The Experts below are selected from a list of 300 Experts worldwide ranked by ideXlab platform
Jianfa Han - One of the best experts on this subject based on the ideXlab platform.
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Impacts of Thermochemical Sulfate Reduction, Oil Cracking, and Gas Mixing on the Petroleum Fluid Phase in the Tazhong Area, Tarim Basin, China
Energy & Fuels, 2019Co-Authors: Zhiyao Zhang, Guangyou Zhu, Yijie Zhang, Linxian Chi, Jianfa HanAbstract:Petroleum fluids in the deep Ordovician reservoirs of the Tarim Basin vary in phase and molecular composition. An improved understanding of the secondary Geochemical Alteration processes is critical for successful exploration and fluid property prediction. Three oil samples from the Ordovician condensate and oil reservoirs were analyzed using comprehensive 2D gas chromatography/time-of-flight mass spectrometry (GC×GC-TOFMS). Molecular signatures revealed varying levels of diamondoids and organosulfur compounds (OSCs) that were preferentially enriched in the condensate and a gas saturated oil; however, these molecular signatures were not generated through in-reservoir oil cracking or thermochemical sulfate reduction (TSR) as favorable thermal and medium conditions were not available. Severe cracking and TSR occurred in deeper Cambrian source-reservoirs and generated secondary Geochemical products including diamondoids, OSCs, and H2S. Such secondary products were carried by dry gases derived for oil crackin...
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The complexity, secondary Geochemical process, genetic mechanism and distribution prediction of deep marine oil and gas in the Tarim Basin, China
Earth-Science Reviews, 2019Co-Authors: Guangyou Zhu, Zhiyao Zhang, Xiaoxiao Zhou, Li Tingting, Jianfa Han, Sun ChonghaoAbstract:Abstract Most Paleozoic marine craton basins in China are rich in natural gas except the Tarim Basin, where both oil and gas are prolific. Various hydrocarbon types have been found in this basin, including deep ultra-heavy oil, heavy oil, normal oil, volatile oil, condensate and natural gas. Petroleums with diverse types even coexist within a single reservoir. Generally, the Ordovician and Cambrian reservoirs are deeply buried (5500–8000 m) and intensively altered after initial oil and gas accumulations, bringing challenges to physical property prediction before drilling and evaluation of exploration targets. Based on recent exploration discoveries and experimental data, we systematically analyzed the origin of oil and gas, demonstrated the mechanisms and processes of secondary Geochemical Alteration (e.g. biodegradation, gas washing fractionation, TSR and high-temperature cracking). Moreover, the preservation mechanism of ultra-deep normal oil was also clarified, and the distribution patterns of oil and gas were predicted. Tarim Basin has been uplifted and shallowly buried in the early accumulation stage, then rapidly and deeply buried in the late stage, resulting in various Geochemical Alteration processes at different burial stages. Through the reconstruction of complex deep-strata oil and gas accumulation histories, the spatial distribution of deep petroleum types were predicted. This review has provided detailed assessment with case studies in the Tarim Basin, and shed light on the preservation mechanisms and the Alteration processes of deep liquid petroleums. In addition to massive gas accumulations, liquid oils still have great exploration potential in strata deeper than 8000 m in the Tarim Basin.
Guangyou Zhu - One of the best experts on this subject based on the ideXlab platform.
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Impacts of Thermochemical Sulfate Reduction, Oil Cracking, and Gas Mixing on the Petroleum Fluid Phase in the Tazhong Area, Tarim Basin, China
Energy & Fuels, 2019Co-Authors: Zhiyao Zhang, Guangyou Zhu, Yijie Zhang, Linxian Chi, Jianfa HanAbstract:Petroleum fluids in the deep Ordovician reservoirs of the Tarim Basin vary in phase and molecular composition. An improved understanding of the secondary Geochemical Alteration processes is critical for successful exploration and fluid property prediction. Three oil samples from the Ordovician condensate and oil reservoirs were analyzed using comprehensive 2D gas chromatography/time-of-flight mass spectrometry (GC×GC-TOFMS). Molecular signatures revealed varying levels of diamondoids and organosulfur compounds (OSCs) that were preferentially enriched in the condensate and a gas saturated oil; however, these molecular signatures were not generated through in-reservoir oil cracking or thermochemical sulfate reduction (TSR) as favorable thermal and medium conditions were not available. Severe cracking and TSR occurred in deeper Cambrian source-reservoirs and generated secondary Geochemical products including diamondoids, OSCs, and H2S. Such secondary products were carried by dry gases derived for oil crackin...
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The complexity, secondary Geochemical process, genetic mechanism and distribution prediction of deep marine oil and gas in the Tarim Basin, China
Earth-Science Reviews, 2019Co-Authors: Guangyou Zhu, Zhiyao Zhang, Xiaoxiao Zhou, Li Tingting, Jianfa Han, Sun ChonghaoAbstract:Abstract Most Paleozoic marine craton basins in China are rich in natural gas except the Tarim Basin, where both oil and gas are prolific. Various hydrocarbon types have been found in this basin, including deep ultra-heavy oil, heavy oil, normal oil, volatile oil, condensate and natural gas. Petroleums with diverse types even coexist within a single reservoir. Generally, the Ordovician and Cambrian reservoirs are deeply buried (5500–8000 m) and intensively altered after initial oil and gas accumulations, bringing challenges to physical property prediction before drilling and evaluation of exploration targets. Based on recent exploration discoveries and experimental data, we systematically analyzed the origin of oil and gas, demonstrated the mechanisms and processes of secondary Geochemical Alteration (e.g. biodegradation, gas washing fractionation, TSR and high-temperature cracking). Moreover, the preservation mechanism of ultra-deep normal oil was also clarified, and the distribution patterns of oil and gas were predicted. Tarim Basin has been uplifted and shallowly buried in the early accumulation stage, then rapidly and deeply buried in the late stage, resulting in various Geochemical Alteration processes at different burial stages. Through the reconstruction of complex deep-strata oil and gas accumulation histories, the spatial distribution of deep petroleum types were predicted. This review has provided detailed assessment with case studies in the Tarim Basin, and shed light on the preservation mechanisms and the Alteration processes of deep liquid petroleums. In addition to massive gas accumulations, liquid oils still have great exploration potential in strata deeper than 8000 m in the Tarim Basin.
Zhiyao Zhang - One of the best experts on this subject based on the ideXlab platform.
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Impacts of Thermochemical Sulfate Reduction, Oil Cracking, and Gas Mixing on the Petroleum Fluid Phase in the Tazhong Area, Tarim Basin, China
Energy & Fuels, 2019Co-Authors: Zhiyao Zhang, Guangyou Zhu, Yijie Zhang, Linxian Chi, Jianfa HanAbstract:Petroleum fluids in the deep Ordovician reservoirs of the Tarim Basin vary in phase and molecular composition. An improved understanding of the secondary Geochemical Alteration processes is critical for successful exploration and fluid property prediction. Three oil samples from the Ordovician condensate and oil reservoirs were analyzed using comprehensive 2D gas chromatography/time-of-flight mass spectrometry (GC×GC-TOFMS). Molecular signatures revealed varying levels of diamondoids and organosulfur compounds (OSCs) that were preferentially enriched in the condensate and a gas saturated oil; however, these molecular signatures were not generated through in-reservoir oil cracking or thermochemical sulfate reduction (TSR) as favorable thermal and medium conditions were not available. Severe cracking and TSR occurred in deeper Cambrian source-reservoirs and generated secondary Geochemical products including diamondoids, OSCs, and H2S. Such secondary products were carried by dry gases derived for oil crackin...
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The complexity, secondary Geochemical process, genetic mechanism and distribution prediction of deep marine oil and gas in the Tarim Basin, China
Earth-Science Reviews, 2019Co-Authors: Guangyou Zhu, Zhiyao Zhang, Xiaoxiao Zhou, Li Tingting, Jianfa Han, Sun ChonghaoAbstract:Abstract Most Paleozoic marine craton basins in China are rich in natural gas except the Tarim Basin, where both oil and gas are prolific. Various hydrocarbon types have been found in this basin, including deep ultra-heavy oil, heavy oil, normal oil, volatile oil, condensate and natural gas. Petroleums with diverse types even coexist within a single reservoir. Generally, the Ordovician and Cambrian reservoirs are deeply buried (5500–8000 m) and intensively altered after initial oil and gas accumulations, bringing challenges to physical property prediction before drilling and evaluation of exploration targets. Based on recent exploration discoveries and experimental data, we systematically analyzed the origin of oil and gas, demonstrated the mechanisms and processes of secondary Geochemical Alteration (e.g. biodegradation, gas washing fractionation, TSR and high-temperature cracking). Moreover, the preservation mechanism of ultra-deep normal oil was also clarified, and the distribution patterns of oil and gas were predicted. Tarim Basin has been uplifted and shallowly buried in the early accumulation stage, then rapidly and deeply buried in the late stage, resulting in various Geochemical Alteration processes at different burial stages. Through the reconstruction of complex deep-strata oil and gas accumulation histories, the spatial distribution of deep petroleum types were predicted. This review has provided detailed assessment with case studies in the Tarim Basin, and shed light on the preservation mechanisms and the Alteration processes of deep liquid petroleums. In addition to massive gas accumulations, liquid oils still have great exploration potential in strata deeper than 8000 m in the Tarim Basin.
Pascal Audigane - One of the best experts on this subject based on the ideXlab platform.
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Predicting long-term Geochemical Alteration of wellbore cement in a generic geological CO2 confinement site: tackling a difficult reactive transport modeling challenge
Journal of Hydrology, 2012Co-Authors: Fabrizio Gherardi, Pascal Audigane, Eric C. GaucherAbstract:The safety of the future CO2 geological storage is largely dependent on the integrity of existing surrounding wells. Well integrity is of major concern in confinement sites where the number of abandoned wells is particularly high, such as it often occurs in depleted gas and/or oil fields. The degradation of the cement filling of these wells is a key issue to insure the confinement of the CO2. Laboratory experiments are unable to produce data for long periods of interaction; therefore, numerical modeling stands as a powerful means to predict the long-term evolution of the cement plugs, and to assess well integrity and leakage risk for the confining system. We thus present the 16 results of a set of numerical simulations that predict the evolution of fluid chemistry and mineral Alteration in the cement of an idealized abandoned wellbore at the top of the Dogger aquifer in Paris Basin, France, where CO2 geological disposal is currently under consideration. A continuum-based reactive transport formulation has been adopted which accounts for multi-component reactivity under water saturated and diffusion-controlled mass transfer conditions. Simplified two-dimensional models have been applied to simulate the complex Geochemical interactions occurring at the interfaces between cement, aquifer and caprock domains. The simulations predict a two-stage evolution of the cement porous matrix, after interaction with acid fluids from reservoir: (i) a first, "clogging" stage, characterized by a decrease in porosity due to calcite precipitation, and (ii) a second stage of porosity reopening, related to the disappearance of primary cement phases, and the re-dissolution of secondary minerals, such as zeolites. Overall, the interaction with acid fluids causes a severe mineralogical Alteration of the cement and the development of a carbonated, low-porosity layer near the reservoir interface. As the caprock imposes a high partial pressure of CO2, some mineralogical Alteration of the cement is promoted also at the interface with the caprock. This pattern of reaction results in a large increase in porosity that might lead to the formation of vertical ascent route for reservoir fluids.
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Predicting long-term Geochemical Alteration of wellbore cement in a generic geological CO2 confinement site: Tackling a difficult reactive transport modeling challenge
Journal of Hydrology, 2012Co-Authors: Fabrizio Gherardi, Pascal Audigane, Eric C. GaucherAbstract:International audienceThe safety of the future CO2 geological storage is largely dependent on the integrity of existing surrounding wells. Well integrity is of major concern in confinement sites where the number of abandoned wells is particularly high, such as it often occurs in depleted gas and/or oil fields. The degradation of the cement filling of these wells is a key issue to insure the confinement of the CO2. Laboratory experiments are unable to produce data for long periods of interaction; therefore, numerical modeling stands as a powerful means to predict the long-term evolution of the cement plugs, and to assess well integrity and leakage risk for the confining system. We thus present the 16 results of a set of numerical simulations that predict the evolution of fluid chemistry and mineral Alteration in the cement of an idealized abandoned wellbore at the top of the Dogger aquifer in Paris Basin, France, where CO2 geological disposal is currently under consideration. A continuum-based reactive transport formulation has been adopted which accounts for multi-component reactivity under water saturated and diffusion-controlled mass transfer conditions. Simplified two-dimensional models have been applied to simulate the complex Geochemical interactions occurring at the interfaces between cement, aquifer and caprock domains. The simulations predict a two-stage evolution of the cement porous matrix, after interaction with acid fluids from reservoir: (i) a first, "clogging" stage, characterized by a decrease in porosity due to calcite precipitation, and (ii) a second stage of porosity reopening, related to the disappearance of primary cement phases, and the re-dissolution of secondary minerals, such as zeolites. Overall, the interaction with acid fluids causes a severe mineralogical Alteration of the cement and the development of a carbonated, low-porosity layer near the reservoir interface. As the caprock imposes a high partial pressure of CO2, some mineralogical Alteration of the cement is promoted also at the interface with the caprock. This pattern of reaction results in a large increase in porosity that might lead to the formation of vertical ascent route for reservoir fluids
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integrative modeling of caprock integrity in the context of co2 storage evolution of transport and Geochemical properties and impact on performance and safety assessment
Oil & Gas Science and Technology-revue De L Institut Francais Du Petrole, 2010Co-Authors: Olivier Bildstein, Pascal Audigane, Christophe Kervévan, Vincent Lagneau, Philippe Delaplace, Anthony Crédoz, Erwan Perfetti, Nicolas Jacquemet, Michel JullienAbstract:The objective of the “Geocarbone-Integrite” project (2005-2008) was to develop a methodology to assess the integrity of the caprock involved in the geological storage of CO2 . A specific work package of the project (WP5) was dedicated to the integration of (1) the phenomenology describing the evolution of the storage system with a focus on the mechanisms occurring in the caprock and at the interface with the caprock, and (2) the data obtained from the investigation of petrographical, geomechanical, and Geochemical properties, before and after reaction with CO2 -rich solutions, performed in the other work packages (WP1 to WP4). This knowledge was introduced in numerical models and specific safety scenarios were defined in order to assess the performance of the CO2 storage system.The results of the modeling show that the injection of CO2 can potentially have a significant effect on the caprock by changing the porosity due to the dissolution and precipitation of minerals, but that the impact is limited to a zone from several decimeters to several meters of the caprock close to the interface with the reservoir depending on whether the supercritical carbon dioxide (SC-CO2 ) plume enters into the caprock and if fractures are present at this location.The methodology used in this project can be applied to a pilot site for the injection of CO2 in the Paris Basin. A key aspect of the safety of such a facility will be to look at the coupling of Geochemical Alteration and the evolution of geomechanical properties in the short and medium terms (several hundreds of years). The challenge for the future will be to structure and apply the safety assessment methodology with an operational finality, in order to support the robustness of the transition step to CGS projects at the industrial scale.
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Integrative modeling of caprock integrity in the context of CO2 storage: evolution of transport and Geochemical properties and impact on performance and safety assessment
Oil & Gas Science and Technology - Revue d'IFP Energies nouvelles, 2010Co-Authors: Olivier Bildstein, Pascal Audigane, Christophe Kervévan, Vincent Lagneau, Philippe Delaplace, Anthony Crédoz, Erwan Perfetti, Nicolas Jacquemet, Michel JullienAbstract:The objective of the “Géocarbone-Intégrité” project (2005-2008) was to develop a methodology to assess the integrity of the caprock involved in the geological storage of CO2. A specific work package of the project (WP5) was dedicated to the integration of (1) the phenomenology describing the evolution of the storage system with a focus on the mechanisms occurring in the caprock and at the interface with the caprock, and (2) the data obtained from the investigation of petrographical, geomechanical, and Geochemical properties, before and after reaction with CO2-rich solutions, performed in the other work packages (WP1 to WP4). This knowledge was introduced in numerical models and specific safety scenarios were defined in order to assess the performance of the CO2 storage system. The results of the modeling show that the injection of CO2 can potentially have a significant effect on the caprock by changing the porosity due to the dissolution and precipitation of minerals, but that the impact is limited to a zone from several decimeters to several meters of the caprock close to the interface with the reservoir depending on whether the supercritical carbon dioxide (SC-CO2) plume enters into the caprock and if fractures are present at this location. The methodology used in this project can be applied to a pilot site for the injection of CO2 in the Paris Basin. A key aspect of the safety of such a facility will be to look at the coupling of Geochemical Alteration and the evolution of geomechanical properties in the short and medium terms (several hundreds of years). The challenge for the future will be to structure and apply the safety assessment methodology with an operational finality, in order to support the robustness of the transition step to CGS projects at the industrial scale.
Sun Chonghao - One of the best experts on this subject based on the ideXlab platform.
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The complexity, secondary Geochemical process, genetic mechanism and distribution prediction of deep marine oil and gas in the Tarim Basin, China
Earth-Science Reviews, 2019Co-Authors: Guangyou Zhu, Zhiyao Zhang, Xiaoxiao Zhou, Li Tingting, Jianfa Han, Sun ChonghaoAbstract:Abstract Most Paleozoic marine craton basins in China are rich in natural gas except the Tarim Basin, where both oil and gas are prolific. Various hydrocarbon types have been found in this basin, including deep ultra-heavy oil, heavy oil, normal oil, volatile oil, condensate and natural gas. Petroleums with diverse types even coexist within a single reservoir. Generally, the Ordovician and Cambrian reservoirs are deeply buried (5500–8000 m) and intensively altered after initial oil and gas accumulations, bringing challenges to physical property prediction before drilling and evaluation of exploration targets. Based on recent exploration discoveries and experimental data, we systematically analyzed the origin of oil and gas, demonstrated the mechanisms and processes of secondary Geochemical Alteration (e.g. biodegradation, gas washing fractionation, TSR and high-temperature cracking). Moreover, the preservation mechanism of ultra-deep normal oil was also clarified, and the distribution patterns of oil and gas were predicted. Tarim Basin has been uplifted and shallowly buried in the early accumulation stage, then rapidly and deeply buried in the late stage, resulting in various Geochemical Alteration processes at different burial stages. Through the reconstruction of complex deep-strata oil and gas accumulation histories, the spatial distribution of deep petroleum types were predicted. This review has provided detailed assessment with case studies in the Tarim Basin, and shed light on the preservation mechanisms and the Alteration processes of deep liquid petroleums. In addition to massive gas accumulations, liquid oils still have great exploration potential in strata deeper than 8000 m in the Tarim Basin.