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Finding a representative network losses model for large-scale transmission expansion planning with renewable energy sources

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  • Fitiwi, Desta Z.
  • Olmos, L.
  • Rivier, M.
  • de Cuadra, F.
  • Pérez-Arriaga, I.J.

Abstract

The global drive for integration of RESs (renewable energy sources) means that TEP (transmission expansion planning) has to be carried out over geographically wide and large-scale networks under high levels of uncertainty. This leads to complex combinatorial TEP optimization problems, requiring a huge amount of OPF (optimal power flow) computations. The algorithm employed to calculate the OPF must be reasonably accurate but computationally very efficient, because it has to be run for a lot of operational conditions. Overly simplified OPF formulations are not adequate, since they neglect aspects which play a relevant role in TEP. Specifically, network losses significantly influence TEP solutions, but they are often disregarded due to their computational burden. Given their potential impact on the optimal TEP solution, the main focus of this paper is to find an appropriate losses model in the context of medium to long-term TEP for large-scale power systems. Keeping the balance between accuracy and computation time is essential in such problems. The paper presents two alternative linear losses models, as well as two variants of existing ones. These models are compared and tested using case studies, including small, medium and large-scale networks. Practical conclusions and recommendations are drawn from numerical results.

Suggested Citation

  • Fitiwi, Desta Z. & Olmos, L. & Rivier, M. & de Cuadra, F. & Pérez-Arriaga, I.J., 2016. "Finding a representative network losses model for large-scale transmission expansion planning with renewable energy sources," Energy, Elsevier, vol. 101(C), pages 343-358.
    • Handle: RePEc:eee:energy:v:101:y:2016:i:c:p:343-358
    DOI: 10.1016/j.energy.2016.02.015
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    Cited by:

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    3. Yang, Zhifang & Zhong, Haiwang & Lin, Wei & Lin, Jeremy & Chen, Yonghong & Xia, Qing & Liu, Wentao & Zhang, Xuan, 2019. "Mapping between transmission constraint penalty factor and OPF solution in electricity markets: analysis and fast calculation," Energy, Elsevier, vol. 168(C), pages 1181-1191.
    4. Mo, Huadong & Sansavini, Giovanni, 2019. "Impact of aging and performance degradation on the operational costs of distributed generation systems," Renewable Energy, Elsevier, vol. 143(C), pages 426-439.
    5. Neumann, Fabian & Hagenmeyer, Veit & Brown, Tom, 2022. "Assessments of linear power flow and transmission loss approximations in coordinated capacity expansion problems," Applied Energy, Elsevier, vol. 314(C).
    6. Kim, Hyo-Jin & Lim, Seul-Ye & Yoo, Seung-Hoon, 2017. "Is the Korean public willing to pay for a decentralized generation source? The case of natural gas-based combined heat and power," Energy Policy, Elsevier, vol. 102(C), pages 125-131.
    7. Santos, Sérgio F. & Fitiwi, Desta Z. & Cruz, Marco R.M. & Cabrita, Carlos M.P. & Catalão, João P.S., 2017. "Impacts of optimal energy storage deployment and network reconfiguration on renewable integration level in distribution systems," Applied Energy, Elsevier, vol. 185(P1), pages 44-55.
    8. Fitiwi, Desta Z. & Lynch, Muireann & Bertsch, Valentin, 2020. "Enhanced network effects and stochastic modelling in generation expansion planning: Insights from an insular power system," Socio-Economic Planning Sciences, Elsevier, vol. 71(C).

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