A Fully Coupled Three-Phase Model for Capillary Pressure and Relative Permeability for Implicit Compositional Reservoir Simulation

Hustad, Odd Steve; Browning, David John

doi:10.2118/125429-ms

Cited by 10 publications

(5 citation statements)

References 15 publications

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“…The model further revised by many researchers and widely used in commercial simulators, such as Eclipse and CMG (Al-Nuaimi et al., 2018; Coats, 1980; GeoQuest, 2014; Hustad and Browning, 2010). This is a simple and practical approach to evaluate the effect of miscibility on the relative permeability.…”

Section: Relative Permeability Of Gas/oil Systemmentioning

confidence: 99%

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Analytical solution of Buckley-Leverett equation for gas flooding including the effect of miscibility with constant-pressure boundary

Chen

et al. 2019

Energy Exploration & Exploitation

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This paper presents an analytical solution of Buckley-Leverett equation for gas flooding with constant-pressure boundary including the effect of miscibility on the viscosity and relative permeability. First, a relative permeability model and a viscosity model with consideration of miscibility are used to describe the variations of relative permeability and viscosity of oil and gas. Then, based on the fractional-flow theory, the Buckley-Leverett equation for gas flooding with constantpressure boundary including the effect of miscibility is constructed and solved analytically. From the analytical solution, the saturation and pressure profiles, the total volumetric flux and the breakthrough time are determined. To verify the theory, the analytical solution is compared with the numerical solution. The comparison shows that the analytical solution is in reasonable agreement with numerical solution. Through the study on the influential factors, it can be concluded that total volumetric flux is increasing with the increases of permeability and pressure and decrease of gas viscosity. The increase of total volumetric flux accelerates breakthrough of the injected gas. Furthermore, with the pressure increase, there are remarkable reduction in residual oil saturation and improvement of relative permeability, resulting in higher gas saturation and oil displacement efficiency. The analytical solution presented in this paper provides guidance on analyzing the distribution of saturation and pressure profiles, predicting the gas production and oil recovery efficiency of oil well.

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Section: Relative Permeability Of Gas/oil Systemmentioning

confidence: 99%

“…Compared with the traditional way, the technique showed good results and the overall numerical error was reduced. The interpolation parameter is the function of IFT in these models (Al-Nuaimi et al., 2018; Alzayer et al., 2018; Hustad and Browning, 2010; Mott et al., 2000). Mott et al.…”

Section: Relative Permeability Of Gas/oil Systemmentioning

confidence: 99%

Analytical solution of Buckley-Leverett equation for gas flooding including the effect of miscibility with constant-pressure boundary

Chen

et al. 2019

Energy Exploration & Exploitation

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“…As was discussed in the previous section, they ignored the effect of the oil phase on hysteresis and used Killough's two-phase model. Hustad (2010) assumed that capillary pressure between each pair of phases can be described by two different functions depending on which phase saturation is used. Hence, a total of 6 independent functions can be defined and he suggested an algorithm to choose between several possible combinations for three phases.…”

Section: Three-phase Capillary Pressure Modelsmentioning

confidence: 99%

Compositional Three-Phase Relative Permeability and Capillary Pressure Models Using Gibbs Free Energy

Neshat

Pope

2017

Day 1 Mon, February 20, 2017

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This paper presents new coupled three-phase relative permeability and capillary pressures models for implementation in a four-phase flow compositional EOS simulator. Identification of hydrocarbon and aqueous phases based on their molar Gibbs free energy is a key feature of the new model. Instead of using phase labels (gas/oil/solvent/aqueous) to define parameters such as relative permeability endpoints, residual saturations and exponents, the parameters are continuously interpolated between reference values using the Gibbs free energy of each phase at each time step. Models independent of phase label have many advantages in terms of both numerical stability and physical consistency. The models integrate and unify relevant physical parameters including trapping number and hysteresis into one rigorous algorithm for application in numerical reservoir simulators. The robustness of the new models is demonstrated with simulations of miscible WAG and solvent stimulation to remove condensate and/or water blocks in both conventional and unconventional formations.

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“…Jerauld (1997) proposed a 'gas-like' parameter based on the parachor-weighted molar density of immiscible oil, gas, and the current condition. Hustad (2002) related the endpoint saturation to the ratio of IFT under the current state to an immiscible state and also scaled the two-phase relative permeabilities. Yuan and Pope (2012) stated that to avoid any discontinuities in the relative permeability it should be a function of intensive thermodynamic properties that are continuous at local thermodynamic equilibrium.…”

Section: Compositional Effectsmentioning

confidence: 99%

A New Approach to Model Hysteresis and Its Impact on CO2-EOR Processes with Mobility Control Strategies

Beygi

Delshad

Pudugramam

et al. 2013

SPE Western Regional &Amp; AAPG Pacific Section Meeting 2013 Joint Technical Conference

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Mobility control methods have the potential to improve coupled enhanced oil recovery and CO 2 storage (CO 2 -EOR). There is a need for improved three-phase relative permeability models with hysteresis including especially the effects of cycle dependency so that more accurate predictions of these methods can be made. We propose a new three-phase relative permeability model with hysteresis applicable to different fluid configurations in porous medium under different wettability conditions. The model also includes compositional effects. Three-phase parameters are estimated based on saturationweighted interpolation of two-phase parameters. The proposed hysteresis model is an extension of the Land trapping model but with a dynamic Land coefficient introduced. The trapping model estimates a constantly increasing trapped saturation for intermediate-and non-wetting phases. The model overcomes some of the limitations of existing three-phase hysteresis models for non-water wet rocks and mitigates the complexity associated with commonly applied models in numerical simulators. The model is validated using multi-cyclic three-phase water-alternating-gas experimental data for non-water wet rocks. Numerical simulations of a carbonate reservoir with and without hysteresis were used to assess the impact of the saturation direction and saturation path on gas entrapment and oil recovery. Background and Literature ReviewUnlike water-wet rocks, mixed-wet reservoirs show a continuous oil phase in three-phase flow resulting in small, yet nonzero, values of the oil relative permeability (Salathiel, 1973). The dependence of oil isoperms on one or two phase saturations in the saturation space is complex and difficult to predict a priori (van Dijke et al., 2001). Moreover, by studying three-phase displacement processes and pore-scale mechanisms in etched micromodels, it was revealed that fluid configurations can be categorized based on the phase spreading coefficient

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A Fully Coupled Three-Phase Model for Capillary Pressure and Relative Permeability for Implicit Compositional Reservoir Simulation

Cited by 10 publications

References 15 publications

Analytical solution of Buckley-Leverett equation for gas flooding including the effect of miscibility with constant-pressure boundary

Analytical solution of Buckley-Leverett equation for gas flooding including the effect of miscibility with constant-pressure boundary

Compositional Three-Phase Relative Permeability and Capillary Pressure Models Using Gibbs Free Energy

A New Approach to Model Hysteresis and Its Impact on CO2-EOR Processes with Mobility Control Strategies

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