Evaluation of Source Rock Potential for Hydrocarbon Generation in Shallow Offshore, Lamu Basin, Kenya

The ever-increasing demand for oil and gas has driven its exploration in rather extreme conditions. In Lamu offshore, which is hitherto underexplored, most of the wells already drilled turned out dry save for a few wells with hydrocarbon shows despite the promising reservoir properties and related geological structures. This, therefore, necessitated a source rock evaluation study in the area to ascertain the presence and potential of the source rock by integrating the geochemical data analysis and petroleum system modeling. The shallow Lamu offshore source rock quantity, quality, and maturity have been estimated through the determination of the total organic carbon (TOC) average values, Kerogen typing, and Rock-Eval pyrolysis measurements respectively. Geochemical data for Kubwa-1, Mbawa-1, Pomboo-1, and Simba-1 were evaluated for determining the source rock potential for hydrocarbon generation. Petroleum system modeling was applied in evaluating geological conditions necessary for a successful charge within a software that integrated geochemical and petrophysical characterization of the sedimentary formations in conjunction with boundary conditions that include basal heat flow, sediment-water interface temperature, and Paleo-water depth. The average TOC of 0.89 wt % in the study area suggests a fair organic richness which seems higher in the late cretaceous (0.98 wt %) than in the Paleocene (0.81 wt %). Vitrinite reflectance and Tmax values in the study area indicate the possible presence of both mature and immature source rocks. Type III Kerogen was the most dominant Kerogen type, and gas shows are the most frequent hydrocarbon encountered in the Lamu Basin with a few cases registering type II/III and type II. The charge properties (i.e. Temperature, transformation ratio, and Vitrinite reflectance) over geologic time at each of the wells have been estimated and their spatial variation mapped as seen from the burial history and depth curves overlaid with temperature, transformation ratio, and Vitrinite reflectance respectively. From the upper cretaceous maturity maps, the results seem to favor near coastal regions where average TOC is about 1.4 wt %, Vitrinite reflectance is more than 0.5%, transformation ratio is more than 10%, and temperatures range from 80°C to 160°C. The results postulate the absence of a definitive effective source rock with a likelihood of having cases of potential and possible source rocks. Moreover, greater uncertainty rests on the source rock’s presence and viability tending toward the deep offshore. Geochemical analysis and petroleum system modeling for hydrocarbon source rock evaluation improved the understanding of the occurrence of the possible and potential source rocks and processes necessary for hydrocarbon generation.

Rock-Eval热分解法及其在土壤有机碳研究中的应用

土壤有机碳的稳定性影响土壤固碳潜力,如何提取土壤活性及稳定性碳组分用以定量表征土壤有机碳稳定性,是土壤固碳研究领域的关键科学问题。当前,提取土壤有机碳活性及稳定性组分的方法多样,包括物理、化学及生物手段,导致结果难以比较,同时存在耗时长、成本高及操作步骤繁琐等缺点。所以,亟需一种高效、可信度高且应用广泛的测定方法。对比分析不同热分解技术的优缺点,包括热裂解气相-质谱联用测定技术、热重分析技术、差示扫描量热分析技术及Rock-Eval(RE)热分解方法,普遍认为RE方法操作简单、耗时短、成本低、结果易于分析,可信度较高,可以很好地表征土壤有机碳稳定性,有利于土壤有机碳研究的横向对比。本文通过Citespace软件综述了RE方法在土壤学和有机碳研究中发展过程,梳理了其应用现状及进展。提出RE方法有助于通过建立不同土地利用方式、气候带以及不同土壤质地间活性及稳定性碳库的比较网络体系,完善我国土壤碳库监测系统。

Quick Evaluation of Present-Day Low-Total Organic Carbon Carbonate Source Rocks from Rock-Eval Data: Middle–Upper Ordovician in the Tabei Uplift, Tarim Basin

Previous studies have postulated the contribution of present-day low-total organic carbon （TOC） marine carbonate source rocks to oil accumulations in the Tabei Uplift, Tarim Basin, China. However, not all present-day low-TOC carbonates have generated and expelled hydrocarbons; therefore, to distinguish the source rocks that have already expelled sufficient hydrocarbons from those not expelled hydrocarbons, is crucial in source rock evaluation and resource assessment in the Tabei Uplift. Mass balance can be used to identify modern low-TOC carbonates resulting from hydrocarbon expulsion. However, the process is quite complicated, requiring many parameters and coefficients and thus also a massive data source. In this paper, we provide a quick and cost effective method for identifying carbonate source rock with present-day low TOC, using widely available Rock-Eval data. First, we identify present-day low-TOC carbonate source rocks in typical wells according to the mass balance approach. Second, we build an optimal model to evaluate source rocks from the analysis of the rocks＇ characteristics and their influencing factors, reported as positive or negative values of a dimensionless index of Rock-Eval data （IR）. Positive IR corresponds to those samples which have expelled hydrocarbons. The optimal model optimizes complicated calculations and simulation processes; thus it could be widely applicable and competitive in the evaluation of present-day low TOC carbonates. By applying the model to the Rock-Eval dataset of the Tabei Uplift, we identify present-day iow-TOC carbonate source rocks and primarily evaluate the contribution equivalent of 11.87×10^9 t oil.

A New Method for Hydrocarbon Loss Recovering of Rock-Eval Pyrolysis

How to accurately recover the hydrocarbon loss is a crucial step in reservoir evaluation by Rock-Eval pyrolysis. However, it is very difficult to determine the recovering coefficients because there are numerous factors causing the hydrocarbon loss. Aiming at this problem, a new method named critical point analysis is put forward in this paper. The first step of the method is to find the critical point by drawing the scatterplot of hydrocarbon contents versus the ratio of the light component of with the heavy component of;And the second step is to calculate the recovering coefficient by contrasting the pyrolysis parameters at the critical point of different sample types. This method is not only been explained reasonably theoretically,but also has got a good application effect in Huanghua depression.

Petroleum Source-Rock Evaluation and Hydrocarbon Potential in Montney Formation Unconventional Reservoir, Northeastern British Columbia, Canada

Source-rock characteristics of Lower Triassic Montney Formation presented in this study shows the total organic carbon (TOC) richness, thermal maturity, hydrocarbon generation, geographical distribution of TOC and thermal maturity (Tmax) in Fort St. John study area (T86N, R23W and T74N, R13W) and its environs in northeastern British Columbia, Western Canada Sedimentary Basin (WCSB). TOC richness in Montney Formation within the study area is grouped into three categories: low TOC ( 3.5 wt%), and high TOC (>3.5 wt% %). Thermal maturity of the Montney Formation source-rock indicates that >90% of the analyzed samples are thermally mature, and mainly within gas generating window (wet gas, condensate gas, and dry gas), and comprises mixed Type II/III (oil/gas prone kerogen), and Type IV kerogen (gas prone). Analyses of Rock-Eval parameters (TOC, S2, Tmax, HI, OI and PI) obtained from 81 samples in 11 wells that penetrated the Montney Formation in the subsurface of northeastern British Columbia were used to map source rock quality across the study area. Based on total organic carbon (TOC) content mapping, geographical distribution of thermal maturity (Tmax) data mapping, including evaluation and interpretation of Rock-Eval parameters in the study area, the Montney Formation kerogen is indicative of a pervasively matured petroleum system in the study area.

Prognostication of hydrocarbon generative potential in the onshore and offshore Niger Delta, Nigeria using TOC content and rock-eval pyrolysis techniques

This article prognosticates the hydrocarbon generation potential of core samples from fields A, B, C and D in Niger delta, Nigeria. The objectives of this study are to characterize the quality of these core samples by organic geochemical analyses. A total of ten core samples collected from fields A, B, C and D in Niger delta were analyzed using total organic carbon(TOC) content analysis, rock-eval pyrolysis technique. The analytical results of the studied core samples reveal that they have generally high total organic carbon contents(TOC), suggesting that conditions in the Niger delta favour organic matter production and preservation. There is a variation in the kerogen types and this may be attributed to the relative stratigraphic positions of the core samples within the Niger delta. The rock-eval results indicate that the samples from fields C and D contain predominantly Type II kerogen with a capacity to generate oil and gas and hence have good generative potential. The samples from fields A and B contain mainly Type III kerogen and are gas-prone with moderate generative potential.

Assessment of Rock-Eval T_(max) Data in Bambra-2 Well of Barrow Sub-basin, North West Shelf of Australia: A Case Study of Contaminated Rock-Eval Data

The contamination of cuttings and side wall core (SWC) samples in the Bambra 2 well by drilling mud additives and natural hydrocarbons may cause Rock Eval T max (℃) data to be suspect, and affect its utility in the assessment of thermal maturity. The Rock Eval results of 284 cuttings samples, 31 side wall core samples and conventional core samples from the Jurassic Cretaceous sedimentary sequences in the Bambra 2 well are presented in this paper. Significantly lower T max values from cuttings samples compared with T max values from conventional core samples and solvent extracted SWC samples, from the deeper and higher maturity interval, are thought to have been caused by contamination by diesel and other drilling mud additives. The cuttings samples in the Barrow Group of Cretaceous may be contaminated by natural hydrocarbons, resulting their T max values to be 2-10 ℃ lower than a regularly increased T max trend from core samples. This study indicates that more reliable Rock Eval T max data are obtained from the conventional core samples and solvent extracted SWC samples. This study also indicates that the T max values from some SWC samples were also affected by free hydrocarbons, due to the use of diesel as a mud additive as well.

A Study on Hydrocarbon-Generating Potential and Kinetics of Source-Rock Pyrolysis

A study on the potential and kinetics of hydrocarbon (HC) generation of30 source-roch samples from a certain depression has been made by means of ROCKEVAL technique. In the qyrolysis experiment, the source maerial types, maturation andhydrocarbon-generating potential of source rocks from three Upper Jurassic horizons ofthat area have been evaluated in terms of such indicators as the type-index, hydrocarbongenerating potential and maximum pyrolysis temperature (Tmax). The results show thatthe pyrolysis HC yield of immature source rocks is much higher than that of mature rocksin case that the source material is of high quantity and organic matter is abundant, whichsuggests that it is important for evaluating the HC-generating potential to use immaturesamples for pyrolysis. In the pyrolytic simulation experiments on other two immaturesamples, it was found that the hydrocarbon yield is temperaure-dependent, and thereafterthe kinetical parameters for source rocks, such as reactional grade, appearant activationenergy and frequency facor were calculated.

Integrated Biostratigraphy, Depositional Setting and Geochemical Analyses for Petroleum Potential Evaluation of the Lower Cretaceous(Barremian – Albian) Strata of the Koppeh-Dagh Basin, Northeastern Iran

The lower Cretaceous rock units of the Koppeh-Dagh Basin of northeastern Iran were investigated here in terms of biostratigraphy,depositional setting and geochemical analyses to find out if they,alike other parts of the world,are rich in petroleum.For this purpose,a stratigraphic framework is established using calcareous nannofossil and palynological elements.A nannoplankton zonation based on which subzones of the zones CC7–CC8 of Sissingh(1977)and their equivalent NC6–NC8 of Roth(1978)was established indicating a Late Barremian–Albian age.Palynological assemblages led us to establish the local palynozone of Odontochitina operculata.A dominantly marginal basin to a transitional zone between shelf and basin under a dysoxic–anoxic condition with low to moderate sedimentation rates coincided with a gradual sea level rise was introduced as the environment of deposition for the strata via interpretation of the palynological parameters and quantitative palynology.The obtained data from Rock-Eval pyrolysis in compilation with palynofacies analysis reveals that the studied succession contains mainly gas-prone type III kerogen.The Spore Coloration Index(SCI)alongside with the Rock-Eval pyrolysis results(low values of HI and TOC)proves that these rock units locally produced natural gas during the time under consideration.

Potential Evaluation and Basin Modeling of the Pabdeh Formation in Zagros Basin: A Case Study

Pabdeh Formation is one of the most important source rocks in Zagros basin. In this study, thermal modeling and comparing of hydrocarbon potential evaluation of Pabdeh Formation in Mish Anticline and Gachsaran oil field have been investigated. For this reason, Rock-Eval pyrolysis was carried out on 21 cuttings samples collected from 2 boreholes (Well No. 55 and 83) of Gachsaran oil field and outcrop of Mish anticline. Accordingly, the Kerogen types of Pabdeh Formation in Gachsaran oil field are II, but in Mish anticline are type II and III. The amount of inert organic carbon determined for the Pabdeh Formation in Mish anticline is about 4.879 wt%, while for Gachsaran oil field, it is estimated at 0.153 (Well. No. 55) and 1.156 (Well. No. 83) wt%. Absorption of hydrocarbon by rock matrix was also determined. The amount of absorption in Mish anticline is more than that of Gachsaran oil field. This is mostly due to the presence of argillaceous matrix in this area, but the clays have not been successful in absorbing organic matter;this is due to the result obtained from small amount of organic matter in the basin. The Rock-Eval data revealed that the sedimentary paleo-environment strongly affected the source potential of this formation as it changed from the continental and Deltaic in the Mish anticline to deeper marine in Gachsaran oil field. In addition, curves of Burial history were drawn for Gachsaran well No. 55, in order to assess the thermal maturity of the Pabdeh formation. The results of the methods indicated that Pabdeh formation in Gachsaran oil field had a good to very good hydrocarbon potential and had entered to oil window.

Interpreting effects of TOC_(inert) organic content on source rock potential using S_2 vs. TOC graph in Maamba Coalfield,southern Zambia

The authors present the effects of the total organic carbon( TOCinert) during pyrolysis and how it overall affects the estimates of the hydrocarbon index( HI) using the cross plot S2 vs. TOC graph. A total of 21 drillcore samples consisting of the non-carbonaceous mudstones,carbonaceous mudstones,coaly mudstones and coals with S2> 0. 35 are selected and used. The average TOC for the sampled population is 10. 36 wt%.TOCinertmeasured from the S2 vs. TOC graph is 2. 97 wt% and the average pyrolysable TOCliveis 7. 39 wt%. The HI is 102 mg HC / g TOC and the pyrolysable HI is 175 mg HC / g TOC,indicating that the TOCinertor mi-neral matrix adsorbs some of the hydrocarbons liberated during pyrolysis resulting into the low HI values which affects the correct determination of the source rock potential. Other applications of the S2 vs. TOC cross plot have been used to determine the depositional system tracts. The high stand system tract is also determined through this method.

松辽盆地中央坳陷区三肇凹陷上白垩统青山口组一段页岩含油性特征

松辽盆地中央坳陷区上白垩统青山口组湖相暗色页岩沉积蕴含了数量可观的页岩油资源,其中齐家—古龙凹陷青山口组页岩油勘探已取得重大突破。采用井场密闭热释方法,结合室内溶剂抽提和比较热解方法,综合评价松辽盆地中央坳陷区三肇凹陷青山口组一段页岩含油性特征。结果表明,研究层段青山口组页岩总有机碳含量介于1.48%~6.97%,平均3.40%,Tmax值(抽提后)介于440~453℃,平均448℃,产率指数(PI)介于0.28~0.67,表明青山口组一段页岩处于大量生油阶段。井场和室内相结合的评价方法获得的页岩油含量介于4.00~19.49 mg/g,平均13.74 mg/g;其中游离油含量介于3.41~13.63 mg/g,平均8.70 mg/g;束缚油含量介于0.60~9.43 mg/g,平均5.04 mg/g。游离油由受限油和可动油组成,受限油含量介于1.81~8.49 mg/g,平均4.15 mg/g;可动油含量介于1.36~11.05 mg/g,平均4.55 mg/g,两者比例约为1∶1。以可动油含量平均值推算,可动油资源量为12 kg/m3,揭示三肇凹陷青山口组一段具有良好的可动页岩油资源潜力。

岩石热解方法应用于页岩油气研究需注意的几个问题

岩石热解方法自问世以来被广泛地应用于烃源岩的研究,其可以简便、快捷地评价岩石的含油特性、干酪根的生烃特征以及有机质的丰度、类型和成熟度,但该方法有其适用的范围,且岩石热解数据不合理的解释会增加页岩油气勘探的风险。基于近年来发表的大量实验测试数据,总结了在岩石热解分析数据解释中经常出现的3个问题。①对于高-过成熟的样品,其应用性受到限制;利用氢指数(HI)、氧指数(OI)、岩石最高热解峰温(T_(max))以及热解过程中产生的烃类(S_(2))与二氧化碳(S_(3))数量的比值(S_(2)/S_(3))来划分有机质的类型,应尽量针对有机质成熟度(镜质体反射率,R_(o))低于1.35%的烃源岩。②T_(max)的有效性取决于S_(2)峰的大小及其是否对称,T_(max)的准确性依赖于有机质的类型和R_(o);残余烃与黄铁矿含量会对T_(max)的准确性造成一定的影响。对于Ⅰ,Ⅱ和Ⅲ型有机质,为确保测试获得的T_(max)准确、有效,烃源岩的R_(o)应不高于1.70%。③含油饱和度指数(OSI)被用来表征页岩油的可动潜力,OSI大于100 mg/g指示页岩油甜点。值得注意的是,OSI并不能直接指示页岩中的含油饱和度,对于有机质含量较高的层段,OSI通常低于100 mg/g,而较低的总有机碳含量也能导致OSI大于100 mg/g。目前,大多数论文所报道的极具潜力的页岩油储层,只有极少数OSI高于100 mg/g。因此,将OSI大于100 mg/g作为一个评价页岩油可动性和甜点的参数值是否合适值得进一步思考。建议针对不同类型的沉积盆地和不同的页岩地层建立各自的OSI评价标准。此外,不同岩性的样品在存储和制备过程中轻烃损失量差异较大,应对多岩相共生页岩油储层采用分岩相评价方法。

西峰剖面有机质记录的黄土高原L_6-L_1古湿度演变

对甘肃西峰黄土剖面L6～L1层段162块样品进行了(Rock-Eval)2+PLUS分析,获得了TOC和热解烃的含量,以及有机质最高热解峰温(Tmax)的数据,并以与下降水有关的有机质和与蒸发水有关的矿物包裹有机质之比估算了古湿度的分布。结果表明,古土壤层的湿度比相邻黄土层的大,湿度的变化范围为47%～80%,其中湿度最大的层段为S5上部,次之为S1,湿度最小的层段为L6,次之为L4,L2-S1-L1层段的古湿度变化与陕西渭南剖面的相当层位具有很好的对应性。上述结果与黄土研究中常用的矿物粒度分析、CaCO3、Fe2+和Fe3+及磁化率等方法的测定结果具有良好的可比性。西峰剖面L6-S5-L4层段有机质和湿度的变化都很大,反映大气环流在这段时间异常活跃,具有热湿事件或黄土高原气候变化的边界特征。而在L4以来,特别是L4-S3-L3层段,湿度变化幅度相对较稳定,总的趋势向湿度减小方向发展,而在S2以后湿度演变有增大的趋势。

Biostratigraphy, Palynofacies and Organic Geochemical Characterization of Three Wells, Western Offshore Niger Delta Nigeria

Ditch samples from AP-4, ER-51 and UK-2 offshore Niger Delta were subjected to biostratigraphic and organic geochemical analyses which entail foraminiferal, palynological, Spore Colour Index (SCI), Rock-Eval Pyrolysis and Fourier Transform Infrared Spectroscopy (FTIR) analyses. The results have established N19 and N17;N17, N16 and N15;and N9 and N8 biozones;and P600 and P700 palynological zones. The dominance of palynomaceral (PM) I and II suggests Type III kerogen. PM III and IV (Type II and IV) were recorded. SCI ranges from 3/4 to 5/6 suggesting an early to mature liquid hydrocarbon generation phase. Rock-Eval Pyrolysis shows that the Total Organic Carbon (TOC), Hydrogen Index (HI), Pyrolysis temperature (Tmax), and Vitrinite Reflectance (VRo) range from 2.48 wt% - 6.37 wt%, 78 - 258, 411°C - 431°C and 0.26% - 0.69% respectively suggesting high TOC of Type II/III kerogen. FTIR indices show Type I kerogen in all the wells. VRo results range from 0.4 - 0.5 indicating an immature source. High concentrations of aliphatic saturates in identified functional groups indicate a low biodegradation. The abundance and diversity of recovered assemblages and dominance of PM I and II suggest shallow depositional environments with an age range of late Miocene to early Pliocene. Palynomaceral, SCI, and Rock-Eval inference contradict FTIR kerogen type suggesting that IR spectroscopy might not be suitable for kerogen typing and origin. The geochemical and biostratigraphical inferences must be corroborated for a successful evaluation. However, the source rock in the study area has adequate organic matter with the prospect to generate both oil and gas at appropriate maturity.

开放体系下平凉组页岩干酪根的生烃动力学研究

对鄂尔多斯盆地奥陶系平凉组海相页岩进行了3种升温速率下的Rock—Eval热解模拟实验，研究了其干酪根在开放体系下的热解生烃演化特征。通过分析热解烃S2的产率随温度的变化，结合Kinetics生烃动力学专用软件计算，获得了其开放体系下的生油动力学参数，活化能分布范围为（57～81）×4185kJ／mol。在此基础上进行的动力学模拟结果与实验数据非常吻合，可较好地将实验数据外推到地质实际过程。此外，发现热解残渣中的H／C（原子比）值与热解温度、干酪根转化率有较好的相关关系，可建立H／C值与转化率或者等效镜质组反射率的可靠模板，表明Rock—Eval热解实验与H／C值结合，可快速评价下古生界源岩的成熟度、转化率和生烃量等指标，将其应用于资源量计算等方面。

页岩滞留液态烃的定量评价

利用低温样品前处理技术并与地质分析相结合,建立了应用氯仿沥青"A"和热解参数定量评价页岩中滞留烃的方法。通过自生自储油气藏中原油与烃源岩氯仿抽提物组分对比,建立了东营凹陷主要生油窗范围内氯仿沥青"A"轻烃恢复系数随烃源岩生烃演化而变化的关系曲线,Ro小于0.5%,氯仿沥青"A"恢复系数较小,其重要增加发生在Ro为0.7%以后,Ro在1.2%时达到1.40以上。通过新鲜冷冻样品与常温保存样品的对比,建立了热解过程中散失轻烃的确定方法,并建立了不同演化阶段的散失系数,其变化规律与氯仿沥青"A"恢复系数相似。通过原样及抽提残渣的热解对比分析,建立了不同演化阶段烃源岩热解S2中滞留烃的比例系数,在成熟阶段(Ro为0.8%),这一比例可高达50%以上。通过上述技术方法,可以客观评价页岩中滞留烃含量,对油气资源评价具有重要意义。

不同热模拟实验煤热解产物特征及动力学分析

利用Rock-Eval-Ⅱ型热解仪、TG-MS(热失重—质谱联用仪)及金管装置对松辽盆地沙河子组煤样进行了热模拟实验。TG-MS实验中甲烷生成温度对应的Ro与地质条件下气态烃产物生成时的成熟度接近,而Rock-Eval-II实验中烃气生成时对应的Ro要远小于地质条件下气态烃产物生成时对应的成熟度。TG-MS实验中煤生甲烷终止温度约为850℃,对应的Ro约为5.3%(10℃/min升温速率)。金管实验650℃时(Ro约为4.9%,升温速率2℃/h)煤生气能力尚未结束,气态烃质量产率一直呈增长趋势,同时高温阶段密闭体系中甲烷的来源主要是有机质的初次裂解。煤生气动力学参数在徐家围子地区的应用结果表明,不同生烃装置热裂解实验下获得的动力学参数外推结果差别很大,建议采用TG-MS实验装置模拟地质条件下烃源岩边生气边排出的情况,采用金管装置热裂解实验模拟存在二次裂解的封闭体系下的生气情况。

页岩油探井现场地质评价实验流程与技术进展

页岩油勘探钻完井过程中需要及时对页岩含油性及页岩油的可动性进行快速评价,而已有的现场评价技术主要适用于常规砂岩储层,难于满足页岩非均质性描述的需求,迫切需要建立针对性的实验技术序列。根据页岩油探井现场快速地质评价客观需求,结合实验仪器的客观技术指标,提出了现场实验项目、取样保存和实验技术流程,并开展了现场技术方法实验和应用研究,研制磁流体变密度岩石总体积测试装置,解决了易松散形变页岩难于取柱塞样而无法及时获取物性参数的难题,建立了无固定形状页岩物性分析技术;采用液氮冷冻密闭粉碎制样技术避免轻烃损失,岩石热解分析数据更为真实;优化现场测试项目之间以及现场和实验室分析项目之间的衔接,实验支撑更为高效。新技术在江汉盆地潜江组、济阳坳陷沙河街组和鄂尔多斯盆地延长组七段应用效果显著,为陆相页岩油勘探快速地质评价提供了科学依据。同时也需要指出,中国目前页岩油勘探现场实验技术还不完善,还没有相应的规范标准,下一步攻关方向应该是,在完善现场实验技术和应用技术的基础上,形成规范的方法技术体系,搭建页岩油勘探快速地质评价技术平台。

应用岩石热解数据S_2-TOC相关图进行烃源岩评价

应用岩石热解数据评价烃源岩的传统方法具有一定的局限性。由于矿物基质的吸附或"死碳"的影响,有机质类型的"范氏图解"往往夸大烃源岩有机质类型的非均质性。对松辽盆地上白垩统不同有机质丰度和有机质类型的烃源岩生烃动力学研究表明,它们具有相似的生烃动力学特征,说明尽管有机质丰度存在较强的非均质性,但其有效源岩类型(区别于应用范氏图划分的有机质类型)是一致的。这些烃源岩的岩石裂解烃(S2)与有机质丰度(TOC)的相关系数很高,与生烃动力学的分析结果一致,表明应用S2-TOC相关图划分烃源岩的有机质类型可以更真实地反映烃源岩的有效源岩类型,S2-TOC相关图是评价烃源岩有效源岩类型的有效手段。过去岩石热解数据用于反映烃源岩成熟度的主要指标是tmax,tmax对于偏Ⅱ/Ⅲ型的烃源岩比较适用,而对于Ⅰ型烃源岩,由于生油窗内变化不明显,tmax不能完全反映有机质的成熟过程;而且tmax也受运移油等其他因素影响。不同成熟度的烃源岩的S2-TOC图分析结果显示,随着成熟度的增加,S2-TOC的回归斜率和TOC逐渐减小;利用不同成熟度的烃源岩建立的S2-TOC图可用于评价烃源岩的成熟度。松辽盆地不同沉积相中烃源岩的S2-TOC相关图的特征表明,只要有有利的有机质保存条件,各沉积相下均可发育优质的烃源岩;S2-TOC相关图可以反映烃源岩形成的沉积环境和有机质保存条件。