We discuss the application of the new open-source Rapid Reservoir Modelling software (RRM) to create a suite of 3D reservoir models of a complex carbonate formation where each model is increasingly more refined such that progressively more small-scale geological structures are preserved. Using flow diagnostics we then calculate key metrics for the dynamic reservoir behaviour to quantify the similarities and dissimilarities of the flow behaviour across the different models. This analysis allows us to identify at which scale geological heterogeneities need to be resolved in the reservoir model to capture the essential flow behaviours. The workflow presented in this study hence allows us to efficiently and effectively test different geological concepts and analyse how multi-scale geological heterogeneities that may need to be represented in a reservoir model impact the predicted dynamic response, so as to design more reliable and robust reservoir models for a broad range of geoenergy applications.

This work presents a new open access carbonate reservoir case study that uniquely considers the majoruncertainties inherent to carbonate reservoirs using one of the most prolific aggradational parasequencecarbonate formation sets in the U.A.E., the Upper Kharaib Member (Early Cretaceous), as an analogue. Theensemble considers a range of interpretational scenarios and geomodelling techniques to capture the maincomponents of its reservoir architecture, stratal geometries, facies, pore systems, diagenetic overprints andwettability variations across its shelf-To-basin profile. Fully anonymized data from 43 wells across 22 fields in the Bab Basin in the U.A.E from different geo-depositional settings and height above the free water level (FWL) was used. The data comprises of a fullsuite of open-hole logs and core data which has been anonymized, rescaled, repositioned and structurallydeformed; FWLs were normalized and the entire model was placed in a unique coordinate system. Theresultant static and dynamic models(s) capture the geological setting and reservoir heterogeneities ofselected fields but now at a manageable scale. Synthetic production data has been generated by adding wellsto an undisclosed -truth case- model to obtain field-wide and well-by-well production data (oil, gas, andwater rates, bottom-hole pressures etc.) from simulation runs. The original oil in place (OOIP) and reserves that have been computed from these models are syntheticand unique. Here we present an initial field development plan and corresponding reservoir simulations thatshowcase the heterogeneity inherent to the model and demonstrate the variability of the flow and storagecapacity of the different reservoir architectures found in and around the Bab Basin. This is an exampleapplication of how we can use synthetic production data to improve our understanding of flow behavioursin carbonates. The novelty of our work is the provision of a unique open access dataset which enables reproduciblescience in the field of reservoir characterisation and simulation, and helps training new generations ofgeoscientists and reservoir engineers in the art of characterising, simulating and predicting the reservoirperformance of carbonate reservoirs under different recovery processes.

This work presents a new open access carbonate reservoir case study that uniquely considers the major uncertainties inherent to carbonate reservoirs using one of the most prolific aggradational parasequence carbonate formation sets in the U.A.E., the Upper Kharaib Member (Early Cretaceous), as an analogue. The ensemble considers a range of interpretational scenarios and geomodelling techniques to capture the main components of its reservoir architecture, stratal geometries, facies, pore systems, diagenetic overprints and wettability variations across its shelf-to-basin profile. Fully anonymized data from 43 wells across 22 fields in the Bab Basin in the U.A.E from different geodepositional settings and height above the free water level (FWL) was used. The data comprises of a full suite of open-hole logs and core data which has been anonymized, rescaled, repositioned and structurally deformed; FWLs were normalized and the entire model was placed in a unique coordinate system. The resultant static and dynamic models(s) capture the geological setting and reservoir heterogeneities of selected fields but now at a manageable scale. Synthetic production data has been generated by adding wells to an undisclosed 'truth case' model to obtain field-wide and well-by-well production data (oil, gas, and water rates, bottom-hole pressures etc.) from simulation runs. The original oil in place (OOIP) and reserves that have been computed from these models are synthetic and unique. Here we present an initial field development plan and corresponding reservoir simulations that showcase the heterogeneity inherent to the model and demonstrate the variability of the flow and storage capacity of the different reservoir architectures found in and around the Bab Basin. This is an example application of how we can use synthetic production data to improve our understanding of flow behaviours in carbonates. The novelty of our work is the provision of a unique open access dataset which enables reproducible science in the field of reservoir characterisation and simulation, and helps training new generations of geoscientists and reservoir engineers in the art of characterising, simulating and predicting the reservoir performance of carbonate reservoirs under different recovery processes.

This work presents a new open access carbonate reservoir case study that uniquely considers the major uncertainties inherent to carbonate reservoirs using one of the most prolific aggradational parasequence carbonate formation set in the U.A.E; the Late Barremian Upper Kharaib Mb. as an analogue. The ensemble considers a range of interpretational scenarios and geomodelling techniques to capture the main components of its reservoir architectures, stratal geometries, facies, pore systems, diagenetic overprints and wettability variations across its platform-to-basin profile. Fully anonymized data from 43 wells across 22 fields in the Bab Basin, U.A.E from different geo-depositional positions and height above FWL’s (specified to capture multiple structural positions) within an area of 36,000 km2 was used. The data comprises of a full suite of open hole logs and core data which has been anonymized, rescaled, repositioned and structurally deformed; FWL’s were normalized and the entire model was placed in a unique coordinate system. Our petrophysical model captures the geological setting and reservoir heterogeneities of selected fields but now at a manageable scale. The novelty of this work has been to create semi-synthetic open access carbonate reservoir models which enable the geoscience and reservoir engineering community to analyse, study and test number of cases related to new numerical algorithms for reservoir characterisation, reservoir simulation, uncertainty quantification, robust optimization and machine learning. The value of this study is also to expose a model and a dataset to the reservoir simulation engineers so they can explore the impact of different fluid flow physics on sweep and recovery across multiple carbonate reservoir architectures with diverse lateral and vertical rock and fluid complexities – all of which can be history-matched against a ‘truth case’.