A Generalized Well Management Scheme for Reservoir Simulation
- W.Y. Fang (Arco Exploration and Production Technology) | K.K. Lo (Arco Alaska Inc.)
- Document ID
- Society of Petroleum Engineers
- SPE Reservoir Engineering
- Publication Date
- May 1996
- Document Type
- Journal Paper
- 116 - 120
- 1996. Society of Petroleum Engineers
- 5.6.9 Production Forecasting, 4.1.2 Separation and Treating, 4.1.5 Processing Equipment, 5.5 Reservoir Simulation, 3.1.6 Gas Lift, 5.4.2 Gas Injection Methods, 4.3.4 Scale, 5.2.1 Phase Behavior and PVT Measurements
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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 based on 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-tie id models is limited by water, gas and liquid handling limits at both field- and flow station-levels. The gas production is limited by injectivity as well as gas handling limits. For a 12-year production forecast on Field A, the new scheme increased oil production by 3 to 9%. For a 12-year production forecast on field B, the new scheme increased oil production by 7 to 9%.
Most reservoir simulations presented in the literature focus on the performance characteristics of petroleum reservoirs and scant attention has been given to the impact of the facility handling capacities on fluid production rates. Facility handling limits are indeed not a factor if the facility is sized to handle the fluids a field can produce for all times and the injection capacities are designed to exceed reservoir injectivity. In practice, however, this is seldom the case because of cost considerations. Even if a facility is adequately configured at field startup, because of changing economic conditions, new development opportunities or unexpected reservoir performance, the actual oil production rate of a field over time may still be limited by facility handling and injecting capacities. In any case, the evaluation of the impact of facility handling limits on field production is an important reservoir management concern in its own right, if only for assessing whether further facility expansions are economically justified.
The constraints limiting oil production vary with fields and with time. They may be the facility handling limits for water, liquid, gas and lift gas. The lift gas availability may be constrained by gas production which in turn may be limited by compression capacity.
Most well management schemes in reservoir simulators presented in the literature are formulated in an ad hoc manner and not systematically address the maximization of oil production. production optimization, some papers focused on lift gas allocation alone and others considered maximizing oil production under conditions that only apply to the field under consideration. In this paper, we attempt to formulate a well management scheme that optimizes total field oil rate under fairly general conditions with multiple facility limits. The formulation includes lift gas allocation for each well as part of the maximization problem.
Various techniques for maximizing oil production, including linear programming and nonlinear techniques, have been proposed in the literature.
|File Size||275 KB||Number of Pages||5|