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Stefan Spinler - One of the best experts on this subject based on the ideXlab platform.
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capacity payment impact on gas fired generation investments under rising renewable feed in a real options analysis
Energy Economics, 2016Co-Authors: Daniel Hach, Stefan SpinlerAbstract:We assess the effect of capacity payments on investments in gas-fired power plants in the presence of different degrees of renewable energy technology (RET) penetration. Low variable cost renewables increasingly make investments in gas-fired generation unprofitable. At the same time, growing feed-in from intermittent RETs amplifies fluctuations in power generation, thus entailing the need for flexible buffer capacity—currently mostly gas-fired power plants. A real options approach is applied to evaluate investment decisions and timing of a single investor in gas-fired power generation. We investigate the necessity and effectiveness of capacity payments. Our model incorporates multiple uncertainties and assesses the effect of capacity payments under different degrees of RET penetration. In a numerical study, we implement stochastic processes for peak-Load Electricity prices and natural gas prices. We find that capacity payments are an effective measure to promote new gas-fired generation projects. Especially in times of high renewable feed-in, capacity payments are required to incentivize peak-Load investments.
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capacity payment impact on gas fired generation investments under rising renewable feed in a real options analysis
2013Co-Authors: Daniel Hach, Stefan SpinlerAbstract:We assess the effect of capacity payments on investments in gas-fired power plants in the presence of different degrees of renewable energy technology (RET) penetration. Low variable cost renewables increasingly make investments in gas-fired generation unprofitable. At the same time, growing feed-in from intermittent RETs amplifies fluctuations in power generation, thus entailing the need for flexible buffer capacity - currently mostly gas-fired power plants. We use a real options approach to evaluate investment decisions and timing of a single investor in gas fired power generation. We investigate the necessity and effectiveness of capacity payments. Our model incorporates multiple uncertainties and assesses the effect of capacity payments under different degrees of RET penetration. In a numerical study, we implement stochastic processes for peak-Load Electricity prices and natural gas prices. We find that capacity payments are an effective measure to promote new gas-fired generation projects. Especially in times of high renewable feed-in, capacity payments are required to incentivize peak-Load investments.
Eric David Larson - One of the best experts on this subject based on the ideXlab platform.
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biomass gasifier aeroderivative gas turbine combined cycles part a technologies and performance modeling
Journal of Engineering for Gas Turbines and Power-transactions of The Asme, 1996Co-Authors: Stefano Consonni, Eric David LarsonAbstract:Gas turbines fueled by integrated biomass gasifiers are a promising option for base-Load Electricity generation from a renewable resource. Aeroderivative turbines, which are characterized by high efficiencies at smaller scales, are of special interest because transportation costs for biomass constrain biomass conversion facilities to relatively modest scales. Commercial development activities and major technological issues associated with biomass integrated-gasifier/gas turbine (BIG/GT) combined cycle power generation are reviewed in Part A of this two-part paper. Also, the computational model and the assumptions used to predict the overall performance of alternative BIG/GT cycles are outlined. The model evaluates appropriate value of key parameters (turbomachinery efficiencies, gas turbine cooling flows. steam production in the heat recovery steam generator, etc.) and then carries out energy, mass, and chemical species balances for each plant component, with iterations to insure wholeplant consistency. Part B of the paper presents detailed comparisons of the predicted performance of systems now being proposed for commercial installation in the 25-30 MW e power output range, as well as predictions for advanced combined cycle configurations (including with intercooling) with outputs from 22 to 75 MW e . Finally, an economic assessment is presented, based on preliminary capital cost estimates for BIG/GT combined cycles.
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biomass gasifier aeroderivative gas turbine combined cycles part b performance calculations and economic assessment
Journal of Engineering for Gas Turbines and Power-transactions of The Asme, 1996Co-Authors: Stefano Consonni, Eric David LarsonAbstract:Gas turbines fueled by integrated biomass gasifiers are a promising option for base-Load Electricity generation from a renewable resource. Aeroderivative turbines, which are characterized by high efficiencies in small units, are of special interest because transportation costs for biomass constrain conversion facilities to relatively modest scales. Part A of this two-part paper reviewed commercial development activities and major technological issues associated with biomass integrated-gasifier/gas turbine (BIG/GT) combined cycle power generation. Based on the computational model also described in Part A, this paper (Part B) presents results of detailed design-point performance calculations for several BIG/GT combined cycle configurations. Emphasis is given to systems now being proposed for commercial installation in the 25-30 MW e power output range. Three different gasifier designs are considered: air-blown, pressurized fluidized-bed gasification; air-blown, near-atmospheric pressure fluidized-bed gasification; and near-atmospheric pressure, indirectly heated fluidized-bed gasification. Advanced combined cycle configurations (including with intercooling) with outputs from 22 to 75 MW are also explored. An economic assessment is also presented, based on preliminary capital cost estimates for BIG/GT combined cycles and expected biomass costs in several regions of the world.
Ali Abbas - One of the best experts on this subject based on the ideXlab platform.
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temporal multiscalar decision support framework for flexible operation of carbon capture plants targeting low carbon management of power plant emissions
Applied Energy, 2016Co-Authors: Norhuda Abdul Manaf, Abdul Qadir, Ali AbbasAbstract:A real-time control-optimization framework previously developed across multiple time scales is used for the analysis of power plant net operating revenue when retrofitted with a carbon capture plant. This framework which features high sample frequency commensurate with Electricity dispatch and control instrumentation levels is proposed as a decision support tool for flexible operation of the carbon capture plant while considering Electricity and carbon price dynamics. This paper presents the results of implementing this framework for operational flexibility of solvent-based post-combustion CO2 capture (PCC) process in response to power plant dynamic Loads (Load following and unit turndown). An integrated plant (power plant with PCC) subject to forecast 2020 Electricity and carbon prices is shown to generate yearly net operating revenue of approximately 12% of the gross revenue. While, the same integrated plant generates net operating revenue loss of roughly 13% under 2011 Electricity and carbon prices. These results underpin the strategy that employs the proposed optimization-based control framework for flexible operation of a PCC plant in the year 2020, because such framework captures financial benefits hidden in the dynamics of Electricity Load, Electricity and carbon price trends, and does so at high temporal resolution.
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dynamic modelling identification and preliminary control analysis of an amine based post combustion co2 capture pilot plant
Journal of Cleaner Production, 2016Co-Authors: Norhuda Abdul Manaf, Ashleigh Cousins, Paul Feron, Ali AbbasAbstract:Abstract Solvent-based post combustion CO 2 capture (PCC) is considered as a mature technology for dealing with CO 2 emissions from fossil-fired power plants. In this study, a mathematical black box model is developed to analyse the dynamic responses of a PCC pilot plant. The model identification reported the dynamics of variables of the key units in the plant, the absorber, rich/lean heat exchanger and desorber. Pilot plant dynamic data were used to develop a data-driven model for each unit operation. Individual models were integrated to produce a simplified 4 × 3 PCC process model of the PCC plant. The fastest dynamic with a time constant ranging from 2 to 3 min featured in the relationship between power plant flue gas flow rate and CO 2 concentration in the absorber off gas. Whereas, the slowest response with a process time constant between 9 and 27 min occurred in CO 2 concentration at the top of the stripper due to changes in reboiler heat duty. Preliminary control analysis using relative gain array (RGA) analysis suggested that carbon capture efficiency, CC (%), and energy performance, EP (MJ per kg of CO 2 captured), can be controlled by manipulating the lean solvent flow rate and reboiler heat duty, respectively. The proposed control structure was tested and tracked CC and EP random set point step changes in the range between 7–25 h and 4–5 h respectively. This study contributes to understanding transient variable behaviours in PCC plants; concurrent with current industrial requirements for controllability and flexible operation of PCC plants, in response to the dynamics of power plant Load, Electricity and carbon prices.
Charles Forsberg - One of the best experts on this subject based on the ideXlab platform.
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meeting the needs of a nuclear renewables electrical grid with a fluoride salt cooled high temperature reactor coupled to a nuclear air brayton combined cycle power system
Nuclear Technology, 2014Co-Authors: Charles Forsberg, Daniel CurtisAbstract:The traditional role of nuclear power has been the production of base-Load Electricity. However, the needs of the Electricity grid are changing because of (a) the introduction of significant electr...
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nuclear hydrogen using high temperature electrolysis and light water reactors for peak Electricity production
Nuclear Science, 2010Co-Authors: Charles Forsberg, Mujid S. KazimiAbstract:In a carbon-dioxide-constrained world, the primary methods to produce Electricity (nuclear, solar, wind and fossil fuels with carbon sequestration) have low operating costs and high capital costs. To minimise the cost of Electricity, these plants must operate at maximum capacity; however, the electrical outputs do not match changing Electricity demands with time. A system to produce intermediate and peak Electricity is described that uses light water reactors (LWR) and high temperature electrolysis. At times of low Electricity demand the LWR provides steam and Electricity to a high temperature steam electrolysis system to produce hydrogen and oxygen that are stored. At times of high Electricity demand, the reactor produces Electricity for the electrical grid. Additional peak Electricity is produced by combining the hydrogen and oxygen by operating the high temperature electrolysis units in reverse as fuel cells or using an oxy-hydrogen steam cycle. The storage and use of hydrogen and oxygen for intermediate and peak power production reduces the capital cost, increases the efficiency of the peak power production systems, and enables nuclear energy to be used to meet daily, weekly and seasonal changes in electrical demand. The economic viability is based on the higher Electricity prices paid for peak-Load Electricity.
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An Air-Brayton Nuclear-Hydrogen Combined-Cycle Peak- and Base-Load Electric Plant
Volume 6: Energy Systems: Analysis Thermodynamics and Sustainability, 2007Co-Authors: Charles ForsbergAbstract:A combined-cycle power plant is proposed that uses heat from a high-temperature nuclear reactor and hydrogen produced by the high-temperature reactor to meet base-Load and peak-Load electrical demands. For base-Load Electricity production, air is compressed; flows through a heat exchanger, where it is heated to between 700 and 900°C; and exits through a high-temperature gas turbine to produce Electricity. The heat, via an intermediate heat-transport loop, is provided by a high-temperature reactor. The hot exhaust from the Brayton-cycle turbine is then fed to a heat recovery steam generator that provides steam to a steam turbine for added electrical power production. To meet peak Electricity demand, after nuclear heating of the compressed air, hydrogen is injected into the combustion chamber, combusts, and heats the air to 1300°C - the operating conditions for a standard natural-gas-fired combined-cycle plant. This process increases the plant efficiency and power output. Hydrogen is produced at night by electrolysis or other methods using energy from the nuclear reactor and is stored until needed. Therefore, the Electricity output to the electric grid can vary from zero (i.e., when hydrogen is being produced) to the maximum peak power while the nuclear reactor operates at constant Load. Because nuclear heat raises air temperatures above the auto-ignition temperatures of the hydrogen and powers the air compressor, the power output can be varied rapidly (compared with the capabilities of fossil-fired turbines) to meet spinning reserve requirements and stabilize the grid. Copyright © 2007 by ASME.
Daniel Hach - One of the best experts on this subject based on the ideXlab platform.
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capacity payment impact on gas fired generation investments under rising renewable feed in a real options analysis
Energy Economics, 2016Co-Authors: Daniel Hach, Stefan SpinlerAbstract:We assess the effect of capacity payments on investments in gas-fired power plants in the presence of different degrees of renewable energy technology (RET) penetration. Low variable cost renewables increasingly make investments in gas-fired generation unprofitable. At the same time, growing feed-in from intermittent RETs amplifies fluctuations in power generation, thus entailing the need for flexible buffer capacity—currently mostly gas-fired power plants. A real options approach is applied to evaluate investment decisions and timing of a single investor in gas-fired power generation. We investigate the necessity and effectiveness of capacity payments. Our model incorporates multiple uncertainties and assesses the effect of capacity payments under different degrees of RET penetration. In a numerical study, we implement stochastic processes for peak-Load Electricity prices and natural gas prices. We find that capacity payments are an effective measure to promote new gas-fired generation projects. Especially in times of high renewable feed-in, capacity payments are required to incentivize peak-Load investments.
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capacity payment impact on gas fired generation investments under rising renewable feed in a real options analysis
2013Co-Authors: Daniel Hach, Stefan SpinlerAbstract:We assess the effect of capacity payments on investments in gas-fired power plants in the presence of different degrees of renewable energy technology (RET) penetration. Low variable cost renewables increasingly make investments in gas-fired generation unprofitable. At the same time, growing feed-in from intermittent RETs amplifies fluctuations in power generation, thus entailing the need for flexible buffer capacity - currently mostly gas-fired power plants. We use a real options approach to evaluate investment decisions and timing of a single investor in gas fired power generation. We investigate the necessity and effectiveness of capacity payments. Our model incorporates multiple uncertainties and assesses the effect of capacity payments under different degrees of RET penetration. In a numerical study, we implement stochastic processes for peak-Load Electricity prices and natural gas prices. We find that capacity payments are an effective measure to promote new gas-fired generation projects. Especially in times of high renewable feed-in, capacity payments are required to incentivize peak-Load investments.
