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Articles de revues sur le sujet « Fracture parameter »

Auteur : Grafiati

Publié le 9 mars 2023

Mis à jour le 19 juillet 2025

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1

Sil, Samik. "Fracture parameter estimation from well-log data." GEOPHYSICS 78, no. 3 (2013): D129—D134. http://dx.doi.org/10.1190/geo2012-0407.1.

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We evaluated a method of deriving seismic fracture parameters from vertical-well-log data with the assumption that the fractured medium is transversely isotropic with a horizontal axis of symmetry (HTI). One approximation we used is that the observed vertical P-wave velocity is the same as the background isotropic P-wave velocity of the HTI medium. Another assumption was that the fractures and cracks are noninteractive and penny shaped. Using these approximations, we generated the fracture compliance matrix for each layer. Fracture parameters were then derived by constructing the HTI stiffness

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Liu, Chao, Xinggui Yang, Wenqi Cao, Jin Lin, Yuxuan Liu, and Hang Zhang. "Discrimination Model of Interaction Between Hydraulic Fracture and Natural Fracture Based on Energy Balance." Processes 13, no. 6 (2025): 1652. https://doi.org/10.3390/pr13061652.

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Hydraulic fracturing technology has been extensively applied for the efficient development of unconventional reservoirs. Influenced by geological discontinuities such as naturally fractured weak planes, the complex interaction behaviors between hydraulic fractures and natural fractures significantly challenge the prediction of hydraulic fracture propagation paths. Establishing interaction discrimination models to predict these behaviors proves crucial for characterizing post-stimulation fracture complexity. This study develops a discrimination model for hydraulic-natural fracture interactions

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Yu, Qingyan, Qi Wang, Pengcheng Liu, et al. "Theoretical Study and Application of Rate Transient Analysis on Complex Fractured-Caved Carbonate Reservoirs." Geofluids 2021 (January 23, 2021): 1–15. http://dx.doi.org/10.1155/2021/6611957.

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Carbonate reservoirs are mainly fractured-caved reservoirs with very well-developed dissolved pores, fractures, and caves. They have strong heterogeneity with various types of reservoir pore spaces. Using seismic inversion and reservoir static characterization, the result shows that the fractured-caved carbonate rocks in China are mainly caves with poor connectivity and complex oil-water distribution. Large-scale dissolved caves are mostly discrete and isolated, while the fractures are complex and various. The fracture features are observed either as a single large fractures or as a local frac

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Zhou, Xin, Jianping Chen, Yunkai Ruan, Wen Zhang, Shengyuan Song, and Jiewei Zhan. "Demarcation of Structural Domains in Fractured Rock Masses Using a Three-Parameter Simultaneous Analysis Method." Advances in Civil Engineering 2018 (December 6, 2018): 1–13. http://dx.doi.org/10.1155/2018/9358098.

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A structural domain represents a volume of a rock mass with similar mechanical and hydrological properties. To demarcate structural domains (or statistically homogeneous regions) in fractured rock masses, this study proposes a three-parameter simultaneous analysis method (3PSAM) that simultaneously considers rock fracture orientation, trace length, and aperture to evaluate statistical homogeneity between two regions. First, a 102-patch three-dimensional Schmidt net, which represents a new comprehensive classification system, is established to characterize rock fractures based on their orientat

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Zhang, Tingting, Ruifeng Zhang, Jianzhang Tian, et al. "Two-parameter prestack seismic inversion of porosity and pore-structure parameter of fractured carbonate reservoirs: Part 2 — Applications." Interpretation 6, no. 4 (2018): SM9—SM17. http://dx.doi.org/10.1190/int-2018-0019.1.

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Fractures and fracture-related dissolution pores, as well as cavities, molds, and vugs, provide the major conduit and/or storage space for hydrocarbons in the deeply buried carbonate hill of Hexiwu field, Bohai Bay Basin. The fractured reservoir generally has lower porosity but better permeability than moldic/vuggy reservoir, and it consists of the major part of the buried-hill slope and buried-hill internal reservoirs. The conventional method of characterizing carbonate reservoirs, however, often mixes these two types of reservoirs together because they both have low acoustic impedance and lo

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Wang, Kang, Suping Peng, Yongxu Lu, and Xiaoqin Cui. "Full waveform inversion in fractured media based on velocity–stress wave equations in the time domain." Geophysical Journal International 227, no. 2 (2021): 1060–75. http://dx.doi.org/10.1093/gji/ggab243.

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SUMMARY In the process of seismic wave propagation, the presence of fractures will cause a seismic wave response associated with fracture compliance. Full waveform inversion (FWI) is an effective way to quantitatively obtain fracture compliance values, which can simulate seismic wave propagation in a fractured medium and compute the gradient expression of the fracture compliance parameters. To obtain the fracture compliance parameters quantitatively, a new technique based on FWI needs to be proposed. Based on linear slip theory, a new finite-difference scheme using a rotated grid has been deve

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Legostaev, D. Yu, and S. P. Rodionov. "Numerical Investigation of the Structure of Fracture Network Impact on the Fluid Flow through a Poroelastic Medium." Известия Российской академии наук. Механика жидкости и газа, no. 4 (July 1, 2023): 93–107. http://dx.doi.org/10.31857/s1024708422600543.

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Two-dimensional single-phase flow of a weakly compressible fluid through a deformable fractured-porous medium is considered. A poroelastic model is used for coupled simulation of the fluid flow and the related changes in the stress state of the medium. Fracture network is simulated using the discrete fracture model. The fractures in the region under consideration have random location and orientations, and the fracture length distribution follows a power law. The dependence of the hydraulic properties of fractured porous media on its stress-strain state and the structure of the fracture network

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Zhang, Bochao, Lixin Wang, and Jianming Liu. "Finite Element Analysis and Prediction of Rock Mass Permeability Based on a Two-Dimensional Plane Discrete Fracture Model." Processes 11, no. 7 (2023): 1962. http://dx.doi.org/10.3390/pr11071962.

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The safety of underground engineering projects is significantly influenced by groundwater. One of the key complexities is identifying the primary seepage paths within underground rock formations, understanding the patterns of seepage, and determining the effects of fracture parameters on the fluid movement inside the rock mass. To address these issues, a probabilistic model is constructed for random fractures using the finite element method, reflecting the random nature of fracture distributions in the real world. This model allows for an in-depth examination of the distribution of pore water

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Yan, Tianfan, and Yike Liu. "Fracture detection using scattered waves in the angle domain." GEOPHYSICS 86, no. 4 (2021): S257—S269. http://dx.doi.org/10.1190/geo2020-0128.1.

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The singly and multiply scattered waves generated from interfaces of a fractured medium have strong energy, and their propagation directions contain information of fracture parameters. To exploit the useful information in the scattered waves, a fracture scattering imaging method is developed based on reverse time migration and angle decomposition. In this method, a fracture-parameter-related local image matrix is constructed in the angle domain based on the relation between the fracture parameters and the propagation angle of the scattered waves. The distribution of the scattered waves in the

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Partsinevelou, Aikaterini-Sofia. "Using the SWAT model in analyzing hard rock hydrogeological environments. Application in Naxos Island, Greece." Bulletin of the Geological Society of Greece 51 (October 4, 2017): 18. http://dx.doi.org/10.12681/bgsg.11960.

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The main parameter that controls the groundwater flow regime in fractured aquifers is the fracture pattern. Its description is crucial for a hydrogeological study, as the hydraulic properties of hard rocks are mainly controlled by fracturing. The parameters of the fracture pattern that were analyzed in the study area were the frequency and spatial location of the fractures, the density of fractures and the degree of fracture intersection.Furthermore, a straight link between the fracture pattern and the hydrological conditions is important for a first analysis of the potential groundwater zones

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11

Jiang, Le, Peng Gao, Jie Liu, et al. "Simulation and Optimization of Dynamic Fracture Parameters for an Inverted Square Nine-Spot Well Pattern in Tight Fractured Oil Reservoirs." Geofluids 2020 (September 22, 2020): 1–9. http://dx.doi.org/10.1155/2020/8883803.

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Dynamic fractures are a geological attribute of water flooding development in tight fractured oil reservoirs. However, previous studies have mainly focused on the opening mechanism of dynamic fractures and the influence of dynamic fractures on development. Few attempts have been made to investigate the optimization of the dynamic fracture parameter. In this study, the inverted square nine-spot well pattern model is established by taking fractured reservoir’s heterogeneity and its threshold pressure gradients into account. This simulation model optimizes the various parameters in a tight fractu

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Movahed, Zohreh, Meisam Ashraf, and Ali Asghar Movahed. "Assessment of Fracture Density Distribution from Image Logs for Sensitivity Analysis in the Asmari Fractured Reservoir." EARTH SCIENCES AND HUMAN CONSTRUCTIONS 3 (December 14, 2023): 99–118. http://dx.doi.org/10.37394/232024.2023.3.9.

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Characterizing fracture properties in naturally fractured reservoirs poses a significant challenge. While welltesting remains valuable, it often fails to provide precise descriptions of these properties. Bridging this gap requires the integration of geological expertise to enhance fracture assessment. This study addresses the limitations of well-test analysis and explores the application of Conventional Image Logs in structural, fracture, and geomechanical analysis. However, effectively combining these applications with well-test analysis on a field scale reveals a substantial knowledge gap. A

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ZHANG, LIMING, CHENYU CUI, XIAOPENG MA, ZHIXUE SUN, FAN LIU, and KAI ZHANG. "A FRACTAL DISCRETE FRACTURE NETWORK MODEL FOR HISTORY MATCHING OF NATURALLY FRACTURED RESERVOIRS." Fractals 27, no. 01 (2019): 1940008. http://dx.doi.org/10.1142/s0218348x19400085.

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The distribution of fractures is highly uncertain in naturally fractured reservoirs (NFRs) and may be predicted by using the assisted-history-matching (AHM) that calibrates the reservoir model according to some high-quality static data combined with dynamic production data. A general AHM approach for NFRs is to construct a discrete fracture network (DFN) model and estimate model parameters given the observations. However, the large number of fractures prediction required in the AHM process could pose a high-dimensional optimization problem. This difficulty is particularly challenging when the

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14

Stadtműller, Marek. "Well logging interpretation methodology for carbonate formation fracture system properties determination." Acta Geophysica 67, no. 6 (2019): 1933–43. http://dx.doi.org/10.1007/s11600-019-00351-w.

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Abstract The article presents the methodology for the qualitative determination of fracture zones in the profiles of carbonate formations, based on the complex fracture analysis (CFA) method. Three additive fracture ranges were distinguished, characterized by successively increasing aperture and fracture length values, operatively named micro, meso and macro. Furthermore, the quantitative characterization of fractures with different apertures was done. The methodology of laboratory data integration, fracture porosity and fracture permeability measurements performed on thin section and polished

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15

Ge, Zijian, Shulin Pan, and Jingye Li. "Seismic AVOA Inversion for Weak Anisotropy Parameters and Fracture Density in a Monoclinic Medium." Applied Sciences 10, no. 15 (2020): 5136. http://dx.doi.org/10.3390/app10155136.

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In shale gas development, fracture density is an important lithologic parameter to properly characterize reservoir reconstruction, establish a fracturing scheme, and calculate porosity and permeability. The traditional methods usually assume that the fracture reservoir is one set of aligned vertical fractures, embedded in an isotropic background, and estimate some alternative parameters associated with fracture density. Thus, the low accuracy caused by this simplified model, and the intrinsic errors caused by the indirect substitution, affect the estimation of fracture density. In this paper,

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16

Geng, Yudi, and Jun Zhou. "Parameter optimization of acid fracturing in ultra-deep fault zone carbonate reservoir." E3S Web of Conferences 338 (2022): 01021. http://dx.doi.org/10.1051/e3sconf/202233801021.

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The characteristics of fracture development are complex in Shunbei area. The natural fracture development is different between different fault zones and in different locations of the same fault zone. Not all natural fractures can be activated during acid fracturing, and not all natural fractures can contribute to well productivity after acid fracturing. The use of natural fractures can not only improve the seepage capacity of the reservoir, but also improve the well productivity. Therefore, the influence of artificial fracture on the opening and fracture conductivity maintenance of natural fra

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17

Zheng, Yongxiang, Jianjun Liu, and Yun Lei. "The Propagation Behavior of Hydraulic Fracture in Rock Mass with Cemented Joints." Geofluids 2019 (June 27, 2019): 1–15. http://dx.doi.org/10.1155/2019/5406870.

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The formation of the fracture network in shale hydraulic fracturing is the key to the successful development of shale gas. In order to analyze the mechanism of hydraulic fracturing fracture propagation in cemented fractured formations, a numerical simulation about fracture behavior in cemented joints was conducted based firstly on the block discrete element. And the critical pressure of three fracture propagation modes under the intersection of hydraulic fracturing fracture and closed natural fracture is derived, and the parameter analysis is carried out by univariate analysis and the response

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18

Chen, Huaizhen, Tiansheng Chen, and Kristopher A. Innanen. "Estimating tilted fracture weaknesses from azimuthal differences in seismic amplitude data." GEOPHYSICS 85, no. 3 (2020): R135—R146. http://dx.doi.org/10.1190/geo2019-0344.1.

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Tilted transverse isotropy (TTI) provides a useful model for the elastic response of a medium containing aligned fractures with a symmetry axis oriented obliquely in the vertical and horizontal coordinate directions. Robust methods for determining the TTI properties of a medium from seismic observations to characterize fractures are sought. Azimuthal differencing of seismic amplitude data produces quantities that are particularly sensitive to TTI properties. Based on the linear slip fracture model, we express the TTI stiffness matrix in terms of the normal and tangential fracture weaknesses. P

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19

Xia, Kaiwen, Cangli Liu, and Patrick Kanopoulos. "On the Energy of Dynamic Fractures." International Journal of Nonlinear Sciences and Numerical Simulation 13, no. 2 (2012): 117–23. http://dx.doi.org/10.1515/ijnsns.2011.119.

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Abstract The validity of the constant propagation fracture energy postulation for dynamic fracture is discussed. As shown from existing direct and indirect experimental results, this assumption may not represent the physical reality. For spontaneous fractures, the fracture energy was shown to increase linearly with the crack length, and for dynamic fractures driven by known amplitude impulsive loading (generated by planar impact), the fracture energy was not a constant either. Despite of its phenomenogical origin, the Broberg's theory developed for self-similar crack growth works well for both

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20

Lu, Le, and Dongxiao Zhang. "Assisted History Matching for Fractured Reservoirs by Use of Hough-Transform-Based Parameterization." SPE Journal 20, no. 05 (2015): 942–61. http://dx.doi.org/10.2118/176024-pa.

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Summary Successful production in fractured reservoirs is significantly dependent on knowledge of the location, orientation, and conductivity of the fractures. Early water breakthrough can be prevented and sweep efficiency can be improved with the help of comprehensive and accurate information of fracture distributions. However, it is a challenge to estimate fracture distributions by conventional-history-matching methods because of the complexity of such reservoirs. Although there has been great progress in assisted-history-matching techniques during the last 2 decades, estimating fracture dist

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Shen, Feng, Xiang Zhu, and M. Nafi Toksöz. "Effects of fractures on NMO velocities and P‐wave azimuthal AVO response." GEOPHYSICS 67, no. 3 (2002): 711–26. http://dx.doi.org/10.1190/1.1484514.

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This paper attempts to explain the relationships between fractured medium properties and seismic signatures and distortions induced by geology‐related influences on azimuthal AVO responses. In the presence of vertically aligned fractures, the relationships between fracture parameters (fracture density, fracture aspect ratio, and saturated fluid content) and their seismic signatures are linked with rock physics models of fractured media. The P‐wave seismic signatures studied in this paper include anisotropic parameters (δ(v), (v), and γ(v)), NMO velocities, and azimuthal AVO responses, where δ(

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Ye, Dayu, Guannan Liu, and Gao Feng. "Quantifying Fracture Dynamics in Clean Energy: A Novel Fractal Perspective." E3S Web of Conferences 530 (2024): 05002. http://dx.doi.org/10.1051/e3sconf/202453005002.

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Geothermal energy, as an emergent source of power, has consistently been a focal point of scholarly investigation both domestically and internationally, with a particular emphasis on the prediction and assessment of its extraction efficiency. In common geothermal extraction projects, the seepage behavior of water within the fractures for the geothermal reservoirs significantly impacts the efficiency of resource extraction. This study introduces an interdisciplinary fractal model for geothermal extraction. An enhanced fractal theory, tailored for geothermal reservoirs, is proposed, employing fo

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Hörl, Maximilian, and Christian Rohde. "Rigorous derivation of discrete fracture models for Darcy flow in the limit of vanishing aperture." Networks and Heterogeneous Media 19, no. 1 (2024): 114–56. http://dx.doi.org/10.3934/nhm.2024006.

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<abstract><p>We consider single-phase flow in a fractured porous medium governed by Darcy's law with spatially varying hydraulic conductivity matrices in both bulk and fractures. The width-to-length ratio of a fracture is of the order of a small parameter $ \varepsilon $ and the ratio $ {{K_\mathrm{f}}}^\star / {{K_\mathrm{b}}}^\star $ of the characteristic hydraulic conductivities in the fracture and bulk domains is assumed to scale with $ \varepsilon^\alpha $ for a parameter $ \alpha \in \mathbb{R} $. The fracture geometry is parameterized by aperture functions on a submanifold o

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Sri, Feni Maulindani, Rusdi Pauhesti, Prima Andry, Agus Wibowo Djunaedi, and Widiyatni Harin. "Determination of Reservoir Parameter of Naturally Fractured Reservoir at SF Field using Rate Type Curve Analysis." International Journal of Current Science Research and Review 07, no. 06 (2024): 3994–4003. https://doi.org/10.5281/zenodo.12155859.

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Abstract : This Naturally Fractured Reservoir (NFR) is become challenging to identify the behavior of performance in fluid flow in producing well at SF oil Field. Generally, this unique of mechanism that cannot be treated as homogenous reservoir, because has two porous media in this reservoir such as matrix and fracture, the dominantly fluid flow comes from the networks of fractures, but for matrix porous media as function of source that transfer fluid to the fractures. This complexity of reservoir needs deepest investigate the characteristic of this reservoir and estimating the reservoir para

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Tang, Dong, Huixiang Jian, Min Song, and Zhongming Jiang. "Migration of Leaked Oil Vapor in Underground Water-Sealed Oil Storage Cavern Considering the Influence of Fractures." Journal of Marine Science and Engineering 11, no. 6 (2023): 1248. http://dx.doi.org/10.3390/jmse11061248.

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During the operation of underground water-sealed oil storage caverns, a large amount of oil vapor is generated due to volatilization. Oil vapor can easily leak into the surrounding rock, and fractures in the surrounding rock are usually the dominant channels for oil vapor leakage. To study the influence of fractures on oil vapor leakage and migration in underground water-sealed oil storage caverns during the oil storage period, a gas–liquid two-phase flow model of the fracture–pore dual medium in fractured rock mass was established. The program was implemented on the COMSOL platform by using w

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Zhao, Zhi Hong, Jian Chun Guo, and Fan Hui Zeng. "A New Model for Predicting Productivity and Application for Fractured Horizontal Wells." Advanced Materials Research 524-527 (May 2012): 1310–13. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1310.

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Due to the differences of stress and physical property in the pay zone, the fractured horizontal well may be different in length and azimuth angle. Furthermore, because of the mutual disturbance among fractures, the accurate prediction of production of fractured horizontal wells become more complicated. This paper presents a new model to predict the production of the fractured horizontal wells by considering the effects of fracture number, fracture length, fracture interval, fracture symmetry, azimuth angle and conductivity. Compared with the numerical simulation, this model needs less paramet

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Civan, F., and M. L. L. Rasmussen. "Parameters of Matrix/Fracture Immiscible-Fluids Transfer Obtained by Modeling of Core Tests." SPE Journal 17, no. 02 (2012): 540–54. http://dx.doi.org/10.2118/104028-pa.

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Summary Methodology is presented and proved for determination of the best-estimate parameter values affecting the matrix/fracture-interface fluid transfer in naturally fractured reservoirs. Fracture/surface-hindered interface transfer of immiscible fluids is considered between matrix blocks and surrounding natural fractures. Improved matrix/fracture-transfer models are applied on the basis of presumed matrix-block shapes. Analytical solutions and the limiting isotropic-matrix long-time shape factors developed for special boundary conditions are used for interpretation of typical laboratory tes

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Chichinina, Tatiana, Vladimir Sabinin, and Gerardo Ronquillo-Jarillo. "QVOA analysis: P-wave attenuation anisotropy for fracture characterization." GEOPHYSICS 71, no. 3 (2006): C37—C48. http://dx.doi.org/10.1190/1.2194531.

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This paper investigates [Formula: see text]-anisotropy for characterizing fractured reservoirs — specifically, the variation of the seismic quality factor [Formula: see text] versus offset and azimuth (QVOA). We derive an analytical expression for P-wave attenuation in a transversely isotropic medium with horizontal symmetry axis (HTI) and provide a method (QVOA) for estimating fracture direction from azimuthally varying [Formula: see text] in PP-wave reflection data. The QVOA formula is similar to Rüger’s approximation for PP-wave reflection coefficients, the theoretical basis for amplitude v

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Ren, Fengyu, Jing Zhang, Zhihua Ouyang, and Hao Hu. "Calculation of Elastic Modulus for Fractured Rock Mass Using Dimensional Analysis Coupled with Numerical Simulation." Mathematical Problems in Engineering 2021 (February 12, 2021): 1–14. http://dx.doi.org/10.1155/2021/2803837.

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Underground mining activities make the fractures in the natural rock mass develop randomly. The elastic modulus of the fractured rock mass Em is changed with the redistribution and development of the fractures. An equivalent model of fractured rock mass is structured to represent the hydraulic conductivity and the rock mass strain because of the continuum theory. Dimensional analysis is very useful to build relationship of the parameters in complex physical phenomena. Based on the engineering phenomenon of groundwater flowing into the goaf along the fracture in the rock mass, a fuzzy expressio

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Dershowitz, Bill, Paul LaPointe, Thorsten Eiben, and Lingli Wei. "Integration of Discrete Feature Network Methods With Conventional Simulator Approaches." SPE Reservoir Evaluation & Engineering 3, no. 02 (2000): 165–70. http://dx.doi.org/10.2118/62498-pa.

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Summary The discrete feature network (DFN) approach offers many key advantages over conventional dual porosity (DP) approaches, particularly when issues of connectivity dominate recovery and reservoir stimulation in fractured and heterogeneous reservoirs. DP models have been developed for complex multiphase and thermal effects, and have been implemented for basin scale modeling. However, DP models address only the dual porosity nature of fractured reservoirs, generally simplifying connectivity and scale-dependent heterogeneity issues which are modeled efficiently and more accurately by the DFN

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Qiao, Lianlian, Erhu Liu, Dong Sun, et al. "Numerical Investigation of Vertical Hydraulic Fracture Propagation and Fracturing Parameter Optimization in Deep Coalbed Methane Reservoirs." Processes 13, no. 3 (2025): 909. https://doi.org/10.3390/pr13030909.

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Deep coalbed methane (CBM) reservoirs hold substantial resource potential and play a crucial role in China’s unconventional natural gas development. However, the vertical propagation behavior of hydraulic fractures in deep CBM formations remains inadequately understood, posing challenges for optimizing fracturing parameters to control fracture height growth and enhance fracture development within the coal seam. To address this, this study establishes numerical simulation models to investigate hydraulic fracture propagation in directional wells, incorporating three typical lithological combinat

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Ding, Benjamin T. K., Kaamini Pillay, and Sreedharan Sechachalam. "Radial shaft fracture obliquity as a predictor of distal radioulnar joint instability." Journal of Hand Surgery (European Volume) 43, no. 7 (2018): 732–38. http://dx.doi.org/10.1177/1753193418756591.

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We assessed whether radial shaft fracture obliquity measurements on radiographs could predict intra-operative distal radioulnar joint instability. We also clinically validated previously described predictors of distal radioulnar joint instability, which included a fracture line within 7.5 cm of the lunate fossa, radial shortening >5 mm, and ulna styloid fracture. We retrospectively analysed the radiographs of all surgically managed patients in our unit with radial shaft fractures from 2006 through 2016. The degree of obliquity was analysed on the basis of the maximum fracture-line angle in

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Huang, Shijun, Jiaojiao Zhang, Sidong Fang, and Xifeng Wang. "An Analytical Method for Parameter Interpretation of Fracture Networks in Shale Gas Reservoirs considering Uneven Support of Fractures." Geofluids 2021 (October 14, 2021): 1–15. http://dx.doi.org/10.1155/2021/3800525.

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In shale gas reservoirs, the production data analysis method is widely used to invert reservoir and fracture parameter, and productivity prediction. Compared with numerical models and semianalytical models, which have high computational cost, the analytical model is mostly used in the production data analysis method to characterize the complex fracture network formed after fracturing. However, most of the current calculation models ignore the uneven support of fractures, and most of them use a single supported fracture model to describe the flow characteristics, which magnifies the role of sup

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Huang, Shijun, Jiaojiao Zhang, Sidong Fang, and Xifeng Wang. "An Analytical Method for Parameter Interpretation of Fracture Networks in Shale Gas Reservoirs considering Uneven Support of Fractures." Geofluids 2021 (October 14, 2021): 1–15. http://dx.doi.org/10.1155/2021/3800525.

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In shale gas reservoirs, the production data analysis method is widely used to invert reservoir and fracture parameter, and productivity prediction. Compared with numerical models and semianalytical models, which have high computational cost, the analytical model is mostly used in the production data analysis method to characterize the complex fracture network formed after fracturing. However, most of the current calculation models ignore the uneven support of fractures, and most of them use a single supported fracture model to describe the flow characteristics, which magnifies the role of sup

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Liu, Jie, Zhenhua Xu, Zhe Yuan, Hanyu Bie, and Pengcheng Liu. "Numerical Simulation Study on Fracture Parameter Optimization in Developing Low-Permeability Anisotropic Reservoirs." Geofluids 2018 (December 24, 2018): 1–9. http://dx.doi.org/10.1155/2018/1690102.

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The diamond-shape inverted nine-spot well pattern is widely used in developing low-permeability reservoirs with fractures. However, production wells with equal fracture lengths will lead to nonuniform displacement, especially in anisotropic reservoir. Previous researches mainly focused on equal-length fractures, while studies on the unequal-length fractures which can dramatically improve the development efficiency were little. In this paper, a corresponding numerical model with unequal length of fracture designed in the edge and the corner wells was built in a low-permeability anisotropic rese

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Aghli, Ghasem, Reza Moussavi-Harami, and Ruhangiz Mohammadian. "Reservoir heterogeneity and fracture parameter determination using electrical image logs and petrophysical data (a case study, carbonate Asmari Formation, Zagros Basin, SW Iran)." Petroleum Science 17, no. 1 (2019): 51–69. http://dx.doi.org/10.1007/s12182-019-00413-0.

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AbstractAssessment of reservoir and fracture parameters is necessary to optimize oil production, especially in heterogeneous reservoirs. Core and image logs are regarded as two of the best methods for this aim. However, due to core limitations, using image log is considered as the best method. This study aims to use electrical image logs in the carbonate Asmari Formation reservoir in Zagros Basin, SW Iran, in order to evaluate natural fractures, porosity system, permeability profile and heterogeneity index and accordingly compare the results with core and well data. The results indicated that

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Far, Mehdi E., Bob Hardage, and Don Wagner. "Fracture parameter inversion for Marcellus Shale." GEOPHYSICS 79, no. 3 (2014): C55—C63. http://dx.doi.org/10.1190/geo2013-0236.1.

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We inverted P-wave amplitude variation with offset and azimuth (AVOAz) data from the Marcellus Shale to obtain fracture parameters that can fully describe the elastic behavior of fractured rocks with overall symmetry of orthorhombic or monoclinic. AVOAz data from two interfaces, (1) the upper interface between top Marcellus and Stafford limestone and (2) the lower interface between base Marcellus and Onondaga limestone, were used for inversion. To check the validity of our inversion results, fracture parameters for the Marcellus Shale were inverted for each interface using Monte Carlo simulati

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Bakulin, Andrey, Vladimir Grechka, and Ilya Tsvankin. "Estimation of fracture parameters from reflection seismic data—Part II: Fractured models with orthorhombic symmetry." GEOPHYSICS 65, no. 6 (2000): 1803–17. http://dx.doi.org/10.1190/1.1444864.

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Existing geophysical and geological data indicate that orthorhombic media with a horizontal symmetry plane should be rather common for naturally fractured reservoirs. Here, we consider two orthorhombic models: one that contains parallel vertical fractures embedded in a transversely isotropic background with a vertical symmetry axis (VTI medium) and the other formed by two orthogonal sets of rotationally invariant vertical fractures in a purely isotropic host rock. Using the linear‐slip theory, we obtain simple analytic expressions for the anisotropic coefficients of effective orthorhombic medi

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Qin, Xilin, Zhixian Gui, Fei Yang, Yuanyuan Liu, Wei Jin, and Jian Xiong. "Prediction of sweet spots in tight sandstone reservoirs based on anisotropic frequency-dependent AVO inversion." Journal of Geophysics and Engineering 18, no. 5 (2021): 664–80. http://dx.doi.org/10.1093/jge/gxab044.

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Abstract The frequency-dependent amplitude-versus-offset (FAVO) method has become a practical method for fluid detection in sand reservoirs. At present, most FAVO inversions are based on the assumption that reservoirs are isotropy, but the application effect is not satisfactory for fractured reservoirs. Hence, we analyse the frequency variation characteristics of anisotropy parameters in tight sandstone reservoirs based on a new petrophysical model, and propose a stepwise anisotropic FAVO inversion method to extract frequency-dependent attributes from prestack seismic field data. First, we com

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ZHANG, KAI, XIAOPENG MA, YANLAI LI, et al. "PARAMETER PREDICTION OF HYDRAULIC FRACTURE FOR TIGHT RESERVOIR BASED ON MICRO-SEISMIC AND HISTORY MATCHING." Fractals 26, no. 02 (2018): 1840009. http://dx.doi.org/10.1142/s0218348x18400091.

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Hydraulic fracturing is an important measure for the development of tight reservoirs. In order to describe the distribution of hydraulic fractures, micro-seismic diagnostic was introduced into petroleum fields. Micro-seismic events may reveal important information about static characteristics of hydraulic fracturing. However, this method is limited to reflect the distribution area of the hydraulic fractures and fails to provide specific parameters. Therefore, micro-seismic technology is integrated with history matching to predict the hydraulic fracture parameters in this paper. Micro-seismic s

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Kharrat, Riyaz, Ali Kadkhodaie, Siroos Azizmohammadi, et al. "A Comprehensive Investigation of the Relationship between Fractures and Oil Production in a Giant Fractured Carbonate Field." Processes 12, no. 4 (2024): 631. http://dx.doi.org/10.3390/pr12040631.

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This study examines the connections between various fracture indicators and production data with an example from one of the giant fields in the Middle East producing complex fractured carbonate lithologies. The field under study hosts two reservoirs with a long development and production history, including carbonates from the Asmari and Bangestan Formations. A fracture intensity map was generated based on the interpretation of image logs from 28 wells drilled within the field. Mud loss data were collected and mapped based on the geostatistical Gaussian Random Function Simulation (GRFS) algorit

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Han, Tongcheng, and Sam Yang. "Dielectric properties of fractured carbonate rocks from finite-difference modeling." GEOPHYSICS 84, no. 1 (2019): MR37—MR44. http://dx.doi.org/10.1190/geo2018-0003.1.

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Fractures are common features in virtually all types of geologic rocks and tend to dominate their mechanical and hydraulic properties. Detection and characterization of fractures in rocks are of interest to a variety of geophysical applications. We have investigated the frequency-dependent dielectric properties of fractured porous carbonate rocks in the frequency range [Formula: see text] and their relationships with different types of fluids filling the fractures, fracture connectivity, and directions of electrical field applied to the rocks using numerical simulation methods based on a 3D fi

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Fleischhacker, Evi, Georg Siebenbürger, Johannes Gleich, Wolfgang Böcker, Fabian Gilbert, and Tobias Helfen. "The Accuracy of Distal Clavicle Fracture Classifications—Do We Need an Amendment to Imaging Modalities or Fracture Typing?" Journal of Clinical Medicine 11, no. 19 (2022): 5638. http://dx.doi.org/10.3390/jcm11195638.

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Background: Despite its fair-to-moderate reliability, the “modified Neer classification” is widely accepted and used. The purpose of this study was to reevaluate its applicability. Methods: Of n = 59 patients with distal clavicle fractures, fractures were classified on standard radiographs. Afterwards, an MRI examination was performed, and fractures reclassified. The primary outcome parameter was quantifying the rate of misclassification. The secondary outcome parameters were the evaluation of the ligamentous injury constellations. Results: In all cases, the fracture course and ligamental inte

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Hu, Hao, Yingcai Zheng, Xinding Fang, and Michael C. Fehler. "3D seismic characterization of fractures with random spacing using the double-beam method." GEOPHYSICS 83, no. 5 (2018): M63—M74. http://dx.doi.org/10.1190/geo2017-0739.1.

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Obtaining information on the spatial distribution of subsurface natural and induced fractures is critical in the production of geothermal or hydrocarbon fluids. Traditional seismic characterization methods for subsurface fractures are based on the assumption of effective anisotropy medium theory, which may not be true in reality when the fracture distribution is random. We have tested the recently proposed double-beam method to characterize nonuniformly distributed fractures. We built a 3D layered reservoir model; the reservoir layer was geometrically irregular, and it contained a set of rando

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Kumar, Ashish, and Mukul M. Sharma. "Diagnosing Hydraulic Fracture Geometry, Complexity, and Fracture Wellbore Connectivity Using Chemical Tracer Flowback." Energies 13, no. 21 (2020): 5644. http://dx.doi.org/10.3390/en13215644.

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The productivity of a hydraulically fractured well depends on the fracture geometry and fracture–wellbore connectivity. Unlike other fracture diagnostics techniques, flowback tracer response will be dominated only by the fractures, which are open and connected to the wellbore. Single well chemical tracer field tests have been used for hydraulic fracture diagnostics to estimate the stagewise production contribution. In this study, a chemical tracer flowback analysis is presented to estimate the fraction of the created fracture area, which is open and connected to the wellbore. A geomechanics co

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Somodi, Gábor, and Balázs Vásárhelyi. "Scale and Rock Type Dependency of Mórágy Granite Formation in the Aspect of Fracture Density." Geotechnics 5, no. 2 (2025): 34. https://doi.org/10.3390/geotechnics5020034.

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The geometry of rock mass fractures is typically characterized through geological and geotechnical investigations. Detailed descriptions of granitic host rock can yield valuable data for constructing fracture network models. However, significant discrepancies often arise between data representing the mechanical and hydraulic properties of rocks. At the study site, fracture geometry data were gathered through surface and underground surveying, borehole logging, and underground mapping. Three-dimensional photogrammetry was utilized alongside traditional rock mass classification methods (Q-system

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Chen, Li, Sun Lichun, Sun Hansen, Feng Ruyong, Wang Cunwu, and Zhang Fang. "A Method to Improve Computational Efficiency of Productivity Evaluation with Rectangular Coalbed Methane Reservoir." Geofluids 2022 (March 11, 2022): 1–11. http://dx.doi.org/10.1155/2022/3558643.

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Computational efficiency is the key factor to be considered in the productivity evaluation of rectangular coalbed methane reservoir. There are three main factors affecting the calculation speed: the nonlinearity of the material balance equation of coalbed methane reservoir, the poor conductivity of fractures cannot be considered as infinite conductivity fractures, and the Duhamel convolution is needed in history fitting and boundary image inversion. At present, there is no method to quickly evaluate the productivity of finite conductivity fracture model in rectangular coalbed methane reservoir

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Matvienko, Yu G. "Two-parameter elastic-plastic fracture criterion and corrected fracture toughness." Industrial laboratory. Diagnostics of materials 88, no. 8 (2022): 59–69. http://dx.doi.org/10.26896/1028-6861-2022-88-8-59-69.

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The basic aspects of the J-A concept of elastic-plastic two-parameter fracture mechanics, based on a three-term asymptotic description of the stress field at the crack tip are presented. It is noted that the field of elastic-plastic stresses at the crack tip is controlled by two parameters of fracture mechanics, namely, J-integral and parameter A. Parameter A is a measure of the deviation of the stress field from the HRR-stress field and can be considered a parameter of elastic-plastic constraint at the crack tip both under conditions of small- and large-scale yielding. The results of studying

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Malikova, Lucie, Hana Simonova, Barbara Kucharczykova, and Petr Miarka. "Multi-parameter fracture mechanics." Frattura ed Integrità Strutturale 13, no. 49 (2019): 65–73. http://dx.doi.org/10.3221/igf-esis.49.07.

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Wagner, D. A., and J. C. Simo. "Fracture parameter for thermoinelasticity." International Journal of Fracture 56, no. 2 (1992): 159–87. http://dx.doi.org/10.1007/bf00015598.

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