This study is based on the sedimentation conditions, organic geochemistry, storage spaces, physical properties, lithology and gas content of the shale gas reservoirs in Longmaxi Formation of the Jiaoshiba area and the...This study is based on the sedimentation conditions, organic geochemistry, storage spaces, physical properties, lithology and gas content of the shale gas reservoirs in Longmaxi Formation of the Jiaoshiba area and the gas accumulation mode is summarized and then compared with that in northern America. The shale gas reservoirs in the Longmaxi Formation in Jiaoshiba have good geological conditions, great thickness of quality shales, high organic content, high gas content, good physical properties, suitable depth, good preservation conditions and good reservoir types. The quality shales at the bottom of the deep shelf are the main target interval for shale gas exploration and development. Shale gas in the Longmaxi Formation has undergone three main reservoiring stages:the early stage of hydrocarbon generation and compaction when shale gas reservoirs were first formed; the middle stage of deep burial and large-scale hydrocarbon generation, which caused the enrichment of reservoirs with shale gas; the late stage of uplift, erosion and fracture development when shale gas reservoirs were finally formed.展开更多
Through analysis of components and carbon isotope compositions of gas desorbed from shale cores,the carbon isotope reversal phenomenon in the shale gas from the Silurian Longmaxi Formation of Jiaoshiba area in Sichuan...Through analysis of components and carbon isotope compositions of gas desorbed from shale cores,the carbon isotope reversal phenomenon in the shale gas from the Silurian Longmaxi Formation of Jiaoshiba area in Sichuan Basin were well studied.Results showed that compared with the wellhead gas,the desorbed gas from Longmaxi shale had significantly more wet components and more heavy carbon isotope values;carbon isotope values of each component became heavier with the desorption time,δ^(13)C_(1)values of different samples had maximum positive variations of 12.3-23.9‰,butδ^(13)C_(2)values only had maximum positive variations of 0.8e2.3‰,indicating carbon isotope values of methane changed more obviously than that of heavy hydrocarbon.The above results were consistent with previous results of shale core desorption experiments carried out by other researchers.Shale gas in strata might have no carbon isotope reversal,and the phenomenon thatδ^(13)C_(1)values changed more significantly thanδ^(13)C_(2)values during the core desorption was not caused by diffusion rate differences among different components,but mainly due to different desorption stages of methane and ethane,i.e.,the ethane was in its early desorption stage while the methane was in its later desorption stage;during the production process,phase differences among different components of alkane gas and differences in the desorption stages induced by adsorption,could be the major cause for total reversal of carbon isotopes of shale gas in Longmaxi Formation,but it also could not excluded that mixture of kerogen cracking gas and crude oil cracking gas probably had a partial or more major contribution to the carbon isotope reversal.展开更多
It is essential to investigate shale lithofacies distribution and controlling factor of the shale for geological evaluation of shale gas exploration and development.Through comprehensive analysis of cores,thin section...It is essential to investigate shale lithofacies distribution and controlling factor of the shale for geological evaluation of shale gas exploration and development.Through comprehensive analysis of cores,thin sections,cathode luminescence,whole-rock X-ray diffraction,element capture spectroscopy,major/trace element and other data,three major types and eight sub-type shale lithofacies in the shale of Wufeng Formation-Member 1 of Longmaxi Formation in Jiaoshiba area are identified by the three-end-member method and shale lithological classification nomenclature,and the spatiotemporal distribution law and main development controlling factors of shale lithofacies are well studied.In the Jiaoshiba area,vertically,the marine shale develops siliceous shale,mixed shale and argillaceous shale from bottom to top.Besides,lateral distribution of the shale is different from north to south;the shale lithofacies in the north area changes rapidly,the mixed shale in the north area is much thicker than that in the south area,while the siliceous shale in the south area is relatively thicker.Difference in the shale lithofacies is controlled by special sedimentary geologic events;development of the siliceous shale is controlled by the Ordovician-Silurian global volcanic event to some extent,while the mixed shale is significantly influenced by effect of bottom current,and the argillaceous shale is mainly affected by supply of terrestrial clastic material.展开更多
页岩气的生成和聚集具有不同于常规油气藏的独特规律,页岩气储层的研究是页岩气勘探与开发的核心问题。目前,对焦石坝地区页岩气储层的认识是相对有限的,需要对本区页岩气储层做进一步研究。基于大量实验室测试数据的统计分析显示:上奥...页岩气的生成和聚集具有不同于常规油气藏的独特规律,页岩气储层的研究是页岩气勘探与开发的核心问题。目前,对焦石坝地区页岩气储层的认识是相对有限的,需要对本区页岩气储层做进一步研究。基于大量实验室测试数据的统计分析显示:上奥陶统五峰组和下志留统龙马溪组目的层段总有机碳(TOC)含量介于0.55%~5.89%,平均为2.54%,且具有自上而下有机碳含量逐渐增加的趋势;基于全岩X-射线衍射分析方法,页岩中黏土矿物含量介于16.6%~62.8%,平均为40.9%,自上而下逐渐减少,脆性矿物含量自上而下逐渐增加,总量介于37.2%~83.4%,平均为59.1%;基于氦气注入法检测了目的层段的孔隙度,实测氦气孔隙度介于1.17%~7.98%,平均为4.61%,目的层段孔隙度呈现出'两高夹一低'的三分性特征;稳态法水平渗透率介于0.002~335.209 m D,平均为23.785 m D;通过高压压汞法对储层孔隙结构进行了研究,大量的测试数据表明,介孔级别的孔隙发育,且介孔提供了主要的孔比表面积,而介孔和大孔对渗透率起主要的贡献;将氩离子剖光技术和扫描电镜(SEM)相结合对储层的孔隙类型进行了观察,总体表现为自上而下有机孔隙增加、无机孔隙减少;由解吸法测得总含气量介于0.44~5.19 m3/t,平均为1.97 m3/t,从上到下呈现出逐渐增大的趋势。研究表明,焦页1井海相页岩气储层发育的控制因素有矿物组成和有机质发育特征等。TOC是控制下部储层段的主要内在因素,也是提供页岩气储存空间的重要物质;成岩阶段晚期,黏土矿物组合发生变化,蒙脱石向伊利石转变,形成新的微孔隙,增加了储层的孔隙度,对上部储层段有较大影响;脆性矿物含量大于50%,易于形成裂缝,可造成地层渗透性能的显著增强。总体来看,五峰组和龙马溪组的底部层段是优质储层,也是主要的产气层段。展开更多
基金supported by the Sinopec Key Project named Whole Evaluation on Shale Gas Exploration and Targets Optimization in Sichuan Basin and Its Marginal Areas
文摘This study is based on the sedimentation conditions, organic geochemistry, storage spaces, physical properties, lithology and gas content of the shale gas reservoirs in Longmaxi Formation of the Jiaoshiba area and the gas accumulation mode is summarized and then compared with that in northern America. The shale gas reservoirs in the Longmaxi Formation in Jiaoshiba have good geological conditions, great thickness of quality shales, high organic content, high gas content, good physical properties, suitable depth, good preservation conditions and good reservoir types. The quality shales at the bottom of the deep shelf are the main target interval for shale gas exploration and development. Shale gas in the Longmaxi Formation has undergone three main reservoiring stages:the early stage of hydrocarbon generation and compaction when shale gas reservoirs were first formed; the middle stage of deep burial and large-scale hydrocarbon generation, which caused the enrichment of reservoirs with shale gas; the late stage of uplift, erosion and fracture development when shale gas reservoirs were finally formed.
基金This study was supported by the project of"Formation conditions and favorable zone evaluation of shale gas in the Lower Paleozoic of Sichuan Basin and its peripheral blocks"of Sinopec Science and Technology Division(No.P13129).
文摘Through analysis of components and carbon isotope compositions of gas desorbed from shale cores,the carbon isotope reversal phenomenon in the shale gas from the Silurian Longmaxi Formation of Jiaoshiba area in Sichuan Basin were well studied.Results showed that compared with the wellhead gas,the desorbed gas from Longmaxi shale had significantly more wet components and more heavy carbon isotope values;carbon isotope values of each component became heavier with the desorption time,δ^(13)C_(1)values of different samples had maximum positive variations of 12.3-23.9‰,butδ^(13)C_(2)values only had maximum positive variations of 0.8e2.3‰,indicating carbon isotope values of methane changed more obviously than that of heavy hydrocarbon.The above results were consistent with previous results of shale core desorption experiments carried out by other researchers.Shale gas in strata might have no carbon isotope reversal,and the phenomenon thatδ^(13)C_(1)values changed more significantly thanδ^(13)C_(2)values during the core desorption was not caused by diffusion rate differences among different components,but mainly due to different desorption stages of methane and ethane,i.e.,the ethane was in its early desorption stage while the methane was in its later desorption stage;during the production process,phase differences among different components of alkane gas and differences in the desorption stages induced by adsorption,could be the major cause for total reversal of carbon isotopes of shale gas in Longmaxi Formation,but it also could not excluded that mixture of kerogen cracking gas and crude oil cracking gas probably had a partial or more major contribution to the carbon isotope reversal.
基金The work was supported by supported by the National Science and Technology Major Project of China(2016ZX05060)the National Natural Science Foundation of China(No.41602147,No.41702149)the China Postdoctoral Science Foundation(2017M622559).
文摘It is essential to investigate shale lithofacies distribution and controlling factor of the shale for geological evaluation of shale gas exploration and development.Through comprehensive analysis of cores,thin sections,cathode luminescence,whole-rock X-ray diffraction,element capture spectroscopy,major/trace element and other data,three major types and eight sub-type shale lithofacies in the shale of Wufeng Formation-Member 1 of Longmaxi Formation in Jiaoshiba area are identified by the three-end-member method and shale lithological classification nomenclature,and the spatiotemporal distribution law and main development controlling factors of shale lithofacies are well studied.In the Jiaoshiba area,vertically,the marine shale develops siliceous shale,mixed shale and argillaceous shale from bottom to top.Besides,lateral distribution of the shale is different from north to south;the shale lithofacies in the north area changes rapidly,the mixed shale in the north area is much thicker than that in the south area,while the siliceous shale in the south area is relatively thicker.Difference in the shale lithofacies is controlled by special sedimentary geologic events;development of the siliceous shale is controlled by the Ordovician-Silurian global volcanic event to some extent,while the mixed shale is significantly influenced by effect of bottom current,and the argillaceous shale is mainly affected by supply of terrestrial clastic material.
文摘页岩气的生成和聚集具有不同于常规油气藏的独特规律,页岩气储层的研究是页岩气勘探与开发的核心问题。目前,对焦石坝地区页岩气储层的认识是相对有限的,需要对本区页岩气储层做进一步研究。基于大量实验室测试数据的统计分析显示:上奥陶统五峰组和下志留统龙马溪组目的层段总有机碳(TOC)含量介于0.55%~5.89%,平均为2.54%,且具有自上而下有机碳含量逐渐增加的趋势;基于全岩X-射线衍射分析方法,页岩中黏土矿物含量介于16.6%~62.8%,平均为40.9%,自上而下逐渐减少,脆性矿物含量自上而下逐渐增加,总量介于37.2%~83.4%,平均为59.1%;基于氦气注入法检测了目的层段的孔隙度,实测氦气孔隙度介于1.17%~7.98%,平均为4.61%,目的层段孔隙度呈现出'两高夹一低'的三分性特征;稳态法水平渗透率介于0.002~335.209 m D,平均为23.785 m D;通过高压压汞法对储层孔隙结构进行了研究,大量的测试数据表明,介孔级别的孔隙发育,且介孔提供了主要的孔比表面积,而介孔和大孔对渗透率起主要的贡献;将氩离子剖光技术和扫描电镜(SEM)相结合对储层的孔隙类型进行了观察,总体表现为自上而下有机孔隙增加、无机孔隙减少;由解吸法测得总含气量介于0.44~5.19 m3/t,平均为1.97 m3/t,从上到下呈现出逐渐增大的趋势。研究表明,焦页1井海相页岩气储层发育的控制因素有矿物组成和有机质发育特征等。TOC是控制下部储层段的主要内在因素,也是提供页岩气储存空间的重要物质;成岩阶段晚期,黏土矿物组合发生变化,蒙脱石向伊利石转变,形成新的微孔隙,增加了储层的孔隙度,对上部储层段有较大影响;脆性矿物含量大于50%,易于形成裂缝,可造成地层渗透性能的显著增强。总体来看,五峰组和龙马溪组的底部层段是优质储层,也是主要的产气层段。
