Methods and Systems for Calculating and Evaluating Value of Information for Reservoir Fluid Models Derived from DFA Tool Data

摘要

A method for deriving VOI for a hydrocarbon-bearing reservoir fluid model based on DFA data (“true fluid model”) versus an “incorrect fluid model” includes calculating first, second and third objective functions that are based on NPV(s) of simulated production by a reservoir simulator with different configurations. For the first objective function, the simulator is configured with the incorrect fluid model and control variables that are optimized to derive a first group of control variable values. For the second objective function, the simulator is configured with the true fluid model and the first group of control variable values. For the third objective function, the simulator is configured with the true fluid model and control variables that are optimized to identify a second group of control variable values. The objective functions can be deterministic, or can include statistics that account for uncertainty. A visualization of such results with uncertainty is also described.

主权项

1. A method of deriving information that characterizes value of a hydrocarbon-bearing reservoir fluid model based on downhole fluid sampling and analysis operations, the method comprising:
i) providing or deriving a first fluid model that describes properties of the reservoir fluid as a function of location within the reservoir of interest, wherein the first fluid model is based on downhole fluid sampling and analysis operations; ii) providing or deriving a second fluid model that describes properties of the reservoir fluid as a function of location within the reservoir of interest, wherein the second fluid model is based on fluid sampling and analysis operations that are different from the downhole fluid sampling and analysis operations from which the first fluid model is based; iii) using a reservoir simulator configured with the second fluid model of ii) and a set of control variables, to simulate production of reservoir fluids from the reservoir of interest, and calculating at least one net present value of fluid production simulated by the reservoir simulator; iv) deriving optimal values for the set of control variables of iii) by maximizing a first objective function that is based on at least one net present value of the reservoir fluid production simulated by the reservoir simulator in iii); and v) using the reservoir simulator configured with the first fluid model and the optimal values of the set of control variables as derived in iv), to simulate production of reservoir fluids from the reservoir of interest, and calculating at least one net present value of reservoir fluid production simulated by the reservoir simulator; and vi) performing calculations involving a second objective function that is based on at least one net present value of reservoir fluid production simulated by the reservoir simulator in v) in order to derive information that characterizes value of the first fluid model.