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1.
Natural bitumen is the evolutionary residue of hydrocarbon of sedimentary organic matter. Several kinds of bitumen with different occurrences, including bitumen in source rock, migration bitumen filled in fault, oil-bed bitumen and paleo-reservoir bitumen, are distributed widely in the Dabashan foreland. These kinds of bitumen represent the process of oil/gas formation, migration and accumulation in the region. Bitumen in source rock filled in fractures and stylolite and experienced deformation simultaneously together with source rock themselves. It indicated that oil/gas generation and expelling from source rock occurred under normal buried thermal conditions during prototype basin evolution stages prior to orogeny. Occurrences of bitumen in source rock indicated that paleo-reservoir formation conditions existed in the Dabashan foreland. Migration bitumen being widespread in the fault revealed that the fault was the main channel for oil/gas migration, which occurred synchronously with Jurassic foreland deformation. Oil-bed bitumen was the kind of pyrolysis bitumen that distributed in solution pores of reservoir rock in the Dabashan foreland depression, the northeastern Sichuan Basin. Geochemistry of oil-bed bitumen indicated that natural gas that accumulated in the Dabashan foreland depression formed from liquid hydrocarbon by pyrolysis process. However, paleo-reservior bitumen in the Dabashan forleland was the kind of degradation bitumen that formed from liquid hydrocarbon within the paleo-reservior by oxidation, alteration and other secondary changes due to paleo-reservior damage during tectonics in the Dabashan foreland. In combination with the tectonic evolution of the Dabashan foreland, it is proposed that the oil/gas generated, migrated and accumulated to form the paleo-reservoir during the Triassic Indosinian tectonic movement. Jurassic collision orogeny, the Yanshan tectonic movement, led to intracontinental orogeny of the Dabashan area accompanied by geofluid expelling and paleo-reservoir damage in the Dabashan foreland. The present work proposed that there is liquid hydrocarbon exploration potential in the Dabashan foreland, while there are prospects for the existence of natural gas in the Dabashan foreland depression. 相似文献
2.
Where the Neuquén Basin of Argentina abuts the Andes, hundreds of veins of solid hydrocarbon (bitumen) are visible at the surface. Many of these veins became mines, especially in the last century. By consensus, the bitumen has resulted from maturation of organic-rich shales, especially the Vaca Muerta Fm of Late Jurassic age, but also the Agrio Fm of Early Cretaceous age. To account for their maturation, recent authors have invoked regional subsidence, whereas early geologists invoked magmatic activity. During 12 field seasons (since 1998), we have tracked down the bitumen localities, mapped the veins and host rocks, sampled them, studied their compositions, and dated some of them. In the provinces of northern Neuquén and southernmost Mendoza, the bitumen veins are mostly sub-vertical dykes. They tend to be straight and continuous, crosscutting regional structures and strata of all ages, from Jurassic to Palaeocene. Most of the localities lie within 70 km of Tromen volcano, although four are along the Rio Colorado fault zone and another two are at the base of Auca Mahuida volcano. On both volcanic edifices, lavas are of late Pliocene to Pleistocene age. Although regionally many of the bitumen dykes tend to track the current direction of maximum horizontal tectonic stress (ENE), others do not. However, most of the dykes radiate outward from the volcanoes, especially Tromen. Thicknesses of dykes tend to be greatest close to Tromen and where the host rocks are the most resistant to fracturing. Many of the dykes occur in the exhumed hanging walls of deep thrusts, especially at the foot of Tromen. Here the bitumen is in places of high grade (impsonite), whereas further out it tends to be of medium grade (grahamite). A few bitumen dykes contain fragments of Vaca Muerta shale, so that we infer forceful expulsion of source rock. At Curacó Mine, some shale fragments contain bedding-parallel veins of fibrous calcite (beef) and these contain some bitumen, which is geochemically of low grade. In contrast, a large crosscutting bitumen dyke is of higher grade and formed later. At other localities, near basement faults, bitumen dykes have cap-rocks of hydrothermal calcrete. Other dykes or their wall rocks contain hydrothermal minerals. Finally, some dykes splay upward towards the current land surface. We conclude that (1) the bitumen dykes formed during volcanic activity in Pliocene–Pleistocene times, and that (2) heat advection by hydrothermal fluids helped to generate oil, which migrated upwards or downwards from the source rock and filled intrusive veins, before solidifying to bitumen, by loss of volatile elements. This unconventional hydrocarbon system may have significant implications for regional exploration in the foothills of the Andes. 相似文献
3.
根据储层中沥青的产状、元素组成、固体碳同位素、饱和烃色谱、生物标志化合物以及芳烃色谱-质谱等,对磨溪地区龙王庙组储层固体沥青的地球化学特征、成因及来源进行了剖析。研究结果表明,其总体上具有低H/C原子比值、高反射率的特征,是古油藏原油经裂解形成的残留物。储层沥青的正构烷烃分布较为完整,碳数在C16-C31范围,没有受到明显的生物降解作用。其可能的烃源岩发育于还原环境,有机质来源于低等水生生物,为海相泥页岩。固体沥青碳同位素值介于-33.1‰~-35.4‰之间,与下寒武统烃源岩干酪根碳同位素具有很好的可比性,同时,其生物标志化合物组成也与下寒武统烃源岩相似,表明其烃源来自于下寒武统筇竹寺组。 相似文献
4.
南盘江盆地古油藏沥青地球化学特征及成因 总被引：5，自引：3，他引：5
南盘江地区生物礁古油藏的储层沥青主要分布在上二叠统和中上泥盆统。古油藏的储集层均为生物礁滩灰岩,沥青的主要储集空间以洞、缝为主,其次为基质孔隙和生物体腔内。南盘江古油藏沥青的成熟度很高, H／C原子比小于0．4,主要由残碳构成,这是沥青的非极性和极性抽提无抽提物的直接原因。在古油藏沥青地球化学特征研究的基础上,综合分析认为南盘江古油藏沥青主要源自泥盆系烃源岩,其次可能与下二叠统烃源岩有关。南盘江古油藏沥青与生物降解沥青和沉淀沥青质有很大的区别,其成因是油藏深埋时在高温、高压的作用下原油裂解成气后的焦沥青。 相似文献
5.
Organic-rich (18.2%) Monterey Formation diatomite from California was studied. The organic matter consist of 94% bitumen and 6% kerogen. Biological markers from the bitumen and from pyrolysates of the coexisting asphaltenes and kerogen were analyzed in order to elucidate the relationship between the various fractions of the organic matter. While 17 alpha(H), 18 alpha(H), 21 alpha(H)-28,30-bisnorhopane was present in the bitumen and in the pryolysate of the asphaltenes, it was not detected in the pyrolysates of the kerogen. A C40-isoprenoid with "head to head" linkage, however, was present in pyrolysates of both kerogen and asphaltenes, but not in the bitumen from the diatomite. The maturation level of the bitumen, based on the extent of isomerization of steranes and hopanes, was that of a mature oil, whereas the pyrolysate from the kerogen showed a considerably lower maturation level. These relationships indicate that the bitumen may not be indigenous to the diatomite and that it is a mature oil that migrated into the rock. We consider the possibility, however, that some of the 28,30-bisnorhopane-rich Monterey Formation oils have not been generated through thermal degradation of kerogen, but have been expelled from the source rock at an early stage of diagenesis. 相似文献
6.
In laboratory simulation of oil generation, products from closed systems pyrolysis of immature source rocks in the presence of water gives the closest match to petroleum compositions observed in nature. Fresh biomass can also be converted to fluids by pyrolysis, but in the absence of the sedimentary diagenetic transformations, the initially much higher oxygen content gives high yields of oxygen containing products. In this work, the reactions that occur during hydrous pyrolysis of a Kimmeridge source rock, a brown coal and two polymeric waste materials from alginate production are compared in terms of quantities of the main products and kinetic models of the reaction systems. The biomass pyrolysis and the simulated maturation are described in similar reaction networks. Conversion of biomass to fluids occurred with reaction networks and activation energy distributions comparable to the brown coal, while for the Kimmeridge source rock reactions a simpler reaction network could be used. The biomass samples gave a high degree of conversion to fluid products, and higher yields of bitumen than the coal. 相似文献
7.
目前虽认为元坝气田长兴组天然气主要为原油裂解气,但尚未进行该气田的古油藏的定量恢复并计算原油裂解气的资源量,并系统分析古油藏原油的来源.长兴组储层普遍可见固体沥青,是原油裂解的直接产物,且原油裂解在本区构造抬升变形前就已经完成,因此储层沥青可用来识别古油层的分布.根据储层沥青的纵向和平面分布,确定了7个可靠的古油藏和4个可能的古油藏,并运用容积法恢复出本区聚集的古原油为6.14×108 t,计算出相应的原油裂解气为3 807.08×108 m3,远大于现今气田的天然气探明储量,表明原油裂解气可以提供充足的气源,进一步证明了天然气主要为原油裂解气.通过长兴组储层沥青与不同层系烃源岩干酪根的碳同位素δ13C值对比,并结合烃源层分布和TOC等资料,确定古油藏原油主要来源于有机质类型以Ⅱ型为主的上二叠统吴家坪组烃源岩,其次为长兴组/大隆组烃源岩.后者主要分布在广元-南江-通江地区,该区的天然气勘探不能忽视该套烃源岩的生烃潜力与成藏贡献. 相似文献
8.
Hydrous and anhydrous closed-system pyrolysis experiments were conducted on a sample of Mahogany oil shale (Eocene Green River Formation) containing Type-I kerogen to determine whether the role of water had the same effect on petroleum generation as reported for Type-II kerogen in the Woodford Shale. The experiments were conducted at 330 and 350 °C for 72 h to determine the effects of water during kerogen decomposition to polar-rich bitumen and subsequent bitumen decomposition to hydrocarbon-rich oil. The results showed that the role of water was more significant in bitumen decomposition to oil at 350 °C than in kerogen decomposition to bitumen at 330 °C. At 350 °C, the hydrous experiment generated 29% more total hydrocarbon product and 33% more C15+ hydrocarbons than the anhydrous experiment. This is attributed to water dissolved in the bitumen serving as a source of hydrogen to enhance thermal cracking and facilitate the expulsion of immiscible oil. In the absence of water, cross linking is enhanced in the confines of the rock, resulting in formation of pyrobitumen and molecular hydrogen. These differences are also reflected in the color and texture of the recovered rock. Despite confining liquid-water pressure being 7-9 times greater in the hydrous experiments than the confining vapor pressure in the anhydrous experiments, recovered rock from the former had a lighter color and expansion fractures parallel to the bedding fabric of the rock. The absence of these open tensile fractures in the recovered rock from the anhydrous experiments indicates that water promotes net-volume increase reactions like thermal cracking over net-volume decrease reactions like cross linking, which results in pyrobitumen. The results indicate the role of water in hydrocarbon and petroleum formation from Type-I kerogen is significant, as reported for Type-II kerogen. 相似文献
9.
Low-grade sandstone-hosted thorium mineralization is recorded in the Carboniferous Northwest Irish Basin in the Republic of Ireland and Northern Ireland. The thorium is concentrated within bitumen nodules which are replacive within the sandstones. A source of thorium was available in a Caledonian granite in the basin watershed, and the bitumen was a product of hydrocarbons generated within the basin. The thorium occurs as thorite inclusions in the bitumen, and the development of the nodules was enhanced by the polymerization of fluid hydrocarbons by irradiation from the thorium. Thorium mobility may have been enhanced by the formation of organometallic complexes. Mineralization probably therefore occurred during hydrocarbon migration, dated as Late Carboniferous to Permian. 相似文献
10.
11.
It is concluded that there are three hydrocarbon generation and accumulation processes in northeastern Sichuan on the basis of the characteristics of solid bitumen, gas-light oils-heavy oils, homogenization temperature of fluid inclusions and diagenesis for beach- and reef-facies dolomite gas- bearing reservoirs in the Puguang Gas Field, northeastern Sichuan Basin, southern China. The first hydrocarbon generation and accumulation episode occurred in the Indosinian movement （late Middle Triassic）. The sapropelic source rocks of the O3w （Upper Ordovician Wufeng Formation）-S1l （Lower Silurian Longmaxi Formation） were buried at depths of 2500 m to 3000 m with the paleogeothermal temperature ranging from 70℃ to 95℃, which yielded heavy oil with lower maturity. At the same time, intercrystalline pores, framework pores and corrosion caused by organic acid were formed within the organic reef facies of P2ch （Upper Permian Changxing Formation）. And the first stage of hydrocarbon reservoir occurred, the level of surface porosity of residual solid bitumen {solid bitumen/ （solid bitumen ＋ residual porosity）} was higher than 60%. The second episode occurred during the Middle Yanshanian movement （late Middle Jurassic）. During that period, the mixed organic source rocks were deposited in an intra-platform sag during the Permian and sapropelic source rocks of O3w-S1l experienced a peak stage of crude oil or light oil and gas generation because they were buried at depths of 3500 m to 6800 m with paleogeothermal temperatures of 96-168℃. At that time, the level of surface porosity of residual solid bitumen of the T1f shoal facies reservoirs was between 25% and 35%, and the homogenization temperatures of the first and second stages of fluid inclusions varied from 100℃ to 150℃. The third episode occurred during the Late Yanshanian （Late Cretaceous） to the Himalayan movement. The hydrocarbon reservoirs formed during the T1f and P2ch had the deepest burial of 7700 m to 8700 m and paleogeotemperatu 相似文献
12.
《Applied Geochemistry》1993,8(3):245-254
The Porphyrin Maturity Parameter (PMP), which is derived from the vanadyl porphyrin distribution, is an excellent parameter for: (1) identifying the zone of hydrocarbon generation from marine source rock extracts; and (2) determining from oils the thermal maturity of their source rocks at expulsion.The PMP is measured using a methodology which is inexpensive, reliable and faster than earlier methods, allowing it to be used as a routine exploration tool. The PMP may be a more reliable maturity indicator for marine organic matter than some conventional methods such as vitrinite reflectance. Unlike most conventional maturity parameters guided by processes other than kerogen conversion, the reactions causing PMP evolution directly monitor the generation of bitumen and the concurrent thermal degradation of kerogen.Measurements on hydrous pyrolyzates from the Monterey Formation (offshore California), source rock bitumens from the Devonian-Mississippian Bakken Shale (Williston Basin), and Miocene Monterey equivalent source strata (San Joaquin Basin, California) illustrate the method. In all cases reviewed so far, PMP begins increasing at the onset of hydrocarbon generation and increases systematically and predictably as kerogen decomposition proceeds.In oils generated from high-S marine kerogens, PMP reflects the maturity of the source rock at the time of oil expulsion, provided that the oil does not undergo subsequent reservoior maturation or mixing with in-situ bitumen. 相似文献
13.
康山“古油藏”讨论之三——康山“沥青脉”的成因 总被引：1，自引：0，他引：1
通过对康山固体可燃脉体产状、脉石矿物性质、构造发展史的综合分析,认为其成因很可能是下寒武统荷塘组中的软沥青和有机质,在加里东运动期间,由于区域应力体系的变化而爆炸运移形成的。康山脉石矿物是沥青和有机质,不是煤和无机物。沥青的源岩为下寒武统荷塘组富有机质的黑色泥岩、硅质泥岩、硅质岩。康山脉中的固体沥青和有机质,当初挤入时应呈塑性流动状态,康山沥青系由石油经热演化而成。 相似文献
14.
Dennis Netoff 《Sedimentology》2002,49(1):65-80
Large bodies of fluidized sandstone occur in the Jurassic Entrada, Carmel, Page and Navajo Formations at several locations in south‐central Utah. They are most abundant in the Entrada Sandstone, where they commonly occur in clusters, have a cylindrical form and have a sharp contact with their cross‐bedded host rock. These clastic pipes are as wide as 75 m and have exposed heights of as much as 100 m. Some of the Entrada pipes extend well into the underlying Carmel redbeds. Other clastic pipes in the Entrada Sandstone are less deformed and display various degrees of brittle‐to‐hydroplastic deformation and liquefaction. Clastic pipes in the Page and Navajo Sandstones are less common, but are similar in size and form to those in the Entrada and Carmel, and probably have a similar origin. Some massive sandstone bodies are irregular in form and have tongue‐like projections into the host rock, implying forcible injection of fluidized sand. Several pipe–host contacts in the Entrada Sandstone display small‐scale ring faults. Where relative displacement can be clearly demonstrated, pipe sandstones are invariably down‐faulted, locally as much as 5 m. At two sites, Carmel host rock is upwarped around the Entrada pipes. Stratified and cross‐bedded breccia blocks occur in many Entrada pipes, and preliminary petrographic analysis indicates that at least some of these breccia blocks are derived from the host rock. Homogeneous pipe sandstones are also petrographically similar to their Entrada host rock, suggesting that some pipes originate through fluidization of the fine‐grained Entrada. Fluidization of the Entrada must have occurred in a water‐saturated environment during early diagenesis but before complete lithification, most probably under considerable porewater pressure. Although there are no known modern analogues to these huge masses of structureless sandstone, they may have a small‐scale modern counterpart in earthquake‐induced sandblows. These features were most probably caused by large‐magnitude seismic events during the Middle Jurassic, although other possibilities cannot be ruled out at this point. 相似文献
15.
J. Parnell 《Geological Journal》1995,30(1):25-38
Carboniferous rocks in the north Solway onshore outcrop show evidence of hydrocarbon migration. Oil residues occur as intergranular bitumen in sandstones, thoriferous bitumen nodules in sandstones and uraniferous bitumens in fractures associated with the North Solway Fault at the northern margin of the Solway Basin. Oil was emplaced in sandstones after the dissolution of dolomite, calcite and clay cements. The radioelement-rich bitumens represent deposition following interactions between migrating hydrocarbons and metalliferous fluids. The close proximity of the Caledonian Criffel granodiorite, unroofed by Carboniferous times, suggests that the pluton was the source of uranium and thorium. Hydrocarbon source rocks are identified further east in the more complete succession exposed in the Esk Valley region, along with further oil residues. Time-temperature modelling suggests that oil was generated from Lower Carboniferous source rocks during the Permo-Triassic. Chemical age dating of uraninite in bitumen yields early Jurassic ages, which may reflect the time of hydrocarbon migration along the North Solway Fault system, and may be related to a mid-Jurassic episode of regional uplift. Analyses of thorite in bitumen nodules give a wider spread of data, probably due to the migration of daughter lead. 相似文献
16.
川东北飞仙关组储层固体沥青地球化学特征及其气源指示意义 总被引：6，自引：1，他引：5
运用有机岩石学、有机地球化学、催化加氢热解、GC—IRMS等方法和技术,深入研究了川东北飞仙关组储层固体沥青及可能烃源岩的地球化学特征。研究认为,飞仙关组储层固体沥青反射率高,双反射明显,为非均质结构储层焦沥青;在碳酸盐岩储层的各种孔隙中,呈脉状、球粒状、角片状或块状等他形充填,具有中间相结构和镶嵌状结构特征,反映其高温热变质成因;元素组成有S/C高、H/C低的特点,其固体碳同位素组成与长兴组烃源岩干酪根相似。储层固体沥青的可能烃源岩发育于还原—弱氧化咸水沉积环境,有机质来源于水生藻类;氯仿沥青“A”饱和烃甾萜类生物标志物对比表明,上二叠长兴组烃源岩是主要来源,飞仙关组、下志留统烃源岩亦有贡献;催化加氢产物饱和烃及其正构烷烃单体碳同位素组成显示,坡2井飞仙关组储层固体沥青与罐5井飞仙关组烃源岩具有明显的亲缘关系,这也可作为飞仙关组海槽相烃源岩对飞仙关组气藏有贡献的佐证。 相似文献
17.
LIU Shugen HUANG Wenming JANSA Luba F. WANG Guozhi SONG Guangyong ZHANG Changjun SUN Wei MA Wenxin 《《地质学报》英文版》2014,88(5):1466-1487
Hydrothermal Dolomite （HTD） is present in the Upper Sinian （Upper Proterozoic） Dengying Formation, east Sichuan Basin, China. The strata are comprised by primary dolomite. The HTD has various textures, including zebra dolomite, subhorizontal sheet-like cavities filled by saddle dolomite and breccias cemented by saddle dolomites as well occur as a fill of veins and fractures. Also co-occur MVT type lead-zinc ores in the study area. The δ13C and δ18O isotopes of HTD in the Upper Sinian Dengying Formation are lighter than those of the host rocks, while STSr/86Sr is higher. The apparent difference in carbon, oxygen and strontium isotopes, especially the large difference in S7Sr/S6Sr isotopes ratio indicate crystallization from hot basinal and/or hydrothermal fluids. Saddle dolomite was precipitated at temperatures of 270-320℃. The diagenetic parasequences of mineral assemblage deposited in the Dengying Formation are： （1） dolomite host rock →sphalerite-galena-barite-fluorite; （2） dolomite host rock →saddle dolomite →quartz; （3） dolomite host rock →saddle dolomite→bitumen; （4） dolomite host rock →saddle dolomite →barite. The mean chemical composition of the host dolomite matrix and HTD didn＇t change much during hydrothermal process. The fluids forming the HTDs in the Dengying Formation were mixtures of freshwater from the unconformity at the top of Sinian, fluids from diagenetic compaction and hydrocarbon generation ＆ expulsion from the Lower Cambrian Niutitang Formation mudstones or the Doushantuo Formation silty mudstones, and hydrothermal fluids from the basement. The hydrocarbon reservoirs associated with the HTD were mostly controlled by the basement faults and fractures and karsting processes at the unconformity separating Sinian and Cambrian strata. The hydrocarbon storage spaces of HTD included dissolved cavities and intercrystalline pores. Dissolution cavities are extensive at the top of Dengying Formation, up to about 46m below the unconformity between Sinian an 相似文献
18.
漠河盆地早白垩世依列克得组火山岩系烃源岩有机地球化学特征 总被引：1，自引：0，他引：1
应用岩石热解、氯仿沥青抽提、饱和烃气相色谱和色谱-质谱等分析方法,对首次在漠河盆地依列克得组发现的烃源岩进行研究。 结果表明：烃源岩由煤、油页岩和页岩构成,有机碳(TOC)质量分数＞10%,干酪根类型主要为Ⅱ2,镜质体反射率（Ro）为0.56%~0.59%,属于低成熟阶段,烃源岩达到很好级别。烃源岩有机母质均以陆生高等植物输入为主,也有水生生物的输入,反映原始母质具有水生生物和陆源高等植物混源的特征。依列克得组沉积时期,湖盆水体含盐度及还原性具有较大的变化,处于淡水湖-咸水湖的交替状态,沉积水体分层比较明显,有利于有机质的保存和转化。 相似文献
19.
据实测实验数据分析了川中及川东南地区典型构造上勘探井震旦系—下古生界泥岩及沥青样品的生物标志化合物的特征,证实源岩的沉积环境主要为具有一定盐度的还原环境,生物多来自于低等水生生物的菌藻类。川中震旦系—下古生界和川东南震旦系储层沥青主要来自寒武系泥岩;川东南下古生界储层沥青则为寒武系和志留系的混合来源。利用Karweil方法分析了川中地区高科1井寒武系烃源岩的成烃史;采用磷灰石裂变径迹技术与Easy%Ro模型联合模拟恢复了川东南地区丁山1井的生烃史;对比分析表明,川东南寒武系烃源岩成熟时间、主生油及主生气期均早于川中寒武系烃源岩。 相似文献
20.
寒武系烃源古油藏油裂解气特征及成藏条件 总被引：4，自引：0，他引：4
在寒武系为母源的气藏中,普遍存在的固体沥青、25-降藿烷、氮气等三种物质,实际是古油藏残余油裂解的产物。25-降藿烷一般与氧化—降解油有关,氮气来自油藏水洗时溶入的大气,二者共同反映古油藏经历的抬升破坏作用。寒武系烃源一般经历过两次成藏:加里东—海西期形成“油藏”,燕山—喜马拉雅期裂解为“气藏”。寒武系油裂解气成藏的地质条件是:古构造聚油、后期改造适度、叠合盆地增熟、断层作为油气运移通道等。围绕加里东—海西期古油藏寻找原生、次生油裂解气是今后寻找寒武系来源油气的重要途径。 相似文献