| Zusammenfassung: |
Thermal history, petroleum system, structural, and tectonic constraints are...
Thermal history, petroleum system, structural, and tectonic constraints are reviewed and integrated in order to derive of a new conceptual model for the Norman Wells oil field, and a new play type for tectonically active foreland regions. The thermal history recorded by Devonian rocks suggests that the source rocks experienced peak thermal conditions in the Triassic-Jurassic, which is when oil was likely generated. After oil generation and expulsion the Canol Formation, which is an oil shale, retained a certain fraction of hydrocarbons. The shallow reservoir (650-350 m) is a Devonian carbonate bank overlain by the Canol Formation and resides within a fault block in a hanging wall position to the Norman Range thrust fault. Both reservoir and source rocks are naturally fractured and have produced high API non-biodegraded oil. Thrust faults in the region formed after the Paleocene, and a structural cross-section of the field shows that the source and reservoir rocks at Norman Wells have been exhumed by over 1 km since then. The key proposition of the exhumation model is that as Canol Formation rocks underwent thrust-driven exhumation, they crossed a ductile-brittle transition zone and fractures formed sympathetic to the thrust fault that were oriented in a dip-direction. The combination of pore overpressure and new dip-directed subvertical fractures liberated oil from the Canol Formation and allowed for up-dip oil migration. Reservoir rocks were similarly fractured and improved permeability enhanced charging and pooling of oil. GPS and seismicity data indicate that strain transfer across the northern Cordillera is a response to accretion of the Yakutat terrane along the northern Pacific margin of North America, which is also the probable driving force for foreland shortening and rock exhumation at Norman Wells.
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