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Well-data-based discrete fracture and matrix modelling and flow-based upscaling of multilayer carbonate reservoir horizons

By
Caroline Milliotte
Caroline Milliotte
1
NFR Studies GmbH, Hofer-Leitinger, Geidorfgürtel 20, 8010 Graz, Austria
2
Present Address: Thermo Fisher Scientific, 73 Northbourne Avenue, Canberra ACT 2600, Australia
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Sima Jonoud
Sima Jonoud
3
Reservoir Technology Group on Carbonates, Statoil ASA, Sandsliveien 90, 5020 Bergen, Norway
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Ole Petter Wennberg
Ole Petter Wennberg
3
Reservoir Technology Group on Carbonates, Statoil ASA, Sandsliveien 90, 5020 Bergen, Norway
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Stephan K. Matthäi
Stephan K. Matthäi
4
Institute of Reservoir Engineering, Department of Mineral Resources & Petroleum Engineering, Montanuniversitaet Leoben, Max Tendler Strasse 4, 8700 Leoben, Austria
5
Present Address: Department of Infrastructure Engineering, University of Melbourne, Melbourne, VIC 3010, Australia
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Alexandra Jurkiw
Alexandra Jurkiw
3
Reservoir Technology Group on Carbonates, Statoil ASA, Sandsliveien 90, 5020 Bergen, Norway
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Lukas Mosser
Lukas Mosser
4
Institute of Reservoir Engineering, Department of Mineral Resources & Petroleum Engineering, Montanuniversitaet Leoben, Max Tendler Strasse 4, 8700 Leoben, Austria
6
Present Address: Department of Earth Science and Engineering, South Kensington Campus, Imperial College London, Royal School of Mines, Prince Consort Rd, Kensington, London SW7 2BP, United Kingdom
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Published:
January 01, 2018

Abstract

Discrete fracture and matrix (DFM) homogenization, simultaneously capturing reservoir layers and contained fractures, is an alternative to discrete fracture network (DFN) upscaling. Here, the DFM approach was applied to a fractured carbonate reservoir. Honouring geostatistical data from well logs, near-well multilayer reservoir models were constructed and analysed. Fracture aperture variations were modelled with a new semi-analytical model including a special treatment of layer-restricted fractures. Important results concern both pre-processing of stochastically generated DFMs for finite-element meshing, and the ensemble permeability values obtained by numerical homogenization of single v. multilayer models, respectively. Upscaling by volume averaging of vertically stacked single-layer DFMs results only in a fraction of the equivalent horizontal permeability that is obtained by homogenization of the multilayer models. Inspection of the flow patterns shows that this discrepancy arises because many fractures contact each other at layer boundaries fostering cross-flow. This effect is further enhanced where fractures intersect multiple layers. Compared to earlier DFN models for this reservoir, the DFM-derived fracture and matrix ensemble permeabilities are up to four times higher, highlighting how important it is to include the rock matrix into equivalent permeability calculations.

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Contents

Geological Society, London, Special Publications

Subseismic-Scale Reservoir Deformation

M. Ashton
M. Ashton
Badley Ashton America Inc., USA
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S. J. Dee
S. J. Dee
BP Exploration and Operating Company Limited, UK
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O. P. Wennberg
O. P. Wennberg
Statoil, Norway
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The Geological Society of London
Volume
459
ISBN electronic:
9781786203403
Publication date:
January 01, 2018

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