Reservoir simulation

Work Flow History Matches Numerical Simulation Models of Fractured Shale Wells

This paper presents a step-by-step work flow to facilitate history matching numerical simulation models of hydraulically fractured shale wells.

Oil relative permeability (top) and gas saturation (bottom) after simulation goes below bubblepoint.
Fig. 1—Oil relative permeability (top) and gas saturation (bottom) after simulation goes below bubblepoint.
SPE 199149

This paper presents a step-by-step work flow to facilitate history matching numerical simulation models of hydraulically fractured shale wells. Sensitivity analysis simulations are performed with a coupled hydraulic fracturing, geomechanics, and reservoir simulator. The results are used to develop what the authors term “motifs” that inform the history-matching process. Using intuition from these simulations, history matching can be expedited by changing matrix permeability, fracture conductivity, matrix-pressure-dependent permeability, boundary effects, and relative permeability.

Introduction

The concept of rate transient analysis (RTA) involves the use of rate and pressure trends of producing wells to estimate properties such as permeability and fracture surface area.

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