川东北地区普光2井飞仙关组储层沥青地球化学特征及成因分析

根据储层中沥青的产状及类型、族组成、饱和烃色谱、生物标志化合物以及储层沥青反射率等,对普光2井飞仙关组储层固体沥青的地球化学特征及成因进行了详尽的剖析。研究结果表明,普光2井飞仙关组储层沥青为古油藏原油经裂解成气之后的残留物,属热演化的焦沥青。储层沥青的正构烷烃分布较为完整,碳数在C14~C30范围,没有受到明显的生物降解作用。Pr/Ph、Pr/nC17和Ph/nC18比值都小于1.0;OEP值1.25～1.43,CPI值0.98～1.19,无奇偶优势或偶奇优势;规则甾烷系列中C27化合物含量占优势,C27-C29规则甾烷呈不对称的“V”字型分布,甾烷异构化程度较低,明显低于异构化平衡值,认为是由于高、过成熟阶段S构型比R构型裂解速率更快的结果。飞一段、飞二段孕甾烷、升孕甾烷含量明显较飞三段高,可能是有机质生源或沉积环境性质上的不同所致。萜类化合物以五环萜烷为主,三环萜烷较为发育,其以C23三环萜烷为基峰,伽马蜡烷的含量较高。这些特征表明普光2井储层沥青主要来源于低等水生生物,有机质的热演化程度较高,主要处于高-过成熟阶段,有机母质形成于沉积水体咸度较高的海相沉积环境中。储层沥青中高含量25 降藿烷并非生物降解作用所致,而主要与源岩的热演化程度较高有关。     

普光气田及邻区碳酸盐储层沥青的分子地球化学研究

从普光气田及邻近地区二叠系和下三叠统15个含沥青碳酸盐储集岩样品分步提取了自由态油气组分和油气包裹体组分,并且应用限定体系(金管)热解实验获取了固体沥青热解组分.各组分进一步做色谱和色谱-质谱分析获取了生物标志物组成.分析结果表明,从油气包裹体组分、自由态油气组分至固体沥青热解组分,伽马蜡烷/C31升藿烷比值依次增高.同时油气包裹体组分 C23三环萜烷/(C23三环萜烷+C30藿烷)、C21/(C21+ΣC29)甾烷、C27重排甾烷/(C27重排甾烷+C27规则甾烷)、20S/(20R+20S) C29甾烷和αββ/(ααα+αββ) C29甾烷等成熟度指标与自由态组分相近,而明显高于固体沥青热解组分.根据分子指标,可以推断古油藏的原油来源于不同的烃源岩,早期充注的原油来源于下志留统烃源岩,具有较低的伽马蜡烷含量和较高的成熟度;晚期充注的原油来源于上二叠统烃源岩,具有较高的伽马蜡烷含量和较低的成熟度.固体沥青主要为晚期充注、来源于上二叠统烃源岩的原油裂解生气的产物     

川西北侏罗系沙溪庙组固体沥青包裹烃的释放及其地球化学意义

固体沥青分子结构中可能存在类似于沥青质的吸附包裹现象,其包裹烃组分属于成熟度较低条件下的产物,包含有早期的地球化学信息.选用 H2O2/CH3COOH 作为氧化体系对其进行轻度化学氧化降解释放其中的包裹烃,并结合有机地球化学研究手段对川西北下寺侏罗系沙溪庙组固体沥青进行研究.结果显示,该固体沥青可溶组分中烷烃类包括生物标志物基本未检测到,仅残留一些简单的芳烃化合物,很难提供有用的地球化学信息.而其包裹组分中检测到一系列偶碳数正构-1-链烯、正构烷烃和部分异构烷烃以及生物标志物等.包裹组分中 Ts/(Ts+Tm)比值为0.26, C29甾烷20S/(20S+20R)比值为0.43,均反映了固体沥青低成熟度的特征;规则甾烷相对含量 C29>C27>C28,显示弱的 C29优势,其中(C27+C28)占52.1%, C29占47.9%;正构烷烃的分布呈微弱偶碳数优势;固体沥青总碳同位素值为–21.5‰,显示强烈富集13C 的特征.分析表明,藻类等低等水生生物对源岩母质有重要贡献,但不能确定是否有陆生高等植物的输入,母源可能沉积于弱的还原环境.沙溪庙组固体沥青与该地区其他层位固体沥青、油砂和油苗可能有不同的来源.     

小太平山油砂油地球化学及生物降解特征

采用小太平山同一层位不同深度且连续的油砂样品,对油砂油的地球化学及生物降解特征进行分析。小太平山油砂油在生物降解作用下产生了丰富的25-降霍烷,常规藿烷和甾烷也发生了一系列变化。由于分子结构和稳定性不同,抗降解能力不同,C_(21)/C_(23)三环萜烷、伽马蜡烷/C_(30)藿烷、Ts/Tm、C_(30)重排藿烷/C_(30)藿烷值、αααC_(27)R/αααC_(29)R、C_(28)αααR/C_(29)αααR、C_(29)ααα20R/αββ20S、C_(29)ααα20R/αββ20R、C_(27)重排甾烷/(规则甾烷+重排甾烷)、常规藿烷异构体降解为25-降霍烷的比例,均反映出油砂油的生物降解程度随深度的增加而增大。小太平山油砂油随含水饱和度的增加降解程度增大,证实地层水有利于细菌类微生物的迁移、营养物质的传递,促进原油的生物降解及25-降霍烷的产生。     

准噶尔盆地车排子地区原油油源分析

车排子地区紧邻沙湾凹陷和四棵树凹陷,油源条件优越,具有多层系含油特点,前人对该区原油油源认识存在较大分歧.本次研究在研究区原油生物标志物分析基础上,结合金刚烷异构化指标和正构烷烃单体碳同位素分布,对车排子地区原油油源进行了分析.结果表明,车排子地区存在3类原油:(1)Ⅰ类原油为新近系沙湾组轻质油,表现为侏罗系来源特征,Pr/Ph比值大于2.0,原油碳同位素值偏重,δ13C值大于?28.0‰,姥鲛烷(Pr)、植烷(Ph)和三环萜烷含量较低,Pr/nC17和Ph/nC18比值小于0.3,不含β-胡萝卜烷,三环萜烷/藿烷比值分布在0.08～0.18之间,C24四环萜烷/C26三环萜烷比值分布在1.61～3.81之间,ααα20R规则甾烷具有C27和C29规则甾烷优势,呈C27>C28C28相似文献   

卡塔克隆起中1井储层沥青地球化学特征与成因

塔里木盆地海相原油的成因至今仍有争议,而对储层沥青的地球化学特征剖析,能为探索海相原油的成因提供依据。选取卡塔克隆起上的中1井不同层系储层沥青,详尽剖析了其地球化学特征。研究结果揭示,中1井储层沥青的Pr/Ph为1.14～1.39,CPI值 1.01～1.08,OEP值0.98～1.05,无奇偶优势或偶奇优势,伽玛蜡烷、C28甾烷丰度低,硫芴系列丰富。甾烷成熟度参数和Ts/(Ts+Tm)均指示中1井储层沥青处于成熟—高成熟热演化范畴。依据特征生物标志物的分布对沥青的成因示踪,中1井储层沥青与上奥陶统烃源岩有成因关系,而中1井储层沥青与塔东2井寒武系原油分子特征的迥异也佐证该认识。     

内蒙古突泉盆地突参1井原油地球化学特征与油源分析

在内蒙古突泉盆地牤牛海坳陷南部突参1井的1684.5~1698.2m深度段侏罗系万宝组发现轻质原油,揭示了该区较好的油气勘探新领域。对该井原油和主要烃源岩分子地球化学特征、族组分稳定C同位素等进行了分析认为,该原油为轻质高蜡原油,C31升藿烷、C29甾烷异构化等成熟度参数显示该原油为成熟原油。正构烷烃呈单峰前峰型,姥鲛烷较植烷占绝对优势(Pr/Ph2.5),C29规则甾烷含量远高于C27甾烷,伽马蜡烷含量低,表明该原油生烃母质形成于以陆源高等植物为主的偏氧化沉积环境,原油来自该区侏罗系万宝组煤系泥岩。     

东营凹陷生物降解稠油甾烷分子的选择蚀变

为分析生物降解原油中甾烷生物标志物分子发生选择性蚀变的先后顺序及生物降解作用对甾烷分子成熟度参数的影响,在渤海湾盆地东营凹陷广饶潜山油藏选择了发生不同程度生物降解作用的原油,利用色谱质谱(GC-MS)仪对其中甾烷进行了定量测试分析和对比。结果发现在生物降解过程中,不同级别的生物降解作用对甾烷具有不同程度的影响:6级以下的生物降解作用对甾烷的降解能力有限,甾烷及其相关化合物比值没有可以识别的改变;6级以上的严重生物降解作用会对甾烷生物标志物的相关参数产生显著的影响。在严重生物降解原油中(级别≥6):甾烷系列被降解和蚀耗的先后顺序为,ααα20R>αββ20R>αββ20S≥ααα20S,C27>C29>C28,规则甾烷优先于重排甾烷发生降解,C27,C28,C29甾烷优先于C20,C21甾烷发生降解;甾烷生物标志物分子参数C2920S/(20S+20R),C29ββ/(ββ+αα)会发生显著升高,不能真实反映成熟度大小。研究结果为正确评价生物降解原油的成熟度及甾烷生物标志物分子的选择性蚀变提供了新的科学依据。     

极端生物降解沥青中8,14- 开环藿烷系列及其地球化学意义

借助色谱- 质谱（GC- MS）和色谱- 质谱- 质谱（GC- MS- MS）分析,对黔南坳陷凯里残余油藏凯棠和洛棉剖面上储层沥青中的烃类组成进行了系统分析,以判断其所遭受生物降解作用的程度,探寻在极端降解原油中是否还存在原生生物标志物,为这类原油的油源研究开拓新的途径和方法。结果表明：凯棠剖面上的储层沥青中尽管仍可检测到较为完整的C19- 30三环萜烷和C27- 35藿烷系列,但C19- 29脱甲基三环萜烷系列和C26- 34 25- 降藿烷系列丰富而完整,甾烷系列中C21- 22低分子量甾烷和重排甾烷优势明显,这一系列特征表明这些沥青遭受了剧烈生物降解作用的改造。但三芳甾类仍保存完好,依据原油生物降解程度的评判标准,判断其生物降解级别介于8~9级之间。洛棉剖面上的储层沥青中藿烷系列基本消失殆尽,三环萜烷系列及其脱甲基产物和25- 降藿烷系列的分布因极端生物降解作用而发生显著变异,某些化合物如C23T、C24T、C23NTE和C28- 29NH成为优势成员;甾烷系列中C21- 22低分子量甾烷占绝对优势,三芳甾类完全消失,据此判断该剖面上沥青的生物降解级别已达到10级或更严重。由于这两个剖面上的沥青遭受了极端生物降解作用的改造,常用的甾、萜类生物标志物完全失去了实用价值。但是,在所分析的这些沥青中都检测到三个系列的C27- 35 8,14- 开环藿烷系列,它们与塔里木盆地塔中地区海相端元油中存在的同类标志物的分布特征相似。正常海相端元油和极端生物降解沥青中同时检测到这三个系列的8,14- 开环藿烷,这一事实表明这类生物标志物在成因上具有原生性,而与生物降解作用无关。此外,在极端生物降解作用沥青中的完好保存,表明它们具有极强的抗生物降解能力,因而它们在此类原油的油源研究中可能具有潜在的实用价值。     

川东南地区海相下组合烃源岩及储层沥青地化特征

为了进一步明确川东南海相下组合烃源岩地化特征、理清源-藏对比关系,支撑下步的勘探部署,通过采集野外样品,利用色谱/色谱-质谱等分析方法,对川东南地区海相下组合(震旦系-志留系)烃源岩及储层沥青地化特征开展分析。研究表明:①海相下组合烃源岩按沉积相类型可划分为浅水相、深水陆棚相及过渡相三种类型;②三环萜烷及藿烷含量、C27～C29规则甾烷构型可作为海相下组合油气源对比的主要地化参数指标;③野外灯影组及石牛栏组储层沥青分别来源于浅水相寒武系牛蹄塘组及志留系龙马溪组烃源岩供给,明心寺组储层沥青来源具有混源特征。     

Geochemical constraints on mixed source and hydrocarbon filling process in the Yingjisu Sag,Tarim Basin,Xinjiang

The Yingjisu Sag was petroliferous for normal oil, condensate oil, reservoir bitumen and natural gases. Geochemical studies showed that natural gases in the Yingjisu Sag were a gas mixture consisting mainly of Cambrian pyrolysis gas, Jurassic condensate oil in well Yingnan 2 and normal oil in well Tadong 2, reflecting the characteristics of marine-phase gases and oils, while crude oils in well Longkou 1 demonstrated the characteristics of both marine and terrestrial oils, which were derived from lower algae and higher plants. Jurassic oils from wells Longkou 1 and Huayingcan 1 and Cambrian crude oils from well Tadong 2 were derived mainly from Cambrian-Lower Ordovician source rocks. Jurassic and Silurian reservoir bitumens from well Yingnan 2 were biodegradated, suggesting they are of marine and terrestrial origins. The bitumens have similar geochemical characteristics, which are correlated well with Ordovician crude oils from well Tadong 2 and Jurassic condensate oil from well Yingnan 2. Based on the characteristics of tectonic evolution in this area and the analysis of hydrocarbon accumulation, the constraints on the mixed source and hydrocarbon filling process in the Yingjisu Sag were brought forward.     

四川盆地东北部气田海相碳酸盐岩储层固体沥青研究

川东北地区海相碳酸盐岩生物礁滩相储层中普遍存在着固体沥青.本文以普光气田上二叠统长兴组和下三叠统飞仙关组储层中固体沥青为研究对象,在显微镜下观察固体沥青的产状特征,测定固体沥青含量和计算固体沥青与储层孔隙的体积比率,分析固体沥青的成因及形成期次,推算古油藏的密度.普光气田飞仙关组固体沥青主要呈环边状附于鲕粒白云岩、残余鲕粒白云岩晶间溶孔,溶蚀孔壁,沥青含量在1.11%～5.73%之间,均值2.92%;长兴组生物礁储层固体沥青多呈团块状充填于各种溶蚀孔洞中,沥青含量0.31%～11.72%之间,均值3.57%.两套储层中的固体沥青含量都有随埋深而减少的趋势.飞仙关组储层中固体沥青与储层孔隙的体积比约为22%,长兴组为43%～56%.普光气田储层固体沥青为热演化成因并为两期形成,飞仙关储层固体沥青为轻质油古油藏裂解形成,长兴组储层固体沥青为稠油古油藏裂解形成.     

Source Rocks for the Giant Puguang Gas Field, Sichuan Basin: Implication for Petroleum Exploration in Marine Sequences in South China

Detailed geochemistry studies were conducted to investigate the origin of solid bitumens and hydrocarbon gases in the giant Puguang gas field. Two types of solid bitumens were recognized: low sulfur content, low reflectance (LSLR) solid bitumens in sandstone reservoirs in the Xujiahe Formation and high sulfur content, high reflectance (HSHR) solid bitumens in the carbonate reservoirs in the Lower Triassic Feixianguan and Upper Permian Changxing formations. Solid bitumens in the Upper Triassic Xujiahe Formation correlate well with extracts from the Upper Triassic to Jurassic nonmarine source rocks in isotopic composition of the saturated and aromatic fractions and biomarker distribution. Solid bitumens in the Feixianguan and Changxing formations are distinctly different from extracts from the Cambrian and Silurian rocks but display reasonable correlation with extracts from the Upper Permian source rocks both in isotopic composition of the saturated and aromatic fractions and in biomarker distribution, suggesting that the Permian especially the Upper Permian Longtan Formation was the main source of solid bitumens in the carbonate reservoirs in the Feixianguan and Changxing formations in the Puguang gas field. Chemical and isotopic composition of natural gases indicates that the majority of hydrocarbon gases originated from sapropelic organic matter and was the products of thermal cracking of accumulated oils. This study indicates that source rock dominated by sapropelic organic matter existed in the Upper Permian and had made major contribution to the giant Puguang gas field, which has important implication for petroleum exploration in marine sequences in South China.     

Source Rocks for the Giant Puguang Gas Field,Sichuan Basin:Implication for Petroleum Exploration in Marine Sequences in South China

Detailed geochemistry studies were conducted to investigate the origin of solid bitumens and hydrocarbon gases in the giant Puguang gas field. Two types of solid bitumens were recognized： low sulfur content, low reflectance （LSLR） solid bitumens in sandstone reservoirs in the Xujiahe Formation and high sulfur content, high reflectance （HSHR） solid bitumens in the carbonate reservoirs in the Lower Triassic Feixianguan and Upper Permian Changxing formations. Solid bitumens in the Upper Triassic Xujiahe Formation correlate well with extracts from the Upper Triassic to Jurassic nonmarine source rocks in isotopic composition of the saturated and aromatic fractions and biomarker distribution. Solid bitumens in the Feixianguan and Changxing formations are distinctly different from extracts from the Cambrian and Silurian rocks but display reasonable correlation with extracts from the Upper Permian source rocks both in isotopic composition of the saturated and aromatic fractions and in biomarker distribution, suggesting that the Permian especially the Upper Permian Longtan Formation was the main source of solid bitumens in the carbonate reservoirs in the Feixianguan and Changxing formations in the Puguang gas field. Chemical and isotopic composition of natural gases indicates that the majority of hydrocarbon gases originated from sapropelic organic matter and was the products of thermal cracking of accumulated oils. This study indicates that source rock dominated by sapropelic organic matter existed in the Upper Permian and had made major contribution to the giant Puguang gas field, which has important implication for petroleum exploration in marine sequences in South China.     

四川盆地东北部海、陆相储层沥青组成特征及来源

本研究系统采集了四川盆地东北部大普光、元坝地区上三叠统须家河组、下三叠统飞仙关组、上二叠统长兴组和鄂西渝东地区中石炭统黄龙组储层固体沥青样品,进行了岩石热解、有机元素、碳同位素和饱和烃、芳烃组分GC/MS的分析,以确定其成因、性质和来源。这些沥青总体上具有低溶性(多数氯仿抽提物/TOC<8%)、高反射率(换算的Ro>1.4%)、低H/C原子比(<0.6)的性质,属焦沥青类,是古油藏原油或运移烃经热裂解成气的残留物。其中,飞仙关组、长兴组碳酸岩储层沥青的S/C原子比值普遍较高(主要在0.025~0.085范围),且硫同位素δ³⁴S值(主要在12‰~24‰)接近硬石膏,说明可能包含有部分TSR成因的沥青。这些高热演化沥青中饱和烃生物标志物的组成和分布出现了异常变化,基本失去了其常规应用意义。芳烃中2,6-/2,10-DMP(二甲基菲)、1,7-/1,9-DMP和4-/1-MDBT(甲基二苯并噻吩)比值,可用来指示沥青烃源岩的有机质生源构成和沉积环境性质。须家河组陆相沥青中这些芳烃比值较高,表征其烃源母质中陆源有机质占优势,且形成于氧化性的环境;而飞仙关组、长兴组及黄龙组海相沥青中这些参数值低得多,意味着其烃源岩有机质生源应以水生生物为主,并沉积于还原性环境。经沥青/烃源岩的碳同位素和二苯并噻吩系列组成对比,认为须家河组储层沥青来源于本层位烃源岩,飞仙关组和长兴组沥青同源于二叠系烃源层。鄂西渝东地区的黄龙组沥青碳同位素偏重(δ¹³C值为-23.2‰~-26.4‰),原始烃源可能主要来自中、下志留统韩家店组及小河坝组地层。     

Geochemical characteristics and origin of reservoir bitumens from Well Zhong 1 in the Katake Uplift,Tarim Basin

The source of marine crude oils from Tarim Basin is still disputed.However,research on the reservoir bitumens may provide a piece of new evidence to elucidate oil source.Geochemical characteristics of reservoir bitumens from different strata from Well Zhong 1 in the Katake Uplift were discussed here in detail.Pr/Ph ratios of reservoir bitumen from Well Zhong 1 range from 1.14 to 1.39,CPI ratios from 1.01 to 1.08,which indicates no odd-even predominance of normal alkanes,with OEP ratios ranging from 0.98 to 1.05.The contents of gammacerane and C28 sterane of reservoir bitumen from Well Zhong 1 are low,while dibenzothiophene series are abundant.Ster-ane isomerization maturity parameter and Ts/(Ts+Tm) ratio indicate that the reservoir bitumen from Well Zhong1 is mature to highly mature.Based on the differences in biomarker distribution,it is concluded that reservoir bitumen from Well Zhong 1,of which molecular parameters are contrary to those in Cambrian oil from Well Tadong 2,origi-nated from the Upper Ordovician source rocks.     

Solid bitumens: an assessment of their characteristics, genesis, and role in geological processes

Familiar since antiquity, and subject in contemporary times to various characterization schemes, the exact nature of solid bitumen is not yet fully known. Bitumens have ‘random polymer-like’ molecular structures, are mobile as highly viscous fluids or were once fluids but have since turned into solids. Solid bitumens consist mainly of large moieties, of polyclyclic aromatic hydrocarbons, occasionally with finely admixed, fine-grained cryptocrystalline graphite. Solid bitumens are distinguished from kerogen, which is the syngenetic and generally finely dispersed particulate organic matter in sedimentary rock that virtually does not migrate following its deposition. Occurrences of solid bitumens are relevant to petroleum exploration as well as the search for, and evaluation of, a variety of metallic mineral deposits. Genesis of bitumen is in many cases linked to the thermal and hydrothermal history of organic matter in sedimentary rock. Apparently bitumen, or more specifically organic acids generated along with bitumen during diagenesis, may alter porosity of reservoir rocks or otherwise prepare the ground for ore deposition. Bitumen is also relatively sensitive to alteration processes, some of which, such as oxidative weathering, water leaching, biodegradation (contact) metamorphism and ionizing radiation may likewise affect its nature. Elemental composition of bitumen commonly reflects the nature of mineral deposits. Is is possible that in petroleum exploration, trace metal abundances of bitumen may eventually allow prediction of crude oil types and volumes anticipated from a given source rock? Beside transition elements, notably Ni and V, highly anomalous concentrations of U, Pt and Au occur in some solid bitumens. During the generation of petroleum from kerogen, the trend in δ¹³C is toward lighter values. The opposite seems to occur when liquid petroleum is subjected to thermal cracking (and /or related processes) yielding solid bitumen enriched in ¹³C, and isotopically light methane. In fact, except for deasphalting and possibly some irradiation processes, the result of thermal cracking, oxidation, water leaching, inspissation (drying) and bacterial degradation of crude oil is that lower molecular weight hydrocarbons are removed leaving bitumen residues enriched in aromatic hydrocarbons, heteroatomic compounds (NSO) and ¹³C. Such phenomena are relevant to bitumen paragenesis in petroleum reservoir rocks, to certain Phanerozoic occurrences of multiple generations of bitumens, and to bitumens in mineral deposits.     

Occurrence and composition of solid bitumens from the Bulonggoer Devonian paleo-oil reservoir,North Xinjiang,China

The Bulonggoer paleo-oil reservoir (BPR) on the northwest Junggar Basin is the first Devonian paleo-oil reservoir discovered in North Xinjiang, China. Solid bitumens occur within sandstone pores and as veins filling fractures. Samples of both types were analyzed using stable carbon isotope and reflectance measurements, as well as molecular biomarker parameters.The extremely positive δ¹³C values and biomarker indicators of depositional environment/lithology, such as pristane/phytane (Pr/Ph), C₂₉/C₃₀ hopane, diasteranes/regular steranes and dibenzothiophene/phenanthrene ratios, indicate a siliciclastic source for the BPR and their deposition in a highly reducing hypersaline environment. The presence of long chain n-alkanes and abundant tetracyclic diterpanes, C₂₀–C₂₁ tricyclic terpanes and perylene are indicators of higher plant organic matter input. Moreover, the bimodal distribution of C₂₇ > C₂₈ < C₂₉ regular steranes and abundant methyltriaromatic steroids also support a contribution of microalgae as well as higher plants organic matter. The similar molecular composition and thermal maturity parameters indicate that the reservoir and veined solid bitumens were altered from a common paleo-petroleum, which originated from peak oil window matured source rocks.All solid bitumens from the BPR are characterized by relatively low bitumen reflectance values (Rb% < 0.7), suggesting that they were generated from low temperature processes rather than oil thermal cracking. Comparatively, the Rb% values for veined bitumens are higher than reservoir bitumens, indicating that the veined bitumens occurred earlier and experienced higher thermal conditions.     

Source Rock Characterization and Petroleum Systems in North Ghadames Basin,Southern Tunisia

This paper presents geochemical analysis of drilled cutting samples from the OMZ‐2 oil well located in southern Tunisia. A total of 35 drill‐cutting samples were analyzed for Rock‐Eval pyrolysis, total organic carbon (TOC), bitumens extraction and liquid chromatography. Most of the Ordovician, Silurian and Triassic samples contained high TOC contents, ranging from 1.00 to 4.75% with an average value of 2.07%. The amount of hydrocarbon yield (pyrolysable hydrocarbon: S2b) expelled during pyrolysis indicates a good generative potential of the source rocks. The plot of TOC versus S2b, indicates a good to very good generative potential for organic matter in the Ordovician, Silurian and Lower Triassic. However, the Upper Triassic and the Lower Jurassic samples indicate fair to good generative potential. From the Vankrevelen diagram, the organic matter in the Ordovician, Silurian and Lower Triassic samples is mainly of type II kerogen and the organic matter from the Upper Triassic and the Lower Jurassic is dominantly type III kerogen with minor contributions from Type I. The thermal maturity of the organic matter in the analyzed samples is also evaluated based on the T_max of the S2b peak. The Ordovician and Lower Silurian formations are thermally matured. The Upper Silurian and Triassic deposits are early matured to matured. However, Jurassic formations are low in thermal maturity. The total bitumen extracts increase with depth from the interval 1800–3000 m. This enrichment indicates that the trapping in situ in the source rocks and relatively short distance vertical migration can be envisaged in the overlying reservoirs. During the vertical migration from source rocks to the reservoirs, these hydrocarbons are probably affected by natural choromatography and in lower proportion by biodegradation.