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Manfred Aigner - One of the best experts on this subject based on the ideXlab platform.
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performance analysis of the micro gas turbine turbec t100 with a new flox combustion system for low calorific fuels
Applied Energy, 2015Co-Authors: Timo Zornek, Thomas Monz, Manfred AignerAbstract:This paper presents the first combustion system, which has been designed for the use of biomass derived product gases in micro gas turbines. The operating performance of the combustion system and of the micro gas turbine Turbec T100 was analyzed experimentally with synthetically mixed fuel compositions. Reliable start-up procedures and steady-state operation were observed. The Turbec T100 reached an electrical power output of 50 to 100kWel with a lower heating value of 5.0MJ/kg. Compared to natural gas, the electrical power output was noticeably higher at constant turbine speeds. Therefore, operation was limited by the power electronic at low speeds, while a second limitation was compressor surging at high speeds. To avoid surging, the turbine outlet temperature had to be reduced at turbine speeds between 64,400rpm and its maximum of 70,000rpm. The pressure losses across the FLOX-combustion chamber remained below 4%, which corresponds to a reduction of 30% compared to the Turbec combustion chamber fired with natural gas. Low pollutant emissions, i.e. CO<30ppm, NOx<6ppm and unburnt hydrocarbons <1ppm, were obtained over the whole operating range. Further optimization potential of the Turbec T100 was analyzed numerically. Neglecting compressor surging and the limitations of the power electronic, the numerical simulations predicted a maximum power output of 137kWel. The ability of the micro gas turbine to run with low calorific fuels is demonstrated and optimization potential is specified.
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Performance analysis of the micro gas turbine Turbec T100 with a new FLOX-combustion system for low calorific fuels
Applied Energy, 2015Co-Authors: Timo Zornek, Thomas Monz, Manfred AignerAbstract:This paper presents the first combustion system, which has been designed for the use of biomass derived product gases in micro gas turbines. The operating performance of the combustion system and of the micro gas turbine Turbec T100 was analyzed experimentally with synthetically mixed fuel compositions. Reliable start-up procedures and steady-state operation were observed. The Turbec T100 reached an electrical power output of 50 to 100kWel with a lower heating value of 5.0MJ/kg. Compared to natural gas, the electrical power output was noticeably higher at constant turbine speeds. Therefore, operation was limited by the power electronic at low speeds, while a second limitation was compressor surging at high speeds. To avoid surging, the turbine outlet temperature had to be reduced at turbine speeds between 64,400rpm and its maximum of 70,000rpm. The pressure losses across the FLOX-combustion chamber remained below 4%, which corresponds to a reduction of 30% compared to the Turbec combustion chamber fired with natural gas. Low pollutant emissions, i.e. CO
Timo Zornek - One of the best experts on this subject based on the ideXlab platform.
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performance analysis of the micro gas turbine turbec t100 with a new flox combustion system for low calorific fuels
Applied Energy, 2015Co-Authors: Timo Zornek, Thomas Monz, Manfred AignerAbstract:This paper presents the first combustion system, which has been designed for the use of biomass derived product gases in micro gas turbines. The operating performance of the combustion system and of the micro gas turbine Turbec T100 was analyzed experimentally with synthetically mixed fuel compositions. Reliable start-up procedures and steady-state operation were observed. The Turbec T100 reached an electrical power output of 50 to 100kWel with a lower heating value of 5.0MJ/kg. Compared to natural gas, the electrical power output was noticeably higher at constant turbine speeds. Therefore, operation was limited by the power electronic at low speeds, while a second limitation was compressor surging at high speeds. To avoid surging, the turbine outlet temperature had to be reduced at turbine speeds between 64,400rpm and its maximum of 70,000rpm. The pressure losses across the FLOX-combustion chamber remained below 4%, which corresponds to a reduction of 30% compared to the Turbec combustion chamber fired with natural gas. Low pollutant emissions, i.e. CO<30ppm, NOx<6ppm and unburnt hydrocarbons <1ppm, were obtained over the whole operating range. Further optimization potential of the Turbec T100 was analyzed numerically. Neglecting compressor surging and the limitations of the power electronic, the numerical simulations predicted a maximum power output of 137kWel. The ability of the micro gas turbine to run with low calorific fuels is demonstrated and optimization potential is specified.
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Performance analysis of the micro gas turbine Turbec T100 with a new FLOX-combustion system for low calorific fuels
Applied Energy, 2015Co-Authors: Timo Zornek, Thomas Monz, Manfred AignerAbstract:This paper presents the first combustion system, which has been designed for the use of biomass derived product gases in micro gas turbines. The operating performance of the combustion system and of the micro gas turbine Turbec T100 was analyzed experimentally with synthetically mixed fuel compositions. Reliable start-up procedures and steady-state operation were observed. The Turbec T100 reached an electrical power output of 50 to 100kWel with a lower heating value of 5.0MJ/kg. Compared to natural gas, the electrical power output was noticeably higher at constant turbine speeds. Therefore, operation was limited by the power electronic at low speeds, while a second limitation was compressor surging at high speeds. To avoid surging, the turbine outlet temperature had to be reduced at turbine speeds between 64,400rpm and its maximum of 70,000rpm. The pressure losses across the FLOX-combustion chamber remained below 4%, which corresponds to a reduction of 30% compared to the Turbec combustion chamber fired with natural gas. Low pollutant emissions, i.e. CO
Robert H Socolow - One of the best experts on this subject based on the ideXlab platform.
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baseload wind energy modeling the competition between gas turbines and compressed air energy storage for supplemental generation
Energy Policy, 2007Co-Authors: Jeffery B Greenblatt, Samir Succar, David Denkenberger, Robert H Williams, Robert H SocolowAbstract:Abstract The economic viability of producing baseload wind energy was explored using a cost-optimization model to simulate two competing systems: wind energy supplemented by simple- and combined cycle natural gas turbines (“wind+gas”), and wind energy supplemented by compressed air energy storage (“wind+CAES”). Pure combined cycle natural gas turbines (“gas”) were used as a proxy for conventional baseload generation. Long-distance electric transmission was integral to the analysis. Given the future uncertainty in both natural gas price and greenhouse gas (GHG) emissions price, we introduced an effective fuel price, p NGeff , being the sum of the real natural gas price and the GHG price. Under the assumption of p NGeff =$5/GJ (lower heating value), 650 W/m 2 wind resource, 750 km transmission line, and a fixed 90% capacity factor, wind+CAES was the most expensive system at ¢6.0/kWh, and did not break even with the next most expensive wind+gas system until p NGeff =$9.0/GJ. However, under real market conditions, the system with the least dispatch cost (short-run marginal cost) is dispatched first, attaining the highest capacity factor and diminishing the capacity factors of competitors, raising their total cost. We estimate that the wind+CAES system, with a greenhouse gas (GHG) emission rate that is one-fourth of that for natural gas combined cycle plants and about one-tenth of that for pulverized coal plants, has the lowest dispatch cost of the alternatives considered (lower even than for coal power plants) above a GHG emissions price of $35/tC equiv. , with good prospects for realizing a higher capacity factor and a lower total cost of energy than all the competing technologies over a wide range of effective fuel costs. This ability to compete in economic dispatch greatly boosts the market penetration potential of wind energy and suggests a substantial growth opportunity for natural gas in providing baseload power via wind+CAES, even at high natural gas prices.
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baseload wind energy modeling the competition between gas turbines and compressed air energy storage for supplemental generation
Energy Policy, 2007Co-Authors: Jeffery B Greenblatt, Samir Succar, David Denkenberger, Robert H Williams, Robert H SocolowAbstract:Abstract The economic viability of producing baseload wind energy was explored using a cost-optimization model to simulate two competing systems: wind energy supplemented by simple- and combined cycle natural gas turbines (“wind+gas”), and wind energy supplemented by compressed air energy storage (“wind+CAES”). Pure combined cycle natural gas turbines (“gas”) were used as a proxy for conventional baseload generation. Long-distance electric transmission was integral to the analysis. Given the future uncertainty in both natural gas price and greenhouse gas (GHG) emissions price, we introduced an effective fuel price, p NGeff , being the sum of the real natural gas price and the GHG price. Under the assumption of p NGeff =$5/GJ (lower heating value), 650 W/m 2 wind resource, 750 km transmission line, and a fixed 90% capacity factor, wind+CAES was the most expensive system at ¢6.0/kWh, and did not break even with the next most expensive wind+gas system until p NGeff =$9.0/GJ. However, under real market conditions, the system with the least dispatch cost (short-run marginal cost) is dispatched first, attaining the highest capacity factor and diminishing the capacity factors of competitors, raising their total cost. We estimate that the wind+CAES system, with a greenhouse gas (GHG) emission rate that is one-fourth of that for natural gas combined cycle plants and about one-tenth of that for pulverized coal plants, has the lowest dispatch cost of the alternatives considered (lower even than for coal power plants) above a GHG emissions price of $35/tC equiv. , with good prospects for realizing a higher capacity factor and a lower total cost of energy than all the competing technologies over a wide range of effective fuel costs. This ability to compete in economic dispatch greatly boosts the market penetration potential of wind energy and suggests a substantial growth opportunity for natural gas in providing baseload power via wind+CAES, even at high natural gas prices.
Thomas Monz - One of the best experts on this subject based on the ideXlab platform.
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performance analysis of the micro gas turbine turbec t100 with a new flox combustion system for low calorific fuels
Applied Energy, 2015Co-Authors: Timo Zornek, Thomas Monz, Manfred AignerAbstract:This paper presents the first combustion system, which has been designed for the use of biomass derived product gases in micro gas turbines. The operating performance of the combustion system and of the micro gas turbine Turbec T100 was analyzed experimentally with synthetically mixed fuel compositions. Reliable start-up procedures and steady-state operation were observed. The Turbec T100 reached an electrical power output of 50 to 100kWel with a lower heating value of 5.0MJ/kg. Compared to natural gas, the electrical power output was noticeably higher at constant turbine speeds. Therefore, operation was limited by the power electronic at low speeds, while a second limitation was compressor surging at high speeds. To avoid surging, the turbine outlet temperature had to be reduced at turbine speeds between 64,400rpm and its maximum of 70,000rpm. The pressure losses across the FLOX-combustion chamber remained below 4%, which corresponds to a reduction of 30% compared to the Turbec combustion chamber fired with natural gas. Low pollutant emissions, i.e. CO<30ppm, NOx<6ppm and unburnt hydrocarbons <1ppm, were obtained over the whole operating range. Further optimization potential of the Turbec T100 was analyzed numerically. Neglecting compressor surging and the limitations of the power electronic, the numerical simulations predicted a maximum power output of 137kWel. The ability of the micro gas turbine to run with low calorific fuels is demonstrated and optimization potential is specified.
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Performance analysis of the micro gas turbine Turbec T100 with a new FLOX-combustion system for low calorific fuels
Applied Energy, 2015Co-Authors: Timo Zornek, Thomas Monz, Manfred AignerAbstract:This paper presents the first combustion system, which has been designed for the use of biomass derived product gases in micro gas turbines. The operating performance of the combustion system and of the micro gas turbine Turbec T100 was analyzed experimentally with synthetically mixed fuel compositions. Reliable start-up procedures and steady-state operation were observed. The Turbec T100 reached an electrical power output of 50 to 100kWel with a lower heating value of 5.0MJ/kg. Compared to natural gas, the electrical power output was noticeably higher at constant turbine speeds. Therefore, operation was limited by the power electronic at low speeds, while a second limitation was compressor surging at high speeds. To avoid surging, the turbine outlet temperature had to be reduced at turbine speeds between 64,400rpm and its maximum of 70,000rpm. The pressure losses across the FLOX-combustion chamber remained below 4%, which corresponds to a reduction of 30% compared to the Turbec combustion chamber fired with natural gas. Low pollutant emissions, i.e. CO
Mathieu Lucquiaud - One of the best experts on this subject based on the ideXlab platform.
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on the retrofitting and repowering of coal power plants with post combustion carbon capture an advanced integration option with a gas turbine windbox
International Journal of Greenhouse Gas Control, 2017Co-Authors: Maria Sanchez Del Rio, Jonathan Gibbins, Mathieu LucquiaudAbstract:Retrofitting a significant fraction of existing coal-fired power plants is likely to be an important part of a global rollout of carbon capture and storage. For plants suited for a retrofit, the energy penalty for post-combustion carbon capture can be minimised by effective integration of the capture system with the power cycle. Previous work on effective integration options has typically been focused on either steam extraction from the power cycle with a reduction of the site power output, or the supply of heat and electricity to the capture system via the combustion of natural gas, with little consideration for the associated carbon emissions. This article proposes an advanced integration concept between the gas turbine, the existing coal plant and post-combustion capture processes with capture of carbon emissions from both fuels. The exhaust gas of the gas turbine enters the existing coal boiler via the windbox for sequential combustion to allow capture in a single dedicated capture plant, with a lower flow rate and a higher CO2 concentration of the resulting flue gas. With effective integration of the heat recovery steam generator with the boiler, the existing steam cycle and the carbon capture process, the reference subcritical unit used in this study can be repowered with an electricity output penalty of 295 kWh/tCO2 – 5% lower than a conventional steam extraction retrofit of the same unit – and marginal thermal efficiency of natural gas combustion of 50% LHV – 5% point higher than in a configuration where the gas turbine has a dedicated capture unit.
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sequential supplementary firing in natural gas combined cycle with carbon capture a technology option for mexico for low carbon electricity generation and co2 enhanced oil recovery
International Journal of Greenhouse Gas Control, 2016Co-Authors: Abigail Gonzalez Diaz, Eva Sanchez Fernandez, Jonathan Gibbins, Mathieu LucquiaudAbstract:Abstract Combined cycle gas turbine power plants with sequential supplementary firing in the heat recovery steam generator could be an attractive alternative for markets with access to competitive natural gas prices, with an emphasis on capital cost reduction, and where supply of carbon dioxide for Enhanced Oil Recovery (EOR) is important. Sequential combustion makes use of the excess oxygen in gas turbine exhaust gas to generate additional CO 2 , but, unlike in conventional supplementary firing, allows keeping gas temperatures in the heat recovery steam generator below 820 °C, avoiding a step change in capital costs. It marginally decreases relative energy requirements for solvent regeneration and amine degradation. Power plant models integrated with capture and compression process models of Sequential Supplementary Firing Combined Cycle (SSFCC) gas-fired units show that the efficiency penalty is 8.2% points LHV compared to a conventional natural gas combined cycle power plant with the same capture technology. The marginal thermal efficiency of natural gas firing in the heat recovery steam generator can increase with supercritical steam generation to reduce the efficiency penalty to 5.7% points LHV. Although the efficiency is lower than the conventional configuration, the increment in the power output of the combined steam cycle leads a reduction of the number of gas turbines, at a similar power output to that of a conventional natural gas combined cycle. This has a positive impact on the number of absorbers and the capital costs of the post combustion capture plant by reducing the total volume of flue gas by half on a normalised basis. The relative reduction of overall capital costs is, respectively, 15.3% and 9.1% for the subcritical and the supercritical combined cycle configurations with capture compared to a conventional configuration. For a gas price of $2/MMBTU, the Total Revenue Requirement (TRR) – a metric combining levelised cost of electricity and revenue from EOR – of subcritical and supercritical sequential supplementary firing is consistently lower than that of a conventional NGCC by, respectively, 2.2 and 5.7 $/MWh at 0 $/t CO 2 and by 4.9 and 6.7 $/MWh at $50/t CO 2 . At a gas price of $4/MMBTU and $6/MMBTU, the TRR of a subcritical configuration is consistently lower for any carbon selling price higher than 2.5 $/t CO 2 and 37 $/t CO 2 respectively.