重复压裂转向机制流-固耦合分析

重复压裂已成为油田老井挖潜、稳产增产的重要技术手段,而地应力转向机制与压裂时机选择一直是制约该技术增产效果的关键问题。对ABAQUS有限元软件平台进行了二次开发,考虑储层孔隙度和渗透性随岩石体积应变的动态演化,实现了流体压力变化与岩石物性参数的全面耦合,并分析了重复压裂转向机制。结果表明,地应力转向现象普遍存在,人工裂缝对地应力的影响范围有限,而孔隙压力变化是造成地应力转向的主要因素;随着生产的持续进行,地层压力下降变缓,岩石体积应变变化趋缓,导致渗透率下降趋于平稳,应力转向距离逐渐增大并最终趋稳;应力差越大、应力转向距离越小,越难形成重复压裂转向裂缝。其研究结果实现了流-固耦合作用下地应力转向的可视化描述,直观地模拟结果有利于指导重复压裂的应用实施。     

低渗透砂岩裂缝孔隙度、渗透率与应力场理论模型研究

低渗透砂岩储集层普遍发育裂缝, 裂缝不仅是重要的流体渗流通道, 而且在油井周围的发育程度直接影响着油井的生产能力.目前裂缝定量化预测方面存在的焦点问题是:缺乏一个有效而合理的力学模型, 裂缝渗透性的求取方法仍处于半定量化, 不具通用性.以史深100块沙三中储集层为目标, 从应力场和裂缝主要参数的关系入手, 以裂缝开度为桥梁, 通过实验和理论推导的方法, 建立了构造应力场和裂缝孔隙度、渗透率之间的定量关系模型.在岩石力学参数测试结果和地质模型建立的基础上, 对目的层裂缝发育时期的古构造应力和现今地应力进行数值模拟, 将结果代入关系模型, 计算研究区裂缝孔隙度和渗透率的空间分布, 进而指导低渗透砂岩油藏的裂缝参数定量预测、产能规划及井网部署.      

基于ABAQUS平台的水力裂缝扩展有限元模拟研究

随着扩展有限元理论的深入研究,利用扩展有限元方法模拟水力压裂具有了一定的可操作性。相比于常规有限元方法,XFEM方法具有计算结果精度高和计算量小的优点。但是,如何模拟射孔孔眼、如何模拟流体与岩石相互作用以及分析水力裂缝的扩展规律仍然是难题。以研究水力压裂裂缝扩展规律为目的,建立了岩石多孔介质应力平衡方程、流体渗流连续性方程和边界条件。通过有限元离散化方法对耦合方程矩阵进行处理。通过富集函数定义初始裂缝（射孔孔眼）,选择最大主应力及损伤变量D分别作为裂缝起裂和扩展判定准则,利用水平集方法模拟水力裂缝扩展过程。数值模拟结果显示：增加射孔方位角、压裂液排量和减小水平地应力差,起裂压力上升;黏度对起裂压力无明显影响。增加射孔方位角、压裂液排量、黏度和减小水平地应力差值有助于裂缝宽度的增加。增加水平地应力差值、压裂液排量和减小射孔方位角以及压裂液黏度有助于裂缝长度增加,反之亦然。基于ABAQUS的水力裂缝扩展有限元法可对不同井型和诸多储层物性参数及压裂施工参数进行分析,且裂缝形态逼真,裂缝面凹凸程度清晰,结果准确。此研究可作为一种简便有效研究水力压裂裂缝扩展规律的方法为油田水力压裂设计与施工提供参考与依据。     

裂缝性低渗透油藏流-固耦合数值模拟

根据低渗裂缝性砂岩油藏的储层特征,建立适合裂缝性砂岩油藏渗流的等效连续介质模型;通过实验得出有效压力改变对储层孔隙度、渗透率影响的规律;考虑低渗透油藏渗流时启动压力梯度和低渗储层的流-固耦合特性,将渗流力学与弹塑性力学相结合,建立起适合低渗透油藏的流-固耦合渗流数学模型,并给出其数值解.在黑油模型和弹塑性有限元程序的基础上,编制了计算低渗透油藏流-固耦合渗流的计算软件.通过数值模拟和不考虑流-固耦合时的计算结果相比,可以看出低渗油藏中流-固耦合效应十分明显.     

油井开采过程中油层变形的流固耦合分析

在油气开采过程中,随着油气的不断采出,必然造成孔隙流体压力的逐渐降低,由此导致储层岩石骨架的有效应力增大,使得油层产生变形或压实。当油层产生变莆或压实时,对油气生产将造成不利影响。比如：使得油藏的渗透率降低,继而使油井的产能降低,同时,油层的变形直接影响着油井和套管的变形与破坏等等。敢开采过程中油层的变形可以描述为三维变形与三维流体流动场的耦合问题,利用可变形多孔介质中流体渗流的流固耦合有限元数值     

页岩油藏多段水平井压后关井阶段压力扩散数学模型研究

多段多簇水平井压裂技术作为页岩油藏的重要开发手段已经得到了广泛认同,压后关井能充分发挥渗吸的作用,提高单井压后产量,但目前压裂液渗吸作用区域一直是困扰油藏工程师的重要难题。本文以陇东页岩油藏多段压裂井为研究对象,基于物质平衡原理,利用渗流力学和岩石力学理论,建立了压裂施工过程中和压后关井过程中流体压力扩散数学模型,研究了压力扩散和压裂液波及体积随时间的变化关系。结果表明：压裂液波及体积随关井时间的增加逐渐增加,但增加的幅度会逐渐降低。储层渗透率越小,孔隙度越大,压裂施工时间越长,关井阶段井底压力越高,地层能量越高。该结果可为页岩油藏最佳关井时间的确定提供理论支持。     

应力、应变与构造超压关系及构造超压控制因素分析

构造应力场引起岩石变形，并使孔隙流体压力发生变化，形成异常流体压力。根据对前人岩石力学实验结果的分析，应力与流体压力间为非线性关系，试件的体积应变与孔隙流体压力间为反相关线性关系。构造异常压力和其他异常压力的形成具有共性特征，都可以抽象为由于孔隙体积和流体体积的相对变化这一个因素。由此也可以将异常压力形成的一般过程概括为：孔隙疲充体饱和的岩石，体积缩小会使饱和流体排出，体积增大会使其周围的流体流入，如果渗透率足够大，流体流动顺畅，这一过程流体压力的变化相对较小。在岩石渗透率较小时，由于流量的限制，流体在这一过程中会产生明显的压力变化，形成异常压力。对于符合达西渗流的流体，异常压力计算时，流量可以用孔隙体积相对变化量替代。这样可以描述构造变形等固体变形所引起的异常压力。根据异常压力的极大值为研究区相应深度的最小主应力和岩石抗张强度之和的特点，可以预测流体封存箱箱壁的最小厚度要求，分析流体封存箱形成的基本条件。构造活动过程中，岩石孔隙的体积应变速率和封存箱壁的渗透率直接控制异常流体压力的大小。高应变速率和低的封存箱壁渗透率是形成构造超压的主要因素。     

有效压力对低渗透多孔介质孔隙度、渗透率的影响

以低渗透多孔介质为研究对象,通过实验得出孔隙度、渗透率随有效压力变化曲线。研究表明,流体在低渗透多孔介质中渗流时,流固耦合效应十分显著。这是因为低渗透多孔介质的孔隙很小,而孔隙度的微小变化,都会对渗透率产生大的影响,因此低渗透介质随有效应力的变化十分明显。由于流固耦合效应的存在,在低渗透油气藏的开发中,不宜采用降压开采,进行油藏数值模拟时,也应进行油藏流固耦合数值模拟。      

页岩气藏微裂缝表观渗透率动态模型研究

为研究页岩气藏开发过程中介质变形和滑脱效应对微裂缝表观渗透率动态变化的影响规律,分析有效应力和多孔介质结构参数等对气体渗流影响机制,采用光滑平板模型,结合分形及气体微观渗流理论,建立了介质变形和滑脱效应耦合作用下的微裂缝表观渗透率动态模型,并对模型进行可靠性验证和参数敏感性分析。研究表明,页岩气藏降压开采过程中受介质变形和滑脱效应“一负一正”耦合影响,微裂缝表观渗透率呈先减小后增大趋势,且临界压力值约为5 MPa;不同有效应力状态下,由于介质变形和滑脱效应耦合机制的差异性,导致表观渗透率变化规律不同,从微观作用机制角度对实验中不同加载条件下页岩应力敏感性的差异做出了理论解释;微裂缝最大开度越小,表观渗透率曲线“凹槽”越深,同时微裂缝孔隙度及开度分形维数越高、迂曲度分形维数越低,表观渗透率值越大。     

构造成矿非线性动力学:1.递增应力流变学模型

本文提出了构造成矿作用动力学研究的递增应力流变学方法。利用该方法将构造变形、应力、流体流动、地球化学反应及成岩成矿作用等多过程耦合起来，可以从多种地质过程的耦合与反馈作用对构造成矿的动力学演化过程进行１～３维数值模拟。模拟的主要内容是在各种过程耦合作用下，以下描述构造成矿体系的主要变量的时空演化：（１）与成矿流体的形成和性质有关的变量，如地层中矿物（包括成矿物质）的溶解速率、流体中各组分的浓度与饱和度、流体温度、压力、离子强度等；（２）与构造变形和流体运移有关的各变量，如应力与变形速率、岩石孔隙度、构造（断裂）渗透率等；（３）与沉淀成矿有关的变量，如矿物（金瞩矿物和脉石矿物）的成核速率、各矿物的沉淀量等；（４）上述各有关变量间的时空耦合关系，如断裂渗透率时空演化与流体流动、汇聚和成矿的耦合关系等。     

储层流固耦合的数学模型和非线性有限元方程

根据饱和多孔介质固体骨架的平衡方程和多孔介质中流体的连续性方程,建立了储层流固耦合数学模型。模型中引入了Jaumann应力速率公式描述多孔介质固体骨架的大变形效应,并考虑了地应力、初始孔隙压力、初始流体密度和初始孔隙度对耦合模型的影响。基于与微分方程等价的加权余量公式,在空间域采用有限元离散,对时间域进行隐式差分格式离散,导出了以单元节点位移和单元节点孔隙压力为未知量的储层流固耦合的非线性有限元增量方程。该模型在石油工程中有广泛的应用,为储层流固耦合的数值模拟奠定了理论基础。     

Prediction and analysis of the stimulated reservoir volume for shale gas reservoirs based on rock failure mechanism

The ultra-low-permeability shale gas reservoir has a lot of well-developed natural fractures. It has been proven that hydraulic fracture growth pattern is usually a complex network fracture rather than conventional single planar fractures by micro-seismic monitoring, which can be explained as the shear and tensile failure of natural fractures or creation of new cracks due to the increase in reservoir pore pressure caused by fluid injection during the process of hydraulic fracturing. In order to simulate the network fracture growth, a mathematical model was established based on full tensor permeability, continuum method and fluid mass conservation equation. Firstly, the governing equation of fluid diffusivity based on permeability tensor was solved to obtain the reservoir pressure distribution. Then Mohr–Coulomb shear failure criterion and tensile failure criterion were used to decide whether the rock failed or not in any block on the basis of the calculated reservoir pressure. The grid-block permeability was modified according to the change of fracture aperture once any type of rock failure criterion was met within a grid block. Finally, the stimulated reservoir volume (SRV) zone was represented by an enhancement permeability zone. After calibrating the numerical solution of the model with the field micro-seismic information, a sensitivity study was performed to analyze the effects of some factors including initial reservoir pressure, injection fluid volume, natural fracture azimuth angle and horizontal stress difference on the SRV (shape, size, bandwidth and length). The results show that the SRV size increases with the increasing initial pore reservoir and injection fluid volume, but decreases with the increase in the horizontal principal stress difference and natural fracture azimuth angle. The SRV shape is always similar for different initial pore reservoir and injection fluid volume. The SRV is observed to become shorter in length and wider in bandwidth with the decrease in natural fracture azimuth angle and horizontal principal stress difference.     

Three-dimensional fracture propagation under specified well-bore pressure

Results are presented for three-dimensional planar fracture propagation in the presence of variations in confining stress, reservoir properties and frac-fluid viscosity when the well-bore pressure is constant throughout the frac-job. Solid rock deformation during the frac-job is described by the dislocation method with singular integral equations, and the fluid flow in the fracture is represented by the finite element method. A convergence study is undertaken on the three-dimensional numerical model, and good agreement is obtained with results from laboratory tests and from the simpler circular model.     

Finite element modeling of hydraulic fracturing in 3D

A procedure based on the finite element method is suggested for modeling of 3D hydraulic fracturing in the subsurface. The proposed formulation partitions the stress field into the initial stress state and an additional stress state caused by pressure buildup. The additional stress is obtained as a solution of the Biot equations for coupled fluid flow and deformations in the rock. The fluid flow in the fracture is represented on a regular finite element grid by means of “fracture” porosity, which is the volume fraction of the fracture. The use of the fracture porosity allows for a uniform finite element formulation for the fracture and the rock, both with respect to fluid pressure and displacement. It is demonstrated how the fracture aperture is obtained from the displacement field. The model has a fracture criterion by means of a strain limit in each element. It is shown how this criterion scales with the element size. Fracturing becomes an intermittent process, and each event is followed by a pressure drop. A procedure is suggested for the computation of the pressure drop. Two examples of hydraulic fracturing are given, when the pressure buildup is from fluid injection by a well. One case is of a homogeneous rock, and the other case is an inhomogeneous rock. The fracture geometry, well pressure, new fracture area, and elastic energy released in each event are computed. The fracture geometry is three orthogonal fracture planes in the homogeneous case, and it is a branched fracture in the inhomogeneous case.     

异常高压气藏储层参数应力敏感性研究

异常高压气藏开采过程中,由于流体的产出,使储层岩石受力发生改变并使储层岩石发生弹塑性变形;而弹塑性变形反过来又影响到储层的孔隙度和渗透率,因此研究储层孔隙度和渗透率应力敏感性具有极其重要的意义。基于岩石力学的基本理论,推导出异常高压气藏岩石变形规律及变形方程,以此理论推导指导试验,将理论研究与实验规律相结合,在模拟地层条件下,对实际岩心样品进行了储层应力敏感性实验研究。实验研究表明,该方法能精确的描述储层孔隙度和渗透率应力敏感性,实验结果与理论推导结果完全吻合,进一步证明了理论推导的正确。     

塔里木盆地和田河气田奥陶系裂缝应力敏感性研究

为研究碳酸盐岩储层应力敏感性及其对气藏产能和气井见水的影响,选取塔里木盆地和田河气田奥陶系钻井岩心, 开展了应力敏感性研究,结合实验结果及数学推导建立了裂缝开度和有效应力之间的力学关系模型,最终借助有限元方 法,对持续开发过程中碳酸盐岩储层裂缝开度的空间变化规律进行了模拟分析。结果表明：裂缝开度的变化随围压或有效 应力变化呈非线性关系;随着围压或有效应力的升高,裂缝开度不断减小,0~0.8 MPa之间减小速度快,岩样应力敏感性 强,到2.6 MPa或5.4 MPa后变化趋于稳定,说明高应力环境下,岩样的应力敏感性减弱,塑性变形特征明显;随着围压的 逐渐降低,裂缝开度不断增大,但不能恢复至初始情况;未来若干年内随着快速开采,和田河气田有效应力增大,裂缝闭 合,产能下降;随着生产井关闭或开采速度放缓,气水界面之上有效应力仍然降低,裂缝闭合,界面之下有效应力增大, 裂缝开启,底水上升,破坏气藏生产。建议在裂缝性碳酸盐岩气藏开发政策的制定过程中,一方面要开展裂缝分布精细研 究,分析裂缝应力敏感性主控因素,同时要制定合理的开发方式和开采速度,确保气藏稳产、高产。     

A coupled compressible flow and geomechanics model for dynamic fracture aperture during carbon sequestration in coal

This paper presents the development of a discrete fracture model of fully coupled compressible fluid flow, adsorption and geomechanics to investigate the dynamic behaviour of fractures in coal. The model is applied in the study of geological carbon dioxide sequestration and differs from the dual porosity model developed in our previous work, with fractures now represented explicitly using lower-dimensional interface elements. The model consists of the fracture-matrix fluid transport model, the matrix deformation model and the stress-strain model for fracture deformation. A sequential implicit numerical method based on Galerkin finite element is employed to numerically solve the coupled governing equations, and verification is completed using published solutions as benchmarks. To explore the dynamic behaviour of fractures for understanding the process of carbon sequestration in coal, the model is used to investigate the effects of gas injection pressure and composition, adsorption and matrix permeability on the dynamic behaviour of fractures. The numerical results indicate that injecting nonadsorbing gas causes a monotonic increase in fracture aperture; however, the evolution of fracture aperture due to gas adsorption is complex due to the swelling-induced transition from local swelling to macro swelling. The change of fracture aperture is mainly controlled by the normal stress acting on the fracture surface. The fracture aperture initially increases for smaller matrix permeability and then declines after reaching a maximum value. When the local swelling becomes global, fracture aperture starts to rebound. However, when the matrix permeability is larger, the fracture aperture decreases before recovering to a higher value and remaining constant. Gas mixtures containing more carbon dioxide lead to larger closure of fracture aperture compared with those containing more nitrogen.     

CO_2注入下岩层变形和流体运移分析(I):两相流-岩层耦合模型

目前国内关于CO2咸水层封存尚处于先导性和试验性研究阶段,对超临界CO2注入过程中岩层力学响应和流体运移的理论与技术方面的认识还不完善。为研究CO2注入下岩层变形和流体运移,基于两相流动数学模型,给出了超临界CO2和咸水质量守恒方程;采用毛细压力和有效饱和度的关系式,将质量守恒方程变换成以毛细压力为变量的表达式,以便于考虑流体压力对岩层的影响。提出了无流体压力影响下的岩层力学本构模型,该模型能够同时考虑岩层的塑性变形和损伤。分析了两相流体-岩层相互作用机制:一方面,采用有效应力原理,考虑流体压力对岩层的力学影响;另一方面,通过岩层固有渗透率变化考虑岩层变形对流体运移的影响。     

渝东北地区WX2井页岩气赋存特征及其勘探指示意义

为了深入研究渝东北地区龙马溪组页岩气赋存特征,该文以WX2井页岩高温高压等温吸附及覆压孔隙度实验数据为 基础,通过误差最小原则挑选了适合研究区的吸附模型,并基于孔隙度随有效应力变化关系建立游离气模型,综合分析了 吸附气、游离气及总含气随埋藏深度的变化特征。研究结果表明：WX2井页岩不同温度下过剩吸附量随着压力增大,均呈 现先增大后减小的趋势,随着温度的升高,最大吸附量逐渐减小,而校正后的绝对吸附量随压力增加,先迅速增大后增速 放缓,且用D-A模型拟合绝对吸附量数据平均误差最小,基本可以反应研究区页岩真实吸附过程。页岩样品在加压过程中 孔隙及微裂隙会逐渐闭合,卸压时绝大部分会重新打开,存在部分塑性变形造成的不可逆损伤,但不可逆损伤所占比重较 轻。不同方向样品孔隙度与有效应力之间具有负指数关系,富含层理页岩平行样品较垂直样品具有更大的初始孔隙度以及 更强的孔隙应力敏感性。页岩气赋存特征综合受控于储集层特征、吸附能力、温度及压力等因素,其中温度对吸附气和游 离气含量为负效应,储层压力为正效应;吸附气、游离气及总含气量均遵循先增大后减小的总体趋势,其中吸附气及游离 气含量分别主要受控于温度及储层压力。此外,临界深度上下,页岩吸附态与游离态相对含量发生变化,其对页岩气富集 评价具有重要意义。     

Dual-porosity elastoplastic analyses of non-isothermal one-dimensional consolidation

A numerical solution, using the finite difference method, and based on a porothermo-elasto-plastic formulation for dual-porosity one-dimensional consolidation has been presented. The model is fully coupled to ensure the interactive behavior of fluid flow, heat flow and solid deformations in the conservation of momentum, mass and energy equations. A bi-linear stress-strain relationship is used to accommodate elastoplastic deformation behavior. A double effective stress law, proposed by Elsworth and Bai (1992), is applied to describe constitutive relationships among the stresses, pressures and temperatures. In order to examine the dual-porosity and thermal effects on the soil consolidation individually, isothermal and non-isothermal consolidations for a dual-porosity column are analyzed. In comparison to the single porosity approach, the present study shows that the pore pressure dissipation is faster and Mandel's effect (Mandel, 1953) is more pronounced at early times of the source disturbance for dual-porosity consolidation. One of the significant parameters affecting the dual-porosity consolidation is the fracture spacing (fracture density); the smaller the fracture spacing, the faster the column drainage.