Abstract
In this work, a multi-period nonlinear programming formulation is presented to obtain the optimal long-term oilfield production planning, based on a two-phase, one-dimensional, and Cartesian-coordinated phenomenological reservoir model. The phenomenological model contains a set of second-order partial differential equations, which are approximated by a collocation on finite element method. This CFE method prevents mathematical stability limitations due to stiffness problems, resulting in an algebraic equation system added as an optimization set of constraints. This is a significant and innovating approach as there are only a handful of similar studies in the literature that integrate phenomenological models as mathematical constraints in the optimization problem. However, these works do not solve the model using long-term production planning coupled with a simultaneous strategy. Also, formulation applied to two study cases allowed solving the optimization problem within an adequate time without requiring a high-performance computing platform. Results show the economic impact of simultaneously considering the constraints and the state variables evolution throughout the reservoir’s life span to obtain the optimal long-term production planning.
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Abbreviations
- \(A\) :
-
Transversal area [ft2]
- \(\dot{B}\) :
-
Oil formation volumetric factor [reservoir Bbl/STB]
- \(\overline{B}\) :
-
Water formation volumetric factor [reservoir Bbl/STB]
- \(\dot{C}\) :
-
Oil compressibility [psi−1]
- \(\tilde{C}\) :
-
Total compressibility [psi−1]
- \({\text{Coil}}\) :
-
Lifting cost [USD/STB]
- \(\overline{C}\) :
-
Water compressibility [psi−1]
- \({\text{Cwat}}\) :
-
Disposal water cost [USD/STB]
- \(\hat{C}\) :
-
Rock compressibility [psi−1]
- \(\dot{d}\) :
-
Number of temporal finite elements [−]
- \(\dot{e}\) :
-
Number of spatial finite elements [−]
- \(\dot{G}\) :
-
Oil geometry factor [reservoir Bbl]
- \(\overline{G}\) :
-
Water geometry factor [reservoir Bbl]
- \(h\) :
-
Reservoir thickness [ft]
- \(K\) :
-
Absolute permeability [mD]
- \(\dot{K}\) :
-
Oil relative permeability [−]
- \(\overline{K}\) :
-
Water relative permeability [−]
- \(\dot{M}\) :
-
Temporal collocation matrix [−]
- \(\overline{M}\) :
-
Spatial collocation matrix [−]
- \(\dot{n}\) :
-
Oil exponent for Brooks–Corey function [−]
- \(\overline{n}\) :
-
Water exponent for Brooks–Corey function [−]
- \(P\) :
-
Pressure [psi]
- \({\text{Pi}}\) :
-
Initial reservoir pressure [psi]
- \({\text{Po}}\) :
-
Pressure at the left limit of the reservoir [psi]
- \({\text{Pf}}\) :
-
Pressure at the right limit of the reservoir [psi]
- \({\text{Pwf}}\) :
-
Bottom-hole flowing pressure [psi]
- \(\widetilde{{{\text{Pwf}}}}\) :
-
Minimum bottom-hole flowing pressure [psi]
- \(\dot{Q}\) :
-
Volume rate of oil produced per block volume unit [STBPD]
- \(\overline{Q}\) :
-
Volume rate of water produced per block volume unit [STBPD]
- \(\dot{r}\) :
-
Number of temporal collocation points [−]
- \(\overline{r}\) :
-
Effective ratio [ft]
- \(\hat{r}\) :
-
Wellbore ratio [ft]
- \(S\) :
-
Skin factor [−]
- \(\dot{S}\) :
-
Oil saturation [(oil volume-Bbl)/(pore volume-Bbl)]
- \(\overline{S}\) :
-
Water saturation [(water volume-Bbl)/(pore volume-Bbl)]
- \(\tilde{S}\) :
-
Initial reservoir oil saturation [(oil volume-Bbl)/(pore volume-Bbl)]
- \(\ddot{S}\) :
-
Irreducible oil saturation [(oil volume-Bbl)/(Pore volume-Bbl)]
- \(\hat{S}\) :
-
Initial reservoir water saturation [(water vol-Bbl)/(pore vol-Bbl)]
- \(\overline{\overline{S}}\) :
-
Connate water saturation [(water volume-Bbl)/(pore volume-Bbl)]
- \(\dot{T}\) :
-
Oil transmissibility [STBPD/psi]
- \(\overline{T}\) :
-
Water transmissibility [STBPD/psi]
- \(\tilde{T}\) :
-
Time horizon [years]
- \(V\) :
-
Oil selling prices [USD]
- \(x\) :
-
Spatial dimension [ft]
- \(\dot{y}\) :
-
Number of spatial collocation points [−]
- \(\dot{z}\) :
-
Number of wells drilled [−]
- \(\overline{Z}\) :
-
Well’s location
- \(\Delta x\) :
-
Length finite reservoir element [ft]
- \(\Delta y\) :
-
Width of finite spatial element [ft]
- \(\Delta z\) :
-
Length of finite temporal element [days]
- \(\dot{\mu }{ }\) :
-
Oil viscosity [cP]
- \(\overline{\mu }\) :
-
Water viscosity [cP]
- \(\emptyset\) :
-
Porosity [pore volume (ft3)/bulk volume (ft3)]
- \(\dot{\psi }\) :
-
Water relative permeability at connate water saturation [−]
- \(\overline{\psi }\) :
-
Water relative permeability at irreducible oil saturation [−]
- \(D\) :
-
Temporal finite elements for OCFE method 1, 2,…,\(\dot{d}\)
- \(E\) :
-
Spatial finite elements for OCFE method 1, 2,…,\(\dot{e}\)
- \(R\) :
-
Temporal collocation points 1,…,\(\dot{r}\)
- \(Y\) :
-
Spatial collocation points 1,…,\(\dot{y}\)
- \(Z\) :
-
Drilled wells 1, 2,…,\(\dot{z}\)
- \(d\) :
-
Temporal finite element position for CFE method
- \(e\) :
-
Spatial finite element position for CFE method
- \(r\) :
-
Temporal collocation point position for CFE method
- \(y\) :
-
Spatial collocation point position for CFE method
- \(z\) :
-
Drilled well
- \({\text{CFE}}\) :
-
Collocation on finite elements method
- \({\text{DE}}\) :
-
Differential equations
- \({\text{FD}}\) :
-
Finite difference method
- \({\text{HPC}}\) :
-
High-performance computing
- \({\text{IBC}}\) :
-
Inter-element boundaries
- \({\text{IMPES}}\) :
-
Implicit pressure explicit saturation
- \({\text{IPOPT}}\) :
-
Interior point optimizer
- \({\text{MILP}}\) :
-
Mixed-integer linear programming
- \({\text{MINLP}}\) :
-
Mixed-integer nonlinear programming
- \({\text{MIP}}\) :
-
Mixed-integer programming
- \({\text{NPV}}\) :
-
Net present value
- \({\text{PDE}}\) :
-
Partial differential equations
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Acknowledgements
The authors are grateful to the handling editor and the anonymous referees for their valuable remarks, comments, and new references, which helped to improve the original presentation. This research was supported by the Chemical Engineering Department of Universidad de los Andes in Bogota, Colombia.
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Appendix A
Appendix A
Before implementing CFE method in the phenomenological model, the terms that contain the second-order spatial derivative must be reduced to Eqs. 32 and 33:
where
When the collocation method is applied:
Replacing Eqs. 36 and 37 in Eqs. 32 and 33, respectively,
The term \(\left( {\frac{\partial P}{{\partial x}} } \right)_{j,e}\) is approximated using the same method. The position in which this derivative is located should be considered to solve the generated system adequately, as shown from Eqs. (11–15). Terms \(\left( {A\frac{{K\dot{K}}}{{\dot{\mu }}} } \right)_{j,e}\) and \(\left( {A\frac{{K\overline{K}}}{{\overline{\mu }}} } \right)_{j,e}\), also known as \(\dot{T}_{j,e}\) and \(\overline{T}_{j,e}\), refer to the fluid transmissibility and they are estimated as established by [14].
On the other hand, the phenomenological model has a first-order temporal derivative term that is discretized as done in Eq. 40.
Including time dimensions for the Eqs. 38 and 39, and assuming the terms \(\dot{T}_{j,e}\) and \(\overline{T}_{j,e}\) remains constant through each temporal element, the resulting expression are shown in Eqs. 41 and 42.
After replacing Eqs. 42, 41 and 40 in 3, the obtained result is presented in 12. In addition, the IBC for spatial elements (see Eq. 43) are also required to ensure the solution function continuity.
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Aristizabal, J., del Mar Prieto, M., Vargas, L. et al. Multi-period Optimization for Long-Term Oilfield Production Planning. J Optim Theory Appl 197, 71–97 (2023). https://doi.org/10.1007/s10957-023-02191-7
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DOI: https://doi.org/10.1007/s10957-023-02191-7