Improved IMPES Scheme for the Simulation of Incompressible Three-Phase Flows in Subsurface Porous Media

Liang, Runhong; Fan, Xiaolin; Luo, Xianbing; Sun, Shuyu; Zhu, Xingyu

doi:10.3390/en14102757

Cited by 3 publications

(3 citation statements)

References 27 publications

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“…Supercritical CO 2 accumulated at the top of the reservoir due to buoyancy in 2150, rather than moving rapidly laterally (Fig. 5 b,d) 82 . The system was gravity dominated, as counter-current movement ensued in the vertical route owing to the gravity segregation of CO 2 , water, and oil, and the CO 2 invasion into the reservoir being stable due to gravity stability and gravity exceeding viscous forces 83 , it is also pertinent to note that low injection rate is accompanied with less lateral spreading of gas 84 .…”

Section: Resultsmentioning

confidence: 97%

Dynamic modeling of geological carbon storage in an oil reservoir, Bredasdorp Basin, South Africa

Afolayan,

Mackay,

Opuwari

2023

Sci Rep

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Geological carbon storage provides an efficient technology for the large-scale reduction of atmospheric carbon, and the drive for net-zero emissions may necessitate the future usage of oil reservoirs for CO2 projects (without oil production), hence, dynamic modeling of an oil reservoir for CO2 storage in the Bredasdorp basin, South Africa, was therefore conducted. Injection into the reservoir was for 20 years (2030–2050), and 100 years (2050–2150) to study the CO2–brine–oil interactions, with sensitivities carried out on reservoir boundary conditions. The closed boundary scenario experienced pressure buildup with a target injection rate of 0.5 Mt/year, and a cutback on injection rate progressively until 2050 to not exceed the fracture pressure of the reservoir. The CO2 plume migration was not rapid due to the reduced volume of CO2 injected and the confining pressure. The system was gravity dominated, and gravity stability was not attained at the end of the simulation as fluid interfaces were not yet flat. The open boundary reservoir did not experience a pressure buildup because all boundaries were open, the target injection rate was achieved, and it was a viscous-dominated system. In both cases, the dissolution of CO2 in oil and brine was active, and there was a growing increase of CO2 fraction dissolved in water and oil, a decline in gaseous mobile CO2 phase between 2050 and 2150, and active trapping mechanisms were structural trapping, dissolution in oil and water, and residual trapping. The study showed that boundary condition was very crucial to the success of the project, with direct impacts on injection rate and pressure. This pioneering study has opened a vista on the injection of CO2 into an oil reservoir, and CO2–brine–oil interactions, with sensitivities carried out on reservoir boundary conditions in a closed and an open hydrocarbon system in South Africa.

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Section: Resultsmentioning

confidence: 97%

Dynamic modeling of geological carbon storage in an oil reservoir, Bredasdorp Basin, South Africa

Afolayan,

Mackay,

Opuwari

2023

Sci Rep

View full text Add to dashboard Cite

show abstract

“…Supercritical CO2 accumulated at the top of the reservoir due to buoyancy in 2150, rather than moving laterally (Fig. 5b & d) 57 . The system was gravity dominated, as counter-current movement ensued in the vertical route owing to the gravity segregation of CO 2 , water, and oil, though the gravity segregation was reduced because of relative permeability [58][59][60][61] , with increasing residence time, the system will be fully gravity stable evidenced by uid interfaces being at.…”

Section: Injection and Pressurementioning

confidence: 98%

Dynamic modeling of geological carbon storage in an oil reservoir, Bredasdorp Basin, South Africa

Afolayan

Mackay²,

Opuwari

2023

Preprint

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Geological carbon storage provides an efficient technology for the large-scale reduction of atmospheric carbon, and the drive for net-zero emissions may necessitate the future usage of oil reservoirs for CO2 projects, (without oil production), hence, dynamic modeling of an oil reservoir for CO2 storage in the Bredasdorp basin, South Africa, was therefore conducted. Injection into the reservoir was for 20 years (2030–2050), and 100 years (2050–2150) to study the CO2-brine-oil interactions, with sensitivities carried out on reservoir boundary conditions. The closed boundary scenario experienced pressure buildup with a target injection rate of 0.5 Mt/year, and a cutback on injection rate progressively until 2050 to not exceed the fracture pressure of the reservoir. The CO2 plume migration was not rapid due to the reduced volume of CO2 injected and the confining pressure. The system was gravity dominated, and gravity stability was not attained at the end of the simulation as fluid interfaces were not yet flat. The open boundary reservoir did not experience a pressure buildup because all boundaries were open, the target injection rate was achieved, and it was a viscous-dominated system. In both cases, the dissolution of CO2 in oil and brine was active, and there was a growing increase of CO2 fraction dissolved in water and oil, a decline in gaseous mobile CO2 phase between 2050 and 2150, and active trapping mechanisms were structural trapping, dissolution in oil and water, and residual trapping. The study showed that boundary condition was very crucial to the success of the project, with direct impacts on injection rate and pressure. This pioneer study has opened a vista on the injection of CO2, and CO2-brine-oil interactions, with sensitivities carried out on reservoir boundary conditions in a closed and an open hydrocarbon system in South Africa.

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“…The implicit methods, in contrast, are “unconditionally stable” but very expensive from the computational point of view and may lead to mass balance errors. See for example [ 30 , 31 ] for two-phase flow using an implicit pressure and explicit saturation schemes, three-phase fluid flow [ 32 ], finite element methods [ 33 – 36 ].…”

Section: Introductionmentioning

confidence: 99%

Investigating the migration of immiscible contaminant fluid flow in homogeneous and heterogeneous aquifers with high-precision numerical simulations

Feo

Celico

2022

PLoS ONE

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Numerical modeling of the migration of three-phase immiscible fluid flow in variably saturated zones is challenging due to the different behavior of the system between unsaturated and saturated zones. This behavior results in the use of different numerical methods for the numerical simulation of the fluid flow depending on whether it is in the unsaturated or saturated zones. This paper shows that using a high-resolution shock-capturing conservative method to resolve the nonlinear governing coupled partial differential equations of a three-phase immiscible fluid flow allows the numerical simulation of the system through both zones providing a unitary vision (and resolution) of the migration of an immiscible contaminant problem within a porous medium. In particular, using different initial scenarios (including impermeable “lenses” in heterogeneous aquifers), three-dimensional numerical simulation results are presented on the temporal evolution of the contaminant migration following the saturation profiles of the three-phases fluids flow in variably saturated zones. It is considered either light nonaqueous phase liquid with a density less than the water, or dense nonaqueous phase liquid, which has densities greater than the water initially released in unsaturated dry soil. Our study shows that the fate of the migration of immiscible contaminants in variably saturated zones can be accurately described, using a unique mathematical conservative model, with different evolution depending on the value of the system’s physical parameters, including the contaminant density, and accurately tracking the evolution of the sharp (shock) contaminant front.

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Improved IMPES Scheme for the Simulation of Incompressible Three-Phase Flows in Subsurface Porous Media

Cited by 3 publications

References 27 publications

Dynamic modeling of geological carbon storage in an oil reservoir, Bredasdorp Basin, South Africa

Dynamic modeling of geological carbon storage in an oil reservoir, Bredasdorp Basin, South Africa

Dynamic modeling of geological carbon storage in an oil reservoir, Bredasdorp Basin, South Africa

Investigating the migration of immiscible contaminant fluid flow in homogeneous and heterogeneous aquifers with high-precision numerical simulations

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