共查询到20条相似文献，搜索用时 93 毫秒
1.
There are two key factors which determine the generation of condensate in the Banqiao depression to a certain extent: 1) the
presence of abundant source material which produce condensate, and 2) favorable palaeotemperature conditions. The second member
of oil-generating strata in the Shahejie Formation is the only condensate-supplying member. Sporo-pollen data from the oil-generation
strata show that there are abundant shrubEphedripites of coniferales.
However, the compounds characteristic of the sporo-pollens are sesquiterpenoids. Such characteristic compounds are also enriched
in condensate. Meanwhile, the palaeo-temperature gradient in this member is almost the same as that of today, varying from
110 to 140°C and thus favouring the transformation of terrestrial kerogen into hydrocarbons. Furthermore, as judged from the
nature of faults, it is impossible that the condensate migrated vertically from the third member of the Shahejie Formation.
Therefore, the condensate in the depression was generated neither in the immature and low-mature stages nor in the overmature
stage. It is the product of the mature stage. 相似文献
2.
Liu Yiqun Feng Qiao Li Wenhou Department of Geology Northwest University Xi''an Shaanxi Fei Zhenbi 《《地质学报》英文版》1997,71(3):305-316
The maximum palaeotemperature of oil-bearing sandstones in the UpperTriassic in the eastern Ordos basin has been determined by using many methods including thevitrinite reflectance, fluid inclusion, apatite fission track, illite crystallinity, chlorite polytypeand diagenetic change of authigenic minerals. The thermal gradient in the Late Mesozoic wasabout 2.9-3.0℃/100m. The Upper Triassic was in a mature stage of organic matter andhydrocarbon began to be generated and migrated during this period. The palaeotemperatures ofoil-bearing sandstones were in the range of 88-110℃; those for the generation and migrationof oil ranged from 112 to 122℃. The thickness of the denuded strata overlying the UpperTriassic was 2465-2750m. The present burial depth of oil-bearing sandstones is generally from400 to 1200m. At a depth of ca. 1900m, the temperature may reach 140℃. Below this depth,organic matter was supermature and mainly generated gas. 相似文献
3.
This work aims to reconstruct the burial history of various kinds of sandstones penetrated by the well YS201 in the Yaoyingtai region of the Changling Fault Depression, southern Songliao Basin, China. Analyses of fluid inclusions in the reservoir rocks, combined with a review of the regional tectonic evolution, revealed the hydrocarbon accumulation stage and accumulation age of the Early Cretaceous Denglouku group and the first member of the Quantou group reservoir, which are the future exploration focus for deep gas reservoirs in this region. Acoustic time data and sedimentary rates calculated for sediments in the YS201 well yielded thicknesses for the Yingcheng, Nenjiang, and Mingshui groups of 506, 539.18, and 144.85 m, respectively, thereby revealing the burial history of the sediments in the well. Fluid inclusions of the Denglouku group reservoir and the first member of the Quantou group reservoir contain oil inclusions and hydro-carbonaceous salt water inclusions. The main peaks of the homogenization temperature and salinity of these saltwater inclusions in the first member of the Quantou group reservoir are generally 110–120℃ and 6 wt % –8 wt %, respectively, and for the Denglouku group are 130–140℃ and 4 wt%–6 wt%. The data for both reservoirs show only one main peak, indicating that they both have experienced single-stage accumulation. Combining the homogenization temperature of the reservoir fluid inclusions with the burial and thermal history of the sediments in the YS201 well, we infer that the hydrocarbon gas in these two intervals accumulated at 79 Ma(middle Late Cretaceous). 相似文献
4.
5.
Paleogeotemperatures of the Tarim Basin have been determined on the basis of the degree of thermal alteration of organic matter
and its thermal history. Evidence shows that the paleogeothermal gradient for this area is generally low: 3°C/100 m for the
Paleozoic group and 2.5°C/100 m for the Mesozoic group. The establishment of a geological paleogeothermal model makes it possible
to gain a deeper understanding of oil-generating processes. The peak of oil-generation is generally set at a depth of 5000–6000
m. Higher pressure within the strata is favourable for the preservation of oil at great depths. Organic matter enclosed in
carbonate minerals is believed to be another important source of oil. It is suggested that there may be large reserves of
natural gases in the area studied with a rough estimation of about 0.6 × 104 billion m3. 相似文献
6.
泰宁白垩纪红层盆地由朱口、梅口、龙安3个盆地组成,盆地内出露的岩石地层为沙县组和崇安组。近期工作,首次在龙安盆地沙县组采获植物化石和孢粉化石,梅口盆地崇安组采获孢粉化石。根据植物化石及孢粉组合特征,沙县组地质时代为晚白垩世早、中期,相当于赛诺曼期-土仑期(Cenomanian-Turonian);崇安组为晚白垩世晚期,相当于康尼亚克期-马斯特里赫特期(Coniacian-Maastrichtian)。依据泰宁梅口盆地崇安组孢粉组合特征,建立晚白垩世晚期Pinuspollenites-Ulmipollenites minor组合,以代表福建白垩纪第Ⅵ孢粉组合。 相似文献
7.
8.
Chongzhong Sun 《中国地球化学学报》1984,3(1):72-83
With oil-generating formations in the Dongying basin as the objective of study, this paper deals with the relations among petroporphyrins, lithology, oxidation-reduction conditions, maturation and conversion of organic matter, and burial depth. It is considered that the content of petroporphyrins in the oil-generating formations depends on the quantity and nature of organic matter, sediment ary environment and burial depth. There is a porphyrin-rich interval at 2,200–2,700 m with the corresponding geothermal temperature ranging from 93° to 119°C. It is also an oil-accumulating zone. Nickel in the crude or in the nucleus of petroporphyrin is accumulated during the process of oil generation. Nickel-porphyrin abundance in the oil-generating formations has a negative correlation with the content of nickel. Evaluation of the oil-generating formations has been made on the bosis of petroporphyrin data. 相似文献
9.
10.
由伊利石结晶度研究桂西右江地区区域极低级变质作用 总被引：10，自引：0，他引：10
运用伊利石结晶度Kübler指数将桂西右江地区下三叠统罗楼群和中三叠统百逢组下段划归为浅层变质带(K.I△2θ°为0.22～0.25);将中三叠统百逢组上段和河口组划归为近变质带,中三叠统百逢组上段为高级近变质带(K.I△2θ°为0.26～0.33);中三叠统上部河口组为低级近变质带(K.I△2θ°为0.38～0.40),不排除局部为成岩带的可能.地层柱自下向上,伊利石结晶度Kübler指数由小变大,变质程度由高变低,而且,变质作用级别与岩层在地层柱中位置协调以及变质带边界与地层界线趋于一致,证明为区域埋藏极低级变质作用.凌云明山金矿区剖面矿体和百逢组各层段伊利石结晶度Kübler指数为0.42～0.50,属成岩带,且没有明显时空变化规律. 相似文献
11.
新疆和田杜瓦地区晚二叠世孢粉组合 总被引：11，自引：0，他引：11
本文论及所研究的新疆塔里木盆地和田地区原来分别属于叶尔羌群(J_(1-2))和二叠—三叠系(杜瓦组上部)两个部分采集的孢粉化石.沉积物中含有多种对地层研究非常重要的生物化石,如介形虫、叶肢介、鱼及孢粉等.根据孢粉组合的研究,这些地层可视为上二叠统,其孢粉组合以裸子植物花粉占主导地位为特征,可与新疆吉木萨尔县大龙口晚二叠世晚期地层梧桐沟组对比,并相当于西欧的镁灰岩统和苏联的鞑靼阶. 相似文献
12.
松辽盆地北部铀矿地质研究相对薄弱。本文利用岩心、测井资料,综合运用沉积学、盆地分析、砂岩型铀矿成矿理论,对松辽盆地东北隆起区内的沉积建造特征进行了系统梳理:(1)理清了松辽盆地东北隆起区盆缘的地层结构及含铀含氧水渗入窗口的时空分布特征,绥棱以北嫩江组以下地层整体为超覆结构,仅海伦隆起泉头组在盆缘具有削蚀结构从而具备渗入窗口;而绥棱以南的晚白垩世地层整体在盆缘都呈削蚀结构,均具备窗口。(2)研究区可识别出冲积扇、扇三角洲、曲流河、辫状河、三角洲、滩坝及半深湖—深湖相这7种沉积相类型;在海伦隆起、绥棱背斜、庆安隆起等不同构造单元具有不同的沉积充填样式。(3)探讨了松辽盆地东北隆起区砂岩型铀矿的主攻层位、找矿类型及找矿方向:庆安地区泉头组冲积扇扇中辫状河河道砂体是最有利的勘探对象,其次是铁力地区姚家组的扇三角洲砂体和海伦地区泉头组的辫状河河道砂体,最后是绥棱地区嫩一段的三角洲前缘砂体。该研究可为松辽盆地东北隆起区铀矿勘查突破提供新的找矿思路。 相似文献
13.
营城盆地位于松辽盆地东缘,其地层可与松辽盆地地层对比。营城盆地层序（三级）地层应与松辽盆地Ⅰ-VI和IX、X层序（火石岭组、沙河子组、营城组、登娄库组和泉头组）地层相对应,营城盆地地层应该划分为侏罗系上统火石岭组（J3h）;白垩系下统沙河子组（k1sh）、营城组（k1y）、泉头组（k1q）;第四系（Q）。主要可采工业煤层产在沙河子组。 相似文献
14.
通过岩心观察、沉积构造、矿物学特征、测井数据对松辽盆地南部永平地区泉四段进行沉积微相的判别,划分为湖泊相和曲流河三角洲相,包含2种亚相和3种微相。借助JF229井区密井网条件进行精细小层对比和砂体拆分,将永平地区泉四段划分为12个小层,按时间关系划分为9期河道,以此为依据研究该区沉积演化过程并总结沉积模式。泉四段早期,全区主要发育较稳定的三角洲前缘沉积。10小层时期伴随有一次短暂的湖侵-湖退,而后迅速恢复三角洲前缘沉积;泉四段末期从4小层开始发生广泛湖侵。结合连井剖面,进一步研究河道性质及演化特征,为追索有利砂体提供依据。 相似文献
15.
辽宁北部秀水盆地秀D1井孢粉组合及其地层意义 总被引：2，自引：1，他引：1
孢粉化石采自辽宁省北部秀水盆地的秀D1井,分析、鉴定和系统研究结果表明,来自秀D1井井深62.1~1089.7m的孢粉化石自下而上划分为3个孢粉组合,下部孢粉组合(井深703.85~1089.7m)以Osmundacidites-Klukisporites-Podocarpidites为代表,地质时代为晚侏罗世堤塘期(Tithonian),中部孢粉组合(井深381.5~699.3m)以Densoisporites-Cicatricosisporites-Piceaepollenites为代表,地质时代为早白垩世贝里阿斯期(Berriassian),上部孢粉组合(井深62.1~339m)以Cicatricosisporites-Impardecispora-Pinuspollenites为代表,地质时代为早白垩世凡兰吟期—欧特里夫期(Valanginian-Hauterivian)。秀D1井钻遇地层所含孢粉组合特征在区域上可以与冀北地区大北沟组,辽宁西部地区下白垩统义县组、九佛堂组,松辽盆地东南缘下白垩统火石岭组、沙河子组所产的孢粉组合对比。含孢粉组合地层时代的确定解决了井柱地层的划分,以及与区域地层的对比关系,同时为区域地层古生物研究提供了翔实的基础资料。 相似文献
16.
哈尔滨东宾县凹陷白垩纪地层层序及其与松辽盆地的对比 总被引：1，自引：0，他引：1
根据实测剖面并结合前人研究成果厘定了宾县凹陷白垩纪地层层序:下白垩统板子房组、宁远村组、淘淇河组、泉头组和上白垩统青山口组、姚家组。综合运用岩性地层、生物地层、地质事件和同位素年龄的方法将宾县凹陷白垩系与松辽盆地进行了对比。根据同位素年龄对比,板子房组相当于沙河子组上部和营城组下部,宁远村组相当于营城组中上部。根据植物化石组合分析,淘淇河组可与营城组顶部、登娄库组和泉头组底部对比。“鸟河组”下部红层作为区域性气候事件的产物可与泉头组下部对比;该组以Triangulicypristorsuosus和Triangulicypristorsuosusvar.nota繁盛为特征的介形类化石组合与青山口组相似,轮藻类化石Atopocharatrivolvis、Aclistocharasongliaoensis和Obtusocharaniaoheensis在泉头组至嫩江组均有发现;因此将“鸟河组”分解为泉头组、青山口组、姚家组和嫩江组。 相似文献
17.
Abdulwahab S. Alaug Magdy S. Mahmoud Amr S. Deaf Thamer K. AL-Ameri 《Arabian Journal of Geosciences》2014,7(6):2515-2530
The current work investigates the hydrocarbon potentiality of the upper Jurassic–lower Cretaceous rocks in the Marib-Shabwah Basin, Central Yemen, through the Sabatayn-1 well. Therefore, palynological and organic geochemical analyses were carried out on 37 ditch cutting and 12 core samples from the well. Palynofacies analysis of the Madbi (late Oxfordian–early Tithonian) and Nayfa (Berriasian–Valanginian) Formations sediments indicates deposition of their organic-rich shale, calcareous shale and marl in middle to outer shelf environments under dysoxic–anoxic conditions, containing mainly kerogen of types II to III. However, the shales of the lower Sabatayn (Tithonian) Formation were deposited in an inner shelf environment of prevailing dysoxic–suboxic conditions, and show kerogen types III to II. Regional warm and relatively dry palaeoclimate but with local humid conditions developed near the site of the well is thought to have prevailed during deposition of the studied well sediments. The geochemical analyses of the Madbi Formation show higher total organic carbon content (TOC) than the overlying Sabatayn and Nayfa formations: it is varies between 1.2 and 7, and with average 4 wt% TOC, and the obtained S2 values (～3–10, average 7 mg HC/g rock) indicates that the Madbi Formation is mainly good source rock. It shows a good petroleum potential of 4–11 mg HC/g dry rock, and the Rock-Eval pyrolysis indicates mainly kerogen types II to III (oil to gas prone) of hydrogen index values (132–258, and only one sample from Lam Member is of 360 and average 215 mg HC/g TOC). The thermal maturation parameters as T max (425–440 °C), production index (average 0.13 mg HC/g rock) and thermal alteration index (2 to 2+) reflected that this formation is present at margin of maturation to early mature stage oil window. So, the Lam Member (upper part) of the Madbi Formation is considered the main hydrocarbon (oil and gas) source rock in the Marib-Shabwah Basin. Accordingly, we predict that the Meem Member is an active source for gas and oil accumulations in the overlying sandstone reservoir of the Sabatayn Formation in the Sabatayn-1 well. 相似文献
18.
松辽盆地南部协尔苏凹陷泉头组一段分为上、下两部分,下部为以泥石流为主的冲积扇相沉积,上部为冲积扇-辫状河相沉积.分析表明：下部砂体泥砾混杂、粒度较粗,不利成矿;上部主要发育两层砂体,砂体厚5~40 m,延伸稳定,有利于砂岩型铀矿化的形成.根据泉一段砂体的岩石学特征、岩石化学特征、后生氧化-还原特征认为,由于深部有机流体的后生还原作用及基底-盖层贯通断裂继承性活动对下部层位煤层气进行纵向疏导,泉一段砂体后生地球化学环境改变为还原环境,主要表现为发育煤成烃油浸砂岩及烃类质量分数很高,砂岩由原生红色褪色化成灰色、灰绿色;在此基础上,后期叠加层间氧化作用,但由于下部层位煤层气持续作用,本区氧化特征不明显,氧化砂岩以浸染状、斑点状、团块状和条带状残留于还原砂岩中.通过分析协尔苏凹陷钻孔岩心铀钍含量及铀矿化特征,认为达官五家子地段、塔林布敦吐地段泉一段砂体铀含量高,铀的活化迁移作用明显,砂体存在铀的后生富集;铀的存在形式主要为吸附铀,为黏土矿物及有机质,铀矿物主要为沥青铀矿.分析认为研究区具有较好的铀成矿潜力. 相似文献
19.
《Journal of Asian Earth Sciences》1999,17(1-2):255-267
The oil-generating potential of coals and other organic-rich sediments from the Late Oligocene–Early Miocene Nyalau Formation, the offshore extension of which is believed to be a major source rock, is evaluated. Coals of the Nyalau Formation are typically dominated by vitrinite, with moderate and low amounts of exinite and inertinite, respectively. Significant amounts of clay minerals are present in these coals and those containing between 15 to 65% mineral matter by volume are termed carbargilite. The samples analysed range from sub-bituminous to high-volatile bituminous rank, possessing vitrinite reflectance in the range 0.42% to 0.72%. Tmax values range from 425°–450°C which is in good agreement with vitrinite reflectance data. Good oil-generating potential is anticipated from these coals and carbargilites with moderate to rich exinite content (15–35%). This is supported by their high hydrogen indices of up to 400 mgHC/gTOC, Py–GC (S2) pyrograms with n-alkane/alkene doublets extending beyond nC30, and their being in the early to mid-mature oil-window range. Petrographically, the most significant evidence of the oil-generating potential of these coals is the generation of petroleum-like materials (exsudatinite) visible under the microscope. Exsudatinite is a secondary maceral, commonly considered to represent the very beginning of oil generation in coal, which is shown here to also have an important role to play in hydrocarbon expulsion. The precursor of exsudatinite in these coals is the maceral bituminite which readily expels or mobilizes to hydrocarbon-like material in the form of oil smears and/or exsudatinite as observed under the microscope. The maceral bituminite is considered to play a major generative role via early exsudatinite generation, which is considered to facilitate the overall expulsion process in coaly source rocks. 相似文献
20.
Thamer Khazaal Al-Ameri Nagham Mohammed Al-Jubouri Murtadha J. Isa Rami Eidan Al-Azzawi 《Arabian Journal of Geosciences》2013,6(10):3725-3735
Organic geochemical analysis and palynological studies of the organic matters of subsurface Jurassic and Lower Cretaceous Formations for two wells in Ajeel oil field, north Iraq showed evidences for hydrocarbon generation potential especially for the most prolific source rocks Chia Gara and Sargelu Formations. These analyses include age assessment of Upper Jurassic (Tithonian) to Lower Cretaceous (Berriasian) age and Middle Jurassic (Bathonian–Tithonian) age for Chia Gara and Sargelu Formations, respectively, based on assemblages of mainly dinoflagellate cyst constituents. Rock-Eval pyrolysis have indicated high total organic carbon (TOC) content of up to 18.5 wt%, kerogen type II with hydrogen index of up to 415 mg HC/g TOC, petroleum potential of 0.70–55.56 kg hydrocarbon from each ton of rocks and mature organic matter of maximum temperature reached (Tmax) range between 430 and 440 °C for Chia Gara Formation, while Sargelu Formation are of TOC up to 16 wt% TOC, Kerogen type II with hydrogen index of 386 mg HC/g TOC, petroleum potential of 1.0–50.90 kg hydrocarbon from each ton of rocks, and mature organic matter of Tmax range between 430 and 450 °C. Qualitative studies are done in this study by textural microscopy used in assessing amorphous organic matter for palynofacies type belonging to kerogen type A which contain brazinophyte algae, Tasmanites, and foraminifera test linings, as well as the dinoflagellate cysts and spores, deposited in dysoxic–anoxic environment for Chia Gara Formation and similar organic constituents deposited in distal suboxic–anoxic environment for Sargelu Formation. The palynomorphs are of dark orange and light brown, on the spore species Cyathidites australis, that indicate mature organic matters with thermal alteration index of 2.7–3.0 for the Chia Gara Formation and 2.9–3.1 for the Sargelu Formation by Staplin's scale. These characters have rated the succession as a source rock for very high efficiency for generation and expulsion of oil with ordinate gas that charged mainly oil fields of Baghdad, Dyala (B?aquba), and Salahuddin (Tikrit) Governorates. Oil charge the Cretaceous-Tertiary total petroleum system (TPS) are mainly from Chia Gara Formation, because most oil from Sargelu Formation was prevented passing to this TPS by the regional seal Gotnia Formation. This case study of mainly Chia Gara oil source is confirmed by gas chromatography–mass spectrometry analysis for oil from reservoirs lying stratigraphically above the Chia Gara Formation in Ajeel and Hamrine oil fields, while oil toward the north with no Gotnia seal could be of mainly Sargelu Formation source. 相似文献