The Characteristics of Relative Permeability Curves in Naturally Fractured Carbonate Reservoirs

Lian, Peiqing; Cheng, Linsong

doi:10.2118/154814-pa

Cited by 52 publications

(34 citation statements)

References 14 publications

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“…[1][2][3][4][5][6][7][8][9][10][11][12][13][14][15][16] Relative permeability is a basic parameter for characterizing multiphase fluid flow behavior, which has a significant impact on the evaluation of multiphase flow performance. Therefore, many studies have been carried out on the relative permeability in porous media.…”

Section: Introductionmentioning

confidence: 99%

“…[5][6][7][8][9][10][11][12] Besides, much effort was devoted to numerical simulations. [13][14][15][16] Burdine studied relative permeability curves by a method which utilized capillary pressure information.…”

Section: Introductionmentioning

confidence: 99%

“…Moreover, the characteristics of oil-water relative permeability curves in natural matrix cores and fractured cores have been differentiated. 9 In 2002, Xu and Wu used lattice Boltzmann method (LBM) to simulate the relative permeability in two-phase flow through porous media. 13 Bryant and Blunt presented a predictive calculation of two-phase relative permeability in granular porous media formed from a dense random packing of equal spheres using pore network modeling.…”

Section: Introductionmentioning

confidence: 99%

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A Novel Fractal Model for Two-Phase Relative Permeability in Porous Media

Lei

Dong

et al. 2015

Fractals

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Multiphase flow in porous media is very important in various scientific and engineering fields. It has been shown that relative permeability plays an important role in determination of flow characteristics for multiphase flow. The accurate prediction of multiphase flow in porous media is hence highly important. In this work, a novel predictive model for relative permeability in porous media is developed based on the fractal theory. The predictions of two-phase relative permeability by the current mathematical models have been validated by comparing with available experimental data. The predictions by the proposed model show the same variation trend with the available experimental data and are in good agreement with the existing experiments. Every parameter in the proposed model has clear physical meaning. The proposed relative permeability is expressed as a function of the immobile liquid film thickness, pore structural parameters (pore fractal dimension D f and tortuosity fractal dimension D T ) and fluid viscosity ratio. The effects of these parameters on relative permeability of porous media are discussed in detail.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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A Novel Fractal Model for Two-Phase Relative Permeability in Porous Media

Lei

Dong

et al. 2015

Fractals

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“…In terms of laboratory experiments, there is little data showing effective stress effects on relative permeability in NFCRs. For this study, the results from experiments conducted by McDonald et al (1991) and Lian et al (2012) indicate that the irreducible wetting phase (water) saturation, S wir , increases with effective confining stress, σ 0 , while the water relative permeability, k rw , shifts to the right. This behavior suggests that the rock becomes increasingly water wet as effective stress increases.…”

Section: Resultsmentioning

confidence: 84%

New Semi‐Analytical Insights Into Stress‐Dependent Spontaneous Imbibition and Oil Recovery in Naturally Fractured Carbonate Reservoirs

Haghi

Chalaturnyk

Geiger

2018

Water Resources Research

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Fluid injection and withdrawal in a porous medium create changes in pore pressure that alter effective stresses within the medium. This leads to pore volume changes, which can be described by the poroelastic theory. These changes in pore volume can influence fluid flow processes, such as capillary diffusion and imbibition, potentially altering multiphase flow characteristics in subsurface reservoirs with a focus on oil recovery in the naturally fractured carbonate reservoirs. In this study, a semi‐analytical model is developed to analyze the impact of stress‐dependent spontaneous imbibition. The model allows us to study the influence of stress‐dependent effects on porosity, absolute permeability, relative permeability, and capillary pressure on the imbibition and oil recovery mechanisms of both intact rock and fracture in naturally fractured carbonate reservoirs. In order to capture the geomechanical interactions involved, pure compliance poroelastic definitions and nonlinear joint normal stiffness equations are used to assess the deformation of intact rock and fracture, respectively. The model shows that increasing effective confining stress shifts the imbibition capillary pressure curve upward, resulting in improved absorption of the wetting phase into the smaller pores and enhanced extraction of the nonwetting phase. Model calculations provide a rationale for how and why irreducible water saturation increases during compression of mixed‐wet carbonates and decreases in the case of initially strong water‐wet carbonates. It is also shown how higher relative permeability of the wetting phase leads to a greater diffusion of the wetting phase and improved oil recovery for the less deformed mixed‐wet rock.

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“…When the permeability of the core is low, the nonlinearity of the concave curve is strong. Lian and Cheng (2012) conducted experiments on the oil-water relative permeability of carbonate cores from the Kenkiyak oil field and compared the differences in relative permeability curves between the natural matrix cores and the artificial fracture cores. Their study showed that water injection should be implemented when reservoir pressure was relatively higher to maintain formation pressure during water flooding and reduce the effect of stress sensitivity.…”

Section: Introductionmentioning

confidence: 99%

Displacement efficiency in the water flooding process in fracture–vuggy reservoirs

et al. 2017

J Petrol Explor Prod Technol

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To determine how fracture-vuggy structure, pressure, and injection-production mode influence displacement efficiency in the water flooding process in fracture-vuggy reservoirs, two types of models were built based on the characteristic of such reservoir: two fracture models with different fracture apertures and two fracturevuggy models with different sizes of vugs. A series of twophase fluid flow experiments was conducted to study oil and water distribution as well as flow pattern in the water flooding process. Results show that displacement efficiency is significantly influenced by injection-production mode and injection pressure. By contrast, its relationship with the size of vugs is insignificant. Under the same injectionproduction mode, high-to-low recovery that corresponds to model type includes the small fracture, large fracture, small vug, and large vug models. Under the same pore volume multiple, high-to-low recovery that corresponds to model includes the small fracture, small vug, large fracture, and large vug models.

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The Characteristics of Relative Permeability Curves in Naturally Fractured Carbonate Reservoirs

Cited by 52 publications

References 14 publications

A Novel Fractal Model for Two-Phase Relative Permeability in Porous Media

A Novel Fractal Model for Two-Phase Relative Permeability in Porous Media

New Semi‐Analytical Insights Into Stress‐Dependent Spontaneous Imbibition and Oil Recovery in Naturally Fractured Carbonate Reservoirs

Displacement efficiency in the water flooding process in fracture–vuggy reservoirs

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