库车坳陷依奇克里克地区下侏罗统阿合组致密砂岩储层的成岩差异性特征研究     

张立强  严一鸣  罗晓容  王振彪  张海祖 《地学前缘》2018,25(2):170-178

塔里木盆地库车坳陷依奇克里克地区深层致密砂岩储层的非均质性强,成岩成藏过程复杂。根据岩心观察、薄片鉴定、流体包裹体、荧光特征及碳氧同位素等分析,对下侏罗统阿合组致密砂岩的岩石类型、成岩演化及其差异性特征进行了研究。研究表明,阿合组致密砂岩分为强钙质胶结砂岩(C类)、富刚性颗粒岩屑砂岩(A类)、含塑性颗粒岩屑砂岩(D类)、富塑性颗粒岩屑砂岩(B类)4类,经历了两期油气充注,不同类型砂岩的成岩、致密化及成藏过程差异明显。A类砂岩的构造缝及溶蚀孔隙均较发育,渗透率较高、孔隙度分布范围广,代表第二期油气充注的蓝色荧光强。D类砂岩的长石及软岩屑含量稍高,晚期溶蚀作用发育,孔隙度较高、渗透率低,黄色和蓝色荧光共存。A、D两类为有效的致密气藏储层,成岩、成藏过程有差异,D类砂岩早期与晚期油气充注共存,早期油气充注减缓后期压实和碳酸盐胶结作用的发生,有利于晚期酸性溶蚀及油气充注。A类砂岩裂缝发育,对储集性能的影响大,渗透性好,晚期油气充注受早期油气充注的影响小。  相似文献   

Applying octamethylcyclotetrasiloxane as a probe liquid for characterizing the pore size distribution of oil-bearing tight sandstones by nuclear magnetic resonance cryoporometry     

《Marine and Petroleum Geology》2017

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Prediction of diagenetic facies using well logs – A case study from the upper Triassic Yanchang Formation,Ordos Basin,China     

《Marine and Petroleum Geology》2017

Understanding diagenetic heterogeneity in tight sandstone reservoirs is vital for hydrocarbon exploration. As a typical tight sandstone reservoir, the seventh unit of the Upper Triassic Yanchang Formation in the Ordos Basin (Chang 7 unit), central China, is an important oil-producing interval. Results of helium porosity and permeability and petrographic assessment from thin sections, X-ray diffraction, scanning electron microscopy and cathodoluminescence analysis demonstrate that the sandstones have encountered various diagenetic processes encompassing mechanical and chemical compaction, cementation by carbonate, quartz, clay minerals, and dissolution of feldspar and lithic fragments. The sandstones comprise silt-to medium-grained lithic arkoses to feldspathic litharenites and litharenites, which have low porosity (0.5%–13.6%, with an average of 6.8%) and low permeability (0.009 × 10⁻³ μm² to 1.818 × 10⁻³ μm², with an average of 0.106 × 10⁻³ μm²).This study suggests that diagenetic facies identified from petrographic observations can be up-scaled by correlation with wire-line log responses, which can facilitate prediction of reservoir quality at a field-scale. Four diagenetic facies are determined based on petrographic features including intensity of compaction, cement types and amounts, and degree of dissolution. Unstable and labile components of sandstones can be identified by low bulk density and low gamma ray log values, and those sandstones show the highest reservoir quality. Tightly compacted sandstones/siltstones, which tend to have high gamma ray readings and relatively high bulk density values, show the poorest reservoir quality. A model based on principal component analysis (PCA) is built and show better prediction of diagenetic facies than biplots of well logs. The model is validated by blind testing log-predicted diagenetic facies against petrographic features from core samples of the Upper Triassic Yanchang Formation in the Ordos Basin, which indicates it is a helpful predictive model.  相似文献   

Influence of natural fractures on gas accumulation in the Upper Triassic tight gas sandstones in the northwestern Sichuan Basin,China     

《Marine and Petroleum Geology》2017

The Upper Triassic Xujiahe Formation in the northwestern Sichuan Basin, China, is a typical tight gas sandstone reservoir that contains natural fractures and has an average porosity of 1.10% and air permeability less than 0.1 md because of compaction and cementation. According to outcrops, cores and image logs, three types of natural fractures, namely, tectonic, diagenetic and overpressure-related fractures, have developed in the tight gas sandstones. The tectonic fractures include small faults, intraformational shear fractures and horizontal shear fractures, whereas the diagenetic fractures mainly include bed-parallel fractures. According to thin sections, the microfractures also include tectonic, diagenetic and overpressure-related microfractures. The diagenetic microfractures consist of transgranular, intragranular and grain-boundary fractures. Among these fractures, intraformational shear fractures, horizontal shear fractures and small faults are predominant and significant for fluid movement. Based on the Monte Carlo method, these intraformational shear fractures and horizontal shear fractures improve the reservoir porosity and permeability, thus serving as an important storage space and primary fluid-flow channels in the tight sandstones. The small faults may provide seepage channels in adjacent layers by cutting through layers. In addition, these intragranular and grain-boundary fractures increase the connectivity of the tight gas sandstones by linking tiny pores. The tectonic microfractures improve the seepage capability of the tight gas sandstones to some extent. Low-dip angle fractures are more abundant in the T₃X³ member than in the T₃X² and T₃X⁴ members. The fracture intensities of the sandstones in the T₃X³ member are greater than those in the T₃X² and T₃X⁴ members. The fracture intensities do not always decrease with increasing bed thickness for the tight sandstones. When the bed thickness of the tight sandstones is less than 1.0 m, the fracture intensities increase with increasing bed thickness in the T₃X³ member. Fluid inclusion evidence and burial history analysis indicate that the tectonic fractures developed over three periods. The first period was at the end of the Triassic to the Early Jurassic. The tectonic fractures developed during oil generation but before the matrix's porosity and permeability reduced, which suggests that these tectonic fractures could provide seepage channels for oil migration and accumulation. The second period was at the end of the Cretaceous after the matrix's porosity and permeability reduced but during peak gas generation, which indicates that gas mainly migrated and accumulated in the tectonic fractures. The third period was at the end of the Eogene to the Early Neogene. The tectonic fractures could provide seepage channels for secondary gas migration and accumulation from the Upper Triassic Xujiahe Formation into the overlying Jurassic Formation.  相似文献   

CEC比值法在凝灰质砂岩储层测井评价中的应用——以海-塔盆地X凹陷凝灰质砂岩储层为例          下载免费PDF全文

潘保芝  刘思慧  黄布宙  房春慧  郭宇航 《地球物理学报》2016,59(5):1920-1926

凝灰质砂岩储层一直是测井评价中的难点.凝灰质的存在使储层的孔隙结构和物性变化都很大,其含量直接影响储层参数的求取,对储层饱和度的影响不容忽视.本文以海-塔盆地X凹陷的凝灰质砂岩储层为例进行测井评价研究.基于泥质和凝灰质的测井响应差异利用粒子群和细菌觅食的混合优化算法计算储层中两者的含量,然后通过阳离子交换量(CEC)的实验数据验证了凝灰质具有导电性,进而利用CEC与电阻率之间的关系得到凝灰质电阻率的计算方法,并且应用到饱和度的计算,最终得到了一种新的计算凝灰质砂岩储层饱和度的方法——CEC比值法,并取得了良好的应用效果.  相似文献   

不同围压和流体饱和状态下致密砂岩弹性各向异性特征   总被引：3，自引：1，他引：2       下载免费PDF全文

宋连腾  王赟  刘忠华  王卿 《地球物理学报》2015,58(9):3401-3411

为研究致密砂岩声波速度及其各向异性随围压的变化规律以及不同流体饱和状态下的弹性各向异性特征,钻取了不同方向的岩心并在实验室超声波频率下对致密砂岩的声学特性进行了测量,分别给出干燥和饱和水状态下,不同方向样品纵横波速度、刚性系数以及各向异性系数随围压的变化规律,并对实验结果进行了分析讨论.实验结果表明致密砂岩纵横波速度、纵横波速度比以及刚性系数均随围压增加而增加,但其在不同饱和状态下的变化率却截然不同;纵横波速度比、各向异性系数在饱和水状态下变化规律不明显,表明孔隙流体的存在对于岩石物理性质有着非常重要的影响.这方面的实验工作不但对于考察不同流体性质对致密岩石弹性各向异性影响是必要的,而且有助于致密砂岩油水和气层的识别.  相似文献   

致密砂岩气藏可动流体赋存特征的微观地质因素: 以苏里格气田东部盒8段储层为例     

任大忠  孙卫  卢涛  李跃刚  张茜  周楷 《现代地质》2015,29(6):1409-1417

以苏里格气田东部盒8段典型的致密砂岩气藏为例,运用核磁共振、恒速压汞、铸体薄片、物性、X-衍射等实验资料,探讨了影响可动流体赋存差异的微观地质 因素。结果表明,盒8段储层可动流体饱和度低,T₂谱分布均为左高峰右低峰的双峰态;黏土矿物的充填与孔隙类型是孔隙结构复杂的重要因素,孔隙结构是影响可动流体赋存特征的关键;面孔率、喉道 半径、孔喉半径比是影响可动流体饱和度的主要因素,有效孔隙体积、分选系数对可动流体饱和度影响明显,储层物性、黏土矿物、有效喉道体积、孔隙半径对可动流体饱和度影响较弱。  相似文献   

酸性环境干湿循环对泥质砂岩力学特性影响的试验研究   总被引：2，自引：0，他引：2  

刘新荣  张梁  傅晏 《岩土力学》2014,35(Z2):45-52

由于库水位升降及降雨等原因,岩体经常处于干湿交替状态,对岩体工程的长期稳定性不利。以三峡库区泥质砂岩为研究对象,进行了酸性环境干湿循环交替作用后的常规单轴与三轴压缩试验研究,获得了泥质砂岩在酸性溶液浸泡干湿循环后的相关力学参数。相对于没有经过干湿循环作用的干燥试件,经过不同次数的干湿循环作用后,泥质砂岩的弹性模量、单轴抗压强度、黏聚力与内摩擦角都有不同程度的降低。各个力学指标的总体变化趋势是在第一次饱水之后有大幅度的降低,此后随着干湿循环次数的增加其降低的幅度逐渐减小。同时,酸性溶液的pH值对力学指标的影响很大,存在对泥质砂岩力学性能影响较大的一个临界pH值,低于此值酸性溶液对泥质砂岩力学性能影响显著增大,高于此值酸性溶液对其力学性能影响较小。  相似文献   

碎屑砂岩三轴压缩下强度和变形特性试验研究   总被引：1，自引：0，他引：1  

张玉  徐卫亚  赵海斌  王伟  梅松华 《岩土力学》2014,35(3):666-674

基于碎屑岩组织结构疏松、含水率较高、物理力学性能较差、呈孔隙式胶结接触等特点,对碎屑砂岩首先开展了物理特性试验分析,认为其微、细观结构复杂、内部破坏严重,矿物成分为石英、长石、绢云母等,化学成分以SiO2为主,属微透水、小孔隙率砂岩,且渗水化学侵蚀并不显著。其次,开展了静水压力、单轴压缩和三轴压缩试验,研究了碎屑砂岩的强度和变形破坏特性。最后,初步探索了物理特性与强度变形特性的关系。结果表明,静水压力为2.6 MPa时,岩样内部微缺陷压密完成;单轴压缩曲线呈明显6阶段特征,峰值应力达0.98 MPa,属脆-延性破坏;三轴压缩条件下,岩样呈压缩为主的延性扩容破坏,轴向压缩和环向体积扩容达6%和4%;曲线无明显破坏荷载,呈现非线性、塑性硬化、存在屈服平台和体积由压缩向扩容过渡等特性。且体积扩容破损应力与屈服应力基本相同,扩容转折点随围压增加而增大,围压可增强岩样抵抗变形破坏的能力。试验结果旨在为岩石工程稳定分析及本构模型构建提供可靠的依据。  相似文献   

孔隙砂岩多次化学注浆试验研究     

钱自卫  曹丽文  姜振泉  孙强 《岩土力学》2014,35(8):2226-2230

选取宁东地区典型的孔隙砂岩,采用不同颜色示踪的化学浆液进行4次注浆试验;揭示了浆液在孔隙中的扩散、充填规律及注浆次数与被注岩层渗透系数、孔隙率之间的关系。研究发现：每次化学注浆浆液的充填情况有明显的差别,首次注浆浆液在整个岩样均有较均匀的充填,后续的各次注浆浆液均呈现部分区域积聚充填的现象;随着注浆次数的增加岩样的渗透系数减小,孔隙充填率增加,渗透系数、孔隙充填率与注浆次数的关系可分别采用幂函数及对数函数拟合;4次注浆后岩样的渗透系数减小了97%,说明多次注浆起到了很好的减渗效果。依据试验成果,建立数值计算模型,预测了不同注浆次数、不同开挖条件下注浆孔及井筒的涌水量,并与井筒实际涌水量进行对比,发现两者数据较为吻合,说明依据试验结果建立数值模型进行涌水量预测是可行的。  相似文献