Gas Science and Engineering最新文献

{"title":"Gas hydrate stability for CO2-methane gas mixes in the Pegasus B asin, New Zealand: A geological control for potential gas production using methane-CO2 exchange in hydrates","authors":"Ingo A. Pecher ,&nbsp;Karsten F. Kroeger ,&nbsp;Gareth J. Crutchley ,&nbsp;Michael T. Macnaughtan","doi":"10.1016/j.jgsce.2024.205456","DOIUrl":"10.1016/j.jgsce.2024.205456","url":null,"abstract":"<div><div>Gas hydrate is an ice-like form of water containing gas, in nature mostly methane (CH₄), which requires moderate pressures and low temperatures. The replacement of CH₄ by CO₂, which also forms a hydrate, could allow CH₄ production from hydrate while sequestering CO₂. A number of recent studies have focused on theoretical background, experimental simulations, and engineering approaches related to CH₄-CO₂ exchange in hydrates. We here investigate a key geologic constraint for possible CH₄-CO₂ exchange in sub-seafloor reservoirs, hydrate stability. We analyze seismic data and gas hydrate system models from the Pegasus Basin east of New Zealand, a region with evidence for abundant gas hydrates. Pressure-temperature conditions beneath the seafloor need to be within the stability fields for both CH₄ hydrate and hydrate from the resulting gas mix after CO₂ injection. Based on experimental and theoretical studies, we consider 64% a benchmark for maximum achievable CH₄ replacement by CO₂, resulting in a mix of 64% CO₂ – 36% CH₄, in hydrate. Down to a water depth of 1087 m, hydrate from this gas mix is stable within the entire CH₄ hydrate stability field. A gap develops in deeper water with the base of gas hydrate stability (BGHS) for CH₄ being deeper than for the 64% CO₂ – 36% CH₄ mix. In nature, most mechanisms for CH₄ hydrate formation favor high saturation near the BGHS. For an evaluation of possible CH₄-CO₂ exchange, it is therefore important to investigate mixed-gas hydrate stability near the CH₄-BGHS and to identify CH₄ hydrates closer to the seafloor.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205456"},"PeriodicalIF":0.0,"publicationDate":"2024-09-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142320376","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":"Spontaneous imbibition in hydrate-bearing sediments under creep","authors":"Kailun Wang ,&nbsp;Gang Lei ,&nbsp;Jiangtao Qu ,&nbsp;Yang Wu ,&nbsp;Wan Cheng ,&nbsp;Jiadi Tang ,&nbsp;Yuyi Lu","doi":"10.1016/j.jgsce.2024.205452","DOIUrl":"10.1016/j.jgsce.2024.205452","url":null,"abstract":"<div><p>During hydrate exploitation, water generated by the phase transition of natural gas hydrate (NGH) invades the pore space of hydrate-bearing sediments (HBS) through spontaneous imbibition (SI), restricting the depressurization-based extraction. Besides, the creep behaviors of HBS complicate the SI process. Therefore, it is crucial to understand SI behaviors in HBS under creep. This study presents a theoretical model considering the effects of creep behaviors of HBS due to effective stress, as well as occurrence patterns and saturation of NGH. Moreover, fracture networks generation due to hydration in HBS, wall roughness, gravity, and dynamic contact angle are considered. The proposed model is adequately validated by available experimental data. In addition, based on the derived model, parameter sensitivity analysis is carried out. The results demonstrate that the porosity and wall roughness of HBS significantly enhance the SI capacity of HBS. Moreover, when other parameters are fixed, the SI capacity decreases with the increase of hydrate saturation (or retained water saturation). In addition, during the creep process, the SI capacity decreases with time. The derived model not only helps to better understand and predict the SI kinetics in gas hydrate reservoirs, but also provides guidance for the hydrate exploitation process.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205452"},"PeriodicalIF":0.0,"publicationDate":"2024-09-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142241188","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":"Gas hydrate technological applications: From energy recovery to carbon capture and storage","authors":"Ahmad AA. Majid","doi":"10.1016/j.jgsce.2024.205455","DOIUrl":"10.1016/j.jgsce.2024.205455","url":null,"abstract":"<div><p>Hydrates are crystalline structures that trap small gas molecules inside hydrogen-bonded water cages. These structures form at high pressure and low temperature. In recent years, there has been a growing interest in gas hydrates for technological applications, specifically in energy recovery, as well as carbon dioxide capture and storage. In the CO₂/CH₄ exchange using gas hydrates, researchers have reported a large amount of natural gas trapped in the form of gas hydrates under the ocean seafloor and permafrost regions. This large amount of natural gas trapped inside hydrate cages in oceanic and permafrost deposits has driven interest in the energy sector to investigate the possibility of safely harvesting gas hydrates as one of energy resources. However, there are still unanswered fundamental questions including the mechanism of natural gas recovery from gas hydrates. Another gas hydrate-based technology that has a growing interest is the use of gas hydrates for separation including carbon dioxide capture and storage. Carbon dioxide molecules have been shown to be preferentially trapped in the hydrate phase, demonstrating the possibility of the usage for carbon capture technology. Similarly, there are still underlying concerns of these applications, such as thermodynamics and stability of gas hydrates in porous materials, and the crystallization kinetics and mechanism of hydrate formation. This paper provides an overview of laboratory investigations conducted to understand the mechanism and evaluate the feasibility of energy recovery as well as discussion on recent advances in laboratory investigations on gas hydrate-based technology.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205455"},"PeriodicalIF":0.0,"publicationDate":"2024-09-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://www.sciencedirect.com/science/article/pii/S2949908924002516/pdfft?md5=46f959d3052890ffc1d17d12632743bc&pid=1-s2.0-S2949908924002516-main.pdf","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142257747","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"OA","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

{"title":"Solid amine adsorbent with surfactant modification for Direct Air Capture (DAC) under different temperature and humidity conditions","authors":"Yuxuan Wang ,&nbsp;Yihang Liu ,&nbsp;Yijun Wang ,&nbsp;Yihe Miao ,&nbsp;Takeshi Hagio ,&nbsp;Xinqi Qiao ,&nbsp;Xinling Li ,&nbsp;Zhen Huang","doi":"10.1016/j.jgsce.2024.205453","DOIUrl":"10.1016/j.jgsce.2024.205453","url":null,"abstract":"<div><p>Direct air capture (DAC) technologies have been vigorously pursued to achieve the goal of net-zero CO₂ emissions due to the dramatic increase in atmosphere CO₂ concentrations and global temperatures. In practical DAC conditions, variations in temperature and humidity can lead to different CO₂ adsorption outcomes. Current studies lack comprehensive information on the optimal temperature and humidity conditions for DAC. In this study, a comparison between PMSU-F (impregnating polyethyleneimine (PEI600) on MSU-F support) and PPMSU-F (co-impregnating polyethylene glycol (PEG200) with PEI600 on MSU-F support) under different temperature and relative humidity conditions were conducted. Under dry conditions, the addition of PEG200 effectively enhanced the adsorption capacity, adsorption rate, and amine efficiency and decreased the energy consumption for desorption depending on the comparison of the two absorbents. Under the popular atmospheric temperature ranges (−5 °C–45 °C), an increase in temperature favors CO₂ adsorption. Under humid conditions, the presence of PEG200 had a negative effect due to its strong hydrophilicity. By comparing dry and humid conditions, the introduction of moisture generally enhanced overall CO₂ adsorption performance, and the adsorption capacity interestingly further increased under low-temperature conditions. The highest CO₂ adsorbing capacity of PMSU-F (3.82 mmol/g) and PPMSU-F (3.76 mmol/g) appeared at −5 °C and 75% relative humidity, indicating that low temperature and relatively high relative humidity were more favorable for DAC, which is possibly attributed to the thermodynamic control under low temperatures with moisture. The results indicate that the adsorbents chosen in this study are promising for DAC under low temperatures and relatively high humidity conditions. The performances of modified DAC adsorbents, e.g., adsorption capacity, stability, antioxidant property for industrial-grade DAC system should be evaluated in the next work.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205453"},"PeriodicalIF":0.0,"publicationDate":"2024-09-16","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142241187","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":"Behaviors of hydrate cap formation via CO2-H2O collaborative injection:Applying to secure marine carbon storage","authors":"Mingjun Yang ,&nbsp;Mingyu Wu ,&nbsp;Ziming Yang ,&nbsp;Pengfei Wang ,&nbsp;Bingbing Chen ,&nbsp;Yongchen Song","doi":"10.1016/j.jgsce.2024.205451","DOIUrl":"10.1016/j.jgsce.2024.205451","url":null,"abstract":"<div><p>Leakage prevention of carbon dioxide (CO₂) determines the safety of carbon marine geological storage. Hydrate caps have been proven to be one of the most effective structures for preventing CO₂ leakage, which has attracted worldwide attention. However, the structure and formation behavior of hydrate caps during CO₂ storage process are still unclear. In this study, a strategy of CO₂-H₂O co-injection was proposed to simulate the actual flow process and accelerate the hydrate cap formation rate. A series of CO₂-H₂O flow rates (0.25–10 mL/min) were employed. The results show that there will be four stages for the dynamic formation process of hydrate cap: fluid migration and diffusion, local hydrate formation, local area plugging, and hydrate cap formation. What's more, the water-gas flow ratio is inversely proportional to hydrate cap formation rate and positively proportional to the carbon storage efficiency. Meanwhile, the huge sealed capacity of hydrate cap was also proved in this work. The sequestration pressure of CO₂ under hydrate cap exceeds 12 MPa, and the maximum carbon storage efficiency increases from 53.12% to 93.30%. Moreover, the macrostructure of hydrate cap consists of two layers with a certain hydrate saturation: the zero-permeability layer and the low-permeability layer. The zero-permeability layer determined the sealed capacity of hydrate cap. These findings may provide a theoretical foundation for the prevention of CO₂ leakage in actual project of carbon marine geological storage.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205451"},"PeriodicalIF":0.0,"publicationDate":"2024-09-14","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142241186","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":"Mechanical and acoustic characterization of carbon dioxide gas replacement of methane gas hydrate","authors":"Tao Liu,&nbsp;Peng Wu,&nbsp;Lei Huang,&nbsp;Yanghui Li,&nbsp;Yongchen Song","doi":"10.1016/j.jgsce.2024.205444","DOIUrl":"10.1016/j.jgsce.2024.205444","url":null,"abstract":"<div><p>CO₂ replacement presents a promising approach for the extraction of natural gas hydrate, offering advantages in cleanliness and safety. In this study, CO₂ replacement CH₄ hydrate experiments were carried out by using the triaxial, hydrate specimens with varying replacement ratios were prepared through different methods, and triaxial tests were performed to evaluate the mechanical properties of sediments after replacement. The key findings are as follows: the shear damage behaviors of CH₄, CO₂, and their mixed hydrate specimens are similar. Acoustic data indicates that initial CO₂ injection during replacement causes dissociation of CH₄ hydrate, potentially reducing the failure strength of the reservoir. However, post-replacement hydrate specimens exhibited higher failure strength than their original counterparts. This study provides valuable insights into the mechanical stability of CH₄ hydrate reservoirs during CO₂ replacement process.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205444"},"PeriodicalIF":0.0,"publicationDate":"2024-09-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142218448","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":"Undrained triaxial tests of underconsolidated overlying sediments of hydrate deposits in the South China Sea","authors":"Lei Wang ,&nbsp;Wenqi Yu ,&nbsp;Yang Ge ,&nbsp;Shi Shen ,&nbsp;Zhaoran Wu ,&nbsp;Yiming Zhu ,&nbsp;Yongchen Song ,&nbsp;Yanghui Li","doi":"10.1016/j.jgsce.2024.205442","DOIUrl":"10.1016/j.jgsce.2024.205442","url":null,"abstract":"<div><p>The South China Sea (SCS) is an important repository for natural gas hydrates (NGHs), where some NGH deposits and their overlying sediments (OSs) are in an underconsolidated state. During the exploitation of NGHs, the stability of the OSs of the NGH deposits is one of the key factors in ensuring mining safety. Especially under different consolidation degrees, the mechanical response and stability of the OSs will vary, which directly affects the safety and efficiency of the NGH mining. This research explores the influence of different consolidation degrees on the mechanical properties of the OSs of NGH deposits in the SCS. The strength and pore pressure characteristics were analyzed through undrained triaxial shear tests. The findings indicate that an increase in consolidation degree enhances the strain softening behavior, and an increase in initial effective stress enhance the strain hardening and shear contraction behaviors of the samples. The failure strength, modulus, and maximum excess pore pressure increase with the consolidation degree and initial effective stress, and there is an approximately linear correlation between failure strength and consolidation degree. Therefore, the exploitation of NGHs in the SCS must comprehensively consider the burial depth and consolidation degree of the OSs. The findings of this study will assist in optimizing mining plans and enhancing safety during the exploitation process.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205442"},"PeriodicalIF":0.0,"publicationDate":"2024-09-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142229770","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":"Hybrid machine learning framework for multi-well trajectory optimization in an unconventional field","authors":"D. Davudov ,&nbsp;U. Odi ,&nbsp;A. Gupta ,&nbsp;G. Singh ,&nbsp;B. Dindoruk ,&nbsp;A. Venkatraman ,&nbsp;K. Osei","doi":"10.1016/j.jgsce.2024.205443","DOIUrl":"10.1016/j.jgsce.2024.205443","url":null,"abstract":"<div><p>The well placement problem in the petroleum industry is usually solved by integrating an optimizer with a reservoir simulation model. This is a time-consuming approach requiring thousands of simulation runs depending on the complexity of the reservoir system. This paper introduces two well placement optimization models: a Fast-Marching Model (FMM) based on fluid flow physics and a Hybrid Model integrating reservoir simulations and FMM results with a gradient boosting algorithm. These models prioritize speed and accuracy when integrated with genetic algorithm optimization, demonstrated using a synthetic unconventional field. From 290 randomly selected locations across the synthetic unconventional field, simulation runs were performed to determine cumulative gas production and used as ground truth. Using reservoir properties at these locations as inputs, Relative Opportunity Ranking (ROR) maps were generated using the FMM and Hybrid Model approaches. The ROR maps were then linked with a genetic algorithm to determine optimal well locations, iteratively updating ROR maps with penalty maps until all wells were appropriately placed. Results indicated that the standalone FMM generated ROR maps were highly correlated with the simulation results. Time complexity analysis revealed that both models were significantly faster than traditional methods, with the FMM independent of simulation and the Hybrid Model requiring only about 290 simulation runs. Ultimately, these models have shown tremendous potential for integration into current reservoir engineering workflows, reducing decision-making times in both greenfield and brownfield scenarios.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205443"},"PeriodicalIF":0.0,"publicationDate":"2024-09-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142229769","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":"Numerical modeling of multiphase flow in porous media considering micro- and nanoscale effects: A comprehensive review","authors":"Jianchao Cai ,&nbsp;Xiangjie Qin ,&nbsp;Xuanzhe Xia ,&nbsp;Xinghe Jiao ,&nbsp;Hao Chen ,&nbsp;Han Wang ,&nbsp;Yuxuan Xia","doi":"10.1016/j.jgsce.2024.205441","DOIUrl":"10.1016/j.jgsce.2024.205441","url":null,"abstract":"<div><div>Multiphase flow in porous media involves a variety of natural and industrial processes. However, the microscopic description of multiphase flow is challenging due to fluid-fluid and fluid-solid interactions combined with complex pore topology. Thus, a systematic review of multiphase flow from molecular to pore scale perspectives is necessary. This work summarizes recent progress in numerical modeling of multiphase flow from molecular scale, pore scale, and reservoir scale simulations considering micro- and nanoscale effects. The analysis focuses on immiscible and miscible flow associated with liquid and gas phases, highlighting the micro- and nanoscale effects on the flow characteristics. Molecular simulations capture nanoscale effects such as adsorption, diffusion, and slip behaviors. The variation of wettability, pressure, and fluid saturation leads to film, slug, and droplet flows in nanopores. Pore scale simulations explain complex flow behaviors in microporous and nanoporous media. Capillary number and wettability lead to different invasion morphologies. Adsorption and slip effects are non-negligible for fluid flow in nanoporous media. Furthermore, there are obvious differences in reservoir simulation results with and without considering micro- and nanoscale effects. Generally, this in-depth review is intended to provide a comprehensive description of the multiphase flows through multiscale simulation methods being developed and assist industrial processes.</div></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"131 ","pages":"Article 205441"},"PeriodicalIF":0.0,"publicationDate":"2024-09-10","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142327207","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":"Impact mechanism of microscopic pore structure on sensitivity and ability of CO2-ECBM based on X-ray nano-CT","authors":"Liuni Song ,&nbsp;Xiaoyang Guo ,&nbsp;Cunbao Deng ,&nbsp;Lemei Zhang ,&nbsp;Yu Zhang ,&nbsp;Linjie Cao","doi":"10.1016/j.jgsce.2024.205436","DOIUrl":"10.1016/j.jgsce.2024.205436","url":null,"abstract":"<div><p>To scientifically explain the mechanism of increasing CBM production by CO₂ injection pressure from the microscopic scale, and effectively evaluate the CBM production enhancement potential, adopting the fluid intrusion method and ray non-destructive testing technique, this research reconstructed the real coal microscopic pore structure and carried out the microscopic scale numerical simulation of CO₂-ECBM. The results indicate that there exists a limit to the magnitude of growth in CO₂-ECBM displacement efficiency driven by gas injection pressure. The pressure sensitivity, enhancing potential, and production enhancement ability of CO₂-ECBM change continually over time. In high metamorphic coal reservoirs, the disadvantages of the engineering cycle, absolute displacement efficiency, and CBM production-increasing ability are obvious, while pressure sensitivity and enhancing potential are higher in the middle and late stages. The differences exhibited by CO₂-ECBM in different metamorphic coals are attributed to the pore structure quality. Specifically, high-quality pores have the characteristics of convenient passage, multiple paths, and higher pore surface areas. The findings can enrich the CO₂-ECBM production enhancement mechanism in different coal seams, providing new theoretical viewpoints for accurately assessing its application effect and production enhancement potential.</p></div>","PeriodicalId":100568,"journal":{"name":"Gas Science and Engineering","volume":"130 ","pages":"Article 205436"},"PeriodicalIF":0.0,"publicationDate":"2024-08-31","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"142122342","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}