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Analysis of Optimal HVDC Back-to-Back Placement Based on Composite System Reliability

Author

Listed:
  • Nanang Hariyanto

    (School of Electrical Engineering and Informatics, Bandung Institute of Technology, Bandung 40132, Indonesia)

  • Niko B. Simamora

    (School of Electrical Engineering and Informatics, Bandung Institute of Technology, Bandung 40132, Indonesia)

  • Kevin M. Banjar-Nahor

    (School of Electrical Engineering and Informatics, Bandung Institute of Technology, Bandung 40132, Indonesia)

  • Hendry Timotiyas Paradongan

    (School of Business and Management, Bandung Institute of Technology, Bandung 40132, Indonesia)

Abstract

HVDC is a promising interconnection solution for connecting asynchronous systems and ensuring power control. In Indonesia, a remote industrial system in Sumatra is experiencing load growth and has the option to draw power from the Sumatra system. However, due to frequency differences, the use of HVDC is crucial. The Generation Expansion Planning has proposed six converters but not their interconnection points. This study will determine the most reliable interconnection locations. The chosen converters are modular multilevel converters (MMCs) with high modularity. The converter reliability modeling considers voltage levels, the number of modules, and redundancy strategies. This modeling is then implemented at the power system level to obtain the best placement at the available high-voltage (HV) substation options. Determining the best placement is based on the optimal reliability index. The optimal placement also includes the option to convert from HV to medium-voltage (MV) interconnection. MV interconnection offers higher flexibility but tends to be more expensive. The availability for HV converters is 99.69%, while for MV converters, it is slightly higher, at 99.81%. Additionally, converting from HV to MV reduces the SAIFI (system average interruption frequency index) from 0.2668 to 0.2284 occurrences per year, lowering the interruption cost from 7.804 million USD to 5.737 million USD per year. The sensitivity of interruption, investment, and maintenance costs shows that converting at least one HV converter to MV remains economical. In this case study, the optimal converter placement includes Area VI–2, recommended for conversion from HV to a more distributed MV configuration, improving reliability and economic efficiency.

Suggested Citation

  • Nanang Hariyanto & Niko B. Simamora & Kevin M. Banjar-Nahor & Hendry Timotiyas Paradongan, 2024. "Analysis of Optimal HVDC Back-to-Back Placement Based on Composite System Reliability," Energies, MDPI, vol. 17(19), pages 1-27, October.
    • Handle: RePEc:gam:jeners:v:17:y:2024:i:19:p:5008-:d:1494276
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    References listed on IDEAS

    as
    1. Izhar Us Salam & Muhammad Yousif & Muhammad Numan & Kamran Zeb & Moatasim Billah, 2023. "Optimizing Distributed Generation Placement and Sizing in Distribution Systems: A Multi-Objective Analysis of Power Losses, Reliability, and Operational Constraints," Energies, MDPI, vol. 16(16), pages 1-28, August.
    2. Simeon Hagspiel, Andreas Knaut, and Jakob Peter, 2018. "Reliability in Multi-regional Power Systems: Capacity Adequacy and the Role of Interconnectors," The Energy Journal, International Association for Energy Economics, vol. 0(Number 5).
    3. Munif Nazmus Sakib & Sahar Pirooz Azad & Mehrdad Kazerani, 2022. "A Critical Review of Modular Multilevel Converter Configurations and Submodule Topologies from DC Fault Blocking and Ride-Through Capabilities Viewpoints for HVDC Applications," Energies, MDPI, vol. 15(11), pages 1-32, June.
    4. Crozier, Constance & Baker, Kyri, 2022. "The effect of renewable electricity generation on the value of cross-border interconnection," Applied Energy, Elsevier, vol. 324(C).
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