Three-phase pore-network modelling for mixed-wet carbonate reservoirs

    Research output: Contribution to conferenceOther

    Abstract

    Carbonate reservoirs have structural heterogeneities (triple porosity: pore-vug-fracture) and are mixed- to oilwet. The interplay of structural and wettability heterogeneities impacts the sweep efficiency and oil recovery. The choice of an IOR or EOR process and the prediction of oil recovery requires a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks and physically robust flow functions, i.e. relative permeability and capillary pressure functions. Obtaining these flow functions is a challenging task, especially when three fluid phases coexist. In this work we use pore-network modelling, a reliable and physically-based simulation tool, to predict three-phase flow functions. We have developed a new pore-scale network model for rocks with variable wettability. Unlike other models, this model comprises a novel thermodynamic criterion for formation and collapse of oil layers. The new model hence captures film/layer flow of oil adequately which impacts the oil relative permeability at low oil saturation and hence the accurate prediction of residual oil. Pore-networks extracted from pore-space reconstruction methods and CT images have been used as input for our simulations and the model comprises a constrained set of parameters that can be tuned to mimic the wetting state of a given reservoir. We have validated our model with available experimental data for a range of wettabilities. A sensitivity analysis has been carried out to investigate the dependency of relative permeabilities on layer collapse and film/layer flow under various wetting conditions. Additionally, WAG injection has been simulated with different lengths of so-called multi-displacement chains and different flood end-points. The flow functions generated by our model can be passed to the next scales (upscaling) to predict the oil recovery at the reservoir scale and we demonstrate this using a proof-of-concept study.
    Original languageEnglish
    Pages1-15
    Number of pages15
    DOIs
    Publication statusPublished - Oct 2011
    EventSPE Reservoir Characterisation and Simulation Conference and Exhibition 2011 - Abu Dhabi, Abu Dhabi, United Arab Emirates
    Duration: 9 Oct 201111 Oct 2011

    Conference

    ConferenceSPE Reservoir Characterisation and Simulation Conference and Exhibition 2011
    CountryUnited Arab Emirates
    CityAbu Dhabi
    Period9/10/1111/10/11

    Fingerprint

    Carbonates
    Wetting
    Recovery
    Rocks
    Oils
    Capillarity
    Sensitivity analysis
    Flow of fluids
    Porosity
    Acoustic waves
    Thermodynamics
    Fluids

    Cite this

    Al-Dhahli, A., Geiger, S., & van Dijke, M. I. . J. (2011). Three-phase pore-network modelling for mixed-wet carbonate reservoirs. 1-15. SPE Reservoir Characterisation and Simulation Conference and Exhibition 2011, Abu Dhabi, United Arab Emirates. https://doi.org/10.2118/147991-MS
    Al-Dhahli, A. ; Geiger, S. ; van Dijke, M. I .J. / Three-phase pore-network modelling for mixed-wet carbonate reservoirs. SPE Reservoir Characterisation and Simulation Conference and Exhibition 2011, Abu Dhabi, United Arab Emirates.15 p.
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    abstract = "Carbonate reservoirs have structural heterogeneities (triple porosity: pore-vug-fracture) and are mixed- to oilwet. The interplay of structural and wettability heterogeneities impacts the sweep efficiency and oil recovery. The choice of an IOR or EOR process and the prediction of oil recovery requires a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks and physically robust flow functions, i.e. relative permeability and capillary pressure functions. Obtaining these flow functions is a challenging task, especially when three fluid phases coexist. In this work we use pore-network modelling, a reliable and physically-based simulation tool, to predict three-phase flow functions. We have developed a new pore-scale network model for rocks with variable wettability. Unlike other models, this model comprises a novel thermodynamic criterion for formation and collapse of oil layers. The new model hence captures film/layer flow of oil adequately which impacts the oil relative permeability at low oil saturation and hence the accurate prediction of residual oil. Pore-networks extracted from pore-space reconstruction methods and CT images have been used as input for our simulations and the model comprises a constrained set of parameters that can be tuned to mimic the wetting state of a given reservoir. We have validated our model with available experimental data for a range of wettabilities. A sensitivity analysis has been carried out to investigate the dependency of relative permeabilities on layer collapse and film/layer flow under various wetting conditions. Additionally, WAG injection has been simulated with different lengths of so-called multi-displacement chains and different flood end-points. The flow functions generated by our model can be passed to the next scales (upscaling) to predict the oil recovery at the reservoir scale and we demonstrate this using a proof-of-concept study.",
    author = "A. Al-Dhahli and S. Geiger and {van Dijke}, {M. I .J.}",
    year = "2011",
    month = "10",
    doi = "10.2118/147991-MS",
    language = "English",
    pages = "1--15",
    note = "SPE Reservoir Characterisation and Simulation Conference and Exhibition 2011 ; Conference date: 09-10-2011 Through 11-10-2011",

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    Al-Dhahli, A, Geiger, S & van Dijke, MIJ 2011, 'Three-phase pore-network modelling for mixed-wet carbonate reservoirs', SPE Reservoir Characterisation and Simulation Conference and Exhibition 2011, Abu Dhabi, United Arab Emirates, 9/10/11 - 11/10/11 pp. 1-15. https://doi.org/10.2118/147991-MS

    Three-phase pore-network modelling for mixed-wet carbonate reservoirs. / Al-Dhahli, A.; Geiger, S.; van Dijke, M. I .J.

    2011. 1-15 SPE Reservoir Characterisation and Simulation Conference and Exhibition 2011, Abu Dhabi, United Arab Emirates.

    Research output: Contribution to conferenceOther

    TY - CONF

    T1 - Three-phase pore-network modelling for mixed-wet carbonate reservoirs

    AU - Al-Dhahli, A.

    AU - Geiger, S.

    AU - van Dijke, M. I .J.

    PY - 2011/10

    Y1 - 2011/10

    N2 - Carbonate reservoirs have structural heterogeneities (triple porosity: pore-vug-fracture) and are mixed- to oilwet. The interplay of structural and wettability heterogeneities impacts the sweep efficiency and oil recovery. The choice of an IOR or EOR process and the prediction of oil recovery requires a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks and physically robust flow functions, i.e. relative permeability and capillary pressure functions. Obtaining these flow functions is a challenging task, especially when three fluid phases coexist. In this work we use pore-network modelling, a reliable and physically-based simulation tool, to predict three-phase flow functions. We have developed a new pore-scale network model for rocks with variable wettability. Unlike other models, this model comprises a novel thermodynamic criterion for formation and collapse of oil layers. The new model hence captures film/layer flow of oil adequately which impacts the oil relative permeability at low oil saturation and hence the accurate prediction of residual oil. Pore-networks extracted from pore-space reconstruction methods and CT images have been used as input for our simulations and the model comprises a constrained set of parameters that can be tuned to mimic the wetting state of a given reservoir. We have validated our model with available experimental data for a range of wettabilities. A sensitivity analysis has been carried out to investigate the dependency of relative permeabilities on layer collapse and film/layer flow under various wetting conditions. Additionally, WAG injection has been simulated with different lengths of so-called multi-displacement chains and different flood end-points. The flow functions generated by our model can be passed to the next scales (upscaling) to predict the oil recovery at the reservoir scale and we demonstrate this using a proof-of-concept study.

    AB - Carbonate reservoirs have structural heterogeneities (triple porosity: pore-vug-fracture) and are mixed- to oilwet. The interplay of structural and wettability heterogeneities impacts the sweep efficiency and oil recovery. The choice of an IOR or EOR process and the prediction of oil recovery requires a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks and physically robust flow functions, i.e. relative permeability and capillary pressure functions. Obtaining these flow functions is a challenging task, especially when three fluid phases coexist. In this work we use pore-network modelling, a reliable and physically-based simulation tool, to predict three-phase flow functions. We have developed a new pore-scale network model for rocks with variable wettability. Unlike other models, this model comprises a novel thermodynamic criterion for formation and collapse of oil layers. The new model hence captures film/layer flow of oil adequately which impacts the oil relative permeability at low oil saturation and hence the accurate prediction of residual oil. Pore-networks extracted from pore-space reconstruction methods and CT images have been used as input for our simulations and the model comprises a constrained set of parameters that can be tuned to mimic the wetting state of a given reservoir. We have validated our model with available experimental data for a range of wettabilities. A sensitivity analysis has been carried out to investigate the dependency of relative permeabilities on layer collapse and film/layer flow under various wetting conditions. Additionally, WAG injection has been simulated with different lengths of so-called multi-displacement chains and different flood end-points. The flow functions generated by our model can be passed to the next scales (upscaling) to predict the oil recovery at the reservoir scale and we demonstrate this using a proof-of-concept study.

    U2 - 10.2118/147991-MS

    DO - 10.2118/147991-MS

    M3 - Other

    SP - 1

    EP - 15

    ER -

    Al-Dhahli A, Geiger S, van Dijke MIJ. Three-phase pore-network modelling for mixed-wet carbonate reservoirs. 2011. SPE Reservoir Characterisation and Simulation Conference and Exhibition 2011, Abu Dhabi, United Arab Emirates. https://doi.org/10.2118/147991-MS