scholarly journals Features of application of the methane-hydrogen fraction as fuel for thermal power plant boiler

2019 ◽  
Vol 21 (3) ◽  
pp. 109-116
Author(s):  
M. A. Taymarov ◽  
V. K. Ilyin ◽  
E. G. Chiklyaev ◽  
R. G. Sungatullin
Keyword(s):  
Heat Flux ◽  
Natural Gas ◽  
Burning Rate ◽  
Hydrogen Content ◽  
Power Plants ◽  
Thermal Power ◽  
Petroleum Products ◽  
Heat Of Combustion ◽  
Combustion Heat ◽  
Gaseous Hydrocarbon

The methane-hydrogen fraction is a gaseous hydrocarbon by-product during oil processing for obtaining petroleum products. Until recently, the methane-hydrogen fraction was used as furnace oil in internal technological processes at a refinery. Some of the low-calorie methane-hydrogen fraction was burned in flares. Driven by the prospect of the methane-hydrogen fraction use as a fuel alternative to natural gas for burning in thermal power plants boilers, it became necessary to study the methane-hydrogen fraction combustion processes in large volumes. The conversion of ON-1000/1 and ON-1000/2 furnaces from the combustion of the methane- hydrogen fraction with combustion heat of 25.45 MJ/m3 to the combustion of the composition with combustion heat of 18.8 MJ/m3 leads to a decrease in temperature in the flame core for 100 °C as an average. The intensity of flame radiation on the radiant tubes decreases. Therefore, the operation of furnaces during combustion of methane-hydrogen fraction with a low heat of combustion at the gas oil hydro-treating unit is carried out only with a fresh catalyst, which allows lower flame temperatures in the burner.The experiments to determine the concentration of nitrogen oxides NOx and the burning rate w of the methane-hydrogen fraction in the ON-1000/1 furnace and natural gas in the TGM-84A boiler, depending upon the heat of combustion Qnr were carried out. The obtained results showed that the increase in the hydrogen content Н2 from 10.05 % to 18.36% (by mass) results in an increase in the burning rate w by 45%. The burning rate of natural gas with methane CH4 content of 98.89% in the TGM-84A boiler is 0.84 m/s, i.e. it is 2.5 times lower than the burning rate of the methane- hydrogen fraction with H2 content of 10.05%. The distributions of heat flux from the flame qf over the burner height h in the TGM-84A boiler were obtained in case of natural gas burning and calculation of burning of the methane-hydrogen fraction with a hydrogen content of 10.05% and methane of 28.27%. The comparison of the obtained data shows that burning of methane- hydrogen fraction causes an increase in the incident heat flux qf at the outlet of the burner.

scholarly journals Study of the speed of flame distribution in the combustion of methane-hydrogen fractions

2019 ◽  
Vol 124 ◽  
pp. 05065
Author(s):  
M.A. Taymarov ◽  
R.V. Akhmetova ◽  
Ye.G. Chiklyayev ◽  
Y.V. Lavirko ◽  
E.A. Akhmetov ◽  
...  
Keyword(s):  
Natural Gas ◽  
Flame Propagation ◽  
Hydrogen Content ◽  
Power Plants ◽  
Thermal Power ◽  
Propagation Rate ◽  
Heat Of Combustion ◽  
Oil Refining ◽  
Thermal Power Plants ◽  
Concentration Limits

At present, natural gas of the Urengoyskoye field is burned in boilers of thermal power plants (TPP) to generate electricity. At the same time, refineries and petrochemical plants deepen the processing of fossil liquid hydrocarbons. The final product of processing is not only motor fuels, ethylene glycols, plastics, accompanying inert gases such as argon, but also a large amount of combustible secondary gaseous mixtures of the methane series. These mixtures contain a wide array of combustible components. Among them there is the methane-hydrogen fraction, which is characterized by a fairly high hydrogen content. A distinctive feature of the use of hydrogen as a fuel is the high rate of flame propagation and the relatively low heat of combustion [1, p.6-8]. The methane-hydrogen fraction due to the volatility of the composition and a wide range of changes in the heat of combustion was recently used in refineries for their own needs as an insignificant additive to combusted natural gas in process furnaces [2-5]. If the methane-hydrogen fraction was not utilized as a fuel in these furnaces, it was burned in flares. Due to the increase in oil refining volumes and the increase in the amount of methane-hydrogen fraction produced, it became realistic to use this gaseous fraction as the main fuel for power boilers of thermal power plants located near petrochemical plants. In the near future, it is planned to use the methane-hydrogen fraction as an additive to the natural gas for 20 power steam boilers of the Nizhnekamsk CHP-1 with a total thermal capacity of 6000 MW. The supplier of the methane-hydrogen fraction is the TAIF NK oil refineries. Depending on the technology of oil refining, the hydrogen content in the methane-hydrogen fraction ranges from 10 to 27% (by weight). The concentration limits of hydrogen ignition in a mixture with air have been experimentally studied by many researchers [6–8] mainly during bench testing or inside laboratories. A feature of the oxidation of hydrogen by air oxygen is the fact that there is a difference between the spread of the flame in limited volumes and in large volumes of the furnace space of energy boilers [9]. In small volumes, when the flame front collides with the wall, oxidation reactions are interrupted, and this does not occur in large volumes. Therefore, the study of flame propagation speed and concentration limits of ignition of methanehydrogen fractions mixed with air in relation to the conditions of furnace volumes of power boilers is relevant. In this work using the in-house software [2-5] calculations were made to determine the burning rate for various compositions of mixtures of methane-hydrogen fractions (MHF) with Urengoi natural gas. It was found that the flame propagation rate of the MHF, compared with hydrogen (see Table 2), decreases 1.76 times. For a mixture of the MHF with Urengoi gas with thermal fractions of the MHF of 12% and 25%, the flame propagation rate increases, respectively, 1.4 times and 1.78 times compared with burning pure Urengoi gas.

Power Cycles of Generation III and III+ Nuclear Power Plants

2014 ◽  
Author(s):  
Alexey Dragunov ◽  
Eugene Saltanov ◽  
Igor Pioro ◽  
Pavel Kirillov ◽  
Romney Duffey
Keyword(s):  
Renewable Energy ◽  
Natural Gas ◽  
Thermal Efficiency ◽  
Nuclear Power ◽  
Power Plants ◽  
Renewable Energy Sources ◽  
Thermal Power ◽  
Electrical Energy ◽  
Energy Sources ◽  
Thermal Power Plants

It is well known that the electrical-power generation is the key factor for advances in any other industries, agriculture and level of living. In general, electrical energy can be generated by: 1) non-renewable-energy sources such as coal, natural gas, oil, and nuclear; and 2) renewable-energy sources such as hydro, wind, solar, biomass, geothermal and marine. However, the main sources for electrical-energy generation are: 1) thermal - primary coal and secondary natural gas; 2) “large” hydro and 3) nuclear. The rest of the energy sources might have visible impact just in some countries. Modern advanced thermal power plants have reached very high thermal efficiencies (55–62%). In spite of that they are still the largest emitters of carbon dioxide into atmosphere. Due to that, reliable non-fossil-fuel energy generation, such as nuclear power, becomes more and more attractive. However, current Nuclear Power Plants (NPPs) are way behind by thermal efficiency (30–42%) compared to that of advanced thermal power plants. Therefore, it is important to consider various ways to enhance thermal efficiency of NPPs. The paper presents comparison of thermodynamic cycles and layouts of modern NPPs and discusses ways to improve their thermal efficiencies.

The Commercial Potentials of Underground Natural Gas Storage in Nigeria

2021 ◽  
Author(s):  
Adedamola Adegun ◽  
Femi Rufai
Keyword(s):  
Natural Gas ◽  
Power Plants ◽  
Thermal Power ◽  
Gas Storage ◽  
Industrial Clusters ◽  
Domestic Market ◽  
Underground Gas Storage ◽  
Natural Gas Storage ◽  
Hydro Power ◽  
Energy Mix

Abstract Nigeria is the 2nd biggest natural gas producer in Africa, with much of it exported as LNG, some re-injected while a small fraction serves the domestic market. The volume supplied to the domestic market plays an outsized role in the energy mix and economy of Nigeria with over 90% supplied to thermal power plants and industrial clusters. As huge upstream gas projects continue to take Final Investment Decision, pipeline takeaway capacity grows and demand increases, the dependence on natural gas and preponderance in the energy mix will likely persist. Natural gas is the present and future of Nigeria's energy needs. The domestic gas industry is evolving but has been fraught with challenges. Oil and gas infrastructure are often disrupted and production shut-in, mostly triggered by infrastructure unavailablity, environmental concerns and prioritisation of hydro power generation during River Niger's white and black floods, all of which come at a cost to upstream producers. Gas producers are often compelled to curtail production of gas plants (associated and non-associated) to avoid environmental disasters and prohibitive gas flare penalties. Can underground gas storage (UGS) be an opportunity for gas producers to guarantee continued operations during disruptions and provide buffer for national strategic benefits? This paper seeks to explore the potential technical and economic dynamics of underground natural gas storage in Nigeria in the context of extant technical regulations, seasonal demand variations, gas flare penalties and local operating environment. The paper presents types of underground storages and recommends the most suitable, considers options for optimal location of UGS in Nigeria and undertakes an economic evaluation of a UGS project. The findings are further presented alongside the critical technical, regulatory and fiscal factors that may facilitate future investments and growth of underground gas storage in Nigeria.

Consumption of combustible minerals in the context of the targets of sustainable development of Ukraine and global environment changes

2021 ◽  
Vol 3-4 (185-186) ◽  
pp. 109-125
Author(s):  
Myroslav Podolskyy ◽  
Dmytro Bryk ◽  
Lesia Kulchytska-Zhyhailo ◽  
Oleh Gvozdevych
Keyword(s):  
Sustainable Development ◽  
Renewable Energy ◽  
Natural Gas ◽  
Power Plants ◽  
Renewable Energy Sources ◽  
Thermal Power ◽  
Energy Resource ◽  
Fuel Oil ◽  
Energy Sources ◽  
The European Union

An analysis of Ukraine’s sustainable development targets, in particular in the field of energy, resource management and environmental protection, are presented. It is shown that regional energetic is a determining factor for achieving the aims of sustainable development. Changes in the natural environment in Ukraine due to external (global) and internal (local) factors that are intertwined and overlapped can cause threats to socio-economic development. It is proved that in the areas of mining and industrial activity a multiple increase in emissions of pollutants into the environment are observed. The comparison confirmed the overall compliance of the structure of consumption of primary energy resources (solid fossil fuels, natural gas, nuclear fuel, oil and petroleum products, renewable energy sources) in Ukraine and in the European Union, shows a steaby trend to reduce the share of solid fuels and natural gas and increasing the shares of energy from renewable sources. For example, in Ukraine the shares in the production and cost of electricity in 2018 was: the nuclear power plants – 54.33 % and in the cost – 26.60 %, the thermal power – 35.95 and 59.52 %, the renewable energy sources – 9.6 and 13.88 %. The energy component must be given priority, as it is crucial for achieving of all other goals of sustainable development and harmonization of socio-economic progress. The paper systematizes the indicators of regional energy efficiency and proposes a dynamic model for the transition to sustainable energy development of the region.

SANITARY PROTECTION ZONES BY NOISE FACTOR FROM GAS DISTRIBUTION POINTS

Akustika ◽  
2021 ◽  
pp. 133-137
Author(s):  
Vladimir Tupov ◽  
Vitaliy Skvortsov
Keyword(s):  
Power Plant ◽  
Natural Gas ◽  
Thermal Power Plant ◽  
Power Plants ◽  
Thermal Power ◽  
Design Stage ◽  
Thermal Power Plants ◽  
Gas Distribution ◽  
Surrounding Area ◽  
Protection Zone

The power equipment of thermal power plants is a source of noise to the surrounding area. One of the sources of noise for the surrounding area are gas distribution points (GDP) of thermal power plants (TPP) and district thermal power plants (RTS). Noise from gas distribution points may exceed sanitary standards at the border of the sanitary protection zone. The article shows that the radiated noise from gas distribution points depends on the power of the thermal power plant (natural gas consumption) and the type of valves. Three types of valves used in gas distribution points are considered. Formulas are obtained for calculating the width of the sanitary protection zone for gas distribution points for thermal stations, depending on the consumption of natural gas (electric power of the thermal power plant) and the type of valve. It is shown that, depending on the valve used, the noise level at the border of the sanitary protection zone can either meet sanitary standards or exceed them. This allows at the design stage to select the required type of valve or to determine mitigation measures from hydraulic fracturing.

Advanced Gas Turbine Technology for Sendai Thermal Power Station, Unit No. 4

2011 ◽  
Author(s):  
Sadahiro Ohno ◽  
Hiroyuki Yamazaki ◽  
Naoki Hagi ◽  
Hidehiko Nishimura
Keyword(s):  
Carbon Dioxide ◽  
Natural Gas ◽  
Gas Turbine ◽  
Thermal Power Station ◽  
Thermal Efficiency ◽  
Power Plants ◽  
Thermal Power ◽  
Power Station ◽  
Advanced Technologies ◽  
Station Unit

Worldwide environmental concerns are placing center focus on effective utilization of energy and carbon dioxide emission reductions. The power generation industry has engaged in the replacement of existing aged thermal power plants with state-of-the-art natural gas fired power plants capable of achieving considerable reductions in energy consumption and emissions of green house gases. The replacement of three exiting 175MW heavy oil and coal-firing power plants with a highly effective 446MW gas-firing combined cycle power plant owned and operated by Tohoku Electric Power Company is one example of this effort. The construction of the new Sendai thermal power station, Unit No.4 started in November, 2007 achieving commercial operation in July, 2010. Mitsubishi Heavy Industries most recent 50Hz F class gas turbine upgrade, the M701F4 was adopted for this project. This engine is based on the successful M701F3 gas turbine with a 6% air flow increase and a slight bump of the turbine inlet temperature in order to achieve better thermal efficiency and more power output. The application of these advanced technologies resulted in a plant thermal efficiency of approximately 58% LHV of the new unit from the original 43% of the previous coal-firing units. The application of these advanced technologies and the use of natural gas resulted in a 2/3 carbon-dioxide emissions reduction.

Repowering: An Option for Refurbishment of Old Thermal Power Plants in Latin-American Countries

2010 ◽  
Author(s):  
Washington Orlando Irrazabal Bohorquez ◽  
Joa˜o Roberto Barbosa ◽  
Luiz Augusto Horta Nogueira ◽  
Electo E. Silva Lora
Keyword(s):  
Power Plant ◽  
Natural Gas ◽  
Steam Turbine ◽  
Gas Turbine ◽  
Power Plants ◽  
Thermal Power ◽  
Rankine Cycle ◽  
Combined Cycle ◽  
Fuel Oil ◽  
Thermal Power Plants

The operational rules for the electricity markets in Latin America are changing at the same time that the electricity power plants are being subjected to stronger environmental restrictions, fierce competition and free market rules. This is forcing the conventional power plants owners to evaluate the operation of their power plants. Those thermal power plants were built between the 1960’s and the 1990’s. They are old and inefficient, therefore generating expensive electricity and polluting the environment. This study presents the repowering of thermal power plants based on the analysis of three basic concepts: the thermal configuration of the different technological solutions, the costs of the generated electricity and the environmental impact produced by the decrease of the pollutants generated during the electricity production. The case study for the present paper is an Ecuadorian 73 MWe power output steam power plant erected at the end of the 1970’s and has been operating continuously for over 30 years. Six repowering options are studied, focusing the increase of the installed capacity and thermal efficiency on the baseline case. Numerical simulations the seven thermal power plants are evaluated as follows: A. Modified Rankine cycle (73 MWe) with superheating and regeneration, one conventional boiler burning fuel oil and one old steam turbine. B. Fully-fired combined cycle (240 MWe) with two gas turbines burning natural gas, one recuperative boiler and one old steam turbine. C. Fully-fired combined cycle (235 MWe) with one gas turbine burning natural gas, one recuperative boiler and one old steam turbine. D. Fully-fired combined cycle (242 MWe) with one gas turbine burning natural gas, one recuperative boiler and one old steam turbine. The gas turbine has water injection in the combustion chamber. E. Fully-fired combined cycle (242 MWe) with one gas turbine burning natural gas, one recuperative boiler with supplementary burners and one old steam turbine. The gas turbine has steam injection in the combustion chamber. F. Hybrid combined cycle (235 MWe) with one gas turbine burning natural gas, one recuperative boiler with supplementary burners, one old steam boiler burning natural gas and one old steam turbine. G. Hybrid combined cycle (235 MWe) with one gas turbine burning diesel fuel, one recuperative boiler with supplementary burners, one old steam boiler burning fuel oil and one old steam turbine. All the repowering models show higher efficiency when compared with the Rankine cycle [2, 5]. The thermal cycle efficiency is improved from 28% to 50%. The generated electricity costs are reduced to about 50% when the old power plant is converted to a combined cycle one. When a Rankine cycle power plant burning fuel oil is modified to combined cycle burning natural gas, the CO2 specific emissions by kWh are reduced by about 40%. It is concluded that upgrading older thermal power plants is often a cost-effective method for increasing the power output, improving efficiency and reducing emissions [2, 7].

scholarly journals CFD analysis of the combustion in the BERL burner fueled with a hydrogen-natural gas mixture

2020 ◽  
Vol 197 ◽  
pp. 10002
Author(s):  
Tommaso Capurso ◽  
Vito Ceglie ◽  
Francesco Fornarelli ◽  
Marco Torresi ◽  
Sergio M. Camporeale
Keyword(s):  
Natural Gas ◽  
Power Plants ◽  
Renewable Energy Sources ◽  
Thermal Power ◽  
Ghg Emissions ◽  
Combustion Model ◽  
Gas Mixture ◽  
Low Carbon ◽  
Radial Temperature ◽  
The Impact

The regulatory restrictions, currently acting, impose a significant reduction of the Greenhouse Gas (GHG) emissions. After the coal-to-gas transition of the last decades, the fossil fuel-to-renewables switching is the current perspective. However, the variability of energy production related to Renewable Energy Sources requires the fundamental contribution of thermal power plants in order to guaranty the grid stability. Moving toward a low-carbon society, the industry is looking at a reduction of high carbon content fuels, pointing to Natural Gas (NG) and more recently to hydrogen-NG mixtures. In this scenario, a preliminary study of the BERL swirled stabilized burner is carried out in order to understand the impact of blending natural gas with hydrogen on the flame morphology and CO emissions. Preliminary 3D CFD simulations have been run with the purpose to assess the best combination of combustion model (Non Premixed and Partially Premixed Falmelets), turbulence model (Realizable k ɛ and the Reynolds Stress equation model) and chemical kinetic mechanism (GriMech3.0, GriMech 1.2 and Frassoldati). The numerical results of the BERL burner fueled with natural gas have been compared with experimental data in terms of flow patterns, radial temperature profiles, O2, CO and CO2 concentrations. Finally, a 30% hydrogen in natural gas mixture has been considered, keeping fixed the thermal power output of the burner and the global equivalence ratio.

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