A Generalized Well-Management Scheme for Reservoir Simulation

TLDR

Oil production in the two full‑field models is constrained by water, gas, and liquid handling limits at field and flow‑station levels, with gas production further limited by injectivity and gas handling capacities. The scheme combines reservoir performance, wellbore hydraulics, surface facility constraints, and lift‑gas allocation, predicts well performance from current hydraulics and reservoir conditions, and is implemented in a black‑oil simulator via separable programming and a simplex algorithm. Applied to two full‑field models, the scheme increased oil production by 3–9% over a 12‑year forecast.

Abstract

Summary A new generalized well-management scheme has been formulated to maximize oil production under multiple facility constraints. The scheme integrates reservoir performance, wellbore hydraulics, surface facility constraints, and lift-gas allocation to maximize oil production. It predicts well performance on the basis of up-to-date hydraulics and reservoir conditions. The scheme has been implemented in a black oil simulator by using separable programming and simplex algorithm. This production optimization scheme has been applied to two full-field models. The oil production of these two full-field models is limited by water, gas, and liquid handling limits at both field and flow-station levels. The gas production is limited by injectivity and gas handling limits. For a 12-year production forecast, the new scheme increased oil production by 3 to 9%.