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Economic evaluation of solar thermal hybrid H2O turbine power generation systems

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  • Kosugi, Takanobu
  • Pak, Pyong Sik

Abstract

The economics of two proposed solar thermal hybrid power generation systems (STHSs) have been evaluated. Each system consists of direct-steam-generation solar collectors, a steam accumulator and a gas turbine power generation system which uses steam as its working fluid. One (STHS-A) of the proposed systems emits CO2 generated by burning fuel, whereas the other (STHS-B) captures the CO2. Assuming that the systems are located in San Francisco, USA, where solar radiation energy is approximately the same as the global average, the levelized electricity costs (LECs) of the STHSs have been estimated considering future uncertainty of fuel cost and the capital cost of the solar collector. The LECs of combined cycle plants, which are considered to be one of the major thermal power generation systems in the near future, have also been estimated to evaluate the economics of the proposed systems. When fuel (methane) cost is 4.5 $/GJ, for example, the STHS-A has been estimated to be the most economical among the evaluated systems where the carbon tax is higher than a value in the range of 106–244 $/t-C, whereas the STHS-B is the most economical where the carbon tax is higher than a value between 368 and 475 $/t-C.

Suggested Citation

  • Kosugi, Takanobu & Pak, Pyong Sik, 2003. "Economic evaluation of solar thermal hybrid H2O turbine power generation systems," Energy, Elsevier, vol. 28(3), pages 185-198.
    • Handle: RePEc:eee:energy:v:28:y:2003:i:3:p:185-198
    DOI: 10.1016/S0360-5442(02)00092-0
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    Citations

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    Cited by:

    1. Gou, Chenhua & Cai, Ruixian & Hong, Hui, 2007. "A novel hybrid oxy-fuel power cycle utilizing solar thermal energy," Energy, Elsevier, vol. 32(9), pages 1707-1714.
    2. Santos, Lúcia & Soares, Isabel & Mendes, Carla & Ferreira, Paula, 2014. "Real Options versus Traditional Methods to assess Renewable Energy Projects," Renewable Energy, Elsevier, vol. 68(C), pages 588-594.
    3. Pak, Pyong Sik & Lee, Young Duk & Ahn, Kook Young, 2010. "Characteristics and economic evaluation of a power plant applying oxy-fuel combustion to increase power output and decrease CO2 emission," Energy, Elsevier, vol. 35(8), pages 3230-3238.
    4. Pak, Pyong Sik & Lee, Young Duk & Ahn, Kook Young, 2009. "Characteristics and economic evaluation of a CO2-capturing repowering system with oxy-fuel combustion for utilizing exhaust gas of molten carbonate fuel cell (MCFC)," Energy, Elsevier, vol. 34(11), pages 1903-1909.
    5. Ilkan, M. & Erdil, E. & Egelioglu, F., 2005. "Renewable energy resources as an alternative to modify the load curve in Northern Cyprus," Energy, Elsevier, vol. 30(5), pages 555-572.
    6. Jamel, M.S. & Abd Rahman, A. & Shamsuddin, A.H., 2013. "Advances in the integration of solar thermal energy with conventional and non-conventional power plants," Renewable and Sustainable Energy Reviews, Elsevier, vol. 20(C), pages 71-81.
    7. Nixon, J.D. & Dey, P.K. & Davies, P.A., 2012. "The feasibility of hybrid solar-biomass power plants in India," Energy, Elsevier, vol. 46(1), pages 541-554.
    8. Mellouk, Lamyae & Ghazi, M. & Aaroud, A. & Boulmalf, M. & Benhaddou, D. & Zine-Dine, K., 2019. "Design and energy management optimization for hybrid renewable energy system- case study: Laayoune region," Renewable Energy, Elsevier, vol. 139(C), pages 621-634.
    9. Dowling, Alexander W. & Zheng, Tian & Zavala, Victor M., 2017. "Economic assessment of concentrated solar power technologies: A review," Renewable and Sustainable Energy Reviews, Elsevier, vol. 72(C), pages 1019-1032.
    10. Ye, Xuemin & Wang, Jia & Li, Chunxi, 2016. "Performance and emission reduction potential of renewable energy aided coal-fired power generation systems," Energy, Elsevier, vol. 113(C), pages 966-979.

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