Combined cycle gas turbine for combined heat and power production with energy storage by steam methane reforming

Year 2021, Volume: 5 Issue: 3, 231 - 243, 30.09.2021

Ivan Komarov , Sergei Osipov , Olga Zlyvko , Andrey Vegera , Vladimir Naumov

https://doi.org/10.30521/jes.936064

Cited By: 1

Abstract

The co-generation facilities have maximal thermal efficiency. In the case of the Russian Federation, for the power production industry, the development of the co-generation combined cycle facilities (CCGT-CHP) is especially urgent. The CCGT-CHP daily load schedule requires the demand of both electricity and heat, and the heat demand depends only upon the ambient air temperature. The gas turbine power reduction and the subsequent steam turbine power reduction during the electric load drop down are limited by the necessity to maintain the steam flow to district water heater to supply heat power. Methane steam reforming allows the recovery of the excess steam heat in the form of synthetic gas together with the CCGT-CHP electric power reduction. This paper considers three versions of the CCGT-CHP steam use in the Methane reforming: Bleeding steam supply, throttling of the heat recovery steam generator exit steam and the supply of this steam to the steam production in a steam transformer. Steam Methane reforming allows a reduction in the steam turbine supply power of 25% during the electric system power drop down. In the daytime, during the maximal system load, the produced synthetic gas is used and it is necessary to use the peak load gas turbine, which allows a 23% electric power increase. Energy storage by steam Methane reforming increases the contribution margin by 2.9%.

Keywords

Combined cycle gas turbine, Combined heat and power, Maneuverability, Steam methane reforming

Supporting Institution

Ministry of Science and Higher Education of the Russian Federation

Project Number

FSWF-2020-0020

References

• [1] Zaryankin, A, Mager, A, Rogalev, A, Komarov, I. Superpowerful combined cycle power units with one gas turbine. WIT Transactions on Ecology and the Environment 2014; 190(1): 251-260. DOI: 10.2495/EQ140251.
• [2] Rogalev, N, Prokhorov, V, Rogalev, A, Komarov, I, Kindra, V. Steam boilers′ advanced constructive solutions for the ultra-supercritical power plants. International Journal of Applied Engineering Research 2016; 11(18): 9297-9306.
• [3] Lisin, E, Rogalev, A, Strielkowski, W, Komarov, I. Sustainable modernization of the Russian power utilities industry. Sustainability 2015; 7(9): 11378-11400. DOI: 10.3390/su70911378.
• [4] Internet Web-Site: Hub indices: Trading System Administrator of Wholesale Electricity Market Transactions, https://www.atsenergo.ru/results/rsv/hubs/hubs?zone=1.
• [5] Komarnicki, P. Energy storage systems: Power grid and energy market use cases. Archives of Electrical Engineering 2016; 65(3): 495-511. DOI: 10.1515/aee-2016-0036.
• [6] Guney, MS, Tepe, Y. Classification and assessment of energy storage systems. Renewable and Sustainable Energy Reviews 2017; 75: 1187-1197. DOI: 10.1016/j.rser.2016.11.102.
• [7] Alami AH. Mechanical energy storage for renewable and sustainable energy resources. Heidelberg, GERMANY: Springer International Publishing, 2020.
• [8] Sinyugin V, Magruk V, Rodionov V. Hydro-storage power plants in modern electric power industry. Moscow, RUSSIA: Litres, 2018.
• [9] Myasina MA, Kosmynina NM. Study of the modes of the Zagorskaya PHES. In: 23-rd International Symposium of Students and Young Scientists Problems of Geology and Subsurface Development; 8-12 April 2019: TPU Publishing House, Tomsk, Russia, pp. 240-241.
• [10] Frate, GF, Ferrari, L, Desideri, U. Energy storage for grid-scale applications: Technology review and economic feasibility analysis. Renewable Energy 2021; 163: 1754-1772. DOI: 10.1016/j.renene.2020.10.070.
• [11] Ceran, B. A comparative analysis of energy storage technologies. Polityka Energetyczna – Energy Policy Journal 2018; 21(3): 97-110. DOI: 10.24425/124498.
• [12] Alva, G, Lin, Y, Fang, G. An overview of thermal energy storage systems. Energy 2018; 144: 341-378. DOI: 10.1016/j.energy.2017.12.037.
• [13] Rogalev, A, Komarov, I, Kindra, V, Zlyvko, O. Entrepreneurial assessment of sustainable development technologies for power energy sector. Entrepreneurship and Sustainability Issues 2018; 6(1): 429-445. DOI: 10.9770/jesi.2018.6.1(26).
• [14] Rogalev, A, Grigoriev, E, Kindra, V and Rogalev, N. Thermodynamic optimization and equipment development for a high efficient fossil fuel power plant with zero emissions. Journal of Cleaner Production 2019; 236: 117592. DOI: 10.1016/j.jclepro.2019.07.067.
• [15] Valamin, AY, Kultyshev, AY, Bilan, VN, Goldberg, AA, Sakhnin, YA, Shekhter, MV, Aguilera, HCP, Stepanov, MY, Shibaev, TL, Polyaeva, YN. The cogeneration steam turbine of the T-63/76-8.8 type for a series of PGU-300 combined cycle power plants. Thermal Engineering 2012; 59(12): 883-892. DOI: 10.1134/S0040601512120099.
• [16] Karpunin, AP. Study of the influence of the parameters of GTU and CCGT on their characteristics based on the technique with detailed taking into account of losses from cooling in a gas turbine. PhD, National Research University, Moscow, Russia, 2016.
• [17] Trukhnii, AD. Combined-cycle plants of power plants. Moscow, RUSSIA: MPEI, 2013.
• [18] Romano, MC, Cassotti, EN, Chiesa, P, Meyer, J, Mastin, J. Application of the sorption enhanced-steam reforming process in combined cycle-based power plants. Energy Procedia 2011; 4: 1125-1132. DOI: 10.1016/j.egypro.2011.01.164.
• [19] Carapellucci, R, Giordano, L. Upgrading existing gas-steam combined cycle power plants through steam injection and methane steam reforming. Energy 2019; 173: 229-243. DOI: 10.1016/j.energy.2019.02.046.
• [20] Lozza, G, Chiesa, P. Natural gas decarbonization to reduce CO2 emission from combined cycles: Part I – Partial oxidation. J. Eng. Gas Turbines Power 2002; 124(1): 82-88.
• [21] Lozza, G, Chiesa, P. Natural gas decarbonization to reduce CO2 emission from combined cycles: Part II— Steam-methane reforming. J. Eng. Gas Turbines Power 2002; 124(1): 89-95.
• [22] Internet Web-Site: Official exchange rates: Bank of Russia, https://cbr.ru/currency_base/dynamics, Feb 2021.
• [23] Canière, H, Willockx, A, Dick, E, De Paepe, M. Raising cycle efficiency by intercooling in air-cooled gas turbines. Applied Thermal Engineering 2006; 26(16): 1780-1787. DOI: 10.1016/j.applthermaleng.2006.02.008.
• [24] Fahim MA, Alsahhaf TA, Elkilani A. Hydrogen Production. In: Fahim MA, Alsahhaf TA, Elkilani A, editors. Fundamentals of Petroleum Refining. Oxford, UK: Elsevier, 2010. pp. 285-302.
• [25] Equipment design and cost estimation for small modular biomass systems, synthesis gas cleanup, and oxygen separation equipment. Task 1: Cost estimates of small modular systems. Final report. San Francisco, USA: National Renewable Energy Laboratory, 2006.
• [26] Internet Web-Site: H2A: Hydrogen analysis production models: National Renewable Energy Laboratory, https://www.nrel.gov/hydrogen/h2a-production-models.html.
• [27] Corradetti, A, Desideri, U. Analysis of gas-steam combined cycles with natural gas reforming and CO2 capture. Journal of Engineering for Gas Turbines and Power 2005; 127(3): 545-552. DOI: 10.1115/1.1850941.
• [28] Alivanova, SV, Kurennaya, VV. Marginal analysis as the effective method of choice of administrative decisions. Scientific Journal of KubSAU 2012; 80(06): 0801206015.