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    Compositional simulation model for carbon dioxide flooding with improved fluid trapping, A

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    A compositional simulation model ...
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    Author
    Brown, Jeffrey S.
    Advisor
    Kazemi, Hossein
    Date issued
    2014
    Date submitted
    2014
    Keywords
    hysteresis
    enhanced oil recovery
    carbon dioxide
    compositional simulation
    trapping
    reservoir simulation
    Enhanced oil recovery
    Simulation methods
    Carbon dioxide
    Oil field flooding
    Carbon sequestration
    Hysteresis
    Permeability
    
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    URI
    http://hdl.handle.net/11124/17037
    Abstract
    A new formulation for fluid trapping using a dual-media approach which includes compositional trapping and interphase mass transfer was developed, coded, and validated. This formulation does not exist in notable commercial reservoir simulators. The formulation was incorporated into a three-dimensional, three-phase, parallel compositional simulator to simulate carbon dioxide (CO2) water-alternating-gas (WAG) injection. Fluid phase trapping is both a channeling issue and a pore-scale issue. Pore-scale phase trapping is strongly related to hysteresis in the relative permeability and capillary pressure; the simulator incorporates them in a methodology consistent with these issues. New algorithms were developed to implement the CO2 solubility in water and oil and CO2 phase trapping in a way that preserves the mass balance of the oil, water, and gas phases. The new simulator was implemented using a parallel infrastructure to facilitate computationally intensive fine grid systems. For test examples, we focused on a mixed wet carbonate reservoir in the Middle East. These tests were used to evaluate the significance of various trapping scenarios. Compositional trapping, gas relative permeability hysteresis, CO2 solubility in water, and permeability heterogeneity were found to have significant impacts on oil recovery and timing, as well as CO2 storage and utilization during waterflood and CO2 WAG processes.
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