Abstract
In order to accommodate the uncertainty and variability of wind power, this paper proposes a scenario-based probabilistic model to assess the impact of intermittent wind power-based Renewable Energy Resources (RES) on the Transmission Network Expansion Planning (TNEP). The objectives comprise the evaluation of impacts considering the wind power penetration into connected and unconnected buses, as well as the optimization of reinforcements that must be made to avoid unwanted wind cutting operations and load shedding. The wind power uncertainties are represented through scenarios obtained from real historical series grouped by using the well-known k-means algorithm. The methodology performance is verified in a practical equivalent Brazilian southern system, modified to include a significant amount of wind energy. The obtained results show that the RES insertion impacts the TNEP task, changing the expansion decision.
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Abbreviations
- AC :
-
Alternating current
- DC :
-
Direct current
- EHA :
-
Efficient hybrid algorithm
- EPS :
-
Electrical power system
- MBA :
-
Modified bat-inspired algorithm
- MINLP :
-
Mixed-integer nonlinear programming
- OBF :
-
Objective function
- OPF :
-
Optimal power flow
- RES :
-
Renewable energy sources
- SC :
-
Simulation case
- TNEP :
-
Transmission network expansion planning
- WS :
-
Wind scenarios
- \(\gamma _{ij}\) :
-
Susceptance of fictitious line ij, considered as 0.001 per unit (pu)
- \(\rho _{w}\) :
-
Wind generation scenarios probability of occurrence
- \(b_{ij}\) :
-
Susceptance of line ij
- \(ce_{ij}\) :
-
Investment cost of a candidate transmission line ij ($)
- \(d_{i,w}\) :
-
Demand at bus i (MW) at wind generation scenario w
- \(dc_i\) :
-
Specific deficit generation cost at bus i ($/MW)
- \(dwc_i\) :
-
Wind Curtailment cost at bus i ($/MW)
- \(fC^{max}_{ij}\) :
-
Active power flow limit of a candidate transmission line ij (MW)
- \(fE^{max}_{ij}\) :
-
Active power flow limit of an existing transmission line ij (MW)
- \(g_{ij}\) :
-
Conductance of line ij
- k :
-
Number of clusters to the k-means metho
- \(N_{S}\) :
-
Number of wind generation scenarios
- \(pg_i^{max}\) :
-
Superior limit of \(pg_{i,w}\) (MW)
- \(pg_i^{min}\) :
-
Inferior limit of \(pg_{i,w}\) (MW)
- \(pw_{i,w}\) :
-
Active wind power generation at bus i at wind generation scenario w (MW)
- B :
-
Set of load buses
- C :
-
Set of branches with candidate transmission lines
- E :
-
Set of branches with existing transmission lines
- F :
-
Set of branches with fictitious transmission lines
- W :
-
Set of wind generation scenarios
- w :
-
Index for wind generation scenario
- Z :
-
Set of generation buses
- \(Z^*\) :
-
Set of buses where the wind generation units were allocated
- \(\theta _{ij,w}\) :
-
Angular difference between terminal buses i and j at wind generation scenario w
- \(EP_{ij}\) :
-
Expansion binary 0/1 parameter for reinforcement ij
- \(fC_{ij,w}\) :
-
Active power flow (MW) of candidate transmission line ij, at wind generation scenario w
- \(fE_{ij,w}\) :
-
Active power flow (MW) of transmission line ij, at wind generation scenario w
- \(fF_{ij,w}\) :
-
Active power flow (MW) of fictitious line ij, at wind generation scenario w
- \(pd_{i,w}\) :
-
Active power deficit at bus i at wind generation scenario w (MW)
- \(pg_{i,w}\) :
-
Active power generation at bus i at wind generation scenario w (MW)
- \(pwc_{i,w}\) :
-
Wind Curtailment at bus i at wind generation scenario w (MW)
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Acknowledgements
The authors would like to thank the Brazilian Research Agencies: CAPES, CNPq, FAPEMIG and INERGE for supporting this research.
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Moraes, C.A., de Oliveira, L.W., de Oliveira, E.J. et al. A probabilistic approach to assess the impact of wind power generation in transmission network expansion planning. Electr Eng 104, 1029–1040 (2022). https://doi.org/10.1007/s00202-021-01361-y
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DOI: https://doi.org/10.1007/s00202-021-01361-y