scholarly journals Combustion of Coal-Derived Fuel Gas in an Oxygen-Blown Pressurized Topping Combustor

1997 ◽  
Author(s):  
Peter D. J. Hoppesteyn ◽  
Jans Andries ◽  
Klaus R. G. Hein
Keyword(s):  
Carbon Dioxide ◽  
Gas Turbine ◽  
Flue Gas ◽  
Carbon Dioxide Concentration ◽  
The United States ◽  
Combined Cycle ◽  
Fluidised Bed ◽  
Successful Operation ◽  
Fuel Gas ◽  
System Pressure

Advanced integrated gasification combined cycle (IGCC) plants promise to be efficient and environmentally friendly systems to utilise solid fuels for the production of electricity and heat. An IGCC system consists of a gasifier, producing a low calorific value (LCV) fuel gas, and a gas turbine in which the LCV fuel gas is being combusted. At this time some demonstration IGCC plants have been commissioned in the United States and Europe. A sound understanding of the interaction between the gasifier and the gas turbine combustor is critical for successful operation of an IGCC system. Reliable theoretical and experimental information on the characteristics of the gas turbine as a whole and the combustor as such, leading to this information is needed prior to commercialisation of these IGCC systems. The combustion of natural gas in gas turbine combustors has been studied extensively. The combustion of coal-derived LCV fuel gas however has been studied in much less detail. To obtain more fundamental data on the combustion of LCV fuel gas, a 1.5 MW pressurised fluidised bed gasifier (PFBG) with a separate pressurised topping combustor (PTC) has been designed, built and operated at Delft University of Technology (The Netherlands). The maximum system pressure is 10 bar. Experiments have been performed at 8 bar, using recirculated flue gas, steam and oxygen as gasifying agents. The produced LCV fuel gas is combusted in an oxygen blown PTC. In this way a flue gas with a high carbon dioxide concentration can be obtained from which the carbon dioxide can be removed more easily than from flue gases. A numerical model has been constructed to simulate the combustion of the LCV fuel gas in the PTC. A detailed description of the test rig will be given. The first experimental results will be described and compared with simulation results obtained with the commercial Computational Fluid Dynamics code Fluent version 4.3. Finally the future work will be described.

scholarly journals Powering Ahead

2011 ◽  
Vol 133 (05) ◽  
pp. 30-33 ◽  
Author(s):  
Lee S. Langston
Keyword(s):  
Power Plant ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Nuclear Power ◽  
Electrical Power ◽  
The United States ◽  
Combined Cycle ◽  
Electrical Power System ◽  
Efficient Technology ◽  
The Military

This article explores the increasing use of natural gas in different turbine industries and in turn creating an efficient electrical system. All indications are that the aviation market will be good for gas turbine production as airlines and the military replace old equipment and expanding economies such as China and India increase their air travel. Gas turbines now account for some 22% of the electricity produced in the United States and 46% of the electricity generated in the United Kingdom. In spite of this market share, electrical power gas turbines have kept a much lower profile than competing technologies, such as coal-fired thermal plants and nuclear power. Gas turbines are also the primary device behind the modern combined power plant, about the most fuel-efficient technology we have. Mitsubishi Heavy Industries is developing a new J series gas turbine for the combined cycle power plant market that could achieve thermal efficiencies of 61%. The researchers believe that if wind turbines and gas turbines team up, they can create a cleaner, more efficient electrical power system.

Gas Turbine Combined Cycle With CO2-Capture Using Auto-Thermal Reforming of Natural Gas

2000 ◽  
Author(s):  
Thormod Andersen ◽  
Hanne M. Kvamsdal ◽  
Olav Bolland
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Process Integration ◽  
Combined Cycle ◽  
Co2 Removal ◽  
Gas Turbine Combustor ◽  
Chemical Absorption ◽  
Fuel Gas ◽  
The Impact ◽  
Water Gas

A concept for capturing and sequestering CO2 from a natural gas fired combined cycle power plant is presented. The present approach is to decarbonise the fuel prior to combustion by reforming natural gas, producing a hydrogen-rich fuel. The reforming process consists of an air-blown pressurised auto-thermal reformer that produces a gas containing H2, CO and a small fraction of CH4 as combustible components. The gas is then led through a water gas shift reactor, where the equilibrium of CO and H2O is shifted towards CO2 and H2. The CO2 is then captured from the resulting gas by chemical absorption. The gas turbine of this system is then fed with a fuel gas containing approximately 50% H2. In order to achieve acceptable level of fuel-to-electricity conversion efficiency, this kind of process is attractive because of the possibility of process integration between the combined cycle and the reforming process. A comparison is made between a “standard” combined cycle and the current process with CO2-removal. This study also comprise an investigation of using a lower pressure level in the reforming section than in the gas turbine combustor and the impact of reduced steam/carbon ratio in the main reformer. The impact on gas turbine operation because of massive air bleed and the use of a hydrogen rich fuel is discussed.

Analysis of Intermediate Temperature Combined Cycles With a Carbon Dioxide Topping Cycle

2008 ◽  
Author(s):  
R. Chacartegui ◽  
D. Sa´nchez ◽  
F. Jime´nez-Espadafor ◽  
A. Mun˜oz ◽  
T. Sa´nchez
Keyword(s):  
Carbon Dioxide ◽  
Power Plant ◽  
Gas Turbine ◽  
High Efficiency ◽  
Solar Power ◽  
Combined Cycle ◽  
Inlet Temperature ◽  
Pressure Drops ◽  
Combined Cycles ◽  
Topping Cycle

The development of high efficiency solar power plants based on gas turbine technology presents two problems, both of them directly associated with the solar power plant receiver design and the power plant size: lower turbine intake temperature and higher pressure drops in heat exchangers than in a conventional gas turbine. To partially solve these problems, different configurations of combined cycles composed of a closed cycle carbon dioxide gas turbine as topping cycle have been analyzed. The main advantage of the Brayton carbon dioxide cycle is its high net shaft work to expansion work ratio, in the range of 0.7–0.85 at supercritical compressor intake pressures, which is very close to that of the Rankine cycle. This feature will reduce the negative effects of pressure drops and will be also very interesting for cycles with moderate turbine inlet temperature (800–1000 K). Intercooling and reheat options are also considered. Furthermore, different working fluids have been analyzed for the bottoming cycle, seeking the best performance of the combined cycle in the ranges of temperatures considered.

Thermo-Economic Assessment Under Electrical Market Uncertainties of a Combined Cycle Gas Turbine Integrated With a Flue Gas-Condensing Heat Pump

2020 ◽  
Author(s):  
Alberto Vannoni ◽  
Andrea Giugno ◽  
Alessandro Sorce
Keyword(s):  
Power Plant ◽  
Power Systems ◽  
Gas Turbine ◽  
Heat Pump ◽  
Flue Gas ◽  
Power Plants ◽  
Greenhouse Gas Emission ◽  
Capital Expenditure ◽  
Combined Cycle ◽  
Gas Turbine Power Plant

Abstract Renewable energy penetration is growing, due to the target of greenhouse-gas-emission reduction, even though fossil fuel-based technologies are still necessary in the current energy market scenario to provide reliable back-up power to stabilize the grid. Nevertheless, currently, an investment in such a kind of power plant might not be profitable enough, since some energy policies have led to a general decrease of both the average price of electricity and its variability; moreover, in several countries negative prices are reached on some sunny or windy days. Within this context, Combined Heat and Power systems appear not just as a fuel-efficient way to fulfill local thermal demand, but also as a sustainable way to maintain installed capacity able to support electricity grid reliability. Innovative solutions to increase both the efficiency and flexibility of those power plants, as well as careful evaluations of the economic context, are essential to ensure the sustainability of the economic investment in a fast-paced changing energy field. This study aims to evaluate the economic viability and environmental impact of an integrated solution of a cogenerative combined cycle gas turbine power plant with a flue gas condensing heat pump. Considering capital expenditure, heat demand, electricity price and its fluctuations during the whole system life, the sustainability of the investment is evaluated taking into account the uncertainties of economic scenarios and benchmarked against the integration of a cogenerative combined cycle gas turbine power plant with a Heat-Only Boiler.

Calculated Ground Level Concentration of Pollutants From Gas Turbine Using an Air Quality Display Model Computer Program

1974 ◽  
Author(s):  
N. R. Dibelius ◽  
George Touchton ◽  
Thomas Kane
Keyword(s):  
Air Quality ◽  
Computer Program ◽  
Gas Turbine ◽  
Meteorological Data ◽  
Ground Level ◽  
The United States ◽  
Combined Cycle ◽  
Ground Level Concentration ◽  
Model Computer ◽  
Two Machines

This paper contains the calculated ground level concentrations of air pollutants from 11 gas turbine models. These calculations were made using Charlotte, N.C. meteorological data. Four of these are simple cycle machines covering a range of size from 5050 hp to 65 MW and four are regenerative machines. Another three are combined cycle (STAG) machines, two machines having unfired and one having a fired heat recovery steam generator. The calculations were made using a slightly modified version of the United States Environmental Protection Agencies Air Quality Display Model Computer Program.

Thermoeconomic Analysis of a Gas Turbine Plant With Fuel Decarbonization and Carbon Dioxide Sequestration

2002 ◽  
Author(s):  
M. Bozzolo ◽  
M. Brandani ◽  
A. Traverso ◽  
A. F. Massardo
Keyword(s):  
Carbon Dioxide ◽  
Gas Turbine ◽  
Capital Investment ◽  
Carbon Tax ◽  
Carbon Dioxide Sequestration ◽  
Production Costs ◽  
Fuel Gas ◽  
Total Capital ◽  
Total Capital Investment ◽  
Water Gas

In this paper the thermoeconomic analysis of gas turbine plants with fuel decarbonisation and carbon dioxide sequestration is presented. The study focuses on the amine (MEA) decarbonisation plant lay-out and design, also providing economic data about the total capital investment costs of the plant. The system is fuelled with methane that is chemically treated through a partial oxidation and a water-gas shift reactor. CO2 is captured from the resulting gas mixture, using an absorbing solution of water and MEA that is continuously re-circulated through an absorption tower and a regeneration tower: the decarbonised fuel gas is afterwards burned in the gas turbine. The heat required by CO2 sequestration is mainly recovered from the gas turbine exhausts and partially from the fuel treatment section. The reduction in efficiency and the increase in energy production costs due to fuel amine decarbonisation is evaluated and discussed for different gas turbine sizes and technologies (microturbine, small size regenerated, aeroderivative, heavy duty). The necessary level of carbon tax for a conventional plant without a fuel decarbonisation section is calculated and a comparison with the Carbon Exergy Tax procedure is carried out, showing the good agreement of the results.

Optimization Concerns for Combined Cycle Power Plants: II — Optimum Fuel Gas Heating

2003 ◽  
Author(s):  
Walter I. Serbetci
Keyword(s):  
Gas Turbine ◽  
Power Output ◽  
Heat Rate ◽  
Combined Cycle ◽  
Hot Water ◽  
Fuel Temperature ◽  
General Electric ◽  
Fuel Gas ◽  
Gas Heating ◽  
Overall Efficiency

As the second study in a sequence of studies conducted on the optimization of combined cycle plants [Ref. 1], this paper presents the effects of fuel gas heating on plant performance and plant economics for various 1×1×1 configurations. First, the theoretical background is presented to explain the effects of fuel gas heating on combustion turbine efficiency and on the overall efficiency of the combined cycle plant. Then, *CycleDeck-Performance Estimator™ and *GateCycle™ computer codes were used to investigate the impact of fuel gas heating on various 1×1×1 configurations. The configurations studied here are: 1) GE CC107FA with three pressure/reheat HRSG and General Electric PG7241(FA) gas turbine (Fig. 1), 2) GE CC106FA with three pressure/reheat HRSG and General Electric PG6101(FA) gas turbine and, 3) GE CC 107EA with three pressure/non-reheat HRSG with General Electric PG7121(EA) gas turbine. In all calculations, natural gas with high methane percentage is used as a typical fuel gas. Hot water from the outlet of IP economizer is used to heat the fuel gas from its supply temperature of 80 °F (27 °C). Heating the fuel gas to target temperatures of 150 °F, 200 °F, 250° F, 300 °F, 350 °F, 375 °F, 400 °F and 425 °F ( 66, 93, 121, 149, 177, 191, 204 and 218 °C), the combustion turbine power output, the combustion turbine heat rate and the plant power output and the corresponding heat rate are determined for each target fuel temperature. For each configuration, the heat transfer surface required to heat the fuel gas to the given target temperatures are also determined and budgetary price quotes are obtained for the fuel gas heaters. As expected, as the fuel temperature is increased, the overall efficiency (therefore the heat rate) improved, however at the expense of some small power output loss. Factoring in the fuel cost savings, the opportunity cost of the power lost, the cost of the various size performance heaters and the incremental auxiliary power consumption (if any), a cost-benefit analysis is carried out and the economically optimum fuel temperature and the corresponding performance heater size are determined for each 1×1×1 configuration.

scholarly journals Conceptual Mean-Line Design of Single and Twin-Shaft Oxy-Fuel Gas Turbine in a Semiclosed Oxy-Fuel Combustion Combined Cycle

2013 ◽  
Vol 135 (8) ◽  
Author(s):  
Majed Sammak ◽  
Egill Thorbergsson ◽  
Tomas Grönstedt ◽  
Magnus Genrup
Keyword(s):  
Mach Number ◽  
Gas Turbine ◽  
Mass Flow ◽  
Rotational Speed ◽  
Gas Turbines ◽  
Combined Cycle ◽  
Fuel Gas ◽  
Power Turbine ◽  
Exit Mach Number ◽  
Line Design

The aim of this study was to compare single- and twin-shaft oxy-fuel gas turbines in a semiclosed oxy-fuel combustion combined cycle (SCOC–CC). This paper discussed the turbomachinery preliminary mean-line design of oxy-fuel compressor and turbine. The conceptual turbine design was performed using the axial through-flow code luax-t, developed at Lund University. A tool for conceptual design of axial compressors developed at Chalmers University was used for the design of the compressor. The modeled SCOC–CC gave a net electrical efficiency of 46% and a net power of 106 MW. The production of 95% pure oxygen and the compression of CO2 reduced the gross efficiency of the SCOC–CC by 10 and 2 percentage points, respectively. The designed oxy-fuel gas turbine had a power of 86 MW. The rotational speed of the single-shaft gas turbine was set to 5200 rpm. The designed turbine had four stages, while the compressor had 18 stages. The turbine exit Mach number was calculated to be 0.6 and the calculated value of AN2 was 40 · 106 rpm2m2. The total calculated cooling mass flow was 25% of the compressor mass flow, or 47 kg/s. The relative tip Mach number of the compressor at the first rotor stage was 1.15. The rotational speed of the twin-shaft gas generator was set to 7200 rpm, while that of the power turbine was set to 4800 rpm. A twin-shaft turbine was designed with five turbine stages to maintain the exit Mach number around 0.5. The twin-shaft turbine required a lower exit Mach number to maintain reasonable diffuser performance. The compressor turbine was designed with two stages while the power turbine had three stages. The study showed that a four-stage twin-shaft turbine produced a high exit Mach number. The calculated value of AN2 was 38 · 106 rpm2m2. The total calculated cooling mass flow was 23% of the compressor mass flow, or 44 kg/s. The compressor was designed with 14 stages. The preliminary design parameters of the turbine and compressor were within established industrial ranges. From the results of this study, it was concluded that both single- and twin-shaft oxy-fuel gas turbines have advantages. The choice of a twin-shaft gas turbine can be motivated by the smaller compressor size and the advantage of greater flexibility in operation, mainly in the off-design mode. However, the advantages of a twin-shaft design must be weighed against the inherent simplicity and low cost of the simple single-shaft design.

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