Numerical Simulation Research on Hydraulic Fracturing Promoting Coalbed Methane Extraction

Fan, Yu; Shu, Longyong; Huo, Zhonggang; Hao, Jing; Li, Yang

doi:10.1155/2021/3269592

Cited by 9 publications

(5 citation statements)

References 31 publications

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“…On the contrary, the gas phase permeability rose continuously. As a result, a large amount of methane diffused and transported to the shaft to form production capacity, thus reaching peak gas production. , After 280 days of extraction, the overall gas production followed a steady upward trend. By 400–450 days of extraction, the gas production increased significantly, basically above 500 m 3 /d, reaching a maximum of 850 m 3 /d.…”

Section: Resultsmentioning

confidence: 99%

Coalbed Methane Enhancement in Low-Permeability Reservoirs by Hydraulic Fracturing with Coated Ceramsite

Guo

Song

et al. 2023

Energy Fuels

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The overall fracturing stimulation effect using quartz sand as a proppant is poor, resulting in no breakthrough in the production of coalbed methane (CBM) wells in the low permeability coal reservoir of Lu’an Mining Area. In this study, the mixed coated ceramsite of three particle sizes (40–60, 16–40, and 12–20 mesh) was selected as a proppant to conduct a hydraulic fracturing field experiment on CBM wells, located near the three wells fractured with quartz sand in the study area. The drainage and production effects of mixed particle size-coated ceramsite and quartz sand fractured wells in the area were compared. The results show that the cumulative gas production from the coated ceramsite fractured CBM well was approximately 93,004 m3 in 238 days of gas production, with a maximum daily gas production of 825 m3/d, approximately 3.3 times that of the quartz sand fractured wells. After 400 days of gas production, the two types of proppant-fractured CBM wells differed notably, the daily gas production of the coated ceramsite-fractured well being 450–825 m3/d and that of the quartz sand-fractured wells being only 150–250 m3/d. In the stable production stage, the coated ceramsite-fractured well displayed a better gas production potential. Therefore, in view of the low permeability of the coal reservoir, the use of coated ceramsite to fracture CBM wells can achieve a more satisfactory production enhancement effect. The research findings can provide a reference for fracturing-induced production enhancement of low-permeability reservoirs.

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Section: Resultsmentioning

confidence: 99%

Coalbed Methane Enhancement in Low-Permeability Reservoirs by Hydraulic Fracturing with Coated Ceramsite

Guo

Song

et al. 2023

Energy Fuels

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“…It offers a higher range of ability to simulate physical phenomenon and their interaction, heat transfer, fluid dynamics, electromagnetic, and more. Yongpeng et al 133 used COMSOL multiphysics to study the influence of coal bed methane permeability, initial gas pressure, and fracture length on methane production from a fractured well. This software can be coupled with particle flow code to study the hydraulic fracturing mechanism and the flowing ability of the coal reservoirs.…”

Section: Finite Element Methodsmentioning

confidence: 99%

A comprehensive review of numerical simulation methods for hydraulic fracturing

Ismail,

Azadbakht

2024

Num Anal Meth Geomechanics

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Hydraulic fracturing unlocks previously inaccessible hydrocarbons in unconventional reservoirs by creating artificial pathways in the unconventional reservoir. Numerical simulation expands the scope of hydraulic fracturing design for various reservoir conditions. This review paper explores the synergy between numerical simulation and hydraulic fracturing modeling, focusing on critical elements like geomechanical behavior, geological conditions, and fluid dynamics. Analytical models in hydraulic fracturing design are discussed to underscore their foundational importance. The assumption of constant fracture height limits the application of Perkins–Kern–Nordgren model (PKN) and Kristianovich‐Geertsma‐de Klerk model (KGD). Radial models assume 3D flow but lack reliability in nonradial settings, and the Pseudo 3D model (P3D) shares PKN's assumptions with variable fracture height, sacrificing some details for efficiency. Planar 3D model (PL3D) enhances accuracy by discarding PKN's elastic response assumption but requires extended computation. Unconventional fracture model is effective for complex scenarios but relies on DFN modeling parameters for accuracy. The choice of numerical simulation method in hydraulic fracturing depends on the specific aspect studied, each with its strengths and limitations. For instance, boundary element methods are efficient for exterior problems, finite element modeling suits 3D nonplanar fractures, and the extended finite element method excels in hydraulic and natural fracture interactions. Peridynamics shows potential but needs further development for cost‐effectiveness. PFC and UDEC/3DEC‐based simulations can explore microscopic mechanisms. Combining these methods with other approaches provides a comprehensive study of realistic reservoir conditions. This review guides the selection of a suitable numerical simulation methodology based on the study's scope.

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“…Fluid Migration within Fractures. The modified Darcy's law is adopted to govern the fluid flow of gas and water in fractures [31]:…”

Section: Seepage Field Controlling Equationmentioning

confidence: 99%

Numerical Optimization of Drilling Parameters for Gas Predrainage and Excavating-Drainage Collaboration on Roadway Head

et al. 2022

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In order to improve efficiency of gas drainage, the reasonable layout parameters for borehole on roadway head are investigated. Assuming that the coal mass has a dual pore structure with fractures and pores, a multiphysical field coupling mathematical model is proposed for gas drainage. The governing equations of gas adsorption, seepage, and diffusion are considered. The process of gas preextraction and excavating-extraction collaboration on roadway heading face in 2606 haulage roadway of Zhangcun mine is modeled by finite element (FE) method. The effects of gas drainage under different drilling arrangements are analyzed. The results show that the fastest decreasing rate of gas content occurs at the beginning of drainage, and decreasing rate of gas content tends to be stable in the later stage. After removing the predraining on roadway head, the gas content at the center of coal wall on the roadway heading face will rebound. The included angle between the borehole and the roadway middle line determines the spatial area of gas drainage. Too small included angle will reduce the area of gas content reduction, while too large included angle will result in a blind area on both sides of the roadway. The change in borehole spacing affects the decreasing rate of gas content in the rock and coal around the roadway. Large spacing may cause an inadequate decreasing rate in the middle of the roadway, while small spacing may cause an inadequate decreasing rate in both sides of the roadway. In the field application, the pure gas flow and gas concentration of drainage show a downward trend in whole. The gas concentration decreased from 13.2% to 10.8%, and the pure gas flow decreased from 10.6 m3/min to 8.15 m3/min. Research achievements can provide a basis for gas drainage in underground roadway.

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Numerical Simulation Research on Hydraulic Fracturing Promoting Coalbed Methane Extraction

Cited by 9 publications

References 31 publications

Coalbed Methane Enhancement in Low-Permeability Reservoirs by Hydraulic Fracturing with Coated Ceramsite

Coalbed Methane Enhancement in Low-Permeability Reservoirs by Hydraulic Fracturing with Coated Ceramsite

A comprehensive review of numerical simulation methods for hydraulic fracturing

Numerical Optimization of Drilling Parameters for Gas Predrainage and Excavating-Drainage Collaboration on Roadway Head

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