四川盆地北缘灯影组深埋白云岩优质储层形成与保存机制

叠合盆地深埋碳酸盐岩优质储层的形成和保存机理是一个复杂而又有争议的议题。大量的地质地球化学证据表明,四川盆地北缘灯影组深埋白云岩在灯四段和灯二段末期先后发生了两期古岩溶作用,在灯影组内形成了大小不等的晶洞和次生孔隙。在后期的深埋-隆升过程中,表生期的岩溶孔洞被不同世代的矿物充填,先存的孔洞被不同程度的改造和破坏,随埋藏深度的增加先存孔洞的体积变小;同时CO2、有机酸、H2S和多期外来酸性热液流体的溶蚀改造又形成了部分新的次生孔洞;油气藏主要赋存于残余的表生岩溶孔洞和新生次生溶孔内。研究表明,灯影组深埋白云岩优质储层的形成和保存不仅受表生岩溶作用、古岩溶地貌和沉积微相的影响和控制,而且还受深埋隆升过程中多期流体充注、溶蚀-沉淀和石油热裂解的复合控制。其中,表生岩溶作用是影响优质储层形成的最为关键性因素,古岩溶地貌和沉积微相控制了优质储层的时空分布,表生岩溶作用影响的深度最深达500m左右。多期侵蚀性流体的溶蚀和石油热裂解所引起的超压使先存表生岩溶孔洞能得以保存。     

Modeling of gas generation from the Alam El-Bueib formation in the Shoushan Basin, northern Western Desert of Egypt

The Shoushan Basin is an important hydrocarbon province in the northern Western Desert, Egypt, but the burial/thermal histories for most of the source rocks in the basin have not been assigned yet. In this study, subsurface samples from selected wells were collected to characterize the source rocks of Alam El-Bueib Formation and to study thermal history in the Shoushan Basin. The Lower Cretaceous Alam El-Bueib Formation is widespread in the Shoushan Basin, which is composed mainly of shales and sandstones with minor carbonate rocks deposited in a marine environment. The gas generative potential of the Lower Cretaceous Alam El-Bueib Formation in the Shoushan Basin was evaluated by Rock–Eval pyrolysis. Most samples contain sufficient type III organic matter to be considered gas prone. Vitrinite reflectance was measured at eight stratigraphic levels (Jurassic–Cretaceous). Vitrinite reflectance profiles show a general increase of vitrinite reflectance with depth. Vitrinite reflectance values of Alam El-Bueib Formation range between 0.70 and 0.87 VRr %, indicating a thermal maturity level sufficient for hydrocarbon generation. Thermal maturity and burial histories models predict that the Alam El-Bueib source rock entered the mid-mature stage for hydrocarbon generation in the Tertiary. These models indicate that the onset of gas generation from the Alam El-Bueib source rock began in the Paleocene (60 Ma), and the maximum volume of gas generation occurred during the Pliocene (3–2 Ma).     

Source rock characterization and hydrocarbon generation modeling of the Middle to Late Eocene Mangahewa Formation in Taranaki Basin,New Zealand

The Middle to Late Eocene Mangahewa Formation of Taranaki Basin, New Zealand, has been evaluated in terms of organic matter abundance, type, thermal maturity, burial history, and hydrocarbon generation potential. Mangahewa Formation reflects the deposition of marine, marginal marine, shallow marine, and terrestrial strata due to alternative transgressive and regressive episodes in Taranaki Basin. The sediments of the Mangahewa Formation contain type II (oil prone), types II–III (oil-gas prone), and type III kerogens (gas prone), with hydrogen index values ranging from 58 to 490 mg HC/g total organic content (TOC). Vitrinite reflectance data ranging between 0.55 and 0.8 %R_o shows that the Mangahewa Formation is ranging from immature to mostly mature stages for hydrocarbon generation. Burial history and hydrocarbon generation modeling have been applied for two wells in the study area. The models have been interpreted that Mangahewa Formation generated oil in the Mid Miocene and gas during Middle to Late Miocene times. Interpretations of the burial models confirm that hydrocarbons of Mangahewa Formation have not yet attained peak generation and are still being expelled from the source rock to present.     

渤海盆地辽东湾地区古近系烃源岩成熟演化模拟

古近系是辽东湾地区的主力烃源岩层系, 包括孔店组(Ek)-沙河街组四段(Es⁴)、沙河街组三段(Es³)、沙河街组一、二段(Es1-2)、东营组三段(Ed³)4套烃源岩, 它们主要分布在该地区的3个凹陷(辽西、辽中和辽东)的各个次洼中。在沉积和构造发育史的基础上, 结合烃源岩地球化学和热史等参数对烃源岩成熟演化进行模拟。对辽中凹陷各洼陷典型井区的烃源岩演化模拟表明辽中凹陷不同洼陷内各烃源岩层系的成熟演化历史存在明显差异:在东营组沉积末期,Es⁴-Ek烃源岩普遍进入生油门限,现今,基本上处于高-过成熟阶段;在馆陶组沉积末期,Es³和Es^-2烃源岩普遍进入生油门限,Ed³烃源岩部分进入生油门限,现今,Es³和Es^-2烃源岩在辽中凹陷的部分地区达到生油高峰期。同时, 利用Basinview软件模拟了辽东湾地区古近系4套烃源岩的成熟演化历史, 表明在盆地演化过程中同一套烃源岩在辽东湾地区不同凹陷进入生油门限和达到生油高峰及生气阶段的时间存在差异。研究成果可以为该地区深凹区的烃源岩预测与评价和计算烃源岩体积、生、排烃量等提供重要参数,这对指导该地区的油气资源勘探具有重要意义。      

雪峰山隆起北缘热历史及其对牛蹄塘组生烃作用的影响

对于复杂构造带的古老- 深层页岩，烃类的生成过程可能是多阶段的。准确恢复页岩的成熟演化过程是研究页岩气富集机理的先决条件。本文依托雪峰山隆起北缘新钻探的地质调查井，恢复雪峰山北缘古生代以来的热历史，从热演化的角度讨论牛蹄塘组页岩的生烃潜力。元素分析显示，热液活动对牛蹄塘组黑色页岩有机质的富集产生了积极影响，特别是下部页岩热液指示指标异常高、显著的Ce负异常、Eu正异常和Y正异常，都证明了牛蹄塘组早期受热液作用的影响。古温标联合反演结果显示，雪峰山北缘自古生代以来先后经历了三次升温—降温过程。三次热演化高峰依次出现在晚奥陶世末期、中三叠世末期和早白垩世末期，所达到的最高温度依次降低。三次升温过程分别受到早古生代拉张作用和岩浆活动、晚古生代—早中生代快速沉降作用和早白垩世岩浆活动的控制。受沉积埋藏作用和早期热事件的影响，牛蹄塘组页岩在寒武纪—早志留世快速经历了生油高峰、原油裂解高峰等生烃关键时期，在晚奥陶世达到过成熟阶段。随后第一次的抬升剥蚀作用，破坏了页岩及上覆盖层的封闭性，形成有利于气体扩散的裂缝或断层通道，使得早期形成的烃类散失。     

雅布赖盆地萨尔台凹陷侏罗系新河组有效烃源岩研究

对雅布赖盆地萨尔台凹陷侏罗系新河组有效烃源岩进行有机质下限分析,识别有效烃源岩分布范围,并分析有效烃源岩下限值与成熟度的关系。本文据烃源岩生排烃机理,通过w（TOC）与热解参数w（S₁）之间的关系,确定了雅布赖盆地萨尔台凹陷新河组下段有效烃源岩w（TOC）下限值,其中盐场次凹有效烃源岩w（TOC）下限值为1.0%,小湖次凹w（TOC）下限值为0.7%,梭托次凹不具备排烃条件。利用△log R法计算新河组下段的页岩w（TOC）含量,识别并统计了单井有效烃源岩厚度,参照沉积相和地层厚度确定了有效烃源岩的分布特征,新河组下段有效烃源岩主要分布在小湖次凹中央洼槽带,累计厚度最大约600 m,盐场次凹有效烃源岩累计厚度基本小于100 m,梭托次凹不发育有效烃源岩。成熟度越大,有效烃源岩w（TOC）下限值越小     

A study of hydrocarbon generation and expulsion of the Nkporo Shales in Anambra Basin,Nigeria

This study is a contribution to our understanding of the hydrocarbon potentials of the Nkporo Shale in the Anambra Basin, Nigeria. The main objective was to simulate the hydrocarbon generation and expulsion in the Nkporo source horizons encountered in Igbariam-1, Iji-1, and Ajire-1 wells drilled in the basin, using the one-dimensional Genesis Zetaware basin modeling software. This software enabled the integration of burial and thermal influences on Nkporo source rocks with kinetic parameters, in order to define the timing of hydrocarbon generation and expulsion in relation to the main structural episodes in the basin. The Nkporo source horizons encountered in Igbariam-1 well (2,650 m) has not expelled hydrocarbons but has a remaining potential of 380 mg/gTOC. Conversely, in Iji-1 well (3,450 m) and Ajire-1 well (3,250 m), the Nkporo source rocks expelled oil of about 110–127 mg/gTOC and gas of about 85–125 mg/gTOC. The time of expulsion was in Eocene–Oligocene (51–30 My) at the rate of 10.5–11.5 mg/gTOC/My. The remaining potentials for Nkporo source rocks in Iji-1 and Ajire-1 wells are 160 and 125 mg/gTOC, respectively. The result shows an increasing trend in maturation, generation, and expulsion of hydrocarbons with increasing depth towards the southwestern part of the basin. This resulted in an increase in the generated hydrocarbon volumes to the south due to (a) increased burial depth and early maturation and (b) changing source lithofacies—more marine. The fault system linking potential reservoirs such as Owelli Sandstone to the source rock suggests a possible migration of the generated hydrocarbons to those reservoirs at that time.     

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale,China

High maturity oil and gas are usually generated after primary oil expulsion from source rocks, especially from oil prone type I/II kerogen. However, the detailed impacts of oil expulsion, or retention in source rock on further thermal degradation of kerogen at the high maturity stage remain unknown. In the present study, we collected an Ordovician Pingliang shale sample containing type II kerogen. The kerogens, which had previously generated and expelled oil and those which had not, were prepared and pyrolyzed in a closed system, to observe oil expulsion or oil retention effects on later oil and gas generation from kerogen. The results show that oil expulsion and retention strongly impacts on further oil and gas generation in terms of both the amount and composition in the high maturity stage. Gas production will be reduced by 50% when the expulsion coefficient reaches 58%, and gas from oil-expelled kerogen (less oil retained) is much drier than that from fresh kerogen. The oil expulsion also causes n-alkanes and gas compounds to have heavier carbon isotopic compositions at high maturity stages. The enrichment of ¹³C in n-alkanes and gas hydrocarbons are 1‰ and 4–6‰ respectively, compared to fresh kerogen. Oil expulsion may act as open system opposite to the oil retention that influences the data pattern in crossplots of δ¹³C₂–δ¹³C₃ versus C₂/C₃, δ¹³C₂–δ¹³C₃ versus δ¹³C₁ and δ¹³C₁–δ¹³C₂ versus ln(C₁/C₂), which are widely used for identification of gas from kerogen cracking or oil cracking. These results suggest that the reserve estimation and gas/source correlation in deep burial basins should consider the proportion of oil retention to oil expulsion the source rocks have experienced.     

The application of chromatographic gas ratio analysis in reservoir fluid evaluation of “Beta” field in the Congo basin

This study assessed the hydrocarbon generation potentials/timing of the Awgu source rock horizons encountered in Igbariam-1, Iji-1 and Ajire-1 wells drilled in the southern Benue Trough; using one-dimensional (1D) Genesis Zetaware basin modelling software. This software enabled the integration of burial and thermal influences on Awgu source rocks with kinetic parameters. Thermal and burial history models indicate that the Awgu source horizons encountered at 3249m in Igbariam-1 well (northern part of the basin), expelled 85mg/gtoc of oil and 12 mg/gtoc of gas and hydrocarbon generation began in early Eocene with maximum expulsion in the mid-Eocene (52my) at the rate of 7mg/gtoc/my. To the south of the basin, the Awgu source horizons were encountered at greater depths in Iji-1 and Ajire-1 wells and hydrocarbon generation began in the mid-Palaeocene and peaked in the late Palaeocene (58my) at the rate of 32–38mg/gtoc/my. This resulted in an increase in generated hydrocarbon volume to the south due to (a) increased burial depth and early maturation, and (b) changing source lithofacies -more marine. The fault system linking potential reservoirs such as the Agbani sandstone and the overlying Owelli sandstone to the source rock suggests a possible migration of the generated hydrocarbons to those reservoirs at that time.     

Thermal maturity in the Central European Basin system (Schleswig-Holstein area): results of 1D basin modelling and new maturity maps

Thermal maturity information has been compiled for one of the deepest parts of the Central European Basin system, the Schleswig-Holstein area in northern Germany. New vitrinite reflectance data were obtained and old data were evaluated from a total of 31 wells. Furthermore, numerical 1D basin modelling was performed in order to interpolate/extrapolate vitrinite reflectance data to base Zechstein and base Keuper. For these two horizons, maturity maps were finally compiled revealing large differences in present-day thermal maturity within the basin. For example, vitrinite reflectance at base Zechstein ranges from greater than 4.5% in the Glueckstadt Graben to less than 1% in the northern part of the study area. Highest thermal maturity of base Keuper occurs in the West Holstein Trough and in the northern part of the Glueckstadt Graben. The timing of maturation is greatly affected by the complex tectonic evolution of the area. For six key wells distributed over the entire study area, burial and temperature histories as well as evolution of maturity were evaluated using 1D basin modelling. Deepest burial and maximum temperatures occurred either during Jurassic, Upper Cretaceous or Neogene times in these wells. Only some parts of the sedimentary package in Schleswig-Holstein show a significant increase in maturity during the Tertiary leading to additional hydrocarbon generation and entrapment.     

川西南地区下寒武统筇竹寺组页岩热演化史及页岩气成藏意义

页岩热演化史与页岩气的成烃、成藏过程关系极为密切.一方面,页岩热演化过程决定了页岩生烃过程、页岩气类型和生气量;另一方面,页岩有机孔隙的形成与页岩热演化过程密切相关.在前期热史恢复基础上,以锆石（U-Th）/He和沥青反射率R_b等古温标进行标定,模拟了川西南地区代表性钻孔下寒武统筇竹寺组页岩热演化史,探讨了页岩热演化过程与页岩气成烃、成藏的关系.研究结果表明,川西南地区下寒武统筇竹寺组页岩热演化过程和生烃史差异性明显,可以识别出两种模式:加里东期坳陷区,筇竹寺组页岩在加里东期成熟,中?晚二叠世期间快速演化定型,两个生烃高峰期分别出现在志留纪（生油高峰?湿气阶段）、中?晚二叠世（干气阶段）,此后再无明显的生烃活动;加里东期古隆起区,筇竹寺组页岩在加里东期未熟?低熟,晚海西期?燕山期持续增熟,亦存在两期生烃高峰,分别是中?晚二叠世（生油高峰阶段）、晚侏罗世?早白垩世（湿气?干气阶段）,筇竹寺组页岩生烃过程持续到晚白垩世末期.分析表明中?晚二叠世期间筇竹寺组页岩的埋深差异造成了其受峨眉山地幔柱热效应的影响不同,进而决定了加里东期坳陷区与隆起区筇竹寺组页岩热演化过程和生烃史差异,并最终导致了威远?犍为地区筇竹寺组页岩含气性优于盆地外围.综合川西南地区筇竹寺页岩生烃史和孔隙度演化模型,将川西南成藏条件相对优越的威远?犍为地区筇竹寺组页岩气成藏过程分为4个阶段:早古生代时期源?储?盖形成和生物气成藏阶段、中?晚二叠世期间初始成藏阶段、晚侏罗世?早白垩世主成藏阶段和晚白垩世以后调整改造阶段.该成果以页岩热演化过程为切入点解释了川西南威远?犍为地区与盆地外围下寒武统筇竹寺组页岩气成藏差异的原因.      

海拉尔盆地呼和湖凹陷下白垩统烃源岩地球化学特征及热演化史

呼和湖凹陷下白垩统烃源岩生油条件好,油气资源潜力大.利用研究区7口钻井270个热解资料和125个镜质体反射率数据,分析了下白垩统烃源岩地球化学特征及热演化史.下白垩统烃源岩有机质类型主要为Ⅲ-Ⅱ2型干酪根,现今热演化程度具有中间高、四周低的特点.主力烃源岩层南屯组属于中等-好烃源岩,在约128 Ma进入生烃门限,现今处于高成熟-生气阶段.大磨拐河组属于差-中等烃源岩,在约124 Ma进入生烃门限,现今处于中等-低成熟阶段,大磨拐河组二段烃源岩至今未进入生烃高峰.热史模拟表明呼和湖凹陷在伊敏组沉积晚期达到最大古地温,地温演化具有先升高后降低的特点.从南屯组沉积至今,地温梯度先升高到50~55℃/km,后逐渐降低为现今的35.4℃/km.早白垩世以来较高的地温场对油气生成、成藏起控制作用.包裹体均一温度结合热演化史结果表明126~87 Ma（伊敏组沉积时期）应是呼和湖凹陷油气主成藏期.晚白垩世以来盆地发生抬升,温度降低,烃源岩生烃强度减弱.      

湖相富有机质泥质白云岩生排烃模拟及其对页岩油勘探的启示

富有机质湖相白云质泥岩、泥质白云岩及其贫有机质粉砂岩、白云岩夹层是我国陆相盆地页岩油勘探的重要领域,但目前针对湖相富有机质白云质泥岩或泥质白云岩在近地质条件下的生排烃一体化模拟研究尚属空白.以典型低熟富有机质泥质白云岩为例,开展了近地质条件下的生排烃一体化模拟实验,揭示了其呈现四阶段生排烃演化模式.结果表明,R_o ≤ 0.74%时为缓慢生油伴生烃气、排油能力有限阶段,0.74% < R_o ≤ 0.84%时为快速生油伴生烃气、排油能力逐渐增高阶段,0.84% < R_o ≤ 1.28%≈1.30%时为生烃气伴生油与油初始裂解、高效排油阶段,1.30% < R_o ≤ 2.00%时为油裂解烃气兼干酪根生烃气阶段;同时,R_o < 0.68%时滞留油主要以有机质吸附态赋存,而0.68% ≤ R_o ≤ 2.00%时滞留油主要以游离态赋存于矿物基质微-纳米级孔缝系统内.综合分析提出湖相泥质白云岩烃源层系有利页岩油勘探的成熟度范围为0.84%~1.30%.      

Hydrocarbon fluid inclusions and source rock parameters: A comparison from two dry wells in the western offshore,India

Fluid inclusions represent the direct evidence of paleofluids and can provide valuable information on the evolution of sedimentary basins and oil-bearing strata. Hydrocarbon fluid inclusion(s) (HCFIs) are the vestiges of oil from the geological formations. The paper delineates the paleotemperature (T_h)/ oil window, the oil quality of HCFIs and Raman peaks corresponding to hydrocarbon species of HCFIs using fluid inclusion techniques, and source rock potential of hydrocarbon generation, thermal maturity, the quantity of organic matter, and the kerogen types obtained through Rock-Eval pyrolysis data from two dry wells RV-1 well of Mumbai offshore and KKD-1A well of Kerala-Konkan Basin. The present study compares the fluid inclusion parameters as well as the source rock geochemical characteristics of these two dry wells to address the scientific problem of the wells going dry. Further, evaluated whether the results agree with an earlier finding from a case study of two wells named KK4C-Al (Kerala-Konkan basin) and RV-1 well where only a few parameters such as temperature of homogenization (T_h) & API gravity were utilised, and the chances of getting oil in the nearby areas of these two wells were reported. In the present study, the fluid inclusion parameters such as the palaeotemperature (T_h), API Gravity and Raman spectra were obtained from micron sized fluid inclusions at different depths for a quick assessment of nature of oil inclusions within the two dry wells. Along with fluid inclusion parameters, different source rock parameters obtained from Rock-Eval Pyrolysis analysis (secondary data) such as S1, S2, S3, T_max, Hydrogen Index (HI), Oxygen Index (OI), Potential Yield (PY), Production Index (PI) and Total Organic Carbon Content (TOC) were also considered for a detailed source-rock evaluation of two wells (RV-1 and KKD-1A) and the results act as the supporting evidence to address the reason for the wells gone dry.Temperature of homogenisation (T_h) of hydrocarbon Fluid Inclusion Assemblages (FIAs) from both the wells fall in the oil window (60–150 °C) range indicating that there was a conducive thermal condition favourable for oil generation in these two basins. API gravity of oils in RV-1 well of Mumbai offshore (48–53) was lighter when compared to those in KKD-1A (18–22) of Kerala-Konkan basin. Raman spectra of HCFI samples could decipher important hydrocarbon species from RV-1 well samples. Raman spectra of KKD-1A well show less prominent peaks (broad) only. Pyrolysis data shows that Paleocene–Early Eocene source rocks of Panna formation of RV1 well are mature enough to generate hydrocarbons. On the other hand, Paleocene aged source rocks of Kasargod formation of KKD-1A well are immature. Source rock maturity therefore could be considered as crucial in hydrocarbon generation in these two wells even if oil-window was achieved. This study reports that, in RV-1 well, even though it is a dry well in a proven basin, the oil window, API gravity of oils and constituents from HCFIs of RV-1 well and the source-rock maturity opens up a demand for detailed exploration in nearby areas of RV-1 in the Mumbai offshore basin hopeful of finding a high-value prospect for oil, whereas the fluid inclusion studies in the HCFIs of KKD-1A well of Kerala-Konkan basin is showing only a minimal chance of oil generation that too of a heavy nature and the source rock immature characteristics suggesting only minimal generation of hydrocarbons. Due to the heaviness of the available oil in the KKD-1A well impedes migration. Our study suggests that there is no potential for finding oil in the nearby areas of KKD-1A well of Kerala-Konkan basin.     

酒东盆地热演化史与油气关系研究

酒东盆地是由两期不同性质、不同世代盆地叠合而成。早、中侏罗世-早白垩世为拉张盆地,第三纪以来为挤压坳陷盆地。酒东盆地现今地温梯度及大地热流值较低,分别为300℃/100m及51mW/m2。营尔凹陷中生代晚期地温梯度高于现今地温梯度,可达350～420℃/100m;新生代以来大幅沉降,地温梯度降低,烃源岩的热演化程度受现今地温场控制。盆地热演化史与油气关系研究表明营尔凹陷下白垩统赤金堡组烃源岩主生油期有两期,分别在早白垩世晚期及第三纪以来。下白垩统下沟组和中沟组烃源岩主生油期仅有一次,主要为上新世以来。营尔凹陷有良好的找油前景。     

Depositional environment,hydrocarbon generation and expulsion potential of the middle Permian Pingdiquan source rocks based on geochemical analyses in the eastern Junggar Basin,NW China

As the most important source rocks in the eastern Junggar Basin, the middle Permian Pingdiquan (P₂p) source rocks have attracted increasing attention after the discovery of tight oil in the Shazhang uplift. The P₂p source rocks are widely distributed (up to 7546 km²) and have an elevated thickness in the eastern Junggar Basin. To explore the P₂p tight oil resource in the eastern Junggar Basin, 113 core samples from 34 exploration wells were analysed geochemically and re-examined for their organic matter abundance, type and thermal maturity, hydrocarbon potential and sedimentary environment. Geochemical analysis results indicate that the P₂p source rocks are fair to good source rocks dominated by Type II kerogen, presently in a low mature–mature stage, and biomarkers and trace elements indicate deposition in a terrestrial to coastal environment under oxic to dysoxic, and fresh to brackish conditions, with possible intermittent seawater influence, implying proximity to the open sea. Based on hydrocarbon expulsion modelling, hydrocarbon expulsion began at 0.87% R_o, and the peak expulsion occurred at 1.1% R_o. Hydrocarbon generation intensities in the Shazhang uplift and the Wucaiwan sag are relatively large, with values centred at 4–6.5 million t/km² and 4–6 million t/km², respectively, with total hydrocarbon generation and expulsion from the P₂p source rocks approximately 4.56 × 10⁹ t and 1.44 × 10⁹ t, respectively, indicating significant tight oil exploration potential in the eastern Junggar Basin. The Shazhang uplift and the Wucaiwan sag are two hydrocarbon expulsion centres in the study area with the largest hydrocarbon expulsion intensity centred around the Shazhang uplift, exceeding 3 × 10⁶ t/km². We suggest that the area with high hydrocarbon expulsion intensities is a favourable target for tight oil accumulation and exploration.     

地质条件下湖相烃源岩生排烃效率与模式

烃源岩排烃研究是油气地球化学研究中最薄弱的环节,而排烃效率又是准确评价常规油气与非常规页岩油气资源的关键参数。目前对于烃源岩排烃效率的认识差异很大,尚未建立完整的各种类型有机质湖相烃源岩在地质条件下生排烃效率与模式。本文以中国渤海湾、松辽等4个大型湖相含油气盆地以及酒泉青西凹陷、泌阳凹陷等9个中小型湖相富油盆地/断陷为对象,通过15000余个湖相烃源岩样品在自然热演化过程中热解生烃潜力指数的变化研究,揭示了湖相烃源岩在地质条件下的生排烃特征,构建了湖相烃源岩在地质条件下的生排烃效率与模型。无论是大型湖相沉积盆地还是中小型断陷盆地,甚至是盐湖相沉积盆地,烃源岩生排烃特征基本一致。随着成熟度的增高,湖相烃源岩排烃效率逐渐增高,在低成熟阶段排烃效率较低,在成熟与高成熟阶段具有高或很高的排烃效率。Ⅰ型、Ⅱ型有机质类型烃源岩排烃模式相似,相对排烃效率在低成熟阶段小于45%,成熟生油高峰时达85%~90%,至生油窗下限时达90%以上;累积排烃效率在低成熟阶段小于10%,生油高峰时达50%~60%,生油窗下限时达75%~85%,主要的排烃阶段在镜质组反射率0.7%~1.2%之间,生油窗阶段生成并排出了绝大部分烃类。湖相Ⅲ型有机质烃源岩排烃效率明显低于Ⅰ、Ⅱ型有机质烃源岩,生油窗阶段累积排烃效率仅为50%左右,主要生排烃阶段在镜质组反射率0.8%~2.0%之间。控制湖相烃源岩排烃量和排烃效率的主要因素是有机质丰度、类型和成熟度,而盆地类型、断裂发育程度、烃源岩沉积环境、相邻输导层孔渗条件等因素均不影响烃源岩排烃与排烃效率。     

塔东地区构造热事件及其对原油裂解的影响

塔东地区目前共有7口探井钻遇油气勘探潜力较大的寒武系-下奥陶统碳酸盐岩地层。主要对这7口井古生界的有机质成熟度资料做了系统分析,发现其中2口井古生界有机质成熟度剖面呈直线型,属于正常的地热演化剖面;另外5口井古生界有机质成熟度存在非常明显的拐点;7口井古生界与中新生界的有机质成熟度之间不连续,即有明显的“断层”,表明塔东隆起区及斜坡区古生界地层的有机质成熟度增加并不是由于沉积埋藏造成的,而是由于深部的异常热事件造成的。从成熟度变化分析,异常热事件在垂向上主要影响下古生界地层,在平面上异常成熟度现象分布在走滑性深大断裂带附近,远离走滑性深大断裂带的井中有机质成熟度表现为正常的热演化剖面,说明在塔东地区异常热事件与深大断裂有关,称之为构造热事件。构造热事件成为塔东隆起或斜坡区在中新生代时古生界原油裂解的主要热动力。7口探井中多期沥青的存在,进一步说明该地区有过后期原油裂解,同一样品中沥青反射率存在明显的差异,反映沥青是在不同阶段形成的。其中1期沥青分布区域没有受到异常热事件影响,沥青只是早期正常埋藏成因;对2期沥青分析说明有1期后期异常热事件,与该区断裂主要活动时期（J3末）是一致的;对3期沥青分析说明存在2期后期异常热事件,与车尔臣断裂带的2期活动（S₃-D₂、J₃末）一致。     

东海盆地椒江凹陷古新统烃源岩地球化学特征及生烃历史

为揭示东海盆地椒江凹陷油气勘探潜力,基于地球化学和盆地数值模拟方法对古新统月桂峰组、灵峰组和明月峰组烃源岩开展生烃能力和生烃过程研究.结果表明,月桂峰组和灵峰组泥岩有机质丰度高,以Ⅱ型干酪根为主,为水生生物和陆源高等植物混合来源,且形成于偏还原环境.夹有薄层炭质泥岩和煤的明月峰组泥岩有机质丰度低,以Ⅲ型干酪根为主,为陆源高等植物来源且形成于氧化环境.古新世至始新世,椒江凹陷大幅度沉降且古热流较高,是古新统烃源岩热演化程度增加的主要时期.受埋藏史和成熟度史共同控制,月桂峰组和灵峰组经历了2次生烃作用,第1次发生在古新世晚期,第2次发生在始新世中期至晚期,生烃强度高.明月峰组仅在始新世末期经历了1次生烃作用,生烃强度低.椒江凹陷古新统烃源岩生烃潜力强,具有广阔的油气勘探前景,应围绕生烃中心尤其是月桂峰组生烃中心选择形成于中新世之前的有效圈闭进行钻探.      

新疆塔里木盆地孔雀河地区下古生界烃源岩与成烃史分析

塔里木盆地孔雀河地区寒武—奥陶系烃源岩分布广泛,厚度由东北向西南逐渐增大,累计最大厚度达4 000余米,寒武系—下奥陶统烃源岩有机质处于高成熟-过成熟阶段,中上奥陶统烃源岩有机质处于成熟-高成熟阶段.在剥蚀量和古地温研究基础上,通过单井埋藏史与古地温曲线的叠合,总结出孔雀河地区寒武—奥陶系烃源岩的生烃史,共3类7型:第一为二次生烃类,按进入二次生烃时间可进一步分为三型;第二为持续生烃类,按埋藏史可再分为两型;第三为下部过成熟类,按达到过成熟温度(240℃)的时间可进一步分为两型.在所划分的3类7型中只有底部过成熟二型属于不具备生排烃能力的无效烃源岩,这一结果扩大了本区的油气资源前景.