华北下古生界原生油气藏的形成条件

重点讨论了华北下古生界原生油气藏的生油条件及保存条件。根据29条露头剖面及44口井资料,编制了一套生油条件分析图六幅,划出了七个生油层组,圈出了各组有利及较有利生油区,分析了下古生界区域构造发展轮廓,为进一步研究下古生界生油条件奠定基础。 从华北下古生界经历的历次地壳运动性质,结合二次生油理论,讨论了下古生界原生油气藏的保存条件。最后初步指出了华北下古生界原生油气藏的勘探方向。     

利用特征元素随钻确定济阳坳陷下古生界顶界面技术

随钻判断下古生界顶界面,是济阳坳陷下古生界碳酸盐岩油气藏钻井施工中的录井核心工作。济阳坳陷下古生界顶界面的类型分为高位角度不整合、低位角度不整合、断层式、平行不整合四种类型。X射线荧光录井仪可以随钻快速分析1 2种元素。研究发现,对于高位角度不整合、低位角度不整合和断层式界面,钻至下古生界碳酸盐岩Ca、Mg元素含量会大幅度提高;对于平行不整合式界面,上古生界石炭系本溪组灰岩的Al元素含量明显大于下古生界奥陶系八陡组灰岩的。现场使用X射线荧光录井仪随钻分析岩屑,根据特征元素确定济阳坳陷下古生界顶界面,具有准确、快速、低成本的特点,提高了勘探综合效益。     

鄂尔多斯地区古生界生烃史和排烃史的模拟

利用盆地模拟方法对鄂尔多斯地区古生界的生烃史和排烃史进行了模拟研究．结果表明，该区上古生界烃源岩处于高成熟阶段，下古生界烃源岩已进入过成熟阶段，这两套烃源岩在地史上都出现过两次生、排烃高峰，上古生界的生、排烃量远大于下古生界．这些结果可用于评价该区的油气远景和认识油气藏的形成过程。     

南华北下古生界海相碳酸盐岩评价标准研究

关于碳酸盐岩类烃源岩有机质丰度的下限值至今尚无统一标准,本文主要研究南华北地区下古生界海相碳酸盐岩的评价标准。通过参考大量国内外前人提出的碳酸盐岩有机质丰度下限,根据南华北地区下古生界海相碳酸盐岩有机质丰度、类型及成熟度的具体情况提出适合本地区下古生界海相碳酸盐岩的评价标准并给予烃源岩的初步评价。     

鄂尔多斯地区古生界生烃史和排烃史的模拟

利用盆地模拟方法对鄂尔多斯地区古生界的生烃史和排烃史进行了模拟研究。结果表明，该区上古生界烃源岩处于高成熟阶段，下古生界烃源岩已进入过成熟阶段，这两套烃源岩地地史上都再现过两次生、排烃高峰，上古生界的生、排烃量远大于下古生界，这些结果可用于评价该区的油气远景和认识油气藏的形成过程。     

华北盆地北部下古生界古地温演化与含油潜力分析

本文从区域古地温演化的角度出发,探讨了华北盆地北部下古生界的含油远景。分析的基础主要建立在作者编制的古地温演化图之上。制图的方法引用了电子计算机;利用等值线扫描数字化处理基础图件,编成下古生界古地温演化图。根据古地温演化的特点,并考虑其它与油气有关的地质因素,作者对下古生界五套生储盖组合分别进行评价;同时指出在华北盆地北部寻找下古生界原生油气藏的有利地区。     

鄂尔多斯盆地东南部下古生界碳酸盐岩天然气成藏条件

为研究鄂尔多斯盆地东南部下古生界碳酸盐岩天然气成藏特征,指导下一步天然气勘探开发,采用地质与地球化学相结合的方法,通过岩溶古地貌恢复、烃源岩有机碳对比、储层成岩作用研究,对下古生界天然气成藏地质条件进行了探讨。结果表明:研究区处于古岩溶斜坡地带,其西部为古岩溶高地,东部为古岩溶盆地,古岩溶斜坡呈北西-南东向展布,古沟槽呈树枝状沿东西向展布;气藏的形成受不整合面沟槽地貌的控制,在斜坡与侵蚀沟槽及斜坡与高地的边缘地带含气性能好。上古生界煤系烃源岩是下古生界主要的供烃层位,其生烃强度是下古生界的4~5倍。在裂缝的沟通作用下,天然气由古沟槽侵蚀区和铝土岩缺失部位进入下古生界风化壳岩溶储层,表生岩溶作用和溶蚀作用形成的孔、洞、缝为油气充注提供了储集条件。     

鄂尔多斯盆地东南部上古生界天然气勘探潜力分析

鄂尔多斯盆地东南部已有少数探井在上古生界见到工业气流。研究表明:本区发育下古生界海相、上古生界海陆有两套烃源岩,其分布广,生烃能力强,资源丰富,二叠系下石盒子组及山西组碎屑砂岩发育,为良好储集层,上石盒子组为湖相泥岩与上倾方向致密泥岩提供了良好的直接盖层及侧向封堵条件,勘探前景良好。     

苏里格地区下古生界储层流体包裹体特征及其成藏作用

为确定苏里格地区下古生界天然气充注时间和成藏期次,采用流体包裹体测试技术和分析方法,利用包裹体的均一温度,对该地区下古生界马家沟组储层流体包裹体样品进行了测试分析.苏里格地区下古生界储层中发育三类流体包裹体:盐水包裹体、含液态烃包裹体和液态烃包裹体.流体包裹体均一温度具有明显的双峰特征,两个峰值分别为95～110℃和145～155℃,这表明研究区下古生界天然气充注与成藏期次主要有两期.利用包裹体测试资料、结合埋藏史和热史综合分析表明苏里格地区下古生界天然气成藏时间为190～215 Ma和150～160 Ma,其中150～160 Ma(晚三叠世末-早侏罗世)是本区最重要的一次天然气成藏期.     

华北北部下古生界沉积相发育特征

本文试图从找油的角度对华北北部下古生界沉积相发育特征进行初步探讨。文中根据本区沉积发育特点进行了沉积相的划分,并利用有20条露头及录井剖面组成的能控制全区的五条沉积相对比大剖面,进行了区域沉积相对比。以此对下古生界每组段的沉积相发育特征进行了初步的讨论,从而获得了以下几点认识:(1)本区下古生界纵向上可划分为三个沉积发育阶段和两大海浸旋回;(2)下古生界各组段沉积相的横向递变具有一定的规律性,反映出古地形发育具有一定的继承性;(3)下古生代的海浸来自南北两个方向,但不同时期各有差异;(4)下古生代的古海洋具有内陆海的性质;(5) 局限海和广海是生油有利相带。下古生界生油有利相带的发育第二海浸旋回优于第一旋回,在横向上以北部为最佳。     

Discussion of gas enrichment mechanism and natural gas origin in marine sedimentary basin,China

There are abundant natural gas resources in Chinese marine sedimentary basin. The exploration hot shots of natural gas are the Palaeozoic marine strata here in recent years, and several large scale gas fields have been discovered. Chinese Palaeozoic high-post matured and coal measure hydrocarbon source rocks are mainly prone to gas generation in the present. This research considered that gas source rocks and TSR are the key cause of gas enrichment of marine strata. High-quality argillaceous and coal measure hydrocarbon rocks are distributed widely in the Palaeozoic marine strata, which have been in highly matured phase in the present. The argillaceous source rock generally contains various sulfates that could accelerate crude oil cracking to gas for TSR occurrence, and coal measure source rock mainly generates gas, so Chinese marine basin gives priority to accumulating gas. Marine strata have not founded oil reservoirs in the Sichuan Basin and Ordos Basin, and they consist mainly of dry gas. Marine natural gases are the mixed gases of oil cracking gas and coal-formed gas in a general way, oil cracking gases contain usually some H2S and CO2. Hydrocarbon carbon isotopes are very complicated, and methane and ethane isotopic values bear apparent reversal caused by thermal evolution and mixing among different genetic types of natural gas. Coal-formed gases are the main component of Chinese marine natural gas. The Upper Permian of the Sichuan Basin and the Carboniferous-Permian of the Ordos Basin coal measure hydrocarbon source rock present large hydrocarbon generation potential, which are the prospecting highlight of marine natural gas hereafter. Oil cracking gas exploration will be paid much attention to in the Tarim Basin because of the lack of coal measure hydrocarbon source rock.     

Discussion of gas enrichment mechanism and natural gas origin in marine sedimentary basin, China

There are abundant natural gas resources in Chinese marine sedimentary basin. The exploration hot shots of natural gas are the Palaeozoic marine strata here in recent years, and several large scale gas fields have been discovered. Chinese Palaeozoic high-post matured and coal measure hydrocarbon source rocks are mainly prone to gas generation in the present. This research considered that gas source rocks and TSR are the key cause of gas enrichment of marine strata. High-quality argillaceous and coal measure hydrocarbon rocks are distributed widely in the Palaeozoic marine strata, which have been in highly matured phase in the present. The argillaceous source rock generally contains various sulfates that could accelerate crude oil cracking to gas for TSR occurrence, and coal measure source rock mainly generates gas, so Chinese marine basin gives priority to accumulating gas. Marine strata have not founded oil reservoirs in the Sichuan Basin and Ordos Basin, and they consist mainly of dry gas. Marine natural gases are the mixed gases of oil cracking gas and coal-formed gas in a general way, oil cracking gases contain usually some H2S and CO2. Hydrocarbon carbon isotopes are very complicated, and methane and ethane isotopic values bear apparent reversal caused by thermal evolution and mixing among different genetic types of natural gas. Coal-formed gases are the main component of Chinese marine natural gas. The Upper Permian of the Sichuan Basin and the Carboniferous-Permian of the Ordos Basin coal measure hydrocarbon source rock present large hydrocarbon generation po- tential, which are the prospecting highlight of marine natural gas hereafter. Oil cracking gas exploration will be paid much attention to in the Tarim Basin because of the lack of coal measure hydrocarbon source rock.     

Lower Paleozoic oil relationships within Williston Basin, Canada

The Williston Basin is a significant petroleum province, containing oil production zones that include the Middle Cambrian to Lower Ordovician, Upper Ordovician, Middle Devonian, Upper Devonian and Mississippian and within the Jurassic and Cretaceous. The oils of the Williston Basin exhibit a wide range of geochemical characteristics defined as "oil families", although the geochemical signature of the Cambrian Deadwood Formation and Lower Ordovician Winnipeg reservoired oils does not match any "oil family". Despite their close stratigraphic proximity, it is evident that the oils of the Lower Palaeozoic within the Williston Basin are distinct. This suggests the presence of a new "oil family" within the Williston Basin. Diagnostic geochemical signatures occur in the gasoline range chromatograms, within saturate fraction gas chromatograms and biomarker fingerprints. However, some of the established criteria and cross-plots that are currently used to segregate oils into distinct genetic families within the basin do not always meet with success, particularly when applied to the Lower Palaeozoic oils of the Deadwood and Winnipeg Formation.     

Lower Paleozoic oil relationships within Williston Basin, Canada

The Williston Basin is a significant petroleum province, containing oil production zones that include the Middle Cambrian to Lower ()rdovician, Upper Ordovician, Middle Devonian, Upper Devonian and Mississippian and within the Jurassic and Cretaceous. The oils of the Williston Basin exhibit a wide range of geochemical characteristics defined as “oil families“, although the geochemical signature of the Cambrian Deadwood Formation and Lower Ordovician Winnipeg reservoired oils does not match any “oil family“. Despite their close stratigraphic proximity, it is evident that the oils of the/rower Palaeozoic within the Williston Basin are distinct. This suggests the presence of a new “oil family“ within the Williston Basin. Diagnostic geochemical signatures occur in the gasoline range chromatograms, within saturate fraction gas chromatograms and biomarker fingerprints. However, some of the established criteria and cross-plots that are currently used to segregate oils into distinct genetic families within the basin do not always meet with success, particularly when applied to the Lower Palaeozoic oils of the Deadwood and Winnipeg Formation.     

Observation of hydrocarbon generation and migration of highly-matured carbonates by means of laser-induced fluorescence microscopy

Some important information on hydrocarbon generation, inclusion and migration in highly-matured carbonates of lower Palaeozoic age from the Ordos Basin and Tarim Basin hasbeen analyzed by a newly-combined laser-induced fluorescence microscope (LFM) designed by our laboratory. The following information has been obtained from the lower Ordovician lamellar carbonates with equivalent vitrinite reflectance (Ro) as high as 1.6%-1.7% and residual TOC of 0.14%-0.35% from the Ordos Basin: wide occurrences of oil and source macerals with strong fluorescence, including G. Prisca alginite, lamalginite, telalginite and algae-detrinite; fluorescing asphalt among mineral crystals; some groundmass and spheroid-like reservoir bitumen with high maturation levels in the pores of dolomites. Various kinds of fluorescing organic inclusions and asphalt have been found in the carbonates, calcareous shales and silt-shales with high maturation levels from the Cambrian-Ordovician strata in the Tarim Basin. All this helps us find and evaluate significant and excellent source rocks for large-and middle-scale gas fields. The net and micro-net systems for hydrocarbon generation, expulsion and migration in carbonates have been revealed by the highly-powered laser-induced fluorescence microscopy.     

Stratigraphy and paleontology of the marine Jurrassic strata in Vietnam

Marine Jurassic strata in Vietnam have yielded characteristic ammonites and occur in: (1) west Quang Binh Province located in the eastern margin of the Nam Theun Basin (the main part of which is located in Middle Laos); (2) the Nong Son Basin situated in the north of the Kon Tum Geoblock; (3) the Da Lat Basin, the largest Jurassic basin in Vietnam, extending from the southern margin of the Kon Tum Geoblock to southeast of Ho Chi Minh City. In the first two, Lower Jurassic marine beds occupy the lower part of the section and grade up into Middle Jurassic red beds. In central Da Lat Basin the section consists completely of marine strata containing many ammonite levels dated from Early Sinemurian to Bajocian, whereas the marginal basin section is like the first two areas. Based particularly on biostratigraphical evidence, a marine transgression is considered to have entered the Indochina Block as early as the Late Hettangian. During the early transgression the fauna was distinctly endemic, showing the separate character of the basins, but since the Late Sinemurian, communication between the Da Lat and other basins was established; the marine regime in Da Lat Basin ended around the Late Bathonian.     

Stratigraphy and paleontology of the marine Jurrassic strata in Vietnam

Marine Jurassic strata in Vietnam have yielded characteristic ammonites and occur in: (1) west Quang Binh Province located in the eastern margin of the Nam Theun Basin (the main part of which is located in Middle Laos); (2) the Nong Son Basin situated in the north of the Kon Tum Geoblock; (3) the Da Lat Basin, the largest Jurassic basin in Vietnam, extending from the southern margin of the Kon Tum Geoblock to southeast of Ho Chi Minh City. In the first two, Lower Jurassic marine beds occupy the lower part of the section and grade up into Middle Jurassic red beds. In central Da Lat Basin the section consists completely of marine strata containing many ammonite levels dated from Early Sinemurian to Bajocian, whereas the marginal basin section is like the first two areas. Based particularly on biostratigraphical evidence, a marine transgression is considered to have entered the Indochina Block as early as the Late Hettangian. During the early transgression the fauna was distinctly endemic, showing the separate character of the basins, but since the Late Sinemurian, communication between the Da Lat and other basins was established; the marine regime in Da Lat Basin ended around the Late Bathonian.     

四川盆地西部海相碎屑岩-陆相碎屑岩的转换过程

四川盆地是一个叠合盆地,经历了海相碳酸盐岩到海相碎屑岩、海相碎屑岩到陆相碎屑岩的转换和变迁.这两个转换过程最终结束均发生在四川盆地西部.海相碎屑岩到陆相碎屑岩的转换发生在晚三叠世末,相对应的地层单位为上三叠统须家河组.通过对须家河组厚度和沉积相变化,以及龙门山前砾岩的分布特征研究,认为这一转换主要发生于须家河组沉积末期(T_3x~4-T_3x~6),时间上随地区不同而不同,空间上具有由北往南的先后顺序.这揭示龙门山造山带的造山隆升过程具有由北往南的特点.这一转换过程导致川西前陆盆地内南、北段油气地质条件存在差异.寻找河口沙坝、三角洲平原河道砂等形成的优质储层应是须家河组油气勘探的关键.     

Evaluation criteria for gas source rocks of marine carbonate in China

Hydrocarbon generating and expulsion simulation experiments are carried out using samples artifically matched between the acid-dissolved residue of relatively low-maturity limestone and the original sample. This work makes up for the insufficiency of source rock samples with high abundance of organic matters and low maturity in China. The organic carbon content of the 10 prepared samples varies between 0.15% and 0.74%. Pyrolysis data and simulation experiment results of hydrocarbon generating and expulsion, which were obtained by a high-temperature and high-pressure open system, indicate that the lower limit of organic carbon content for marine carbonate rock to generate and expel hydrocarbons is 0.23%—0.31%. In combination with the numerical analysis of organic carbon in marine carbonate rocks from Tarim Basin, Sichuan Basin, Ordos Basin and North China, as well as the contribution of these gas source rocks to the discovered gas pools, we think that the organic carbon criterion for carbonate gas source rocks should be 0.3%.     

Discovery of Cathaysiodendron Lee from the Early Carboniferous of Jingyuan, Gansu, western China

As one of the representative members of the Late Palaeozoic Cathaysian flora, Cathaysiodendron has been previously recorded from the Early Permian Taiyuan and Shanxi Formations in north China. The species of Cathaysiodendron presented here are from the lower member of Chouniugou Formation of Ciyao, Jingyuan, Gansu. The overlying marine beds yield fusulinids that are of Visean age in western Europe and conodonts of the Datang Stage in south China, so that the age of the bed containing Cathaysiodendron as Visean, Early Carboniferous, is well constrained. Such a record of Cathaysiodendron is significant in terms of Carboniferous phytogeography and the evolution of the Cathaysian Lepidophytes. A new species, Cathaysiodendron jingyuanense Wang & Wu sp. nov. is described and a second one mentioned.