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Artículos de revistas sobre el tema "Compositional hydraulic fracturing model"

Autor: Grafiati

Publicado: 4 de junio de 2021

Última modificación: 7 de febrero de 2022

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1

Friehauf, Kyle E., and Mukul M. Sharma. "A New Compositional Model for Hydraulic Fracturing With Energized Fluids." SPE Production & Operations 24, no. 04 (2009): 562–72. http://dx.doi.org/10.2118/115750-pa.

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2

Ribeiro, Lionel H., and Mukul M. Sharma. "A New 3D Compositional Model for Hydraulic Fracturing With Energized Fluids." SPE Production & Operations 28, no. 03 (2013): 259–67. http://dx.doi.org/10.2118/159812-pa.

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3

Bulgakova, Guzel T., Andrey R. Sharifullin, and Marat R. Sitdikov. "Mathematical modeling heat and mass transfer in a vertical hydraulic fracture crack during inflation and cleaning*." Tyumen State University Herald. Physical and Mathematical Modeling. Oil, Gas, Energy 6, no. 2 (2020): 41–62. http://dx.doi.org/10.21684/2411-7978-2020-6-2-41-62.

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When designing hydraulic fracturing for high-temperature formations, it is important to know the temperature change in the fracture during the injection of fracturing fluid. The temperature profile in the hydraulic fracture is necessary to calculate the optimal composition of the fracturing fluid, which necessarily includes a crosslinker (crosslinker) and a breaker (breaker), the concentration of which is calculated by the temperature at the end of the crack. Currently, this concentration is calculated based on the maximum temperature of the formation, which can lead to a decrease in the effic

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4

Shen, Feng, Zhou Wu, Nan Wang, and Yong Ming Li. "The Prediction of Wellhead Pressure of Hydraulic Fracturing." Applied Mechanics and Materials 405-408 (September 2013): 3323–27. http://dx.doi.org/10.4028/www.scientific.net/amm.405-408.3323.

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The accurate prediction of wellhead pressure in process of hydraulic fracturing is a keypoint to guide the design and construction of the fracturing, and does help in choosing appropriate wellhead equipment and pipeline. This paper calculates the formation breakdown pressure by using a self-made formation stress calculation software, analyzes perforation friction and near-wellbore friction on the basis of Michael theory, eatablishes a model of wellbore friction through Darcy-Weisbach equation and the momentum interaction theory of two-phase flow, and according to the composition of wellhead pr

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5

Eyre, Thomas S., David W. Eaton, Dmitry I. Garagash, et al. "The role of aseismic slip in hydraulic fracturing–induced seismicity." Science Advances 5, no. 8 (2019): eaav7172. http://dx.doi.org/10.1126/sciadv.aav7172.

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Models for hydraulic fracturing–induced earthquakes in shales typically ascribe fault activation to elevated pore pressure or increased shear stress; however, these mechanisms are incompatible with experiments and rate-state frictional models, which predict stable sliding (aseismic slip) on faults that penetrate rocks with high clay or total organic carbon. Recent studies further indicate that the earthquakes tend to nucleate over relatively short injection time scales and sufficiently far from the injection zone that triggering by either poroelastic stress changes or pore pressure diffusion i

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6

Carpenter, Chris. "Diagnostic Fracture Injection Test Analysis Method Addresses Layered Rocks." Journal of Petroleum Technology 73, no. 02 (2021): 54–55. http://dx.doi.org/10.2118/0221-0054-jpt.

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This article, written by JPT Technology Editor Chris Carpenter, contains highlights of paper SPE 199690, “Diagnostic Fracture Injection Test Analysis and Interpretation in Layered Rocks,” by Shuang Zheng, SPE, Ripudaman Manchanda, SPE, and HanYi Wang, The University of Texas at Austin, et al., prepared for the 2020 SPE Hydraulic Fracturing Technology Conference and Exhibition, The Woodlands, Texas, 4-6 February. The paper has not been peer reviewed. Formation-property estimations based on diagnostic fracture injection tests (DFITs) typically are based on analysis of pressure data assuming the

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7

Wang, Junjian, and Sheik S. Rahman. "Investigation of Water Leakoff Considering the Component Variation and Gas Entrapment in Shale During Hydraulic-Fracturing Stimulation." SPE Reservoir Evaluation & Engineering 19, no. 03 (2016): 511–19. http://dx.doi.org/10.2118/174392-pa.

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Summary The water leakoff into the shale matrix during the hydraulic-fracture treatment has been a critical issue in determining fracture geometry. Furthermore, water leakoff also affects mechanical properties of the surrounding rock matrix which, in turn, affects fracture propagation. Conventional approaches for the prediction of leakoff were inadequate because several important phenomena are ignored. In this paper, several effects on water leakoff into shale matrix during shale-gas reservoir stimulation are considered. A simplified structure is used to depict the complex pore network in shal

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8

Kishida, Kiyoshi, Shogo Izawa, Sho Ogata, and Hideaki Yasuhara. "Development of rock fracturing model considering mineral composition and distribution and its application to coupled Thermal-Hydraulic-Mechanical-Chemical (THMC) simulator." Japanese Geotechnical Society Special Publication 8, no. 3 (2020): 76–81. http://dx.doi.org/10.3208/jgssp.v08.j45.

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9

Cahalan, Mark, David Moskal, Cimon Song, and Jianhan Wu. "Optimization of reverse osmosis flowback water treatment using halotolerant microbes naturally enriched in fractured shales." University of Ottawa Science Undergraduate Research Journal 1 (August 23, 2018): 60. http://dx.doi.org/10.18192/osurj.v1i1.3720.

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Flowback water recovered after hydraulic fracturing operations poses a serious environmental concern due to the sheer quantity produced and its toxic chemical composition. Traditional methods of wastewater treatment cannot be used for flowback water treatment due to its high concentration of non-biodegradable dissolved solids. Consequently, alternative technology has been developed to address this problem. Reverse osmosis (RO) treatment is one such example. However, guar gum gelling agents found in flowback water impede membrane permeability and water flux rate of RO, consequently decreasing t

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10

Fung, Larry S., and Shouhong Du. "Parallel-Simulator Framework for Multipermeability Modeling With Discrete Fractures for Unconventional and Tight Gas Reservoirs." SPE Journal 21, no. 04 (2016): 1370–85. http://dx.doi.org/10.2118/179728-pa.

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Summary Economic gas rate from ultralow-permeability shale reservoirs requires the creation of a complex fracture network in a large volume known as the stimulated reservoir volume (SRV). The fracture network connects a large surface area of the reservoir to the well. It is created by injecting low-viscosity fracturing fluid (slickwater) at very high rates in multiple stages along the horizontal wellbore. Numerical simulation is used to evaluate the stimulation designs and completion strategy. Microseismic (MS) -survey fracture mapping can provide a measurement of the overall SRV and an estima

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11

Tzschichholz, F., H. J. Herrmann, H. E. Roman, and M. Pfuff. "Beam model for hydraulic fracturing." Physical Review B 49, no. 10 (1994): 7056–59. http://dx.doi.org/10.1103/physrevb.49.7056.

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12

Seales, Maxian B., Robert Dilmore, Turgay Ertekin, and John Yilin Wang. "Numerical Analysis of the Source of Excessive Na+ and Cl- Species in Flowback Water From Hydraulically Fractured Shale Formations." SPE Journal 21, no. 05 (2016): 1477–90. http://dx.doi.org/10.2118/180911-pa.

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Summary Fracture fluid is composed of fresh water, proppant, and a small percentage of other additives, which support the hydraulic-fracturing process. Excluding situations in which flowback water is recycled and reused, the total dissolved solids in fracture fluid is limited to the fluid additives, such as potassium chloride (1 to 7 wt% KCL), which is used as a clay stabilizer to minimize clay swelling and clay-particle migration. However, the composition of recovered fluid, especially as it relates to the total dissolved solids (TDS), is always substantially different from the injected fract

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13

Li, Jinbu, Shuangfang Lu, Min Wang, Guohui Chen, Weichao Tian, and Chenxue Jiao. "A novel approach to the quantitative evaluation of the mineral composition, porosity, and kerogen content of shale using conventional logs: A case study of the Damintun Sag in the Bohai Bay Basin, China." Interpretation 7, no. 1 (2019): T83—T95. http://dx.doi.org/10.1190/int-2018-0088.1.

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The quantitative prediction of the mineral composition, porosity, and kerogen content of shales is significant for the evaluation of shale oil and gas potential and the hydraulic fracturing process. We have developed a new method for the shale’s components prediction (SCP-[Formula: see text]) by combining the back-propagation (BP) neural network and an improved [Formula: see text] method based on conventional logs. First, we constructed and calibrated the shale fraction model according to the volume of the minerals, kerogen, and porosity determined through laboratory analyses. Subsequently, we

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14

Ledevin, M., N. Arndt, A. Davaille, R. Ledevin, and A. Simionovici. "The rheological behaviour of fracture-filling cherts: example of Barite Valley dikes, Barberton Greenstone Belt, South Africa." Solid Earth 6, no. 1 (2015): 253–69. http://dx.doi.org/10.5194/se-6-253-2015.

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Abstract. In the Barberton Greenstone Belt, South Africa, a 100–250 m thick complex of carbonaceous chert dikes marks the transition from the Mendon Formation to the Mapepe Formation (3260 Ma). The sub-vertical- to vertical position of the fractures, the abundance of highly shattered zones with poorly rotated angular fragments and common jigsaw fit, radial structures, and multiple injection features point to repetitive hydraulic fracturing that released overpressured fluids trapped within the shallow crust. The chemical and isotopic compositions of the chert favour a model whereby seawater-der

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15

Papanastasiou, P. C. "A coupled elastoplastic hydraulic fracturing model." International Journal of Rock Mechanics and Mining Sciences 34, no. 3-4 (1997): 240.e1–240.e15. http://dx.doi.org/10.1016/s1365-1609(97)00132-9.

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16

Luo, Chenyi, and Wolfgang Ehlers. "A three-dimensional model of hydraulic fracturing." PAMM 16, no. 1 (2016): 465–66. http://dx.doi.org/10.1002/pamm.201610221.

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17

Lu, Weiyong, and Bingxiang Huang. "Mathematical model of methane driven by hydraulic fracturing in gassy coal seams." Adsorption Science & Technology 38, no. 3-4 (2020): 127–47. http://dx.doi.org/10.1177/0263617420919247.

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During hydraulic fracturing in gassy coal, methane is driven by hydraulic fracturing. However, its mathematical model has not been established yet. Based on the theory of ‘dual-porosity and dual-permeability’ fluid seepage, a mathematical model is established, with the cleat structure, main hydraulic fracture and methane driven by hydraulic fracturing considered simultaneously. With the help of the COMSOL Multiphysics software, the numerical solution of the mathematical model is obtained. In addition, the space–time rules of water and methane saturation, pore pressure and its gradient are obta

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18

Advani, S. H., T. S. Lee, and R. H. Dean. "Variational Principles for Hydraulic Fracturing." Journal of Applied Mechanics 59, no. 4 (1992): 819–26. http://dx.doi.org/10.1115/1.2894048.

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A new application of an energy rate variational principle for hydraulic fracturing processes is introduced. The formation structural, fracture mechanics, and fracture fluid flow responses are integrally coupled in this treatment. This unified principle, with various specialized forms, provides a formal framework for the study of continuum as well as discrete models. The applicability of the developed formulations is demonstrated by deriving time-explicit solutions for a penny-shaped model and comparing numerical results with corresponding responses from Lagrangian and finite element methods.

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19

Qu, Zhanqing, Jiwei Wang, Tiankui Guo, et al. "Optimization on fracturing fluid flowback model after hydraulic fracturing in oil well." Journal of Petroleum Science and Engineering 204 (September 2021): 108703. http://dx.doi.org/10.1016/j.petrol.2021.108703.

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20

Su, Yu Jie, and Rui Wu. "The Applications of BP Neural Network Based on MIV in Hydraulic Fracturing." Advanced Materials Research 971-973 (June 2014): 300–305. http://dx.doi.org/10.4028/www.scientific.net/amr.971-973.300.

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As a effective stimulation, hydraulic fracturing was commonly used in the mining process of complicated low permeability reservoirs, especially in horizontal shale gas wells more widely. In this paper, we establish the BP (Back Propagation) neural network based on MIV (Mean Impact Value) which is different from traditional BP neural network. We choose the independent variables of training set, plus or minus a certain percentages. Measured by the absolute size of MIV value and analyze the changes of MIV value, we identify the main factors in hydraulic fracturing. Combined qualitative analysis w

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21

Long, Gongbo, Songxia Liu, Guanshui Xu, Sau-Wai Wong, Hanxin Chen, and Boqi Xiao. "A Perforation-Erosion Model for Hydraulic-Fracturing Applications." SPE Production & Operations 33, no. 04 (2018): 770–83. http://dx.doi.org/10.2118/174959-pa.

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22

Huang, Xuemin, Jingyi Wang, Shengnan (Nancy) Chen, and Ian D. Gates. "A simple dilation-recompaction model for hydraulic fracturing." Journal of Unconventional Oil and Gas Resources 16 (December 2016): 62–75. http://dx.doi.org/10.1016/j.juogr.2016.09.006.

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23

Wang, Li, Hongzheng Xu, Yunxing Cao, and Shimin Liu. "A poromechanical model of hydraulic fracturing volumetric opening." Engineering Fracture Mechanics 235 (August 2020): 107172. http://dx.doi.org/10.1016/j.engfracmech.2020.107172.

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24

Md Yusof, Muhammad Aslam, and Nur Adilla Mahadzir. "Development of mathematical model for hydraulic fracturing design." Journal of Petroleum Exploration and Production Technology 5, no. 3 (2014): 269–76. http://dx.doi.org/10.1007/s13202-014-0124-z.

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25

Goncharova, G. S., and M. G. Khramchenkov. "Mathematical Model of Hydraulic Fracturing of a Bed." Journal of Engineering Physics and Thermophysics 89, no. 4 (2016): 848–53. http://dx.doi.org/10.1007/s10891-016-1445-1.

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26

Feng, Yan Jun, and Xiu Wei Shi. "Hydraulic Fracturing Process: Roles of In Situ Stress and Rock Strength." Advanced Materials Research 616-618 (December 2012): 435–40. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.435.

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This paper presents results of a comprehensive study involving analytical and field experimental investigations into the factors controlling the hydraulic fracturing process. Analytical theories for fracture initiation of vertical and horizontal borehole are reviewed. The initiation and propagation process of hydraulic fracturing is performed in the field by means of hydraulic fracturing and stepwise hydraulic fracturing, the effect of factors such as in-situ stress and rock strength on fracture propagation process is studied and discussed. The fracture initiation pressures estimated from the

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27

Yongpeng, Fan, Shu Longyong, Huo Zhonggang, Hao Jinwei, and Yang Li. "Numerical Simulation Research on Hydraulic Fracturing Promoting Coalbed Methane Extraction." Shock and Vibration 2021 (July 13, 2021): 1–12. http://dx.doi.org/10.1155/2021/3269592.

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Although hydraulic fracturing technology has been comprehensively investigated, few scholars have studied the influence of hydraulic fracturing on the effect of coalbed methane (CBM) extraction, and few considered the interaction between water and CBM in the research process, which is not conducive to guiding the engineering design of hydraulic fracturing wells. In this work, a hydraulic-mechanical-thermal coupled model for CBM extraction in hydraulic fracturing well is established; it combines gas-liquid two-phase infiltration, where nonisothermal adsorption is also considered. The COMSOL Mul

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28

Liangwei, LI. "Coupling numerical model of hydraulic fracturing seepage in soft coal based on elastoplastic damage." E3S Web of Conferences 198 (2020): 01038. http://dx.doi.org/10.1051/e3sconf/202019801038.

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In order to guide the field application of hydraulic fracturing of soft coal in coal mine, based on the elastic-plastic damage theory, the coupling numerical model of soft coal hydraulic fracturing seepage was studied. The porosity strain relationship equation, permeability strain relationship equation, the relationship between permeability and volume plastic tensile strain and volume plastic shear strain of coal and rock mass are derived, and the plastic correction equation and softening parameters are defined. The stress coupling equation and yield criterion are programmed and embedded into

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29

Cai, Bo, Yun Hong Ding, Yong Jun Lu, Chun Ming He, and Gui Fu Duan. "Leak-Off Coefficient Analysis in Stimulation Treatment Design." Advanced Materials Research 933 (May 2014): 202–5. http://dx.doi.org/10.4028/www.scientific.net/amr.933.202.

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Hydraulic fracturing was first used in the late 1940s and has become a common technique to enhance the production of low-permeability formations.Hydraulic fracturing treatments were pumped into permeable formations with permeable fluids. This means that as the fracturing fluid was being pumped into the formation, a certain proportion of this fluid will being lost into formation as fluid leak-off. Therefore, leak-off coefficient is the most leading parameters of fracturing fluids. The accurate understanding of leak-off coefficient of fracturing fluid is an important guidance to hydraulic fractu

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30

Yuan, Zhigang, and Yaohua Shao. "Numerical Modeling on Hydraulic Fracturing in Coal-Rock Mass for Enhancing Gas Drainage." Advances in Civil Engineering 2018 (December 12, 2018): 1–16. http://dx.doi.org/10.1155/2018/1485672.

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The mechanism of how hydraulic fracturing influences gas drainage in coal-rock mass is still not clear due to its complex mechanism. In this work, statistical distributions are firstly introduced to describe heterogeneity of coal-rock mass; a novel simultaneously coupled mathematical model, which can describe the fully coupled process including seepage-damage coupling during hydraulic fracturing process and subsequent gas flow during gas drainage process, is established; its numerical implementation procedure is coded into a Matlab program to calculate the damage variables, and it partly uses

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31

Ni, Lin, Xue Zhang, Liangchao Zou, and Jinsong Huang. "Phase-field modeling of hydraulic fracture network propagation in poroelastic rocks." Computational Geosciences 24, no. 5 (2020): 1767–82. http://dx.doi.org/10.1007/s10596-020-09955-4.

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Abstract Modeling of hydraulic fracturing processes is of great importance in computational geosciences. In this paper, a phase-field model is developed and applied for investigating the hydraulic fracturing propagation in saturated poroelastic rocks with pre-existing fractures. The phase-field model replaces discrete, discontinuous fractures by continuous diffused damage field, and thus is capable of simulating complex cracking phenomena such as crack branching and coalescence. Specifically, hydraulic fracturing propagation in a rock sample of a single pre-existing natural fracture or natural

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32

Yang, Z., D. Tamhane, A. K. Khurana, D. G. Crosby, and M. Jones. "RETROGRADE CONDENSATION OR WATER IMBIBITION ? A CASE STUDY OF GAS WELL PRODUCTIVITY DECLINE BEFORE AND AFTER HYDRAULIC FRACTURING." APPEA Journal 36, no. 1 (1996): 562. http://dx.doi.org/10.1071/aj95034.

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Studies have been carried out to diagnose the cause of productivity decline for the Kaimiro-1 well in the Kaimiro gas field, Taranaki Basin, New Zealand. The gas flow rate for Kaimiro-1, declined from 5 MMSCFD (0.14 Mm3 per day) in 1983 to about 0.6 MMSCFD (0.017 Mm3 per day) in 1993, immediately prior to hydraulic fracturing. While hydraulic fracturing initially increased production rates, long term post-fracture results have been disappointing. The volumetric gas-in-place for the field was estimated to be at least 100 BCF (2.83 Gm3), whereas the total cumulative gas recovery to date is 5.1 B

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33

Smetannikov, O. Y., Y. A. Kashnikov, S. G. Ashihmin, and D. V. Shustov. "Numerical model of crack growth in hydraulic re-fracturing." Computational Continuum Mechanics 8, no. 2 (2015): 208–18. http://dx.doi.org/10.7242/1999-6691/2015.8.2.18.

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34

Yi, Tongchun, and J. M. Peden. "A Comprehensive Model of Fluid Loss in Hydraulic Fracturing." SPE Production & Facilities 9, no. 04 (1994): 267–72. http://dx.doi.org/10.2118/25493-pa.

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35

Smetannikov, Oleg, Yuriy Kashnikov, Sergey Ashikhmin, and Artem Kukhtinskiy. "Numerical model of fracture growth in hydraulic re-fracturing." Frattura ed Integrità Strutturale 13, no. 49 (2019): 140–55. http://dx.doi.org/10.3221/igf-esis.49.16.

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36

Devloo, Philippe R. B., Paulo Dore Fernandes, Sônia M. Gomes, Cedric Marcelo Augusto Ayala Bravo, and Renato Gomes Damas. "A finite element model for three dimensional hydraulic fracturing." Mathematics and Computers in Simulation 73, no. 1-4 (2006): 142–55. http://dx.doi.org/10.1016/j.matcom.2006.06.020.

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37

Stopa, Jerzy, Paweł Wojnarowski, and Damian Janiga. "Integrated model of hydraulic fracturing and hydro-carbon production." AGH Drilling, Oil, Gas 31, no. 1 (2014): 49. http://dx.doi.org/10.7494/drill.2014.31.1.49.

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38

Schätzer, Markus, and Thomas-Peter Fries. "Hydraulic fracturing with a simplified fluid model and XFEM." PAMM 16, no. 1 (2016): 167–68. http://dx.doi.org/10.1002/pamm.201610072.

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39

Antonov, I. D. "Pseudo-three-dimensional model for hydraulic fracturing with foams." Journal of Physics: Conference Series 1236 (June 2019): 012055. http://dx.doi.org/10.1088/1742-6596/1236/1/012055.

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40

Feng, Runhua, Yihuai Zhang, Ali Rezagholilou, Hamid Roshan, and Mohammad Sarmadivaleh. "Brittleness Index: From Conventional to Hydraulic Fracturing Energy Model." Rock Mechanics and Rock Engineering 53, no. 2 (2019): 739–53. http://dx.doi.org/10.1007/s00603-019-01942-1.

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41

Wangen, Magnus. "A 2D Model of Hydraulic Fracturing, Damage and Microseismicity." Pure and Applied Geophysics 175, no. 3 (2017): 813–28. http://dx.doi.org/10.1007/s00024-017-1718-4.

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42

Wangen, Magnus. "A 2D volume conservative numerical model of hydraulic fracturing." Computers & Structures 182 (April 2017): 448–58. http://dx.doi.org/10.1016/j.compstruc.2017.01.003.

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43

Lin, Kuan-Han, John P. Eason, Zhou (Joyce) Yu, and Lorenz T. Biegler. "Nonlinear Model Predictive Control of the Hydraulic Fracturing Process." IFAC-PapersOnLine 53, no. 2 (2020): 11428–33. http://dx.doi.org/10.1016/j.ifacol.2020.12.579.

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44

Ge, Zhang, Sun, and Hu. "Fully Coupled Multi-Scale Model for Gas Extraction from Coal Seam Stimulated by Directional Hydraulic Fracturing." Applied Sciences 9, no. 21 (2019): 4720. http://dx.doi.org/10.3390/app9214720.

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Although numerous studies have tried to explain the mechanism of directional hydraulic fracturing in a coal seam, few of them have been conducted on gas migration stimulated by directional hydraulic fracturing during coal mine methane extraction. In this study, a fully coupled multi-scale model to stimulate gas extraction from a coal seam stimulated by directional hydraulic fracturing was developed and calculated by a finite element approach. The model considers gas flow and heat transfer within the hydraulic fractures, the coal matrix, and cleat system, and it accounts for coal deformation. T

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45

Liu, Liyuan, Lianchong Li, Derek Elsworth, Sheng Zhi, and Yongjun Yu. "The Impact of Oriented Perforations on Fracture Propagation and Complexity in Hydraulic Fracturing." Processes 6, no. 11 (2018): 213. http://dx.doi.org/10.3390/pr6110213.

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To better understand the interaction between hydraulic fracture and oriented perforation, a fully coupled finite element method (FEM)-based hydraulic-geomechanical fracture model accommodating gas sorption and damage has been developed. Damage conforms to a maximum stress criterion in tension and to Mohr–Coulomb limits in shear with heterogeneity represented by a Weibull distribution. Fracturing fluid flow, rock deformation and damage, and fracture propagation are collectively represented to study the complexity of hydraulic fracture initiation with perforations present in the near-wellbore re

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46

Ji, Enyue, Zhongzhi Fu, Shengshui Chen, Jungao Zhu, and Zhizhou Geng. "Numerical Simulation of Hydraulic Fracturing in Earth and Rockfill Dam Using Extended Finite Element Method." Advances in Civil Engineering 2018 (2018): 1–8. http://dx.doi.org/10.1155/2018/1782686.

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Hydraulic fracturing is one of the most important factors affecting the safety of earth and rockfill dam. In this paper, the extended finite element method (XFEM) is used to simulate the hydraulic fracturing behavior in an actual high earth and rockfill dam. The possibility of hydraulic fracturing occurrence is analyzed, and the critical crack length is obtained when hydraulic fracturing occurs. Then, the crack propagation path and length is obtained by inserting initial crack of different lengths at different elevation. The results indicate that hydraulic fracturing will not occur without the

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47

Li, Jianxiong, Shiming Dong, Wen Hua, Xiaolong Li, and Xin Pan. "Numerical Investigation of Hydraulic Fracture Propagation Based on Cohesive Zone Model in Naturally Fractured Formations." Processes 7, no. 1 (2019): 28. http://dx.doi.org/10.3390/pr7010028.

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Complex propagation patterns of hydraulic fractures often play important roles in naturally fractured formations due to complex mechanisms. Therefore, understanding propagation patterns and the geometry of fractures is essential for hydraulic fracturing design. In this work, a seepage–stress–damage coupled model based on the finite pore pressure cohesive zone (PPCZ) method was developed to investigate hydraulic fracture propagation behavior in a naturally fractured reservoir. Compared with the traditional finite element method, the coupled model with global insertion cohesive elements realizes

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48

Deng, Qigen, Fajun Zhao, Hong Li, Jingping Yin, Tao Zhang, and Junjie Wei. "Technology and practice of the roof-caving of hydraulic fracturing in a fully mechanized caving face." Thermal Science 25, no. 3 Part B (2021): 2117–26. http://dx.doi.org/10.2298/tsci191104096d.

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A fracture expansion criterion of hydraulic fracturing was suggested to deal with the hard and stable roof control in coal mines. An experiment was designed for the roof control, and the reliability of model was verified. Four different types of fracturing holes and fracturing technology were designed in the setup room, and the hydraulic fracturing in the roof of a fully mechanized caving face was implemented.

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49

Zhao, Wan Chun, Ting Ting Wang, Guo Shuai Ju, and Da Chun Zheng. "The Study on Fractal Damage of Rock under Hydraulic Fracturing Basing on Conversation of Energy." Applied Mechanics and Materials 29-32 (August 2010): 1363–68. http://dx.doi.org/10.4028/www.scientific.net/amm.29-32.1363.

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The fractal characteristics is Considered in rock porosity structure, and rock damage variable is defined by reduced amount pore number whose radius is greater than R during arbitrary fracturing stage. Assuming that the micro-fracturing process of evolution cracks meets Logistic bifurcation standard model, according to energy conservation principle, the model of hydraulic fracturing of rock damage and infiltration of evolution is established based on the porosity fractal damage theory. And then the hydraulic fracturing rock evolution model is built. Taking one well of any oil field as the exam

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50

Yang, Tian Hong, Leslie George Tham, S. Y. Wang, Wan Cheng Zhu, Lian Chong Li, and Chun An Tang. "Micromechanical Model for Simulating Hydraulic Fractures of Rock." Advanced Materials Research 9 (September 2005): 127–36. http://dx.doi.org/10.4028/www.scientific.net/amr.9.127.

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A numerical model is developed to study hydraulic fracturing in permeable and heterogeneous rocks, coupling with the flow and failure process. The effects of flow and in-situ stress ratio on fracture, material homogeneity and breakdown pressure are specifically studied.

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