WO2020056750A1 - 一种页岩气藏介质结构耦合及缝网形态判识方法 - Google Patents

一种页岩气藏介质结构耦合及缝网形态判识方法 Download PDF

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WO2020056750A1
WO2020056750A1 PCT/CN2018/107074 CN2018107074W WO2020056750A1 WO 2020056750 A1 WO2020056750 A1 WO 2020056750A1 CN 2018107074 W CN2018107074 W CN 2018107074W WO 2020056750 A1 WO2020056750 A1 WO 2020056750A1
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stress
fracture
shale
fracture network
morphology
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PCT/CN2018/107074
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English (en)
French (fr)
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朱维耀
宋智勇
岳明
刘昀枫
陈震
马东旭
刘文超
亓倩
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北京科技大学
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Priority to PCT/CN2018/107074 priority Critical patent/WO2020056750A1/zh
Priority to US16/620,657 priority patent/US11371344B2/en
Publication of WO2020056750A1 publication Critical patent/WO2020056750A1/zh
Priority to AU2020100760A priority patent/AU2020100760A4/en

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    • G01V20/00—
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • E21B49/02—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N3/00—Investigating strength properties of solid materials by application of mechanical stress
    • G01N3/08—Investigating strength properties of solid materials by application of mechanical stress by applying steady tensile or compressive forces
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/20—Computer models or simulations, e.g. for reservoirs under production, drill bits
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N2203/00—Investigating strength properties of solid materials by application of mechanical stress
    • G01N2203/02—Details not specific for a particular testing method
    • G01N2203/026—Specifications of the specimen
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/62—Physical property of subsurface
    • G01V2210/624—Reservoir parameters
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/64—Geostructures, e.g. in 3D data cubes
    • G01V2210/646—Fractures

Definitions

  • the invention relates to the technical field of oil and natural gas extraction, in particular to a method for identifying structural coupling of shale gas reservoirs and fracture network morphology.
  • China's natural gas dependence was as high as 39%, and it is expected to approach 50% by 2035.
  • the country faces severe oil and gas security issues.
  • China's shale gas reservoirs are rich in resources.
  • China's recoverable shale gas resources are about 36 trillion cubic meters, accounting for about 20% of the world's total.
  • China's shale gas reservoirs have a burial depth (generally between 1500 and 4000 meters, the deepest being 6950 meters), low permeability (permeability between 0.01 and 1mD), microfracture development, and multiscale flow. Complex mechanism.
  • Reservoir fracturing reform is the main way to improve the development effect of shale gas reservoirs. It promotes the formation of a multi-scale pore-fracture network consisting of nanometer pores, micro-fractures, and artificial fractures in shale reservoirs. Non-linear flow characteristics. During the exploitation of shale reservoirs, nano-micron pores, micro-fractures, and artificial fractures are coupled by seepage and stress fields. The mechanism is complex and non-linear. At present, there are no technologies and methods for observing and monitoring fracture morphology. Establish a multi-media coupling and fracture network identification method for shale gas reservoirs.
  • the technical problem to be solved by the present invention is to provide a method for structural coupling of shale gas reservoirs and identification of fracture network patterns.
  • the method includes the following steps:
  • K K 0 e -b ( ⁇ - ⁇ p) ,
  • shale reservoirs have micro-fracture development characteristics, ⁇ is 1.
  • the stress sensitivity constant b is the basis for distinguishing the shape of the seam mesh.
  • K and Q current gas production
  • k / k0 q / q0.
  • the index of normalized flow and effective stress can be obtained. Relationship; therefore, the process of drawing the morphological identification plate of the fracture network in step (4) includes: drawing the stress sensitivity plates of different morphologies of the fracture network based on the indoor core stress sensitivity experiment in step (2), where the abscissa is valid Stress, the ordinate is the normalized flow parameter.
  • the normalized flow parameter is the ratio of the daily gas production Q to the daily gas production peak Q max .
  • the formed plate can be applied to actual fracturing wells, and the fracturing fracture morphology can be directly identified by real-time effective stress and normalized flow, which has profound effects on the implementation of volume fracturing in shale gas reservoirs and the formulation of development work systems. significance.
  • FIG. 1 is a flow chart of a method for identifying a medium structure coupling and a fracture network in a shale gas reservoir according to the present invention
  • FIG. 2 is a schematic view of different shapes of the sewing net in the present invention, wherein (a) is a feather-like sewing net, (b) is a cluster-like sewing net, (c) is a mesh-like sewing net, and (d) is a tree-like sewing net;
  • Figure 3 shows the stress sensitivity characteristics of different seam morphologies.
  • the invention provides a method for structural coupling and fracture network identification of shale gas reservoir media.
  • the present invention is based on an indoor core experiment of a shale gas reservoir in China, and summarizes the methods for identifying the structural coupling of the shale gas reservoir and the fracture network morphology. With this method, the volume of fracturing shale gas reservoirs can be formed. Quantitative characterization of complex seam networks is of great significance to the actual development of the site and the prediction of recovery factor.
  • the matrix shale stress-sensitivity test experiment was performed at room temperature and normal pressure, and nitrogen was used as the experimental gas for simulating natural gas.
  • Confining equipment uses high-precision plunger-driven pumps.
  • the back pressure control system uses the BP-100 air spring back pressure valve produced by the American company, and uses a high-precision multi-stage plunger drive pressure pump to control.
  • the experimental method adopted is the "pressure difference-flow method", and the effective stresses selected in the experiment are 4MPa, 5MPa, 7MPa, 9MPa, 11MPa, 13MPa, 16MPa, 19MPa, 22MPa.
  • the experiment set back pressure of 1MPa and inlet pressure of 3MPa and kept constant.
  • the core is installed in the core holder, the initial value of the instrument is reset to zero, the confining pressure is increased to 4 MPa, and the back pressure is increased to 1 MPa.
  • the artificial fracturing rock sample has a large permeability, and the “differential pressure-flow method” experiment has a large error. Therefore, the overburden porous infiltration meter KFSY / T08-055 is used for testing.
  • the test fluid is high-purity nitrogen.
  • the selected core is dried in a constant temperature box at 105 ° C for 48 hours.
  • the pressure difference between inlet and outlet is 2MPa.
  • the permeability is also dimensionlessly treated, which is expressed as K / K 0 , and K 0 is the initial permeability. See Figure 2 for details.
  • the shale reservoir has micro-fracture development characteristics, so ⁇ is approximately equal to 1.
  • the pores of the reservoir are compressed under the influence of rock pressure in the overlying formation. After leaving the gas reservoir conditions, the pressure on the rock skeleton is relieved, and some pore channels inside the reservoir will open or become larger. .
  • the low effective stress interval in the experiment cannot reflect the real reservoir situation.
  • the initial effective pressure of the original formation should be used as a starting point to test the stress sensitivity of the shale gas reservoir.
  • the buried depth of the reservoir in the target area is about 1600m.
  • the overlying formation pressure and pore pressure of the shale reservoir are about 34MPa and 25MPa, respectively. Therefore, an effective pressure of 9MPa should be selected to evaluate the effectiveness of the reservoir. Start of stress.
  • the stress sensitivity constant is a parameter reflecting the degree of deformation of the porous medium with stress, which is related to the physical properties of the rock itself and the shape of the fracture network. Based on all the experimental points, the stress sensitivity constants were calculated from 0.101 MPa -1 to 0.322 MPa -1 ; among them, the range of stress sensitivity constants for different forms of seam mesh is shown in Table 1.

Abstract

一种页岩气藏介质结构耦合及缝网形态判识方法，属于石油及天然气开采技术领域。首先利用改进的巴西压劈实验对页岩岩心进行压裂试验，并对缝网形态进行分类；其次进行不同裂缝形态的岩心进行页岩基质－裂缝结构与应力敏感性实验测试；再次，根据室内岩心数据求取不同缝网形态的应力敏感常数范围；最后，基于室内岩心应力敏感性实验，结合生产实际，绘制缝网形态判识图版。该图版可以应用于实际压裂井，直接通过实时的有效应力和归一化流量判识压裂裂缝形态，对页岩气藏体积压裂实施效果及制定开发工作制度具有深远意义。

Description

一种页岩气藏介质结构耦合及缝网形态判识方法 技术领域
本发明涉及石油及天然气开采技术领域，特别是指一种页岩气藏介质结构耦合及缝网形态判识方法。
背景技术
2017年我国天然气对外依存度高达39％，预计2035年接近50％，国家面临严峻的油气安全问题。我国页岩气藏资源丰富，截至2017年中国页岩气可采资源量约36万亿立方米，约占全球20％。与国外页岩气藏相比，我国页岩气藏具有埋藏深(一般在1500～4000米，最深达6950米)、渗透率低(渗透率在0.01～1mD)、微裂缝发育、多尺度流动机理复杂的特点。
储层压裂改造是改善页岩气藏开发效果的主要方式，促使页岩储层中形成纳微米孔隙-微裂缝-人工裂缝组成的多尺度孔缝网络，故页岩气储层中存在强非线性流动特征。页岩储层开采过程中，纳微米孔隙、微裂缝、人工裂缝结构受渗流场、应力场耦合作用，机理复杂、非线性强，目前尚无观察和监测裂缝形态的技术及方法，因此亟需建立页岩气藏多重介质耦合及缝网形态判识方法。
发明内容
本发明要解决的技术问题是提供一种页岩气藏介质结构耦合及缝网形态判识方法。
该方法包括步骤如下：
(1)对缝网形态进行分类：使用改进的巴西压劈实验对页岩岩心进行压裂试验，将压裂裂缝形态划分为：树状缝网、羽状缝网、簇状缝网及网状缝网；其中，改进的巴西压劈实验为发明专利《一种页岩岩芯的裂缝扩展分析装置及分析方法》(CN201410548672.6)中所记载的方法；
(2)进行页岩基质-裂缝结构与应力敏感性实验测试：选择步骤(1)中不同裂缝形态的岩心，通过岩心驱替实验(设定有效应力范围为4MPa～22MPa)进行页岩基质－裂缝结构与应力敏感性实验测试，记录岩心渗透率、有效应力参数；
(3)求取不同缝网形态的应力敏感常数：根据步骤(2)中不同裂缝形态岩心在不同应力条件下的渗透率及有效应力参数，采用指数函数的形式拟合实验数据，并求取应力敏感常数；
(4)绘制缝网形态判识图版：根据步骤(3)中得到的四种缝网形态的实测应力敏感常数，建立有效应力和生产井流量的模型，并将流量参数归一化处理，最终形成缝网形态判识图版。
其中，步骤(3)中采用指数函数的形式拟合实验数据具体为：
根据有效应力的方法，有效应力与渗透率变化率的数学表达式为：
K＝K 0e -b(σ-αp)，
式中：σ为上覆地层压力，单位为MPa；p为储层孔隙压力，单位为MPa；α为有效应力系数；K 0为有效应力为零时的岩石渗透率，单位为10 -3μm 2；K为任意地层压力条件下的渗透率，单位为10 -3μm 2；b为应力敏感常数，单位为Mpa -1；其中，页岩储层具有微裂缝发育特征，α取1。
应力敏感性常数b是区分缝网形态的依据，由于实际生产过程中，K和Q(当日产气量)正相关，即k/k0＝q/q0，可得归一化流量与有效应力的指数关系；由此，步骤(4)中绘制缝网形态判识图版的过程包括：基于步骤(2)中室内岩心应力敏感性实验，绘制不同缝网形态应力敏感性图版，其中，横坐标为有效应力，纵坐标为归一化流量参数。
其中，归一化流量参数为当日产气量Q与日产气量峰值Q max的比值。
本发明的上述技术方案的有益效果如下：
上述方案中，形成的图版可以应用于实际压裂井，直接通过实时的有效应力和归一化流量判识压裂裂缝形态，对页岩气藏体积压裂实施效果及制定开发工作制度具有深远意义。
附图说明
图1为本发明的页岩气藏介质结构耦合及缝网形态判识方法流程图；
图2为本发明中不同缝网形态示意图，其中，(a)为羽状缝网，(b)为簇状缝网，(c)为网状缝网，(d)为树状缝网；
图3为不同缝网形态应力敏感性特征曲线。
具体实施方式
为使本发明要解决的技术问题、技术方案和优点更加清楚，下面将结合附图及具体实施例进行详细描述。
本发明提供一种页岩气藏介质结构耦合及缝网形态判识方法。
如图1所示，该方法步骤为：
(1)对缝网形态进行分类：使用改进的巴西压劈实验对页岩岩心进行压裂试验，将压裂裂缝形态划分为：树状缝网、羽状缝网、簇状缝网及网状缝网；
(2)进行页岩基质-裂缝结构与应力敏感性实验测试：选择步骤(1)中不同裂缝形态的岩心，通过岩心驱替实验进行页岩基质－裂缝结构与应力敏感性实验测试，记录岩心渗透率、有效应力参数；
(3)求取不同缝网形态的应力敏感常数：根据步骤(2)中不同裂缝形态岩心在不同应力条件下的渗透率及有效应力参数，采用指数函数的形式拟合实验数据，并求取应力敏感常数；
(4)绘制缝网形态判识图版：根据步骤(3)中得到的四种缝网形态的实测应力敏感常数，建立有效应力和生产井流量的模型，并将流量参数归一化处理，最终形成缝网形态判识图版。
在具体设计中，本发明立足中国某页岩气藏室内岩心实验，总结了页岩气藏介质结构耦合及缝网形态判识方法，以此方法可以对页岩气藏体积压裂后形成的复杂缝网进行量化表征，对现场实际开发及采收率预测具有重大意义。
具体的实施方式如下：
(1)页岩基质－裂缝结构与应力敏感性实验测试
基质页岩应力敏感测试实验在室温常压下进行，使用氮气作为模拟天然气的实验气体。围压设备使用高精度柱塞驱替泵。回压控制系统使用美国公司生 产的BP-100空气弹簧回压阀，使用高精确度多级柱塞驱替压力泵进行控制。采用的实验方法为“压差-流量法”，实验分别选取的有效应力为4MPa，5MPa，7MPa，9MPa，11MPa，13MPa，16MPa，19MPa，22MPa。实验设定回压1MPa、进口压力3MPa并保持恒定。
实验步骤：
①将岩心在烘箱恒温70℃下烘干50h，测定长度、直径、重量及孔隙度、渗透率等基础数据；
②岩心装进岩心夹持器内，把仪器初始值归零，加围压至4MPa，并加回压至1MPa不变；
③整个实验过程中，注入压力3MPa保持恒定，做气体单相渗流实验；
④当渗流状态稳定时，记录下初始有效应力下的岩样渗透率，按照预先设计的有效应力值调整围压，记录下围压增加过程中不同的渗透率K，按计划测定不同围压有效应力值，到达最大有效应力后，按照升压实验拟定的压力点逐步降低压力，并测定渗透率，实验结束。
其中，人工压裂岩样渗透率较大，采用“压差-流量法”实验误差较大，因此采用覆压孔渗仪KFSY/T08-055进行测试，实验流体采用的是高纯氮，对所选岩心，在105℃的条件下，在恒温箱内烘干48小时。进出口压差为2MPa，通过测量4MPa，7MPa，14MPa，21MPa，27MPa。渗透率同样作了无因次处理，即表示为K/K 0，K 0为初始渗透率，详见图2。
实验结果与讨论：
页岩基质－裂缝结构与应力敏感性实验结果表明：页岩渗透率变化幅度较大，初始渗透率越低，下降幅度越大，主要是由于岩样的孔隙分布特征决定的，渗透率较低的岩样平均孔隙半径也较小，在有效应力改变时，小孔隙容易闭合进而导致渗透能力下降，相对于渗透率大的岩样更容易产生应力敏感的现象。
将实验曲线数据进行拟合，根据有效应力的方法，有效应力与渗透率变化率呈良好的指数关系。其数学表达式为：
K＝K 0e -b(σ-αp)
式中：σ为上覆地层压力，单位为MPa；p为储层孔隙压力，单位为MPa；α为有效应力系数；K 0为有效应力为零时的岩石渗透率，单位为10 -3μm 2；K为 任意地层压力条件下的渗透率，单位为10 -3μm 2；b为应力敏感常数，单位为Mpa -1，N.R.Warpinski和L.W.Teufel在1992年通过实验给出不同多孔介质的有效应力系数，认为裂缝发育的储层，α→1。页岩储层具有微裂缝发育特征，因此α近似等于1。
在气藏条件下，受上覆地层岩石压力的影响，储层的孔隙处于被压缩状态，脱离气藏条件后，岩石骨架承受的压力得到缓解，储层内部的部分孔隙通道将开启或变大。实验中的低有效应力区间不能反映真实储层的情况，若对储层进行评价，应以原始地层初始有效压力为起点来测试页岩气藏的应力敏感性。目标区储层埋藏深度为1600m左右，根据现场地层测试和测井等资料得到页岩储层上覆地层压力和孔隙压力分别为34MPa和25MPa左右，因此应选取有效压力9MPa为评价储层的有效应力起点。
将页岩岩样全部实验点和以储层有效应力为起点的渗透率与有效应力通过指数函数拟合，式中指数项系数即为应力敏感常数。应力敏感常数是反映多孔介质随应力变形程度的参数，与岩石自身的物理性质及压裂缝网形态相关。基于全部实验点计算得到应力敏感常数为0.101MPa -1～0.322MPa -1；其中，不同缝网形态的应力敏感常数范围如表1所示。
表1 不同缝网形态与应力敏感常数对应表
Figure PCTCN2018107074-appb-000001
从羽状缝、簇状缝、网状缝和树状缝四种不同的缝网形态进行分析，详见图3。该图版可以应用于实际压裂井，直接通过实时的有效应力和归一化流量判识压裂裂缝形态。
应用实例：
针对重庆某页岩气藏水平井，埋深1600m，地层初始压力35MPa，体积压裂初期日产气量20万方。目前的日产气量2万方，井底流压为15MPa。
根据原始地层压力和井底流压折算为地层岩石有效应力为20MPa，截止 目前日产气量下降90％，即Q/Q max＝0.1，即应力敏感常数为0.1151。从应力敏感常数范围表确定为树状缝网，这一结论可直接判识压裂裂缝网络形态为树状缝网，不需再次计算应力敏感常数。
以上所述是本发明的优选实施方式，应当指出，对于本技术领域的普通技术人员来说，在不脱离本发明所述原理的前提下，还可以做出若干改进和润饰，这些改进和润饰也应视为本发明的保护范围。

Claims (4)

  1. 一种页岩气藏介质结构耦合及缝网形态判识方法，其特征在于：包括步骤如下：
    (1)对缝网形态进行分类：使用改进的巴西压劈实验对页岩岩心进行压裂试验，将压裂裂缝形态划分为：树状缝网、羽状缝网、簇状缝网及网状缝网；
    (2)进行页岩基质-裂缝结构与应力敏感性实验测试：选择步骤(1)中不同裂缝形态的岩心，通过岩心驱替实验进行页岩基质－裂缝结构与应力敏感性实验测试，记录岩心渗透率、有效应力参数；
    (3)求取不同缝网形态的应力敏感常数：根据步骤(2)中不同裂缝形态岩心在不同应力条件下的渗透率及有效应力参数，采用指数函数的形式拟合实验数据，并求取应力敏感常数；
    (4)绘制缝网形态判识图版：根据步骤(3)中得到的四种缝网形态的实测应力敏感常数，建立有效应力和生产井流量的模型，并将流量参数归一化处理，最终形成缝网形态判识图版。
  2. 根据权利要求1所述的页岩气藏介质结构耦合及缝网形态判识方法，其特征在于：所述步骤(3)中采用指数函数的形式拟合实验数据具体为：
    根据有效应力的方法，有效应力与渗透率变化率的数学表达式为：
    K＝K 0e -b(σ-αp)，
    式中：σ为上覆地层压力，单位为MPa；p为储层孔隙压力，单位为MPa；α为有效应力系数；K 0为有效应力为零时的岩石渗透率，单位为10 -3μm 2；K为任意地层压力条件下的渗透率，单位为10 -3μm 2；b为应力敏感常数，单位为Mpa -1；其中，页岩储层具有微裂缝发育特征，α取1。
  3. 根据权利要求1所述的页岩气藏介质结构耦合及缝网形态判识方法，其特征在于：所述步骤(4)中绘制缝网形态判识图版的过程包括：基于步骤(2)中室内岩心应力敏感性实验，绘制不同缝网形态应力敏感性图版，其中，横坐标为有效应力，纵坐标为归一化流量参数。
  4. 根据权利要求3所述的页岩气藏介质结构耦合及缝网形态判识方法， 其特征在于：所述归一化流量参数为当日产气量与日产气量峰值的比值。
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