高煤级煤储层渗透性与应力耦合模型及控制机理

煤储层应力敏感性是影响煤层气井产能的地质因素,以鄂尔多斯盆地东南缘高煤级煤储层为对象,通过煤样的应力敏感性实验和现场测试,建立了高煤级煤储层渗透性与应力之间的相关关系和模型;探讨了渗透性变化的控制机理.研究结果表明, 煤储层渗透率随应力的增加按负指数函数规律降低.在应力小于5 MPa时,煤储层渗透率随应力增加快速下降,应力敏感性最强;应力在5~10 MPa时,渗透率随应力增加而较快下降,应力敏感性较强;而当应力大于10 MPa后,渗透率随应力的增加下降速度减缓,应力敏感性减弱.与沁水盆地南部高煤级煤样实验结果对比认为,鄂尔多斯盆地东南缘山西组2煤层应力敏感性要小于沁水盆地南部山西组3煤层的应力敏感性.煤储层渗透性是在应力作用下煤储层中裂隙产生压缩(压密)变形,裂隙开度急剧减小的结果.因此在煤层气开发过程中控制排采速度,尤其是排采早期降液速度,对于防止煤储层应力敏感性,提高采收率具有实际意义.     

基于BP神经网络的储层渗透率预测及质量评价方法

储层渗透率预测和评价是油气藏勘探与开发急需突破的瓶颈技术之一,BP神经网络预测储层渗透率的研究在行业中已有一定的应用,但受限于数据规模、参数调整及模型评价方法,该方法预测结果不稳定,且不能准确给出全井段储层的连续渗透率的预测质量,在油田现场并未大规模推广应用.本文针对传统BP神经网络预测储层渗透率方法中存在的问题,在对机器学习的数据处理、参数选择系统考察的基础上,定量分析了不同输入曲线、网络结构、样本大小对渗透率预测模型精度的影响,总结了BP神经网络预测渗透率模型的参数优选方案;并提出了一种基于模型森林的预测曲线质量逐点评价方法,实现了对全井段渗透率预测的质量评价.实际应用表明,本研究提出的储层渗透率预测及质量评价方法与实际岩心渗透率吻合度高,推广应用前景良好.     

油水饱和泥质砂岩流动电位的频散特性

油水饱和泥质砂岩中流动电位的研究对于揭示含油储层震电勘探和动电测井的机理有着重要的意义.本文首先从岩石孔隙的微观结构出发,构造了描述水润湿条件下油水饱和泥质砂岩储层的毛管模型.在模型中依据油水流动遵守的Navier-Stokes方程和电化学传质动力学理论,建立了描述油水饱和泥质砂岩流动电位的数学方程,并数学模拟了岩石储渗参数对流动电位频散特性的影响规律.研究结果表明:储层孔隙内流体受到的粘滞力与惯性力控制着水相和油相的流动,从而决定了流动电位的频散特性.随着孔隙度的增大,油水两相各自的有效渗透率均增大;而含水饱和度的升高使得水相有效渗透率增大,油相有效渗透率减小.在水润湿条件下,流动电位耦合系数随含水饱和度升高而增大,随束缚水饱和度的升高而减小.另外,流动电位相对耦合系数也随含水饱和度的升高而增大,但无频散现象.     

裂缝-孔隙介质储层渗透率表征及其影响因素分析

含裂缝多孔介质渗透率预测是非常规油气资源勘探开发的一个紧迫问题.现有多孔介质岩石物理模型通常利用圆形孔管模拟宏观岩石孔隙空间,难以定量描述软孔隙/裂缝在压力作用下的闭合情况,缺乏裂缝/孔隙间流量交换的连通机制.本文提出含三维裂缝/软孔隙网络多孔介质模型,将储层岩石裂缝/软孔隙表示为椭圆截面微管,建立了周期性压力作用下微观裂缝流量表达式,通过网络模型和流量守恒条件,得到含有三维裂缝/软孔隙网络的多孔介质渗透率计算方法.数值算例表明,预测结果与实验数据分布范围吻合很好,能够给出不同类型岩心对应孔隙纵横比的分布图.三维裂缝/软孔隙网络模型建立了宏观可观测量与裂缝参数之间关系,能够定量分析岩石渗透率随裂缝体密度、纵横比、孔隙流体类型和围压等因素的变化规律,为复杂条件下储层渗透率预测提供了一种有效方法.     

基于多任务学习的测井储层参数预测方法

基于多任务神经网络模型,提出一种多任务测井储层参数预测方法,利用测井数据对储层孔隙度、渗透率及含水饱和度同时进行预测.分别采用同架构和异架构多任务模型对测井储层参数进行预测,通过数值实验对比,多任务预测模型有效提升了单任务储层参数预测模型的效果,且提升幅度与模型结构有关,异架构多任务模型的总体预测效果好于同架构多任务模...     

储层条件下波速的变化规律及其影响因素的实验研究

为了在模拟储层的温度压力条件下,更精确地测定大庆砂岩样品在干燥、饱水和饱油等不同情况下的纵、横波速及其变化规律,首先对由于岩石的非完全弹性而引起的隐伏效应、滞后效应等因素对波速测量的影响进行了分析,提出了相应的改进方法以提高测试的精度．实验结果表明,波速随压力的增大以对数形式增加,随温度的升高呈线性减小．通过实测数据的分析和计算,提出了压力影响系数和温度影响系数,且认为它们与岩性参数有关．     

泥质砂岩液相渗透率计算新方法

液相渗透率描述了岩石的渗流特性,是评价储层与预测油气产能的重要参数.液相渗透率是指盐水溶液在岩石孔隙中流动且与岩石孔隙表面黏土矿物发生物理化学作用时所测得的渗透率;液相渗透率的实验测量条件更加接近实际地层泥质砂岩的条件,使得液相渗透率更能反映地层条件下泥质砂岩的渗流特性;然而,现有的液相渗透率评价模型较少,且模型未能揭示液相渗透率与溶液矿化度之间的关系.基于此,开展了液相渗透模型推导与计算方法研究;文中首先将岩石等效为毛管束模型,推导建立了液相渗透率与比表面、喉道曲折度、总孔隙度、黏土束缚水孔隙度等参数之间的关系;其次,根据岩石物理体积模型,推导建立了黏土束缚水孔隙度与阳离子交换容量、溶液矿化度等参数的关系;最终,将黏土束缚水孔隙度引入液相渗透率计算公式,建立了基于总孔隙度、阳离子交换容量、溶液矿化度、比表面、喉道曲折度等参数的液相渗透率理论计算模型.液相渗透率计算模型与两组实验数据均表明,液相渗透率随阳离子交换容量的增大而降低,随溶液矿化度的增大而增大.然而,液相渗透率理论计算模型的实际应用中喉道曲折度、比表面等参数求取困难,直接利用理论模型计算液相渗透率受到限制.在分析液相渗透率与孔隙渗透率模型的基础上,建立了液相渗透率与空气渗透率之间的转换模型,形成了利用转化模型计算液相渗透率的新方法.为进一步验证液相渗透率与空气渗透率转化模型的准确性,基于两组实验数据,利用转换模型计算了液相渗透率;液相渗透率计算结果与岩心测量液相渗透率实验结果对比显示,液相渗透率计算结果与实际岩心测量结果吻合较好,文中建立的液相渗透率与空气渗透率转化模型合理可靠.     

深层砂岩油藏储层孔喉特征参数及预测模型

储层微观孔隙结构是影响油气富集与油气田开发效果的内在因素.为探讨深层砂岩油藏储层孔喉参数特征及分布规律,应用铸体图像分析技术、高压压汞技术对渤海湾盆地东濮凹陷濮城油田沙河街组深层砂岩油藏储层孔喉特征参数进行了研究.铸体图像分析技术研究表明,储层物性与孔隙半径、喉道宽度呈正相关关系;面孔率参数与孔隙度、渗透率相关性较好,面孔率较相应的孔隙度参数小;比表面、形状因子与其储层物性参数不相关,储层孔隙、喉道形状无规律;由特低渗至高渗储层,孔喉比参数无明显变化趋势,孔喉配位数呈增大趋势,孔喉均质系数、分选系数、变异系数规律性不强.高压压汞资料分析研究表明,储层最大喉道半径、平均喉道半径、主流喉道半径、主流喉道半径下限值、最小可流动喉道半径等均与储层岩石的渗透率参数呈正相关关系;平均水力半径与平均喉道半径呈正相关关系;储层岩石比表面与渗透率参数呈负相关关系.基于高压压汞资料,建立了渤海湾盆地东濮凹陷濮城油田沙河街组深层砂岩油藏储层孔喉参数预测模型.     

储层岩石流动电位频散特性的数学模拟

利用储层岩石流动电位的频散特性评价复杂储层已经成为勘探地球物理领域关注的热点,但是目前还没有形成基于储层岩石储渗特性及电化学性质的具有普遍指导意义的理论方法和数学模型.本文利用微观毛管理论,通过随时间谐变条件下渗流场和电流场的耦合模型,建立了描述储层岩石流动电位频散特性的数学方法,定量分析了频率域储层岩石动态渗透率、动电耦合系数和流动电位耦合系数随储层岩石孔隙度、溶液浓度和阳离子交换量的变化规律.研究结果表明:储层岩石流动电位频散特性是储层流体惯性力与流体黏滞力相互作用的结果.储层岩石孔隙度越大,储层维持流体原有运动状态的能力越大,临界频率越小;储层岩石的溶液浓度和阳离子交换量对临界频率没有影响.储层岩石的孔隙度越大,流体流动能力越强,流动电位各耦合系数的数值越大;溶液浓度越小或阳离子交换量越大,孔隙固液界面的双电层作用越强,各耦合系数的数值越大.     

四川盆地WR区块页岩气藏孔隙压力分布特征

页岩气储层孔隙压力是页岩气藏保存条件综合评价过程中的一项重要指标.常规基于欠压实成因的地层孔隙压力预测方法并不适用于存在大量有机质生烃增压过程的页岩气储层.本文在页岩储层岩石物理建模的基础上,通过在模型中添加有机相来间接考虑有机质生烃作用对泥页岩正常压实趋势的影响,结合有效应力原理,形成了面向页岩气储层的孔隙压力预测技术.该技术在四川盆地南部WR区块页岩气藏实际预测结果表明,研究区五峰组-龙马溪组页岩气藏属于典型的超压气藏.在纵向上,五峰-龙马溪组底部的有机碳含量高的优质页岩层段表现为明显的超压特征,压力系数介于1.6～2.1之间.在平面分布上,深凹区压力系数大,西部深凹区保存条件比东部隆起区要好.压力系数预测结果与钻井实测吻合率大于97％,该方法有效提高了钻前地层压力预测精度.     

Threshold pressure gradient of fluid flow through multi-porous media in low and extra-low permeability reservoirs

After analyzing many studies of fluid flow theory of multi-porous media in low and extra-low permeability reservoirs and the numerical simulation of non-Darcy flow, we found that a negative flow rate occurs in the existing non-Darcy flow equation, which is unreasonable. We believe that the existing equation can only be considered as a discriminant to judging Darcy flow or non-Darcy flow, and cannot be taken as a fluid flow governing equation of multi-porous media. Our analysis of the experimental results shows that the threshold pressure gradient (TPG) of low and extra-low permeability reservoirs is excessively high, and does not conform to fluid flow through multi-porous media in the actual reservoir situation. Therefore, we present a reasonable TPG ranging from 0.006 to 0.04 MPa/m at the well depth of 1500 m and oil drainage distance of 500 m. The results of our study also indicate that the non-Darcy flow phenomenon will disappear when the TPG reaches a certain value. In addition, the TPG or non-Darcy flow in low and extra-low permeability reservoirs does not need to be considered in the productivity prediction and reservoir numerical simulation. At present, the black oil model or dual-porous media is suitable for simulating low and extra-low permeability reservoirs.     

煤层气储层物性影响因素和预测方法综述与展望

为了解决煤储层物性的预测方法问题,本文基于大量的文献调研,梳理了煤储层孔隙性和渗透性的影响因素和预测方法,并进行了预测技术展望.研究表明,孔隙性影响因素主要有煤层埋深、压实作用、变质程度和显微组分等,孔隙度预测方法主要有双侧向迭代法、阿尔奇公式裂缝孔隙度估算法、双侧向数值模拟法、相关分析方法及支持向量机等方法;渗透性影响因素主要有煤层埋深、储层压力、煤的变质程度、煤体结构、煤岩组分、应力状态、基质收缩作用和裂隙系统发育程度等,渗透性预测方法主要有F-S计算方法、基于达西定律的计算方法、相关分析法及多层次模糊综合评判法等其他方法.本文认为遵循“地质约束测井、岩心刻度测井”的原则,加强煤层气储层岩石物理研究和物性影响因素分析是基础;常规测井信息与测井新技术信息结合,“多尺度信息融合”建立煤岩孔隙度和渗透率解释新模型,充分发挥多种非线性数学方法的优势构建煤岩物性非线性数学预测方法有一定的实际意义.     

低渗砂岩储层渗透率各向异性规律的实验研究

应用1摩尔/升的盐水作为孔隙介质,采用液体压力脉冲法对采自鄂尔多斯盆地某油田三叠系延长组低渗砂岩样品进行了渗透率随有效应力的变化规律实验研究.在围压0～100MPa,孔隙压力0～12MPa范围内,样品的渗透率变化范围在0～60×10-18 m2之间,实验结果表明样品的渗透率随有效应力的增加而减少.通过拟合实验结果,得到渗透率随有效应力的变化规律较好的符合幂函数关系,相关系数介于0.903～0.984之间.同时对同一样品的X,Y,Z相互垂直三个方向的渗透率随有效应力的变化进行了比较,结果表明渗透率的各向异性同样是压力的函数,且随着有效应力的增加,不同平面内的渗透率各向异性表现出了不同的变化规律.但在实验压力范围内,渗透率各向异性皆为正值,表明在有效应力为100MPa范围内孔隙内流体的流动方向未发生改变.研究结果为鄂尔多斯盆地低渗(超低渗)油气田开发,特别是对深部油气田开发过程中开发方式的选择与设计,充分利用渗透率各向异性的特点,提高采收率提供了新的岩石物性资料.     

Influence of pore pressure on velocity in low-porosity sandstone: Implications for time-lapse feasibility and pore-pressure study

As seismic data quality improves, time‐lapse seismic data is increasingly being called upon to interpret and predict changes during reservoir development and production. Since pressure change is a major component of reservoir change during production, a thorough understanding of the influence of pore pressure on seismic velocity is critical. Laboratory measurements show that differential pressure (overburden minus fluid pressure) does not adequately determine the actual reservoir conditions. Changes in fluid pressure are found to have an additional effect on the physical properties of rocks. The effective‐stress coefficient n is used to quantify the effect of pore pressure compared to confining pressure on rock properties. However, the current practice in time‐lapse feasibility studies, reservoir‐pressure inversion and pore‐pressure prediction is to assume that n= 1. Laboratory measurements, reported in both this and previous research show that n can be significantly less than unity for low‐porosity rocks and that it varies with porosity, rock texture and wave type. We report the results of ultrasonic experiments to estimate n for low‐porosity sandstones with and without microcracks. Our results show that, for P‐waves, n is as low as 0.4 at a differential pressure of 20 MPa (about 3000 psi) for a low‐porosity sandstone. Thus, in pore‐pressure inversion, an assumption of n= 1 would lead to a 150% underestimation of the pore pressure. Comparison of the effective‐stress coefficient for fractured and unfractured samples suggests that the presence of microfractures increases the sensitivity of P‐wave velocity to pore pressure, and therefore the effective‐stress coefficient. Our results show that the effective‐stress coefficient decreases with the differential pressure, with a higher differential pressure resulting in a lower effective‐stress coefficient. While the effective‐stress coefficient for P‐wave velocity can be significantly less than unity, it is close to one for S‐waves.     

Fluid Pressure Variation in a Sedimentary Geothermal Reservoir in the North German Basin: Case Study Groß Schönebeck

The Rotliegend of the North German basin is the target reservoir of an interdisciplinary investigation program to develop a technology for the generation of geothermal electricity from low-enthalpy reservoirs. An in situ downhole laboratory was established in the 4.3 km deep well Groβ Schönebeck with the purpose of developing appropriate stimulation methods to increase permeability of deep aquifers by enhancing or creating secondary porosity and flow paths. The goal is to learn how to enhance the inflow performance of a well from a variety of rock types in low permeable geothermal reservoirs. A change in effective stress due to fluid pressure was observed to be one of the key parameters influencing flow properties both downhole and in laboratory experiments on reservoir rocks. Fluid pressure variation was induced using proppant-gel-frac techniques as well as waterfrac techniques in several different new experiments in the borehole. A pressure step test indicates generation and extension of multiple fractures with closure pressures between 6 and 8.4 MPa above formation pressure. In a 24-hour production test 859 m³ water was produced from depth indicating an increase of productivity in comparison with former tests. Different depth sections and transmissibility values were observed in the borehole depending on fluid pressure. In addition, laboratory experiments were performed on core samples from the sandstone reservoir under uniaxial strain conditions, i.e., no lateral strain, constant axial load. The experiments on the borehole and the laboratory scale were realized on the same rock types under comparable stress conditions with similar pore pressure variations. Nevertheless, stress dependences of permeability are not easy to compare from scale to scale. Laboratory investigations reflect permeability variations due to microstructural heterogeneities and the behavior in the borehole is dominated by the generation of connections to large-scale structural patterns.     

New proposed method for prediction of reservoir sedimentation distribution

Prediction of sediment distribution in reservoirs is an important issue for dam designers to determine the reservoir active storage capacity.Methods proposed to calculate sediment distribution are varied,and mainly empirical.Among all the methods currently available,only area-reduction and areaincrement methods are considered as the principal methods for prediction of sediment distribution.In this paper,data of 16 reservoirs in the United States are used to propose a new empirical method for prediction of sediment distribution in reservoirs.In the proposed method,reservoir sediment distribution is related to sediment volume and original reservoir characteristics.To validate the accuracy of the new proposed method,obtained results are compared with survey data for two reservoirs.The results of this investigation showed that the proposed method has an acceptable accuracy.     

基于叠前反演的流体敏感属性实验研究及应用

提取叠前地震振幅信息的叠前反演技术已成为储层预测的重要手段,其能获得各种岩石弹性参数,丰富储层预测方法.因目标储层的差异性,优选并建立有利的流体敏感参数对储层流体检测尤为重要.本文基于岩石物理实验, 测量并分析了岩石弹性参数随流体饱和度的变化特征, 进一步根据岩石物理理论建立组合流体敏感参数, 达到对油气检测的最佳敏感效果.定义了流体敏感量,定量分析岩石弹性参数的流体敏感性.最后本文在X区块进行了叠前地震反演的应用, 结果表明通过岩石物理实验分析并建立获得的流体敏感参数能明显的提高储层的识别能力.     

测井资料Xu-White模型预测横波速度的一些新观点

目前横波预测的方法大致可以分为两种:经验公式预测和理论岩石物理模型。由于经验公式预测一般具有区域性,研究者更重视岩石物理模型预测。目前大多数岩石物理模型预测横波的方法假定地下流体的物性参数(速度和密度)不受地层深度的影响,且孔隙扁率是恒定的,实际上这并不科学。因为矿物的体积模量和剪切模量随所处地层深度发生改变,而对于孔隙扁率则随颗粒形状、孔隙度等的变化有较大变化。针对这些情况,提出一种新的改进的Xu-White横波预测方法,并可取得较好的效果。     

部分饱和砂岩储层地震物理模拟及含气饱和度预测分析

含气饱和度预测是天然气储层地震解释工作的重要目标.本文将岩石物理分析与地震物理模拟技术相结合,构建了部分;饱和砂岩储层物理模型并进行含气饱和度预测分析.物理模型中设置了高孔渗常规砂岩和低孑孔渗致密砂岩两种模拟储层,每种储层都是由具有不同含水饱和度的气-水双相饱和砂体组成.岩石物理分析结果显示在低孔渗致密砂岩中气-水混合流体更加倾向于非均匀的斑块分布,而结合了Brie等效流体公式的Gassmann流体替换理论可以更准确地描述纵波速度随含水饱和度的变化趋势.对物理模型进行地震资料采集处理后,对比了AVO特征和叠前同步反演结果对两种砂岩储层含气饱和度预测能力的差异.AVO特征结果显示,对于混合流体均匀分布的高孔渗砂岩储层,AVO响应曲线和属性变化很难对含气饱和度进行估算;对于混合流体斑块分布的致密砂岩储层,AVO特征可以定性地分辨出储层是否为高、中、低含气情况.反演结果显示,密度及纵横波速度比分别对高孔渗及致密砂岩储层的含气饱和度有着较好的指示能力.