页岩气开采的相关实验、模型和环境效应

页岩气是一种重要的非常规天然气资源,正在改变世界能源、经济和政治格局。渗透率是评价页岩气藏商业开采可行性的重要参数之一,由于页岩的致密性,页岩气的流动机理不同于常规气藏,因此,页岩储层渗透率测试和页岩气流动模型已成为当前国际研究的热点课题之一。在对页岩气开采技术简单介绍的基础上,综述了页岩储层渗透率测试的试验和理论研究现状,分析了气体吸附对页岩渗透率的影响。阐述了页岩气流动模型的最新进展,分析了双重孔隙模型描述气体迁移的准确性,提出了描述均匀储层中页岩气解吸-扩散-渗流多级运移模型。评述了页岩气开采的温室效应和对地下水的影响,并简单介绍了适合页岩气开采的新技术即无水压裂开采技术,即采用CO2对页岩气藏分段压裂,同时将CO2埋存于废弃井中。最后,对页岩储层渗透率测试和页岩气流动模型研究的新发展以及无水压裂技术进行了展望。     

Numerical modeling of stress effects on solute transport in fractured rocks

The effects of stress/deformation on fluid flow and contaminant transport in fractured rocks is one of the major concerns for performance and safety assessments of many subsurface engineering problems, especially radioactive waste disposal and oil/gas reservoir fields. However, very little progress has been made to study this issue due to difficulties in both experiments and numerical modeling. The objective of this study is to systematically investigate the influence of stress on solute transport in fractured rocks for the first time, considering different stress and hydraulic pressure conditions. A hybrid approach combining discrete element method (DEM) for stress-flow simulations and a particle tracking algorithm is developed. The impact of matrix diffusion (diffusion of molecular size solutes in and out of the rock matrix, and sorption onto the surface of micropores in rock matrix) is also included. The numerical results show that stress not only significantly changes the solute residence time through the fracture networks, but also changes the solute travel paths. Matrix diffusion plays a dominant role in solute transport when the hydraulic gradient is small, which is often encountered in practice.     

高塌落度防渗墙填料扩散系数快速测定的透析试验

扩散是低渗透系数情况下溶质迁移的主要方式,目前尚没有测定高塌落度防渗墙填料扩散系数的试验方法。根据沥出试验原理,将处于流动状态的填料用半透膜包裹进行透析试验,通过有限圆柱中溶质迁移解析解对溶质迁移过程进行拟合求其扩散系数,探讨了试验和数据处理的相关问题,研究了膨润土含量和盐浴浓度对扩散系数的影响规律。结果表明,随拟合天数增加,填料中NaCl有效扩散系数减小,而误差增大;高塌落度填料中溶质迁移明显比压实土样中快,按拟合误差小于0.5%作为试验数据取舍依据,这一误差要求实际上是对溶质迁移以扩散为主导这一条件的量化,保证了采用纯扩散解析解进行数据拟合的合理性;扩散系数随填料中膨润土含量增加而减小,随盐浴浓度增加而减小,但在试验范围内数值变化不大,透析试验是快速测定防渗墙填料中溶质有效扩散系数的可行方法。     

The verification of displacement methane effect caused by hydraulic fracturing in gassy coal seams

During hydraulic fracturing in gassy coal seams, the gas concentration in mining path ways is found to increase significantly. This phenomenon should be the displacement methane effect caused by hydraulic fracturing. Does this effect exist objectively? To this end, laboratory and field verification experiments were carried out. An experimental system integrated with true triaxial hydraulic fracturing, seepage, and displacement gas was developed. The largest sample size was 500?×?500?×?500 mm³. Proper sealing was assured in the experimental system, and the effects of coal bed methane were simulated effectively. Methane at a specific pressure was injected into a sealed coal sample. After pressure stabilization and the methane adsorption reached its equilibrium level, the high-pressure water was injected into the coal sample from the surface. Absorbed methane in the coal sample was displaced from the bottom of the coal by water pressure seepage. After the conduction of deep borehole hydraulic fracturing in a high gassy coal seam, the gas was displaced inward and outward from the main fracture section. The permeability, diffusion, and transfer of the gas resulted in a region of increased methane content in both sides of the main fracture section. And the methane content in the main fracture section was decreased. Along the length of the borehole, the methane content changed significantly. The existence of displaced methane caused by hydraulic fracturing in gassy coal seams was first verified by laboratory experiments and then field tests. The pore-pressure gradient provides power for driving methane by hydraulic fracturing. The amount of desorbed methane resulted from the competitive adsorption of water and methane is more than that of the absorbed methane resulted from increased methane pressure, which provides material guarantee for displacing methane by hydraulic fracturing. The displacement methane caused by hydraulic fracturing in gassy coal seams was also found to be time dependent.     

An adjoint-based optimization method for gas production in shale reservoirs

In this work, we consider a new model for flow in a multiporosity shale gas reservoir constructed within the framework of an upscaling procedure where hydraulic fractures are treated as (\(n-1\)) interfaces (\(n=2,3\)). Within this framework, the hydrodynamics is governed by a new pressure equation in the shale matrix which is treated as a homogenized porous medium composed of organic matter (kerogen aggregates with nanopores) and inorganic impermeable solid (clay, calcite, quartz) separated from each other by a network of interparticle pores of micrometer size. The solution of the pressure equation is strongly influenced by the constitutive response of the retardation parameter and effective hydraulic conductivity where the former incorporates gas adsorption/desorption in the nanopores of the kerogen. By focusing our analyses on this nonlinear diffusion equation in the domain occupied by the shale matrix, an optimization strategy seated on the adjoint sensitivity method is developed to minimize a cost functional related to gas production and net present value in a single hydraulic fracture. The gradient of the objective functional computed with the adjoint formulation is explored to update the controlled pressure drop aiming to optimize production in a given window of time. The combination of the direct approach and gradient-based optimization using the adjoint formulation leads to the construction of optimal production scenarios under controlled pressure decline in the well. Numerical simulations illustrate the potential of the methodology proposed herein in optimizing gas production.     

断层影响下的页岩气储层水力压裂模拟研究

断层对页岩气储层压裂改造有重要影响,甚至诱发深部地震事件和近地表环境问题.本文采用多物理场耦合方法,基于渗流和应力耦合理论,研究储层水力压裂过程中断层以及封闭顶板中水力破坏区域的产生与演化机理,并分析讨论流体沿高渗通道运移扩散机理,研究结果表明:(1)断层改变储层水力破坏区域形态并且扩展了水力压裂破坏空间.较高注水压力...     

Preliminary hydrogeological assessment of Late Cretaceous–Tertiary Ardley coals in part of the Alberta Basin,Alberta, Canada

A preliminary hydrogeological evaluation was undertaken on the gas potential of shallow coals in the Pembina–Warburg exploration area in the Alberta Basin, Alberta Canada. Regional data for the Late Cretaceous–Tertiary Ardley Coal Zone (ACZ) were compiled and supplemented with site-specific data collected from a key test- well drilled as part of a regional exploration program. Limited regional pressure data suggest hydraulic communication between the uppermost Ardley with the overlying Paskapoo Formation. A comparison between hydraulic head and topography suggests that flow, at least in part of the Ardley–Paskapoo, is gravity driven. However, a decoupling of the hydraulic regime appears evident from pressure test data in beds stratigraphically below the uppermost Scollard (Ardley) and above the base of Scollard at least in the eastern part of the study area where the test-well was drilled. The decoupling is evident in regional pressure data but the precise stratigraphic position may vary.Regionally, formation waters typically are Na–HCO₃ type with salinities (as TDS) of less than 2000 mg/L. Anomalously high bicarbonate (dissolved inorganic carbon or DIC) concentrations exceeding 1500 mg/L with δ¹³C_DIC + 22.50‰ and dissolved methane identified in formation waters collected directly from Ardley coal in test-well 103 point to the presence of secondary biogenic gas. The ¹³C isotopes for DIC, coupled with ¹⁸O and ²H isotopes for associated groundwater and regional hydraulic data, suggest that the uppermost Ardley Coal Zone in the eastern part of the study area is part of a regional, topographically driven, dynamic flow system in which methanogenic processes are modifying groundwater chemistry and gas charging parts of the area. Whether or not biogenic gas-charging in the Ardley is pervasive is uncertain. The relatively small coal data set requires that further exploration in the study area should consider the presence of microbial gas and the potential for hydrogeological controls on its distribution. However, further detailed testing will be necessary to develop a consistent and useful database for exploration and development.     

An analytical model for multiple fractured shale gas wells considering fracture networks and dynamic gas properties

Multi-stage fractured horizontal wells play an important role in developing shale gas reservoirs by significantly improving productivity. By considering fracture networks, gas desorption, stress-sensitive fracture permeability, and pressure-dependent gas PVT properties, an analytical model is developed for shale gas wells. Fracture networks are handled based on transient linear flow, gas desorption is handled by defining a new total compressibility, stress-dependent hydraulic fracture permeability is handled by variable substitution, and pseudo-pressure and pseudo-time are used to handle pressure-dependent PVT properties. After obtaining the solution of the linearized model, a material balance method and successive substitution iteration procedure are proposed to convert the pseudo-time into real time and calculate the production contribution from gas desorption. The results show that induced fractures also have a great impact on the production of the well. Production contribution from free gas and adsorbed gas could be quantified using the proposed material balance principle and iterative method. The rank of parameters that influence the ultimate recovery is the following: half-length of hydraulic fracture, induced fracture length/hydraulic fracture spacing, hydraulic fracture spacing, conductivity of induced fractures, conductivity of hydraulic fracture, and induced fracture spacing.     

煤基质中甲烷扩散特征及其对气井产能的影响

扩散是煤层甲烷运移的关键环节之一,而目前有关煤层中甲烷扩散特征的认识并不充分.以沁水盆地南部高煤阶煤层气藏为例,应用微纳渗流力学理论分析了煤基质中气体扩散模式及定量表征参数;应用Simed软件开展了扩散性能对不同煤体结构煤层气排采规律的影响数值研究.结果表明:煤层甲烷的扩散受化学势梯度的驱动,产气过程中体相扩散、努森扩散和构型扩散模式并存且呈动态变化;甲烷扩散性能受气体温度、压力、气体种类、水分以及基质孔隙结构共同影响,基质孔隙吸附甲烷会改变微孔孔径并影响扩散路径的空间形态;煤基质中甲烷的扩散是非热力平衡过程,扩散系数是吸附量的函数.基于拟稳态扩散的数值研究表明,扩散性能强弱对于长期累计产气量几乎没有影响,而对短期产气速率具有较大的影响;扩散性能弱的,产气速率峰值较低,但峰值之后的一段时间内产气速率相对较高;与高渗煤层相比,低渗构造煤层的产气速率对吸附时间常数更敏感.      

粘土衬垫中渗透系数与扩散系数的关系

扩散系数和渗透系数是设计与评价垃圾填埋场衬垫等环境工程研究时需要确定的重要参数。通过分析粘土衬垫材料中渗透系数和扩散系数的物理意义和确定方法,在土多孔介质微观结构分析的基础上得到渗透系数和扩散系数的关系表达式,并基于蒙脱石层间Poiseuille定律得到膨润土有效扩散系数的计算公式。验证表明,在一定精度范围内文中表达式是有效的。得出的渗透系数和扩散系数的关系表达式,对于根据已有渗透系数的研究成果来预测和分析扩散系数是有意义的。      

Numerical Modeling of Natural Fracture Distributions in Shale

The production efficiency of shale gas is affected by the interaction between hydraulic and natural fractures. This study presents a simulation of natural fractures in shale reservoirs, based on a discrete fracture network (DFN) method for hydraulic fracturing engineering. Fracture properties of the model are calculated from core fracture data, according to statistical mathematical analysis. The calculation results make full use of the quantitative information of core fracture orientation, density, opening and length, which constitute the direct and extensive data of mining engineering. The reliability and applicability of the model are analyzed with regard to model size and density, a calculation method for dominant size and density being proposed. Then, finite element analysis is applied to a hydraulic fracturing numerical simulation of a shale fractured reservoir in southeastern Chongqing. The hydraulic pressure distribution, fracture propagation, acoustic emission information and in situ stress changes during fracturing are analyzed. The results show the application of fracture statistics in fracture modeling and the influence of fracture distribution on hydraulic fracturing engineering. The present analysis may provide a reference for shale gas exploitation.     

离散裂隙网络对页岩气井产能影响的数值模拟

页岩作为典型的非常规储层,基质孔隙小,渗透率极低,水平井多级水力压裂为其商业开发的主要手段。准确模拟页岩气产能,应同时考虑水力裂隙和天然裂隙的渗流。基于离散裂隙模型和等效连续模型建立页岩气渗流数学模型,利用有限元分析方法进行数值求解,研究不同走向裂隙组对页岩气井产能的影响。研究认为,页岩基质为气体的生产提供了主要气源,天然裂隙作为渗流的主要通道,将气体输送到水力裂缝,进而到达井筒。模拟结果表征,离散裂隙的渗流特征对于页岩气井的产能有重要影响。根据页岩储层的天然裂隙走向,可以优化相应的水平井方位。对于二维离散裂隙网络模型,水平井沿着2个裂隙组夹角的平分线更有利于生产。      

Regional fracture network permeability using outcrop scale measurements

Estimating the hydraulic properties of fractured aquifers is challenging due to the complexity of structural discontinuities that can generally be measured at a small scale, either in core or in outcrop, but influence groundwater flow over a range of scales. This modeling study uses fracture scanline data obtained from surface bedrock exposures to derive estimates of permeability that can be used to represent the fractured rock matrix within regional scale flow models. The model is developed using PETREL, which traditionally benefits from high resolution data sets obtained during oil and gas exploration, including for example seismic data, and borehole logging data (both lithological and geophysical). The technique consists of interpreting scanline fracture data, and using these data to generate representative Discrete Fracture Network (DFN) models for each field set. The DFN models are then upscaled to provide an effective hydraulic conductivity tensor that represents the fractured rock matrix. For each field site, the upscaled hydraulic conductivities are compared with estimates derived from pumping tests to validate the model. A hydraulic conductivity field is generated for the study region that captures the spatial variability of fracture networks in pseudo-three dimensions from scanline data. Hydraulic conductivities estimated using this approach compare well with those estimated from pumping test data. The study results suggest that such an approach may be feasible for taking small scale fracture data and upscaling these to represent the aquifer matrix hydraulic properties needed for regional groundwater modeling.     

低透煤层井下长钻孔水力压裂增透技术

针对我国低透气性煤层普遍存在瓦斯抽采效果差的现状,提出了利用大直径长钻孔水力压裂对煤层进行增透的技术措施,探讨了长钻孔水力压裂增透机理,并进行了煤矿井下煤层水力压裂瓦斯抽采试验。在成功施工顺层长钻孔的基础上,研发了一套适合井下水力压裂施工的快速封孔工具组合,分析了压裂过程中参数变化规律,提出了水力压裂影响范围、压裂效果和瓦斯抽采效果评价方法,并进行了考察和评价。研究表明:该技术克服了传统井下水力压裂存在的封孔质量差、压裂影响范围小等问题,压裂后煤层透气性系数提高了2.67倍,压裂最大影响半径达到了58 m,压裂后连续抽采130 d累计抽采纯瓦斯量为31.39万m3,日最高抽采量2 668 m3,瓦斯体积分数平均70.05%,百米钻孔瓦斯抽采纯量达到0.55 m3/min。      

Mapping the hydraulic connection between a coalbed and adjacent aquifer: example of the coal-seam gas resource area,north Galilee Basin,Australia

Coal-seam gas production requires groundwater extraction from coal-bearing formations to reduce the hydraulic pressure and improve gas recovery. In layered sedimentary basins, the coalbeds are often separated from freshwater aquifers by low-permeability aquitards. However, hydraulic connection between the coalbed and aquifers is possible due to the heterogeneity in the aquitard such as the existence of conductive faults or sandy channel deposits. For coal-seam gas extraction operations, it is desirable to identify areas in a basin where the probability of hydraulic connection between the coalbed and aquifers is low in order to avoid unnecessary loss of groundwater from aquifers and gas production problems. A connection indicator, the groundwater age indictor (GAI), is proposed, to quantify the degree of hydraulic connection. The spatial distribution of GAI can indicate the optimum positions for gas/water extraction in the coalbed. Depressurizing the coalbed at locations with a low GAI would result in little or no interaction with the aquifer when compared to the other positions. The concept of GAI is validated on synthetic cases and is then applied to the north Galilee Basin, Australia, to assess the degree of hydraulic connection between the Aramac Coal Measure and the water-bearing formations in the Great Artesian Basin, which are separated by an aquitard, the Betts Creek Beds. It is found that the GAI is higher in the western part of the basin, indicating a higher risk to depressurization of the coalbed in this region due to the strong hydraulic connection between the coalbed and the overlying aquifer.     

Implications for focused fluid transport at the northern Cascadia accretionary prism from a correlation between BSR occurrence a d near-sea-floor reflectivity anomalies imaged in a multi-frequency seismic data set

 A high-resolution seismic survey was carried out at the accretionary prism on the continental slope off Vancouver Island, Canada. Two GI-Gun data sets with different source frequency ranges of 50–150 and 100–500 Hz were combined with 4 kHz narrow-beam echosounding data (Parasound). The data allow spatial correlation between a gas hydrate bottom simulating reflector (BSR) and distinct areas of high near-sea-floor reflectivity. An integrated interpretation of the multi-frequency data set provides insight into the regional distribution of tectonically induced fluid migration and gas hydrate formation in the vicinity of ODP Leg 146 Sites 889 and 890. The BSR at the base of the gas hydrate stability field is observed within accreted and deformed sediments, but appears to be absent within bedded slope basin deposits. It is suggested that these basin deposits inhibit vertical fluid flow and prevent the formation of a BSR, whereas the hydraulic conductivity of the accreted sediments is sufficiently high to allow for pervasive gas migration. An elevation of the BSR beneath the flanks of a topographic high is interpreted as an indicator for local upflow of warm fluids along permeable pathways within outcropping accreted sediments. Parasound data reveal discontinuous zones of high reflectivity at or directly beneath the sea floor, which may indicate local cementation of surface sediments. In combination with GI-Gun data, the occurrence of these reflective areas can be related to the location of slope sedimentary basins acting as hydraulic seals. It is proposed that the seals sometimes fail along faults extending beneath the BSR, leading to focused upflow of methane-bearing fluid and the formation of carbonate pavements at the sea floor. Received: 9 November 1998 / Accepted: 6 April 1999     

利用滨海地下水系统对双频潮汐的响应识别含水层压力传导系数

含水层的压力传导系数是地下水溶质运移及扩散的重要参数,通常压力传导系数由抽水试验确定,即通过抽水给地下水系统一个扰动,然后监测地下水水位的响应,进而计算压力传导系数.对滨海地区含水层来说,潮汐波动就是天然的抽(注)水试验.潮汐由不同频率的分潮构成,前两项主频潮汐基本可代表潮汐主要特征.利用地下水水位对潮汐的响应,识别含...     

Production rate analysis of multiple-fractured horizontal wells in shale gas reservoirs by a trilinear flow model

Most multiple-fractured horizontal wells experience long-term linear flow due to the ultralow permeability of shale gas reservoirs. Considering the existence of natural fractures caused by compression and shear stresses during the process of tectonic movement or the expansion of high-pressure gas, a shale gas reservoir can be more appropriately described by dual-porosity medium. Based on the assumption of slab dual-porosity, this paper uses the trilinear flow model to simulate the transient production behavior of multiple-fractured horizontal wells in shale gas reservoirs, which takes the desorption of adsorbed gas, Knudsen diffusion and gas slippage flow in the shale matrix into consideration. Production decline curves are plotted with the Stehfest numerical inversion algorithm, and sensitivity analysis is done to identify the most influential reservoir and hydraulic fracture parameters. It was found that the density and permeability of the natural fracture network are the most important parameters affecting the production dynamics of multiple-fractured horizontal wells in shale gas reservoirs. The higher the density and permeability of the natural fractures are, the shorter the time is required to exploit the same amount of reserve, which means a faster investment payoff period. The analytical model presented in this paper can provide some insight into the reserve evaluation and production prediction for shale gas reservoirs.     

Stochastic analysis of the effect of spatial variability of diffusion parameters on radionuclide transport in a low permeability clay layer

Most studies that incorporate subsurface heterogeneity in groundwater flow and transport models only analyze and simulate the spatial variability of hydraulic conductivity. Heterogeneity of the other flow and transport parameters are usually neglected. This approach is often justified, but there are, however, cases in which disregarding the heterogeneity of the other flow and transport parameters can be questionable. In low permeability media, for instance, diffusion is often the dominant transport mechanism. It therefore seems logical to incorporate the spatial variability of the diffusion parameters in the transport model. This study therefore analyses and simulates the spatial variability of the effective diffusion coefficient and the diffusion accessible porosity with geostatistical techniques and incorporates their heterogeneity in the transport model of a low permeability formation. The formation studied was Boom clay (Belgium), a candidate host rock for the deep geological disposal of high-level radioactive waste. The calculated output radionuclide fluxes of this model are compared with the fluxes calculated with a homogeneous model and a model with a heterogeneous hydraulic conductivity distribution. This analysis shows that the heterogeneity of the diffusion parameters has a much larger effect on the calculated output radionuclide fluxes than the heterogeneity of hydraulic conductivity in the low permeability medium under study.     

Geomechanical Characteristics of Gas Shales: A Case Study in the North Perth Basin

Gas shales are one type of unconventional reservoirs which have attracted significant attention for gas production in recent years. Gas production from very tight shales requires employment of hydraulic fracturing as a stimulation technique. To design hydraulic fracture operation the mechanical properties of the targeted and surrounding formations should be estimated. Also, the magnitude and orientation of in situ stresses in the field need to be known to estimate the fracture initiation and propagation pressures. This study focuses on gas shale characteristics in the North Perth Basin and uses data corresponding to well Arrowsmith-2 (AS-2) which is the first dedicated shale gas well drilled in Western Australia. A log-based analysis was used to build the rock mechanical model (RMM). The RMM results were used to set up a hydraulic fracturing laboratory experiment. The test was done in the presence of three principal stresses to mimic the real field stress conditions. The test results include the pressure–time curve which was used to estimate the initiation and propagation pressure at that depth. The results were used to draw some practical conclusions related to hydraulic fracturing operation in the field.