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《海洋地质前沿》2021,37(3)
随着东海盆地H地区油气勘探的发现,花港组烃源岩的勘探潜力也日益受到重视。通过烃源岩岩石热解分析、稳定碳同位素分析、镜质体反射率测定以及干酪根组分分析,对烃源岩特征进行研究。结果表明:氯仿沥青"A"组分中饱和烃和芳烃组分的碳同位素组成特征和碳同位素CV值显示研究区花港组泥岩烃源岩存在海陆相有机质;花港组烃源岩镜质体反射率Ro值为0.76%～1.11%,热解最高峰温主体介于440～465℃,已进入烃源岩热演化成熟阶段;泥岩烃源岩干酪根类型指数主体0,热解氢指数150 mg/g,花港组烃源岩发育Ⅲ型干酪根;泥岩烃源岩有机碳TOC主体0.5%,热解生烃潜量S_1+S_2主体1 mg/g,氯仿沥青"A"主体0.05%,为差泥岩烃源岩。研究区花港组烃源岩煤岩样品热解生烃潜量S_1+S_2主体100 mg/g,氯仿沥青"A"主体1.5%,氢指数HI主体275 mg/g,主体为好煤岩烃源岩。总之,研究区煤岩烃源岩品质优于泥岩烃源岩,泥岩烃源岩发育海陆相有机质,且陆相有机质丰度优于海相有机质。 相似文献
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烃源岩有机碳含量(TOC)是烃源岩评价的关键表征参数。番禺4洼钻遇文昌组烃源岩的钻井有限,实测地化参数难以反映凹陷内烃源岩全貌,文章通过烃源岩TOC地球物理预测技术,综合运用地球化学、测井和地球物理信息,获得了文昌组烃源岩TOC三维数据体。研究结果表明:文昌组主要发育好-极好烃源岩,TOC主体分布在3.0%～5.0%;文昌组底部主要发育差—中等烃源岩,TOC分布普遍2.0%;中部发育极好烃源岩,TOC主要分布在4.0%～6.0%;表层优质烃源岩集中发育于南洼中心,TOC主要分布在4.0%左右。预测结果与实测资料匹配关系好,有效地弥补钻井少且分布不均的不足,为精细油气资源潜力评价提供一种全新尝试。 相似文献
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通过系统收集和分析库泰盆地钻井岩屑样品及野外露头样品,首次对下中新统海相油气系统进行了评价。结果发现该区域以生物礁碳酸盐岩为标志层,发育多套海相沉积旋回,海相沉积油气系统具有自生自储自封堵特征:暗色海相泥岩为主力烃源岩,海相砂岩为有利储层,同时,海相泥岩作为有效盖层。下中新统海相烃源岩样品有机质类型为Ⅱ/Ⅲ型,以Ⅱ型为主,总有机碳质量分数(TOC)平均值1.92%,有机质处于低熟-成熟阶段,为有效烃源岩,烃源岩厚度较大,指示良好的生烃潜力;储层多期发育,具有低阻特征。自西向东,库泰盆地油气成藏系统时代变新、层系变浅:①盆地东部望加锡海峡深水-半深水区域以上中新统-上新统深水沉积成藏系统为主;②中部马哈坎三角洲-浅海区域以中中新统三角洲相成藏组合为主;③马哈坎褶皱带以下中新统海相成藏组合为主;④盆地西部以渐新统-始新统裂谷期成藏组合为主。新层段海相油气成藏系统的发现,揭示了库泰盆地有利成藏组合的分带规律,指明了库泰盆地中西部区域的未来油气勘探方向。 相似文献
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南黄海海域广泛分布了海相古生界,区域地质研究表明,南黄海海相古生界主要发育4套烃源岩层系,分别为下寒武统幕府山组泥质烃源岩,上奥陶统-下志留统五峰组-高家边组泥质烃源岩,下二叠统栖霞组灰质烃源岩和上二叠统龙潭-大隆组泥质烃源岩。通过对这4套烃源岩沉积特征及地球化学实验数据分析,开展了烃源岩地化特征和生烃潜力的评价。评价结果认为,下寒武统幕府山组、下二叠统栖霞组烃源岩有机质丰度高,类型好,生烃潜力高,为好-最好烃源岩;上二叠统龙潭组、大隆组烃源岩,其有机质丰度高,但有机质组成以陆源有机质为主,为较好烃源岩;奥陶-志留系为一般烃源岩,在此基础上,计算南黄海地区的天然气资源量为2.75万亿m~3。 相似文献
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南黄海海域与下扬子地区海相中-古生界地层对比及烃源岩评价 总被引：1，自引：0，他引：1
南黄海海域广泛分布了海相中-古生界,区域地质研究表明,南黄海海域不仅是下扬子向海的延伸,而且是下扬子的主体.扬子地区的沉积盖层发育十分良好,海相中-古生界大致可分为两大套:震旦系-志留系与泥盆系-中三叠统.通过南黄海海域与下扬子地区海相中-古生界地层的对比研究,认为南黄海海域发育了与陆地相同的海相中-古生界,其中下古生界主要烃源岩有上震旦统陡山沱组、下寒武统幕俯山组、上奥陶统五峰组、下志留统龙马溪和高家边组;上古生界-三叠系主要烃源岩为下三叠统青龙组、上二叠统大隆组和龙潭组、下二叠系栖霞组,其中上震旦统泥质岩、下寒武统泥质岩、下志留统泥质岩和二叠系碳酸盐岩是4套主要的烃源岩. 相似文献
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南黄海盆地二叠系烃源岩的生烃层系多、热演化程度高、沉积环境变化大,前人极少从生物标志化合物的角度探讨烃源岩的差异。本文通过对CSDP-2井二叠系16个成熟-过成熟烃源岩样品进行有机地球化学分析,剖析了四套烃源岩的饱和烃、芳香烃馏分中生物标志化合物的组成、演化规律及地质意义。结果表明,二叠系不同层系烃源岩的甾烷系列、三芳甾烷系列、烷基二苯并噻吩系列化合物和β-胡萝卜烷的相对丰度具有显著差异,据此可将其分为栖霞组下段和龙潭组-大隆组泥岩、栖霞组上段和孤峰组硅质岩、孤峰组硅质泥岩3类烃源岩。研究显示,栖霞组下段和龙潭组-大隆组泥岩烃源岩沉积于淡水氧化或微咸水贫氧环境,有机质来源于浮游生物和陆生高等植物;栖霞组上段-孤峰组烃源岩沉积于还原咸水或静水硫化环境,其中硅质岩烃源岩的有机质来源于浮游生物和硅藻,硅质泥岩烃源岩的有机质来源于浮游生物、硅藻和陆生高等植物。此外,甲基菲指数、烷基二苯并噻吩参数（4-MDBT/DBT、MDBI、4,6-/1,4-DMDBT）可作为上二叠统烃源岩的成熟度指标,但不能作为中—下二叠统烃源岩的成熟度指标。 相似文献
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《海洋地质与第四纪地质》2017,(3)
通过精细测量及观测南京、巢湖、浙江地区25个露头点露头资料和典型剖面测量以及资料收集整理,综合分析认为下扬子陆域主要发育下寒武统荷塘组、下奥陶统宁国组(大湾-牯牛组)、上奥陶统五峰组-下志留统高家边组、下二叠统栖霞组、上二叠统龙潭组、上二叠统大隆组6套区域性主力烃源岩。烃源岩的发育受多种因素控制,在下扬子地区主要受构造演化、最大海平面变化、古地貌单元、沉积环境等因素控制。在构造演化控制的特定古地理格局下,大规模海侵期控制了烃源岩发育层位,古地貌单元控制了烃源岩分布范围,沉积环境控制了烃源岩的类型。以下扬子陆域烃源岩研究为对比基础,探讨了寻找南黄海盆地烃源岩的方向。 相似文献
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南沙海域礼乐盆地中生界油气资源潜力 总被引：4，自引：0，他引：4
位于南沙东部海域的礼乐盆地是一大型的中、新生代叠置盆地,其特有的地质背景及巨厚的中生代地层显示了其与南沙海域其他新生代沉积盆地的差异。盆地内发育的厚度超过4 000 m的中生代海相地层,主要包括了上侏罗统—下白垩统的滨—浅海相含煤碎屑岩或半深海相页岩、上三叠统—下侏罗统三角洲—浅海相砂泥岩和中三叠统深海硅质页岩等3套地层,展示出盆地具有良好的油气生成潜力。而早期位于华南陆缘、现今位于南沙东部海域的礼乐盆地中生界,完全具备了形成油气藏的基本石油地质条件,具有较为良好的油气资源潜力,其中生界油气资源勘探具有非常重要的意义,将成为我国海域油气勘探的一个重要新领域。 相似文献
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The Upper Jurassic marlstones (Mikulov Fm.) and marly limestones (Falkenstein Fm.) are the main source rocks for conventional hydrocarbons in the Vienna Basin in Austria. In addition, the Mikulov Formation has been considered a potential shale gas play. In this paper, organic geochemical, petrographical and mineralogical data from both formations in borehole Staatz 1 are used to determine the source potential and its vertical variability. Additional samples from other boreholes are used to evaluate lateral trends. Deltaic sediments (Lower Quarzarenite Member) and prodelta shales (Lower Shale Member) of the Middle Jurassic Gresten Formation have been discussed as secondary sources for hydrocarbons in the Vienna Basin area and are therefore included in the present study.The Falkenstein and Mikulov formations in Staatz 1 contain up to 2.5 wt%TOC. The organic matter is dominated by algal material. Nevertheless, HI values are relative low (<400 mgHC/gTOC), a result of organic matter degradation in a dysoxic environment. Both formations hold a fair to good petroleum potential. Because of its great thickness (∼1500 m), the source potential index of the Upper Jurrasic interval is high (7.5 tHC/m2). Within the oil window, the Falkenstein and Mikulov formations will produce paraffinic-naphtenic-aromatic low wax oil with low sulfur content. Whereas vertical variations are minor, limited data from the deep overmature samples suggest that original TOC contents may have increased basinwards. Based on TOC contents (typically <2.0 wt%) and the very deep position of the maturity cut-off values for shale oil/gas production (∼4000 and 5000 m, respectively), the potential for economic recovery of unconventional petroleum is limited. The Lower Quarzarenite Member of the Middle Jurassic Gresten Formation hosts a moderate oil potential, while the Lower Shale Member is are poor source rock. 相似文献
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Significant oil and gas accumulations occur in and around Lougheed Island, Arctic Canada, where hydrocarbon prospectivity is controlled by potential source rock distribution and composition. The Middle to Upper Triassic rocks of the Schei Point Group (e.g. Murray Harbour and Hoyle Bay formations) contain a mixture of Types I and II organic matter (Tasmanales marine algae, amorphous fluorescing bituminite). These source rocks are within the oil generation zone and have HI values up to 600 mg HC/g Corg. The younger source rocks of the Lower Jurassic Jameson Bay and the Upper Jurassic Ringnes formations contain mainly gas-prone Type II/III organic matter and are marginally mature. Vitrinite reflectance profiles suggest an effective geothermal gradient essentially similar to the present-day gradient (20 to 30°C/km). Maturation gradients are low, ranging from 0.125 to 0.185 log%Ro/km. Increases in subsidence rate in the Early Cretaceous suggest that the actual heat flow history was variable and has probably diminished from that time. The high deposition rates of the Christopher Formation shales coincide with the main phase of rifting in Aptian-Albian times. Uplift and increased sediment supply in the Maastrichtian resulted in a new sedimentary and tectonic regime, which culminated in the final phase of the Eurekan Orogeny. Burial history models indicate that hydrocarbon generation in the Schei Point Group took place during rifting in Early Cretaceous, long before any Eurekan deformation. 相似文献
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The Triassic formation is a possible new giant hydrocarbon generated formation in Northwest China and Mid-Asia. Taking the Upper Triassic formation in the Sikeshu Sag in Junggar Basin as an example, based on the comprehensive analysis on the geochemical characteristics of the cores and the dark mudstone of the outcrops and reservoir formation conditions, we have evaluated the Upper Triassic source rocks by comparing with those in the Ulungu Depression, and reached the following findings. Firstly, the Upper Triassic formation is mainly composed of dark mudstone and sandy mudstone deposits, and the hydrocarbon source rock is mainly distributed in the middle and upper parts with a thickness range of 100–150 m and area of 3500 km2. Secondly, the source rock, moderate in organic matter abundance (with TOC range of 1%–3%), has the material basis for hydrocarbon generation. Thirdly, the organic matter has high percentage of sapropelinite, and is dominated by type II2. Fourthly, the degree of the thermal evolution is moderate, and the source rock with Ro higher than 0.7% has a distribution area of about 1800 km2, providing the conditions of massive hydrocarbon generation. Fifthly, the source rock has great burial depth and wide distribution; the source rock with a Ro of higher than 0.7% and thickness of more than 100 m has an area of around 1400 km2, implying huge resource potential. Sixthly, the next step exploration should focus on highly mature hydrocarbon generation central area in the Upper Triassic - Lower Jurassic in the east of the sag to search for and confirm favorable traps. The research findings have important reference value for promoting the resource status of, deepening the understanding of reservoir formation, and clarifying the exploration direction in the Sikeshu Sag and other periphery Mid-Asia areas. 相似文献
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Jurassic-Cretaceous rift successions and basin geometries of the Sverdrup Basin are reconstructed from a review and integration of stratigraphy, igneous records, outcrop maps, and subsurface data. The rift onset unconformity is in the Lower Jurassic portion of the Heiberg Group (approximately 200–190 Ma). Facies transgress from early syn-rift sandstones of the King Christian Formation to marine mudstones of the Jameson Bay Formation. The syn-rift succession of marine mudstones in the basin centre, Jameson Bay to Deer Bay formations, ranges from Early Jurassic (Pleinsbachian) to Early Cretaceous (Valanginian). Early post-rift deposits of the lower Isachsen Formation are truncated by the sub-Hauterivian unconformity, which is interpreted as a break up unconformity at approximately 135–130 Ma. Cessation of rift subsidence allowed for late post-rift sandstone deposits of the Isachsen Formation to be distributed across the entire basin. Marine deposition to form mudstone of the Christopher Formation throughout the Canadian Arctic Islands and outside of the rift basin records establishment of a broad marine shelf during post-rift thermal subsidence at the start of a passive margin stage. The onset of the High Arctic Large Igneous Province at approximately 130 Ma appears to coincide with the breakup unconformity, and it is quite typical that magma-poor rifted margins have mainly post-rift igneous rocks. We extend the magma-poor characterization where rifting is driven by lithospheric extension, to speculatively consider that the records from Sverdrup Basin are consistent with tectonic models of retro-arc extension and intra-continental rifting that have previously been proposed for the Amerasia Basin under the Arctic Ocean. 相似文献
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《Marine and Petroleum Geology》2012,37(1):13-34
Structured organic matters of the Palynomorphs of mainly dinoflagellate cysts are used in this study for dating the limestone, black shale, and marl of the Middle Jurassic (Bajocian–Bathonian) Sargelu Formation, Upper Jurassic (Upper Callovian – Lower Oxfordian) Naokelekan Formation, Upper Jurassic (Kimeridgian and Oxfordian) Gotnia and Barsarine Formations, and Upper Jurassic – Lower Cretaceous (Tithonian-Beriassian) Chia Gara source rock Formations while spore species of Cyathidites australis and Glechenidites senonicus are used for maturation assessments of this succession. Materials' used for this palynological study are 320 core and cutting samples of twelve oil wells and three outcrops in North Iraq.Terpane and sterane biomarker distributions, as well as stable isotope values, were determined for oils potential source rock extracts of Jurassic-Lower Cretaceous strata to determine valid oil-to-source rock correlations in North Iraq. Two subfamily carbonate oil types-one of Middle Jurassic age (Sargelu) carbonate rock and the other of mixed Upper Jurassic/Cretaceous age (Chia Gara) with Sargelu sources as well as a different oil family related to Triassic marls, were identified based on multivariate statistical analysis (HCA & PCA). Middle Jurassic subfamily A oils from Demir Dagh oil field correlate well with rich, marginally mature, Sargelu source rocks in well Mk-2 near the city of Baiji. In contrast, subfamily B oils have a greater proportion of C28/C29 steranes, indicating they were generated from Upper Jurassic/Lower Cretaceous carbonates such as those at Gillabat oil field north of Mansuriyah Lake. Oils from Gillabat field thus indicate a lower degree of correlation with the Sargelu source rocks than do oils from Demir Dagh field.Palynofacies assessments are performed for this studied succession by ternary kerogen plots of the phytoclast, amorphous organic matters, and palynomorphs. From the diagram of these plots and maturation analysis, it could be assessed that the formations of Chia Gara and Sargelu are both deposited in distal suboxic to anoxic basin and can be correlated with kerogens classified microscopically as Type A and Type B and chemically as Type II. The organic matter, comprised principally of brazinophyte algae, dinoflagellate cysts, spores, pollen, foraminifera test linings, and phytoclasts in all these formations and hence affected with upwelling current. These deposit contain up to 18 wt% total organic matters that are capable to generate hydrocarbons within mature stage of thermal alteration index (TAI) range in Stalplin's scale (Staplin, 1969) of 2.7–3.0 for the Chia Gara Formation and 2.9–3.1 for the Sargelu Formation. Case study examples of these oil prone strata are; one 7-m (23-ft) thick section of the Sargelu Formation averages 44.2 mg HC/g S2 and 439 °C Tmax (Rock-Eval pyrolysis analyses) and 16 wt% TOC especially in well Mk-2 whereas, one 8-m (26-ft) thick section of the Chia Gara and 1-m (3-ft) section of Naokelekan Formations average 44.5 mg HC/g S2 and 440 °C Tmax and 14 wt% TOC especially in well Aj-8. One-dimension, petroleum system models of key wells using IES PetroMod Software can confirm their oil generation capability.These hydrocarbon type accumulation sites are illustrated in structural cross sections and maps in North Iraq. 相似文献
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Three bitumen fractions were obtained and systematically analysed for the terpane and sterane composition from 30 Paleozoic source rocks and 64 bitumen-containing reservoir rocks within the Upper Sinian, Lower Cambrian, Lower Silurian, Middle Carboniferous, Upper Permian and Lower Triassic strata in the Sichuan Basin and neighbouring areas, China. These bitumen fractions include extractable oils (bitumen I), oil-bearing fluid inclusions and/or closely associated components with the kerogen or pyrobitumen/mineral matrix, released during kerogen or pyrobitumen isolation and demineralization (bitumen II), and bound compounds within the kerogen or pyrobitumen released by confined pyrolysis (bitumen III). In addition, atomic H/C and O/C ratios and carbon isotopic compositions of kerogen and pyrobitumen from some of the samples were measured. Geochemical results and geological information suggest that: (1) in the Central Sichuan Basin, hydrocarbon gases in reservoirs within the fourth section of the Upper Sinian Dengying Formation were derived from both the Lower Cambrian and Upper Sinian source rocks; and (2) in the Eastern Sichuan Basin, hydrocarbon gases in Middle Carboniferous Huanglong Formation reservoirs were mainly derived from Lower Silurian source rocks, while those in Upper Permian and Lower Triassic reservoirs were mainly derived from both Upper Permian and Lower Silurian marine source rocks. For both the source and reservoir rocks, bitumen III fractions generally show relatively lower maturity near the peak oil generation stage, while the other two bitumen fractions show very high maturities based on terpane and sterane distributions. Tricyclic terpanes evolved from the distribution pattern C20 < C21 < C23, through C20 < C21 > C23, finally to C20 > C21 > C23 during severe thermal stress. The concentration of C30 diahopane in bitumen III (the bound components released from confined pyrolysis) is substantially lower than in the other two bitumen fractions for four terrigenous Upper Permian source rocks, demonstrating that this compound originated from free hopanoid precursors, rather than hopanoids bound to the kerogen. 相似文献
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Upper Jurassic organic matter-rich, marine shales of the Mandal Formation have charged major petroleum accumulations in the North Sea Central Graben including the giant Ekofisk field which straddles the graben axis. Recent exploration of marginal basin positions such as the Mandal High area or the Søgne Basin has been less successful, raising the question as to whether charging is an issue, possibly related to high thermal stability of the source organic matter or delayed expulsion from source to carrier.The Mandal Formation is in part a very prolific source rock containing mainly Type II organic matter with <12 wt.-% TOC and HI < 645 mg HC/g TOC but Type III-influenced organofacies are also present. The formation is therefore to varying degrees heterogeneous. Here we show, using geochemical mass balance modelling, that the petroleum expulsion efficiency of the Mandal Formation is relatively low as compared to the Upper Jurassic Draupne Formation, the major source rock in the Viking Graben system. Using maturity series of different initial source quality from structurally distinct regions and encompassing depositional environments from proximal to distal facies, we have examined the relationship between free hydrocarbon retention and organic matter structure. The aromaticity of the original and matured petroleum precursors in the Mandal source rock plays a major role in its gas retention capacity as cross-linked monoaromatic rings act on the outer surface of kerogen as sorptive sites. However, oil retention is a function of both kerogen and involatile bitumen compositions. Slight variations in total petroleum retention capacities within the same kerogen yields suggest that texture of organic matter (e.g. organic porosity) could play a role as well. 相似文献
19.
印支运动以后,在现今的南海及其周围存在过2个古海洋,其中晚侏罗世一早白垩世消失于南海北部陆缘区、北巴拉望-礼乐滩-南沙地块以北的古海洋为“中特提斯”,而早第三纪期间消失于南沙地块以南沙捞越一带的古海洋为“古南海”。它们的结束时间和消失的古地理位置完全不同。对它们的正确识别和区分,对目前进行的南海周边地区中一新生代构造演化研究极为重要。对马来半岛、加里曼丹岛中生代岩相古地理资料的整理和分析结果支持如下结论：中特提斯洋的延伸是从苏门答腊的Woyla缝合线,过婆罗洲的Meratus缝合线。然后绕西南婆罗洲地块至加里曼丹岛的西北(Lupar带或者Boyan带),进入南海西南角(南沙-礼乐滩-北巴拉望地块等以北),再接南海北部陆缘区内的中特提斯缝合线。该区中生代海相地层的分布明显受构造演化的控制,整体趋势是向南退缩。印支运动以前、早-中三叠世的海侵广泛分布于古特提斯带及以南地区,涉及华南,中南地块,马来半岛及以南地区;印支运动基本结束了古特提斯带的海侵,因此晚三叠世一早侏罗世的海侵主要限于中特提斯海域及以南地区,如与中特提斯洋相邻的陆域,包括华南的湘赣粤海湾晚三叠世一早侏罗世的海侵、中南半岛东南部早侏罗世的海侵以及新加坡早侏罗世的海相地层。白垩纪海相地层主要分布于中特提斯以南地区,如加里曼丹岛。 相似文献
20.
Shanshan Zhou Youchuan Li Jianping Li Wenjing Ding Xin Li Weilai Zhang 《海洋学报(英文版)》2023,42(3):138-150
The terrigenously-dominated marine shales which were deposited in the lower Eocene Pinghu Formation were thought to be a potential source rock in the Xihu Depression of the East China Sea Shelf Basin. However, the exceptionally high total organic carbon content (TOC, >6% on average) of the tidal sand ridge samples was not compatible with their sedimentary environment, indicating coal-bearing sedimentary debris may have been transferred from the coast to the ocean. In this study, new sights into the origins and supply of organic materials in the coastal environment were proposed in the neritic organic matter of the Eocene Pinghu Formation. A discriminant model was developed using plynofacies analysis data to pinpoint the source of organic materials in marine source rocks. The discrimination results suggested that marine mudstones were associated with tidal flat mudstones rather than deltaic ones. The biomarker characteristics of mudstones deposited in various environments support this assertion, indicating that the supply of plant materials in tidal flats is the primary organic matter source for the marine environment. The organic matter abundance was elevated in tidal flats due to their superior preservation conditions. Additionally, the lithological assemblage of tidal flats suggests that tidal currents can scour marshes and then transport dispersed terrigenous organic materials to neritic areas. These findings indicate that coal-bearing sedimentary debris was likely transferred from the coast to the ocean, and tidal currents are thought to be the dominant mechanism driving organic matter from the tidal to the marine environment. 相似文献