Journal of Geophysics and Engineering Impact Factor & Information

Publisher: Nanjing shi you wu tan yan jiu suo; Institute of Physics (Great Britain), IOP Publishing

Journal description

Published by the Nanjing Institute of Geophysical Prospecting and the Institute of Physics, this major new publication promotes research and developments in geophysics and related areas of engineering. It has predominantly an applied science and engineering focus, but also publishes contributions in all earth-physics disciplines from global geophysics to applied and engineering geophysics.

Current impact factor: 0.90

Impact Factor Rankings

2015 Impact Factor Available summer 2015
2013 / 2014 Impact Factor 0.895
2012 Impact Factor 0.721
2011 Impact Factor 0.634
2010 Impact Factor 0.805
2009 Impact Factor 0.787
2008 Impact Factor 0.621
2007 Impact Factor 0.762
2006 Impact Factor 0.839
2005 Impact Factor 0.86

Impact factor over time

Impact factor
Year

Additional details

5-year impact 0.77
Cited half-life 4.40
Immediacy index 0.11
Eigenfactor 0.00
Article influence 0.27
Website Journal of Geophysics and Engineering website
ISSN 1742-2140
OCLC 60310620
Material type Periodical, Internet resource
Document type Journal / Magazine / Newspaper, Internet Resource

Publisher details

IOP Publishing

  • Pre-print
    • Author can archive a pre-print version
  • Post-print
    • Author can archive a post-print version
  • Conditions
    • Pre-print on author's personal website, repository or arXiv.
    • Pre-print can not be updated after submission
    • Post-print on author's personal website immediately
    • Post-print on institutional repository, subject-based repository, PubMed Central or third party eprint servers after 12 months embargo
    • Publisher's version/PDF cannot be used
    • Published source must be acknowledged with citation
    • Must link to publisher version with DOI
    • Set statements to accompany different versions (see policy)
    • Publisher last contacted on 17/02/2014
  • Classification
    ​ green

Publications in this journal

  • [Show abstract] [Hide abstract]
    ABSTRACT: An accurate inversion of original reservoir resistivity is an important problem for waterflood development in oilfields in the middle-late development period. This paper describes the theoretical model of original resistivity recovery for a conglomerate reservoir established by petrophysical models, based on the stratigraphic model of reservoir vertical invasion of the conglomerate reservoir of an oilfield. Likewise two influencing factors of the resistivity change with a water-flooded reservoir were analyzed. The first one is the clay volume decrease due to an injected water wash argillaceous particle and the reservoir resistivity changes are influenced by it, and the other is to inject water to displace crude oil in the pore space leading to the increase of the water-bearing volume. Moreover the conductive ions of the injected water and the original formation water exchange and balance because of their salinity difference, and the reservoir resistivity changes are also influenced by them. Through the analysis of the above influential factors based on the fine identification of conglomerate lithologies the inversion models of three variables, including changes in the amount of clay, the resistivity of the irreducible water and the increase of the water bearing volume, were established by core analysis data, production performance and well logging curves information, and accurately recovered the original reservoir resistivity of the conglomerate. The original oil saturation of the reservoir was calculated according to multiple linear regression models. Finally, the produced index is defined as the difference of the original oil saturation and current oil saturation to the original oil saturation ratio, and it eliminates the effects of conglomerate lithologies and heterogeneity for the quantitative evaluation of flooded layers by the use of the principle of relative value. Compared with traditional flooding sensitive parameters which are oil saturation and water production rate, the interpretation accuracy of the production index can achieve 82%, provide technical support for the development programs determination and the well adjustment pattern in the second development of the oilfield.
    Journal of Geophysics and Engineering 10/2015; 12(5). DOI:10.1088/1742-2132/12/5/780
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    ABSTRACT: The adaptive optimized window generalized S transform (AOGST) variant with frequency and time is a method for the time–frequency mapping of a signal. According to the AOGST method, an optimized regulation factor is calculated based on the energy concentration of the S transform. The value of this factor is 1 for standard S transform where in the AOGST method its value is limited by the interval of [0, 1]. However, AOGST may not produce an acceptable resolution for all parts of the time–frequency representation. We applied aggregation of confined interval-adaptive optimized generalized S transforms (ACI-AOGST) instead of the AOGST method. The proposed method applies the modified AOGST method to specific frequency and time intervals. By calculating regulation factors for limited frequency and time intervals of signal, arranging them in a suitable order and applying the ACI-AOGST one can provide a transformation with lowest distortion and highest resolution in comparison to other transformations. The proposed method has been used to analyse the time–frequency distribution of a synthetic signal as well as a real 2D seismic section of a producing gas reservoir located south of Iran. The results confirmed the robustness of the ACI-AOGST method.
    Journal of Geophysics and Engineering 10/2015; 12(5). DOI:10.1088/1742-2132/12/5/770
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    ABSTRACT: More than 30% of hydrocarbon reservoirs are reported in carbonates that mostly include evidence of fractures and karstification. Generally, the detection of karstic sinkholes prognosticate good quality hydrocarbon reservoirs where looser sediments fill the holes penetrating hard limestone and the overburden pressure on infill sediments is mostly tolerated by their sturdier surrounding structure. They are also useful for the detection of erosional surfaces in seismic stratigraphic studies and imply possible relative sea level fall at the time of establishment. Karstic sinkholes are identified straightforwardly by using seismic geometric attributes (e.g. coherency, curvature) in which lateral variations are much more emphasized with respect to the original 3D seismic image. Then, seismic interpreters rely on their visual skills and experience in detecting roughly round objects in seismic attribute maps. In this paper, we introduce an image processing workflow to enhance selective edges in seismic attribute volumes stemming from karstic sinkholes and finally locate them in a high quality 3D seismic image by using circular Hough transform. Afterwards, we present a case study from an on-shore oilfield in southwest Iran, in which the proposed algorithm is applied and karstic sinkholes are traced.
    Journal of Geophysics and Engineering 10/2015; 12(5). DOI:10.1088/1742-2132/12/5/764
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    ABSTRACT: Shale content is known in reservoir evaluation as an important parameter in well logging. However, the log response characteristics are simultaneously affected by shale and tuff existing in tuffaceous sandstone reservoirs. Due to the fact that tuff content exerts an influence on the calculation of shale content, the former is equally important as the latter. Owing to the differences in the source and composition between shale and tuff, the calculation of tuff content using the same methods for shale content cannot meet the accuracy requirements of logging evaluation. The present study takes the tuffaceous reservoirs in the X depression of the Hailar–Tamtsag Basin as an example. The differences in the log response characteristics between shale and tuff are theoretically analyzed and verified using core analysis data. The tuff is then divided into fine- and coarse-grained fractions, according to the differences in the distribution of the radioactive elements, uranium, thorium and potassium. Next, a volume model suitable for tuffaceous sandstone reservoirs is established to include a sandstone matrix, shale, fine-grained tuff, coarse-grained tuff and pore. A comparison of three optimization algorithms shows that the particle swarm optimization (PSO) yields better calculation results with small mean errors. The resistivity differences among shale, fine-grained tuff and coarse-grained tuff are considered in the calculation of saturation. The water saturation of tuffaceous reservoirs is computed using the improved Poupon’s equation, which is suitable for tuffaceous sandstone reservoirs with low water salinity. The method is used in well Y, and is shown to have a good application effect.
    Journal of Geophysics and Engineering 10/2015; 12(5). DOI:10.1088/1742-2132/12/5/810
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    ABSTRACT: Cation exchange capacity (Q v) is a key parameter in resistivity-based water saturation models of shaly sand reservoirs, and the accuracy of Q v calculation is crucial to the prediction of saturations of oil and gas. In this study, a theoretical expression of Q v in terms of shaly sand permeability (K shaly-sand), total porosity (Φ t), and salinity of formation water (S) is deduced based on the capillary tube model and the physics volume model. Meanwhile, the classical Schlumberger–Doll research (SDR) model has been introduced to estimate K shaly-sand. On this basis, a novel technique to estimate Q v from nuclear magnetic resonance (NMR) logs is proposed, and the corresponding model is also established, whose model parameters are calibrated by laboratory Q v and NMR measurements of 15 core samples from the Toutunhe formation of the Junggar Basin, northwest China. Based on the experimental data sets, this technique can be extended to reservoir conditions to estimate continuous Q v along the intervals. The processing results of field examples illustrate that the Q v calculated from field NMR logs are consistent with the analyzed results, with the absolute errors within the scope of ±0.1 mmol cm−3 for the majority of core samples.
    Journal of Geophysics and Engineering 10/2015; 12(5). DOI:10.1088/1742-2132/12/5/745
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    ABSTRACT: The strength of rocks subjected to cyclic stress and temperature variations must be determined to ensure the stability of caverns for underground compressed air energy storage. This paper proposes a strength criterion for rocks subjected to cyclic stress and temperature variations; the proposed criterion is based on the least energy dissipation principle and the rock damage induced by cyclic stress and temperature effects. The cyclic uniaxial stress-temperature tests and uniaxial compression tests after cycling are conducted to validate preliminarily the proposed criterion. The applicability of the proposed strength criterion and the influence of damage factor selection are discussed. The proposed strength criterion has a clear physical meaning and only involves four parameters to be determined. The predicted rock strengths are in good agreement with the laboratory test results, confirming the applicability of the proposed criterion. The proposed strength criterion can degenerate into certain existing criteria. Moreover, the damage factor is suggested to be calculated with the use of the peak secant modulus when the proposed strength criterion is applied.
    Journal of Geophysics and Engineering 10/2015; 12(5). DOI:10.1088/1742-2132/12/5/753
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    ABSTRACT: Shale oil is a key resource that could mitigate the impending energy shortage in the future. Despite its abundance in China, studies on shale oil are still at the preliminary stage. Shale oil development through CO2 flooding has been successfully implemented in the United States. Therefore, the mechanics of CO2 flooding in shale oil reservoirs should be investigated. This study applies a simulation method to evaluate the development efficiency of CO2 flooding in shale oil reservoirs. Near-miscible CO2 flooding can effectively develop shale oil. After 20 years, recovery could improve by up to 9.56% as a result of depletion development under near-miscible CO2 flooding with 0.5% pore volume gas injection. Horizontal well injection is better than vertical well injection in terms of sweep efficiency and recovery. Cyclic gas injection is superior to continuous gas injection because the former reduces gas channelling. Thus, the use of horizontal wells with near-miscible cyclic gas injections has the potential to effectively develop shale oil reservoirs.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/702
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    ABSTRACT: Estimation of in situ stresses is a key step in many petroleum engineering applications, ranging from wellbore stability to sanding analysis and hydraulic fracturing design. Direct techniques conventionally used to determine in situ stresses are indeed very time consuming and expensive. These measurements would also be restricted as to the depth of acquisition, and generalization of the results to entire rock masses may not yield representative results. In this paper, applications of three indirect methods–Zoback’s polygon, shear moduli, and poroelastic–are studied to assess their applicability in providing reliable stress estimation under isotropic and anisotropic conditions. Determination of elastic, strength, and in situ stress parameters according to the assumption of each method for one of the vertical wells drilled in south Iran indicated that the shear moduli method is an appropriate approach for prediction of maximum horizontal stress within an interval where sufficient field data including leak-off tests are acquired. However, the poroelastic method seems to be a better method in prediction of in situ stresses under anisotropic conditions. This might be due to the presence of excessive shale formations in subsurface layers, causing structural or intrinsic anisotropy-based methods such as poroelastic equations to deliver more accurate results. However, making general conclusions based on studying a single vertical wellbore may not be sufficient, and therefore further studies are required.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/657
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    ABSTRACT: A lot of research on the 2D or 3D effects of large-scale basins (within several kilometers depth) have been conducted in the past. However, different 2D aspects of small-scale sedimentary basins (within tens of meters depth) remain in the developing stage. Here, an attempt is made to analyze different aspects of small-scale basins using both numerical and empirical investigations. In the first step, the 2D effects of small-scale basins on strong motion characteristics are numerically examined both in the time and frequency domains. In addition, the effects of input motion are also explained by the results of model excitation in different orthogonal directions. Then, the numerical outcomes are verified by the analysis of actual earthquake data recorded at a downhole array in the Fujisawa small basin, Japan. In the second step, since available recorded earthquake data in small basins with a clear understanding of subsurface geology are very limited, different 2D aspects of the small basin are parametrically investigated. For this purpose, extensive parametrical studies are carried out on the main features of a small basin such as slope angle, shape, infill soil properties, and basin thickness by using the finite difference numerical method. The horizontal and vertical peak ground accelerations of 2D with respect to 1D ones are defined as the horizontal and vertical aggravation factors (AGH and AGV ). The AGH and AGV factors show large sensitivity to infill soil properties, shape and thickness, and small sensitivity to slope angle. The values of AGH and AGV factors vary in the range of 0.5–2 with large variations around small basin edges due to wave coupling, conversion, scattering and focusing in the vicinity of small basin edges. These cause a complicated pattern of 2D de-amplification and amplification, which mostly affect the motion in the high frequency range (>1 Hz). Finally, the outcomes provide numerical and field evidence on the 2D effects of small basins, and give some recommendations for design codes.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/535
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    ABSTRACT: Blended acquisition significantly improves the seismic acquisition efficiency. However, the direct imaging of blended data is not satisfactory due to the crosstalk contamination. Assuming that the distribution of subsurface reflectivity is sparse, in this paper, we formulate the seismic imaging problem of blended data as a Basis Pursuit denoise (BPDN) problem. Based on compressed sensing, we propose a L1 norm constrained migration method applying to the direct imaging of blended data. The Fast Iterative Shrinkage-Thresholding Algorithm, which is stable and computationally efficient, is implemented in our method. Numerical tests on the theoretical models show that the crosstalk introduced by blended sources is effectively attenuated and the migration quality has been improved enormously.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/620
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    ABSTRACT: Sandstone reservoirs have generally high porosity in the Shawan formation of the Chunguang oil field, Junggar basin, because they developed in geological conditions of shallow and weak compaction. High porosity always links lower acoustic velocities in sandstone. However, when it is more than a certain value (approximately 27.5%), the porosity is not in accordance with acoustic velocities. In addition, cast thin sections illustrated incoherence between pore types and porosity. Fluids and mineral content are the two main factors changing acoustic velocities. This means that acoustic velocities of the high-porosity sandstone are mainly affected by the mineral content and fluid properties. Hence, data from litho-electric analysis are used to measure velocities of the compression shear waves, and thin sections are used to identify the mineral content. By the application of cross-plot maps, relations of acoustic velocities and mineral contents are proposed. Mineral contents include mainly quartz, feldspar, and tuff. In normal rock physical models, the shale content is calculated from well logs. The mineral grain is often regarded as pure quartz grain or average mineral composition. However, the application of the normal rock physics model will be inaccurate for high-porosity sandstone. Experience regression functions of the velocity model are established to estimate acoustic velocities. Also, mineral content logs could be predicted by using the P-wave acoustic log, and the rock physics model would be enhanced by using these logs of dynamic mineral contents. Shear wave velocity could also be estimated more accurately.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/629
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    ABSTRACT: Contamination of seismic signal with noise is one of the main challenges during seismic data processing. Several methods exist for eliminating different types of noises, but optimal random noise attenuation remains difficult. Based on multi-scale, multi-directional locality of curvelet transform, the curvelet thresholding method is a relatively new method for random noise elimination. However, the high redundancy of a 3D curvelet transform makes its computational time and memory for massive data processing costly. To improve the efficiency of the curvelet thresholding denoising, a low-redundancy curvelet transform was introduced. The redundancy of the low-redundancy curvelet transform is approximately one-quarter of the original transform and the tightness of the original transform is also kept, thus the low-redundancy curvelet transform calls for less memory and computational resource compared with the original one. Numerical results on 3D synthetic and field data demonstrate that the low-redundancy curvelet denoising consumes one-quarter of the CPU time compared with the original curvelet transform using iterative thresholding denoising when comparable results are obtained. Thus, the low-redundancy curvelet transform is a good candidate for massive seismic denoising.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/566
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    ABSTRACT: Low porosity and permeability make it extremely difficult to develop shale oil and gas reservoirs. The stimulated reservoir volume is believed to have potential to obtain industry production by multi-stage or simultaneous fracturing in horizontal wells. The formation mechanism of network hydraulic fractures in fractured shale reservoirs remains poorly understood. In this article, a true tri-axial hydraulic fracturing system associated acoustic emission monitor was deployed to simulate hydraulic fracturing on shale outcrops. Results showed that the properties of natural fractures (such as aperture, orientation), compared to the viscosity and displacement of the fracturing fluid, affect the propagation direction of hydraulic fractures more predominantly. Each natural fracture in a natural fracture network can independently affect the hydraulic fracture. Low displacement (below the diffusion ability of a reservoir) fracturing tends to connect pre-existing fractures, while high displacement (surpass the diffusion ability of a reservoir) tends to create new fractures. After the breakdown pressure, an increase in injection rate results in more acoustic emission energy and induces new fractures. These results suggest that step-displacement fracturing technology is a possible mechanism to obtain effective fracture networks. Such an understanding would help to avoid unproductive, or sometimes destructive, costly segments of the hydraulic fracturing treatment design.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/714
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    ABSTRACT: Gas shale has shown considerable force in gas production worldwide, but little attention has been paid to its electrical properties, which are essential for reservoir evaluation and differentiating absorbed gas and free gas. In this study, experiments are designed to research water saturation establishment methods and electrical properties of gas shale. Nuclear magnetic resonance (NMR) with short echo space (TE) is used to identify water saturation and distribution of saturated pores which contribute to the conductivity. The experimental results indicate that NMR with shorter TE can estimate porosity and fluid distribution better than NMR with longer TE. A full range of water saturation is established by the combination of new-type spontaneous imbibition and semi-permeable plate drainage techniques. Spontaneous imbibition gains water saturation from 0% to near irreducible water saturation, and, semi-permeable plate drainage desaturates from 100% to irreducible water saturation. The RI-Sw curve shows a nonlinear relationship, and can be divided into three parts with different behaviors. The comparative analysis of transverse relaxation time (T 2) distribution and RI-Sw curves, indicates that free water, and water trapped by capillarity in the non-clay matrix, differ in terms of electrical conductivity from water absorbed in clay. The new experiments prove the applicability of imbibition, drainage and NMR in investigating electrical properties of gas shale and differentiating fluid distribution which makes contribution to conductivity.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/610
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    ABSTRACT: Horizontal drilling and multi-stage hydraulic fracturing have been common and efficient practices in exploitation of tight reservoirs. Establishing corresponding mathematical models and analyzing transient pressure behaviors of this type of well-reservoir configuration can provide a better understanding of fluid flow patterns in formation as well as estimations of important parameters. Most current models proposed for fractured horizontal wells in tight reservoirs do not incorporate either reservoir permeability loss during the production, which is believed to be non-ignorable or finite conductivity of hydraulic fractures.A coupling model for a multi–fractured horizontal well (MFHW) in tight reservoirs is presented in this article, in which finite conductivity of hydraulic fractures and stress-dependant reservoir permeability are taken into account simultaneously. A semi-analytical solution is obtained in the Laplace domain by using source function theory, Laplace transformation, perturbation technique, discretization of fractures, and superposition principle. Analysis of transient pressure responses indicates that several characteristic flow periods of fractured horizontal wells in tight reservoirs can be identified, including linear flow in fracture, bi-linear flow, linear flow in reservoir, pseudo-radial flow around fractures, and pseudo-radial flow around the horizontal wellbore and fractures. Parametric analysis shows that fracture conductivity, fracture spacing, fracture length, permeability modulus, and skin effect can significantly influence the transient pressure responses of fractured horizontal wells in tight reservoirs. The model presented in this article can be applied to obtain important parameters pertinent to reservoir or fractures by type curve matching, and it can also provide useful information for optimizing fracture parameters. Finally, the model presented in this article can also be easily extended to dual-porosity cases.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/638
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    ABSTRACT: Reverse time migration (RTM) is an accurate seismic imaging method for imaging the complex subsurface structure. Traditional common shot RTM suffers from low efficiency due to the large number of single shot gathers, especially for marine seismic data. Phase encoding is commonly used to reduce the computational cost of RTM. Phase encoding in the frequency domain is usually related to time shift in the time domain. Therefore, phase-encoding-based RTM needs time padding to avoid information loss which degrades the efficiency of the time-domain wavefield extrapolator. In this paper, an efficient time-domain RTM scheme based on the amplitude encoding is proposed. This scheme uses the orthogonal cosine basis as the encoding function, which has similar physical meaning to plane wave encoding (i.e. plane-wave components with different surface shooting angles). The proposed scheme can generate a qualified imaging result as well as common shot RTM but with less computational cost. Since this scheme does not need time padding, it is more efficient than the phase encoding schemes and can be conveniently implemented in the time domain. Numerical examples on the Sigsbee2a synthetic dataset demonstrate the feasibility of the proposed method.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/601
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    ABSTRACT: As a powerfully diagnostic tool for structural interpretation, reservoir characterization, and hydrocarbon detection, quality factor Q provides useful information in seismic processing and interpretation. Popular methods, like the spectral ratio (SR) method, central frequency shift (CFS) method and peak frequency shift (PFS) method, have their respective limitations in dealing with field seismic data. The lack of a reliable method for estimating Q from reflection seismic data is an issue when utilizing the Q value for hydrocarbon detection. In this article, we derive an approximate equation and propose a dominant and central frequency shift (DCFS) method by combining the quality factor Q, the travel time, and dominant and central frequencies of two successive seismic signals along the wave propagating direction. Based on multi-layered analysis, we then proposed a method to obtain continuous volumetric Q estimation results. A test using synthetic data and statistical experiments showed the proposed method can achieve higher accuracy and robustness compared with existing methods. Application of field data also shows its potential and effectiveness to estimate seismic attenuation.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/577
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    ABSTRACT: Rock electrical parameters of tight gas sandstone show large variations in the T 2 member in Dingbei Block, Ordos Basin, China. Applying the same rock electrical parameters in water saturation calculations would lead to large errors. Based on casting thin sections, x-ray diffraction, scanning electron microscopy (SEM), cathode luminescence, porosity and permeability, image analysis, and high-pressure mercury intrusion/withdrawal method, identification of the diagenetic facies are first conducted, and then their pore structure and their relationship with rock electrical parameters are investigated.Five diagenetic facies (A–E), which are identified based mainly on pore types and authigenic minerals, have different pore structure and rock electrical parameters. Conceptual models that incorporate the rock properties of each diagenetic facies have been built, before applying the electrical efficiency theory to explain the values of cementation exponent (m) and saturation exponent (n). A conventional network model, a shunt pore model, a netted pore model, and a dotted line model are utilized to mimic the intergranular pores, authigenic kaolinite intercrystal pores, carbonate-cement dissolution pores, and clay-matrix intercrystal pores, respectively. A decrease of the contents of large pores increases electrical efficiency and therefore reduces m. The saturation exponent, which depends on the distribution of water and gas, can be better understood by applying the different pore models. In the shunt and netted pore models, gas displacement starts from the larger pores and smaller pores provide alternative conduction pathways, hence sustaining electrical efficiency and decreasing n. Clay-matrix intercrystal pores are mainly micropores, since the brine in the rocks are isolated after gas displacement, reducing overall electrical efficiency and dramatically increasing the value of n in the diagenetic facies, which is dominated by clay-matrix intercrystal pores.
    Journal of Geophysics and Engineering 08/2015; 12(4). DOI:10.1088/1742-2132/12/4/587