorical boosting (CatBoost), were taught and tested using more than 3800 real measurements of CH 4 and CO 2 sorption in shale and coal formations. To find automatically their appropriate control parameters and improve their prediction ability, RBFNN and CatBoost were evolved using grey wolf optimization (GWO). The obtained results exhibited the encouraging prediction capabilities of the suggested models. In addition, it was found that CatBoost‐GWO is the most accurate scheme with total root mean square (RMSE) and determination coefficient ( R 2 ) of 0.1229 and 0.9993 for CO 2 sorption, and 0.0681 and 0.9970 for CH 4 sorption, respectively. Additionally, this approach demonstrated its physical validity by respecting the real sorption tendencies with respect to operational parameters. Furthermore, the CatBoost‐GWO model outperforms recently published machine learning approaches. Lastly, the findings of this study offer a significant contribution by demonstrating that the suggested model can greatly improve the ease of estimating CO 2 and CH 4 sorption in tight formations, thereby facilitating the simulation of other parameters related to this process. © 2024 Society of Chemical Industry and John Wiley &amp; Sons, Ltd.

Fahd Mohamad Alqahtani

Mohamed Riad Youcefi

Hakim Djema

Menad Nait Amar

Mohammad Ghasemi

Data‐driven framework for predicting the sorption capacity of carbon dioxide and methane in tight reservoirs

数据驱动框架预测致密储层中二氧化碳和甲烷的吸附能力

Abstract The reverse water‐gas shift (RWGS) reaction offers an effective method for mitigating CO 2 emissions. Due to its affordability and physicochemical stability, iron has garnered significant attention as a potential catalyst for RWGS. The incorporation of nickel and copper promoters can enhance CO 2 conversion and CO selectivity in Fe‐based catalysts. This study focuses on modifying the strength of the Strong Metal‐Support Interaction (SMSI) through particle size optimization. Doping Cu into NiFe‐based catalysts restricts particle size, which influences the curvature of the Ni 0 @FeO x interface. This curvature enhances the electron coupling between Ni 0 and FeO x , promoting the formation of a denser and thicker Ni 0 and FeO x layer. This results in a nearly 90% increase in the CO 2 reaction rate during the sintering resistance test by anchoring Ni 0 and facilitating electron transfer to active sites. Such morphological evolution improves high‐temperature resistance to sintering during RWGS. © 2024 Society of Chemical Industry and John Wiley &amp; Sons, Ltd.

Jiayi Wu

Wenhao Zhang

Hecao Chen

Weifeng Yu

Bo Sun

Minghui Zhu

Yi‐Fan Han

Enhanced sintering resistance of NiFe‐based RWGS catalysts through Cu doping

通过Cu掺杂提高NiFe基RWGS催化剂的烧结抗性

Abstract Large‐scale geological storage of carbon dioxide (CO 2 ) is indispensable for mitigating climate change but faces significant challenges, especially in the accurate quantitative assessment of leakage risks to ensure long‐term security. Given these circumstances, this paper proposes an innovative approach for quantitatively assessing CO 2 leakage risk to address the previous limitations of limited accuracy and insufficient data. We construct a fault tree and transform it into a Bayesian network–directed acyclic graph, and then use judgment sets along with fuzzy set theory to obtain prior probabilities of root nodes. The feature, event, and process method was utilized to identify key components and subsequently determine the conditional probability table (CPT) of the leaf node. The subjective experience assessments from experts are defuzzified to obtain the CPTs of intermediate nodes. The obtained basic probability parameters are input into the directed acyclic graph to complete the model construction. After calculating the leakage probability using this model, it is combined with the severity of impacts to conduct a comprehensive risk assessment. Furthermore, critical CO 2 risk sources can be determined through posterior probability calculations when intermediate nodes are designated as deterministic risk events. The gradual implementation process of the proposed model is demonstrated via a typical case study. The results indicate an overall CO 2 leakage probability of 29%, with probabilities of leakage along faults/fractures, caprock, and well identified as 32%, 28%, and 19%, respectively. The project is categorized as a medium‐low risk level. When leakage is confirmed, tectonic movement, thickness, and delamination at interface connections/the presence of cracks are the critical risk sources, and measures to mitigate key risks are outlined. The identified key risk factors conform to empirical evidence and previous research, validating the accuracy of the model. This study is instrumental in CO 2 geological storage risk assessment and scalable development program design. © 2024 Society of Chemical Industry and John Wiley &amp; Sons, Ltd.

Meng Jing

Qi Li

Guizhen Liu

Quan Xue

Quantitative assessment of CO<sub>2</sub> leakage risk in geologic carbon storage management

地质碳封存管理中二氧化碳泄漏风险的定量评估

Abbreviation	Greenhouse Gas Sci Technol
Journal Impact	2.67
Quartiles(Global)	ENVIRONMENTAL SCIENCES(Q3)

ISSN	2152-3878
h-index	44

Publication Information	Publisher: John Wiley and Sons Inc，Publishing cycle: ，Journal Type: journal，Open Access Journals: No
Basic data	Year of publication: 2011，Proportion of original research papers: 91.84%，Self Citation Rate:3.70%， Gold OA Rate: 16.29%
Average review cycle	网友分享经验：>12周，或约稿
Average recruitment ratio	网友分享经验：较易

Greenhouse Gases: Science and Technology

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Techno‐Economic Analysis of Glycerol Steam Reforming with Amine‐Based Carbon Capture for Blue Hydrogen Production: A Rate‐Based Kinetic Model Approach

Study on the effect of alcohol additives on ammonia decarburization performance and ammonia escape

Field‐scale reactive transport assessment of CO₂ storage in the Farnsworth unit through enhanced oil recovery practices

Data‐driven framework for predicting the sorption capacity of carbon dioxide and methane in tight reservoirs

Enhanced sintering resistance of NiFe‐based RWGS catalysts through Cu doping

Techno‐Economic Analysis of Glycerol Steam Reforming with Amine‐Based Carbon Capture for Blue Hydrogen Production: A Rate‐Based Kinetic Model Approach

Study on the effect of alcohol additives on ammonia decarburization performance and ammonia escape

Enhanced sintering resistance of NiFe‐based RWGS catalysts through Cu doping

Data‐driven framework for predicting the sorption capacity of carbon dioxide and methane in tight reservoirs

Quantitative assessment of CO₂ leakage risk in geologic carbon storage management

Greenhouse Gases: Science and Technology

Journal Citation Format

A journal article with 1 author

A journal article with 2 authors

A journal article with 3 authors

A journal article with 5 or more authors

Books Citation Format

Thesis Citation Format

Web sites Citation Format

Patent Citation Format

Staying up late manually editing references? ivySCI automatically matches journals and helps you generate references with a single click.

Share Submission Experience

Techno‐Economic Analysis of Glycerol Steam Reforming with Amine‐Based Carbon Capture for Blue Hydrogen Production: A Rate‐Based Kinetic Model Approach

Study on the effect of alcohol additives on ammonia decarburization performance and ammonia escape

Field‐scale reactive transport assessment of CO2 storage in the Farnsworth unit through enhanced oil recovery practices

Data‐driven framework for predicting the sorption capacity of carbon dioxide and methane in tight reservoirs

Enhanced sintering resistance of NiFe‐based RWGS catalysts through Cu doping

Techno‐Economic Analysis of Glycerol Steam Reforming with Amine‐Based Carbon Capture for Blue Hydrogen Production: A Rate‐Based Kinetic Model Approach

Study on the effect of alcohol additives on ammonia decarburization performance and ammonia escape

Enhanced sintering resistance of NiFe‐based RWGS catalysts through Cu doping

Data‐driven framework for predicting the sorption capacity of carbon dioxide and methane in tight reservoirs

Quantitative assessment of CO2 leakage risk in geologic carbon storage management

Field‐scale reactive transport assessment of CO₂ storage in the Farnsworth unit through enhanced oil recovery practices

Quantitative assessment of CO₂ leakage risk in geologic carbon storage management