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Artykuły w czasopismach na temat „Shale-gas reservoir simulation”

Autor: Grafiati

Data publikacji: 4 czerwca 2021

Data aktualizacji: 1 lutego 2022

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1

Shar, Abdul Majeed, Waheed Ali Abro, Aftab Ahmed Mahesar, and Kun Sang Lee. "Simulation Study to Evaluate the Impact of Fracture Parameters on Shale Gas Productivity." April 2020 39, no. 2 (2020): 432–42. http://dx.doi.org/10.22581/muet1982.2002.19.

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The production from shale gas reservoirs has significantly increased due to technological advancements. The shale gas reservoirs are very heterogeneous and the heterogeneity has a significant effect on the quality and productivity of reservoirs. Hence, it is essential to study the behavior of such reservoirs for accurate modelling and performance prediction. To evaluate the impact of fracture parameters on shale gas reservoir productivity using CMG (Computer Modelling Group) stars simulation software was the main objective of this study. In this paper, a comprehensive analysis considering an e

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Mu, Song Ru, and Shi Cheng Zhang. "Numerical Simulation of Shale Gas Production." Advanced Materials Research 402 (November 2011): 804–7. http://dx.doi.org/10.4028/www.scientific.net/amr.402.804.

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Shale gas reservoirs require a large fracture network to maximize well performance. Microseismic fracture mapping has shown that large fracture networks can be generated in many shale reservoirs. The application of microseismic fracture mapping measurements requires estimation of the structure of the complex hydraulic fracture or the volume of the reservoir that has been stimulated by the fracture treatment. There are three primary approaches used to incorporate microseismic measurements into reservoir simulation models: discrete modeling of the complex fracture network, wire-mesh model, and d

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Hu, Zhiming, Xianggang Duan, Nan Shao, et al. "Experimental Study on the Characteristics of Adsorbed Gas and Gas Production in Shale Formations." Geofluids 2021 (September 4, 2021): 1–12. http://dx.doi.org/10.1155/2021/2448044.

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Adsorbed gas and free gas both exist in shale reservoirs simultaneously due to the unique nanoscale pore structure, resulting in the complex flow mechanism of gas in the reservoir during the development process. The dynamic performance analysis of shale reservoirs has mostly been conducted by the numerical simulation and theoretical model, while the physical simulation method for relevant research is seen rarely in the literature. Thus, in this paper, an experiment system was designed to simulate the degraded development experiments of shale, coal, and tight sandstone to reveal the output law

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4

Dong, Hao, Yi Zhang, Zongwu Li, et al. "Model Optimization of Shale Gas Reservoir Volume Fracturing Dissolved Gas Simulation Adsorbed Gas." Geofluids 2021 (February 18, 2021): 1–15. http://dx.doi.org/10.1155/2021/6631994.

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Shale reservoirs have some natural fractures with a certain density and connectivity. The basic percolation model of shale gas reservoir: the black oil model of gas-water phase is used as the basic model, and the dissolved gas is used to simulate adsorbed gas. Accurate description of natural fractures: random distributed discrete fracture model is used as the basic model to describe natural fractures. By comparing the calculation results of single medium (including random distributed discrete fracture model) and double medium model, the model for predicting shale gas productivity is optimized.

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Zhan, Jie, Zhihao Niu, Mengmeng Li, et al. "Numerical Simulation and Modeling on CO2 Sequestration Coupled with Enhanced Gas Recovery in Shale Gas Reservoirs." Geofluids 2021 (August 4, 2021): 1–15. http://dx.doi.org/10.1155/2021/9975296.

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CO2 geological sequestration in shale is a promising method to mitigate global warming caused by greenhouse gas emissions as well as to enhance the gas recovery to some degree, which effectively addresses the problems related to energy demand and climate change. With the data from the New Albany Shale in the Illinois Basin in the United States, the CMG-GEM simulator is applied to establish a numerical model to evaluate the feasibility of CO2 sequestration in shale gas reservoirs with potential enhanced gas recovery (EGR). To represent the matrix, natural fractures, and hydraulic fractures in s

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6

Shang, Xiaofei, Huawei Zhao, Shengxiang Long, and Taizhong Duan. "A Workflow for Integrated Geological Modeling for Shale Gas Reservoirs: A Case Study of the Fuling Shale Gas Reservoir in the Sichuan Basin, China." Geofluids 2021 (August 25, 2021): 1–22. http://dx.doi.org/10.1155/2021/6504831.

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Shale gas reservoir evaluation and production optimization both require geological models. However, currently, shale gas modeling remains relatively conventional and does not reflect the unique characteristics of shale gas reservoirs. Based on a case study of the Fuling shale gas reservoir in China, an integrated geological modeling workflow for shale gas reservoirs is proposed to facilitate its popularization and application and well improved quality and comparability. This workflow involves four types of models: a structure-stratigraphic model, reservoir (matrix) parameter model, natural fra

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7

Dai, Cheng, Liang Xue, Weihong Wang, and Xiang Li. "Analysis of the Influencing Factors on the Well Performance in Shale Gas Reservoir." Geofluids 2017 (2017): 1–12. http://dx.doi.org/10.1155/2017/7818346.

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Due to the ultralow permeability of shale gas reservoirs, stimulating the reservoir formation by using hydraulic fracturing technique and horizontal well is required to create the pathway of gas flow so that the shale gas can be recovered in an economically viable manner. The hydraulic fractured formations can be divided into two regions, stimulated reservoir volume (SRV) region and non-SRV region, and the produced shale gas may exist as free gas or adsorbed gas under the initial formation condition. Investigating the recovery factor of different types of shale gas in different region may assi

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8

Wei, Mingyao, Jishan Liu, Derek Elsworth, and Enyuan Wang. "Triple-Porosity Modelling for the Simulation of Multiscale Flow Mechanisms in Shale Reservoirs." Geofluids 2018 (May 28, 2018): 1–11. http://dx.doi.org/10.1155/2018/6948726.

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Shale gas reservoir is a typical type of unconventional gas reservoir, primarily because of the complex flow mechanism from nanoscale to macroscale. A triple-porosity model (M3 model) comprising kerogen system, matrix system, and natural fracture system was presented to describe the multispace scale, multitime scale, and multiphysics characteristic of gas flows in shale reservoir. Apparent permeability model for real gas transport in nanopores, which covers flow regime effect and geomechanical effect, was used to address multiscale flow in shale matrix. This paper aims at quantifying the shale

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9

Kim, Juhyun, Youngjin Seo, Jihoon Wang, and Youngsoo Lee. "History Matching and Forecast of Shale Gas Production Considering Hydraulic Fracture Closure." Energies 12, no. 9 (2019): 1634. http://dx.doi.org/10.3390/en12091634.

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Most shale gas reservoirs have extremely low permeability. Predicting their fluid transport characteristics is extremely difficult due to complex flow mechanisms between hydraulic fractures and the adjacent rock matrix. Recently, studies adopting the dynamic modeling approach have been proposed to investigate the shape of the flow regime between induced and natural fractures. In this study, a production history matching was performed on a shale gas reservoir in Canada’s Horn River basin. Hypocenters and densities of the microseismic signals were used to identify the hydraulic fracture distribu

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10

Klimkowski, Łukasz, and Stanisław Nagy. "Key Factors in Shale Gas Modeling and Simulation." Archives of Mining Sciences 59, no. 4 (2014): 987–1004. http://dx.doi.org/10.2478/amsc-2014-0068.

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Abstract Multi-stage hydraulic fracturing is the method for unlocking shale gas resources and maximizing horizontal well performance. Modeling the effects of stimulation and fluid flow in a medium with extremely low permeability is significantly different from modeling conventional deposits. Due to the complexity of the subject, a significant number of parameters can affect the production performance. For a better understanding of the specifics of unconventional resources it is necessary to determine the effect of various parameters on the gas production process and identification of parameter

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11

Du, Fengshuang, and Bahareh Nojabaei. "A Review of Gas Injection in Shale Reservoirs: Enhanced Oil/Gas Recovery Approaches and Greenhouse Gas Control." Energies 12, no. 12 (2019): 2355. http://dx.doi.org/10.3390/en12122355.

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Shale oil and gas resources contribute significantly to the energy production in the U.S. Greenhouse gas emissions come from combustion of fossil fuels from potential sources of power plants, oil refineries, and flaring or venting of produced gas (primarily methane) in oilfields. Economic utilization of greenhouse gases in shale reservoirs not only increases oil or gas recovery, but also contributes to CO2 sequestration. In this paper, the feasibility and efficiency of gas injection approaches, including huff-n-puff injection and gas flooding in shale oil/gas/condensate reservoirs are discusse

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12

Yan, Xun, Jing Sun, and Dehua Liu. "Numerical Simulation of Shale Gas Multiscale Seepage Mechanism-Coupled Stress Sensitivity." Journal of Chemistry 2019 (March 25, 2019): 1–13. http://dx.doi.org/10.1155/2019/7387234.

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The complexity of the gas transport mechanism in microfractures and nanopores is caused by the feature of multiscale and multiphysics. Figuring out the flow mechanism is of great significance for the efficient development of shale gas. In this paper, an apparent permeability model which covers continue, slip, transition, and molecular flow and geomechanical effect was presented. Additionally, a mathematical model comprising multiscale, geomechanics, and adsorption phenomenon was proposed to characterize gas flow in the shale reservoir. The aim of this paper is to investigate some important imp

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13

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 (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 seepag

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14

Sun, Hao, Adwait Chawathé, Hussein Hoteit, Xundan Shi, and Lin Li. "Understanding Shale Gas Flow Behavior Using Numerical Simulation." SPE Journal 20, no. 01 (2015): 142–54. http://dx.doi.org/10.2118/167753-pa.

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Summary Shale gas has changed the energy equation around the world, and its impact has been especially profound in the United States. It is now generally agreed that the fabric of shale systems comprises primarily organic matter, inorganic material, and natural fractures. However, the underlying flow mechanisms through these multiporosity and multipermeability systems are poorly understood. For instance, debate still exists about the predominant transport mechanism (diffusion, convection, and desorption), as well as the flow interactions between organic matter, inorganic matter, and fractures.

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15

Kong, Xiangwen, Hongjun Wang, Wei Yu, Ping Wang, Jijun Miao, and Mauricio Fiallos-Torres. "Compositional Simulation of Geological and Engineering Controls on Gas Huff-n-Puff in Duvernay Shale Volatile Oil Reservoirs, Canada." Energies 14, no. 8 (2021): 2070. http://dx.doi.org/10.3390/en14082070.

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Duvernay shale is a world class shale deposit with a total resource of 440 billion barrels oil equivalent in the Western Canada Sedimentary Basin (WCSB). The volatile oil recovery factors achieved from primary production are much lower than those from the gas-condensate window, typically 5–10% of original oil in place (OOIP). The previous study has indicated that huff-n-puff gas injection is one of the most promising enhanced oil recovery (EOR) methods in shale oil reservoirs. In this paper, we built a comprehensive numerical compositional model in combination with the embedded discrete fractu

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16

Fathi, Ebrahim, Fatemeh Belyadi, and Bahiya Jabbar. "Shale Poroelastic Effects on Well Performance Analysis of Shale Gas Reservoirs." Fuels 2, no. 2 (2021): 130–43. http://dx.doi.org/10.3390/fuels2020008.

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The effect of poroelastic properties of the shale matrix on gas storage and transport mechanisms has gained significant attention, especially during history-matching and hydrocarbon production forecasting in unconventional reservoirs. The common oil and gas industry practice in unconventional reservoir simulation is the extension of conventional reservoir simulation that ignores the dynamic behavior of matrix porosity and permeability as a function of reservoir effective net stress. This approach ignores the significant impact of the poroelastic characteristics of the shale matrix on hydrocarb

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17

Xu, Guixi, Shuzhong Wang, Xiangrong Luo, and Zefeng Jing. "Dry Volume Fracturing Simulation of Shale Gas Reservoir." IOP Conference Series: Earth and Environmental Science 94 (November 2017): 012179. http://dx.doi.org/10.1088/1755-1315/94/1/012179.

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18

Wu, Yu-Shu, Jianfang Li, Didier-Yu Ding, Cong Wang, and Yuan Di. "A Generalized Framework Model for the Simulation of Gas Production in Unconventional Gas Reservoirs." SPE Journal 19, no. 05 (2014): 845–57. http://dx.doi.org/10.2118/163609-pa.

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Summary Unconventional gas resources from tight-sand and shale gas reservoirs have received great attention in the past decade around the world because of their large reserves and technical advances in developing these resources. As a result of improved horizontal-drilling and hydraulic-fracturing technologies, progress is being made toward commercial gas production from such reservoirs, as demonstrated in the US. However, understandings and technologies needed for the effective development of unconventional reservoirs are far behind the industry needs (e.g., gas-recovery rates from those unco

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19

WU, TAO, and SHIFANG WANG. "A FRACTAL PERMEABILITY MODEL FOR REAL GAS IN SHALE RESERVOIRS COUPLED WITH KNUDSEN DIFFUSION AND SURFACE DIFFUSION EFFECTS." Fractals 28, no. 01 (2020): 2050017. http://dx.doi.org/10.1142/s0218348x20500176.

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A better comprehension of the behavior of shale gas transport in shale gas reservoirs will aid in predicting shale gas production rates. In this paper, an analytical apparent permeability expression for real gas is derived on the basis of the fractal theory and Fick’s law, with adequate consideration of the effects of Knudsen diffusion, surface diffusion and flexible pore shape. The gas apparent permeability model is found to be a function of microstructural parameters of shale reservoirs, gas property, Langmuir pressure, shale reservoir temperature and pressure. The results show that the appa

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20

Meng, Xingbang, Zhan Meng, Jixiang Ma, and Tengfei Wang. "Performance Evaluation of CO2 Huff-n-Puff Gas Injection in Shale Gas Condensate Reservoirs." Energies 12, no. 1 (2018): 42. http://dx.doi.org/10.3390/en12010042.

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When the reservoir pressure is decreased lower than the dew point pressure in shale gas condensate reservoirs, condensate would be formed in the formation. Condensate accumulation severely reduces the commercial production of shale gas condensate reservoirs. Seeking ways to mitigate condensate in the formation and enhance both condensate and gas recovery in shale reservoirs has important significance. Very few related studies have been done. In this paper, both experimental and numerical studies were conducted to evaluate the performance of CO2 huff-n-puff to enhance the condensate recovery in

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21

Yang, Rui, Tianran Ma, Weiqun Liu, Yijiao Fang, and Luyi Xing. "Coupled Hydro-Mechanical Analysis of Gas Production in Fractured Shale Reservoir by Random Fracture Network Modeling." International Journal of Applied Mechanics 11, no. 03 (2019): 1950031. http://dx.doi.org/10.1142/s1758825119500315.

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Accurate construction of a shale-reservoir fracture network is a prerequisite for optimizing the fracturing methods and determining shale-gas extraction schemes. Considering the influence of geological conditions, stress levels, desorption–adsorption, and fissure characteristics and distribution, establishing a shale-gas reservoir fracture-network model based on a random fracture network is significant. According to the discrete network model and Monte Carlo stochastic theory, the random fracture network of natural and artificial fractures in a shale-gas reservoir stimulation zone was construc

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22

Fujita, Yusuke, Akhil Datta-Gupta, and Michael J. King. "A Comprehensive Reservoir Simulator for Unconventional Reservoirs That Is Based on the Fast Marching Method and Diffusive Time of Flight." SPE Journal 21, no. 06 (2016): 2276–88. http://dx.doi.org/10.2118/173269-pa.

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Summary Modeling of fluid flow in unconventional reservoirs requires accurate characterization of complex flow mechanisms because of the interactions between reservoir rock, microfractures, and hydraulic fractures. The pore-size distribution in shale and tight sand reservoirs typically ranges from nanometers to micrometers, resulting in ultralow permeabilities. In such extremely low-permeability reservoirs, desorption and diffusive processes play important roles in addition to heterogeneity-driven convective flows. For modeling shale and tight oil and gas reservoirs, we can compute the well-dr

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23

Huang, Jing, Lan Ren, Jinzhou Zhao, Zhiqiang Li, and Junli Wang. "Well Performance Simulation and Parametric Study for Different Refracturing Scenarios in Shale Reservoir." Geofluids 2018 (August 23, 2018): 1–12. http://dx.doi.org/10.1155/2018/4763414.

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Refracturing is an encouraging way to uplift gas flow rate and ultimate gas recovery from shale gas wells. A numerical model, considering the stimulated reservoir volume and multiscale gas transport, is applied to simulate the gas production from a refractured shale gas well. The model is verified against field data from a shale gas reservoir in Sichuan Basin. Two refracturing scenarios: refracturing through existing perforation clusters and refracturing through new perforation zones, are included in the simulation work. Three years after production is determined to be the optimum time for ref

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HU, BOWEN, J. G. WANG, ZHONGQIAN LI, and HUIMIN WANG. "EVOLUTION OF FRACTAL DIMENSIONS AND GAS TRANSPORT MODELS DURING THE GAS RECOVERY PROCESS FROM A FRACTURED SHALE RESERVOIR." Fractals 27, no. 08 (2019): 1950129. http://dx.doi.org/10.1142/s0218348x19501299.

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Previous studies ignore the evolutions of pore microstructure parameters (pore diameter fractal dimension [Formula: see text] and tortuosity fractal dimension [Formula: see text]) but these evolutions may significantly impact the gas transport during gas extraction. In order to investigate these evolutions of fractal dimension properties during gas extraction, following four aspects are studied. Firstly, surface diffusion in adsorbed multilayer is modeled for fractal shale matrix. Our new matrix permeability model considers the slip flow, Knudsen diffusion and surface diffusion. This model is

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25

Pang, Y., M. Y. Soliman, H. Deng, and Hossein Emadi. "Analysis of Effective Porosity and Effective Permeability in Shale-Gas Reservoirs With Consideration of Gas Adsorption and Stress Effects." SPE Journal 22, no. 06 (2017): 1739–59. http://dx.doi.org/10.2118/180260-pa.

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Summary Nanoscale porosity and permeability play important roles in the characterization of shale-gas reservoirs and predicting shale-gas-production behavior. The gas adsorption and stress effects are two crucial parameters that should be considered in shale rocks. Although stress-dependent porosity and permeability models have been introduced and applied to calculate effective porosity and permeability, the adsorption effect specified as pore volume (PV) occupied by adsorbate is not properly accounted. Generally, gas adsorption results in significant reduction of nanoscale porosity and permea

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Huang, Luoyi, Guanglong Sheng, Su Li, et al. "A Review of Flow Mechanism and Inversion Methods of Fracture Network in Shale Gas Reservoirs." Geofluids 2021 (March 16, 2021): 1–10. http://dx.doi.org/10.1155/2021/6689698.

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The pore structure of shale gas reservoirs has strong heterogeneity, and the flow mechanism in multiscale media is complex. The fracture network of hydraulic fracturing is significantly affected by reservoir in situ stress, rock mechanical properties, and natural fracture distribution. At present, there is no efficient and accurate inversion method for fracture networks. Accurately describing fracture network morphology and flow capacity distribution of induced fracture is an important basis for production analysis, fracturing evaluation, and production plan. This article focuses on the hot is

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27

Stopa, Jerzy, Rafał Wiśniowski, Paweł Wojnarowski, Damian Janiga, and Krzysztof Skrzypaszek. "Integrated Approach to Drilling Project in Unconventional Reservoir Using Reservoir Simulation." E3S Web of Conferences 35 (2018): 01002. http://dx.doi.org/10.1051/e3sconf/20183501002.

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Accumulation and flow mechanisms in unconventional reservoir are different compared to conventional. This requires a special approach of field management with drilling and stimulation treatments as major factor for further production. Integrated approach of unconventional reservoir production optimization assumes coupling drilling project with full scale reservoir simulation for determine best well placement, well length, fracturing treatment design and mid-length distance between wells. Full scale reservoir simulation model emulate a part of polish shale – gas field. The aim of this paper is

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Olorode, O. M., I. Y. Akkutlu, and Y. Efendiev. "Compositional Reservoir-Flow Simulation for Organic-Rich Gas Shale." SPE Journal 22, no. 06 (2017): 1963–83. http://dx.doi.org/10.2118/182667-pa.

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Summary A new-generation compositional reservoir-flow-simulation model is presented for gas-bearing organic-rich source rocks, including convective/diffusive mass-balance equations for each hydrocarbon component in the organic (kerogen), inorganic, and fracture continua. The model accounts for the presence of dispersed kerogen with sorbed-gas corrected dynamic porosity. The Maxwell-Stefan theory is used to predict pressure- and composition-dependence of molecular diffusion in the formation. The equations are discretized and solved numerically by use of the control-volume finite-element method

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Chen, Rong, GuoHui Zhang, and ChengGao Yi. "Research progress and prospects of CO2 enhanced shale gas recovery and geologic sequestration." E3S Web of Conferences 53 (2018): 04002. http://dx.doi.org/10.1051/e3sconf/20185304002.

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CO2 injection to strengthen shale gas development is a new technology to improve shale gas recovery and realize geologic sequestration. Many scholars have studied these aspects of this technology: mechanism of CO2 displacement CH4, CO2 and CH4 adsorption capacity, affecting factors of shale adsorption CO2, CO2 displacement numerical simulation, and supercritical CO2 flooding CH4 advantages. Research shows that CO2 can exchange CH4 in shale formations, improve shale gas recovery, on the other hand shale formations is suitable for CO2 sequestration because shale gas reservoir is compact. The sup

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Chen, Zhuoheng, and Peter Hannigan. "A shale gas resource potential assessment of Devonian Horn River strata using a well-performance method." Canadian Journal of Earth Sciences 53, no. 2 (2016): 156–67. http://dx.doi.org/10.1139/cjes-2015-0094.

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Middle to Upper Devonian Horn River strata in British Columbia, western Canada, has become a proven province of commercial shale gas resource in the last few years. The shale gas resource potential in the Horn River Basin has been historically assessed based on reservoir volumetric characteristics. However, as fundamental mechanisms controlling shale gas ultimate recovery remain poorly understood, the classic theories and simulation techniques applied to evaluate recoverable gas for conventional reservoir have proven inadequate for shale gas reservoirs. Determining the ultimate recovery from p

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Yu, Wei, Kamy Sepehrnoori, and Tadeusz W. Patzek. "Modeling Gas Adsorption in Marcellus Shale With Langmuir and BET Isotherms." SPE Journal 21, no. 02 (2016): 589–600. http://dx.doi.org/10.2118/170801-pa.

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Summary Production from shale-gas reservoirs plays an important role in natural-gas supply in the United States. Horizontal drilling and multistage hydraulic fracturing are the two key enabling technologies for the economic development of these shale-gas reservoirs. It is believed that gas in shale reservoirs is mainly composed of free gas within fractures and pores and adsorbed gas in organic matter (kerogen). It is generally assumed in the literature that the monolayer Langmuir isotherm describes gas-adsorption behavior in shale-gas reservoirs. However, in this work, we analyzed four experim

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Gutiérrez - Torres, Ludy Amparo, Luz Diana Molina- Gómez, Helena Margarita Ribón- Barrios, Aristóbulo Bejarano, and Tatiana Milena Juliao- Lemus. "Methodology to define hydrocarbon potential in a shale reservoir based on geochemical data and well logs." CT&F - Ciencia, Tecnología y Futuro 9, no. 1 (2019): 5–14. http://dx.doi.org/10.29047/01225383.147.

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The office U.S. Energy Information Administration (EIA) has suggested significant volumes of hydrocarbon resources in unconventional Shale type reservoirs, which happens to be very interesting nowadays. The complexity of these reservoirs, along with the high level of risk during the exploration stage, and the lack of laboratory data, are challenging for an adequate estimation of hydrocarbon volumes in shale reservoirs. An innovative methodology to estimate prospective resources on a Shale reservoir is proposed in this paper, based on petrophysical and geochemical data from well logs, suc

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Tang, Chao, Xiaofan Chen, Zhimin Du, Ping Yue, and Jiabao Wei. "Numerical Simulation Study on Seepage Theory of a Multi-Section Fractured Horizontal Well in Shale Gas Reservoirs Based on Multi-Scale Flow Mechanisms." Energies 11, no. 9 (2018): 2329. http://dx.doi.org/10.3390/en11092329.

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Aimed at the multi-scale fractures for stimulated reservoir volume (SRV)-fractured horizontal wells in shale gas reservoirs, a mathematical model of unsteady seepage is established, which considers the characteristics of a dual media of matrix and natural fractures as well as flow in the large-scale hydraulic fractures, based on a discrete-fracture model. Multi-scale flow mechanisms, such as gas desorption, the Klinkenberg effect, and gas diffusion are taken into consideration. A three-dimensional numerical model based on the finite volume method is established, which includes the construction

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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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Cheng, Li Jun, Hong Yu Du, Zhi Guo Xie, Pei Wu Liu, and Shuai Huang. "The Practice and Cognition of Hydraulic Fracturing Technique for Shale Gas Reservoir in Southeast Chongqing." Advanced Materials Research 706-708 (June 2013): 416–19. http://dx.doi.org/10.4028/www.scientific.net/amr.706-708.416.

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Shale gas is an important unconventional energy resource. However its only achieved successful commercial exploitation in the United States and Canada. Shale gas well QY1 was carried out in southeast Chongqing.Taking this well as a case, the fracturing design optimization workflow and its practice are described in this paper. The fracturing feasibility of well QY1 was firstly determined by referencing all the physical parameters of target formation. Then the reservoir stress model was revised and reservoir stress profile was established as well. The reservoir simulation software (Eclipse) was

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D.S., Eriska Eklezia, and Hadziqul Abror. "OPTIMASI PANJANG HYDRAULIC FRACTURE PADA RESERVOIR NON-KONVENSIONAL DENGAN METODE UNIFORM CONDUCTIVITY RECTANGULAR FRACTURE." ROTOR 13, no. 1 (2020): 6. http://dx.doi.org/10.19184/rotor.v13i1.19135.

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Energy needs in the future will continue to grow along with the growth of the population. Renewable and non-renewable energy sources continue to develop with various innovations. However, energy consumption from non-renewable energy such as coal, oil, and natural gas still dominates. Therefore, one of the potential non-renewable energy sources that can be optimized at present is unconventional oil and gas reserves. Unconventional oil and gas are oil and gas that comes from sourcerock, low permeability reservoirs, such as shale oil, shale gas, tight sand gas, coal bed methane, and methane-hydra

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Wang, Xiaoqi, and Yanming Zhu. "The Genetic Mechanism and Evolution Process of Overpressure in the Upper Ordovician–Lower Silurian Black Shale Formation in the Southern Sichuan Basin." Minerals 10, no. 3 (2020): 238. http://dx.doi.org/10.3390/min10030238.

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The overpressure phenomenon is a widespread occurrence in unconventional shale gas reservoirs. Multiple overpressure shale gas fields were discovered in southern China, and there is no doubt that the gas production per well increases with increasing pressure coefficient (the ratio of the reservoir fluid pressure to the corresponding normal hydrostatic pressure). Thus, successful evaluation and production strategies of organic-rich shale deposits require an understanding of the evolution of the pressure coefficient and its controlling factors in these deposits. In this paper, drilling engineeri

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Xie, Jiang, Changdong Yang, Neha Gupta, Michael J. King, and Akhil Datta-Gupta. "Integration of Shale-Gas-Production Data and Microseismic for Fracture and Reservoir Properties With the Fast Marching Method." SPE Journal 20, no. 02 (2014): 347–59. http://dx.doi.org/10.2118/161357-pa.

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Summary We present a novel approach to calculate drainage volume and well performance in shale gas reservoirs by use of the fast marching method (FMM) combined with a geometric pressure approximation. Our approach can fully account for complex fracture-network geometries associated with multistage hydraulic fractures and their impact on the well pressure and rates. The major advantages of our proposed approach are its simplicity, intuitive appeal, and computational efficiency. For example, we can compute and visualize the time evolution of the well-drainage volume for multimillion-cell geologi

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Wan, T., J. J. Sheng, M. Y. Soliman, and Y. Zhang. "Effect of Fracture Characteristics on Behavior of Fractured Shale-Oil Reservoirs by Cyclic Gas Injection." SPE Reservoir Evaluation & Engineering 19, no. 02 (2016): 350–55. http://dx.doi.org/10.2118/168880-pa.

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Summary The current technique to produce shale oil is to use horizontal wells with multistage stimulation. However, the primary oil-recovery factor is only a few percent. The low oil recovery and abundance of shale reservoirs provide a huge potential for enhanced oil-recovery (EOR) process. Well productivity in shale oil-and-gas reservoirs primarily depends on the size of fracture network and the stimulated reservoir volume (SRV) that provides highly conductive conduits to communicate the matrix with the wellbore. The fracture complexity is critical to the well-production performance, and it a

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Zhang, Longjun, Daolun Li, Lei Wang, and Detang Lu. "Simulation of Gas Transport in Tight/Shale Gas Reservoirs by a Multicomponent Model Based on PEBI Grid." Journal of Chemistry 2015 (2015): 1–9. http://dx.doi.org/10.1155/2015/572434.

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The ultra-low permeability and nanosize pores of tight/shale gas reservoir would lead to non-Darcy flow including slip flow, transition flow, and free molecular flow, which cannot be described by traditional Darcy’s law. The organic content often adsorbs some gas content, while the adsorbed amount for different gas species is different. Based on these facts, we develop a new compositional model based on unstructured PEBI (perpendicular bisection) grid, which is able to characterize non-Darcy flow including slip flow, transition flow, and free molecular flow and the multicomponent adsorption in

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Pan, Zhejun, and Luke D. Connell. "Reservoir simulation of free and adsorbed gas production from shale." Journal of Natural Gas Science and Engineering 22 (January 2015): 359–70. http://dx.doi.org/10.1016/j.jngse.2014.12.013.

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Guo, Tiankui, Shicheng Zhang, Yushi Zou, and Bo Xiao. "Numerical simulation of hydraulic fracture propagation in shale gas reservoir." Journal of Natural Gas Science and Engineering 26 (September 2015): 847–56. http://dx.doi.org/10.1016/j.jngse.2015.07.024.

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Song, Weiqiang, Hongjian Ni, Peng Tang, et al. "Simulation of Supercritical Carbon Dioxide Fracturing in Shale Gas Reservoir." Journal of Thermal Science 30, no. 4 (2021): 1444–51. http://dx.doi.org/10.1007/s11630-021-1477-5.

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Wang, Xiaoming, Junbin Chen, Jianhong Zhu, and Diguang Gong. "Effect of the Angle between Hydraulic Fracture and Natural Fracture on Shale Gas Seepage." Mathematical Problems in Engineering 2020 (December 23, 2020): 1–13. http://dx.doi.org/10.1155/2020/5136948.

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Fracturing technology is an effective measure to exploit shale gas and the fractures improve the seepage ability of shale reservoir after fracturing. In this paper, taking Chang 7 of Yanchang Formation as the study area, a double porosity seepage model considering natural fracture was established and it was solved by finite element method of COMSOL5.5; then, shale gas seepage was analyzed under different angles between hydraulic fracture and natural fracture finally. Meanwhile, angles between hydraulic fracture and natural fracture were optimized by analyzing both the reservoir pressure distri

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Gao, Hai-Tao, Yan-Ming Zhu, Fu-Hua Shang, and Chong-Yu Chen. "Study on the Shale Gas Reservoir-Forming Characteristics of the Taiyuan Formation in the Eastern Qinshui Basin, China." Journal of Nanoscience and Nanotechnology 21, no. 1 (2021): 72–84. http://dx.doi.org/10.1166/jnn.2021.18465.

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Shales are widely developed in the strata of the Carboniferous-Permian coal measures in the Qinshui Basin, and these shales have great potential for shale gas exploration. In this paper, the shales of the Taiyuan Formation in the eastern Qinshui Basin are studied. The shales of the Taiyuan Formation in the study area are investigated through field investigation, organic geochemical testing, X-ray diffraction, scanning electron microscopy, high pressure mercury injection, low temperature liquid nitrogen adsorption and PetroMod simulation and through other tests to study the reservoir characteri

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ZHANG, QI, YULIANG SU, HUI ZHAO, WENDONG WANG, KAIJIE ZHANG, and MINGJING LU. "ANALYTIC EVALUATION METHOD OF FRACTAL EFFECTIVE STIMULATED RESERVOIR VOLUME FOR FRACTURED WELLS IN UNCONVENTIONAL GAS RESERVOIRS." Fractals 26, no. 06 (2018): 1850097. http://dx.doi.org/10.1142/s0218348x18500974.

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It has been proved that effective stimulated reservoir volume (ESRV) is a significant area dominant to the production of the fractured well in unconventional gas reservoirs. Although ESRV properties can be estimated based on the microseismic technology and the analysis of actual fracturing data, the operations are complicated and results are inaccurate. Due to the complex structure of stimulated reservoir volume (SRV) with fractal and chaotic characteristics, a fractal evaluation model for ESRV (ESRV-FEM) of fractured wells in unconventional gas (both tight and shale gas) reservoirs is develop

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Patwardhan, Samarth D., Fatemeh Famoori, and Suresh Kumar Govindarajan. "Quad-porosity shale systems – a review." World Journal of Engineering 13, no. 6 (2016): 529–39. http://dx.doi.org/10.1108/wje-09-2016-0087.

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Purpose This paper aims to review the quad-porosity shale system from a production standpoint. Understanding the complex but coupled flow mechanisms in such reservoirs is essential to design appropriate completions and further, optimally produce them. Dual-porosity and dual permeability models are most commonly used to describe a typical shale gas reservoir. Design/methodology/approach Characterization of such reservoirs with extremely low permeability does not aptly capture the physics and complexities of gas storage and flow through their existing nanopores. This paper reviews the methods an

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Zhang, Yanbin, Neha Bansal, Yusuke Fujita, Akhil Datta-Gupta, Michael J. King, and Sathish Sankaran. "From Streamlines to Fast Marching: Rapid Simulation and Performance Assessment of Shale-Gas Reservoirs by Use of Diffusive Time of Flight as a Spatial Coordinate." SPE Journal 21, no. 05 (2016): 1883–98. http://dx.doi.org/10.2118/168997-pa.

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Summary Current industry practice for characterization and assessment of unconventional reservoirs mostly uses empirical decline-curve analysis or analytic rate- and pressure-transient analysis. High-resolution numerical simulation with local perpendicular bisector (PEBI) grids and global corner-point grids has also been used to examine complex nonplanar fracture geometry, interaction between hydraulic and natural fractures, and implications for the well performance. Although the analytic tools require many simplified assumptions, numerical-simulation techniques are computationally expensive a

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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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Ding, Didier–Yu. "Modeling of Matrix/Fracture Transfer with Nonuniform-Block Distributions in Low-Permeability Fractured Reservoirs." SPE Journal 24, no. 06 (2019): 2653–70. http://dx.doi.org/10.2118/191811-pa.

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Summary Unconventional shale–gas and tight oil reservoirs are commonly naturally fractured, and developing these kinds of reservoirs requires stimulation by means of hydraulic fracturing to create conductive fluid–flow paths through open–fracture networks for practical exploitation. The presence of the multiscale–fracture network, including hydraulic fractures, stimulated and nonstimulated natural fractures, and microfractures, increases the complexity of the reservoir simulation. The matrix–block sizes are not uniform and can vary in a very wide range, from several tens of centimeters to mete

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