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Abstract

Recent climate changes stimulate the search and introduction of solutions for the reduction of the anthropogenic effect upon the environment. Transition to the oxy-fuel combustion power cycles is an advanced method of CO2 emission reduction. In these energy units, the main fuel is natural gas but the cycles may also work on syngas produced by the solid fuel gasification process. This paper discloses a new highly efficient oxy-fuel combustion power cycle with coal gasification, which utilizes the syngas heat in two additional nitrogen gas turbine units. The cycle mathematics simulation and optimization result with the energy unit net efficiency of 40.43%. Parametric studies of the cycle show influence of the parameters upon the energy unit net efficiency. Change of the cycle fuel from natural gas to coal is followed by a nearly twice increase of the carbon dioxide emission from 4.63 to 9.92 gmCO2/kWh.
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Bibliography

[1] Letcher T.M.: Why do we have global warming? In: Managing Global Warming. An Interface of Technology and Human Issues . Academic Press, 2019, 3–15.
[2] Rogalev A., Komarov I., Kindra V., Zlyvko O.: Entrepreneurial assessment of sustainable development technologies for power energy sector. Entrep. Sustain. Iss. 6(2018), 1, 429–445.
[3] Bose B.K.: Global warming: Energy, environmental pollution, and the impact of power electronics. IEE Ind. Electron. M. 4(2010), 1, 6–17.
[4] Huang W., Chen W., Anandarajah G.: The role of technology diffusion in a decarbonizing world to limit global warming to well below 2C: An assessment with application of Global TIMES model. Appl. Energ. 208(2017), 291–301.
[5] Ziółkowski P., Zakrzewski W., Badur J., Kaczmarczyk O.: Thermodynamic analysis of the double Brayton cycle with the use of oxy combustion and capture of CO2. Arch. Thermodyn. 34(2013), 2, 23–38.
[6] Barba F.C., Sanchez G.M.D., Segui B.S., Darabkhani H.G., Anthony E.J.: A technical evaluation, performance analysis and risk assessment of multiple novel oxy-turbine power cycles with complete CO2 capture. J. Clean. Prod. 133(2016), 971–985.
[7] Kotowicz J., Job M.: Thermodynamic analysis of the advanced zero emission power plant. Arch. Thermodyn. 37(2016), 1, 87–98.
[8] Allam R.J., Palmer M.R., Brown G.W.J., Fetvedt J., Freed D., Nomoto H., Itoh M., Okita N., Jones C.J.: High efficiency and low cost of electricity generation from fossil fuels while elimi-nating atmospheric emissions, including carbon dioxide. Enrgy Proced. 37(2013), 1135–1149.
[9] Khallaghi N., Hanak D. P., Manovic V.: Techno-economic evaluation of nearzero CO2 emission gas-fired power generation technologies: A review. J. Nat. Gas Sci. Eng. 74(2020), 103095.
[10] Scaccabarozzi R., Gatti M., Martelli E.: Thermodynamic analysis and numerical optimization of the NET Power oxy-combustion cycle. Appl. Energ. 178(2016), 505–526.
[11] Rogalev A., Kindra V., Osipov S., Rogalev N.: Thermodynamic analysis of the net power oxy-combustion cycle. In: Proc. 13th Eur. Conf. on Turbomachinery Fluid Dynamics and Thermodynamics, ETC13, Lausanne April 8-12, 2018, ETC2019-030.
[12] Martins F., Felgueiras C., Smitkova M., Caetano N.: Analysis of fossil fuel energy consumption and environmental impacts in European countries. Energies 12(2019), 6, 964.
[13] Warner K.J., Jones G.A.: The 21st century coal question: China, India, development, and climate change. Atmosphere 10(2019), 8, 476.
[14] Hume S.: Performance evaluation of a supercritical CO2 power cycle coal gasification plant. In: Proc. 5th Int. Symp. of Supercritical CO2 Power Cycles, San Antonio, 2016.
[15] Weiland N., Shelton W., White C., Gray D.: Performance baseline for directfired sCO2 cycles. In: Proc. 5th Int. Symp. of Supercritical CO2 Power Cycles, San Antonio, 2016.
[16] Weiland N., White C.: Techno-economic analysis of an integrated gasification direct-fired supercritical CO2 power cycle. Fuel 212(2018), 613–625.
[17] Zhao Y., Zhao L.,Wang B., Zhang S., Chi J., Xiao Y.: Thermodynamic analysis of a novel dual expansion coal-fueled direct-fired supercritical carbon dioxide power cycle. Appl. Energ. 217(2018), 480–495.
[18] Zhao Y., Wang B., Chi J., Xiao Y.: Parametric study of a direct-fired supercritical carbon dioxide power cycle coupled to coal gasification process. Energ. Convers. Manage. 156(2018), 733–745.
[19] Cormos C.Cr.: Integrated assessment of IGCC power generation technology with carbon capture and storage (CCS). Energy 42(2012), 434–445.
[20] Ebrahimi A., Meratizaman M., Reyhani H. A., Pourali O., Amidpour M.: Energetic, exergetic and economic assessment of oxygen production from two columns cryogenic air separation unit. Energy 90(2015), 1298–1316. [21] Kindra V., Rogalev A., Zlyvko O., Zonov A., Smirnov M., Kaplanovich I.: Research on oxy-fuel combustion power cycle using nitrogen for turbine cooling. Arch. Thermodyn. 41(2020), 4, 191–202.
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Authors and Affiliations

Vladimir Kindra
1
Andrey Rogalev
1
Olga Vladimirovna Zlyvko
Vladimir Sokolov
1
Igor Milukov
1

  1. National Research University “Moscow Power Engineering Institute”, Krasnokazarmennaya 14, Moscow, 111250 Russia
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Abstract

The objective of this study was to investigate combustion characteristics of biomass (willow, Salix viminalis) burnt in air and O2/CO2mixtures in a circulating fluidized bed (CFB). Air and oxy-combustion characteristics of wooden biomass in CFB were supplemented by the thermogravimetric and differential thermal analyses (TGA/DTA). The results of conducted CFB and TGA tests show that the composition of the oxidizing atmosphere strongly influences the combustion process of biomass fuels. Replacing N2in the combustion environment by CO2caused slight delay (higher ignition temperature and lower maximum mass loss rate) in the combustion of wooden biomass. The combustion process in O2/CO2mixtures at 30% and 40% O2is faster and shorter than that at lower O2concentrations.

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Authors and Affiliations

Monika Kosowska-Golachowska
Agnieszka Kijo-Kleczkowska
Adam Luckos
Krzysztof Wolski
Tomasz Musiał
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Abstract

Experimental investigations and numerical simulations have been conducted in this study to derive and test the values of kinetic parameters describing oxidation and gasification reactions between char carbon and O2 and CO2 occurring at standard air and oxy-fuel combustion conditions. Experiments were carried out in an electrically heated drop-tube at heating rates comparable to fullscale pulverized fuel combustion chambers. Values of the kinetic parameters, obtained by minimization of the difference between the experimental and modeled values of char burnout, have been derived and CFD simulations reproducing the experimental conditions of the drop tube furnace confirmed proper agreement between numerical and experimental char burnout.

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Authors and Affiliations

Robert Lewtak
Jarosław Hercog
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Abstract

The Rankine cycle steam turbine power plants make a base for world electricity production. The efficiency of modern steam turbine units is not higher than 43–45%, which is remarkably lower compared to the combined cycle power plants. However, an increase in steam turbine power plant efficiency could be achieved by the rise of initial cycle parameters up to ultra-supercritical values: 700–780˚C, 30–35 MPa. A prospective steam superheating technology is the oxy-fuel combustion heating in a sidemounted combustor located in the steam pipelines. This paper reviews thermal schemes of steam turbine power plants with one or two side-mounted steam superheaters. An influence of the initial steam parameters on the facility thermal efficiency was identified and primary and secondary superheater parameters were optimized. It was found that the working fluid superheating in the side-mounted oxy-methane combustors leads to an increase of thermal efficiency higher than that with the traditional boiler superheating in the initial temperature ranges of 700–780˚C and 660–780˚C by 0.6% and 1.4%, respectively.
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Bibliography

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[13] Kosman W.: The influence of external cooling system on the performance of supercritical steam turbine cycles. Arch. Thermodyn. 31(2010), 3, 131–144.
[14] Zaryankin A., Rogalev A., Kindra V., Khudyakova V., Bychkov N.: Reduction methods of secondary flow losses in stator blades: Numerical and experimantal study. In: Proc. 12th Eur. Conf. on Turbomachinery Fluid Dynamics and Thermodynamics, Stockholm, 3-7 April 2017, ETC2017-158.
[15] Zaryankin A., Rogalev A., Garanin I., Osipov S.: Methods of low-pressure cylinders throughput improvement for construction of ultra-high capacity generation units. WIT Trans. Ecol. Environ. 195(2015), 149–160.
[16] Aminov R.Z., Egorov A.N.: Hydrogenoxygen steam generator for a closed hydrogen combustion cycleInt. J. Hydrog. Energy 44(2019), 21, 11161–11167.
[17] Rogalev N., Prokhorov V., Rogalev A., Komarov I., Kindra V.: Steam boilers’ advanced constructive solutions for the ultra-supercritical power plants. Int. J. Appl. Eng. Res. 1(2016), 18, 9297–9306.
[18] Milman O., Yankov G., Krylov V., Ptahin A.: High efficiency steam-gas mixture condenser. J. Phys. Conf. Ser. 1683(2020), 4, 042074.
[19] Milman O., Krylov V., Ptakhin A., Kondratev A., Yankov G.: Steam condensation from a moving steam-gas mixture. Therm. Eng. 65(2018), 12, 916–921.
[20] Zou C., Song Y., Li G., Cao S., He Y., Zheng C.: The chemical mechanism of steam’s effect on the temperature in methane oxy-steam combustion. Int. J. Heat Mass Transf. 75(2014), 12–18.
[21] Mazas A.N., Fiorina B., Lacoste D. A., Schuller T.: Effects of water vapor addition on the laminar burning velocity of oxygen-enriched methane flames. Combust. Flame 158(2011), 12, 2428–2440.
[22] Jin B., Zhao H., Zou C., Zheng C.: Comprehensive investigation of process characteristics for oxy-steam combustion power plants. Energ. Convers. Manag., 99(2015), 92–101.
[23] Milman O., Shifrin B.A.: High-temperature steam turbine unit running on natural gas. In: Proc. of Sem. of the Laboratory for Hydrogen Energy Technologies of JIHT RAS, Moscow 2017, 143–149
[24] Klimenko A.V., Milman O.O., Shifrin B.A.: A high-temperature gas-and-steam turbine plant operating on combined fuel. Therm. Eng. 62(2015), 11, 807–816.
[25] Van der Ham L.V., Kjelstrup S.: Exergy analysis of two cryogenic air separation processes. Energy 35(2010), 12, 4731–4739.
[26] Kotowicz J., Balicki A.: Enhancing the overall efficiency of a lignite-fired oxyfuel power plant with CFB boiler and membrane-based air separation unit. Energ. Convers. Manag. 80(2014), 20–31.
[27] Aspen Plus. https://www.aspentech.com/en/products/engineering/aspen-plus (acessed 21 March 2020).
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Authors and Affiliations

Vladimir Olegovich Kindra
1
Sergey Konstantinovich Osipov
1
Olga Vladimirovna Zlyvko
1
Igor Alexandrovich Shcherbatov
1
Vladimir Petrovich Sokolov
1

  1. National Research University “Moscow Power Engineering Institute”, Krasnokazarmennaya 14, Moscow, 111250 Russia
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Abstract

The electricity production by combustion of organic fuels, especially coal, increases the atmospheric CO2 content, which contributes to global warming. The greenhouse gas emissions by the power production industry may be reduced by the application of CO2 capture and storage systems, but it remarkably decreases the thermal power plant (TPP) efficiency because of the considerable increase of the auxiliary electricity requirements. This paper describes the thermodynamic analysis of a combined cycle TPP with coal gasification and preliminary carbon dioxide capture from the syngas. Utilization of the heat produced in the fuel preparation increases the TPP net efficiency from 42.3% to 47.2%. Moreover, the analysis included the combined cycle power plant with coal gasification and the CO2 capture from the heat recovery steam generator exhaust gas, and the oxy-fuel combustion power cycle with coal gasification. The coal-fired combined cycle power plant efficiency with the preliminary CO2 capture from syngas is 0.6% higher than that of the CO2 capture after combustion and 9.9% higher than that with the oxy-fuel combustion and further CO2 capture. The specific CO2 emissions are equal to 103 g/kWh for the case of CO2 capture from syngas, 90 g/kWh for the case of CO2 capture from the exhaust gas and 9 g/kWh for the case of oxy-fuel combustion.
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Authors and Affiliations

Vladimir Olegovich Kindra
1
Igor Alexandrovich Milukov
1
Igor Vladimirovich Shevchenko
1
Sofia Igorevna Shabalova
1
Dmitriy Sergeevich Kovalev
1

  1. National Research University “Moscow Power Engineering Institute”, Krasnokazarmennaya 14, Moscow, 111250 Russia
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Abstract

Oxy-fuel combustion (OFC) belongs to one of the three commonly known clean coal technologies for power generation sector and other industry sectors responsible for CO2emissions (e.g., steel or cement production). The OFC capture technology is based on using high-purity oxygen in the combustion process instead of atmospheric air. Therefore flue gases have a high concentration of CO2- Due to the limited adiabatic temperature of combustion some part of CO2must be recycled to the boiler in order to maintain a proper flame temperature. An integrated oxy-fuel combustion power plant constitutes a system consisting of the following technological modules: boiler, steam cycle, air separation unit, cooling water and water treatment system, flue gas quality control system and CO2processing unit. Due to the interconnections between technological modules, energy, exergy and ecological analyses require a system approach. The paper present the system approach based on the 'input-output' method to the analysis of the: direct energy and material consumption, cumulative energy and exergy consumption, system (local and cumulative) exergy losses, and thermoecological cost. Other measures like cumulative degree of perfection or index of sustainable development are also proposed. The paper presents a complex example of the system analysis (from direct energy consumption to thermoecological cost) of an advanced integrated OFC power plant.

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Authors and Affiliations

Andrzej Ziębik
Paweł Gładysz

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