Hello friends,
I intend to simulate the cementation process in porous media (i.e. granular soil). I'm not sure if I can model the cement slurry as a mere fluid with high viscosity and density. If it is possible, does it act as a Newtonian fluid or as a non-Newtonian one? If the slurry cannot be accurately modeled as a fluid, how can one simulate the flow of cement slurry/paste in a porous medium?
Any suggestion is appreciated. Thanks a lot in advance.
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Technically, a cement-based slurry is actually a Bingham fluid and not a Newton fluid during the grouting design and construction process. However, it may be approximated as a Newtonian fluid.
You may find this paper on Grout diffusion model in porous media considering the variation in viscosity with time to be useful:
https://www.researchgate.net/publication/330692262_Grout_diffusion_model_in_porous_media_considering_the_variation_in_viscosity_with_time
Thank you Kira Haller for the response. As far as I know, Bingham fluids use a constant plastic viscosity while some believe that the viscosity of the slurry changes with shear rate, resembling the behavior of Herschel–Bulkley fluids. Is there any study comparing the accuracy of different fluid models for cement slurry?
For a cement slurry for oil and gas wells its rheological characterisation has been carried out by many authors (i.e. Bourgoyne A. et al 1991, Technip 1982 and many of the service company manuals/books & publications). This characterisation has been based on a number of assumptions such as that temperature has no influence on the rheology until the slurry is in place. In other words that its rheological behaviour is either assumed at surface or downhole temperature and prior to the onset of dehydration and setting of the slurry. Passage of the slurry through the porous media (invasion) has been modelled by Chin W. (Formation Invasion 1995) which is worth reading. Invasion (Also know as filtrate invasion) can also be modelled using the algorithms used to calculate fluid loss in fracturing treatments, they are based on viscosity, pressure and rock properties. These can be found in most manuals of hydraulic fracturing. I hope it helps
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