The Љdump flood completionЉ (DFC) is a mechanism conceived to inject water from a reservoir with an active aquifer into a depleted reservoir using a drilled well with marginal production or closed due to low pressure. This innovative mechanism allows for saving the costs of drilling an injector well as well as expenses associated to building additional surface facilities, and water treatment procedures.This study includes using dynamic models to evaluate scenarios linked to different DFC schemes, with the goal of increasing the net present value (NPV), while maintaining/increasing pressure in the reservoir.A multidisciplinary team developed a detailed static model to better represent within the dynamic model, the sedimentary bodies dimensions, fluids flows, and the corresponding pressure changes.The static model build used an exhaustive structural framework comprehensively coupled to the reservoir sedimentology model: facies and rock types, bodies' preferential directions, and bodies' dimensions. Before populating properties, sensitivitiess were performed to obtain an optimum grid and better represent facies lateral changes. The facies distribution model was created from the discrete curve of facies proportionality and using bodies dimensions defined in the sedimentology model. The netgross model was based on Vshale/porosity cutoffs. The porosity and NetGross characterizations were generated based on the facies modeling, and using the Sequential Gaussian Simulation (SGS) technique. The P50 of the stochastic simulations was used to establish the OOIP value. The resulting static model was input into a black oil simulator to history match production and pressure, and obtaining a base case for prediction purposes. Subsequently, the sensitiy of the reservoir performance on most significant paramters, i.e. water injection rate, bottom-hole pressure, and number and location of injector wells, was analysed. The procedure was assisted by an optimization simulation tool to obtain optimum values of net present value (NPV). The final result was considered the most optimium injection pattern applicable to the current reservoir conditions. Methodology and modeling techniques applied in this study can easily be extended to reservoirs in the basin with similar features.
The approach to the implementation of this model is supported by the integration of different disciplines as Geosciences (Geophysics, Geology, Stratigraphy, Sedimentology, Petrophysics and Geostatistics) and Reservoir Engineering; through the conformation of a multidisciplinary team with holistic vision and focusing on the Integrated Asset Management concepts in order to optimize the reservoir life cycle and its performance.The objective of this study was to evaluate by numerical simulation different scenarios in the Lower U reservoir of the Napo formation in Culebra and Yulebra fields East Basin of Ecuador. With the purpose of increasing drainage and heavy oil reserves recovery; simulation runs include drilling of directional and horizontal wells.As per heavy oil pressure maintenance and enhanced recovery; simulation includes water injection with different viscosity values (polymer simulation).As a remarkable aspect of the dynamic model generation and its evaluation through the different sub -models as components; additionally the use of an advanced simulation tool that allowed scenarios optimization helping to achieve the higher oil recoveries values with the less number of wells to be drilled.Results show the possibility of increasing the current oil recoverable reserves in 34 MMBLS by drilling 13 directional and 6 horizontal wells; besides with water injection (polymer solution) of 2 cps viscosity leads to increase the conventional scenario recovery over of 43 MM barrels of oil; it is due to the remarkable improvement in mobility ratio generating a greater sweep efficiency with an increase in oil production and a significant impact on the recovery factor (FR).In fact the total implementation of the business plan result in this study increase more than 100%, 77 MM Oil Bls (140MM compare to the official reserves of 63 MM) Also the methodology and techniques employed in this project can be used for any reservoir in the Ecuadorian basin even more too any heavy oil reservoir worldwide that have similar properties such us: thickness, depth and viscosity.
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