Incidence and Importance of Tectonics and Natural Fluid Migration on Reservoir Evolution in Foreland Fold-And-Thrust Belts

Integrated structural-petrographic-magnetic-basin modeling case studies in numerous foreland fold-and-thrust belts provided key information on the critical parameters and processes controlling reservoir evolution from the end of the passive margin phase to the post-orogenic collapse of the tectonic pile. Fluid-rock interactions in reservoir rocks are intensified during tectonic events, as tectonic compaction in the foreland and development and re-opening of fracture systems in the allochthon help remobilizing basinal fluids, to squeeze-out host-rock buffered fluids as well as to reinject exotic fluids in reservoir sandstone or carbonate layers. For instance, quartz cementation in Sub-Andean foothills is dominantly controlled by Layer Parallel Shortening (LPS/tectonic compaction) in the footwall of frontal thrusts. LPS can also be inferred to cause in situ recrystallisation of mesodolomite in the Canadian Cordilleran Foreland Belt. In contrast, secondary hydrothermal dolomitization of limestone strata usually accounts for lateral migration in stratigraphic conduits in the foreland and for vertical migration of mineralizing fluids in open fractures in the allochthon, respectively. Alternatively, vuggy porosity observed in allochthonous carbonate strata in the North American Cordillera can also be interpreted to result from reservoir cooling operating in a dominantly closed fluid system during tectonic uplift and coeval erosion. Basin models can provide realistic estimates of burial-temperature history that can be compared to paleo-thermometers, such as fluid inclusions or stable isotopes, and thus provide a means to determine the relative age of cementation or dissolution episodes. Basin models can also provide fluid velocities, that can be subsequently used as critical constraints on diagenetic models at reservoir scale. Natural fluid-rock interactions induced by exotic tectonic fluids are short, no longer than one million years. As such, they constitute very good models of the long term effects of CO2 and H2 S injection and storage in natural reservoirs. The integrated quantitative appraisal approach proposed here for petroleum evaluation and reservoir prediction, also provides useful information on the overall changes in fluid flow regime and fluid velocities trough time in natural open systems, that should be used as regional boundary conditions for future reservoir storage and monitoring of acid gases in natural reservoirs.

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