Relevant bibliographies by topics / Fracture

Contents

  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers
  6. Reports

Academic literature on the topic 'Fracture'

Author: Grafiati
Published: 4 June 2021
Last updated: 26 October 2024

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Journal articles on the topic "Fracture"

1

Wang, Yueying, Jun Yao, Shuaishi Fu, Aimin Lv, Zhixue Sun, and Kelvin Bongole. "Simulation of counter-current imbibition in water-wet fractured reservoirs based on discrete-fracture model." Open Physics 15, no. 1 (August 3, 2017): 536–43. http://dx.doi.org/10.1515/phys-2017-0061.

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AbstractIsolated fractures usually exist in fractured media systems, where the capillary pressure in the fracture is lower than that of the matrix, causing the discrepancy in oil recoveries between fractured and non-fractured porous media. Experiments, analytical solutions and conventional simulation methods based on the continuum model approach are incompetent or insufficient in describing media containing isolated fractures. In this paper, the simulation of the counter-current imbibition in fractured media is based on the discrete-fracture model (DFM). The interlocking or arrangement of matrix and fracture system within the model resembles the traditional discrete fracture network model and the hybrid-mixed-finite-element method is employed to solve the associated equations. The Behbahani experimental data validates our simulation solution for consistency. The simulation results of the fractured media show that the isolated-fractures affect the imbibition in the matrix block. Moreover, the isolated fracture parameters such as fracture length and fracture location influence the trend of the recovery curves. Thus, the counter-current imbibition behavior of media with isolated fractures can be predicted using this method based on the discrete-fracture model.
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Feng, Yueli, Yuetian Liu, and Gang Lei. "Study on Stress-Dependent Permeability of Fracture Networks in Fractured Porous Media." Geofluids 2021 (June 24, 2021): 1–19. http://dx.doi.org/10.1155/2021/7433547.

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In order to investigate the stress-sensitive characteristics of fracture networks under reservoir actual stress condition and its influence on the seepage in fractured porous media, we carried out permeability tests on experimental models with fracture networks under constant-volume boundary condition. In addition, a novel analytical stress-dependent permeability model of fracture networks in different directions was derived. Based on the test results and the proposed analytical model, the effects of various parameters (e.g., initial fracture aperture, fluid pressure, rock elastic modulus, effective-stress coefficient, and fracture dip) on deformation characteristics of fracture networks and the corresponding permeability tensor of fracture networks were studied. The research results show that, for a fractured porous media with a single group of fractures, the principal value of permeability is always parallel to the fracture-development direction. With increasing effective stress, the principal value of permeability decreases; however, the principal value direction remains unchanged. Moreover, for the fractured porous media with multiple sets of fractures, the principal direction of equivalent permeability will be inclined to the fractures with larger fracture aperture. Specifically, for the fractured porous media with two sets of intersecting fractures, the principal direction of equivalent permeability is parallel to the angular bisector of these two sets of intersecting fractures. Furthermore, the greater the difference of the fracture aperture change rate under effective stress, the more obvious the deviation of the permeability principal direction. The derived analytical model is of great theoretical and scientific significance to deepen the understanding of the stress-sensitive permeability of fractured reservoirs.
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Yuan, Yingzhong, Wende Yan, Fengbo Chen, Jiqiang Li, Qianhua Xiao, and Xiaoliang Huang. "Numerical Simulation for Shale Gas Flow in Complex Fracture System of Fractured Horizontal Well." International Journal of Nonlinear Sciences and Numerical Simulation 19, no. 3-4 (June 26, 2018): 367–77. http://dx.doi.org/10.1515/ijnsns-2017-0135.

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AbstractComplex fracture systems including natural fractures and hydraulic fractures exist in shale gas reservoir with fractured horizontal well development. The flow of shale gas is a multi-scale flow process from microscopic nanometer pores to macroscopic large fractures. Due to the complexity of seepage mechanism and fracture parameters, it is difficult to realize fine numerical simulation for fractured horizontal wells in shale gas reservoirs. Mechanisms of adsorption–desorption on the surface of shale pores, slippage and Knudsen diffusion in the nanometer pores, Darcy and non-Darcy seepage in the matrix block and fractures are considered comprehensively in this paper. Through fine description of the complex fracture systems after horizontal well fracturing in shale gas reservoir, the problems of conventional corner point grids which are inflexible, directional, difficult to geometrically discretize arbitrarily oriented fractures are overcome. Discrete fracture network model based on unstructured perpendicular bisection grids is built in the numerical simulation. The results indicate that the discrete fracture network model can accurately describe fracture parameters including length, azimuth and density, and that the influences of fracture parameters on development effect of fractured horizontal well can be finely simulated. Cumulative production rate of shale gas is positively related to fracture half-length, fracture segments and fracture conductivity. When total fracture length is constant, fracturing effect is better if single fracture half-length or penetration ratio is relatively large and fracturing segments are moderate. Research results provide theoretical support for optimal design of fractured horizontal well in shale gas reservoir.
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Schoenberg, Michael, and Colin M. Sayers. "Seismic anisotropy of fractured rock." GEOPHYSICS 60, no. 1 (January 1995): 204–11. http://dx.doi.org/10.1190/1.1443748.

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A simple method for including the effects of geologically realistic fractures on the seismic propagation through fractured rocks can be obtained by writing the effective compliance tensor of the fractured rock as the sum of the compliance tensor of the unfractured background rock and the compliance tensors for each set of parallel fractures or aligned fractures. The compliance tensor of each fracture set is derivable from a second rank fracture compliance tensor. For a rotationally symmetric set of fractures, the fracture compliance tensor depends on only two fracture compliances, one controlling fracture compliance normal, the other, tangential, to the plane of the fractures. The stiffness tensor, which is more useful in the consideration of elastic wave propagation through rocks, can then be obtained by inversion. The components of the excess fracture compliance tensor represent the maximum amount of information that can be obtained from seismic data. If the background rock is isotropic and the normal and shear compliance of each fracture are equal, although different from those of other fractures, the effective elastic behavior of the fractured rock is orthorhombic for any orientation distribution of fractures. A comparison of the theory with recent ultrasonic experiments on a simulated fractured medium shows near equality of the normal and shear compliance for the case of air‐filled fractures.
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Abedi, Behbood, Mohammad Hossein Ghazanfari, and Riyaz Kharrat. "Experimental Study of Polymer Flooding in Fractured Systems Using Five-Spot Glass Micromodel: The Role of Fracture Geometrical Properties." Energy Exploration & Exploitation 30, no. 5 (October 2012): 689–705. http://dx.doi.org/10.1260/0144-5987.30.5.689.

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Water flooding is being widely used in the petroleum industry and has been considered as a simple inexpensive secondary recovery method. But in fractured formations, existence of fracture system in reservoir rock induces an adverse effect on oil recovery by water flooding. Polymer flooding has been successfully applied as an alternative enhanced oil recovery method in fractured formations. But, the role of fracture geometrical properties on macroscopic efficiency of polymer flooding is not yet well-understood, especially in fractured five-spot systems. In this work five-spot glass micromodel, because of micro-visibility, ease of multiple experimentations and also presence of the unexplored issues, was used to experimentally investigate the influence of fracture geometrical characteristics such as fracture orientation, fracture spacing, fracture overlap and etc on the macroscopic efficiency of polymer flooding. The tests were performed on the fractured models which are initially saturated with the crude oil at fixed flow rate conditions and in a horizontally mounting. The results revealed that the macroscopic efficiency of polymer flooding depends on fracture geometrical properties. Fracture orientation showed more imposing effect than other fracture geometrical properties, and fracture with 45 degree inclination to the mean flow direction, gives greatest oil recovery factor. Large spacing fractures give more recovery than small spacing ones and in case of overlapping, fractures with less overlapping help polymer to better propagate which could be related to their greater effective fracture length. This pre-called effect could be responsible to show how continuity and width to length ratio of fractures affect recovery factor, less fracture discontinuity as well as more length to width ratio of fracture give more swept zone. Also, increasing number of fractures decreases oil recovery factor. The results of this work can be helpful to better understanding the role of fracture geometrical properties on macroscopic efficiency of polymer flooding in five-spot fractured systems.
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Shi, Shanzhi, Renyan Zhuo, Leiming Cheng, Yuankai Xiang, Xinfang Ma, and Tao Wang. "Fracture Characteristics and Distribution in Slant Core from Conglomerate Hydraulic Fracturing Test Site (CHFTS) in Junggar Basin, Northwest China." Processes 10, no. 8 (August 19, 2022): 1646. http://dx.doi.org/10.3390/pr10081646.

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Hydraulic fracture networks, especially fracture geometry, height growth, and proppant transport within the networks, present a critical influence on productivity evaluation and optimization of fracturing parameters. However, information about hydraulic fracture networks in post-fractured formations is seldom available. In this study, the characteristics (density and orientation) of hydraulic fractures were obtained from field observations of cores taken from conglomerate hydraulic fracturing test site (CHFTS). A large number of fractures were observed in the cores, and systematic fracture description was carried out. The fracture analysis data obtained includes fracture density, fracture depth, fracture orientation, morphology, fracture surface features, apertures, fill, fracture mechanical origin (type), etc. Our results show that 228 hydraulic fractures were intersected in a span of 293.71 m of slant core and composed of irregularly spaced single fractures and fracture swarms. One of the potential sources of the observed fracture swarms is near-wellbore tortuosity. Moreover, for regions far away from the wellbore, reservoir heterogeneity can promote complex hydraulic fracture trajectories. The hydraulic fractures were mainly cross-gravel and high-angle fractures and align with maximum horizontal stress (SHmax) ± 15°. The fracture density, orientations, and types obtained from the core fracture description provided valuable information regarding fracture growth behavior. For the near-wellbore area with a transverse distance of less than 25 m from the hydraulically-fractured wellbore, tensile fractures were dominant. While for the area far away from the wellbore, shear fractures were dominant. Our results provide improved understanding of the spatial hydraulic fracture dimensions, proppant distribution, and mechanism of hydraulic fracture formation. The dataset acquired can also be used to calibrate numerical models and characterize hydraulic fracture geometry and proppant distribution.
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He, Jiwei, Qin Li, Guodong Jin, Sihai Li, Kunpeng Shi, and Huilin Xing. "A Numerical Model for Pressure Analysis of a Well in Unconventional Fractured Reservoirs." Energies 16, no. 5 (March 6, 2023): 2505. http://dx.doi.org/10.3390/en16052505.

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Fractured reservoirs are highly heterogeneous in both matrix and fracture properties, which results in significant variations in well production. Assessing and quantifying the influence of fractures on fluid flow is essential for developing unconventional reservoirs. The complicated effects of fractures in unconventional fractured reservoirs on fluid flow highly depend on fracture geometry, fracture distribution, and fracture properties, which can be reflected in pressure transient testing. The biggest challenge lies in delineating the pre-existing natural fracture distribution pattern, density, azimuth, and connectivity. Using the advanced finite element method, this paper builds a finely characterized near-wellbore model to numerically simulate the pressure transient testing process in naturally fractured reservoirs and further evaluates fracture-related effects to obtain a more accurate solution. First, the numerical program is benchmarked by the analytical solutions and numerical results of Eclipse. Next, different fracture models with single fractures or fracture networks are set up to investigate the effects of fracture parameters numerically (e.g., fracture location, fracture dip angle, fracture spacing, the ratio of fracture permeability to matrix permeability, fracture network orientation, horizontal fracture distribution, etc.) on pressure transient behaviors in naturally fractured reservoirs. Velocity and pressure profiles are presented to visualize and analyze their effects, and new features in the flow regimes of the derivative plots of the bottom-hole pressure are identified and discussed. Finally, based on geological and geophysical data, including image logs, core descriptions, wireline logs, and seismic and well test data, a practical fractured model of the Dalwogan 2 well in the Surat basin is built, analyzed, and compared with homogenous and measured data. The results show significance in characterizing the complex fracture networks in near-wellbore models of unconventional fractured reservoirs.
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Al-Rubaie, Ali, and Hisham Khaled Ben Mahmud. "A numerical investigation on the performance of hydraulic fracturing in naturally fractured gas reservoirs based on stimulated rock volume." Journal of Petroleum Exploration and Production Technology 10, no. 8 (August 17, 2020): 3333–45. http://dx.doi.org/10.1007/s13202-020-00980-8.

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Abstract All reservoirs are fractured to some degree. Depending on the density, dimension, orientation and the cementation of natural fractures and the location where the hydraulic fracturing is done, preexisting natural fractures can impact hydraulic fracture propagation and the associated flow capacity. Understanding the interactions between hydraulic fracture and natural fractures is crucial in estimating fracture complexity, stimulated reservoir volume, drained reservoir volume and completion efficiency. However, because of the presence of natural fractures with diffuse penetration and different orientations, the operation is complicated in naturally fractured gas reservoirs. For this purpose, two numerical methods are proposed for simulating the hydraulic fracture in a naturally fractured gas reservoir. However, what hydraulic fracture looks like in the subsurface, especially in unconventional reservoirs, remain elusive, and many times, field observations contradict our common beliefs. In this study, the hydraulic fracture model is considered in terms of the state of tensions, on the interaction between the hydraulic fracture and the natural fracture (45°), and the effect of length and height of hydraulic fracture developed and how to distribute induced stress around the well. In order to determine the direction in which the hydraulic fracture is formed strikethrough, the finite difference method and the individual element for numerical solution are used and simulated. The results indicate that the optimum hydraulic fracture time was when the hydraulic fracture is able to connect natural fractures with large streams and connected to the well, and there is a fundamental difference between the tensile and shear opening. The analysis indicates that the growing hydraulic fracture, the tensile and shear stresses applied to the natural fracture.
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Liu, Jinhui, Yuli Zhou, and Jianguo Chen. "A Two-Dimensional Partitioning of Fracture–Matrix Flow in Fractured Reservoir Rock Using a Dual-Porosity Percolation Model." Energies 14, no. 8 (April 15, 2021): 2209. http://dx.doi.org/10.3390/en14082209.

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Fractures and micropores have varying contributions to the gas permeability of fractured reservoirs. The quantification of the contribution of fractures and micropores that form a dual-porosity system for gas permeability is critical when attempting to accurately evaluate gas production. However, due to insufficient knowledge of fracture–matrix flow partitioning in such dual-porosity systems, it is challenging for previous models to quantitatively characterize the fracture heterogeneity and accurately evaluate the gas flow and permeability in fractured rocks. In this study, we propose a dual-porosity percolation model to quantitatively investigate the contributions of fractures and matrix micropores towards the gas permeability of fractured rocks. Using percolation theory, we establish fracture networks with complex heterogeneity, which are characterized by various fracture densities and percolation probabilities within a porous matrix with various fracture/matrix permeability ratios. The compressible Navier–Stokes and Brinkman equations were adopted to describe the gas flow in the fractures and porous matrix, respectively. The simulation results indicate that the gas permeability of the dual-porosity system has an exponential relationship with the fracture density and matrix permeability. The contribution of fractures and matrix micropores toward gas permeability can be classified by establishing a two-dimensional partitioning of the fracture–matrix flow related to the fracture heterogeneity and fracture/matrix permeability ratio. The contribution of matrix micropores cannot be neglected if the fracture density is lower than a critical value.
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XU, PENG, HAICHENG LIU, AGUS PULUNG SASMITO, SHUXIA QIU, and CUIHONG LI. "EFFECTIVE PERMEABILITY OF FRACTURED POROUS MEDIA WITH FRACTAL DUAL-POROSITY MODEL." Fractals 25, no. 04 (July 25, 2017): 1740014. http://dx.doi.org/10.1142/s0218348x1740014x.

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As natural fractures show statistically fractal scaling laws, fractal geometry has been proposed and applied to model the fracture geometry and to study the hydraulic properties of fractured porous media. In this paper, a fractal dual-porosity model is developed to study the single-phase fluid flow through fractured porous media. An analytical expression for effective permeability of fractured porous media is derived, which depends on the fractal dimension and fracture aperture. The effect of fractal dimensions for fracture aperture distribution and tortuosity, the ratio of minimum to maximum fracture apertures and fracture fraction on the effective permeability have been discussed. In addition, a power law relationship between the effective permeability and fracture fraction is proposed to predict the equivalent hydraulic properties of fractured porous media. Compared with empirical formulas for effective permeability, the present fractal dual-porosity model can capture the statistical characteristics of fractures and shed light on the transport mechanism of fractured porous media.
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Dissertations / Theses on the topic "Fracture"

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Fatahi, Hassan. "Simulation of Hydraulic Fracture Propagation Interacted with Natural Fractures." Thesis, Curtin University, 2016. http://hdl.handle.net/20.500.11937/51882.

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This study developed an advance understanding of the mechanisms of hydraulic fracture initiation, propagation, and natural fractures interaction based-on thorough investigation of effects of various parameters associated with hydraulic and natural fractures through numerical modelling, simulation and laboratory experiments. Thesis progressively demonstrates different steps of the development of numerical modelling, simulation and experimental validation. Factors influencing the initiation and propagation of hydraulic fracture, and natural fractures interactions are thoroughly discussed based upon comprehensive sensitivity studies.
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Selle, Andrew. "Fracture." Bowling Green State University / OhioLINK, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=bgsu1427153464.

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Gross, Matthew Edward. "Discrete fracture modeling for fractured reservoirs using Voronoi grid blocks." Texas A&M University, 2003. http://hdl.handle.net/1969.1/5777.

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Fractured reservoirs are commonly simulated using the Dual Porosity model, but for many major fields, the model does not match field results. For these cases, it is necessary to perform a more complex simulation including either individual fractures or pseudofracture groups modeled in their own grid blocks. Discrete Fracture Modeling (DFN) is still a relatively new field, and most research on it up to this point has been done with Delaunay tessellations. This research investigates an alternative approach using Voronoi diagrams, yet applying the same DFN principles outlined in previous works. Through the careful positioning of node points, a grid of Voronoi polygons can be produced so that block boundaries fall along the fractures, allowing us to use the DFN simulation methods as proposed in the literature. Using Voronoi diagrams allows us to use far fewer polygons than the Delaunay approach, and also allows us to perfectly align flow so as to eliminate grid alignment errors that plagued previous static systems. The nature of the Voronoi polygon further allows us to simplify permeability calculations due to orthogonality and, by extension, is more accurate than the commonly used cornerpoint formulation for non-square grid blocks.
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Kim, Tae Hyung. "Fracture characterization and estimation of fracture porosity of naturally fractured reservoirs with no matrix porosity using stochastic fractal models." [College Station, Tex. : Texas A&M University, 2007. http://hdl.handle.net/1969.1/ETD-TAMU-2570.

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Marchais, Jean-Philippe. "La fracture des corps caverneux." Bordeaux 2, 1993. http://www.theses.fr/1993BOR2M109.

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Lolon, Elyezer P. "Evaluation of the relationship between fracture conductivity, fracture fluid production, and effective fracture length." Texas A&M University, 2004. http://hdl.handle.net/1969.1/3050.

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Low-permeability gas wells often produce less than predicted after a fracture treatment. One of the reasons for this is that fracture lengths calculated after stimulation are often less than designed lengths. While actual fracture lengths may be shorter due to fracture growth out of zone, improper proppant settling, or proppant flowback, short calculated fracture lengths can also result from incorrect analysis techniques. It is known that fracturing fluid that remains in the fracture and formation after a hydraulic fracture treatment can decrease the productivity of a gas well by reducing the relative permeability to gas in the region invaded by this fluid. However, the relationships between fracture fluid cleanup, effective fracture length, and well productivity are not fully understood. In this work I used reservoir simulation to determine the relationship between fracture conductivity, fracture fluid production, effective fracture length, and well productivity. I simulated water saturation and pressure profiles around a propped fracture, tracked gas production along the length of the propped fracture, and quantified the effective fracture length (i.e., the fracture length under single-phase flow conditions that gives similar performance as for multiphase flow conditions), the "cleanup" fracture length (i.e., the fracture length corresponding to 90% cumulative gas flow rate into the fracture), and the "apparent" fracture length (i.e., the fracture length where the ratio of multiphase to single-phase gas entry rate profiles is unity). This study shows that the proppant pack is generally cleaned up and the cleanup lengths are close to designed lengths in relatively short times. Although gas is entering along entire fracture, fracturing fluid remains in the formation near the fracture. The water saturation distribution affects the gas entry rate profile, which determines the effective fracture length. Subtle changes in the gas rate entry profile can result in significant changes in effective fracture length. The results I derived from this work are consistent with prior work, namely that greater fracture conductivity results in more effective well cleanup and longer effective fracture lengths versus time. This study provides better explanation of mechanisms that affect fracturing fluid cleanup, effective fracture length, and well productivity than previous work.
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Chung, Wai-Nang. "Fracture toughness and creep fracture studies of polyethylenes." Thesis, Imperial College London, 1991. http://hdl.handle.net/10044/1/46720.

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Daming, Duan. "Fracture toughness and term fracture behaviour of polyethylenes." Thesis, Imperial College London, 1996. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.243909.

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Helden, Svenhjalmar van. "Looking beyond the fracture prevention in fracture care /." [Maastricht] : Maastricht : [Maastricht University] ; University Library, Universiteit Maastricht [host], 2008. http://arno.unimaas.nl/show.cgi?fid=13442.

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Wang, Mingyu. "Discrete fracture fluid flow modeling and field applications in fractured rocks." Diss., The University of Arizona, 2000. http://hdl.handle.net/10150/284182.

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Fluid flow modeling in fractured rocks is a complicated and important research and application topic in many fields such as geological, hydrogeological, environmental and petroleum engineering. Commonly used methods based on equivalent continuum assumption for fluid flow modeling can generally be applied directly to the porous geological media, but have limited applicability when the geological medium is dominated by fractures. It often happens that only limited time, cost, hydrogeological data and computer resources are available in solving a practical problem of the fluid flow modeling in fractured rocks. Therefore, it is a challenge, but necessary, to investigate the hydraulic behaviors and propose new approaches, procedures, and methodologies to build a reliable fluid flow model for fractured rocks with limited available related data. The general concepts on fluid flow modeling in fractured rocks are introduced firstly and the different ways to treat major and minor fractures in 2-D and 3-D discrete fracture fluid flow modeling are propounded. The author has investigated the relations between the hydraulic behaviors and fracture geometry parameters and found out the effect of fracture parameters on the Representative Elementary Volume (REV) for the fracture systems with statistically distributed fracture geometry parameters including the size, orientation and location. Further, a systemic procedure for fluid flow modeling in fractured rocks in two-dimensional domain is suggested and demonstrated through a 2-D case study for groundwater resources evaluation. Six 3-D conceptual linear pipe discrete fracture fluid flow models which focus on the utilization of fracture information are proposed to simulate packer or pumping tests conducted in fractured rock masses. These models can reflect channel flow in fractures, simplify and minimize the complexity of fluid flow in fractures, save computer resources and increase the possibility to solve a field problem at large scales, and implement a discrete fracture fluid flow model easily. Finally, the author has developed a practicable systemic approach to determine the REV for hydraulic properties and then the hydraulic conductivity tensor for the REV in fractured rocks using single well packer test results. These procedures are illustrated through a 3-D case study by implementing the proposed fluid flow models.
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Books on the topic "Fracture"

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Adler, Pierre M., and Jean-François Thovert. Fractures and Fracture Networks. Dordrecht: Springer Netherlands, 1999. http://dx.doi.org/10.1007/978-94-017-1599-7.

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Adler, Pierre M. Fractures and Fracture Networks. Dordrecht: Springer Netherlands, 1999.

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Adler, Pierre M. Fractures and fracture networks. Boston: Kluwer, 1999.

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Apley, A. Graham. Concise system of orthopaedics and fractures. London: Butterworth Heinemann, 1988.

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McRae, Ronald. Practical fracture treatment. 2nd ed. Edinburgh: Churchill Livingstone, 1989.

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McRae, Ronald. Practical fracture treatment. 3rd ed. Edinburgh: Churchill Livingstone, 1994.

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Esser, Max, FRCS Ed ORTH FRACS., ed. Practical fracture treatment. 5th ed. Edinburgh: Churchill Livingstone, 2008.

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Esser, Max, FRCS Ed ORTH FRACS., ed. Practical fracture treatment. 4th ed. Edinburgh: Churchill Livingstone, 2003.

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Marvin, Tile, ed. The rationale of operative fracture care. 2nd ed. Berlin: Springer, 1996.

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Schatzker, Joseph. The rationale of operative fracture care. 3rd ed. Berlin: Springer, 2005.

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Book chapters on the topic "Fracture"

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Zhao, Yu, Yongfa Zhang, and Pengfei He. "Formation of Complex Networks." In Hydraulic Fracturing and Rock Mechanics, 231–65. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-2540-7_9.

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AbstractWhen a hydraulic fracture interacts with multiple natural fractures (such as bedding planes, faults, weak interlayers, and formation interfaces) in the formation, arrests, bifurcations, crossings, and openings may occur, contributing to forming a complex fracture network (referred as CFN). Shale differs from other types of rocks due to its apparent bedding anisotropy, making it easier to form complex fracture networks during hydraulic fracturing. A mass of field hydraulic fracturing data and laboratory studies have confirmed that the hydraulic fractures generated in shale reservoirs are not bi-wing planar fractures in homogeneous media, but multi-dimensional, asymmetric, and non-planar complex hydraulic fractures (as shown in Fig. 9.1) (Liu et al. in Guti Lixue Xuebao/Acta Mech Solida Sin 37:34–49, 2016; Xiao in Research of hydraulic fracturing dynamic propagation in fractured reservoirs, 2014; Guo and Wang in J Eng Geol 26:118–128, 2016).
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Zhao, Yu, Yongfa Zhang, and Pengfei He. "Fracture Interaction Behaviors." In Hydraulic Fracturing and Rock Mechanics, 199–227. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-2540-7_8.

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AbstractProblems arising from hydraulic fracturing involve the nonlinear coupling of rock deformation and fluid flow, the nonlocal character of the fracture elastic response, the time dependence of fracture propagation and the interacting interference between the pre-existing and induced fractures.
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Speerin, Robyn, Andréa Marques, and Marsha van Oostwaard. "Secondary Fracture Prevention." In Perspectives in Nursing Management and Care for Older Adults, 75–94. Cham: Springer International Publishing, 2023. http://dx.doi.org/10.1007/978-3-031-33484-9_5.

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AbstractFragility fractures signal that osteoporosis or osteopenia may be present. These are fractures often sustained through minimal trauma and commonly happen because of a fall from standing height or less. Low bone density due to osteoporosis or osteopenia means that such falls easily result in fractures. Fragility fractures are common, and the incidence is increasing despite global efforts to improve access to secondary prevention. Fragility fractures can lead to hospitalisation, increased risk of death due to complications, worsening chronic health conditions, and frailty. Hip and vertebral fractures are associated with the worst morbidity, mortality, and loss of functional ability. Pain and disability contribute to impaired quality of life.All people aged 50 years and over who sustain fragility fractures should, therefore, undergo investigation for osteoporosis and, if confirmed, be commenced on osteoporosis medication and be supported to participate in behaviours that are known to improve bone health. Organised and coordinated secondary fragility fracture prevention is the best option to prevent further fractures. This approach requires a multidisciplinary team working across care sectors in collaboration with the patient and family to ensure that care is consistent and person-centred and addresses individual need.Many communities across the globe who sustain fragility fractures, however, do not have access to diagnosis and evidence-informed treatment to prevent the next fracture despite strong evidence that access to treatment and supportive follow-up prevent many subsequent fractures. This chapter aims to explore how secondary fractures can be prevented through evidence-based interventions and services.
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Peng, Liu. "Study on Failure Process of Freeze–Thaw Fractured Rock Under Multistage Cyclic Loads." In Lecture Notes in Civil Engineering, 137–45. Singapore: Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-2532-2_12.

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AbstractIn order to further study the failure characteristics of freeze-thawed rocks in the alpine region under multistage cyclic loads, a numerical simulation analysis was carried out with RFPA2D software, taking the natural fractured granite from the Beizhan Iron Mine in Hejing County, Xinjiang Province as an example. The results show that the degree of natural fracture determines the fracture form of rock, and when the degree of natural fracture is large, the rock will eventually undergo shear slip failure along the natural fracture. When natural fissure rock is subjected to load, its initial structural deterioration occurs at the fissure, and tensile failure occurs. When the natural fracture expands to a certain extent, the rock begins to undergo large-scale compressive shear failure, which eventually leads to shear-slip failure of the fractured rock. The failure mode of fractured rock is affected by the degree of fracture development, the degree of penetration and the inclination Angle.
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Schwartz, Brandon S., Raymond Pensy, W. Andrew Eglseder, and Joshua M. Abzug. "Clavicle Fractures Clavicle fracture." In The Pediatric Upper Extremity, 1259–76. New York, NY: Springer New York, 2015. http://dx.doi.org/10.1007/978-1-4614-8515-5_57.

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Mears, Dana C., and Harry E. Rubash. "Fractures and Fracture Dislocations." In Surgery of the Hip Joint, 85–132. New York, NY: Springer New York, 1987. http://dx.doi.org/10.1007/978-1-4613-8628-5_5.

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Santy-Tomlinson, Julie, Karen Hertz, Anita J. Meehan, Ami Hommel, Andréa Marques, Lingli Peng, and Robyn Speerin. "Orthogeriatric and Fragility Fracture Nursing: An Introduction." In Perspectives in Nursing Management and Care for Older Adults, 1–16. Cham: Springer International Publishing, 2023. http://dx.doi.org/10.1007/978-3-031-33484-9_1.

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AbstractCaring for people following a fragility fracture is often a complex, medium- to long-term undertaking with several phases from acute care through to rehabilitation and secondary fracture prevention. Fragility fractures can have a substantial impact on older peoples’ longer term function, place of residence and quality of life, sometimes leading to long-term residential or end-of-life care.Health professionals caring for patients following fragility fracture are required to provide evidence-based care and coordinate interdisciplinary care. Not all ‘care’ is provided by those professionals who are identified as nurses, and in the future the boundaries of care-giving roles are likely to be more flexible. For these reasons, this book, although focused on nursing (because a significant amount of fragility facture/orthogeriatric care is provided by them), aims to broaden its relevance to all healthcare professionals who provide care in any part of the world.Avoiding the devastating impacts of fragility fractures drives the need to prevent fractures through secondary fracture prevention. This prevention care is lifelong and usually delivered and monitored by a primary care team including general practitioners, nurses, physiotherapists and other specialist practitioners. The pathway of care is, therefore, dynamic and involves the collaboration of many individuals and agencies.Fragility fractures are important indicators that there may be undiagnosed osteoporosis that requires treatment to prevent further fractures. If left untreated, osteoporosis and associated bone fragility can, ultimately, lead to significant injuries such as hip or femoral fractures, which will require hospital admission and surgery, and severely threaten an individual’s health and well-being. This presents significant challenges for clinical teams in every care setting.The aim of this chapter is to introduce the reader to orthogeriatric and fragility fracture care and to both familiarise them with the multiple topics covered in this book and support the interdisciplinary care team in achieving optimal recovery of independent function and quality of life, with no further fractures for all people with fragility fractures.
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Merembayev, Timur, and Yerlan Amanbek. "Natural Fracture Network Model Using Machine Learning Approach." In Computational Science and Its Applications – ICCSA 2023 Workshops, 384–97. Cham: Springer Nature Switzerland, 2023. http://dx.doi.org/10.1007/978-3-031-37114-1_26.

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AbstractA fracture network model is a powerful tool for characterizing fractured rock systems. In this paper, we present the fracture network model by integrating a machine learning algorithm in two-dimensional setting to predict the natural fracture topology in porous media. We also use a machine learning algorithm to predict the fracture azimuth angle for the natural fault data from Kazakhstan. The results indicate that the fracture network model with LightGBM performs better in designing a fracture network parameter for hidden areas based on data from the known area. In addition, the numerical result of the machine learning algorithm shows a good result for randomly selected data of the fracture azimuth.
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Panneerselvam, Elavenil, Poornima Ravi, and B. Sasikala. "Fractures of the Zygomaticomaxillary Complex." In Oral and Maxillofacial Surgery for the Clinician, 1151–99. Singapore: Springer Singapore, 2021. http://dx.doi.org/10.1007/978-981-15-1346-6_56.

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AbstractFractures of the Zygomatico Maxillary complex result in cosmetic deformity as well as functional deficits such as altered vision, restricted mouth opening and paresthesia. Accurate restitution of the form and function of the ZMC is challenging because of its multipoint- articulation within the cranio facial skeleton and the difficulty involved in intra-operative assessment of reduction at all articulations. Management of ZMC fractures is unique; (1) The approaches used for reduction may be different from those for fixation (2) Lack of complete visualization of fracture predisposes to over or under reduction resulting in sub optimal outcomes (3) Philosophies of fixation and stabilization are numerous and debatable.With advancements in the imaging technology, armamentarium and refinement of approaches to fracture, there is an emerging trend towards achieving utmost precision in reduction and fixation with minimally invasive surgical principles. This chapter aims at elaborating the biodynamics of ZMC fractures, the evolution of various techniques for reduction & fixation along with their rationale and finally the cutting-edge technology in management of fractured ZMC.
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Kristensen, Morten Tange, David J. Keene, and Carmen Queirós. "Early Mobilisation and Exercise After Fragility Fracture." In Perspectives in Nursing Management and Care for Older Adults, 129–46. Cham: Springer International Publishing, 2023. http://dx.doi.org/10.1007/978-3-031-33484-9_8.

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AbstractThe aim of this chapter is to promote the role of the nurse and other practitioners in patients’ early mobilisation and exercise after fragility fractures. The importance of early mobilisation and exercise is highlighted, along with practical information on assessment, pain and weight bearing and tips on how to facilitate early mobilisation. There is a focus on early mobilisation after hip fracture as this is the most common significant fragility fracture requiring hospitalisation and surgery. However, many of the issues covered are in common with other types of fragility fracture.
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Conference papers on the topic "Fracture"

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Zhou, Jian, and Chengjin Xue. "Experimental Investigation of Fracture Interaction between Natural Fractures and Hydraulic Fracture in Naturally Fractured Reservoirs." In SPE EUROPEC/EAGE Annual Conference and Exhibition. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/142890-ms.

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Wang, Rujun, Wei Zhou, Shiti Cui, Yiming Wu, Hanbing Xu, Hui Ma, Liming Lian, et al. "Fully Coupled 3D Geomechanical and Natural Fracture Modeling for Fracture Propagation Simulation in Unconventional Resources." In International Petroleum Technology Conference. IPTC, 2022. http://dx.doi.org/10.2523/iptc-22345-ms.

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Abstract Hydraulic fracturing is one of the major production enhancement measures for low permeability fractured reservoirs, where a large amount of oil and gas is stored worldwide. In recent years, during the development and research of these reservoirs, it has been found that the hydraulic fractures formed are no longer the single planar fractures produced by fracturing in homogeneous reservoirs, but complex, non-planar, multiple hydraulic fractures are formed, and the post-fracturing production often shows a positive correlation with the fracture complexity. A large amount of hydraulic fracturing diagnostic data indicates that the interaction between pre-existing natural fractures and induced hydraulic fractures is the key condition leading to the formation of complex hydraulic fractures. Simulation of hydraulic fracture extension in fractured reservoirs requires simulation of fluid pressure changes after the intersection of hydraulic fractures and natural fractures, as well as hydraulic fracture steering and other complex conditions. The traditional hydraulic fracture extension simulation models and theories are no longer suitable for such inhomogeneous reservoir conditions, but the relevant theoretical research is still immature and the interaction between hydraulic fractures and natural fractures during hydraulic fracture extension in fractured reservoirs is still not well understood. It is necessary to further develop theoretical research on hydraulic fracture expansion in fractured reservoirs to understand the mechanism and influencing factors of complex fracture formation, in order to promote the development of field development and theoretical research system of similar reservoirs. In this paper, we simulate and analyze the factors influencing hydraulic fracture expansion in fractured reservoirs. Through a series of numerical simulations, we found that horizontal bedding may open up during hydraulic fracturing to form horizontal fractures, and horizontal and vertical fractures intersect each other to form a complex volumetric fracture network; The distribution length of volumetric fractures increases and the distribution width decreases when the horizontal principal stress difference increases, and the aspect ratio of volumetric fractures increases; the distribution length of volumetric fractures decreases and the width increases when the fracturing construction displacement increases, and the aspect ratio of fractures increases. The residual tensile strength of natural fractures increases, the distribution width of volumetric fractures decreases, the distribution length increases, and the aspect ratio of volumetric fractures increases. The research results can provide some reference and reference for the fracture design and construction of fractured reservoirs.
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Li, Jie, Hanbing Xu, Qiyong Xiong, Yonggang Yi, Wei Zhou, Liwei Zhang, Shengen Chen, et al. "Study on the Influence of Natural Fracture Modeling on Hydraulic Fracture Propagation for Horizontal Wells in Unconventional Resource - A Case Study from China." In ADIPEC. SPE, 2022. http://dx.doi.org/10.2118/211690-ms.

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Abstract Low-permeability oil reservoirs generally have the low production, production rapid productivity decline, and low-ultimate recovery. Staged fracturing is usually conducted for horizontal wells. Hydraulic fracturing technology is generally used to improve fracture conductivity and well productivity, which is one of the key technologies for Enhance Oil Recovery (EOR). How to accurately characterize and simulate the distribution characteristics of hydraulic fracture network in 3D space is particularly important. The stress interference between hydraulic fractures as the objective mechanical behavior in the process of staged fracturing affects the geometry fracture network and the productivity of the reservoir post-fracturing. The hydraulic fractures simulation in natural fractured reservoirs is complex shapes, mainly because natural fractures affect the propagation path of hydraulic fractures. The theoretical model used to describe the hydraulic fracturing in homogeneous reservoirs cannot accurately show the complexity of the spatial morphology of hydraulic fractures in naturally fractured formations. CNCP (the operator) urgently need a mechanical model that can show the stress interference behavior between multiple fractures and the direction of hydraulic fracture propagation, and be used to simulate the spatial form of multiple hydraulic fractures in staged fracturing of horizontal wells and their propagation behavior in naturally fractured formations. Aiming at the impact of natural fractures in the reservoir on the propagation path of hydraulic fractures, this paper established a mechanical model for distinguishing interference behavior of natural fractures and hydraulic fractures. And analyzed the stress field at the tip of the hydraulic fracture and the stress field acting on the natural fracture surface based on the theories related to rock mechanics and fracture mechanics. On the basis of coupling the 3D geomechanical model and the 3D Discrete Fracture Network (DFN) model, this paper established the discriminant model for hydraulic fractures penetrating natural fractures in 3D space to conduct hydraulic fracture propagation simulation for the horizontal well. The research results can be used to optimize the hydraulic fracturing treatment design, and provide technical support for the effective production and profitable development of low-permeability reservoir resources.
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Peng, Sirui, Jinzhou Zhao, Lan Ren, Ran Lin, Bo Zhou, Jianfa Wu, Yi Song, and Cheng Shen. "Research on the Influence of Natural Fracture Development on the Deep Shale Gas Well Fracture Network Construction in Southern Sichuan." In SPE Annual Technical Conference and Exhibition. SPE, 2024. http://dx.doi.org/10.2118/220736-ms.

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Abstract The Sichuan Basin, China's largest shale gas development region, encompasses the natural fracture-rich Luzhou Block. The high-density non-uniform natural fractures in this area significantly influence the construction quality and efficiency of deep shale gas horizontal wells. Research indicates that the mechanical properties and spatial distribution of these natural fractures affect the propagation and diversion of hydraulic fractures, but the governing laws remain to be fully elucidated. This study categorizes the Luzhou Block's naturally fractured areas into six types based on their development characteristics and relative positions to horizontal well sections. Furthermore, it introduces a method for morphological inversion of shale gas well fracture networks using microseismic monitoring data. This method was applied to 24 deep shale gas wells in the Block and combined with the six types of naturally fractured areas, the above underlying influence mechanism was derived. Then it reveals how naturally fractured areas with different characteristics influence the fracture network morphology and complexity and analyzes the relationship between fracture network quality and well production. The results demonstrate that during the hydraulic fracturing process in deep shale gas reservoirs, the development areas of natural fractures can capture or intercept the fracture network, obstructing its expansion behavior, reducing its area and complexity, and ultimately leading to a decrease in gas well production. In particular, when a small-angle, large-scale naturally fractured area develops near the wellbore, the hydraulic fractures will quickly propagate to this area. After activating and communicating the natural fractures, it may cause rapid fluid filtration and a sharp drop in the net pressure within the fractures, severely impacting stimulation performance. It suggests that adjusting construction parameters appropriately may mitigate the adverse impact of natural fractures on the fracturing effect. These findings clarify how naturally fractured areas with different development characteristics affect stimulation performance and offer insights and references for designing and optimizing deep shale gas well fracturing technology.
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Tiab, Djebbar, Dora Patrici Restrepo, and Alpheus Olorunwa Igbokoyi. "Fracture Porosity of Naturally Fractured Reservoirs." In International Oil Conference and Exhibition in Mexico. Society of Petroleum Engineers, 2006. http://dx.doi.org/10.2118/104056-ms.

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Cottrell, Mark, Hooman Hosseinpour, and William Dershowitz. "Rapid Discrete Fracture Analysis of Hydraulic Fracture Development in Naturally Fractured Reservoirs." In Unconventional Resources Technology Conference. Society of Exploration Geophysicists, American Association of Petroleum Geologists, Society of Petroleum Engineers, 2013. http://dx.doi.org/10.1190/urtec2013-245.

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Maier, Christine, Gonçalo Oliveira, and Denis José Schiozer. "Flow-Based Upscaling of Fractured Porous Media Using a Discrete Fracture and Matrix Model and a Fracture Merging Algorithm." In SPE EuropEC - Europe Energy Conference featured at the 84th EAGE Annual Conference & Exhibition. SPE, 2023. http://dx.doi.org/10.2118/214420-ms.

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Abstract Many geo-energy related applications involve predicting the behavior of fluid flow in fractured subsurface reservoirs. Naturally fractured carbonate reservoirs are particularly important for being a major source of the world's hydrocarbon production. These reservoirs are also currently being considered as potential CO2 storage sites that will support net zero emissions goal. Simulation of flow in fractured reservoirs is a challenging task that typically involves upscaling the effective permeability of the fracture network and matrix into continuum models that consider the reservoir scale. The most accurate way to obtain such upscaled permeability for fracture networks is to perform single-phase flow simulations in statistical realizations of the fracture network using three-dimensional unstructured grids and explicit modelling of fractures. This step can be computationally challenging for highly dense fracture networks due to the difficulty in meshing the fractures and the rock matrix. Here, we present a method to reduce the complexity of the fracture network while still preserving the behavior of its effective permeability. Our approach involves a fracture merging algorithm that reduces the number of fractures allowing for faster meshing and upscaling. The fracture merging algorithm uses three different similarity metrics: fracture orientation, fracture area and distance between fractures. These metrics are used to identify similar fractures that can be merged into one single fracture with increased permeability. The upscaling algorithm to obtain the effective permeability of a grid cell containing a fracture network relies on flow simulations in three-dimensional unstructured meshes. We applied our method to different sub-networks extracted from a stochastically generated fracture network of a Brazilian Pre-Salt carbonate reservoir. We found that the average permeability of all fractures of the resulting fracture network increases with merging intensity, i.e., with decreasing the number of fractures, while the resulting upscaled effective permeability for the network remains in the same order of magnitude. This shows that the flow-based upscaling workflow including the merging algorithm leads to a significant reduction of complexity of fracture networks and consequently their 3D unstructured meshes while maintaining the structural and topological features that account for the fracture network effective permeability. Our proposed method is simple to implement and relies only on geometrical properties of the fractures. Other machine-learning based models have been proposed to achieve similar simplification of fracture networks, however, they are not easily incorporated into existing reservoir simulation tools and codes like the method presented in this work. Moreover, such previously published approaches do not consider flow in matrix and thus haven't been tested in scenarios where the matrix also contributes to flow.
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Jo, Hyunil. "Optimizing Fracture Spacing to Induce Complex Fractures in a Hydraulically Fractured Horizontal Wellbore." In SPE Americas Unconventional Resources Conference. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/154930-ms.

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Laubach, S. E., and E. R. Monson. "Coring-Induced Fractures: Indicators of Hydraulic Fracture Propagation in a Naturally Fractured Reservoir." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1988. http://dx.doi.org/10.2118/18164-ms.

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Chen, Jungang, Kan Wu, and John Killough. "Coupled Flow and Geomechanics in Reservoirs with Complex Fractures Using Embedded Meshes." In SPE Annual Technical Conference and Exhibition. SPE, 2022. http://dx.doi.org/10.2118/210388-ms.

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Abstract Conventional modeling of coupled flow and geomechanics in fractured reservoirs requires computation meshes conforming to the fracture geometry, which not only needs complicated gridding techniques but consumes a huge amount of computing resources. The objective of this paper is to present a numerical model that is able to efficiently model coupled porous flow and poroelastic effect in fractured reservoirs with complex fracture distributions. In this paper, embedded discrete fracture modeling (EDFM) is used to model fluid flow in fractured porous media and an extended finite element method (XFEM) is utilized to model displacement discontinuities arising from fractures. To model fracture aperture changes during depletion, a proppant model with linear elasticity is assumed. Moreover, to cope with complex fractures, we consider two basic types of fracture junctions, one is the ‘X’ type junction where two fractures intersect each other, the other is the ‘T’ type fracture where one fracture is captured at the fracture tip by the other without crossing it. Special treatment is performed to preprocess two types of fracture junctions and any combination of these two. The model is validated by analytical solutions as well as cases from other publications. We also present horizontal well production cases where hydraulic fractures intersecting with natural fractures.
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Reports on the topic "Fracture"

1

Plohr, JeeYeon. Fracture. Office of Scientific and Technical Information (OSTI), October 2023. http://dx.doi.org/10.2172/2202596.

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Scott. L51626 Fracture Current Fracture Prediction Models for Girth Welds. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), October 1990. http://dx.doi.org/10.55274/r0010574.

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Interpretive study of published and recent research on Engineering Critical Assessment techniques that relate to pipeline girth welds and compares the relative conservatism/nonconservatism of the API 1104 ECA technique with those proposed by other organizations and countries. Objective: provide greater confidence in these approaches/gain greater acceptance by regulatory bodies.
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Ritchie, R. O., W. W. Gerberich, and J. H. Underwood. Fracture and Fatigue. Fort Belvoir, VA: Defense Technical Information Center, April 1988. http://dx.doi.org/10.21236/ada197310.

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Maurer, William, and Gregory Deskins. GRl-91-0204 Gas Reservoir Wellbore Orientation - Sensitivity Analysis of Parameters Affecting Production. Chantilly, Virginia: Pipeline Research Council International, Inc. (PRCI), June 1991. http://dx.doi.org/10.55274/r0011162.

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A parametric study was performed to investigate the effects of numerous well and reservoir parameters on gas well productivity. GMODl, an analytical model for gas production in homogeneous reservoirs, was used to calculate production data for more than 250 sets of reservoir/wellbore parameters. Vertical, horizontal, slant and fractured wells were investigated. Several conclusions were reached as a result of parametric sensitivity analyses. In the right applications, horizontal gas wells produce 3 to 6 times more than vertical wells. At angles above about 60�, slant wells have significantly increased production rates over vertical wells due to increased wellbore exposure. Additionally, horizontal wells intersecting multiple natural fractures can produce significantly more gas than vertical wells intersecting a single fracture.
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Popelar, C. H., J. D. Walker, C. E. Anderson, Johnson Jr., Beissel G. R., and S. R. Penetrator Case Fracture Predictive Technoiogy: Volume 1-Dynamic Fracture Mechanics Methodology. Fort Belvoir, VA: Defense Technical Information Center, June 1999. http://dx.doi.org/10.21236/ada367712.

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Swartz, Stuart E. Applicability of Fracture Mechanics Methodology to Cracking and Fracture of Concrete. Fort Belvoir, VA: Defense Technical Information Center, February 1986. http://dx.doi.org/10.21236/ada165639.

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Carpenter, S. H. Investigation of fracture toughness and fracture mechanisms using acoustic emission measurements. Office of Scientific and Technical Information (OSTI), January 1991. http://dx.doi.org/10.2172/5404862.

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Carpenter, S. Investigation of fracture toughness and fracture mechanisms using acoustic emission measurements. Office of Scientific and Technical Information (OSTI), October 1988. http://dx.doi.org/10.2172/5525908.

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Borowski, Elisa Claire, and Pania Newell. Fracture testing in geomaterials. Office of Scientific and Technical Information (OSTI), August 2015. http://dx.doi.org/10.2172/1494348.

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Robertson, Brett Anthony. Phase Field Fracture Mechanics. Office of Scientific and Technical Information (OSTI), November 2015. http://dx.doi.org/10.2172/1227184.

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