花岗岩储层测井解释方法研究及应用

针对花岗岩储层非均质性特点,采用了三重孔隙结构解释模型对其进行解释评价.该模型的储集空间包括基质、裂缝和孔洞三部分,随着储集空间的变化,可将该模型转化为孔隙型储层解释模型、孔洞型储层解释模型和裂缝型储层解释模型,这样就可适应多种储层性质的解释需要.由此利用常规测井资料计算了花岗岩储层的总孔隙度、基质孔隙度、孔洞孔隙度和裂缝孔隙度,利用岩心和电成像测井对裂缝孔隙度和孔洞孔隙度的计算结果进行标定和验证,并根据这些参数划分储层类型,计算含油气饱和度,划分油气水层.含油气饱和度的计算是采用反映储层孔隙结构变化的孔隙结构指数变m值,使阿尔奇公式适用于非均质花岗岩储层含油气饱和度的计算.应用上述测井解释方法,对目标井进行精细处理解释和综合评价,取得了很好的应用效果.     

塔河油田碳酸盐岩缝洞型储层的测井识别与评价方法研究

塔河油田奥陶系以碳酸盐岩为主，油气的主要储渗空间为裂缝和溶蚀孔洞，具有很强的非均质性．本文利用常规及成像测井资料，对碳酸盐岩缝洞型储层的识别与评价方法进行研究．为了综合各种测井方法识别裂缝，建立了综合裂缝概率模型，计算综合裂缝概率指示裂缝的发育程度．利用地层微电阻率扫描成像测井资料进行裂缝和溶蚀孔洞的定性、定量解释．定量计算的裂缝参数为：裂缝密度、裂缝长度、裂缝平均宽度、平均水动力宽度、裂缝视孔隙度；定量计算的溶蚀孔洞参数有：面孔率、孔洞密度．根据缝洞型储层孔隙空间类型及其中子孔隙度、补偿密度、声波、双侧向电阻率的测井响应物性特征，建立缝洞型碳酸盐岩储层复杂孔隙介质解释模型，用于确定裂缝、溶蚀孔洞孔隙度和评价储层．     

应用三重孔隙模型评价火成岩储层

火成岩岩性特殊,储层非均质性非常严重,裂缝、孔洞发育,属于典型的多重孔隙介质储层,定量计算火成岩储层基质和裂缝的孔隙度和饱和度是评价火成岩油气层的关键。由基质、天然裂缝和非连通孔洞组成的储层可以模拟成基质和裂缝的并联导电网络,非连通孔洞和基质／裂缝的组合的串联导电网络。采用密度测井资料求取总孔隙度,用深浅双侧向电阻率计算裂缝孔隙度,采用密闭取心分析的孔隙度作为基质孔隙度。通过建立以基质、天然裂缝和非连通孔洞组成的储层的三重孔隙解释模型,找到适合于火成岩缝洞型复杂储层的饱和度方程。将三重孔隙解释模型应用于松辽盆地北部火成岩储层,计算的含水饱和度平均相对误差由16．85％降低至12．42％,精度明显提高,为火成岩储层评价、储量计算与地质建模提供了定量参数。     

裂缝孔隙参数定量表征和刻度及影响因素分析

精确评价裂缝孔隙发育情况对于评价碳酸盐岩等裂缝性地层具有重要意义.评价裂缝孔隙的参数包括裂缝面孔率和裂缝孔隙度,根据两者的定义,对水平缝、低角度缝、倾斜缝、高角度缝和垂直缝分别建立了裂缝孔隙参数计算模型,对不同裂缝倾角、不同井径和不同窗长时的裂缝面孔率和裂缝孔隙度及两者比值进行数值模拟.模拟结果表明:对于低角度缝,窗长...     

碳酸盐岩储层常规测井评价方法

碳酸盐岩储层非均质性强、储集空间类型复杂多样,储层中流体性质的识别及有效厚度的划分比较困难,为了完成碳酸盐岩储层的常规测井评价,根据碳酸盐岩储层地质特征,将储层分为三种类型:1)裂缝+孔隙型储层,其孔隙度大于3.5%,其裂缝为规模较大的构造缝,其次是一些宏观裂缝,是碳酸盐岩储层中最好的储层;2)微裂缝+孔隙型储层,其孔隙度大于3.5%,其裂缝主要为储层微观孔、缝以及孔洞.3)裂缝层,其孔隙度小于3.5%,裂缝较发育,基质孔隙度和储层含油饱和度很小,接近于零,为裂缝层.基于以上三种类型的储层来建立测井地质评价模型,由于碳酸盐岩储层是典型的双重介质模型,分别建立两类孔隙空间的几何模型及流体模型,分别建立三种储层的空间几何模型和流体分布模型,每种模型又分为裂缝系统和岩块孔隙系统,在此基础上总结各种测井曲线的响应特征,分别给出储层参数计算的数理模型,基质岩块和裂缝孔隙度、渗透率和储层油气水饱和度,对裂缝的张开度也进行了定量计算,给出了储层流体性质及有效厚度的划分标准,最终完成碳酸盐岩的常规测井评价.     

用正演数值计算方法开展双侧向测井对裂缝的响应研究

采用有限元分析软件ANSYS对裂缝的双侧向测井视电阻率与裂缝孔隙度、泥浆电阻率、裂缝倾角和基岩电阻率的关系进行了计算. 在大量正演数据的基础上得出双侧向测井响应反演公式和裂缝孔隙度计算公式,提出更为精细的裂缝倾角的弹性划分模型,用双侧向视电阻率值近似估算裂缝倾角的方法,提高了利用双侧向测井求裂缝产状与裂缝孔隙度（裂缝宽度）的精度.     

流体饱和度对裂缝—孔隙岩石频变纵波速度及其各向异性的影响

流体饱和度会改变裂缝性储层的纵波速度,从而影响地层速度的频散特性及各向异性程度,导致储层地震响应特征复杂,储层预测多解性强,流体识别难度大.本文根据多相流体饱和裂缝性储层的特点,借助于Norris和KG模型,建立部分饱和裂缝-孔隙等效介质模型,给出频变地震波速度随流体饱和度变化的精确关系式.数值模拟结果表明,当气、水两相共存时,随着含水饱和度的增加,高频段纵波相速度逐渐增大,各向异性程度逐渐减小;低频段纵波相速度逐渐减小,各向异性程度不变;相速度频散及其各向异性程度逐渐增强.组合已有的孔隙弹性理论模型,对实验室人工裂缝-孔隙砂岩岩样的纵波速度进行拟合,计算得到的曲线与实验室测量散点值吻合度较高,表明组合模型在给定参数下的有效性.该研究能够为多相流体饱和裂缝性储层的地震响应特征分析奠定扎实的理论基础,为提高储层预测的确定性和流体识别的准确性提供可靠的理论依据.     

一种基于阵列声波测井的胶结指数计算方法在饱和度评价中的应用

利用饱和度公式评价储层含油性时,胶结指数一般在某一层位取某一固定值.在复杂岩性储层中,储层非均质性强,孔隙结构复杂,连通性差,导致胶结指数变化较大,利用常数胶结指数计算的含油饱和度精度降低,给储层测井评价带来了极大的困难.基于弹性介质理论,利用阵列声波数据得到地层骨架的剪切模量和体积模量,并计算出骨架的纵波速度.分析发现,地层和骨架的纵波速度比与地层孔隙度和胶结指数具有一定的函数关系,通过地层和骨架的纵波速度比和孔隙度可以计算出连续的胶结指数,进而得到地层饱和度.实验结果表明,本文方法计算得到的地层饱和度与岩心分析饱和度吻合较高,方法一定程度上克服了传统的饱和度模型在复杂岩性储层中的不适用性,为复杂岩性储层含油性准确评价提供了依据.     

基于三水导电模型的裂缝性致密砂岩测井解释方法与应用

裂缝性致密砂岩的解释模型是测井定量评价的基础。依据黄桥地区龙潭组地层裂缝性致密砂岩地质特点和孔隙空间的组成,利用三水模型分析了裂缝性致密砂岩的导电机理,提出了该地区的测井解释理论和方法,实现了组分孔隙度和饱和度的定量计算。应用表明,计算的三水导电组分孔隙度与核磁共振测井结果一致,测井解释结果与测试结果一致,认为该方法适用于该地区裂缝性致密砂岩的测井评价。     

DB气田非均质储层级别划分及常规测井识别方法

DB气田以裂缝-孔隙型、孔隙型岩屑砂岩储层为主,非均质性强,裂缝发育程度是决定产能高低的关键因素之一.立足于储层的录井、岩心分析和测井资料,开发了储层级别划分和常规测井识别储层级别的方法.首先,定义了每米产能指数作为标准化的产能参数;其次,基于产能参数与储层物性参数关系的考察,筛选综合物性参数(孔隙度和总渗透率的乘积)作为储层级别划分的评价指标,将DB气田储层分成了2个级别,给出了分级的物性标准;最后,应用主成分分析法计算了综合主成分,基于综合主成分与每米产能指数交会图给出了应用常规测井资料识别储层级别的标准.2口井的应用效果表明,依据上述方法划分及识别的储层级别与生产情况吻合得较好.     

岩石中裂纹孔隙率的实验测定

岩石中的孔隙按形状划分，可以大致分成孔洞和裂纹两类。孔洞的纵横比大，形状近似于球形，它与油气储藏有密切关系。孔洞孔隙度是岩石孔隙度的主要贡献。裂纹纵横比小，形状细长，它所造成的孔隙度是岩石总孔隙度的一小部分。但是岩石中裂纹的存在和裂纹孔隙度的变化，对于岩石的各向异性和S波的分裂有重要的影响。本文利用两类不同形状孔隙对流体静压力的不同响应，利用改变流体静压力的实验对岩石中的裂纹孔隙率进行了测定；实验得到的裂纹孔隙率和岩石裂纹的闭合压力，为了解岩石各向异性、S波分裂以及地壳动力学提供了基础数据。     

Rock skeleton models and seismic porosity inversion

By substituting rock skeleton modulus expressions into Gassmann approximate fluid equation, we obtain a seismic porosity inversion equation. However, conventional rock skeleton models and their expressions are quite different from each other, resuling in different seismic porosity inversion equations, potentially leading to difficulties in correctly applying them and evaluating their results. In response to this, a uniform relation with two adjusting parameters suitable for all rock skeleton models is established from an analysis and comparison of various conventional rock skeleton models and their expressions including the Eshelby-Walsh, Pride, Geertsma, Nur, Keys-Xu, and Krief models. By giving the two adjusting parameters specific values, different rock skeleton models with specific physical characteristics can be generated. This allows us to select the most appropriate rock skeleton model based on geological and geophysical conditions, and to develop more wise seismic porosity inversion. As an example of using this method for hydrocarbon prediction and fluid identification, we apply this improved porosity inversion, associated with rock physical data and well log data, to the ZJ basin. Research shows that the existence of an abundant hydrocarbon reservoir is dependent on a moderate porosity range, which means we can use the results of seismic porosity inversion to identify oil reservoirs and dry or water-saturated reservoirs. The seismic inversion results are closely correspond to well log porosity curves in the ZJ area, indicating that the uniform relations and inversion methods proposed in this paper are reliable and effective.     

On the tensorial nature of advective porosity

Field tracer tests indicate that advective porosity, the quantity relating advective velocity to Darcy flux, may exhibit directional dependence. Hydraulic anisotropy explains some but not all of the reported directional results. The present paper shows mathematically that directional variations in advective porosity may arise simply from incomplete mixing of an inert tracer between directional flow channels within a sampling (or support) volume ω of soil or rock that may be hydraulically isotropic or anisotropic. In the traditional fully homogenized case, our theory yields trivially a scalar advective porosity equal to the interconnected porosity ϕ, thus explaining neither the observed directional effects nor the widely reported experimental finding that advective porosity is generally smaller than ϕ. We consider incomplete mixing under conditions in which the characteristic time t_D of longitudinal diffusion along channels across ω is much shorter than the characteristic time t_H required for homogenization through transverse diffusion between channels. This may happen where flow takes place preferentially through relatively conductive channels and/or fractures of variable orientation separated by material that forms a partial barrier to diffusive transport. Our solution is valid for arbitrary channel Peclet numbers on a correspondingly wide range of time scales t_D ⩽ t ≪ t_H. It shows that the tracer center of mass is advected at a macroscopic velocity which is generally not collinear with the macroscopic Darcy flux and exceeds it in magnitude. These two vectors are related through a second-rank symmetric advective dispersivity tensor Φ. If the permeability k of ω is a symmetric positive-definite tensor, so is Φ. However, the principal directions and values of these two tensors are generally not the same; whereas those of k are a fixed property of the medium and the length-scale of ω, those of Φ depend additionally on the direction and magnitude of the applied hydraulic gradient. When the latter is large, diffusion has negligible effect on Φ and one may consider tracer mass to be distributed between channels in proportion to the magnitude of their Darcy flux. This is made intuitive through a simple example of an idealized fracture network. Our analytical formalism reveals the properties of Φ but is too schematic to allow predicting the latter accurately on the basis of realistic details about the void structure of ω and tracer mass distribution within it. Yet knowing the tensorial properties of Φ is sufficient to allow determining it indirectly on the basis of ω-scale hydraulic and tracer data, including concentrations that represent homogenized samples extracted from (or sensed externally across) an ω-scale plume.     

Characterization of permeability and porosity from nanosensor observations

In this paper, we investigate the information content in “nanosensors” with limited functionality that might be injected into a reservoir or an aquifer to provide information on the spatial distribution of properties. The two types of sensors that we consider are sensors that can potentially measure pressure at various times during transport, and sensors can be located in space by perturbations in electrical, magnetic, or acoustic properties. The intent of the study is to determine the resolution of estimates of properties that can be obtained from various combinations of sensors, various frequencies of observations, and various specifications on sensor precision.Our goal is to investigate the resolution of model estimates for various types of measurements. For this, we compute linearized estimates of the sensitivity of the observations to the porosity and permeability assuming gaussian errors in the pressure and location observations. Because the flow is one-dimensional and incompressible, observations of location are sensitive to the porosity between the injection location and the sensor location, while the location of particles is sensitive to the effective permeability over the entire interval from injector to producer. When only the pressure is measured but the location of the sensor is unknown, as might be the situation for a threshold sensor, the pressure is sensitive to both permeability and porosity only in the region between the injector and sensor.In addition to the linearized sensitivity and resolution analyses, Markov chain Monte Carlo sampling is used to estimate the posterior pdf for model variables for realistic (non-Gaussian) likelihood models. For a Markov chain of length one million samples approximately 200-500 independent samples are generated for uncertainty and resolution assessment. Results from the MCMC analysis are not in conflict with the linearized analysis.     

核磁共振测井孔隙度观测模式与处理方法研究

核磁共振（NMR）测井是确定地层孔隙度的有效方法,已经得到广泛应用.但是,在我国部分油田的应用中发现核磁测井孔隙度与常规孔隙度之间存在明显差异.本文对NMR测井孔隙度观测模式和处理方法进行研究,分析了NMR孔隙度误差的来源.针对富含蒙脱石、伊利石和伊/蒙混层粘土矿物的陆相沉积砂泥岩地层,根据这些粘土矿物的NMR横向弛豫时间T2值特征以及孔隙度处理结果得到的40 ms附近孔隙度分配量不合适,提出了新的观测模式和处理方法,并用实验验证了新方法的可行性.     

Modeling fracture porosity development using simple growth laws

A model of porosity development has been developed to investigate general relationships between simple fracture aperture growth laws and fracture porosity in evolved fracture arrays in aquifers. The growth of fracture apertures in two-dimensional orthogonal arrays with initially spatially uncorrelated lognormal aperture distributions has been studied, where aperture growth rate is proportional to an exponent of the flow rate through each fracture. The evolved arrays show geometrical phase changes as a function of the aperture growth rate exponent, e, and the standard deviation of the initial aperture distribution, sigma(z). Low values of e and sigma(z) lead to bimodal aperture distributions, where apertures parallel to flow are preferentially enlarged. At moderate values of e and sigma(z), there is a transition to a regime of more complex geometries consisting of networks of channel-like structures of preferentially enlarged apertures. At larger values of e, array-spanning channel-like paths of preferentially enlarged apertures develop, where the tortuosity of the channel-like paths is a linear function of sigma(z). Following an initial growth phase, during which dynamically stable aperture configurations develop, arrays undergo simple amplification. The geometry of the evolved aperture fields is diverse and they can be highly complex; consequently, parameterization and prediction of their evolution in terms of the initial aperture distributions and growth rate laws is not trivial.     

Factors controlling permeability–porosity relationships in magma

A model has been developed to investigate the sensitivity of magma permeability, k, to various parameters. Power-law relationships between k and porosity J are revealed, in agreement with previous experimental and theoretical studies. These relationships take the form % MathType!MTEF!2!1!+- % feaaeaart1ev0aaatCvAUfKttLearuavTnhis1MBaeXatLxBI9gBae % rbd9wDYLwzYbWexLMBbXgBcf2CPn2qVrwzqf2zLnharyavP1wzZbIt % LDhis9wBH5garqqtubsr4rNCHbGeaGqiVCI8FfYJH8sipiYdHaVhbb % f9v8qqaqFr0xc9pk0xbba9q8WqFfeaY-biLkVcLq-JHqpepeea0-as % 0Fb9pgeaYRXxe9vr0-vr0-vqpWqaaeaabiGaciaacaqabeaadaabau % aaaOqaaiqbdUgaRzaajaGaeyypa0Jaem4AaSMaei4la8IaemOCai3a % aWbaaSqabeaacqaIYaGmaaGccqGH9aqpcqWGHbqycqGGOaakcqaHgp % GzcqGHsislcqaHgpGzdaWgaaWcbaGaem4yamMaemOCaihabeaakiab % cMcaPmaaCaaaleqabaGaemOyaigaaaaa!4CE4! [^(k)] = k/r² = a(f- f_cr )^b\hat k = k/r^2 = a(\phi - \phi _{cr} )^b where r is the mean bubble radius, J_cr is the percolation threshold below which permeability is zero, and a and b are constants. It is discovered that % MathType!MTEF!2!1!+- % feaaeaart1ev0aaatCvAUfKttLearuavTnhis1MBaeXatLxBI9gBae % rbd9wDYLwzYbWexLMBbXgBcf2CPn2qVrwzqf2zLnharyavP1wzZbIt % LDhis9wBH5garqqtubsr4rNCHbGeaGqiVCI8FfYJH8sipiYdHaVhbb % f9v8qqaqFr0xc9pk0xbba9q8WqFfeaY-biLkVcLq-JHqpepeea0-as % 0Fb9pgeaYRXxe9vr0-vr0-vqpWqaaeaabiGaciaacaqabeaadaabau % aaaOqaaiqbdUgaRzaajaGaeyOeI0IaeqOXdygaaa!3CDB! [^(k)] - f\hat k - \phi relationships are independent of bubble size. The percolation threshold was found to lie at around 30% porosity. Polydisperse bubble-size distributions (BSDs) give permeabilities around an order of magnitude greater than monodisperse distributions at the same porosity. If bubbles are elongated in a preferred direction then permeability in this direction is increased, but, perpendicular to this direction, permeability is unaffected. In crystal-free melts the greatest control on permeability is the ease of bubble coalescence. In viscous magmas, or when the cooling time-scale is short, bubble coalescence is impeded and permeability is much reduced. This last effect can cause variations in permeability of several orders of magnitude.     

岩石的临界孔隙度反演及横波预测(英文)

临界孔隙度模型是利用岩石的临界孔隙度来计算岩石骨架的弹性模量,岩石的临界孔隙度值受到很多因素的影响,而实际应用中通常无法获得准确的临界孔隙度值,只能选取经验临界孔隙度值,就会给岩石物理建模带来误差。本文提出了一种利用纵波速度反演岩石的临界孔隙度的方法,并且把它应用于横波预测中。实验室和测井数据应用结果表明本文提出的方法可以降低以往选取经验值带来的不确定性,并且能够为横波预测提供准确的临界孔隙度值,提高了横波预测的精度。     

地震密度反演及地层孔隙度估计

地层密度直接与孔隙度、孔隙流体类型、饱和度和骨架矿物成分有关.本文通过理论分析和计算,讨论了油气藏储层物性参数变化引起的密度变化及密度变化对地震波速度、阻抗和振幅的影响,提出了基于完全纵波方程的全波形地震密度反演和孔隙度估计方法,克服了常规地震密度反演对地震数据更多处理引起的信号畸变,提高了地震密度反演和地层孔隙度估计的精度.该方法采用波场导数的时间积分和多炮求和,对地震数据中的噪声具有比较强的压制作用.理论模型研究表明该方法是可行的.通过对我国西部某气田实际数据处理、分析和反演,获得了地层密度和孔隙度,结果与测井基本吻合,证明了预测结果的准确性和方法的有效性,从而为后续的有效储层预测和储量计算提供了可靠的数据.     

Mixing-induced precipitation and porosity evolution in porous media

The dynamics of porosity evolution are explored during mineral precipitation that is induced by the mixing of two fluids of different compositions. During mineral precipitation in geological formations, the physical parameters that characterize the porous matrix, such as porosity and specific surface area, can change significantly. A series of coupled equations that determine the changes in porosity is outlined and solved for a 2D model domain using a finite element scheme. Using model parameters equivalent to those for calcite precipitation in a saline system, the evolution of porosity is examined for two types of porous media: (1) an initially homogeneous system and (2) a heterogeneous system containing high porosity regions that serve initially as preferential flow paths. In addition, the influence of two different expressions that relate specific surface area to porosity is explored. The simulations in both domains indicated that porosity was reduced primarily in the regions in which significant degrees of mixing occurred. Although an effective barrier was created in these regions, the fluids bypassed the clogged areas allowing precipitation to continue farther “downstream”. Furthermore, mixing-induced precipitation can account for systems in which some high porosity regions are filled while others remain almost unchanged. Thus, mixing-induced precipitation represents a viable mechanism for the infilling of pores in fractured and porous rocks. The simulations also demonstrate that the choice of functional form for specific surface area plays an important role in controlling porosity patterns by influencing both the kinetics of precipitation and the permeability of the porous medium. As specific surface area is currently one of the least constrained parameters in models of porosity evolution, this result highlights the need for future experimental studies in this field of research.