泌阳凹陷和枣阳凹陷下第三系生油层的孢粉化石颜色及有机质类型

泌阳凹陷和枣阳凹陷位于南襄盆地的东部,同属白垩-第三系沉积凹陷(图1)。经勘探揭示,这两个凹陷不仅在地层发育,接触关系等方面基本一致,而且两者的沉积旋回性质和主要生油层的沉积时期亦近相同。然而,泌阳凹陷的下第三系含油丰富,以“小而肥”著称,而在枣阳凹陷迄今尚未发现任何规模的油气藏。     

生物─热催化过渡带油气关系

本文在辽河盆地原油和天然气之间碳氢同位素关系研究的基础上，系统地研究了中国生物─热催化过渡带油气的地球化学特征，特别是它们之间同位素组成关系，划分出油气的不同组合类型，从而证明生物─热催化过渡带油气的自生自储特征，认为过渡带是油气形成聚集的重要垂向演化层段。同时为完善烃类形成的多源复合和多阶连续提供了佐证。     

The influence of marine and terrestrial source material on the composition of petroleum

This paper consists of two interrelated parts. In the first part, the influence of the composition of sediment organic matter on crude oil composition is discussed. The second part deals with the origin of normal paraffins in petroleum.Source beds with abundant terrestrial plant matter generate heavy hydrocarbons rich in five-ring naphthenes. Unless such source beds are exposed to a high temperature for a prolonged time, the oils released are also rich in five-ring naphthenes. Such oils are rare; thus far the only examples found are some Eocene Wilcox oils from the Texas Gulf Coast and some Eocene Green River oils from the Uinta Basin, Utah. Normally, oil source beds are not rich in terrestrial plant matter and the five-ring naphthene content of the source bed hydrocarbons, as well as that of the produced oils, is low.The n-paraffins generated by oil source beds rich in terrestrial plant matter are characterized by abnormally low (C₂₁ + C₂₂)/(C₂₈ + C₂₉) ratios of 0.6–1.2. In oils of dominantly marine origin, this ratio is in the range 1.5–5.0. The ratio of marine to terrestrial organic matter in source beds appears to influence both the naphthene composition and the n-paraffin composition of the generated oils.Evidence is presented that petroleum n-parainns originate from slow thermal cracking of fatty acids contained in fats and waxes. Reaction equations are discussed which explain the major geochemical observations, including the difference in carbon-number distribution of the assumed parental fatty acids and of their descendant n-paraffins. In normal oils, which originate mostly from fat rich marine organic matter, the n-paraffin concentration tapers off above C₂₀. The molecular weight range of the fatty acids of plant waxes is considerably higher than that of fats. If plant waxes contribute strongly to the oil source material, the molecular weight distribution of the petroleum n-paraffins formed is abnormal and high carbon numbers in the C₂₄-C₃₂ range dominate.     

The advantages of using n-alkanes, triterpane, and steranes to determine the characterization of sedimentary organic matter

The current geochemical study of n-alkanes, steranes, and triterpanes in bitumen from the Late Maastrichtian–Paleocene El Haria organic-rich facies in West of Gafsa, southern Tunisia, was performed in order to characterize with accuracy their geochemical pattern. The type of organic matter as deduced from n-alkanes, steranes, and triterpanes distributions is type II/III mixed oil/gas prone organic matter. Isoprenoids and biomarkers maturity parameters (i.e., T _s/T _m, 22S/(22S?+?22R) of the C₃₁ αβ-hopanes ratios, 20S/(20R?+?20S) and ββ/(ββ?+?αα) of C₂₉ steranes), revel that the organic-rich facies were deposited during enhanced anoxic conditions in southern Tunisa. The organic matter is placed prior to the peak stage of the conventional oil window (end of diagenesis–beginning of catagenesis). All these result are suggested by total organic carbon analysis, bitumen extraction and liquid chromatography data. Thus, the n-alkanes, triterpane, and steranes study remains valuable and practical for geochemical characterization of sedimentary organic matter.     

Relations between the Chemical Composition of Organic Matter in Lacustrine Ecosystems and the Genesis of Their Sapropel

The paper presents data on sapropels from ten lacustrine systems at the Barabinsk and Kulunda plains in Novosibirsk region. The sapropels are classified according to the type of the biological contribution to their origin and the content of organic matter. The sapropel of lakes Kachkulnya and Barchin, which are rich in organic matter and differ by the type of their origin (macrophytogenic and planktonogenic), were studied in much detail with the application of the following techniques: X-ray diffraction (XRD), atomic absorption spectroscopy (AAS), and elemental (CHNSO) analysis. Groups of organic compounds contained in the organic matter were determined by successive extraction, and the monosaccharide composition was studied by high-performance liquid chromatography (HPLC). The organic matter of sapropel with different type of boilogical contribution was discovered to differ in elemental (CHNSO) composition, group of organics, and the monosaccharide compositions. Our results led us to conclude that the genesis of sapropel significnalty imprints the composition of its organic matter.     

Molecular and structural-group characteristics of hydrocarbons in Late Devonian oils of the Timan–Pechora Province

The paper presents gaz chromatography–mass spectrometry and ¹H- and ¹³C-NMR data on the composition of hydrocarbon markers and structural-group composition of oils in the Timan–Pechora oil and gas province. The set of samples is subdivided into groups whose oils differ in composition and the distribution of their polycyclic biomarkers. All of the oils show closely similar geochemical characteristics, types of their source organic matter, and thermal maturity. Comparison of oil characteristics (composition of the polycyclic biomarkers) and parameters determined by chromatography–mass spectrometry makes it possible to reveal certain important (and calling for further investigation) relations between the composition of the structural groups of hydrocarbons in the oil fluid and its geochemical characteristics.     

Changes in the composition of bitumen extracts and chemical structure of kerogen during hydrous pyrolysis

The paper presents data on the composition of biomarkers from bitumen extracts and the chemical structure of kerogen from C_org-rich sedimentary rocks before and after hydrothermal treatment in an autoclave at 300°C. Samples selected for this study are kukersite and Ordovician Dictyonema shale from the Baltics, Domanik oil shale from the Ukhta region, Upper Permian brown coal from the Pre-Ural foredeep, carbonaceous shale from the Oxfordian horizon of the Russian plate, and Upper Jurassic oil shales from the Sysola oil shale bearing region. The rocks contain type I, II, III, and II-S kerogens. The highest yield of extractable bitumen is achieved for Type II-S kerogen, whereas Type III kerogen produces the lowest amount of bitumen. The stages of organic matter thermal maturation achieved during the experiments correspond to a transition from PC_2–3 to MC_1–2. The ¹³C NMR data on kerogen indicate that the aromatic structures of geopolymers underwent significant changes.     

Productivity and paleoclimatic controls on source rock character in the Aman Trough,north central Sumatra,Indonesia

The Central Sumatra Basin (CSB) is a prolific oil producing basin in Indonesia where a single source rock has been identified, the Brown Shale Formation of the Paleogene Pematang Group. Despite the presence of a single source rock, the oils in the Central Sumatra Basin and particularly in the Aman Trough, exhibit variable molecular and isotopic compositions, previously described as reflective of lateral facies variations within the source rock. Analyses by gas chromatography (GC), gas chromatography–mass spectrometry (GC–MS) and gas chromatography–isotope ratio mass spectrometry (GC–IRMS) of 15 oil samples from the Aman Trough allowed identification of vertical and lateral facies changes within the Brown Shale Formation as well as paleoproductivity and paleoclimatic changes that took place during deposition of this prolific source rock. The molecular and isotopic data indicate the source rock for these oils was deposited in a fresh to brackish water stratified lake in which CO₂ limiting conditions prevailed. Compound specific isotopic data also indicate that changes in paleoclimatic conditions, possibly associated with the Eocene–Oligocene paleoclimatic transition, had an effect on the geochemical composition of the source rock in the Aman Trough.     

Origin and alteration of oils and oil seeps from the Sinú-San Jacinto Basin, Colombia

Liquid hydrocarbons have been detected in the subsurface as well as in the surface in the Sinú-San Jacinto Basin (northwestern Colombia). The origin of the oils has not been conclusively established especially in the southern part of the basin. The most likely source rocks in the basin are the Ciénaga de Oro Fm. of the Oligocene-Early Miocene and the Cansona Fm. of the Upper Cretaceous. In this study, oil samples, seeps and source rock extracts were analyzed by GC and GC/MS, and δ¹³C was determined to identify the source facies. The sulphur content and gravity data were also considered.Two organic facies were identified: one constituted by terrestrial organic matter deposited in siliciclastic sediments in marginal marine to deltaic environments and the other made up of marine organic matter deposited in marine costal shelf to pelagic environments. The oils from the former organic facies have low sulphur contents, whereas the oils from the latter facies have high sulphur levels. Correlation of the oil seeps from the former facies with the Ciénaga de Oro Fm. has not been clearly established. The oil seeps from the latter facies correlate well with the extracts from the source rocks of the Cansona Fm., deposited along the fold belt of San Jacinto (east side). The oil seeps are affected by moderate to severe biodegradation, whereas the oil from the only oil producing well in the Sinú Basin (Floresanto-6 well) has not undergone biodegradation.     

华南碳酸盐岩型铀矿床中有机质及其与铀成矿的关系

华南碳酸盐岩铀矿床,分布广泛,产于泥盒—二叠纪的各地层中。矿床受岩相、构造、水文地球化学等多种条件控制。矿化与有机质关系密切,而有机质的分布受泻湖相带控制。经研究对比,与成矿有关的有机质属于腐泥型,来源于海相微体生物和藻类。铀在各地层中的含量不均匀,富里酸和腐殖酸是含铀的主要有机质。     

Improved understanding of the petroleum systems of the Niger Delta Basin,Nigeria

Biomarker and n-alkane compound specific stable carbon isotope analyses (CSIA) were carried out on 58 crude oil samples from shallow water and deepwater fields of the Niger Delta in order to predict the depositional environment and organic matter characteristics of their potential source rocks. Using a source organofacies prediction approach from oil geochemistry, the presence in the western deepwater oils relatively abundant C₂₇ steranes, C₃₀ 24-n-propyl cholestane, low oleanane index, relatively low pr/ph ratios, gammacerane, and positive to nearly flat C₁₂–C₃₀ n-alkane compound specific stable carbon isotope profiles, suggests that the source facies that expelled these oils contain significant marine derived organic matter deposited under sub-oxic and stratified water column conditions. This contrasts with the terrigenous organic matter dominated source rocks accepted for shallow water Niger Delta oils. Oils in the shallow water accumulations can be separated into terrigenous and mixed marine-terrigenous families. The terrigenous family indicates expulsion from source rock(s) containing overwhelmingly higher plant source organic matter (average oleanane index = 0.48, high C₂₉ steranes) as well as having negative sloping n-alkane isotope profiles. Oxic source depositional conditions (pr/ph > 2.5) and non-stratified conditions (absence to low gammacerane content) are inferred for the terrigenous family. The mixed marine-terrigenous family has biomarker properties that are a combination of the deepwater and terrigenous shallow water oils. Bitumen extracts of the sub-delta Late Cretaceous Araromi Formation shale in the Dahomey Basin are comparable both molecularly and isotopically to the studied western deepwater oil set, but with an over all poor geochemical correlation. This poor geochemical match between Araromi shale and the western deepwater oils does not downgrade the potential of sub-delta Cretaceous source rock contribution to the regional oil charge in the deepwater Niger Delta.     

碳酸盐岩中有机质组成特征分析

对碳酸盐岩有机质组分进行分类时，有两种分类标准，一是主要采用煤岩学方法，二是采用孢粉学研究方法。本文使用煤岩学方法作为标准，对碳酸盐岩有机质的组成特征进行分析。按有机质来源和有机组分光性和形态等方面差别划分为内源有机质、次生有机质和陆源有机质三类。内源有机质类中分腐泥组和动物有机组，前者主要来源于菌藻类，后者则主要来源于浮游动物有机体；次生有机质中区分出微粒体、有机包裹体、沥青；陆源有机质类分类术语仍沿用煤显微组分分类系统和术语。碳酸盐岩烃源岩的有机质主要为腐泥型，有机质来源以低等藻类为主，且有机质组成特征与碳酸盐岩烃源岩的地质年代有关。碳酸盐岩还存在着差异演化的特征。     

Biomarkers and compound-specific stable carbon isotope of n-alkanes in crude oils from Eastern Llanos Basin,Colombia

Representative samples of crude oils from Cusiana, Cupiagua, Apiay, Castilla and Chichimene fields in the Eastern Llanos Basin of Colombia were analyzed to determine its compound-specific stable carbon isotope composition (CSIA) using gas chromatography–isotopic ratio–mass spectrometry (GC–IRMS). GC–IRMS analyses of n-alkanes allowed differentiating between Cretaceous and Cretaceous/Tertiary oil samples. Cretaceous sourced samples have δ¹³C-enriched values than Cretaceous/Tertiary sourced samples; the heavier isotope composition of these samples is due to their major terrigenous organic matter input. Their isotope distribution patterns suggest significant algal and/or bacterial contribution (marine origin). The analysis of the n-alkane fractions by GC–IRMS confirms that the organic matter has marine origin in those samples from Cusiana, Cupiagua and Apiay while Castilla and Chichimene have marine origin with terrestrial inputs. The results were confirmed by gas chromatography/FID and gas chromatography/mass spectrometry (GC/MS). Basic geochemical composition show that samples from Cupiagua/Cusiana fields and Apiay/Castilla/Chichimene fields in the Llanos basin, Colombia present different characteristics reflecting a specific for each depositional environment.     

我国凝析油的成因类型及其地球化学特征和意义

近十几年的勘探实际表明，在我国一些含油气盆地中，许多天然气藏均伴生一定量的凝析油（或轻质油）。按母质类型可将凝析油分为海相腐泥型有机质生成的凝析油、煤系地层腐殖质有机质生成的凝析油、陆相混合型有机质生成的凝析油。本文较详细地从成因机理上讨论了这三种不同成因凝析油的形成特点。海相腐泥型有机质一般在有机质热演化达到高成熟－过成熟阶段，由干酪根或早期形成的高分子液态烃热裂解才形成凝析油。煤系地层中腐殖型有机质从低成熟到过成熟各个阶段所生成的一定量的液态烃一般主要以凝析油的状态与天然气相伴生。陆相混合型有机质从低成熟到过成熟阶段也都可能形成凝析油。利用凝析油单体烃的组份特征，石蜡指数和庚烷值对我国主要含油气盆地凝析油的成熟度进行了计算，所得结果，大都与地质实际相吻合。研究表明我国凝析油成熟度的分布范围从低成熟到过成熟均有。三种不同成因的凝析油其地球化学特征具有一定差异，煤系地层腐殖型有机质形成的凝析油从组份来讲相对富含芳烃，其芳烃含量一般为１６.２～２３.５%，饱和烃/芳烃值为３.２～５.２，同时其姥鲛烷/植烷值相对较高，通常均大于３；而海相腐泥型有机质生成的凝析油则相对富含饱和烃，其饱/芳比值为１１.８～１８.２，同时姥蛟烷/植烷值较低，一般小于1。陆相混合型有机质生成的凝析油则介于二者之间。三类不同成因的凝析油它们的芳烃组份(蔡系、联苯系和药系)和低分子生物标记物(菇类化合物)以及烷烃和芳烃组份的碳同位素组成都具有明显的差异。利用凝析油的这些地球化学特征可以有效地判识凝析油的成熟度和成因类型，从而确定与之相伴生的天然气的成因或来源。     

Geochemistry of Diagenesis of Organogenic Sediments: An Example of Small Lakes in Southern West Siberia and Western Baikal Area

Organogenic sediments (sapropels) in lakes are characterized by a reduced type of diagenesis, during which organic compounds are decomposed, the chemical composition of the pore waters is modified, and authigenic minerals (first of all, pyrite) are formed. Pyrolysis data indicate that organic matter undergoes radical transformatons already in the uppermost sapropel layers, and the composition of this organic matter is principally different from the composition of the organic matter of the its producers. The sapropels contain kerogen, whose macromolecular structure starts to develop during the very early stages of diagenesis, in the horizon of unconsolidated sediment (0–5 cm). The main role in the diagenetic transformations of organic matter in sediments is played by various physiological groups of microorganisms, first of all, heterotrophic, which amonifying, and sulfate-reducing bacteria. SO₄^2? and Fe²⁺ concentrations in the pore waters of the sediments are determined to decrease (because of bacterial sulfate reduction), while concentrations of reduced Fe and S species (pyrite) in the solid phase of the sediment, conversely, increase. Comparative analysis shows that, unlike sapropels in lakes in the Baikal area, sapropels in southern West Siberia are affected by more active sulfate reduction, which can depend on both the composition of the organic matter and the SO₄^2? concentration in the pore waters.     

Hydrocarbons generation potential of the Jurassic–Lower Cretaceous Formation, Ajeel field, Iraq

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 (T_max) 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 T_max 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.     

Generation and expulsion of oils from Permian coals of the Sydney Basin,Australia

Organic geochemical and petrological assessment of coals/coaly shales and fine grained sediments, coupled with organic geochemical analyses of oil samples, all from Permo–Triassic sections of the Southern Sydney Basin (Australia), have enabled identification of the source for the widely distributed oil shows and oil seeps in this region. The Permian coals have higher hydrogen indices, higher liptinite contents, and much higher total organic matter extract yields than the fine grained sediments. A variety of source specific parameters obtained from n-alkanes, regular isoprenoids, terpanes, steranes and diasteranes indicate that the oil shows and seeps were generated and expelled predominantly from higher plant derived organic matter deposited in oxic environments. The source and maturity related biomarkers and aromatic hydrocarbon distributions of the oils are similar to those of the coals. The oil-coal relationship also is demonstrated by similarities in the carbon isotopic composition of the total oils, coal extracts, and their individual n-alkanes. Extracts from the Permo–Triassic fine grained sediments, on the other hand, have organic geochemical signatures indicative of mixed terrestrial and prokaryotic organic matter deposited in suboxic environments, which are significantly different from both the oils and coal extracts. The molecular signatures indicating the presence of prokaryotic organic matter in some of the coal extracts and oils may be due to thin sections of possibly calcareous lithologies interbedded within the coal measures. The genetic relationship between the oils and coals provides new evidence for the generation and expulsion of oils from the Permian coals and raises the possibility for commercial oil accumulations in the Permian and Early Triassic sandstones, potentially in the deeper offshore part of the Sydney Basin.     

北部湾盆地流二段油页岩地球化学特征及成因

北部湾盆地涠西南凹陷和乌石凹陷流二段普遍发育油页岩。有机地球化学分析表明,北部湾盆地流二段油页岩具有高的有机质丰度,油页岩的有机碳含量下限为3%,含油率介于3.5%~10%,达到中等和优质油页岩矿品级,同时属于优质烃源岩。全岩有机显微组分、干酪根镜检和热解等分析表明,北部湾盆地流二段油页岩藻类含量丰富,藻类是有机质的主要来源,有机质类型主要为腐殖—腐泥型,部分为腐泥型,以湖相腐殖—腐泥型油页岩为主,部分为湖相腐泥型油页岩。流二段油页岩中镍和钼等微量元素含量普遍较高,镍和钼的含量与有机碳含量之间存在很好的正相关关系,说明流二段油页岩形成时期北部湾盆地具有富营养湖泊特征。北部湾盆地流二段油页岩中还原硫含量高,普遍大于1%,流二段油页岩形成于还原的沉积环境,具有很好的有机质保存条件。高有机质生产力及湖侵体系域顶部和高位体系域底部的中深湖还原环境共同控制了北部湾盆地流二段油页岩的发育。     

Controls of oil family distribution and composition in nonmarine petroleum systems: A case study from Inner Mongolia Erlian basin,Northern China

The Erlian basin is a continental rift basin located in Inner Mongolia, Northern China. It is a typical representative of Cretaceous Northeast Asian Rift System, which includes many small petroliferous basins in Mongolia Republic and Northern China. Although Lower Cretaceous source rocks are understood to be most important in the Erlian petroleum systems, the precise identification of these source rock intervals and their determination on oil families distribution and composition are poorly understood in this tectonically complicated, nonmarine basin. New bulk data have been gathered from source rock intervals, oil sands and crude oil samples in eight main oil-producing subbasins. Geochemical analyses indicate that Lower Cretaceous Aershan formation (K₁ba) and Tengger 1 formation (K₁bt₁) are two main source intervals in the Erlian basin and their source rock facies vary from profundal lacustrine to marginal lacustrine according to biomarker and trace elements calibration, the profundal lacustrine facies is characterised by brackish water and anoxic environment, which is similar to their correlative oils (Family 1 oils). The marginal lacustrine facies is characterised by freshwater and suboxic environment, which sourced the most common Family 2 oils. Meanwhile, different maturation processes exercise the second control on oil groups and their compositions, the profundal lacustrine source rocks characterised by their sulphur-rich kerogens lead to two oil groups (group 1 and group 2 oils), whose maturity range from low to normal; while, the marginal lacustrine source rock only lead to normal-maturity oils. At last, biodegradation affected the composition of a certain oils and formed group 4 heavy oils. In addition, short migration distance in small subbasins made the contamination or fractionation less notable in the Erlian basin.     

西藏措勤盆地郎山组沉积特征及其石油地质条件

西藏措勤盆地的下白垩统郎山组是在海侵不断扩大背景下的前陆盆地碳酸盐浅海相沉积，主要沉积相类型有碳酸盐浅海、礁、水下浅滩、近岸碳酸盐潮下带、陆缘碎屑潮坪等，在革吉、洞措和色林错坳陷发育了巨厚的浅海泥晶灰岩，成为3个沉积中心。浅海相灰岩为主要的烃源岩，向沉积中心方向加厚，有机质类型以腐泥型为主；主要的储集空间和油气运移通道为裂缝；沉积相类型对孔隙的发育有一定的控制作用。该组中缺乏有利的区域盖层。但其中、下部的潮坪相泥岩、泥灰岩可形成局部较为有利的盖层。