Abstract
A novel volume of fluid method is presented for mineral precipitation coupled with fluid flow and reactive transport. The approach describes the fluid-solid interface as a smooth transitional region, which is designed to provide the same precipitation rate and viscous drag force as a sharp interface. Specifically, the governing equation of mineral precipitation is discretized by an upwind scheme, and a rigorous effective viscosity model is derived around the interface. The model is validated against analytical solutions for mineral precipitation in channel and ring-shaped structures. It also compares well with interface tracking simulations of advection-diffusion-reaction problems. The methodology is finally employed to model mineral precipitation in fracture networks, which is challenging due to the low porosity and complex geometry. Compared to other approaches, the proposed model has a concise algorithm and contains no free parameters. In the modeling, only the pore space requires meshing, which improves the computational efficiency especially for low-porosity media.
Similar content being viewed by others
References
Kampman, N., Bickle, M., Wigley, M., Dubacq, B.: Fluid flow and CO2-fluid-mineral interactions during CO2-storage in sedimentary basins. Chem. Geol. 369, 22–50 (2014)
Xu, R., Li, R., Ma, J., He, D., Jiang, P.: Effect of mineral dissolution/precipitation and CO2 exsolution on CO2 transport in geological carbon storage. Acc. Chem. Res. 50(9), 2056–2066 (2017)
Entrekin, S., Evans-White, M., Johnson, B., Hagenbuch, E.: Rapid expansion of natural gas development poses a threat to surface waters. Front. Ecol. Environ. 9(9), 503–511 (2011)
Paukert Vankeuren, A.N., Hakala, J.A., Jarvis, K., Moore, J.E.: Mineral reactions in shale gas reservoirs: Barite scale formation from reusing produced water as hydraulic fracturing fluid. Environ. Sci. Technol. 51(16), 9391–9402 (2017)
Rabemanana, V., Vuataz, F.-D., Kohl, T., André, L.: Simulation of mineral precipitation and dissolution in the 5-km deep enhanced geothermal reservoir at Soultz-sous-Forêts, France. Proceedings World Geothermal Congress (2005)
Burns, P.C., Klingensmith, A.L.: Uranium mineralogy and neptunium mobility. Elements 2(6), 351–356 (2006)
Ling, B., et al.: Probing multiscale dissolution dynamics in natural rocks through microfluidics and compositional analysis. Proc. Natl. Acad. Sci. 119(32), e2122520119 (2022)
Borgia, A., Pruess, K., Kneafsey, T.J., Oldenburg, C.M., Pan, L.: Numerical simulation of salt precipitation in the fractures of a CO2-enhanced geothermal system. Geothermics 44, 13–22 (2012)
Deng, H., et al.: A 2.5 D reactive transport model for fracture alteration simulation. Environ. Sci. Technol. 50(14), 7564–7571 (2016)
Carman, P.C.: Fluid flow through granular beds. Chem. Eng. Res. Design 75, S32–S48 (1997)
Menefee, A.H., et al.: Rapid mineral precipitation during shear fracturing of carbonate-rich shales. J. Geophys. Res. Solid Earth 125(6), e2019JB018864 (2020)
Vidic, R.D., Brantley, S.L., Vandenbossche, J.M., Yoxtheimer, D., Abad, J.D.: Impact of shale gas development on regional water quality. Science 340(6134), 1235009 (2013)
Ge, Q., Yap, Y., Vargas, F., Zhang, M., Chai, J.: A total concentration method for modeling of deposition. Numer. Heat Transf. B: Fundam. 61(4), 311–328 (2012)
Juric, D., Tryggvason, G.: A front-tracking method for dendritic solidification. J. Comput. Phys. 123(1), 127–148 (1996)
Starchenko, V., Marra, C.J., Ladd, A.J.: Three-dimensional simulations of fracture dissolution. J. Geophys. Res. Solid Earth 121(9), 6421–6444 (2016)
Starchenko, V., Ladd, A.J.: The development of wormholes in laboratory-scale fractures: Perspectives from three-dimensional simulations. Water Resour. Res. 54(10), 7946–7959 (2018)
Ladd, A.J., Szymczak, P.: Reactive flows in porous media: Challenges in theoretical and numerical methods. Annu. Rev. Chem. Biomol. Eng. 12(1), 543–571 (2021)
Kang, Q., Zhang, D., Chen, S.: Simulation of dissolution and precipitation in porous media. J. Geophys. Res. Solid Earth 108(B10), 2505 (2003)
Huber, C., Shafei, B., Parmigiani, A.: A new pore-scale model for linear and non-linear heterogeneous dissolution and precipitation. Geochimica et Cosmochimica Acta 124, 109–130 (2014)
Poonoosamy, J., et al.: A microfluidic experiment and pore scale modelling diagnostics for assessing mineral precipitation and dissolution in confined spaces. Chem. Geol. 528, 119264 (2019)
Tartakovsky, A.M., Meakin, P., Scheibe, T.D., West, R.M.E.: Simulations of reactive transport and precipitation with smoothed particle hydrodynamics. J. Comput. Phys. 222(2), 654–672 (2007)
Li, X., Huang, H., Meakin, P.: A three-dimensional level set simulation of coupled reactive transport and precipitation/dissolution. Int. J. Heat Mass Trans. 53(13–14), 2908–2923 (2010)
Ray, N., Oberlander, J., Frolkovic, P.: Numerical investigation of a fully coupled micro-macro model for mineral dissolution and precipitation. Comput. Geosci. 23(5), 1173–1192 (2019)
Xu, Z., Meakin, P.: Phase-field modeling of solute precipitation and dissolution. J. Chem. Phys 129(1), 014705 (2008)
Xu, Z., Huang, H., Li, X., Meakin, P.: Phase field and level set methods for modeling solute precipitation and/or dissolution. Comput. Phys. Commun. 183(1), 15–19 (2012)
Soulaine, C., Tchelepi, H.A.: Micro-continuum approach for pore-scale simulation of subsurface processes. Transport Porous Med. 113(3), 431–456 (2016)
Soulaine, C., Roman, S., Kovscek, A., Tchelepi, H.A.: Mineral dissolution and wormholing from a pore-scale perspective. J. Fluid Mech. 827, 457–483 (2017)
Yang, F., Stack, A.G., Starchenko, V.: Micro-continuum approach for mineral precipitation. Sci. Rep. 11(1), 1–14 (2021)
Deng, H., Tournassat, C., Molins, S., Claret, F., Steefel, C.: A pore-scale investigation of mineral precipitation driven diffusivity change at the column-scale. Water Resour. Res. 57(5), e2020WR028483 (2021)
Deng, H., Poonoosamy, J., Molins, S.: A reactive transport modeling perspective on the dynamics of interface-coupled dissolution-precipitation. Appl. Geochem. 137, 105207 (2022)
Soulaine, C., Pavuluri, S., Claret, F., Tournassat, C.: porousMedia4Foam: Multi-scale open-source platform for hydro-geochemical simulations with OpenFOAM®. Environ. Model. Softw. 145, 105199 (2021)
Goyeau, B., Benihaddadene, T., Gobin, D., Quintard, M.: Averaged momentum equation for flow through a nonhomogenenous porous structure. Transport Porous Med. 28(1), 19–50 (1997)
Noiriel, C., Soulaine, C.: Pore-scale imaging and modelling of reactive flow in evolving porous media: Tracking the dynamics of the fluid-rock interface. Transport Porous Med. 140(1), 181–213 (2021)
Braissant, O., Cailleau, G., Dupraz, C., Verrecchia, E.P.: Bacterially induced mineralization of calcium carbonate in terrestrial environments: the role of exopolysaccharides and amino acids. J. Sediment. Res. 73(3), 485–490 (2003)
Fernandez-Martinez, A., Hu, Y., Lee, B., Jun, Y.-S., Waychunas, G.A.: In situ determination of interfacial energies between heterogeneously nucleated CaCO3 and quartz substrates: thermodynamics of CO2 mineral trapping. Environ. Sci. Technol. 47(1), 102–109 (2013)
Issa, R.I.: Solution of the implicitly discretised fluid flow equations by operator-splitting. J. Comput. Phys. 62(1), 40–65 (1986)
Mourzenko, V., Békri, S., Thovert, J., Adler, P.: Deposition in fractures. Chem. Eng. Commun. 148(1), 431–464 (1996)
Li, X., Huang, H., Meakin, P.: Level set simulation of coupled advection-diffusion and pore structure evolution due to mineral precipitation in porous media. Water Resour. Res. 44(12), W12407 (2008)
Wang, Z., Battiato, I.: Patch-based multiscale algorithm for flow and reactive transport in fracture-microcrack systems in shales. Water Resour. Res. 56(2), e2019WR025960 (2020)
Wang, Z., Battiato, I.: Upscaling reactive transport and clogging in shale microcracks by deep learning. Water Resour. Res. 57(4), e2020WR029125 (2021)
Molins, S., et al.: Simulation of mineral dissolution at the pore scale with evolving fluid-solid interfaces: Review of approaches and benchmark problem set. Comput. Geosci. 25, 1285–1318 (2021)
Acknowledgements
This work was supported as part of the Center for Mechanistic Control of Water-Hydrocarbon-Rock Interactions in Unconventional and Tight Oil Formations (CMC-UF), an Energy Frontier Research Center funded by the U.S. Department of Energy, Office of Science under DOE (BES) Award DE-SC0019165. Data will be made available on reasonable request.
Author information
Authors and Affiliations
Corresponding author
Ethics declarations
Conflicts of interest
The authors declare that they have no conflict of interest/competing interest.
Additional information
Publisher's Note
Springer Nature remains neutral with regard to jurisdictional claims in published maps and institutional affiliations.
Appendix A Effective viscosity model
Appendix A Effective viscosity model
In this appendix we will prove that the effective viscosity model, described by Eq. (2), can guarantee that the smooth interface exerts the same viscous drag force on the fluid as a sharp interface. We start by constructing a local coordinate system, where the x axis is normal to the interface. The transitional region of the smooth interface is from \(x_1\) to \(x_2\), with \(x_1\) and \(x_2\) in the liquid and solid phases, respectively:
where \(u = \Vert \textbf{u}\Vert \) is the velocity magnitude. Since the viscous force is dominant near the wall boundary, we can neglect the inertial and pressure terms in Eq. () and only keep the viscous term:
We assume the derivative in the normal direction (x direction) is much larger than in the tangential direction and there is no penetration (\(\textbf{u}\cdot \textbf{x}= 0)\):
where f is the viscous drag force exerted on the fluid per unit interface area.
Next we consider a sharp interface. To ensure the fluid occupies the same volume as in the smooth-interface case and the sharp-interface case, the sharp interface location (\(x_0\)) should be:
The governing equation and the boundary conditions are:
where \(\textbf{u}^*\) is the velocity in the sharp-interface case. With the same assumptions, the viscous drag force from the sharp interface, per unit area, is:
The smooth interface and the sharp interface should provide the same viscous drag force, to ensure the momentum balance is accurately described. Thus, we let f in Eq. A4 and Eq. A8 be the same and combine them with Eq. A5:
Integrate both sides from \(x_1\) to \(x_2\):
Substitute the boundary conditions in Eq. A1b:
To ensure Eq. A12 is valid for arbitrary \(\phi (x)\), we have:
Rights and permissions
Springer Nature or its licensor (e.g. a society or other partner) holds exclusive rights to this article under a publishing agreement with the author(s) or other rightsholder(s); author self-archiving of the accepted manuscript version of this article is solely governed by the terms of such publishing agreement and applicable law.
About this article
Cite this article
Wang, Z., Battiato, I. A mineral precipitation model based on the volume of fluid method. Comput Geosci (2024). https://doi.org/10.1007/s10596-024-10280-3
Received:
Accepted:
Published:
DOI: https://doi.org/10.1007/s10596-024-10280-3