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On the Modelling of Subsurface Multiphase Flow using TransAT 24 March, 2015 ASCOMP www.ascomp.ch transat@ascomp.ch

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Flow through porous media: from CCS to CCS-EOR

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Geological Storage of CO2 The issues: Options 1 to 6 above cannot be implemented without a detailed knowledge of the hydrodynamics in the injection locations: the interaction of the various phases and components (e.g. CO 2 ) within the rock pores. This can be achieved by modern simulation.

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Flow through porous media Complex geometry from tomography data

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Flow through porous media Click on movie to play N-Phase model with dense particles as fine porous medium

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Flow through porous media

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Multiphase with CO2 through porous media N-Phase multicomponent model for large interfaces

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Flow Fractures with Leak (loss of drilling fluids) L= 300mm; H=10mm; h=2mm 1-Phase Non-Newtonian fluids modelling

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Velocity Contours for Newtonian (left) and non-Newtonian (right) near fracture Flow Fractures with Leak (loss of drilling fluids)

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Injection process of gas into the mixture of oil & water Fixed the pipe diameter, find the optimal gas injection rate, i.e. optimal the design of valve nozzle diameter and injection pressure etc. Heat transfer due to bubble generation Gas lift in wells and risers

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Diameter of the internal pipe: 50 to 75mm. Valve nozzle diameter: 3.2 to 8.0mm Valve injection pressure: 7-12MP Mass flow rate of the inflow: 30-300 m 3 /day Oil & Water volume rate: 50-100% Compressible gas Pipe length: Gas lift in wells and risers

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N-Phase model for large interfaces Gas lift in wells and risers

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Near wellbore multiphase flow

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Cross heating of oil wells

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