孔隙水压作用下岩样加载破坏过程的数值模拟

应用自主开发的岩石破坏过程渗流与应力耦合分析软件F-RFPA^2D，通过对孔隙水压作用下岩石试件加载破坏过程的数值模拟，研究了孔隙水压力对岩石强度、应力-应变曲线和破坏模式的影响，再现了受压试件在孔隙水压力作用下破坏过程及其逐步演变的应力场和渗流场。结果表明，孔隙水压力对岩石变形、破裂过程及其破坏模式有很大影响。     

渗流影响下岩石损伤和渐进破裂演化过程的数值试验研究

在FLAC-3D软件平台上,开发出岩石破裂过程的渗流-损伤耦合分析程序,对渗流-损伤耦合作用下岩石的裂纹萌生、扩展过程进行模拟研究。分析了在孔隙水压力作用下,含原生裂隙和弱化单元的非均质试件在单轴、三轴加载下的破坏过程,并与非渗流条件下试件在单轴、三轴压缩下的破坏过程相对比,通过动态显示损伤状态、渗流场,并分析应力应变关系、位移图等,对渗流影响下裂隙岩体的损伤和渐进破裂过程进行了研究。     

高水压下岩体裂纹扩展的渗流-断裂耦合机制与数值实现

采用渗流力学、断裂力学理论结合Monte Carlo方法描述岩体裂纹的随机分布,研究高水压作用下岩体原生裂纹的变形和翼形裂纹的萌生、扩展、贯通的渗流-断裂耦合作用机制,建立高水压作用下岩体裂纹的渗流-断裂耦合数学模型,给出该数学模型的求解策略与方法,在Fortran95平台下开发高水压下岩体裂纹扩展的渗流-断裂耦合分析程序HWFSC.for。高水压下岩体裂纹扩展的渗流-断裂耦合体现在岩体裂纹网络和渗流初始条件都随渗流时步变化。对高压注水岩体裂纹扩展过程进行渗流-断裂耦合分析。结果表明,高压注水条件下,岩体裂纹扩展存在起动水压力,当水压力大于起动水压力时,裂纹尖端开始萌生翼形裂纹,随着裂纹水压力的增加,翼形裂纹扩展,进而与其他裂纹搭接贯通,停止扩展。渗流-断裂耦合分析考虑了裂纹动、静水压力对裂纹产生的法向扩张效应及翼形裂纹的扩展而形成新的渗流通道两方面的影响,连通裂纹数随渗流的发展而增加。岩体裂纹的渗流-断裂耦合分析,能较真实地再现岩体裂纹的水力劈裂现象,描述岩体裂纹的扩展、贯通过程及与之相耦合的渗流响应。     

岩石倾斜裂隙与水平裂隙扩展贯通试验及数值模拟研究

采用最新配置的水泥砂浆材料,通过在试件中布置倾斜裂隙和水平裂隙,开展了单轴和双轴条件下的压缩试验,详细分析了不同加载条件下试件裂隙的扩展和贯通规律。试验结果表明:无裂隙内水压时,在单轴压缩条件下倾斜裂隙在扩展贯通水平裂隙后裂纹的扩展路径和方向发生明显改变,试样最终发生劈裂破坏。侧压的增大抑制了倾斜裂隙端部翼裂纹和次生裂纹的萌生,高侧压下翼裂纹没有贯穿水平裂隙,试样破坏模式变成了剪切破坏。水力耦合作用下,单轴压缩时倾斜裂隙翼裂纹尖端的最大主应力分布范围随着内水压的增大逐渐变小,翼裂纹的起裂应力、起裂角和峰值强度逐渐降低,试样发生劈裂破坏。通过数值模拟得到的裂纹扩展贯通规律与试验结果具有良好的一致性,开展了不同内水压时倾斜裂隙扩展贯通无水压的水平裂隙的数值分析,随着内水压的增加倾斜裂隙首先萌生共面裂纹随后产生翼裂纹,翼裂纹扩展贯通水平裂隙时扩展路径同样会发生改变。水力耦合作用下侧压也会抑制翼裂纹的萌生,随着内水压的增大减弱了侧压对倾斜裂隙翼裂纹的抑制作用。     

水力耦合作用下玄武岩启裂机制与临界水压研究

为了研究岩石在水力耦合作用下的启裂机制,针对溪洛渡玄武岩开展了水力耦合三轴试验与声发射测试。试验结果表明：玄武岩峰值强度随着围压的增大而增大,表现出典型的硬脆性行为;当围压保持不变时,其峰值强度随初始水压增大而逐渐降低,同时硬脆性减弱。声发射测试结果表明：玄武岩在水力耦合作用下的裂纹启裂为张拉破坏,在裂纹稳定扩展阶段以张拉破坏为主,以剪切破坏为辅,且这些破坏均主要发生在岩石中部;在裂纹非稳定扩展的峰后阶段,岩石破裂以剪切破坏为主。在玄武岩启裂机制认识的基础上,基于单一圆孔理论推导得到水力耦合条件下岩石裂纹启裂的临界水压破坏准则,并将其引入玄武岩水力耦合三轴试验数值仿真,分析了玄武岩水力耦合破坏过程与水压分布规律,验证了临界水压破坏准则的合理性,对于水力耦合作用下岩石破坏过程研究具有较好的参考价值。     

祁南矿东风井冻结温度场时空演化规律分析

煤矿井壁破损透水事件时有发生,给地下空间利用和矿产资源开采构成重大威胁。为了弄清井壁破损过程承压地下水存在的影响以及透水通道形成机制,采用相似理论设计模型试验并结合流固耦合数值模拟技术开展研究。结果表明,井壁与压力水直接接触不利于其承载变形能力的发展,具体体现在破坏时屈服点位置提前出现,峰值强度及峰值应变降低,宏观裂纹分布更广,这是由压力水渗入井壁混凝土时诱发的渗流场应力场相互耦合作用引起的。对照模型试验结果开展数值仿真分析,获得一套适用于流固耦合状态下井壁破损数值计算参数。基于此开展0.05、0.10、0.20、0.40 MPa孔隙水压影响下井壁破损透水全过程细观数值分析,发现孔隙水压增大使井壁承受的临界侧向荷载依次降低5.88%、17.65%、23.53%,屈服强度附近试件内部裂纹发展明显加速,裂纹不断扩展、贯通,最终形成沟通井壁内外侧壁的透水通道。0.40 MPa孔隙水压下透水通道率先出现,相对于其他3种孔隙水压提前了2.67、2.53、1.67倍计算步,说明孔隙水压越大裂纹扩展速率越快,裂纹扩展路径先径向后环向。声发射监测表明井壁破损透水前夕,事件数量先逐步增大再持续保持高位,破损后应力得到释放,声发射事件频率及数量骤降,该信号特征可作为现场井壁破损透水监测依据,为井壁突水预防和治理提供依据。

     

不同地应力条件下双孔爆破的数值模拟

考虑岩石介质的非均匀性,把爆破过程视为爆炸应力波和爆生气体压力共同作用的结果,基于损伤力学理论建立了岩石爆破的力学模型,并对不同地应力条件下岩石双孔爆破裂纹演化规律进行了数值模拟,分析了不同侧压力系数和埋 深对裂纹扩展规律的影响。数值模拟结果表明：①爆炸应力波导致裂纹的萌生,爆生气体压力则会使裂纹进一步扩展和贯通; ②裂纹演化过程与地应力密切相关,裂纹扩展的主方向趋于最大地应力方向;③随着埋深增加和初始地应力增大,裂纹扩展半径和裂纹区面积减小,地应力对爆破致裂的抑制作用明显。     

爆破开挖对岩体含水裂纹扩展的扰动机制

岩体裂纹的水力劈裂是岩体开裂渗漏甚至施工涌水的重要影响因素之一,也是岩土工程界的研究热点。从断裂力学角度分析了爆破开挖对岩体含水裂纹扩展的扰动作用,结果表明,爆破开挖扰动下,岩体含水裂纹的扩展,与爆炸应力波强度及其入射角、地应力的大小与方向、孔隙水压大小、裂纹的倾角及断裂韧度等因素相关;爆炸应力波的作用,相当于增大了岩体裂纹中的孔隙水压力,每1 cm/s的峰值振动速度相当于增大100 kPa的孔隙水压力,爆破振动速度越大,所产生的爆破扰动荷载越大;岩体开挖引起的岩体裂纹近区地应力及其孔隙水压力的变化,对裂纹的失稳与扩展具有较复杂的影响,可改变裂纹的失稳扩展模式。     

模拟岩石压剪状态下主次裂纹萌生开裂的扩展有限元法

压剪应力状态下,岩石类材料中常见两类裂纹：翼型张拉裂纹和次生压剪裂纹。基于扩展有限元方法（XFEM）,提出了模拟压剪裂纹面作用机制的扩展有限元位移增强方案,并给出了扩展有限元法分叉裂纹处理方法,分别用最大周向拉应力准则和Mohr-Coulomb准则判断张拉裂纹和压剪裂纹的萌生和扩展。基于Matlab平台编写了数值计算程序Betaxfem 2D,通过两个算例对所提方案进行了验证,所得结果与有限元法（FEM）计算结果吻合很好。模拟了单轴压缩载荷下含预制闭合裂纹试件的裂纹分叉、扩展过程,与试验结果的对比表明,所提方案可以模拟和预测岩石类材料张拉、压剪交互分叉裂纹的萌生和扩展行为。     

裂纹前端低孔隙压力区对岩石断裂性质的影响

设计加工了可单独控制孔压和围压的三点弯试验装置,对多组均质性较好的岩石试样在不同孔隙压力条件下进行了三点弯试验,同时建立考虑2D流固耦合的有限元数值模型,采用LVDT测量的裂纹张开位移和DIC(数字成像技术)监测裂尖处应变分布,对建立的有限元模型进行验证和标定,得到裂纹扩展过程中尖端附近的孔压分布及裂纹扩展参数。研究结果表明,岩石破裂过程中裂纹尖端前部存在低孔隙压力区,该低孔隙压力区在裂纹尖端附近形成非均匀孔隙压力分布,使岩石I型断裂韧性大于均匀孔隙压力条件下的I型断裂韧性;I型断裂韧性增加幅度与低孔隙压力区孔隙压力梯度正相关。     

Numerical Modeling of Pore Pressure Influence on Fracture Evolution in Brittle Heterogeneous Rocks

Rock is a heterogeneous geological material. When rock is subjected to internal hydraulic pressure and external mechanical loading, the fluid flow properties will be altered by closing, opening, or other interaction of pre-existing weaknesses or by induced new fractures. Meanwhile, the pore pressure can influence the fracture behavior on both a local and global scale. A finite element model that can consider the coupled effects of seepage, damage and stress field in heterogeneous rock is described. First, two series of numerical tests in relatively homogeneous and heterogeneous rocks were performed to investigate the influence of pore pressure magnitude and gradient on initiation and propagation of tensile fractures. Second, to examine the initiation of hydraulic fractures and their subsequent propagation, a series of numerical simulations of the behavior of two injection holes inside a saturated rock mass are carried out. The rock is subjected to different initial in situ stress ratios and to an internal injection (pore) pressure at the two injection holes. Numerically, simulated results indicate that tensile fracture is strongly influenced by both pore pressure magnitude and pore pressure gradient. In addition, the heterogeneity of rock, the initial in situ stress ratio (K), the distance between two injection holes, and the difference of the pore pressure in the two injection holes all play important roles in the initiation and propagation of hydraulic fractures. At relatively close spacing and when the two principal stresses are of similar magnitude, the proximity of adjacent injection holes can cause fracturing to occur in a direction perpendicular to the maximum principal stress.     

裂隙特征对岩石渗流特性的影响规律研究

裂隙是油气储层主要的储集空间及流体渗流通道,影响油气的运移规律,是油气勘探开发的重要指标。以冀中坳陷任丘油田任10井为例,运用数值模拟方法研究了裂隙开展宽度和裂隙面粗糙度对岩石渗流特性的影响规律。研究结果表明,(1)裂隙开展宽度较小时,孔隙内流体压力仅在入口处小范围内呈扇形分布,裂隙中压力分布曲线呈正切函数型,流体流速在裂隙和孔隙中都较小;随着裂缝开展宽度的增加,孔隙内流体压力逐渐增大,裂隙中压力分布曲线逐渐向直线型转变,流体流速在入口处先减小后稳定,在裂隙中先增加后稳定;(2)裂隙面粗糙度对裂隙岩石渗流特性的影响与裂隙开展宽度有关,在裂隙开展宽度较大时,裂隙面粗糙度对流体压力的分布影响较大;随着裂隙面粗糙度增大,孔隙内流速逐渐增大,而裂隙中流速逐渐减小;(3)随着裂隙开展宽度的增大,影响裂隙流体流动的主控因素逐渐由裂隙开展宽度转变为裂隙面粗糙度。     

Numerical modeling of fluid‐driven fractures in cohesive poroelastoplastic continuum

In this article, we investigate the main parameters that influence the propagation of a fluid‐driven fracture in a poroelastoplastic continuum. These parameters include the cohesive zone, the stress anisotropy, and the pore pressure field. The fracture is driven in a permeable porous domain that corresponds to weak formation by pumping of an incompressible viscous fluid at the fracture inlet under plane strain conditions. Rock deformation is modeled with the Mohr–Coulomb yield criterion with associative flow rule. Fluid flow in the fracture is modeled by the lubrication theory. The movement of the pore fluid in the surrounding medium is assumed to obey the Darcy law and is of the same nature as the fracturing fluid. The cohesive zone approach is used as the fracture propagation criterion. The problem is modeled numerically with the finite element method to obtain the solution for the fracture length, the fracture opening, and the propagation pressure as a function of the time and distance from the pumping inlet. It is demonstrated that the plastic yielding that is associated with the rock dilation in an elastoplastic saturated porous continuum is significantly affected by the cohesive zone characteristics, the stress anisotropy, and the pore pressure field. These influences result in larger fracture profiles and propagation pressures due to the larger plastic zones that are developing during the fracture propagation. Furthermore, it is also found that the diffusion process that is a major mechanism in hydraulic fracture operations influences further the obtained results on the fracture dimensions, plastic yielding, and fluid pressures. These findings may explain partially the discrepancies in net pressures between field measurements and conventional model predictions. Copyright © 2012 John Wiley & Sons, Ltd.     

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.     

Carbon dioxide injection and associated hydraulic fracturing of reservoir formations

The storage potential of subsurface geological systems makes them viable candidates for long-term disposal of significant quantities of CO₂. The geo-mechanical responses of these systems as a result of injection processes as well as the protracted storage of CO₂ are aspects that require sufficient understanding. A hypothetical model has been developed that conceptualises a typical well-reservoir system comprising an injection well where the fluid (CO₂) is introduced and a production/abandoned well sited at a distant location. This was accomplished by adopting a numerical methodology (discrete element method), specifically designed to investigate the geo-mechanical phenomena whereby the various processes are monitored at the inter-particle scale. Fracturing events were simulated. In addition, the influence of certain operating variables such as injection flow rate and fluid pressure was studied with particular interest in the nature of occurring fractures and trend of propagation, the pattern and magnitude of pressure build-up at the well vicinity, pressure distribution between well regions and pore velocity distribution between well regions. Modelling results generally show an initiation of fracturing caused by tensile failure of the rock material at the region of fluid injection; however, fracturing caused by shear failure becomes more dominant at the later stage of injection. Furthermore, isolated fracturing events were observed to occur at the production/abandoned wells that were not propagated from the injection point. This highlights the potential of CO₂ introduced through an injection well, which could be used to enhance oil/gas recovery at a distant production well. The rate and magnitude of fracture development are directly influenced by the fluid injection rate. Likewise, the magnitude of pressure build-up is greatly affected by the fluid injection rate and the distance from the point of injection. The DEM modelling technique illustrated provides an effective procedure that allows for more specific investigations of geo-mechanical mechanisms occurring at subsurface systems. The application of this methodology to the injection and storage of CO₂ facilitates the understanding of the fracturing phenomenon as well as the various factors governing the process.     

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.     

http://www.sciencedirect.com/science/article/pii/S1674987111001277

A numerical model is developed for investigating the evolution of fracture permeability in a coupled fracture-matrix system in the presence of fracture-skin with simultaneous colloidal and bacterial tr...     

A coupled hydro-mechanical analysis for prediction of hydraulic fracture propagation in saturated porous media using EFG mesh-less method

The details of the Element Free Galerkin (EFG) method are presented with the method being applied to a study on hydraulic fracturing initiation and propagation process in a saturated porous medium using coupled hydro-mechanical numerical modelling. In this EFG method, interpolation (approximation) is based on nodes without using elements and hence an arbitrary discrete fracture path can be modelled.The numerical approach is based upon solving two governing partial differential equations of equilibrium and continuity of pore water simultaneously. Displacement increment and pore water pressure increment are discretized using the same EFG shape functions. An incremental constrained Galerkin weak form is used to create the discrete system of equations and a fully implicit scheme is used for discretization in the time domain. Implementation of essential boundary conditions is based on the penalty method. In order to model discrete fractures, the so-called diffraction method is used.Examples are presented and the results are compared to some closed-form solutions and FEM approximations in order to demonstrate the validity of the developed model and its capabilities. The model is able to take the anisotropy and inhomogeneity of the material into account. The applicability of the model is examined by simulating hydraulic fracture initiation and propagation process from a borehole by injection of fluid. The maximum tensile strength criterion and Mohr–Coulomb shear criterion are used for modelling tensile and shear fracture, respectively. The model successfully simulates the leak-off of fluid from the fracture into the surrounding material. The results indicate the importance of pore fluid pressure in the initiation and propagation pattern of fracture in saturated soils.     

页岩气封存顶板变形破裂的机理与数值模拟

由于页岩气赋存机理的特殊性,页岩气成藏受保存条件及顶板类型的影响。封存顶板岩层对页岩气封盖影响极大。本文对页岩气藏封存顶板的破裂机理进行理论分析,并建立模型对顶板进行数值模拟。顶板岩层破裂与注水压力、岩石抗拉强度、地应力有关。封存顶板的破裂机理为压裂初始阶段,储层膨胀变形,封存顶板受压产生剪切裂纹,压裂液进入顶板,当注水压力小于最小主应力时,岩层发生剪切破裂,注水压力达到最小主应力和地应力之和时,岩石发生剪切破裂和张性破裂,裂缝增加并扩展,形成网状体系。数值模拟结果显示,压裂注水会在储层产生水力破坏区域,注水压力升高,水力破坏区域扩大并相互叠加影响,使得水力破坏集中于中间注水口的上部,当顶板岩层内部出现水力破坏区域时,岩石会发生破裂产生裂缝。在储层压裂的整个过程中,开始1h内,裂缝在储层内发展,顶板保持稳定,空隙水压力和变形很小,顶板岩层底部有少量裂纹。压裂2h,顶板底部裂缝增多,岩石空隙水压力上升,且顶板发生变形,中间变形最为明显。压裂3h,裂缝从顶板底部延伸到上部,岩层内部裂缝快速发育,空隙水压力持续升高,变形加大。数值模拟的结果与破裂机理的分析结果相吻合。     

Parameters controlling pressure and fracture behaviors in field injectivity tests: A numerical investigation using coupled flow and geomechanics model

Field injectivity tests are widely used in the oil and gas industry to obtain key formation characteristics. The prevailing approaches for injectivity test interpretation rely on traditional analytical models. A number of parameters may affect the test results and lead to interpretation difficulties. Understanding their impacts on pressure response and fracture geometry of the test is essential for accurate test interpretation. In this work, a coupled flow and geomechanics model is developed for numerical simulation of field injectivity tests. The coupled model combines a cohesive zone model for simulating fluid-driven fracture and a poro-elastic/plastic model for simulating formation behavior. The model can capture fracture propagation, fluid flow within the fracture and formation, deformation of the formation, and evolution of pore pressure and stress around the wellbore and fracture during the tests. Numerical simulations are carried out to investigate the impacts of a multitude of parameters on test behaviors. The parameters include rock permeability, the leak-off coefficient of the fracture, rock stiffness, rock toughness, rock strength, plasticity deformation, and injection rate. The sensitivity of pressure response and fracture geometry on each parameter is reported and discussed. The coupled flow and geomechanics model provides additional advantages in the understanding of the fundamental mechanisms of field injectivity tests.