Methods of determining the admissible price of fuels for combined heat and power generating plants fired with natural gas
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The use of thermal energy storage (TES) in the latent heat of molten salts as a means of conserving fossil fuels and lowering the cost of electric power was evaluated. Public utility systems provided electric power on demand. This demand is generally maximum during late weekday afternoons, with considerably lower overnight and weekend loads. Typically, the average demand is only 60% to 80% of peak load. As peak load increases, the present practice is to purchase power from other grid facilities or to bring older less efficient fossil-fuel plants on line which increase the cost of electric power. The widespread use of oil-fired boilers, gas turbine and diesel equipment to meet peaking loads depletes our oil-based energy resources. Heat exchangers utilizing molten salts can be used to level the energy consumption curve. The study begins with a demand analysis and the consideration of several existing modern fossil-fuel and nuclear power plants for use as models. Salts are evaluated for thermodynamic, economic, corrosive, and safety characteristics. Heat exchanger concepts are explored and heat exchanger designs are conceived. Finally, the economics of TES conversions in existing plants and new construction is analyzed. The study concluded that TES is feasible in electric powermore » generation. Substantial data are presented for TES design, and reference material for further investigation of techniques is included.« less
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The authors have developed a methodology for conducting optimization studies of the operating modes of a cogeneration gas turbine plant, taking into account the determination of the dependence of the change in the price of one type of energy on the price of another type of energy. This approach helps to determine the options for technical solutions that ensure the competitiveness of the gas turbine plant relative to other heat and power generating plants and the most efficient option to choose. Two optimization problems are solved to determine the maximum and minimum boundaries of the heat price range: the problem of minimizing the energy price to determine the maximum heat price and the problem of minimizing the exergy price to find the minimum boundary of the heat price range. The problem of minimizing the price of electricity is solved for a given heat price and the rate of return on investment to build a Pareto-optimal set of solutions for the resulting price range. The results obtained can be used to select optimal technical solutions for construction and operation in regions with different climatic characteristics, that ensure the competitiveness of the products of this cogeneration gas turbine plant.
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Cogeneration is a process of fuel combustion that allows: •·simultaneous production and supply of heat and electric power; •simultaneous solution of challenges associated with power saving and environment protection; •commercialization on the basis of the existing boilers including a bio power fuel firing. The paper presents a survey of the existing heat schemes for cogeneration plants with the fossil types of the hydrocarbon fuel fired therein. An impracticability of using the naturally sustained bio fuels as a heat power source for the similar power plants is illustrated. Thus, an expediency of update of the operated power-and-heat boilers with bio fuel fired as wood chips to ensure generation of both the heat and electric power is underlined. It is noted that for the sake of the target above outlined it would be necessary to have a ceramic air heater built into the bio boiler design, this component being at the same time a part of the electric generator gas turbine engine drive.
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All combustion power plants operate inefficiently, with much of the fuel energy going to waste as heat. This heat can be exploited in a variety of ways, raising the overall efficiency of the power plant. Heat is used for district heating in some US and European cities but this has not proved widely popular. Some industries can also make use of steam for their processes. Wood and paper processing factories will often have their own power plant that supplies both heat and electricity. Combined heat and power plants are most effective when both electricity and heat are supplied to the same customers. Many types of power generation plant can be used for combined heat and power but coal-fired boilers, gas turbines and piston engine-based systems are the most common. Fuel cells can also be exploited. Sizing a combined heat and power plant correctly is the key to economic viability.
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Post-combustion capture retrofits are expected to a
near-term option for mitigating CO 2 emissions from existing
coal-fired power plants. Much of the literature proposes using
power from the existing coal plant and thermal integration of its
supercritical steam cycle with the stripper reboiler to supply the
energy needed for solvent regeneration and CO2 compression. This
study finds that using an auxiliary natural gas turbine plant to
meet the energetic demands of carbon capture and compression may
make retrofits more attractive compared to using thermal
integration in some circumstances. Natural gas auxiliary plants
increase the power output of the base plant and reduce
technological risk associated with CCS, but require favorable
natural gas prices and regional electricity demand for excess
electricity to make using an auxiliary plant more desirable. Three
different auxiliary plant technologies were compared to integration
for 90% capture from an existing, 500 MW supercritical coal plant.
CO2 capture and compression is simulated using Aspen Plus and a
monoethylamine (MEA) absorption process. Thermoflow software is
used to simulate three gas plant technologies. The three
technologies assessed are the gas turbine (GT) with heat recovery
steam generator (HRSG), gas turbine with HRSG and back pressure
steam turbine, and natural gas boiler with back pressure steam
turbine. The capital cost of the MEA unit is estimated using the
Aspen Icarus Process Evaluator, and the capital cost of the
external GT plants are estimated using the Thermoflow Plant
Engineering and Cost Estimator. The gas turbine options are found
to lead to electricity costs similar to integration, but their
performance is highly sensitive to the price of natural gas and the
economic impact of integration. Using a GT with a HRSG only has a
lower capital cost but generates less excess electricity than the
GT with HRSG and back pressure steam turbine. In order to generate
enough steam for the reboiler, a significant amount of excess power
was produced using both gas turbine configurations. This excess
power could be attractive for coal plants located in regions with
increasing electricity demand. An alternate capture plant scenario
where a greater demand for power exists relative to steam is also
considered. The economics of using auxiliary plant power improve
slightly under this alternate energy profile scenario, but the most
important factors affecting desirability of the auxiliary plant
retrofit remain the cost of natural gas, the full cost of
integration, and the potential for sale of excess
electricity.
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Substitute natural gas
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Integrated gasification combined-cycle plants are considered as one of the promising directions for the development of thermal power plants using fossil fuel. Interest in this area is explained by large natural reserves of coal and minimal harmful emissions into the atmosphere during the process of generator gas combustion. The aim of the study is to make the relationship between the specific investment and the efficiency of integrated gasification combined-cycle plant and to perform the optimization researches according to the criterions of minimum electricity price.
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