| CPC G01V 20/00 (2024.01) [G06F 30/20 (2020.01)] | 17 Claims |
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1. A method of determining an equivalent black oil model of a reservoir, the method comprising:
executing a compositional model to obtain three-dimensional pressure-volume-temperature (PVT) properties;
extracting original fluid in place and reservoir performance characteristics from the three-dimensional PVT properties, wherein the three-dimensional PVT properties are generated by:
extracting a plurality of fluid samples from a plurality of depths of the reservoir;
generating a plurality of trend equations for a plurality of components varying with depth of the reservoir;
initializing the compositional model with at least the plurality of trend equations and an Equation of State model calibrated from properties of the plurality of fluid samples;
calculating viscosity parameters from the Equation of State model; and
adjusting parameters of the Equation of State model to correlate calculated viscosity from the Equation of State model with measured viscosity of the plurality of fluid samples by modifying critical volume of C35+ components;
storing the three-dimensional PVT properties as a two-dimensional PVT table;
storing one or more grouped PVT property tables, wherein each grouped PVT property table corresponds with an area of the reservoir having similar PVT properties of the two-dimensional PVT table;
inputting the one or more grouped PVT property tables into a black oil model;
executing the black oil model to obtain estimated fluid in place and estimated reservoir performance characteristics; and
when an equivalency metric is satisfied, storing the black oil model as the equivalent black oil model, wherein the equivalency metric is satisfied when the estimated fluid in place is within defined limits of the original fluid in place, and the estimated reservoir performance characteristics are within defined limits of the reservoir performance characteristics;
when the equivalency metric is not satisfied, storing one or more re-grouped PVT property tables, inputting the one or more re-grouped PVT property tables into the black oil model, and executing the black oil model to obtain updated estimated fluid in place and updated estimated reservoir performance characteristics such that the equivalency metric is satisfied; and
controlling one or more valves of one or more wells within the reservoir according to the equivalent black oil model, accounting for composition changes and variations in fluid mobilities and in driving mechanisms.
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