The Experts below are selected from a list of 1455 Experts worldwide ranked by ideXlab platform
Xiaoliang Huang - One of the best experts on this subject based on the ideXlab platform.
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Prediction Model of Water-Soluble Gas Content in a High-Pressure and High-Temperature Water-Soluble Gas Reservoir
Applied Geochemistry, 2021Co-Authors: Xiaoliang Huang, Li Jiqiang, Pengkun Wang, Feifei FangAbstract:Abstract In high-temperature, high-pressure (HTHP), Water-soluble gas reservoirs, a significant amount of natural gas is dissolved in the formation Water. During development, with changing reservoir pressure, the natural gas in the formation Water will be released. The released natural gas will carry the formation Water to form gas-liquid two-phase flow into the porous media of the gas reservoir, which results in premature Water breakthrough, thus changing the law of formation Water Invasion. In order to determine the influence of Water-soluble gas on formation Water Invasion, it is important to study the Water-soluble gas content of Water-soluble gas reservoirs. Based on experimentation and existing modeling, a prediction model was established for Water-soluble gas content in HTHP Water-soluble gas reservoirs, and the influence of Water-soluble gas content on Water Invasion was studied. From the results, the following conclusions can be drawn. (a) The content of Water-soluble gas increases with increasing pressure, first decreasing and then increasing with increasing temperature. (b) In addition to temperature and pressure, the factors affecting the content of Water-soluble gas include the gas components and the mineralization degree of formation Water. (c) The existing prediction model has the problems of large error and inconsistency with the measured value, (average error being 33.92%), especially lacking consideration of how changing carbon dioxide content in the gas composition affects the Water-soluble gas content. (d) Considering the influences of temperature, pressure, gas components, and formation Water mineralization on the prediction model of Water-soluble gas reservoirs, the calculation results of the model are more in line with the actual circumstances of gas reservoirs, with the average error being 6.81% and the accuracy of Water-soluble gas content prediction being increased five times. (e) Through case analysis, it is shown that the release of Water-soluble gas has a great impact on the Water breakthrough law of gas wells. Considering the Water-soluble gas, the Water breakthrough time of gas wells is relatively early. Results show that the Water-soluble gas content prediction model for HTHP Water-soluble gas reservoirs can predict the Water-soluble gas content of Water-soluble gas reservoirs more accurately, laying a foundation for understanding the Water Invasion law of Water-soluble gas reservoir development and developing such a gas reservoir efficiently.
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Influencing factor analysis of Water Invasion in condensate gas reservoir with bottom Water based on fuzzy comprehensive evaluation and orthogonal experiment
Geosystem Engineering, 2019Co-Authors: Yan Wende, Yuan Yingzhong, Xiaoliang Huang, Li JiqiangAbstract:ABSTRACTCondensate oil and Water Invasion coexist in the condensate gas reservoir with bottom Water. Because of influences of condensate oil pollution and Water Invasion, gas recovery obviously dec...
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Effects of Water Invasion law on gas wells in high temperature and high pressure gas reservoir with a large accumulation of Water-soluble gas
Journal of Natural Gas Science and Engineering, 2019Co-Authors: Xiaoliang Huang, Xiao Guo, Xiang Zhou, Chen Shen, Xiao Qianhua, Yan WendeAbstract:Abstract A high temperature and high pressure (HTHP) gas reservoir with a large accumulation of Water-soluble gas contains a large amount of dissolved gas in formation Water. The dissolved gas in the formation Water will be released due to formation pressure depletion in the production process. At present, few researches have been done on Water Invasion law of gas wells regarding the released dissolved gas, especially when the change rule of Water and gas is not clear in porous media after the release of Water-soluble gas, which leads to the unclear Water Invasion law and the gas reservoirs cannot be developed efficiently. In this paper, a visualization sand filling tube is used to conduct experiments to study the effects of the dissolved gas on the law of the gas-Water contact (GWC) changes in the Water-soluble gas release process. The experimental results show that the release of dissolved gas leads to a GWC rise at the beginning of the depressurization process. After the pressure drops to a lower level, the GWC will decline due to a large amount of dissolved gas being released from formation Water. Subsequently, numerical simulations are performed to study the effects of different solubilities of natural gas, the gas production rate, the aquifer size, and stress sensitivity on the Water Invasion law of the gas well. The simulation results show that a greater solubility of natural gas, a higher gas production rate, a larger aquifer size, and the existence of stress sensitivity all lead to stronger bottom Water coning and an early Water break-through. For the non-coning region, a greater solubility of natural gas will lead to a slower rise in the GWC. The simulation results show that the Water Invasion velocity with Water-soluble gas is faster than the velocity without Water-soluble gas.
Feifei Fang - One of the best experts on this subject based on the ideXlab platform.
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Prediction Model of Water-Soluble Gas Content in a High-Pressure and High-Temperature Water-Soluble Gas Reservoir
Applied Geochemistry, 2021Co-Authors: Xiaoliang Huang, Li Jiqiang, Pengkun Wang, Feifei FangAbstract:Abstract In high-temperature, high-pressure (HTHP), Water-soluble gas reservoirs, a significant amount of natural gas is dissolved in the formation Water. During development, with changing reservoir pressure, the natural gas in the formation Water will be released. The released natural gas will carry the formation Water to form gas-liquid two-phase flow into the porous media of the gas reservoir, which results in premature Water breakthrough, thus changing the law of formation Water Invasion. In order to determine the influence of Water-soluble gas on formation Water Invasion, it is important to study the Water-soluble gas content of Water-soluble gas reservoirs. Based on experimentation and existing modeling, a prediction model was established for Water-soluble gas content in HTHP Water-soluble gas reservoirs, and the influence of Water-soluble gas content on Water Invasion was studied. From the results, the following conclusions can be drawn. (a) The content of Water-soluble gas increases with increasing pressure, first decreasing and then increasing with increasing temperature. (b) In addition to temperature and pressure, the factors affecting the content of Water-soluble gas include the gas components and the mineralization degree of formation Water. (c) The existing prediction model has the problems of large error and inconsistency with the measured value, (average error being 33.92%), especially lacking consideration of how changing carbon dioxide content in the gas composition affects the Water-soluble gas content. (d) Considering the influences of temperature, pressure, gas components, and formation Water mineralization on the prediction model of Water-soluble gas reservoirs, the calculation results of the model are more in line with the actual circumstances of gas reservoirs, with the average error being 6.81% and the accuracy of Water-soluble gas content prediction being increased five times. (e) Through case analysis, it is shown that the release of Water-soluble gas has a great impact on the Water breakthrough law of gas wells. Considering the Water-soluble gas, the Water breakthrough time of gas wells is relatively early. Results show that the Water-soluble gas content prediction model for HTHP Water-soluble gas reservoirs can predict the Water-soluble gas content of Water-soluble gas reservoirs more accurately, laying a foundation for understanding the Water Invasion law of Water-soluble gas reservoir development and developing such a gas reservoir efficiently.
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Experimental study on Water Invasion mechanism of fractured carbonate gas reservoirs in Longwangmiao Formation, Moxi block, Sichuan Basin
Environmental Earth Sciences, 2019Co-Authors: Feifei Fang, Xizhe Li, Shusheng Gao, Huaxun Liu, Weijun Shen, Jie LiAbstract:Fractured carbonate gas reservoirs feature high heterogeneity and difficulty in development, and the Invasion of edge and bottom Water intensifies the complexity of exploitation of such gas reservoirs. In this study, reservoir cores with a permeability of 0.001 mD, 0.1 mD, and 10 mD were selected by analyzing the fracture characteristics of the Longwangmiao gas reservoir, and Water Invasion in fractured carbonate gas reservoirs with edge and bottom Water was simulated using an experimental system to investigate the effects of different parameters on gas reservoir exploitation. The results show that the larger the Water volume ratio, the more serious the Water Invasion and the lower the recovery factor. But Water aquifer did not strongly affect the recovery factor once the Water aquifer exceeded a critical value. The higher the gas production rate, the faster the Water Invasion and the smaller the recovery factor. The recovery factor peaked when the gas production rate was equivalent to the gas supply capacity of the matrix to the fractures. For gas reservoirs with the overall permeability, the higher the matrix permeability, the higher the recovery factor. Although an appropriate fracturing scale was able to enhance the recovery factor when its matrix permeability was low, an excessive fracturing scale would cause Water to flow along the fractures at a rapid rate, which further caused a sharp decline in the recovery factor. With the increase of matrix permeability, fractures exerted a decreasing effect on gas reservoirs. These results can provide insights into a better understanding of Water Invasion and the effects of reservoir properties so as to optimize gas production in fractured carbonate gas reservoirs.
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experimental study on the physical simulation of Water Invasion in carbonate gas reservoirs
Applied Sciences, 2017Co-Authors: Feifei Fang, Shusheng Gao, Huaxun Liu, Weijun Shen, Qingfu WangAbstract:Water Invasion in carbonate gas reservoirs often results in excessive Water production, which limits the economic life of gas wells. This is influenced by reservoir properties and production parameters, such as aquifer, fracture, permeability and production rate. In this study, seven full diameter core samples with dissolved pores and fractures were designed and an experimental system of Water Invasion in gas reservoirs with edge and bottom aquifers was established to simulate the process of Water Invasion. Then the effects of the related reservoir properties and production parameters were investigated. The results show that the edge and bottom aquifers supply the energy for gas reservoirs with dissolved pores, which delays the decline of bottom-hole pressure. The high Water aquifer defers the decline of Water Invasion in the early stage while the big gas production rate accelerates Water influx in gas reservoirs. The existence of fractures increases the discharge area of gas reservoirs and the small Water influx can result in a substantial decline in recovery factor. With the increase of permeability, gas production rate has less influence on recovery factor. These results can provide insights into a better understanding of Water Invasion and the effects of reservoir properties and production parameters so as to optimize the production in carbonate gas reservoirs.
Yan Wende - One of the best experts on this subject based on the ideXlab platform.
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Influencing factor analysis of Water Invasion in condensate gas reservoir with bottom Water based on fuzzy comprehensive evaluation and orthogonal experiment
Geosystem Engineering, 2019Co-Authors: Yan Wende, Yuan Yingzhong, Xiaoliang Huang, Li JiqiangAbstract:ABSTRACTCondensate oil and Water Invasion coexist in the condensate gas reservoir with bottom Water. Because of influences of condensate oil pollution and Water Invasion, gas recovery obviously dec...
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Effects of Water Invasion law on gas wells in high temperature and high pressure gas reservoir with a large accumulation of Water-soluble gas
Journal of Natural Gas Science and Engineering, 2019Co-Authors: Xiaoliang Huang, Xiao Guo, Xiang Zhou, Chen Shen, Xiao Qianhua, Yan WendeAbstract:Abstract A high temperature and high pressure (HTHP) gas reservoir with a large accumulation of Water-soluble gas contains a large amount of dissolved gas in formation Water. The dissolved gas in the formation Water will be released due to formation pressure depletion in the production process. At present, few researches have been done on Water Invasion law of gas wells regarding the released dissolved gas, especially when the change rule of Water and gas is not clear in porous media after the release of Water-soluble gas, which leads to the unclear Water Invasion law and the gas reservoirs cannot be developed efficiently. In this paper, a visualization sand filling tube is used to conduct experiments to study the effects of the dissolved gas on the law of the gas-Water contact (GWC) changes in the Water-soluble gas release process. The experimental results show that the release of dissolved gas leads to a GWC rise at the beginning of the depressurization process. After the pressure drops to a lower level, the GWC will decline due to a large amount of dissolved gas being released from formation Water. Subsequently, numerical simulations are performed to study the effects of different solubilities of natural gas, the gas production rate, the aquifer size, and stress sensitivity on the Water Invasion law of the gas well. The simulation results show that a greater solubility of natural gas, a higher gas production rate, a larger aquifer size, and the existence of stress sensitivity all lead to stronger bottom Water coning and an early Water break-through. For the non-coning region, a greater solubility of natural gas will lead to a slower rise in the GWC. The simulation results show that the Water Invasion velocity with Water-soluble gas is faster than the velocity without Water-soluble gas.
Zhang Yuan-hui - One of the best experts on this subject based on the ideXlab platform.
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Studies on Water Invasion Mechanism of Fractured-Watered Gas Reservoir
Natural Gas Geoscience, 2012Co-Authors: Zhang Yuan-huiAbstract:During the development of fractured and Watered gas reservoir,production wells can be easily accessed by the edge Water or bottom Water along the fracture channel,and gas-Water flow is developed.This causes the increase of flow resistance,closure and separation of some gas area,hence,the decrease of well production and recovery,which has great harm to gas production.Based on the characteristics of the fractured and Watered gas reservoir,a physical model of displacement of gas by Water is established.By means of Water Invasion seepage modeling experiment,the microscopic mechanism of Water Invasion about the gas reservoir is found.When the gas reservoir is Watered,gases are dominated by trapped gas,cut gas and Water-locked gas.Water Invasion of gas reservoir can be macroscopically classified into Water Invasion of rocks with low permeability,Water Invasion of gas reservoir and "reverse Water Invasion" of well shutdown.It makes the gas area separated and Watered,and changes the mobile gas into "dead gas".Combined with the mechanism of Water Invasion of gas reservoir,the Water Invasion rules of K6 gas well fracture system has been studied,which provided a sound basis for the development and adjustment of gas reservoirs.
Takafumi Matsui - One of the best experts on this subject based on the ideXlab platform.
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Evidence for ocean Water Invasion into the Chicxulub crater at the Cretaceous/Tertiary boundary
Meteoritics & Planetary Science, 2004Co-Authors: Kazuhisa Goto, Timothy J. Bralower, Eiichi Tajika, Takashi Hasegawa, Ryuji Tada, Takafumi MatsuiAbstract:The possibility of ocean Water Invasion into the Chicxulub crater following the impact at the Cretaceous/Tertiary boundary was investigated based on examination of an impactite between approximately 794.63 and 894.94 m in the Yaxcopoil-1 (Yax-1) core. The presence of cross lamination in the uppermost part of the impactite suggests the influence of an ocean current at least during the sedimentation of this interval. Abundant occurrence of nannofossils of late Campanian to early Maastrichtian age in the matrices of samples from the upper part of the impactite suggests that the carbonate sediments deposited on the inner rim margin and outside the crater were eroded and transported into the crater most likely by ocean Water that invaded the crater after its formation. The maximum grain size of limestone lithics and vesicular melt fragments, and grain and bulk chemical compositions show a cyclic variation in the upper part of the impactite. The upward fining grain size and the absence of erosional contact at the base of each cycle suggest that the sediments were derived from resuspension of units elsewhere in the crater, most likely by high energy currents association with ocean Water Invasion.
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evidence for ocean Water Invasion into the chicxulub crater at the cretaceous tertiary boundary
Meteoritics & Planetary Science, 2004Co-Authors: Kazuhisa Goto, Timothy J. Bralower, Eiichi Tajika, Takashi Hasegawa, Ryuji Tada, Takafumi MatsuiAbstract:The possibility of ocean Water Invasion into the Chicxulub crater following the impact at the Cretaceous/Tertiary boundary was investigated based on examination of an impactite between approximately 794.63 and 894.94 m in the Yaxcopoil-1 (Yax-1) core. The presence of cross lamination in the uppermost part of the impactite suggests the influence of an ocean current at least during the sedimentation of this interval. Abundant occurrence of nannofossils of late Campanian to early Maastrichtian age in the matrices of samples from the upper part of the impactite suggests that the carbonate sediments deposited on the inner rim margin and outside the crater were eroded and transported into the crater most likely by ocean Water that invaded the crater after its formation. The maximum grain size of limestone lithics and vesicular melt fragments, and grain and bulk chemical compositions show a cyclic variation in the upper part of the impactite. The upward fining grain size and the absence of erosional contact at the base of each cycle suggest that the sediments were derived from resuspension of units elsewhere in the crater, most likely by high energy currents association with ocean Water Invasion.
