scholarly journals 100 MW Combined Cycle Achieves 7000 BTU/KWH Heat Rate at JFK International Airport

1992 ◽  
Author(s):  
Donald A. Kolp ◽  
Richard Roberts ◽  
Soo Young Kim
Keyword(s):  
Gas Turbine ◽  
Heat Recovery ◽  
Waste Heat ◽  
Water Injection ◽  
Heat Rate ◽  
Combined Cycle ◽  
Dual Function ◽  
Electric Generator ◽  
International Airport ◽  
Gas Fuel

In early 1994 a 100 MW LM6000 combined cycle cogeneration plant will begin operation at New York City’s John F. Kennedy International Airport. Thanks to the extremely high simple cycle efficiency of the LM6000 gas turbine (8200 BTU/KWH, 8650 kJ/KWH-LHV dry) and a sophisticated three-pressure steam generating system, a heat rate below 7000 BTU/KWH-LHV (7380 kJ/KWH-LHV) is expected when operating in combined cycle mode. The dual-spool LM6000 achieves its efficiency by means of a 30:1 compression ratio. 2100 F. (1149 C.) firing temperatures and the direct coupling of the low compressor/turbine rotor to the electric generator. The efficiency of the heat recovery steam generator results from the use of three economizers, three evaporators and two superheaters combined with a patented feedwater heating system which yields a 245 F. (118 C.) exhaust stack temperature. Operating flexibility is essential in this application. While the dual-fueled plant is designed for pure combined cycle operation, most of the time it will operate in a cogeneration mode — producing up to 250 × 106 BTU/HR (264 × 106 kJ/HR) of steam for heating in the winter and 7000 (24,618 KW) tons of chilling for air conditioning airport terminals in the summer. The waste heat boilers are designed to be supplementary fired on gas fuel when the airport requires the 110 MW maximum capacity of the plant simultaneously with the maximum thermal load of 250 × 106 BTU/HR (264 × 106 kJ/HR). NOx emissions are controlled with a combination of water injection in the turbine combustors and a dual-function catalyst SCR/CO converter. CO is controlled by means of the converter. Combined gas turbine and duct burner NOx is maintained below 9.0 PPMV dry (@ 15% O2) and CO below 1.5 PPH (0.68 KG/HR) dry (@ 15% O2) when operating on gas fuel. Cycle details, equipment selection and operation as well as the plant economics provide a useful insight into the benefits of these recent developments in gas turbine and heat recovery combined cycle cogeneration technology.

Combined Heat and Power: Gas Turbine Operational Flexibility

2013 ◽  
Author(s):  
James DiCampli
Keyword(s):  
Gas Turbine ◽  
Urban Areas ◽  
Gas Turbines ◽  
Heat Recovery ◽  
National Fire Protection Association ◽  
Combined Heat And Power ◽  
Combined Cycle ◽  
Electricity Production ◽  
Exhaust Heat ◽  
Gas Fuel

Combined heat and power (CHP) is an application that utilizes the exhaust heat generated from a gas turbine and converts it into a useful energy source for heating & cooling, or additional electric generation in combined cycle configurations. Compared to simple-cycle plants with no heat recovery, CHP plants emit fewer greenhouse gasses and other emissions, while generating significantly more useful energy per unit of fuel consumed. Clean plants are easier to permit, build and operate. Because of these advantages, projections show CHP capacity is expected to double and account for 24% of global electricity production by 2030. An aeroderivative power plant has distinct advantages to meet CHP needs. These include high thermal efficiency, low cost, easy installation, proven reliability, compact design for urban areas, simple operation and maintenance, fuel flexibility, and full power generation in a very short time period. There has been extensive discussion and analyses on modifying purge requirements on cycling units for faster dispatch. The National Fire Protection Association (NFPA) has required an air purge of downstream systems prior to startup to preclude potentially flammable or explosive conditions. The auto ignition temperature of natural gas fuel is around 800°F. Experience has shown that if the exhaust duct contains sufficient concentrations of captured gas fuel, and is not purged, it can ignite immediately during light off causing extensive damage to downstream equipment. The NFPA Boiler and Combustion Systems Hazards Code Committee have developed new procedures to safely provide for a fast-start capability. The change in the code was issued in the 2011 Edition of NFPA 85 and titled the Combustion Turbine Purge Credit. For a cycling plant and hot start conditions, implementation of purge credit can reduce normal start-to-load by 15–30 minutes. Part of the time saving is the reduction of the purge time itself, and the rest is faster ramp rates due to a higher initial temperature and pressure in the heat recovery steam generator (HRSG). This paper details the technical analysis and implementation of the NFPA purge credit recommendations on GE Power and Water aeroderivative gas turbines. This includes the hardware changes, triple block and double vent valve system (or drain for liquid fuels), and software changes that include monitoring and alarms managed by the control system.

HRSG Duct Firing Revisited

2018 ◽  
Author(s):  
S. Can Gülen
Keyword(s):  
Power Plant ◽  
Gas Turbine ◽  
Power Output ◽  
Gas Turbines ◽  
Heat Recovery ◽  
Fossil Fuel ◽  
Heat Rate ◽  
Combined Cycle ◽  
Efficiency Improvement ◽  
Combined Cycle Power Plant

Duct firing in the heat recovery steam generator (HRSG) of a gas turbine combined cycle power plant is a commonly used method to increase output on hot summer days when gas turbine airflow and power output lapse significantly. The aim is to generate maximum possible power output when it is most needed (and, thus, more profitable) at the expense of power plant heat rate. In this paper, using fundamental thermodynamic arguments and detailed heat and mass balance simulations, it will be shown that, under certain boundary conditions, duct firing in the HRSG can be a facilitator of efficiency improvement as well. When combined with highly-efficient aeroderivative gas turbines with high cycle pressure ratios and concomitantly low exhaust temperatures, duct firing can be utilized for small but efficient combined cycle power plant designs as well as more efficient hot-day power augmentation. This opens the door to efficient and agile fossil fuel-fired power generation opportunities to support variable renewable generation.

Optimal waste heat recovery in micro gas turbine cycles through liquid water injection

2014 ◽  
Vol 70 (1) ◽  
pp. 846-856 ◽  
Author(s):  
Ward De Paepe ◽  
Francesco Contino ◽  
Frank Delattin ◽  
Svend Bram ◽  
Jacques De Ruyck
Keyword(s):  
Gas Turbine ◽  
Liquid Water ◽  
Heat Recovery ◽  
Waste Heat Recovery ◽  
Waste Heat ◽  
Water Injection ◽  
Micro Gas Turbine

LM2500+ Single Shaft Combined Cycle With Frequency Stabilization

1998 ◽  
Author(s):  
Donald A. Kolp ◽  
Charles E. Levey
Keyword(s):  
Steam Turbine ◽  
Gas Turbine ◽  
Heat Recovery ◽  
Heat Rate ◽  
Combined Cycle ◽  
Heat Recovery Steam Generator ◽  
Equipment Operation ◽  
Combined Cycle Plant ◽  
Stable Frequency ◽  
And Performance

Zorlu Enerji needed 35 MW of reliable power at a stable frequency to maintain constant speed on the spindles producing thread at its parent company’s textile plant in Bursa, Turkey. In December of 1996, Zorlu selected an LM2500+ combined cycle plant to fill its power-generating requirements. The LM2500+ has output of 26,810 KW at a heat rate of 9,735 Kj/Kwh. The combined cycle plant has an output of 35,165 KW and a heat rate of 7,428 Kj/Kwh. The plant operates in the simple cycle mode utilizing the LM2500+ and a bypass stack and in combined cycle mode using the 2-pressure heat recovery steam generator and single admission, 9.5 MW condensing steam turbine. The generator is driven through a clutch by the steam turbine from the exciter end and by the gas turbine from the opposing end. The primary fuel for the plant is natural gas; the backup fuel is naphtha. Utilizing a load bank, the plant is capable of accepting a 12 MW load loss when the utility breaker trips open; it can sustain this loss while maintaining frequency within 1% on the mill load. The frequency stabilizing capability prevents overspeeding of the spindles, breakage of thousands of strands of thread and a costly shutdown of the mill. A description of the equipment, operation and performance illustrates the unique features of this versatile, compact and efficient generating unit.

Hot Windbox and Combined Cycle Repowering to Improve Heat Rate

2010 ◽  
Author(s):  
Tarek A. Tawfik ◽  
Thomas P. Smith
Keyword(s):  
Steam Turbine ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Heat Recovery ◽  
Heat Rate ◽  
The United States ◽  
Combined Cycle ◽  
Plant Performance ◽  
Ambient Conditions ◽  
North East

Retrofitting existing power generation plants by repowering is becoming an attractive option to improve plant performance with less cost. “Hot Windbox Repowering” involves utilizing the hot exhaust gas from a combustion gas turbine and using it as combustion air for an existing fossil-fuel boiler. “Combined Cycle Repowering” or “Full Repowering” involves completely replacing the existing boiler with a combined cycle consisting of a gas turbine(s) and a heat recovery steam generator (HRSG). The existing steam turbine will be used in both repowering scenarios. This paper discusses an engineering study and summarizes the results obtained from repowering an existing heavy-oil / natural gas fired steam power plant in the north east of the United States. The plant consists of a 600 MW boiler and steam turbine. Several engineering studies were considered and evaluated thermodynamically and economically to retrofit such plant. Several options were considered involving different gas turbines, gas turbine combinations, and different repowering methods. The best option is based on retrofitting the unit by a combination of both, hot windbox repowering and combined cycle repowering. The proposed design consists of one gas turbine repowering the windbox of the existing boiler, and a second gas turbine operating in a separate combined cycle configuration with the generated superheated steam tying into the main steam line and expanding in the existing steam turbine. Several heat balances were developed to assist in obtaining meaningful results for this feasibility study. Actual costs were obtained for the gas turbines and heat recovery steam generators (HRSG), as well as installation costs for a more accurate evaluation. The results indicate that the combined output of the repowered unit will generate an additional 295 MW and reduce the heat rate by more than 11 percent at full load and annual average ambient conditions. The estimated capital cost of the project is expected to range from $235 to $245 millions.

The Gas Turbine Waste Heat Recovery System and the U.S. Navy

1978 ◽  
Author(s):  
H. D. Marron ◽  
R. S. Carleton
Keyword(s):  
Gas Turbine ◽  
Heat Recovery ◽  
Waste Heat Recovery ◽  
Waste Heat ◽  
Development Program ◽  
Combined Cycle ◽  
Current Status ◽  
Design Concepts ◽  
Waste Heat Recovery System ◽  
The U.S

This paper will discuss the current status of the gas turbine waste heat recovery systems in the U.S. Navy. This will include discussions of the auxiliary systems currently operational on the SPRUANCE Class Destroyers as well as the combined-cycle cruise propulsion systems currently planned for development initiation in FY’78. The major emphasis of the discussion will be to detail the rationale and to identify the basis upon which the U.S. Navy arrived at a decision to develop combined cycle systems to be available for non-nuclear combatant ship cruise propulsion for the mid 1980’s. The design concepts considered feasible for these applications will be discussed as well as an overview of the development program to completion.

scholarly journals M21 Cruise Marine Combined Cycle Plant

1995 ◽  
Author(s):  
V. I. Romanov ◽  
O. G. Zhiritsky ◽  
A. V. Kovalenko ◽  
V. V. Lupandin
Keyword(s):  
Gas Turbine ◽  
Plant Development ◽  
Heat Recovery ◽  
Waste Heat Recovery ◽  
Waste Heat ◽  
Combined Cycle ◽  
Heat Recovery Boiler ◽  
Technical Data ◽  
Power Turbine ◽  
Combined Cycle Plant

The paper describes M21 cruise marine combined cycle plant for SLAVA class cruisers (COGAG arrangement). Three guided missile cruisers (Figure 1) are powered by these plants (two plants for each cruiser). During this plant development the more strict demands on weight and size had been taken into account as compared with M25 plants for merchant ships. The paper shows technical data of M21 combined cycle plant, descriptions and design features of SPA MASHPROEKT GT 6004R gas turbine with reversible free power turbine, waste-heat recovery boiler, steam turbine with a condenser and a common gear unit. More than 10 year service experience of these plants is shown in this paper.

Gas Turbine Evaporative Cooling: A Novel Method for Combined Cycle Plant Part Load Optimization

2020 ◽  
Author(s):  
Jose Carmona
Keyword(s):  
Gas Turbine ◽  
Heat Recovery ◽  
Evaporative Cooling ◽  
Heat Rate ◽  
Combined Cycle ◽  
Heat Recovery Steam Generator ◽  
Part Load ◽  
Load Optimization ◽  
Water Ratio ◽  
Steam Production

Abstract In power plant engineering, gas turbine (GT) evaporative cooling is traditionally thought as one of the few power augmentation alternatives for existing plants. For most combined cycle plants operating at part load, the GT Inlet Guide Vanes (IGV) will throttle the air flow to the combustor to maintain the turbine exhaust temperature (TET) as high as possible, thus maximizing the overall combined cycle efficiency. The IGV air throttling results in a reduction of the turbine inlet air temperature (TIT) due to a reduction on the mass of fuel burned in the combustors as the available combustion air decreases due to IGV throttling to maintain an optimum air to fuel ratio, resulting on a lower TET compared with the same GT at base load. The compounded result of these effects limits the maximum steam production capacity on the heat recovery steam generator, particularly for the high-pressure section, hampering the efficiency of the steam turbine. The methodology developed in the subject study aims at counteracting the afore-mentioned effects by optimizing the evaporative cooler air/water ratio which results in the lower possible heat rate for full load and part load operation. By dynamically controlling the air/water ratio, a preheating effect can be achieved in the compressor inlet air, which results on higher exhaust gas temperature, thus augmenting the high-pressure steam production on the heat recovery steam generator and accordingly the steam turbine efficiency. For a newly built 907 MWe Combined Cycle Gas Turbine (CCGT) plant, application of the evaporative cooling part load optimization methodology presented in this study could lead to a potential reduction of up to 158kJ/kWh on heat rate and 9.318 g/kWh of CO2 emissions if compared with the same plant without dynamic control of the evaporative cooler air/water ratio.

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