Multi-scale pore-network modelling of WAG in carbonates

Research output: Contribution to conferenceOther

Abstract

Carbonate reservoirs have textural heterogeneities at all length-scales (triple porosity: pore-vug-fracture) and tend to be mixed- to oil-wet. The choice of an enhanced oil recovery process and the prediction of oil recovery require a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks, as well as 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, such as during water-alternating-gas injection (WAG). We have recently developed a method for integration of pore-networks derived from micro CT images at different length-scales, thus capturing pore structures from different types of porosity. The network integration method honours the connectivity between different pore types, including micro-fractures, and their spatial distribution. In this work, we use these multi-scale networks as input for our three-phase flow pore-network model, which comprises a novel thermodynamic criterion for formation and collapse of oil layers that strongly depends on the fluid spreading behaviour and the rock wettability. The criterion affects in particular the oil relative permeability at low oil saturations and the accurate prediction of residual oil saturations. We generate three-phase flow functions for gas injection and WAG from networks with carbonate pore geometries and connectivities and we demonstrate the impact on residual saturations of the different types of porosity and the interaction with different realistic wettability scenarios. We also show that the network generated three-phase flow relative permeabilities are distinctly different from traditional models, such as Stone’s. The flow functions will be used in a heterogeneous carbonate reservoir model and to demonstrate their impact on the sweep efficiency.
Original languageEnglish
Publication statusPublished - Apr 2013
Event17th European Symposium on Improved Oil Recovery 2013 - St Petersburg, Russian Federation
Duration: 16 Apr 201318 Apr 2013

Conference

Conference17th European Symposium on Improved Oil Recovery 2013
Abbreviated titleIOR 2013
CountryRussian Federation
CitySt Petersburg
Period16/04/1318/04/13

Fingerprint

carbonate
three phase flow
oil
gas
modeling
porosity
wettability
water
saturation
permeability
connectivity
fluid
enhanced oil recovery
capillary pressure
prediction
carbonate rock
fluid flow
thermodynamics
spatial distribution
geometry

Cite this

Maier, C., Jiang, Z., Al-Dhahli, A., Van Dijke, M. I. J., Geiger, S., Couples, G. D., & Ma, J. (2013). Multi-scale pore-network modelling of WAG in carbonates. 17th European Symposium on Improved Oil Recovery 2013, St Petersburg, Russian Federation.
@conference{9dff3eb04c4f48be889fe34ed90ab8ee,
title = "Multi-scale pore-network modelling of WAG in carbonates",
abstract = "Carbonate reservoirs have textural heterogeneities at all length-scales (triple porosity: pore-vug-fracture) and tend to be mixed- to oil-wet. The choice of an enhanced oil recovery process and the prediction of oil recovery require a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks, as well as 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, such as during water-alternating-gas injection (WAG). We have recently developed a method for integration of pore-networks derived from micro CT images at different length-scales, thus capturing pore structures from different types of porosity. The network integration method honours the connectivity between different pore types, including micro-fractures, and their spatial distribution. In this work, we use these multi-scale networks as input for our three-phase flow pore-network model, which comprises a novel thermodynamic criterion for formation and collapse of oil layers that strongly depends on the fluid spreading behaviour and the rock wettability. The criterion affects in particular the oil relative permeability at low oil saturations and the accurate prediction of residual oil saturations. We generate three-phase flow functions for gas injection and WAG from networks with carbonate pore geometries and connectivities and we demonstrate the impact on residual saturations of the different types of porosity and the interaction with different realistic wettability scenarios. We also show that the network generated three-phase flow relative permeabilities are distinctly different from traditional models, such as Stone’s. The flow functions will be used in a heterogeneous carbonate reservoir model and to demonstrate their impact on the sweep efficiency.",
author = "Christine Maier and Zeyun Jiang and A. Al-Dhahli and {Van Dijke}, {Marinus Izaak Jan} and Sebastian Geiger and Couples, {Gary Douglas} and Jingsheng Ma",
year = "2013",
month = "4",
language = "English",
note = "17th European Symposium on Improved Oil Recovery 2013, IOR 2013 ; Conference date: 16-04-2013 Through 18-04-2013",

}

Maier, C, Jiang, Z, Al-Dhahli, A, Van Dijke, MIJ, Geiger, S, Couples, GD & Ma, J 2013, 'Multi-scale pore-network modelling of WAG in carbonates', 17th European Symposium on Improved Oil Recovery 2013, St Petersburg, Russian Federation, 16/04/13 - 18/04/13.

Multi-scale pore-network modelling of WAG in carbonates. / Maier, Christine; Jiang, Zeyun; Al-Dhahli, A.; Van Dijke, Marinus Izaak Jan; Geiger, Sebastian; Couples, Gary Douglas; Ma, Jingsheng.

2013. 17th European Symposium on Improved Oil Recovery 2013, St Petersburg, Russian Federation.

Research output: Contribution to conferenceOther

TY - CONF

T1 - Multi-scale pore-network modelling of WAG in carbonates

AU - Maier, Christine

AU - Jiang, Zeyun

AU - Al-Dhahli, A.

AU - Van Dijke, Marinus Izaak Jan

AU - Geiger, Sebastian

AU - Couples, Gary Douglas

AU - Ma, Jingsheng

PY - 2013/4

Y1 - 2013/4

N2 - Carbonate reservoirs have textural heterogeneities at all length-scales (triple porosity: pore-vug-fracture) and tend to be mixed- to oil-wet. The choice of an enhanced oil recovery process and the prediction of oil recovery require a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks, as well as 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, such as during water-alternating-gas injection (WAG). We have recently developed a method for integration of pore-networks derived from micro CT images at different length-scales, thus capturing pore structures from different types of porosity. The network integration method honours the connectivity between different pore types, including micro-fractures, and their spatial distribution. In this work, we use these multi-scale networks as input for our three-phase flow pore-network model, which comprises a novel thermodynamic criterion for formation and collapse of oil layers that strongly depends on the fluid spreading behaviour and the rock wettability. The criterion affects in particular the oil relative permeability at low oil saturations and the accurate prediction of residual oil saturations. We generate three-phase flow functions for gas injection and WAG from networks with carbonate pore geometries and connectivities and we demonstrate the impact on residual saturations of the different types of porosity and the interaction with different realistic wettability scenarios. We also show that the network generated three-phase flow relative permeabilities are distinctly different from traditional models, such as Stone’s. The flow functions will be used in a heterogeneous carbonate reservoir model and to demonstrate their impact on the sweep efficiency.

AB - Carbonate reservoirs have textural heterogeneities at all length-scales (triple porosity: pore-vug-fracture) and tend to be mixed- to oil-wet. The choice of an enhanced oil recovery process and the prediction of oil recovery require a sound understanding of the fundamental controls on fluid flow in mixed- to oil-wet carbonate rocks, as well as 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, such as during water-alternating-gas injection (WAG). We have recently developed a method for integration of pore-networks derived from micro CT images at different length-scales, thus capturing pore structures from different types of porosity. The network integration method honours the connectivity between different pore types, including micro-fractures, and their spatial distribution. In this work, we use these multi-scale networks as input for our three-phase flow pore-network model, which comprises a novel thermodynamic criterion for formation and collapse of oil layers that strongly depends on the fluid spreading behaviour and the rock wettability. The criterion affects in particular the oil relative permeability at low oil saturations and the accurate prediction of residual oil saturations. We generate three-phase flow functions for gas injection and WAG from networks with carbonate pore geometries and connectivities and we demonstrate the impact on residual saturations of the different types of porosity and the interaction with different realistic wettability scenarios. We also show that the network generated three-phase flow relative permeabilities are distinctly different from traditional models, such as Stone’s. The flow functions will be used in a heterogeneous carbonate reservoir model and to demonstrate their impact on the sweep efficiency.

M3 - Other

ER -

Maier C, Jiang Z, Al-Dhahli A, Van Dijke MIJ, Geiger S, Couples GD et al. Multi-scale pore-network modelling of WAG in carbonates. 2013. 17th European Symposium on Improved Oil Recovery 2013, St Petersburg, Russian Federation.