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Reserve provision of combined-cycle unit in joint day-ahead energy and reserve markets

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Listed:
  • Zhang, Rufeng
  • Sun, Haihang
  • Li, Guoqing
  • Jiang, Tao
  • Li, Xue
  • Chen, Houhe
  • Zou, He

Abstract

With the continuous development of natural gas-fired combined cycle power generation technology, the combined cycle (CC) unit's installed capacity is gradually increasing in the power system because of its flexible operation characteristics. Participating in the energy and reserve markets and taking advantage of flexible mode transfer characteristics, the CC unit can provide the system with energy and sufficient reserve capacity. This paper proposes a bi-level strategic bidding model to study the CC unit’s bidding behavior in the day-ahead energy and reserve markets. The upper-level model is an optimal bidding model for the configuration-based CC unit aiming to maximize its profit. The lower-level model is the joint market clearing model of the energy and reserve markets managed by the independent system operator (ISO). CC unit and ISO in this model influence each other by the locational marginal electricity prices (LMEP) and the locational marginal reserve prices (LMRP) obtained from the lower-level market-clearing model. The CC unit submits the bids to the ISO and arranges the generation plan according to the market clearing results of the lower-level market-clearing model carried out by the ISO. The proposed bi-level optimization model is transformed into a mathematical equilibrium constraint (MPEC) problem by Karush-Kuhn-Tucker (KKT) conditions and duality theory. In this paper, the improved IEEE-6 bus and IEEE-57 bus systems are used as case studies to verify the effectiveness of the proposed bidding strategy for the CC unit. The results show that the proposed bidding strategy can effectively improve the profits of the CC unit in the electricity market. Compared with the case of the CC unit only participating in the energy market, the profits of the CC unit in the market increased by 8.84% and 12.3%.

Suggested Citation

  • Zhang, Rufeng & Sun, Haihang & Li, Guoqing & Jiang, Tao & Li, Xue & Chen, Houhe & Zou, He, 2023. "Reserve provision of combined-cycle unit in joint day-ahead energy and reserve markets," Applied Energy, Elsevier, vol. 336(C).
    • Handle: RePEc:eee:appene:v:336:y:2023:i:c:s0306261923001769
    DOI: 10.1016/j.apenergy.2023.120812
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    References listed on IDEAS

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    1. Chen, Houhe & Wang, Di & Zhang, Rufeng & Jiang, Tao & Li, Xue, 2022. "Optimal participation of ADN in energy and reserve markets considering TSO-DSO interface and DERs uncertainties," Applied Energy, Elsevier, vol. 308(C).
    2. Ordoudis, Christos & Pinson, Pierre & Morales, Juan M., 2019. "An Integrated Market for Electricity and Natural Gas Systems with Stochastic Power Producers," European Journal of Operational Research, Elsevier, vol. 272(2), pages 642-654.
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    5. Beiron, Johanna & Montañés, Rubén M. & Normann, Fredrik & Johnsson, Filip, 2020. "Flexible operation of a combined cycle cogeneration plant – A techno-economic assessment," Applied Energy, Elsevier, vol. 278(C).
    6. Khojasteh, Meysam & Faria, Pedro & Vale, Zita, 2022. "A robust model for aggregated bidding of energy storages and wind resources in the joint energy and reserve markets," Energy, Elsevier, vol. 238(PB).
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    Cited by:

    1. Leisen, Robin & Radek, Julian & Weber, Christoph, 2024. "Modeling combined-cycle power plants in a detailed electricity market model," Energy, Elsevier, vol. 298(C).
    2. Seong-Hyeon Cha & Sun-Hyeok Kwak & Woong Ko, 2023. "A Robust Optimization Model of Aggregated Resources Considering Serving Ratio for Providing Reserve Power in the Joint Electricity Market," Energies, MDPI, vol. 16(20), pages 1-27, October.

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