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Energy and the Environment
Published in Marc J. Assael, Geoffrey C. Maitland, Thomas Maskow, Urs von Stockar, William A. Wakeham, Stefan Will, Commonly Asked Questions in Thermodynamics, 2022
Marc J. Assael, Geoffrey C. Maitland, Thomas Maskow, Urs von Stockar, William A. Wakeham, Stefan Will
The overall capacity factor of an offshore system is typically only 40% of the nameplate capacity, so the actual power generated would be 0.4 × 5.4 MW = 2.2 MW. The annual electricity production is 2.2 × 3,600 × 24 × 365 MJ/a = 69.4 TJ/a or 19.3 GWh/a, enough to supply about 5,000 households with electricity. This illustrates the high generating capacity of a single wind turbine given the appropriate weather conditions; however replacing traditional large fossil fuel power plants with windfarms results in a much greater land footprint. As part of a windfarm, the turbine spacing has to be at least ten times the rotor length L to avoid wind interference and shadows; our example case would require (10 × 60)2 m2 = 360,000 m2 per turbine, giving a power density for the windfarm of 6 W/m2 (only about 30% of that delivered by a typical solar panel; see Table 7.7). Wind systems are therefore best suited to locations with a lot of available area and wind (e.g. offshore) but not much sun.
The Data Analysis and Result Interpretation Correlating Human Error and Technology Advancement in Nuclear Operation
Published in Jonathan K. Corrado, Technology, Human Performance, and Nuclear Facilities, 2023
The capacity factor for a power plant is calculated as the ratio between the observed output over a given period of time and the potential output if the facility were consistently running at its nameplate capacity. The calculation of the capacity factor involves dividing the amount of energy produced by a plant during a certain time by the amount of energy that would have been produced if the facility were always running at full capacity. The facility’s capacity factor depends on the type of fuel used, the facility’s design, and its age, among other factors.
Government policy, risk and investment timing
Published in Glen Wright, Sandy Kerr, Kate Johnson, Ocean Energy, 2017
Revenues will be a function of the rate paid per megawatt of electricity by an offtaker, plus any production-based subsidy legislated by government (e.g. feed-in tariff). The amount of electricity delivered will be a function of the installed capacity, the capacity factor (megawatts produced/nameplate capacity) of the installed devices, and their availability (uptime).
Internalizing the external cost of gaseous and particulate matter emissions from the coal-based thermal power plants in India
Published in Particulate Science and Technology, 2021
After attaining the theoretical maximum heat supplied when the power plant operates at its nameplate capacity all through the year assuming complete combustion, the rate of consumption of coal was calculated using the average gross calorific value (GCV) of coal in kJ/kg. The power plants of a given state use coal of various varieties from different sources. This work assumes that a particular state uses coal from a major coal reserve situated in or around the state as the Impact- Pathway approach of estimating the external cost includes the mining and transportation of coal to the plant. Also, the unit cost of electricity includes the operations, maintenance and transportation cost as well. The average proximate and ultimate analysis of the coal from that source was taken for analysis. The data on the source of coal and its calorific used for the installed capacity is given in Table 1. Rate of consumption of coal was calculated using the following relationship: wheremc is the rate of consumption of coal (in kg s−1)Heat supplied (in kJ s−1)GCV in kJ kg−1
The impacts of the coal-electricity price linkage on the profit efficiency of China’s thermal power plants
Published in International Journal of Production Research, 2019
Na Duan, Jun-Peng Guo, Peng Zhou, Bai-Chen Xie
We apply the methods introduced in Section 2 to study the profit inefficiency and its corresponding components of the Chinese thermal power plants during the period 2002–2011. We set the inputs and outputs the same as those in the methods section; that is, the inputs include capital (K), fossil fuel (F), and auxiliary electricity (AE), and the outputs are electricity (E) (desirable) and energy-induced CO2 emissions (C) (undesirable). The coal price is estimated using the coal price index of the province where the power plants are located. We referred to the method of Farsi, Filippini, and Greene (2006) to estimate the capital price as the ratio of the capital expenditure and installed capability. The original object is the electricity distribution sector and the installed capability stands for the total installed capacity of the utilities’ transformers. Here the installed capability corresponds to the nameplate capacity of the power plants. The carbon price is estimated by the historical trade price of the nearest carbon-trading pilot of the power plants. The descriptive statistics of the inputs and outputs are shown in Table 1.
A comprehensive assessment of solar and wind energy potential at the University of Lethbridge campus, a medium-sized western Canadian university
Published in International Journal of Green Energy, 2019
Fariborz Mansouri Kouhestani, James Byrne, Locke Spencer, Paul Hazendonk, Bryson Brown, Daniel Johnson
Wind power output is strongly dependent on the wind speed distribution across the region where wind turbines are placed and the type of wind turbines employed (Weis, Doukas, and Anderson 2010). Southern Alberta represented about 76% of the total wind generation installed capacity in the province at the end of 2016 (Alberta Electric System Operator 2017). These wind facilities performed with an average wind capacity factor (the ratio of the annual average output to the nameplate output) of 35% in 2016 (Alberta Electric System Operator 2017). The annual energy that a wind turbine will generate can be estimated by multiplying the nameplate capacity by the capacity factor and by 8760 h in a year (8784 h in a leap year) (Weis, Doukas, and Anderson 2010). With increase in wind speed in conjunction of increase in height, and with better matching between wind spectra and the turbine, the capacity factor can be increased significantly (Mathew 2006).