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3-D Modeling of Carbonate Reservoir Analogue Outcrops Using Camures Methodology, Sergipe Alagoas Basin (SEAL), Northeast Brazil


The use of data base from analogues outcrops of hydrocarbon reservoirs has been a common procedure to define predictive and geological models, integrating different scales to reduce uncertainty in production and exploration of buried reservoirs. CAMURES Methodology for Multi-scale Reservoir Characterization, focus the vertical and lateral variability of reservoir heterogeneities in order to structure 3D Geological Model, aiming to spatial characterization of diagenetic faciological heterogeneities. CAMURES is developed on outcrops data acquisition with description of facies, associated to logs, 3D digital image (Laser Scanner-Lidar) and sampling collected from interest zones, to perform petrographic and petrophysic analysis. This multiscale approach aims to apply different scales of characterization in analogue outcrops related to buried intervals of the same stratigraphy unit in the same basin and in similar reservoir from another Brazilian coastal basin. For implementation of this methodology, 3 quarries were selected representing deposits of calcarenite (Mata de São José-Riachuelo Formation), calcilutite (Sá-Cotinguiba Formation) and coquina (Intercement-Morro do Chaves Formation), of SEAL Basin. In order to create geological models, procedures of workflow management were performed, covering: confection of lithological logs, Gamma Ray logs, imaging with Laser Scanner, petrographic and petrophysical characterization of samples. The modeling was separated by zones, conditioned to well data containing facies information, layers orientation, as well as average geometry of facies bodies 3D interpreted from point cloud (Laser Scanner) and field data. Petrophysical modeling was conditioned to facies modeling and compared with the model analyzed in microscale. With stratigraphic markers, tracked points cloud and directions and inclinations of layers, the surfaces of 3D model modeling block were created allowing the fully geometry visualization of outcrop stratigraphic surfaces. Zones of high porosity were attributed to Grainstone facies, with average porosities of 21.005% and 20.73%. The integration of multi-scale data in 3D geological modeling software allowed the recognition of heterogeneities responsible for controlling the fluids flow in reservoirs, as well as the compositional attributes of the studied outcrops analogues. All 3D geological models were generated in powerful modeling software using benefits of workflow management mentioned above.