IDEAS home Printed from https://ideas.repec.org/a/eee/energy/v113y2016icp338-354.html
   My bibliography  Save this article

Evaluating the impact of sub-hourly unit commitment method on spinning reserve in presence of intermittent generators

Author

Listed:
  • Kazemi, Mehdi
  • Siano, Pierluigi
  • Sarno, Debora
  • Goudarzi, Arman

Abstract

This paper presents an algorithm to deal with thermal Unit Commitment which takes into account the intermittency and volatility of the renewable energies such as wind and solar energies. Dynamic Programming (DP) integrating Priority Listing order (PL) based on Best Per Unit Cost (BP) was applied to commit the thermal units in an isolated island with generators based on renewable sources. In this work, the effects of a high time resolutions such as 60, 30, 15, 10 and 5 min on production costs, reserves and intermittent generators are investigated. In order to demonstrate the capability of the proposed algorithm, two cases were studied. Firstly, a test system composed of ten diesel generators, three wind turbines and one Photovoltaic (PV) power plant is examined and then the IEEE 118-bus test system, integrating wind and PV power plants, is considered. The presented simulation results show that a proper schedule for each generation unit can be reached at a time resolution closer to real time unit commitment and economic dispatch while a high level of reliability can be guaranteed by assuring practical constraints fulfillment.

Suggested Citation

  • Kazemi, Mehdi & Siano, Pierluigi & Sarno, Debora & Goudarzi, Arman, 2016. "Evaluating the impact of sub-hourly unit commitment method on spinning reserve in presence of intermittent generators," Energy, Elsevier, vol. 113(C), pages 338-354.
    • Handle: RePEc:eee:energy:v:113:y:2016:i:c:p:338-354
    DOI: 10.1016/j.energy.2016.07.050
    as

    Download full text from publisher

    File URL: http://www.sciencedirect.com/science/article/pii/S0360544216309744
    Download Restriction: Full text for ScienceDirect subscribers only
    File URL: https://libkey.io/10.1016/j.energy.2016.07.050?utm_source=ideas
    LibKey link: if access is restricted and if your library uses this service, LibKey will redirect you to where you can use your library subscription to access this item
    ---><---

    As the access to this document is restricted, you may want to search for a different version of it.

    References listed on IDEAS

    as
    1. Wang, Chengshan & Zhou, Yue & Wang, Jidong & Peng, Peiyuan, 2013. "A novel Traversal-and-Pruning algorithm for household load scheduling," Applied Energy, Elsevier, vol. 102(C), pages 1430-1438.
    2. Wang, Jiadong & Wang, Jianhui & Liu, Cong & Ruiz, Juan P., 2013. "Stochastic unit commitment with sub-hourly dispatch constraints," Applied Energy, Elsevier, vol. 105(C), pages 418-422.
    3. Huber, Matthias & Dimkova, Desislava & Hamacher, Thomas, 2014. "Integration of wind and solar power in Europe: Assessment of flexibility requirements," Energy, Elsevier, vol. 69(C), pages 236-246.
    4. Deane, J.P. & Drayton, G. & Ó Gallachóir, B.P., 2014. "The impact of sub-hourly modelling in power systems with significant levels of renewable generation," Applied Energy, Elsevier, vol. 113(C), pages 152-158.
    5. Cutter, Eric & Haley, Ben & Hargreaves, Jeremy & Williams, Jim, 2014. "Utility scale energy storage and the need for flexible capacity metrics," Applied Energy, Elsevier, vol. 124(C), pages 274-282.
    Full references (including those not matched with items on IDEAS)

    Citations

    Citations are extracted by the CitEc Project, subscribe to its RSS feed for this item.
    as


    Cited by:

    1. Kyu-Hyung Jo & Mun-Kyeom Kim, 2018. "Stochastic Unit Commitment Based on Multi-Scenario Tree Method Considering Uncertainty," Energies, MDPI, vol. 11(4), pages 1-17, March.
    2. Goudarzi, Arman & Viray, Z.N.C. & Siano, Pierluigi & Swanson, Andrew G. & Coller, John V. & Kazemi, Mehdi, 2017. "A probabilistic determination of required reserve levels in an energy and reserve co-optimized electricity market with variable generation," Energy, Elsevier, vol. 130(C), pages 258-275.
    3. Psarros, Georgios N. & Nanou, Sotirios I. & Papaefthymiou, Stefanos V. & Papathanassiou, Stavros A., 2018. "Generation scheduling in non-interconnected islands with high RES penetration," Renewable Energy, Elsevier, vol. 115(C), pages 338-352.
    4. Talaat, M. & Elkholy, M.H. & Farahat, M.A., 2020. "Operating reserve investigation for the integration of wave, solar and wind energies," Energy, Elsevier, vol. 197(C).
    5. Psarros, Georgios N. & Papathanassiou, Stavros A., 2023. "Generation scheduling in island systems with variable renewable energy sources: A literature review," Renewable Energy, Elsevier, vol. 205(C), pages 1105-1124.
    6. Mansourshoar, Paria & Yazdankhah, Ahmad Sadeghi & Vatanpour, Mohsen & Mohammadi-Ivatloo, Behnam, 2022. "Impact of implementing a price-based demand response program on the system reliability in security-constrained unit commitment problem coupled with wind farms in the presence of contingencies," Energy, Elsevier, vol. 255(C).
    7. Georgios N. Psarros & Stavros A. Papathanassiou, 2019. "Comparative Assessment of Priority Listing and Mixed Integer Linear Programming Unit Commitment Methods for Non-Interconnected Island Systems," Energies, MDPI, vol. 12(4), pages 1-23, February.
    8. Woo-Jung Kim & Yu-Seok Lee & Yeong-Han Chun & Hae-Seong Jeong, 2022. "Reserve-Constrained Unit Commitment Considering Adjustable-Speed Pumped-Storage Hydropower and Its Economic Effect in Korean Power System," Energies, MDPI, vol. 15(7), pages 1-23, March.
    9. Goudarzi, Arman & Swanson, Andrew G. & Van Coller, John & Siano, Pierluigi, 2017. "Smart real-time scheduling of generating units in an electricity market considering environmental aspects and physical constraints of generators," Applied Energy, Elsevier, vol. 189(C), pages 667-696.

    Most related items

    These are the items that most often cite the same works as this one and are cited by the same works as this one.
    1. Behnam Zakeri & Samuli Rinne & Sanna Syri, 2015. "Wind Integration into Energy Systems with a High Share of Nuclear Power—What Are the Compromises?," Energies, MDPI, vol. 8(4), pages 1-35, March.
    2. Xie, Kaigui & Dong, Jizhe & Singh, Chanan & Hu, Bo, 2016. "Optimal capacity and type planning of generating units in a bundled wind–thermal generation system," Applied Energy, Elsevier, vol. 164(C), pages 200-210.
    3. Philipsen, Rens & Morales-España, Germán & de Weerdt, Mathijs & de Vries, Laurens, 2019. "Trading power instead of energy in day-ahead electricity markets," Applied Energy, Elsevier, vol. 233, pages 802-815.
    4. Ringkjøb, Hans-Kristian & Haugan, Peter M. & Solbrekke, Ida Marie, 2018. "A review of modelling tools for energy and electricity systems with large shares of variable renewables," Renewable and Sustainable Energy Reviews, Elsevier, vol. 96(C), pages 440-459.
    5. Haas, J. & Cebulla, F. & Cao, K. & Nowak, W. & Palma-Behnke, R. & Rahmann, C. & Mancarella, P., 2017. "Challenges and trends of energy storage expansion planning for flexibility provision in low-carbon power systems – a review," Renewable and Sustainable Energy Reviews, Elsevier, vol. 80(C), pages 603-619.
    6. Heggarty, Thomas & Bourmaud, Jean-Yves & Girard, Robin & Kariniotakis, Georges, 2020. "Quantifying power system flexibility provision," Applied Energy, Elsevier, vol. 279(C).
    7. Chang-Gi Min & Mun-Kyeom Kim, 2017. "Net Load Carrying Capability of Generating Units in Power Systems," Energies, MDPI, vol. 10(8), pages 1-13, August.
    8. Cebulla, F. & Fichter, T., 2017. "Merit order or unit-commitment: How does thermal power plant modeling affect storage demand in energy system models?," Renewable Energy, Elsevier, vol. 105(C), pages 117-132.
    9. Yang, Linfeng & Zhang, Chen & Jian, Jinbao & Meng, Ke & Xu, Yan & Dong, Zhaoyang, 2017. "A novel projected two-binary-variable formulation for unit commitment in power systems," Applied Energy, Elsevier, vol. 187(C), pages 732-745.
    10. Abdilahi, Abdirahman M. & Mustafa, Mohd Wazir & Abujarad, Saleh Y. & Mustapha, Mamunu, 2018. "Harnessing flexibility potential of flexible carbon capture power plants for future low carbon power systems: Review," Renewable and Sustainable Energy Reviews, Elsevier, vol. 81(P2), pages 3101-3110.
    11. Shubo Hu & Feixiang Peng & Zhengnan Gao & Changqiang Ding & Hui Sun & Wei Zhou, 2019. "Sample Entropy Based Net Load Tracing Dispatch of New Energy Power System," Energies, MDPI, vol. 12(1), pages 1-23, January.
    12. Zakeri, Behnam & Syri, Sanna & Rinne, Samuli, 2015. "Higher renewable energy integration into the existing energy system of Finland – Is there any maximum limit?," Energy, Elsevier, vol. 92(P3), pages 244-259.
    13. Ingeborg Graabak & Magnus Korpås, 2016. "Variability Characteristics of European Wind and Solar Power Resources—A Review," Energies, MDPI, vol. 9(6), pages 1-31, June.
    14. Zappa, William & Junginger, Martin & van den Broek, Machteld, 2019. "Is a 100% renewable European power system feasible by 2050?," Applied Energy, Elsevier, vol. 233, pages 1027-1050.
    15. Zhang, Menghan & Yang, Zhifang & Lin, Wei & Yu, Juan & Dai, Wei & Du, Ershun, 2021. "Enhancing economics of power systems through fast unit commitment with high time resolution," Applied Energy, Elsevier, vol. 281(C).
    16. Morim, Joao & Cartwright, Nick & Hemer, Mark & Etemad-Shahidi, Amir & Strauss, Darrell, 2019. "Inter- and intra-annual variability of potential power production from wave energy converters," Energy, Elsevier, vol. 169(C), pages 1224-1241.
    17. Guerra, K. & Haro, P. & Gutiérrez, R.E. & Gómez-Barea, A., 2022. "Facing the high share of variable renewable energy in the power system: Flexibility and stability requirements," Applied Energy, Elsevier, vol. 310(C).
    18. Christina Carty & Oscar Claveria, 2022. "“The nexus between variable renewable energy, economy and climate: Evidence from European countries by means of exploratory graphical analysis”," AQR Working Papers 202205, University of Barcelona, Regional Quantitative Analysis Group, revised May 2022.
    19. Hayes, Liam & Stocks, Matthew & Blakers, Andrew, 2021. "Accurate long-term power generation model for offshore wind farms in Europe using ERA5 reanalysis," Energy, Elsevier, vol. 229(C).
    20. Dunguo Mou, 2018. "Wind Power Development and Energy Storage under China’s Electricity Market Reform—A Case Study of Fujian Province," Sustainability, MDPI, vol. 10(2), pages 1-20, January.

    Corrections

    All material on this site has been provided by the respective publishers and authors. You can help correct errors and omissions. When requesting a correction, please mention this item's handle: RePEc:eee:energy:v:113:y:2016:i:c:p:338-354. See general information about how to correct material in RePEc.

    If you have authored this item and are not yet registered with RePEc, we encourage you to do it here. This allows to link your profile to this item. It also allows you to accept potential citations to this item that we are uncertain about.

    If CitEc recognized a bibliographic reference but did not link an item in RePEc to it, you can help with this form .

    If you know of missing items citing this one, you can help us creating those links by adding the relevant references in the same way as above, for each refering item. If you are a registered author of this item, you may also want to check the "citations" tab in your RePEc Author Service profile, as there may be some citations waiting for confirmation.

    For technical questions regarding this item, or to correct its authors, title, abstract, bibliographic or download information, contact: Catherine Liu (email available below). General contact details of provider: http://www.journals.elsevier.com/energy .

    Please note that corrections may take a couple of weeks to filter through the various RePEc services.

    IDEAS is a RePEc service. RePEc uses bibliographic data supplied by the respective publishers.