Effect of Permeability Anisotropy on the Production of Multi-Scale Shale Gas Reservoirs

Huang, Ting; Tao, Zhengwu; Li, Erpeng; Lyu, Qiqi; Guo, Xiaolu

doi:10.3390/en10101549

Cited by 17 publications

(10 citation statements)

References 35 publications

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“…The numerical simulator for shale gas reservoirs was validated in our previous work, and the parameters needed for simulation are listed in Table . In this part, the effects of different gas transport mechanisms such as bulk gas transport and surface diffusion on apparent permeability of nanopores have been studied, and the effects of surface diffusion under different pore radius, surface diffusion coefficient and stimulated reservoir volume on the production rate, and cumulative production of multifractured horizontal well are analyzed thoroughly.…”

Section: Resultsmentioning

confidence: 99%

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

Huang

Cao

Yuan

et al. 2019

Energy Science & Engineering

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Multiflow mechanisms coexist in shale gas reservoirs (SGRs) due to the abundant nanopores and the organic matter as a medium of gas souring and storage. The gas transport mechanisms in nanopores including bulk gas transfer and adsorption‐gas surface diffusion were already investigated in pore‐scale models, but their effects on actual gas production of multistage fractured horizontal wells in SGRs are not clearly understood, which are crucial for the economic development of unconventional resources. Therefore, a comprehensive apparent permeability (AP) model which couples the surface diffusion of adsorbed gas, slippage flow considering the additional flux generated by surface diffusion based on Langmuir's theory, and Knudsen diffusion is established. The presented model is validated with the experimental data and lattice Boltzmann method (LBM) simulation results. Then, we propose a numerical model which combines multiflow mechanisms in microscale pores and a multistage fractured horizontal well (MSFHW) in macroscale shale gas reservoirs together. The effects of different transport mechanisms on both AP of nanopores and gas production are analyzed thoroughly. The results show that the effect of surface diffusion on the apparent permeability of nanopores is much greater than that on the actual gas production of MSFHW, and the influence of high‐pressure condition must be considered when calculating the surface diffusion coefficient. The presented numerical model has important implications for accurate numerical simulation and efficient development of shale gas reservoirs.

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Section: Resultsmentioning

confidence: 99%

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

Huang

Cao

Yuan

et al. 2019

Energy Science & Engineering

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“…So, an apparent permeability model based on Beskok-Karniadakis (BK model) theory is widely used to characterize the multiscale transport of shale gas [19][20][21][22][23][24], and the model can be expressed as follows:…”

Section: Apparent Permeability Model With Stress Sensitivitymentioning

confidence: 99%

Numerical Simulation of Shale Gas Multiscale Seepage Mechanism-Coupled Stress Sensitivity

Yan

Sun

Liu

2019

Journal of Chemistry

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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 impacts in the process of gas transportation, which includes the shale stress sensitivity, adsorption phenomenon, and reservoir porosity. The results reveal that the performance of the multistage fractured horizontal well is strongly influenced by stress sensitivity coefficient. The cumulative gas production will decrease sharply when the shale gas reservoir stress sensitivity coefficient increases. In addition, the adsorption phenomenon has an influence on shale gas seepage and sorption capacity; however, the effect of adsorption is very weak in the early gas transport period, and the impact of later will increase. Moreover, shale porosity also greatly affects the shale gas transportation.

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“…Since anisotropic hydrocarbon reservoirs were recognised in the literature (e.g. Young et al 1964), there have been many studies on the effect of anisotropy on almost every rock physical property, from petrofacies (Marco et al 2007;Johansen et al 2004;Cosen et al 1994), porosity (Huang et al 2015;Zhao et al 2013), elastic properties (Chemali et al 1987;Nathan et al 1990;Johnston and Christensen 1995) and permeability (Huang et al 2017;Kwon et al 2004, Cosan et al 1994. In each case, the study is confined to the micro-scale processes which lead to anisotropy, rather than investigating how these properties conspire to affect the macroscopic properties of the reservoir such as changes in the local fluid saturation and pressure drawdown during production.…”

Section: Introductionmentioning

confidence: 99%

Modelling the Impact of Anisotropy on Hydrocarbon Production in Heterogeneous Reservoirs

2020

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Effective and optimal hydrocarbon production from heterogeneous and anisotropic reservoirs is a developing challenge in the hydrocarbon industry. While experience leads us to intuitive decisions for the production of these heterogeneous and anisotropic reservoirs, there is a lack of information concerning how hydrocarbon and water production rate and cumulative production as well as water cut and water breakthrough time depend on quantitative measures of heterogeneity and anisotropy. In this work, we have used Generic Advanced Fractal Reservoir Models (GAFRMs) to model reservoirs with controlled heterogeneity and vertical and/or horizontal anisotropy, following the approach of Al-Zainaldin et al. (Transp Porous Media 116(1):181-212, 2017). This Generic approach uses fractal mathematics which captures the spatial variability of real reservoirs at all scales. The results clearly show that some anisotropy in hydrocarbon production and water cut can occur in an isotropic heterogeneous reservoir and is caused by the chance placing of wells in high-quality reservoir rock or vice versa. However, when horizontal anisotropy is introduced into the porosity, cementation exponent and grain size (and hence also into the permeability, capillary pressure, water saturation) in the reservoir model, all measures of early stage and middle stage hydrocarbon and water production become anisotropic, with isotropic flow returning towards the end of the reservoir's lifetime. Specifically, hydrocarbon production rate and cumulative production are increased in the direction of anisotropy, as is water cut, while the time to water breakthrough is reduced. We found no such relationship when varying vertical anisotropy because we were using vertical wells but expect there to be an effect if horizontal wells were used.

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Effect of Permeability Anisotropy on the Production of Multi-Scale Shale Gas Reservoirs

Cited by 17 publications

References 35 publications

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

Numerical Simulation of Shale Gas Multiscale Seepage Mechanism-Coupled Stress Sensitivity

Modelling the Impact of Anisotropy on Hydrocarbon Production in Heterogeneous Reservoirs

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