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Abstract

Summary

This work tests a new 2D basin modelling workflow to assess the role of faults on hydrocarbon migration pathways on a well calibrated case study from Western Australia. Linking kinematic restoration to forward petroleum system modeling, this new workflow accounts for fault geometry and property evolution through time, where faults transmissivity architecture can be heterogeneous and modeled with a damaged and gouge zones. From seismic reinterpretation, a new 2D section was built in the North Perth basin, extending from the onshore to the offshore domains and cross-cutting series of normal faults and Permian to Jurassic hydrocarbon discoveries. 2D structural restoration was done within the basin modelling tool, preserving mesh deformation with basin tectonics to honour simulation constraints. A reference scenario that best fits with well calibration data was selected. Faults impact on hydrocarbon migration was tested by separately varying the gouge and damage zone thicknesses as well as the permeability and the capillary pressure of each fault. Oil and gas indications observed within Jurassic reservoirs can only be reproduced with a given range of values, showing that an accurate upscaling of faults transmissivity representing the overall network complexity and structural evolution is crucial to assess faults impact on hydrocarbon migration.

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/content/papers/10.3997/2214-4609.201700616
2017-06-12
2024-04-20

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http://instance.metastore.ingenta.com/content/papers/10.3997/2214-4609.201700616
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Fault Impact on Hydrocarbon Migration - 2D Complex Modelling of the North Perth Basin Petroleum Systems, Australia
Conference Proceedings 2017, 1 (2017); https://doi.org/10.3997/2214-4609.201700616
/content/papers/10.3997/2214-4609.201700616
/content/papers/10.3997/2214-4609.201700616
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