An improved solution to estimate relative permeability in tight oil reservoirs

Tian, Xinliang; Cheng, Linsong; Yan, Yiqun; Liu, Hongjun; Zhao, Wenqi; Guo, Qiang

doi:10.1007/s13202-014-0129-7

Cited by 33 publications

(25 citation statements)

References 4 publications

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“…It is assumed to adhere to the macropore wall due to the molecular forces making the water molecules bounded on the wall. Previous studies have confirmed that the thickness of the water film is related to the pressure gradient (Mo et al 2015;Tian et al 2014Tian et al , 2015Yu and Cheng 2002;Yu and Li 2001). Based on the micro-tube experiment, Tian et al (2014) presented the relationship between the pressure gradient, water viscosity and the thickness of the water film as:…”

Section: The New Modelmentioning

confidence: 89%

A new model for predicting irreducible water saturation in tight gas reservoirs

et al. 2020

Pet. Sci.

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The irreducible water saturation (S wir) is a significant parameter for relative permeability prediction and initial hydrocarbon reserves estimation. However, the complex pore structures of the tight rocks and multiple factors of the formation conditions make the parameter difficult to be accurately predicted by the conventional methods in tight gas reservoirs. In this study, a new model was derived to calculate S wir based on the capillary model and the fractal theory. The model incorporated different types of immobile water and considered the stress effect. The dead or stationary water (DSW) was considered in this model, which described the phenomena of water trapped in the dead-end pores due to detour flow and complex pore structures. The water film, stress effect and formation temperature were also considered in the proposed model. The results calculated by the proposed model are in a good agreement with the experimental data. This proves that for tight sandstone gas reservoirs the S wir calculated from the new model is more accurate. The irreducible water saturation calculated from the new model reveals that S wir is controlled by the critical capillary radius, DSW coefficient, effective stress and formation temperature.

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Section: The New Modelmentioning

confidence: 89%

A new model for predicting irreducible water saturation in tight gas reservoirs

et al. 2020

Pet. Sci.

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“…We analyzed a large amount of micro-tube experiment data within micrometer scale and results of Dissipative Particle Dynamics simulation within nanometer scale (Li et al 2011;Tian et al 2014). Table 1 lists the parameters and results of the micro-tube experiments (Li et al 2011).…”

Section: Representation Of the Thickness Of Boundary Layermentioning

confidence: 99%

A New Model for Determining the Effective Permeability of Tight Formation

et al. 2016

Self Cite

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Unlike conventional reservoirs, tight reservoirs have complex pore structures and severe boundary-layer effect. The pore throat of tight reservoirs is in nanoscale and the boundary layer cannot be ignored because the boundary layer has an important effect to the fluid flow and its influence increases with the reduction in the pore throat radius. These are the main reasons for the ultra-low permeability and low oil recovery for these reservoirs. However, previous studies have paid limited attention to the influences of the boundary-layer effect and the pore size distribution. In this paper, a new model was built to determine the effective permeability for the tight gas and oil reservoirs by taking into account the boundary-layer effect and the pore distribution. The results from this new model show good agreement with the experiment data, and the main factors that impact the effective permeability were analyzed in the study. It is found that the fluid type, means and standard deviation of pore radius, and displacement pressure gradient are the main factors influencing effective permeability. The relationship of air permeability and liquid permeability is also analyzed for tight reservoirs.

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“…where K is the absolute permeability of porous media under effective stress, D f is the pore area fractal dimension, D T is the tortuosity fractal dimension, ϕ is the porosity under effective stress, r max and r min are the maximum and minimum equivalent pore radius, respectively. δ is the thickness of the immobile fluid (boundary layer fluid) film, which can be calculated by 38,42…”

Section: Theoretical Modelmentioning

confidence: 99%

Theoretical and Experimental Study on Stress-Dependency of Oil–water Relative Permeability in Fractal Porous Media

Lei

Dong

et al. 2018

Fractals

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The coupled flow deformation behavior in the porous media has drawn tremendous attention in various scientific and engineering fields. It is reported that the porous media will be compressed and relative permeability in porous media will be changed as the effective stress increases. However, previous studies provided contradictory evidence for the stress-dependent irreducible water saturation and stress-dependent relative permeability. Until now, appropriate stress-dependent relative permeability curve for two-phase flow through porous media remains unclear. The goal of this work was to theoretically and experimentally study the stress-dependent relative permeability. Laboratory sample flooding tests were conducted to measure two-phase relative permeability in porous media under changing effective stress, and a corresponding theoretical model of stress-dependent relative permeability was derived to interpret the experimental results. The predictions from the proposed analytical model exhibited similar variation trends as the experimental data, which verified the theoretical model. Though the results for the stress-dependent relative permeability from previous studies are different, or even opposite, our proposed model with different conditions can provide explanations to these different results. This work provides a comprehensive experimental and theoretical study of stress-dependent relative permeability in porous media, which is beneficial to accurate performance forecasts for the coupled flow deformation behavior in porous media.

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An improved solution to estimate relative permeability in tight oil reservoirs

Cited by 33 publications

References 4 publications

A new model for predicting irreducible water saturation in tight gas reservoirs

A new model for predicting irreducible water saturation in tight gas reservoirs

A New Model for Determining the Effective Permeability of Tight Formation

Theoretical and Experimental Study on Stress-Dependency of Oil–water Relative Permeability in Fractal Porous Media

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