Abstract
Various modeling approaches, including fully three-dimensional (3D) models and vertical-equilibrium (VE) models, have been used to study the large-scale storage of carbon dioxide (CO2) in deep saline aquifers. 3D models solve the governing flow equations in three spatial dimensions to simulate migration of CO2 and brine in the geological formation. VE models assume rapid and complete buoyant segregation of the two fluid phases, resulting in vertical pressure equilibrium and allowing closed-form integration of the governing equations in the vertical dimension. This reduction in dimensionality makes VE models computationally much more efficient, but the associated assumptions restrict the applicability of VE models to geological formations with moderate to high permeability. In the present work, we extend the VE models to simulate CO2 storage in fractured deep saline aquifers in the context of dual-continuum modeling, where fractures and rock matrix are treated as porous media continua with different permeability and porosity. The high permeability of fractures makes the VE model appropriate for the fracture domain, thereby leading to a VE dual-continuum model for the dual continua. The transfer of fluid mass between fractures and rock matrix is represented by a mass transfer function connecting the two continua, with a modified transfer function for the VE model based on vertical integration. Comparison of the new model with a 3D dual-continuum model shows that the new model provides comparable numerical results while being much more computationally efficient.
Similar content being viewed by others
References
Celia, M.A.: Geological storage of captured carbon dioxide as a large-scale carbon mitigation option. Water. Resour. Res. 53(5), 3527–3533 (2017)
International Energy Agency (IEA): Energy technology perspectives 2017. http://www.iea.org/etp2017/summary (2017). Accessed 30 January 2018
United Nations Framework Convention on Climate Change (UNFCCC): The Paris Agreement. http://unfccc.int/paris_agreement/items/9485.php (2017). Accessed 30 January 2018
Intergovernmental Panel on Climate Change (IPCC): Special report on carbon dioxide capture and storage, paper presented at Working Group III of the Intergovernmental Panel on Climate Change, 442 pp. Cambridge Univ. Press, Cambridge (2005)
Iding, M., Ringrose, P.: Evaluating the impact of fractures on the performance of the In Salah CO2 storage site. Int. J. Greenh. Gas Control 4(2), 242–248 (2010)
Verdon, J.P., Kendall, J., Stork, A.L., Chadwick, R.A., White, D.J., Bissell, R.C.: Comparison of geomechanical deformation induced by megatonne-scale CO2 storage at Sleipner, Weyburn, and In Salah. Proc. Natl. Acad. Sci. U. S. A. 110(30), E2762–E2771 (2013)
Li, C., Zhang, K., Wang, Y., Guo, C., Maggia, F.: Experimental and numerical analysis of reservoir performance for geological CO2 storage in the Ordos Basin in China. Int. J. Greenh. Gas Control 45, 216–232 (2016)
Li, X., Li, Q., Bai, B., Wei, N., Yuan, W.: The geomechanics of Shenhua carbon dioxide capture and storage (CCS) demonstration project in Ordos Basin. China. J. Rock Mech. Geotech. Eng. 8(6), 948–966 (2016)
Kazemi, H., Merrill, L.S., Porterfield, K.L., Zeman, P.R.: Numerical simulation of water–oil flow in naturally fractured reservoirs. Soc. Pet. Eng. J. 16(6), 317–326 (1976)
Azom, P.N., Javadpour, F.: Dual-continuum modeling of shale and tight gas reservoirs (SPE159584). SPE Annual Technical Conference and Exhibition, San Antonio (2012)
Festoy, S., Van Golf-Racht, T.D.: Gas gravity drainage in fractured reservoirs through new dual-continuum approach. SPE Reservoir Eng. 4(3), 271–278 (1989)
Pruess, K., Narasimhan, T.N.: A practical method for modeling fluid and heat flow in fractured porous media. Soc. Pet. Eng. J. 25(1), 14–26 (1985)
Gilman, J.R.: An efficient finite-difference method for simulating phase segregation in the matrix blocks in double-porosity reservoirs. SPE Reservoir Eng. 1(4), 403–413 (1986)
Gong, B., Karimi-Fard, M., Durlofsky, L.J.: Upscaling discrete fracture characterizations to dual-porosity, dual-permeability models for efficient simulation of flow with strong gravitational effects. SPE J. 13(1), 58–67 (2008)
van Heel, A.P., Boerrigter, P.M., van Dorp, J.J.: Thermal and hydraulic matrix-fracture interaction in dual-permeability simulation. SPE Reservoir Eva. Eng. 11(4), 735–749 (2008)
Fuentes-Cruz, G., Valko, P.P.: Revisiting the dual-porosity/dual-permeability modeling of unconventional reservoirs: the induced-interporosity flow field. SPE J. 20(1), 125–141 (2015)
Gerke, H.H., van Genuchten, M.T.: A dual-porosity model for simulating the preferential movement of water and solutes in structured porous media. Water. Resour. Res. 29(2), 305–319 (1993)
Bibby, R.: Mass transport of solutes in dual-porosity media. Water. Resour. Res. 17(4), 1075–1081 (1981)
Coppola, A., Gerke, H.H., Comegna, A., Basile, A., Comegna, V.: Dual-permeability model for flow in shrinking soil with dominant horizontal deformation. Water. Resour. Res. 48(8), W08527 (2012)
Duguid, J.O., Lee, P.C.Y.: Flow in fractured porous media. Water. Resour. Res. 13(3), 558–566 (1977)
Jarvis, N.J., Jansson, P.-E., Dik, P.E., Messing, I.: Modeling water and solute transport in marcoporous soil. I. Model description and sensitivity analysis. J. Soil Sci. 42(1), 59–70 (1991)
Vogel, T., Gerke, H.H., Zhang, R., van Genhchten, M.T.: Modeling flow and transport in a two-dimensional dual-permeability system with spatially variable hydraulic properties. J. Hydrol. 238(1–2), 78–89 (2000)
Bandilla, K.W., Celia, M.A., Birkholzer, J.T., Cihan, A., Leister, E.C.: Multiphase modeling of geologic carbon sequestration in saline aquifers. Groundwater. 53(3), 362–377 (2015)
Celia, M.A., Bachu, S., Nordbotten, J.M., Bandilla, K.W.: Status of CO2 storage in deep saline aquifers with emphasis on modeling approaches and practical simulations. Water. Resour. Res. 51(9), 6846–6892 (2015)
Nordbotten, J.M., Celia, M.A.: Similarity solutions for fluid injection into confined aquifers. J. Fluid Mech. 561, 307–327 (2006)
Hesse, M.A., Tchelepi, H.A., Cantwell, B.J., Orr, F.M.: Gravity currents in horizontal porous layers: transition from early to late self-similarity. J. Fluid Mech. 577, 363–383 (2007)
Hesse, M.A., Orr, F.M., Tchelepi, H.A.: Gravity currents with residual trapping. J. Fluid Mech. 611, 35–60 (2008)
Juanes, R., MacMinn, C., Szulczewski, M.: The footprint of the CO2 plume during carbon dioxide storage in saline aquifers: storage efficiency for capillary trapping at the basin scale. Transp. Porous Media 82(1), 19–30 (2010)
Macminn, C.W., Szulczewshi, M.L., Juanes, R.: CO2 migration in saline aquifers. Part 1. Capillary trapping under slope and groundwater flow. J. Fluid Mech. 662, 329–351 (2010)
Golding, M.J., Neufield, J.A., Hesse, M.A., Huppert, H.E.: Two-phase gravity currents in porous media. J. Fluid Mech. 678, 248–270 (2011)
Macminn, C.W., Juanes, R.: Buoyant currents arrested by convective mixing. Geophys. Res. Lett. 40(10), 2017–2022 (2013)
Zheng, Z., Guo, B., Christov, I.C., Celia, M.A., Stone, H.A.: Flow regimes for fluid injection into a confined porous medium. J. Fluid Mech. 767, 881–909 (2015)
Guo, B., Zheng, Z., Celia, M.A., Stone, H.A.: Axisymmetric flows from fluid injection into a confined porous medium. Phys. Fluids 28, 022107 (2016)
Nordbotten, J.M., Kavetski, D., Celia, M.A., Bachu, S.: Model for CO2 leakage including multiple geological layers and multiple leaky wells. Environ. Sci. Technol. 43(3), 743–749 (2009)
Celia, M.A., Nordbotten, J.M., Court, B., Dobossy, M., Bachu, S.: Field-scale application of a semi-analytical model for estimation of CO2 and brine leakage along old wells. Int. J. Greenh. Gas Control 5(2), 257–269 (2011)
Gasda, S.E., Nordbotten, J.M., Celia, M.A.: Vertical equilibrium with sub-scale analytical methods for geological CO2 sequestration. Comput. Geosci. 13, 469–481 (2009)
Geiger, S., Emmanuel, S.: Non-fourier thermal transport in fractured geological media. Water. Resour. Res. 46(7), W07504 (2010)
Gasda, S.E., Nordbotten, J.M., Celia, J.M.: Vertically-averaged approaches for CO2 migration with solubility trapping. Water. Resour. Res. 47(5), W05528 (2011)
Bandilla, K.W., Celia, M.A., Elliot, T.R., Person, M., Ellet, K.M., Rupp, J.A., Gable, C., Zhang, Y.: Modeling carbon sequestration in the Illinois Basin using a vertically-integrated approach. Comput. Vis. Sci. 15(1), 39–51 (2012)
Lake, L.W.: Enhanced oil recovery. Prentice-Hall, Upper Saddle River (1989)
Yortsos, Y.C.: A theoretical analysis of vertical flow equilibrium. Transp. Porous Media 18(2), 107–129 (1995)
de Loubens, R., Ramakrishnan, T.S.: Analysis and computation of gravity-induced migration in porous media. J. Fluid Mech. 675, 60–86 (2011)
Nordbotten, J.M., Dahle, H.K.: Impact of the capillary fringe in vertically integrated models for CO2 storage. Water. Resour. Res. 47(2), W02537 (2011)
Nordbotten, J.M., Celia, M.A.: Geological Storage of CO2: Modeling Approaches for Large-Scale Simulation. Wiley, Hoboken (2012)
Hao, Y., Fu, P., Carrigan, C.R.: Application of a dual-continuum model for simulation of fluid flow and heat transfer in fractured geothermal reservoirs (SGP-TR-198). Proceedings, Thirty-Eighth Workshop on Geothermal Reservoir Engineering, Stanford University, Stanford, California USA (2013)
Warren, J.E., Root, P.J.: The behavior of naturally fractured reservoirs. Soc. Pet. Eng. J. 3(3), 245–255 (1963)
Gilman, J.R., Kazemi, H.: Improved calculations for viscous and gravity displacement in matrix blocks in dual-porosity simulators. J. Pet. Technol. 40(1), 60–70 (1988)
Barenblatt, G.I., Zheltov, I.P., Kochina, I.N.: Basic concepts in the theory of seepage of homogeneous liquids in fissured rocks. PMM (Sov. Appl. Math. Mech.) 24(5), 852–864 (1960)
Ramirez, B., Kazemi, H., Al-Kobaisi, M., Ozkan, E., Atan, S.: A critical review for proper use of water/oil/gas transfer functions in dual-porosity naturally fractured reservoirs: part I. SPE Reservoir Eva. Eng. 12(2), 200–210 (2009)
Al-Kobaisi, M., Kazemi, H., Ramirez, B., Ozkan, E., Atan, S.: A critical review for proper use of water/oil/gas transfer functions in dual-porosity naturally fractured reservoirs: part II. SPE Reservoir Eva. Eng. 12(2), 211–217 (2009)
March, R., Doster, F., Geiger, S.: Assessment of CO2 storage potential in naturally fractured reservoirs with dual-porosity models. Water Resour. Res. 54(3), 1650–1668 (2018)
Brooks, R.H., Corey, A.T.: Hydraulic properties of porous media Hydrology paper, vol. 3. Colorado State University, Fort Collins (1964)
Court, B., Bandilla, K.W., Celia, M.A., Janzen, A., Dobossy, M., Nordbotten, J.M.: Applicability of vertical-equilibrium and sharp-interface assumptions in CO2 sequestration modeling. Int. J. Greenh. Gas Control 10, 134–147 (2012)
Lang, P.S., Paluszny, A., Zimmerman, R.W.: Permeability tensor of three-dimensional fractured porous rock and a comparison to trace map predictions. J. Geophys. Res. Solid Earth 119(8), 6288–6307 (2014)
Faybishenko, B., Benson, S. M., Gale, J. E.: Dynamics of Fluids and Transport in Complex Fractured-Porous Systems. AGU & Wiley, Hoboken (2015)
March, R., Elder, H., Doster, F., Geiger, S.: Accurate dual-porosity modeling of CO2 storage in fractured reservoirs (SPE-182646-MS). SPE Reservoir Simulation Conference, Montgomery, Texas, USA (2017)
Balogun, A., Kazemi, H., Ozkan, E., Al-Kobaisi, M., Ramirez, B.: Verification and proper use of water-oil transfer function for dual-porosity and dual-permeability reservoirs. SPE Reservoir Eva. Eng. 12(2), 189–199 (2009)
Fung, L.S.: Simulation of block-to-block processes in naturally fractured reservoirs. SPE Reservoir Eng 6(4), 477–484 (1991)
Becker, B., Guo, B., Bandilla, K.W., Celia, M.A., Flemisch, B., Helmig, R.: A pseudo-vertical equilibrium model for slow gravity drainage dynamics. Water. Resour. Res. 53(12), 10491–10507 (2017)
Guo, B., Bandilla, K.W., Doster, F., Keilegavlen, E., Celia, M.A.: A vertically integrated model with vertical dynamics for CO2 storage. Water. Resour. Res. 50(8), 6269–6284 (2014)
Acknowledgments
This work was supported in part by the Carbon Mitigation Initiative at Princeton University and by the U.S. Department of Energy (DOE) National Energy Technology Laboratory (NETL) under Grant Number DE-FE0023323. This project is managed and administered by Princeton University and funded by DOE/NETL and cost-sharing partners. Neither the U.S. Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the U.S. Government or any agency thereof. The views and opinions of the authors expressed herein do not necessarily state or reflect those of the U.S. Government or any agency thereof.
Author information
Authors and Affiliations
Corresponding author
Additional information
Publisher’s note
Springer Nature remains neutral with regard to jurisdictional claims in published maps and institutional affiliations.
Rights and permissions
About this article
Cite this article
Tao, Y., Guo, B., Bandilla, K.W. et al. Vertically integrated dual-continuum models for CO2 injection in fractured geological formations. Comput Geosci 23, 273–284 (2019). https://doi.org/10.1007/s10596-018-9805-x
Received:
Accepted:
Published:
Issue Date:
DOI: https://doi.org/10.1007/s10596-018-9805-x