Journal
INTERNATIONAL JOURNAL OF GREENHOUSE GAS CONTROL
Volume 45, Issue -, Pages 70-85Publisher
ELSEVIER SCI LTD
DOI: 10.1016/j.ijggc.2015.12.013
Keywords
CO2 sequestration; Multiphase simulation; Relative permeability; Capillary pressure; Multifluid constitutive relations
Categories
Funding
- FutureGen 2.0 program [DE-FE0001882]
- FutureGen Industrial Alliance
- Battelle Memorial Institute for the Department of Energy (DOE) [DE-AC06-76RLO 1830]
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Constitutive relations between relative permeability (k(r)), fluid saturation (S), and capillary pressure (P-c) determine to a large extent the distribution of brine and supercritical CO2 (scCO(2)) during subsurface injection operations. Published numerical multiphase simulations for brine-scCO(2) systems so far have primarily used four k(r) - S - P-c models. For the S - P-c relations, either the Brooks-Corey (BC) or Van Genuchten (VG) equations are used. The k(r) - S relations are based on Mualem, Burdine, or Corey equations without the consideration of experimental data. Recently, two additional models have been proposed where the k(r) - S relations are obtained by fitting to experimental data using either an endpoint power law or a modified Corey approach. The six models were tested using data from four well-characterized sandstones (Berea, Paaratte, Tuscaloosa, Mt. Simon) for two radial injection test cases. The results show a large variation in plume extent and saturation distribution for each of the sandstones, depending on the used model. The VG-Mualem model predicts plumes that are considerably larger than for the other models due to the overestimation of the gas relative permeability. The predicted plume sizes are the smallest for the VG-Corey model due to the underestimation of the aqueous phase relative permeability. Of the four models that do not use fits to experimental relative permeability data, the hybrid model with Mualem aqueous phase and Corey gas phase relative permeabilities provide the best fits to the experimental data and produce results close to the model with fits to the capillary pressure and relative permeability data. The model with the endpoint power law resulted in very low, uniform gas saturations outside the dry-out zone for the Tuscaloosa sandstone, as the result of a rapidly declining aqueous phase relative permeability. This observed behavior illustrates the need to obtain reliable relative permeability relations for a potential reservoir, beyond permeability and porosity data. (C) 2015 Elsevier Ltd. All rights reserved.
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