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1.
研究由几种导体成分掺杂的混合物的整体电导率.对欧姆定律求平均,得到混合物电导率定义.对电流连续性方程求平均,得到混合物中电场增量方程.求电场增量方程在同种成分上的平均,并结合混合物电导率定义,得到混合物电导率公式.现有的三种混合物结构下电导率公式（电导率串联公式、并联公式和整体各向同性混合物电导率公式）都是混合物电导率公式的特例.进一步分析得出结论,混合物整体电导率是各成分电导率与整体电导率结构并联后的体积串联. 相似文献
2.
应用电场理论研究混合物的电性，得出了混合物的电导率公式和介电常数公式．这一结果表明：混合物的电导率决定于混合物各成分电导率的均值和方差；混合物的介电常数决定于混合物各成分介电常数的均值和方差．作为所得结果的应用，给出了岩石的电导率公式和介电常数公式． 相似文献
3.
混合物整体电导率和各成分电导率的关系 总被引：2，自引：0，他引：2
文中给出了混合物中电场方程的平均形式,在此基础上推导出了混合物整体电导率和各成分电导率的关系,并通过类比给出了混合物整体介电常数和各成分介电常数的关系,作为所得结果的应用,给出了岩石的电导率公式。 相似文献
4.
5.
《地球物理学进展》2020,(4)
在岩石导电机理上,纯水层阿尔奇公式有两点必须改进.第一,岩石骨架不导电,岩石孔隙中的地层水导电,当孔隙度为零时,岩石的电导率为零,电阻率为无穷大.但在现在使用的双对数坐标系下,此坐标点(■=0,F=∞)无法实现.须将电阻率之比改为电导率之比,并采用普通坐标.第二,地层因素F是导体容量孔隙度■和导体几何性质——孔道迂曲度τ两个因素的函数.但是纯水层阿尔奇公式F仅为■一个因素的函数.测井无法获得τ的数值.但通过观察实验数据,τ和■存在内在关联,将τ与■融合,得到■的关系式.普遍消除了F～■关系曲线左、右斜率不同或低孔门限的"非阿尔奇"现象.将公式中的导电因子■扩展为(■S_w)~2,得到含油层阿尔奇公式:■.在油(气)成藏过程中湿性附着液首先被驱替,润湿性对原始油(气)藏不起作用.饱和度指数n值等于2. 相似文献
6.
感应测井视电导率和真电导率关系的积分方程 总被引：2，自引：0，他引：2
李剑浩 《中国科学:地球科学》2014,(5):928-933
本文研究感应测井仪器测量的感应电动势和视电导率的关系、视电导率和地层真电导率的关系.假定格林函数中的电导率是场点坐标的函数,运用格林公式推导出电场强度的视电导率表达式,建立了视电导率和真电导率关系的积分方程,通过对所得积分方程的深入分析,得出等效电导率与视电导率相等以及视电导率函数值包含真电导率两个结论,并提出由井轴视电导率函数求取真电导率的方法,通过数值计算验证了本文提出的方法的有效性.按照上述做法,仪器每移动一点,发射线圈产生一个电场分布,若干接收线圈得到一个视电导率分布,这就形成了感应电场测井. 相似文献
7.
三轴张量感应测井可探测地层电导率各向异性,Zhdanov et al.利用在横向各向同性均匀介质中测井响应的低频渐近式给出了由张量感应测井响应提取地层各向异性电导率和井孔倾角与方位角信息的解析公式,为张量感应测井资料解释奠定了基础.但是,他们给出的井孔倾角公式存在双值解的不确定性,其各向异性电导率解也不是最佳近似解.本文以更为简洁的推导和分析方法,给出了单值的井孔倾角解以及近似程度更好的各向异性电导率解,并通过数值模拟实例加以说明.本文的结果可为张量感应测井资料的视值解释提供更好的选择. 相似文献
8.
本文采用格子玻耳兹曼方法计算混合物的整体电导率．整体电导率与各组分的电导率、体积分数和混合物结构有关．数值计算方法的有效性通过两相混合物并联或串联模型的解析解加以验证．对随机分布模型的计算发现格子玻耳兹曼方法得到的电导率落在H S理论边界内．对Al Bi合金整体电导率的数值模拟结果和实验结果非常相近．对饱和水岩石的介电常数的计算与实验结果相比误差较小．格子玻耳兹曼方法为混合物的整体电导率的计算提供了一个有效的途径. 相似文献
9.
大别超高压榴辉岩高温高压下电导率实验研究 总被引：7，自引：0，他引：7
为研究大陆中下地壳高导层成因及与物质组成之间的关系，用模拟实验的方法在不同的温度、压力条件下分别测定了干的和1mol/LNaCl溶液饱和的榴辉岩的电导率.结果表明，干榴辉岩平行线理方向的电导率比垂直于线理方向的高，但两个方向上的活化能相近.在中下地壳条件下，干榴辉岩的电导率比中下地壳高导层电导率值低几个数量级.常温下1mol/LNaCl溶液饱和的榴辉岩两个方向上的电导率对压力具有不同的依赖性；在中下地壳条件下，1mol/LNaCl溶液饱和的榴辉岩的电导率可达到一般高导层的电导率值.无论干的还是饱和的榴辉岩都不能解释大别山20-50km深处的高导层成因，因此，在该深度范围内榴辉岩不可能是主要的岩石组成. 相似文献
10.
本文用E极化的二维有限元法和有限差分法研究导体层边缘附近的虚感应矢量.首先,研究有一定埋深的导体--围岩界面处的情况,其中包括虚感应矢量的频率响应.其次,研究了海岸效应的虚感应矢量的频率响应.在海岸效应中不仅考虑了不同海水层厚度的影响,还考虑了海水与陆地的电导率比值大小对虚感应矢量的影响.最后,研究了被动陆缘（passive continental margin）处的海岸效应,检查磁感应矢量的测量是否能揭示海岸下面深部电导率的横向变化（即与岩石层厚度变化有关联的电导率变化）. 相似文献
11.
The conductance of pyrite-bearing laminated and dispersed shaly sands is not well understood and resistivity models for pyrite-bearing shaly sands are nonexistent. Thus, we first synthesize clean pyrite-matrix samples, and quartz-matrix samples with variable laminated shale, dispersed shale, and pyrite content and then perform petrophysics experiments to assess the effect of pyrite content on the conductivity of pyrite-bearing shaly sands. Second, based on the differences in conductivity and conduction pathways and geometries because of the variable composition of the pyrite-bearing laminated and dispersed shaly sands, we divide the shaly sands into their components, i.e., laminated shale, quartz grains, pyrite grains, hydrocarbon, dispersed shale, microscopic capillary water, and mobile water. A generalized resistivity model is proposed to describe the conductivity of pyrite-bearing laminated and dispersed shaly sands, based on the combined conductivity differential equation and generalized Archie equation. In the generalized resistivity model, the conductivity differential equation is used to describe the conductivity of dispersed inclusions in a host, whereas the generalized Archie equation is used to describe the conductivity of two conducting phases. Moreover, parallel conductance theory is used to describe the conductivity of dispersed shaly sands and laminated shale. Theoretical analysis suggests that the proposed model satisfies the physical constraints and the model and experimental results agree. The resistivity and resistivity index of shaly sands decrease with increasing conductivity and pyrite. Finally, the accuracy of the resistivity model is assessed based on experimental data from 46 synthetic core samples with different oil saturation. The model can describe the conductivity of clean pyrite-matrix samples, and quartz-matrix samples with different volumes of laminated shale, dispersed shale, and pyrite. An accurate saturation model of pyrite-bearing laminated and dispersed shaly sands is thus obtained and the log data interpretation in complex shaly sands can improve with the proposed model. 相似文献
12.
在水介质中顺序添加分散粘土颗粒、油珠、导电骨架颗粒、层状泥质,并对每一种成分进行连续积分,建立了一种适用骨架导电及含有分散粘土和层状泥质的泥质砂岩通用电阻率模型.通过对该模型的影响因素分析,发现泥质分布形式对模型计算的含水饱和度有很大影响;对应两个不同粘土颗粒电阻率或骨架颗粒电阻率的地层电导率之差,几乎与总含水饱和度无关,而对应两个不同层状泥质电阻率的地层电导率之差,随总含水饱和度增大而增大;骨架胶结指数变化对地层电导率与总含水饱和度关系曲线的影响最大,而粘土胶结指数变化对地层电导率与总含水饱和度关系曲线的影响最小;饱和度指数对地层电导率与总含水饱和度关系曲线的影响随总含水饱和度的增大而减小.通过一组骨架导电的人造岩样的试验,表明当地层水电阻率.小于颗粒电阻率时,该模型可以用于不含粘土的骨架导电的岩石.通过两组分散泥质砂岩岩样实验测量数据和一组层状泥质砂岩测井资料及实际测井资料的计算,表明本文给出的电阻率模型既适用于分散泥质砂岩地层解释又适用于层状泥质砂岩地层解释,同时,还适用于含有分散粘土和层状泥质的混合泥质砂岩地层解释. 相似文献
13.
本文利用人工制作的不同含量分散泥质和层状泥质砂岩岩心样品,测量不同矿化度和不同含油饱和度的岩心电阻率,从实验角度研究了不同泥质分布形式和含量的岩心导电规律,结果表明,泥质分布形式或含量不同,则泥质砂岩导电规律不同.基于层状泥质与分散泥质砂岩的并联导电实验规律,以及分散粘土和地层水混合物的导电规律可用HB电阻率方程描述,建立了考虑泥质分布形式影响的泥质砂岩电阻率模型.通过1组不同泥质分布形式泥质砂岩人造岩心实验数据的测试,表明该模型可以描述分散泥质砂岩、层状泥质砂岩和混合泥质砂岩地层的导电规律.分散泥质,层状泥质,人造岩样,实验测量,并联导电,HB方程,电阻率模型 相似文献
14.
Shaly sands reservoir is one of the most distributive types of the oil(gas)-bearing reservoirs discovered in China, and low resistivity oil(gas)-bearing reservoirs are mostly shaly sands reservoirs. Therefore, shaly sands reservoir conductive model is the key to evaluate low resistivity oil(gas)-bearing reservoirs using logging information. Some defects were found when we studied the clay distribution type conductive model, dual-water conductive model, conductive rock matrix model, etc. Some models could not distinguish the conductive path and nature of microporosity water and clay water and some models did not consider the clay distribution type and the mount of clay volume. So, we utilize the merits,overcome the defects of the above models, and put forward a new shaly sands conductive model-dual water clay matrix conductive model (DWCMCM) in which dual water is the free water and the microporosity water in shaly sands and the clay matrix(wet clay) is the clay grain containing water. DWCMCM is presented here, the advantages of which can tell the nature and conductive path from different water (microporosity water and freewater), in consid-eration of the clay distribution type and the mount of clay volume in shaly sands. So, the results of logging interpretation in the oil(gas)-bearing reservoirs in the north of Tarim Basin area, China with DWCMCM are better than those interpreted by the above models. 相似文献
15.
Heping Pan Jiaying Wang Zhengjun Fan Yong Ma Jianhua Liu Mingqiang Li 《中国科学D辑(英文版)》2001,44(4):346-355
Shaly sands reservoir is one of the most distributive types of the oil(gas)-bearing reservoirs discovered in China, and low resistivity oil(gas)-bearing reservoirs are mostly shaly sands reservoirs. Therefore, shaly sands reservoir conductive model is the key to evaluate low resistivity oil(gas)-bearing reservoirs using logging information. Some defects were found when we studied the clay distribution type conductive model, dual-water conductive model, conductive rock matrix model, etc. Some models could not distinguish the conductive path and nature of microporosity water and clay water and some models did not consider the clay distribution type and the mount of clay volume. So, we utilize the merits,overcome the defects of the above models, and put forward a new shaly sands conductive model—dual water clay matrix conductive model (DWCMCM) in which dual water is the free water and the microporosity water in shaly sands and the clay matrix(wet clay) is the clay grain containing water. DWCMCM is presented here, the advantages of which can tell the nature and conductive path from different water (microporosity water and free-water), in consideration of the clay distribution type and the mount of clay volume in shaly sands. So, the results of logging interpretation in the oil(gas)-bearing reservoirs in the north of Tarim Basin area, China with DWCMCM are better than those interpreted by the above models. 相似文献
16.
Nishank Saxena Ronny Hofmann Seán Dolan Rituparna Sarker Chen Bao Stephan Gelinsky 《Geophysical Prospecting》2019,67(4):843-871
The measured geophysical response of sand – shale sequences is an average over multiple layers when the tool resolution (seismic or well log) is coarser than the scale of sand – shale mixing. Shale can be found within sand – shale sequences as laminations, dispersed in sand pores, as well as load bearing clasts. We present a rock physics framework to model seismic/sonic properties of sub-resolution interbedded shaly sands using the so-called solid and mineral substitution models. This modelling approach stays consistent with the conceptual model of the Thomas–Stieber approach for estimating volumetric properties of shaly sands; thus, this work connects established well log data-based petrophysical workflows with quantitative interpretation of seismic data for modelling hydrocarbon signature in sand – shale sequences. We present applications of the new model to infer thickness of sand – shale lamination (i.e., net to gross) and other volumetric properties using seismic data. Another application of the new approach is fluid substitution in sub-resolution interbedded sand–shale sequences that operate directly at the measurement scale without the need to downscale; such a procedure has many practical advantages over the approach of “first-downscale-and-then-upscale” as it is not very sensitive to errors in estimated sand fraction and end member sand/shale properties and remains stable at small sand/shale fractions. 相似文献
17.
Spectral induced polarization as well as complex electrical measurements are used to estimate, on a non-invasive basis, hydraulic permeability in aquifers. Basic laboratory measurements on a variety of shaly sands, silts and clays showed that the main feature of their conductivity spectra in the frequency range from 10-3 to 103 Hertz is a nearly constant phase angle. Thus, a constant-phase-angle model of electrical conductivity is applied to interpret quantitatively surface and borehole spectral induced polarization measurements. The model allows for the calculation of two independent electrical parameters from only one frequency scan and a simple separation of electrical volume and interface effects. The proposed interpretation algorithm yields the true formation factor, the cation exchange capacity and the surface-area-to-porosity ratio, which corresponds to the inverse hydraulic radius. Using a Kozeny–Carman-like equation, the estimation of hydraulic permeability is possible. 相似文献
18.
P. F. WORTHINGTON 《Geophysical Prospecting》1982,30(5):673-687
The roots of the so-called shaly-sand problem in hydrocarbon evaluation lie in the effect of relatively fine-grained minerals upon measured electrical parameters of granular reservoirs. This influence manifests itself as an excess conductivity, over and above that due to the purely geometric effects of electrolyte distribution within the pore space. For formations with low shaliness, this excess conductivity is usually insignificant in typical oilfield situations. The influence of shaliness upon observed values of formation resistivity has been appraised by collating core-sample data from four different reservoirs. It has been demonstrated that during the course of electrical measurement under conditions of full electrolyte saturation, any given lithology can exhibit both negligible and highly significant shale effects depending upon the resistivity of the interstitial aqueous electrolyte. The effects of shaliness are also governed by the degree of water saturation. Because the manifestation of shaliness in electrical data is not a function of lithology alone, recourse is made to a more realistic concept of shale effects whereby a formation, or section of a formation, is classified as “effectively clean” or “effectively shaly” according to whether it obeys or defies, respectively, the fundamental empirical laws of Archie (1942). In particular, since an intrinsic formation factor can be obtained directly in fully-saturated effectively clean reservoirs, whereas only an apparent quantity may be recorded directly in fully-saturated effectively shaly reservoirs, the ratio of apparent to intrinsic formation factor serves as a useful conceptual indicator of shale effects, attaining the limiting value of unity only under effectively clean conditions. In the context of electrical measurement the terms “shaliness” and “shale effects” are evidently not synonymous and it is the latter which should be considered when selecting equations for the computation of water saturation. The implications for well-log analysis follow through formulated guidelines that describe the relative levels of shale effects in different zones of lithologically uniform reservoirs. 相似文献