东濮凹陷深层天然气成藏机理研究
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摘要
本文立足于东濮凹陷勘探实践,以烃源岩生烃演化和气源对比研究为基础,以典型深层天然气藏成藏动态过程解剖为主线,应用天然气成藏理论、高精度流体包裹体分析、天然气成因判识、自生伊利石测年等一系列油气地质新理论、新技术,研究深层气藏成藏机理,分析深层天然气藏成藏主控因素。
综合利用镜质体反射率法和声波时差法恢复了古近纪末期地层的剥蚀厚度。在此基础上,恢复了东濮凹陷上古生界和古近系烃源岩热演化史与生烃史。研究表明,东营组沉积末期各洼陷地层剥蚀量大小不一,且具有隆起-斜坡-凹陷中心剥蚀量依次减小的特征,由此,烃源岩生烃得到不同程度的抑制甚至停止;新近纪以来盆地整体沉降和不同程度的沉积补偿使得烃源岩进入二次生烃阶段,故两套烃源岩埋藏和生烃演化具有时空分段性,生烃高峰期各异。
采用天然气组分、碳氢同位素、惰性气体同位素等方法进行气源对比。东濮凹陷天然气按成因可分为煤成气、油型气和混合气三种类型。煤成气主要聚集在中央隆起带早期形成的圈闭中;凝析气藏主要环绕濮城-前梨园、葛岗集和柳屯-海通集洼陷三大生气中心分布;混合型凝析气藏分布在断穿基底的二、三级断层附近。煤成气主要由烃源岩干酪根直接裂解而成,以游离相态运移为主,源岩内异常高压是煤成气运聚的主要动力,输导体系以断裂为主,成藏时间为沙一段至东营组剥蚀期,东营运动过程中,天然气边充注边散失,为一期连续充注动态成藏。深层凝析气类型包括原生型、原油裂解型、气侵富化型、逆蒸发型和混合型,源岩流体异常压力是油气运聚原始动力,以砂体输导、环洼分布为主,三期成藏:沙一-东营沉积期、东营抬升剥蚀期和新近纪7-5Ma以来。
煤成气成藏主控因素为烃源岩、输导体系和盖层。其中,烃源岩生气中心控制气藏的分布范围,输导体系控制天然气运聚成藏系统,盖层条件控制天然气纵向富集层位。深层凝析气成藏主控因素为烃源岩、成藏时间、输导体系、盖层。烃源岩母质条件控制凝析气富集程度,埋藏深和晚期成藏有利于凝析气藏的形成和保存,输导体系控制凝析气运聚成藏和分布,盖层条件控制天然气纵向富集层位。
Based on exploration practice, hydrocarbon evolution of source rock and gas source correlation, taking dynamic process of reservoir formation for special gas field, together with applying reservoir formation theory of natural gas, inclusion analysis of fluids with high accuracy, natural gas genesis recognition, autogenic illite age dating, this paper has studied gas reservoir formation mechanism and analyzed principle factors controlling gas reservoir formation.
Integrative applying of vitrinite reflectance and interval transit time method recovered denuded thickness of late Dongying formation of Baleaogene.By burial history and integrative thermal history simulation, thermal evolution and hydrocarbon generation of upper Paleozoic and Baleaogene source rock has been recovered in Dongpu depression. Study shows denudation of late Dongying formation is characteristic: thickness decreases along uplift-slope-center depression.As all the basin subsided and varying degrees sedimentary compensation since Eogene, source rock intake secondary oil generation. So source rock burial and hydrocarbon generation evolution of Baleaogene in Dongpu depression are of time space subsection and hydrocarbon generation peak is obviously of time space difference.
Using components of natural gas, carbon and hydrogen isotope and inert gases isotope, air source correlation for natural gas has been carried out. Natural gas in Dongpu depression can be classified into coal bed gas, oil bed gas and mixed gas by its genesis. Coal bed gas mainly accumulates in the trap developed early in central uplift; condensate gas reservoir mainly surrounds 3 principle gas generation center including Pucheng-Qianliyuan sub-depression, Gegangji sub-depression and Liutun-Haitongji sub-depression; while mixed condensate gas reservoir are near the faults through the basement.
Coal bed gas derived from kerogen cracking of source rock, main migrating in dissociated phase. Abnormal high pressure in the source rock is the main drive for gas accumulation and migration. Migration Pathways give priority to fractures,reservoir formating in denudation phase from Es1 to Ed. In the process of DongYing tectogenesis,gas dissipated when it’s infusing, dynamic reservoir formatting is one serises infusing.Deep condensate gas involves primary type,crude oil cracking type, gas cutting enrichment type, inverse evaporation type and mixed type. Abnormal high pressure in the source rock liquid is the main original drive for oil and gas accumulation and migration, give priority to sand body migration Pathways and surrounding distributing, dividing into three reservoir formation:Es1-Ed, the time of DongYing tectogenesis and 7-5Ma since Neocene.
There are mainly 3 factors controlling coal bed gas reservoir formation comprising of effective source rock, transport system and cap rock, among which gas generation center controls gas reservoir distribution, transport system constrains gas accumulation and migration and cap rock limits vertical enrichment of the gas. It is summed up that principle factors controlling condensate gas reservoir formation includes source rock, reservoir formation time, transport system and cap rock. Parent material of source rock controls condensate gas enrichment. Deep burial and late reservoir formation are favorable for development and preservation of deep condensate gas. Transport system controls condensate gas accumulation, migration and accumulation and cap rock controls vertical enrichment of natural gas.
综合利用镜质体反射率法和声波时差法恢复了古近纪末期地层的剥蚀厚度。在此基础上,恢复了东濮凹陷上古生界和古近系烃源岩热演化史与生烃史。研究表明,东营组沉积末期各洼陷地层剥蚀量大小不一,且具有隆起-斜坡-凹陷中心剥蚀量依次减小的特征,由此,烃源岩生烃得到不同程度的抑制甚至停止;新近纪以来盆地整体沉降和不同程度的沉积补偿使得烃源岩进入二次生烃阶段,故两套烃源岩埋藏和生烃演化具有时空分段性,生烃高峰期各异。
采用天然气组分、碳氢同位素、惰性气体同位素等方法进行气源对比。东濮凹陷天然气按成因可分为煤成气、油型气和混合气三种类型。煤成气主要聚集在中央隆起带早期形成的圈闭中;凝析气藏主要环绕濮城-前梨园、葛岗集和柳屯-海通集洼陷三大生气中心分布;混合型凝析气藏分布在断穿基底的二、三级断层附近。煤成气主要由烃源岩干酪根直接裂解而成,以游离相态运移为主,源岩内异常高压是煤成气运聚的主要动力,输导体系以断裂为主,成藏时间为沙一段至东营组剥蚀期,东营运动过程中,天然气边充注边散失,为一期连续充注动态成藏。深层凝析气类型包括原生型、原油裂解型、气侵富化型、逆蒸发型和混合型,源岩流体异常压力是油气运聚原始动力,以砂体输导、环洼分布为主,三期成藏:沙一-东营沉积期、东营抬升剥蚀期和新近纪7-5Ma以来。
煤成气成藏主控因素为烃源岩、输导体系和盖层。其中,烃源岩生气中心控制气藏的分布范围,输导体系控制天然气运聚成藏系统,盖层条件控制天然气纵向富集层位。深层凝析气成藏主控因素为烃源岩、成藏时间、输导体系、盖层。烃源岩母质条件控制凝析气富集程度,埋藏深和晚期成藏有利于凝析气藏的形成和保存,输导体系控制凝析气运聚成藏和分布,盖层条件控制天然气纵向富集层位。
Based on exploration practice, hydrocarbon evolution of source rock and gas source correlation, taking dynamic process of reservoir formation for special gas field, together with applying reservoir formation theory of natural gas, inclusion analysis of fluids with high accuracy, natural gas genesis recognition, autogenic illite age dating, this paper has studied gas reservoir formation mechanism and analyzed principle factors controlling gas reservoir formation.
Integrative applying of vitrinite reflectance and interval transit time method recovered denuded thickness of late Dongying formation of Baleaogene.By burial history and integrative thermal history simulation, thermal evolution and hydrocarbon generation of upper Paleozoic and Baleaogene source rock has been recovered in Dongpu depression. Study shows denudation of late Dongying formation is characteristic: thickness decreases along uplift-slope-center depression.As all the basin subsided and varying degrees sedimentary compensation since Eogene, source rock intake secondary oil generation. So source rock burial and hydrocarbon generation evolution of Baleaogene in Dongpu depression are of time space subsection and hydrocarbon generation peak is obviously of time space difference.
Using components of natural gas, carbon and hydrogen isotope and inert gases isotope, air source correlation for natural gas has been carried out. Natural gas in Dongpu depression can be classified into coal bed gas, oil bed gas and mixed gas by its genesis. Coal bed gas mainly accumulates in the trap developed early in central uplift; condensate gas reservoir mainly surrounds 3 principle gas generation center including Pucheng-Qianliyuan sub-depression, Gegangji sub-depression and Liutun-Haitongji sub-depression; while mixed condensate gas reservoir are near the faults through the basement.
Coal bed gas derived from kerogen cracking of source rock, main migrating in dissociated phase. Abnormal high pressure in the source rock is the main drive for gas accumulation and migration. Migration Pathways give priority to fractures,reservoir formating in denudation phase from Es1 to Ed. In the process of DongYing tectogenesis,gas dissipated when it’s infusing, dynamic reservoir formatting is one serises infusing.Deep condensate gas involves primary type,crude oil cracking type, gas cutting enrichment type, inverse evaporation type and mixed type. Abnormal high pressure in the source rock liquid is the main original drive for oil and gas accumulation and migration, give priority to sand body migration Pathways and surrounding distributing, dividing into three reservoir formation:Es1-Ed, the time of DongYing tectogenesis and 7-5Ma since Neocene.
There are mainly 3 factors controlling coal bed gas reservoir formation comprising of effective source rock, transport system and cap rock, among which gas generation center controls gas reservoir distribution, transport system constrains gas accumulation and migration and cap rock limits vertical enrichment of the gas. It is summed up that principle factors controlling condensate gas reservoir formation includes source rock, reservoir formation time, transport system and cap rock. Parent material of source rock controls condensate gas enrichment. Deep burial and late reservoir formation are favorable for development and preservation of deep condensate gas. Transport system controls condensate gas accumulation, migration and accumulation and cap rock controls vertical enrichment of natural gas.
引文
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