Coupling of Stress Dependent Relative Permeability and Reservoir Simulation

Ofagbohunmi, Samuel; Chalaturnyk, Richard J.; Leung, Juliana Y.

doi:10.2118/154083-ms

Cited by 14 publications

(6 citation statements)

References 18 publications

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“…7. The Ofagbohunmi et al model (2012) (Ofagbohunmi et al 2012) is an empirical relationship between the S wir and the normalized porosity during compaction. In Li et al model (Li et al 2010), the irreducible water saturation simulations were conducted on tight sandstone samples with the initial porosity (ϕ) of 6.17%, initial permeability (K) of 0.0951 × 10 −3 μm 2 and the initial Fig.…”

Section: Fig 4 the Irreducible Water Saturation Calculated By Differmentioning

confidence: 99%

“…5 The flow diagram of the apparatus for irreducible water saturation measurements Fig. 7 The comparison between the newly developed model and other models (Lei et al 2015;Li et al 2010;Ofagbohunmi et al 2012) irreducible water saturation of 9.8%. In Lei et al model (2015) (Lei et al 2015), the initial porosity ϕ = 6.17%, the Euclidean dimension d = 2, the initial irreducible water saturation S wc0 = 9.8%, rock Poisson's ratio ν = 0.25, and the rock elastic modulus E = 1.05 × 10 3 MPa.…”

Section: Fig 4 the Irreducible Water Saturation Calculated By Differmentioning

confidence: 99%

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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: Fig 4 the Irreducible Water Saturation Calculated By Differmentioning

confidence: 99%

Section: Fig 4 the Irreducible Water Saturation Calculated By Differmentioning

confidence: 99%

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

et al. 2020

Pet. Sci.

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“…Since capillary pressure allows us to capture the pore size and wettability effect, as well as to identify phase trapping and the endpoints of relative permeability, we have modified the form of the empirical functions developed by Khan (), Hamoud et al (), and Ojagbohunmi et al () to derive the following equations to describe the relationship between the endpoints of geo‐dynamic relative permeability and the geodynamic capillary pressure:

S_{wir} ((), t) = S_{wir} ((), - 12.15 + 13.15 ((), \frac{P_{c} (t)}{P_{c}}));

S_{nwr} ((), t) = S_{nwr} ((), - 2.75 + 3.75 ((), \frac{P_{c} (t)}{P_{c}}));

K_{rw - max} ((), t) = K_{rw - max} ((), 38.52 - 37.52 ((), \frac{P_{c}}{P_{c} (t)})); and

K_{rnw - max} ((), t) = K_{rnw - max} ((), 1.001 - 0.001 ((), \frac{P_{c}}{P_{c} (t)})) .

…”

Section: Derivation Of Semi‐analytical Modelmentioning

confidence: 99%

“…While Khan (2009), Hamoud et al (2012, and Ojagbohunmi et al (2012) have presented empirical functions relating porosity change fraction and relative permeability endpoints for Canadian oil sands, similar relationships are required for carbonates. As discussed previously, two lab experimental programs on naturally fractured carbonate undertaken by McDonald et al (1991) and Lian et al (2012) provided opposite results in terms of the changes to irreducible water saturation with compaction.…”

Section: 1029/2018wr024042mentioning

confidence: 99%

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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“…This non-linear coupling impacts the flow capacity of the porous medium due to stressinduced changes in the porous void structure, what becomes manifest by an alteration of the rock permeability. An illustrative simulation has shown, that the impact of non including this coupling in hydrocarbon recovery, is that an overestimation of about 10% of the total oil recovery in a reservoir can appear [1]. In order to study the flow-stress coupling phenomenon, laboratory work in triaxial cells has been worldwide performed along the time using cores of diverse rock types and structures, various fluids and diverse confining stresses and pore pressures [2][3][4][5].…”

Section: Introductionmentioning

confidence: 99%

Permeability simulation in an elastic deformable sandstone under stress changes

Vadillo-Sáenz

Aguilar-Gasteum

Díaz-Viera

et al. 2020

Supl. Rev. Mex. Fis.

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Fluid flow and rock mechanics become coupled in various important phenomena in Geosciences. In order to study this coupling, laboratory work has been carried out in triaxial cells along the years for various rock and fluid types at different confinement stress and pore pressure conditions. In a similar way, poromechanic models have been developed to simulate them, in which constitutive porosity and permeability correlation models in terms of strain, stress and fluid pressure have to be provided. However, to date, the applicability of the available correlation models to describe this phenomenon in different types of rock remains to be analyzed. In this work, a single-phase poroelastic model is applied to simulate a published geomechanical test performed in sandstones to examine the capacity of commonly used constitutive porosity and permeability correlations to describe the behavior of a homogeneous poroelastic medium. After discussing the results, we conclude that for this sandstone, the best permeability constitutive correlation model is Walder and Nur.

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Coupling of Stress Dependent Relative Permeability and Reservoir Simulation

Cited by 14 publications

References 18 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

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

Permeability simulation in an elastic deformable sandstone under stress changes

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