Pub Date : 2023-09-18DOI: 10.46690/ager.2023.09.07
Liming Qiu, Yi Zhu, Qiang Liu, Minggong Guo, Dazhao Song, Anhu Wang
: The accurate detection of coal seam stress field effectively prevents coal and gas outbursts. This study uses wave velocity, wave velocity anomaly coefficient, and wave velocity gradient as indicators to identify stress anomalies in coal seam. The results show that these three indicators of wave velocity are all positively correlated with load, while changes in the wave velocity anomaly coefficient and wave velocity gradient are more gentle than those of wave velocity. The degree of damage of coal can be judged by the wave velocity anomaly coefficient, while the transition between high and low stress zones can be identified by the wave velocity gradient. In areas affected by geological structures such as valleys and mountain tops, the coal seam wave velocity and wave velocity anomaly coefficient may exhibit anomalies. The comparative analysis of wave velocity and its derived indicators can reveal the stress state and coal structure of coal seamwith higher accuracy, identify the areas affected by geological structures such as valleys and mountain tops, and determine the boundary of the stress relief zone after hydraulic fracturing. Combined with the actual geological structure characteristics of coal seam, it can accurately identify the stress disturbance region of coal seam and achieve the purpose of predicting coal and gas outbursts.
{"title":"Response law and indicator selection of seismic wave velocity for coal seam outburst risk","authors":"Liming Qiu, Yi Zhu, Qiang Liu, Minggong Guo, Dazhao Song, Anhu Wang","doi":"10.46690/ager.2023.09.07","DOIUrl":"https://doi.org/10.46690/ager.2023.09.07","url":null,"abstract":": The accurate detection of coal seam stress field effectively prevents coal and gas outbursts. This study uses wave velocity, wave velocity anomaly coefficient, and wave velocity gradient as indicators to identify stress anomalies in coal seam. The results show that these three indicators of wave velocity are all positively correlated with load, while changes in the wave velocity anomaly coefficient and wave velocity gradient are more gentle than those of wave velocity. The degree of damage of coal can be judged by the wave velocity anomaly coefficient, while the transition between high and low stress zones can be identified by the wave velocity gradient. In areas affected by geological structures such as valleys and mountain tops, the coal seam wave velocity and wave velocity anomaly coefficient may exhibit anomalies. The comparative analysis of wave velocity and its derived indicators can reveal the stress state and coal structure of coal seamwith higher accuracy, identify the areas affected by geological structures such as valleys and mountain tops, and determine the boundary of the stress relief zone after hydraulic fracturing. Combined with the actual geological structure characteristics of coal seam, it can accurately identify the stress disturbance region of coal seam and achieve the purpose of predicting coal and gas outbursts.","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-09-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135255964","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-09-13DOI: 10.46690/ager.2023.09.05
David A. Wood
Long horizontal wellbore sections are now a key requirement of oil and gas drilling, particularly for tight reservoirs. However, such sections pose a unique set of borehole-cleaning challenges which are quite distinct from those associated with less inclined wellbores. Experimental studies provide essential insight into the downhole variables that influence borehole cleaning in horizontal sections, typically expressing their results in multivariate empirical relationships with dimensionless cuttings bed thickness/concentration (H%). This study demonstrates how complementary empirical H% relationships focused on pairs of influential variables can be obtained from published experimental data using interpolated trends and optimizers. It also applies five machine learning algorithms to a compiled multivariate (10-variable) interpolated dataset to illustrate how reliable H% predictions can be derived based on such information. Seven optimizer-derived empirical relationships are derived using pairs of influential variables which are capable of predicting H% with root mean squared errors of less than 1.8%. The extreme gradient boosting model provides the lowest H% prediction errors from the 10-variable dataset. The results suggest that in drilling situations where sufficient, locally-specific, information for multiple influential variables is available, machine learning methods are likely to be more effective and reliable at predicting H% than empirical relationships. On the other hand, in drilling conditions where information is only available for a limited number of influential variables, empirical relationships involving pairs of influential variables can provide valuable information to assist with drilling decisions. Document Type: Original article Cited as: Wood, D. A. Variable interaction empirical relationships and machine learning provide complementary insight to experimental horizontal wellbore cleaning results. Advances in Geo-Energy Research, 2023, 9(3): 172-184. https://doi.org/10.46690/ager.2023.09.05
{"title":"Variable interaction empirical relationships and machine learning provide complementary insight to experimental horizontal wellbore cleaning results","authors":"David A. Wood","doi":"10.46690/ager.2023.09.05","DOIUrl":"https://doi.org/10.46690/ager.2023.09.05","url":null,"abstract":"Long horizontal wellbore sections are now a key requirement of oil and gas drilling, particularly for tight reservoirs. However, such sections pose a unique set of borehole-cleaning challenges which are quite distinct from those associated with less inclined wellbores. Experimental studies provide essential insight into the downhole variables that influence borehole cleaning in horizontal sections, typically expressing their results in multivariate empirical relationships with dimensionless cuttings bed thickness/concentration (H%). This study demonstrates how complementary empirical H% relationships focused on pairs of influential variables can be obtained from published experimental data using interpolated trends and optimizers. It also applies five machine learning algorithms to a compiled multivariate (10-variable) interpolated dataset to illustrate how reliable H% predictions can be derived based on such information. Seven optimizer-derived empirical relationships are derived using pairs of influential variables which are capable of predicting H% with root mean squared errors of less than 1.8%. The extreme gradient boosting model provides the lowest H% prediction errors from the 10-variable dataset. The results suggest that in drilling situations where sufficient, locally-specific, information for multiple influential variables is available, machine learning methods are likely to be more effective and reliable at predicting H% than empirical relationships. On the other hand, in drilling conditions where information is only available for a limited number of influential variables, empirical relationships involving pairs of influential variables can provide valuable information to assist with drilling decisions. Document Type: Original article Cited as: Wood, D. A. Variable interaction empirical relationships and machine learning provide complementary insight to experimental horizontal wellbore cleaning results. Advances in Geo-Energy Research, 2023, 9(3): 172-184. https://doi.org/10.46690/ager.2023.09.05","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-09-13","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135787441","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-09-08DOI: 10.46690/ager.2023.10.01
Boyun Guo, Peng Zhang
Concerns exist about CO2 leaks from conventional supercritical CO2 storage reservoirs. This study investigates injecting CO2 into low-temperature offshore reservoirs to lock it in a solid state, thus preventing potential leaks. An analytical model was developed to predict CO2 injectivity into frac-packed injection wells in these low-temperature reservoirs. While the initial transient flow model was complex with Bessel functions and exponential integral, it was further simplified for practical field application. Sensitivity analysis of the model reveals that injectivity is less sensitive to reservoir permeability but more sensitive to fracture conductivity. The analytical model suggests injectivity is directly proportional to fracture width and fracture permeability. The case study utilizing field data from the South China Sea indicates feasible injection rates ranging from 6 to 17 tons/day depending on fracture conductivity. This work provides an analytical tool to predict injectivity for CO2 storage in frac-packed low-temperature offshore reservoirs, contributing to carbon reduction and neutralization goals. Document Type: Short communication Cited as: Guo, B., Zhang, P. Theoretical assessment of CO2 injection into low-temperature water zones for non-leaking storage in hydrate form. Advances in Geo-Energy Research, 2023, 10(1): 1-6. https://doi.org/10.46690/ager.2023.10.01
{"title":"Theoretical assessment of CO2 injection into low-temperature water zones for non-leaking storage in hydrate form","authors":"Boyun Guo, Peng Zhang","doi":"10.46690/ager.2023.10.01","DOIUrl":"https://doi.org/10.46690/ager.2023.10.01","url":null,"abstract":"Concerns exist about CO2 leaks from conventional supercritical CO2 storage reservoirs. This study investigates injecting CO2 into low-temperature offshore reservoirs to lock it in a solid state, thus preventing potential leaks. An analytical model was developed to predict CO2 injectivity into frac-packed injection wells in these low-temperature reservoirs. While the initial transient flow model was complex with Bessel functions and exponential integral, it was further simplified for practical field application. Sensitivity analysis of the model reveals that injectivity is less sensitive to reservoir permeability but more sensitive to fracture conductivity. The analytical model suggests injectivity is directly proportional to fracture width and fracture permeability. The case study utilizing field data from the South China Sea indicates feasible injection rates ranging from 6 to 17 tons/day depending on fracture conductivity. This work provides an analytical tool to predict injectivity for CO2 storage in frac-packed low-temperature offshore reservoirs, contributing to carbon reduction and neutralization goals. Document Type: Short communication Cited as: Guo, B., Zhang, P. Theoretical assessment of CO2 injection into low-temperature water zones for non-leaking storage in hydrate form. Advances in Geo-Energy Research, 2023, 10(1): 1-6. https://doi.org/10.46690/ager.2023.10.01","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-09-08","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"136363181","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-08-20DOI: 10.46690/ager.2023.08.06
Mawda Awag, Eric Mackay, Saeed Ghanbari
The study presents a numerical modelling analysis on CO2 plume migration in a dipping storage aquifer with background flux, which incorporates residual and dissolution trapping of CO2. The purpose of this analysis is to investigate the effect of the background flow velocity on the CO2 plume migration during the early post-injection period. Different velocities of groundwater flow from low to high were considered in the aquifer model. The distribution, migration distance and velocity of the injected CO2 plume as well as the remaining mobile CO2 plume extent are estimated to determine how fast and far the plume propagates with time. Comparison of the results indicate that increasing the background flux velocity causes the plume to migrate longer distances up-dip, while it reduces the height distribution of the plume with time. This reduces the volume of mobile CO2 in the storage aquifer at larger velocities of background flux, hence decreasing the leakage risk of CO2 to the surface. In addition, the CO2 plume decelerates immediately after cessation of injection as its bottom rises vertically and the buoyancy force reduces as the thickness of the plume reduces. However, the plume then accelerates during the initial period of its subsequent lateral migration, as the plume becomes extended, and the buoyancy forces increases somewhat. The degree of lateral extension increases with increasing background water flow velocity, with the leading tip of the plume migrating faster than the trailing edge, until residual and dissolution trapping sufficiently reduce the volume of free phase CO2 that its migration is arrested. Document Type: Original article Cited as: Awag, M., Mackay, E., Ghanbari, A. The impact of background water flow on the early migration of a CO2 plume in a tilted aquifer during the post-injection period. Advances in Geo-Energy Research, 2023, 9(2): 125-135. https://doi.org/10.46690/ager.2023.08.06
研究了含背景通量的倾斜蓄水含水层中CO2羽流迁移的数值模拟分析，其中考虑了CO2的残余和溶解捕集。本分析的目的是研究注入后早期背景流速对CO2羽流迁移的影响。含水层模型考虑了地下水从低到高的不同流速。估算注入CO2羽流的分布、迁移距离和速度以及剩余的可移动CO2羽流范围，以确定羽流随时间传播的速度和距离。结果表明，背景通量速度的增大使羽流向上倾斜的迁移距离增大，同时减小了羽流高度随时间的分布。这在较大的背景通量速度下减少了储存含水层中流动二氧化碳的体积，从而降低了二氧化碳向地表泄漏的风险。另外，CO2羽流在停止喷射后，由于其底部垂直上升而立即减速，浮力随着羽流厚度的减小而减小。然而，在随后的横向迁移的初始阶段，随着羽流的延伸，羽流加速，浮力有所增加。横向扩展的程度随着背景水流速度的增加而增加，羽流的前端迁移速度快于尾缘，直到残余和溶解捕获足以减少自由相CO2的体积，从而阻止其迁移。引用本文:Awag, M.， Mackay, E.， Ghanbari, a .背景水流对倾斜含水层注入后早期CO2柱迁移的影响。地球能源研究进展，2023,9(2):125-135。https://doi.org/10.46690/ager.2023.08.06
{"title":"The impact of background water flow on the early migration of a CO2 plume in a tilted aquifer during the post-injection period","authors":"Mawda Awag, Eric Mackay, Saeed Ghanbari","doi":"10.46690/ager.2023.08.06","DOIUrl":"https://doi.org/10.46690/ager.2023.08.06","url":null,"abstract":"The study presents a numerical modelling analysis on CO2 plume migration in a dipping storage aquifer with background flux, which incorporates residual and dissolution trapping of CO2. The purpose of this analysis is to investigate the effect of the background flow velocity on the CO2 plume migration during the early post-injection period. Different velocities of groundwater flow from low to high were considered in the aquifer model. The distribution, migration distance and velocity of the injected CO2 plume as well as the remaining mobile CO2 plume extent are estimated to determine how fast and far the plume propagates with time. Comparison of the results indicate that increasing the background flux velocity causes the plume to migrate longer distances up-dip, while it reduces the height distribution of the plume with time. This reduces the volume of mobile CO2 in the storage aquifer at larger velocities of background flux, hence decreasing the leakage risk of CO2 to the surface. In addition, the CO2 plume decelerates immediately after cessation of injection as its bottom rises vertically and the buoyancy force reduces as the thickness of the plume reduces. However, the plume then accelerates during the initial period of its subsequent lateral migration, as the plume becomes extended, and the buoyancy forces increases somewhat. The degree of lateral extension increases with increasing background water flow velocity, with the leading tip of the plume migrating faster than the trailing edge, until residual and dissolution trapping sufficiently reduce the volume of free phase CO2 that its migration is arrested. Document Type: Original article Cited as: Awag, M., Mackay, E., Ghanbari, A. The impact of background water flow on the early migration of a CO2 plume in a tilted aquifer during the post-injection period. Advances in Geo-Energy Research, 2023, 9(2): 125-135. https://doi.org/10.46690/ager.2023.08.06","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2023-08-20","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"135877866","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-08-18DOI: 10.46690/ager.2023.09.02
Junqian Li, Jianchao Cai
: Shale oil and gas, as important unconventional resources, have been widely discussed in the last decade. The occurrence characteristics of fluids (oil, gas, and water) in shale reservoirs are closely related to the exploitation of shale oil and gas, therefore the quantitative characterization of fluid occurrence in shale reservoirs has received extensive attention. In this paper, the latest advances and potential challenges on this subject are summarized. With respect to shale oil, the amounts, ratios and micro-distributions of shale oil in different states can be determined using the state equation of liquid and adsorption ratio equation, which contributes to identifying high-quality shale oil reservoirs. However, it is still necessary to strengthen the research on the multi-attribute coupling relationship and oil-rock interaction of shale oil reservoirs, and the determination of occurrence characteristics of adsorbed and free oil under in situ reservoir conditions. In terms of shale gas evaluation, the process analysis method and isotope fractionation method effectively solve the problem of evaluating in situ gas-bearing characteristics of shale, and can accurately estimate the amounts of total, adsorbed and free gas. The quantum physisorption behavior of gas could be a new research direction to reveal the microscopic occurrence mechanism of shale gas. As for shale pore water, a complete evaluation procedure for determining the amounts and micro-distributions of adsorbed and free water in shale matrix pores has been established, which provides insight into the storage and flow of oil and gas. In future work, a study on the quantitative evaluation of water-rock interaction is significant for obtaining the adsorbed and free water under in situ reservoir conditions
{"title":"Quantitative characterization of fluid occurrence in shale reservoirs","authors":"Junqian Li, Jianchao Cai","doi":"10.46690/ager.2023.09.02","DOIUrl":"https://doi.org/10.46690/ager.2023.09.02","url":null,"abstract":": Shale oil and gas, as important unconventional resources, have been widely discussed in the last decade. The occurrence characteristics of fluids (oil, gas, and water) in shale reservoirs are closely related to the exploitation of shale oil and gas, therefore the quantitative characterization of fluid occurrence in shale reservoirs has received extensive attention. In this paper, the latest advances and potential challenges on this subject are summarized. With respect to shale oil, the amounts, ratios and micro-distributions of shale oil in different states can be determined using the state equation of liquid and adsorption ratio equation, which contributes to identifying high-quality shale oil reservoirs. However, it is still necessary to strengthen the research on the multi-attribute coupling relationship and oil-rock interaction of shale oil reservoirs, and the determination of occurrence characteristics of adsorbed and free oil under in situ reservoir conditions. In terms of shale gas evaluation, the process analysis method and isotope fractionation method effectively solve the problem of evaluating in situ gas-bearing characteristics of shale, and can accurately estimate the amounts of total, adsorbed and free gas. The quantum physisorption behavior of gas could be a new research direction to reveal the microscopic occurrence mechanism of shale gas. As for shale pore water, a complete evaluation procedure for determining the amounts and micro-distributions of adsorbed and free water in shale matrix pores has been established, which provides insight into the storage and flow of oil and gas. In future work, a study on the quantitative evaluation of water-rock interaction is significant for obtaining the adsorbed and free water under in situ reservoir conditions","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":8.2,"publicationDate":"2023-08-18","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"41882782","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-08-17DOI: 10.46690/ager.2023.09.03
H. Yarveicy
: This paper experimentally investigates how adding nanoparticles to Soloterra surfactant affects phase behavior and surfactant flooding. These experiments include three phases. In phase one, phase behavior tests are conducted on surfactant solutions to choose the compatible nanoparticle. Phase two entails measuring interfacial tension between the stable nanoparticle + surfactant solutions and hydrocarbon. In phase three, a series of micromodel flooding tests are conducted to experimentally study the possibility of enhancing oil recovery. A possible relationship between static phase behavior and dynamic fluid flow is studied to evaluate the effects of nanoparticles on surfactant solutions. The results of the phase behavior experiment show that Soloterra 964 is compatible with Al 2 O 3 and Cu 2 O. Moreover, the Soloterra 964 + copper oxide solution can help observe all three Winsor types. The interfacial tension test results show that adding nanoparticles to solutions leads to lower interfacial tension. The results of micromodel flooding experiments indicate that adding surfactant and nanoparticle to the injected solution leads to higher breakthrough time and oil recovery. In addition, type III flooding produced a less stable displacement pattern than types II-and II+.
{"title":"Effect of nanoparticles on phase behavior of surfactant-oil-water system: An application in multiphase flow system","authors":"H. Yarveicy","doi":"10.46690/ager.2023.09.03","DOIUrl":"https://doi.org/10.46690/ager.2023.09.03","url":null,"abstract":": This paper experimentally investigates how adding nanoparticles to Soloterra surfactant affects phase behavior and surfactant flooding. These experiments include three phases. In phase one, phase behavior tests are conducted on surfactant solutions to choose the compatible nanoparticle. Phase two entails measuring interfacial tension between the stable nanoparticle + surfactant solutions and hydrocarbon. In phase three, a series of micromodel flooding tests are conducted to experimentally study the possibility of enhancing oil recovery. A possible relationship between static phase behavior and dynamic fluid flow is studied to evaluate the effects of nanoparticles on surfactant solutions. The results of the phase behavior experiment show that Soloterra 964 is compatible with Al 2 O 3 and Cu 2 O. Moreover, the Soloterra 964 + copper oxide solution can help observe all three Winsor types. The interfacial tension test results show that adding nanoparticles to solutions leads to lower interfacial tension. The results of micromodel flooding experiments indicate that adding surfactant and nanoparticle to the injected solution leads to higher breakthrough time and oil recovery. In addition, type III flooding produced a less stable displacement pattern than types II-and II+.","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":8.2,"publicationDate":"2023-08-17","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"45453446","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-08-15DOI: 10.46690/ager.2023.09.01
Jifang Wan, Tao Meng, Jinlong Li, Wei Liu
: With the demand for peak-shaving of renewable energy and the approach of carbon peaking and carbon neutrality goals, salt caverns are expected to play a more effective role in oil and gas storage, compressed air energy storage, large-scale hydrogen storage, and temporary carbon dioxide storage. In order to effectively utilize the underground space of salt mines on a sound scientific basis, the construction of salt caverns for energy storage should implement the maximum utilization of salt layers, improve the cavern construction efficiency, shorten the construction period, and ensure cavern safety. In this work, built upon design experience and on-site practice in salt cavern gas storage, the four pivotal construction stages – conceptual design, solution mining simulation, tightness assessment, and stability evaluation – have been thoroughly enhanced, strengthening the technical framework for salt cavern energy storage.
{"title":"Energy storage salt cavern construction and evaluation technology","authors":"Jifang Wan, Tao Meng, Jinlong Li, Wei Liu","doi":"10.46690/ager.2023.09.01","DOIUrl":"https://doi.org/10.46690/ager.2023.09.01","url":null,"abstract":": With the demand for peak-shaving of renewable energy and the approach of carbon peaking and carbon neutrality goals, salt caverns are expected to play a more effective role in oil and gas storage, compressed air energy storage, large-scale hydrogen storage, and temporary carbon dioxide storage. In order to effectively utilize the underground space of salt mines on a sound scientific basis, the construction of salt caverns for energy storage should implement the maximum utilization of salt layers, improve the cavern construction efficiency, shorten the construction period, and ensure cavern safety. In this work, built upon design experience and on-site practice in salt cavern gas storage, the four pivotal construction stages – conceptual design, solution mining simulation, tightness assessment, and stability evaluation – have been thoroughly enhanced, strengthening the technical framework for salt cavern energy storage.","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":8.2,"publicationDate":"2023-08-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"44944189","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-08-03DOI: 10.46690/ager.2023.08.04
Wendong Wang, Qiuheng Xie, Han Wang, Yuliang Su, S. Rezaei-Gomari
{"title":"Pseudopotential-based multiple-relaxation-time lattice Boltzmann model for multicomponent and multiphase slip flow","authors":"Wendong Wang, Qiuheng Xie, Han Wang, Yuliang Su, S. Rezaei-Gomari","doi":"10.46690/ager.2023.08.04","DOIUrl":"https://doi.org/10.46690/ager.2023.08.04","url":null,"abstract":"","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":8.2,"publicationDate":"2023-08-03","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43677055","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2023-07-30DOI: 10.46690/ager.2023.08.01
Yongfei Yang, R. Horne, Jianchao Cai, Jun Yao
{"title":"Recent advances on fluid flow in porous media using digital core analysis technology","authors":"Yongfei Yang, R. Horne, Jianchao Cai, Jun Yao","doi":"10.46690/ager.2023.08.01","DOIUrl":"https://doi.org/10.46690/ager.2023.08.01","url":null,"abstract":"","PeriodicalId":36335,"journal":{"name":"Advances in Geo-Energy Research","volume":null,"pages":null},"PeriodicalIF":8.2,"publicationDate":"2023-07-30","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"43241676","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":1,"RegionCategory":"地球科学","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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