Methodology and mathematical model with the continuous time for the selection of the optimal power of the gas turbine set for the dual fuel gas-steam combined cycle in a parallel system

2018 ◽  
Vol 141 ◽  
pp. 1161-1172 ◽  
Author(s):  
Ryszard Bartnik ◽  
Zbigniew Buryn ◽  
Anna Hnydiuk-Stefan
Keyword(s):  
Mathematical Model ◽  
Gas Turbine ◽  
Continuous Time ◽  
Parallel System ◽  
Combined Cycle ◽  
Dual Fuel ◽  
Fuel Gas ◽  
Optimal Power ◽  
Selection Of

scholarly journals Methodology and Continuous Time Mathematical Model to Select Optimum Power of Gas Turbine Set for Dual-Fuel Gas-Steam Combined Heat and Power Plant in Parallel System

Energies ◽  
2018 ◽  
Vol 11 (7) ◽  
pp. 1784 ◽  
Author(s):  
Ryszard Bartnik ◽  
Waldemar Skomudek ◽  
Zbigniew Buryn ◽  
Anna Hnydiuk-Stefan ◽  
Aleksandra Otawa
Keyword(s):  
Mathematical Model ◽  
Power Plant ◽  
Gas Turbine ◽  
Continuous Time ◽  
Combined Heat And Power ◽  
Parallel System ◽  
Dual Fuel ◽  
Fuel Gas

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.

scholarly journals Thermo-economic comparative analysis of gas turbine GT10 integrated with air and steam bottoming cycle

2014 ◽  
Vol 35 (4) ◽  
pp. 83-95 ◽  
Author(s):  
Daniel Czaja ◽  
Tadeusz Chmielnak ◽  
Sebastian Lepszy
Keyword(s):  
Economic Analysis ◽  
Gas Turbine ◽  
Power Plants ◽  
Combined Cycle ◽  
Small Range ◽  
Exhaust Gas ◽  
Thermodynamic Optimization ◽  
Technological Structure ◽  
The Cost ◽  
Selection Of

Abstract A thermodynamic and economic analysis of a GT10 gas turbine integrated with the air bottoming cycle is presented. The results are compared to commercially available combined cycle power plants based on the same gas turbine. The systems under analysis have a better chance of competing with steam bottoming cycle configurations in a small range of the power output capacity. The aim of the calculations is to determine the final cost of electricity generated by the gas turbine air bottoming cycle based on a 25 MW GT10 gas turbine with the exhaust gas mass flow rate of about 80 kg/s. The article shows the results of thermodynamic optimization of the selection of the technological structure of gas turbine air bottoming cycle and of a comparative economic analysis. Quantities are determined that have a decisive impact on the considered units profitability and competitiveness compared to the popular technology based on the steam bottoming cycle. The ultimate quantity that can be compared in the calculations is the cost of 1 MWh of electricity. It should be noted that the systems analyzed herein are power plants where electricity is the only generated product. The performed calculations do not take account of any other (potential) revenues from the sale of energy origin certificates. Keywords: Gas turbine air bottoming cycle, Air bottoming cycle, Gas turbine, GT10

Development of a Dual-Fuel Gas Turbine Engine of Liquid and Low-Calorific Gas

2005 ◽  
Author(s):  
Masamichi Koyama ◽  
Hiroshi Fujiwara
Keyword(s):  
Gas Turbine ◽  
Sewage Treatment ◽  
Energy Resource ◽  
Biomass Energy ◽  
Dual Fuel ◽  
Fuel Gas ◽  
Turbine Engine ◽  
Reference Velocity ◽  
Continuous Use ◽  
Wasted Energy

We developed a dual-fuel single can combustor for the Niigata Gas Turbine (NGT2BC), which was developed as a continuous-duty gas turbine capable of burning both kerosene and digester gas. The output of the NGT2BC is 920 kW for continuous use with digester gas and 1375 kW for emergency use with liquid fuel. Digester gas, obtained from sludge processing at sewage treatment plants, is a biomass energy resource whose use reduces CO2 emissions and take advantage of an otherwise wasted energy source. Design features for good combustion with digester gas include optimized the good matching of gas injection and swirl air and reduced reference velocity. The optimal combination of these parameters was determined through CFD analysis and atmospheric rig testing.

Analysis on the Performance Characteristics of SOFC/GT Hybrid Systems Based on a Commercially Available MW-Class Gas Turbine

2005 ◽  
Author(s):  
Tae Won Song ◽  
Jeong L. Sohn ◽  
Tong Seop Kim ◽  
Sung Tack Ro
Keyword(s):  
Gas Turbine ◽  
Hybrid System ◽  
Guide Vane ◽  
Control Strategies ◽  
Operating Conditions ◽  
Performance Characteristics ◽  
Inlet Guide Vane ◽  
Part Load ◽  
Optimal Power ◽  
Selection Of

To investigate the possible applications of the SOFC/MGT hybrid system to large electric power generations, a study for the kW-class hybrid power system conducted in our group is extended to the MW-class hybrid system in this study. Because of the matured technology of the gas turbine and commercial availability in the market, it is reasonable to construct a hybrid system with the selection of a gas turbine as an off-the-shelf item. For this purpose, the performance analysis is conducted to find out the optimal power size of the hybrid system based on a commercially available gas turbine. The optimal power size has to be selected by considering specifications of a selected gas turbine which limit the performance of the hybrid system. Also, the cell temperature of the SOFC is another limiting parameter to be considered in the selection of the optimal power size. Because of different system configuration of the hybrid system, the control strategies for the part-load operation of the MW-class hybrid system are quite different from the kW-class case. Also, it is necessary to consider that the control of supplied air to the MW-class gas turbine is typically done by the variable inlet guide vane located in front of the compressor inlet, instead of the control of variable rotational speed of the kW-class micro gas turbine. Performance characteristics at part-load operating conditions with different kinds of control strategies of supplied fuel and air to the hybrid system are investigated in this study.

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.

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