scholarly journals Plan for obtaining data required for retrofitting burners to industrial fuel gas. Part I. Technical plan for combustion system data (Deliverable No. 44)

1979 ◽  
Author(s):  
Keyword(s):  
Combustion System ◽  
Fuel Gas ◽  
System Data ◽  
Technical Plan

Experimental and Numerical Investigation of Fuel–Air Mixing in a Radial Swirler Slot of a Dry Low Emission Gas Turbine Combustor

2015 ◽  
Vol 138 (6) ◽  
Author(s):  
Festus Eghe Agbonzikilo ◽  
Ieuan Owen ◽  
Jill Stewart ◽  
Suresh Kumar Sadasivuni ◽  
Mike Riley ◽  
...  
Keyword(s):  
Experimental Data ◽  
Large Scale ◽  
Experimental Studies ◽  
Flux Ratio ◽  
Turbulence Models ◽  
Test Facility ◽  
Combustion System ◽  
Fuel Gas ◽  
Low Emission ◽  
Air Mixing

This paper presents the results of an investigation in which the fuel/air mixing process in a single slot within the radial swirler of a dry low emission (DLE) combustion system is explored using air/air mixing. Experimental studies have been carried out on an atmospheric test facility in which the test domain is a large-scale representation of a swirler slot from a Siemens proprietary DLE combustion system. Hot air with a temperature of 300 °C is supplied to the slot, while the injected fuel gas is simulated using air jets with temperatures of about 25 °C. Temperature has been used as a scalar to measure the mixing of the jets with the cross-flow. The mixture temperatures were measured using thermocouples while Pitot probes were used to obtain local velocity measurements. The experimental data have been used to validate a computational fluid dynamics (CFD) mixing model. Numerical simulations were carried out using CFD software ansys-cfx. Due to the complex three-dimensional flow structure inside the swirler slot, different Reynolds-averaged Navier–Stokes (RANS) turbulence models were tested. The shear stress transport (SST) turbulence model was observed to give best agreement with the experimental data. The momentum flux ratio between the main air flow and the injected fuel jet, and the aerodynamics inside the slot were both identified by this study as major factors in determining the mixing characteristics. It has been shown that mixing in the swirler can be significantly improved by exploiting the aerodynamic characteristics of the flow inside the slot. The validated CFD model provides a tool which will be used in future studies to explore fuel/air mixing at engine conditions.

scholarly journals Combustion of LCV Coal Derived Fuel Gas for High Temperature, Low Emissions Gas Turbines in the British Coal Topping Cycle

1991 ◽  
Author(s):  
G. J. Kelsall ◽  
M. A. Smith ◽  
H. Todd ◽  
M. J. Burrows
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Calorific Value ◽  
Pollutant Emissions ◽  
Inlet Temperature ◽  
Outlet Temperature ◽  
Combustion System ◽  
Fuel Gas ◽  
Gas Turbine Combustion ◽  
Topping Cycle

Advanced coal based power generation systems such as the British Coal Topping Cycle offer the potential for high efficiency electricity generation with minimum environmental impact. An important component of the Topping Cycle programme is the development of a gas turbine combustion system to burn low calorific value (3.5–4.0 MJ/m3 wet gross) coal derived fuel gas, at a turbine inlet temperature of 1260°C, with minimum pollutant emissions. The paper gives an overview of the British Coal approach to the provision of a gas turbine combustion system for the British Coal Topping Cycle, which includes both experimental and modelling aspects. The first phase of this programme is described, including the design and operation of a low-NOx turbine combustor, operating at an outlet temperature of 1360°C and burning a synthetic low calorific value (LCV) fuel gas, containing 0 to 1000 ppmv of ammonia. Test results up to a pressure of 8 bar are presented and the requirements for further combustor development outlined.

LNG Interchangeability in Land Based Gas Turbines: The Siemens Approach

2007 ◽  
Author(s):  
Pratyush Nag ◽  
Khalil Abou-Jaoude ◽  
Steve Mumford ◽  
Jianfan Wu ◽  
Matthew LaGrow ◽  
...  
Keyword(s):  
Natural Gas ◽  
Gas Turbines ◽  
Warning System ◽  
Fuel Composition ◽  
Combustion System ◽  
Fuel Gas ◽  
Combustion Dynamics ◽  
Site Specific ◽  
Fuel Characteristics ◽  
Combustion Systems

Liquefied Natural Gas (LNG) from offshore reserves is expected to expand its role in supplementing US natural gas supplies. The quality and hydrocarbon contents of the natural gas imported from these international sources, frequently differs from the compositions of domestic natural gas. With the range of variations in fuel characteristics known to exist with offshore LNG, use of this LNG in gas turbine engines could violate applicable fuel specifications, and lead to operational issues such as, but not limited to, combustion dynamics, flashback, increased emissions, or decreased component life. Another potential issue for gas turbines generating power is that rapid changes in the fuel characteristics that may occur when blending imported and domestic gas, may lead to substantial fluctuations in power output. Fuel flexibility is dominantly tied to the combustion system design. Conventional diffusion flame combustion systems are more tolerant of wide variations in fuel compositions but they are limited by their emission levels. The more advanced premixed flame combustors, the Dry Low NOxs (DLN) and Ultra Low NOx (ULN) combustion systems have significantly better performances in terms of emissions but they are also more sensitive to changes in the fuel composition and characteristics. Siemens has performed test campaigns with commercially operating engines and high pressure combustion test rigs to evaluate their commercially available combustion system configurations for LNG applicability. From these test campaigns, Siemens has defined the set of combustion hardware modifications which is robust to changes in fuel composition within the tested limits. Along with the said combustion hardware upgrade, Siemens has also designed an Integrated Fuel Gas Characterization (IFGC) system (Patent Pending). This IFGC system acts like an early warning system and feeds forward signals into the plant control system. Depending on the changes in the properties of the incoming fuel, the IFGC system is designed to adjust the engine tuning settings to compensate for these dynamic changes in the fuel. Customer implementation of the required hardware as well as associated site-specific engineering will mitigate the operational and emissions risk associated with the fuel changes. Overall, it is Siemens recommendation that LNG type fuels will be acceptable to be used in Siemens Gas Turbines with the preferred combustion hardware in place along with the Integrated Fuel Gas Characterization System. A site specific evaluation would be required to determine the optimal system depending on the expected fuels that the unit would be operating with, along with the emissions permit levels associated with the site.

scholarly journals Development of a Gas Turbine Combustion System for Medium-BTU Fuel

1985 ◽  
Author(s):  
J. F. Savelli ◽  
G. L. Touchton
Keyword(s):  
Carbon Monoxide ◽  
Gas Turbine ◽  
Coal Gasification ◽  
Steam Injection ◽  
Oxides Of Nitrogen ◽  
Combustion System ◽  
Fuel Gas ◽  
High Hydrogen ◽  
Wet Gas ◽  
Gas Turbine Combustion

The Cool Water Coal Gasification Project requires a gas turbine combustion system to burn a high hydrogen medium-Btu coal gas produced in an oxygen-blown gasifier. The gas turbine selected for this demonstration plant is a General Electric Company MS7001E unit. The plant is located in Daggett, California, a location requiring compliance with stringent environmental regulations; that is, oxides of nitrogen (NOx) at 63.5 kg/hr and carbon monoxide (CO) at 35.0 kg/hr in the machine exhaust. The plant operating configuration requires fuel gas to be supplied at 330 °K and 477 °K with 20%/vol moisture blended. A combustion system was developed enabling the gas turbine to operate from full speed no load to full load on both fuel gas configurations. Distillate oil capability was also incorporated to facilitate safe machine startup and shutdown. Emissions requirements for NOx were met with steam injection, “CO” by combustor design, and sulfur oxides are met by fuel gas cleanup. A conventional combustion liner sleeve with a standard air admission schedule was used. A unique fuel nozzle, based upon past low-Btu fuel work, was designed incorporating the latest low erosion oil nozzle. One combustor of the 10 fitted to an MS7001E was tested at full pressure and airflow. Test results indicate, as predicted analytically, that NOx prediction varies substantially between cold dry fuel gas and hot wet gas. NOx compliance was attainable with little degradation of other design considerations. Carbon monoxide emissions were well below the required limits.

A Coal-Fueled Combustion Turbine Cogeneration System With Topping Combustion

1997 ◽  
Vol 119 (1) ◽  
pp. 84-92 ◽  
Author(s):  
J. M. Bee´r ◽  
R. V. Garland
Keyword(s):  
Natural Gas ◽  
Atmospheric Pressure ◽  
Combined Cycle ◽  
Plant Performance ◽  
Combustion System ◽  
Steam Turbines ◽  
Gas Turbine Combustor ◽  
Fuel Gas ◽  
Heating Value ◽  
Cogeneration System

Cogeneration systems fired with coal or other solid fuels and containing conventional extracting-condensing or back pressure steam turbines can be found throughout the world. A potentially more economical plant of higher output per unit thermal energy is presented that employs a pressurized fluidized bed (PFB) and coal carbonizer. The carbonizer produces a char that is fed to the PFB and a low heating value fuel gas that is utilized in a topping combustion system. The topping combustor provides the means for achieving state-of-the-art turbine inlet temperatures and is the main contributor to enhancing the plant performance. An alternative to this fully coal-fired system is the partially coal, partially natural gas-fired air heater topping combustion cycle. In this cycle compressed air is preheated in an atmospheric pressure coal-fired boiler and its temperature raised further by burning natural gas in a topping gas turbine combustor. The coal fired boiler also generates steam for use in a cogeneration combined cycle. The conceptual design of the combustion turbine is presented with special emphasis on the low-emissions multiannular swirl burner topping combustion system and its special requirements and features.

Gas Turbine Combustion of a Minimally Cleaned, Coal-Derived Low-BTU Gas

1985 ◽  
Author(s):  
John C. Blanton ◽  
Daniel P. Smith
Keyword(s):  
Gas Turbine ◽  
Coal Dust ◽  
Fixed Bed ◽  
Combustion Efficiency ◽  
Stable Operation ◽  
Gaseous Emissions ◽  
Combustion System ◽  
Fuel Gas ◽  
Unburned Hydrocarbons ◽  
Gas Turbine Combustion

As part of the joint GE/DoE Water-Cooled Components Test Program,1 a series of tests were performed involving the combustion of a minimally cleaned low-Btu coal gas in a pressurized gas turbine simulator. The fuel gas was produced in a 1-ton/hr advanced fixed-bed gasifier using Illinois #6 coal, and filtered of particulate in a full-pressure, full-temperature cyclone separator. The resulting product had a gross heating value of approximately 5000 kJ/kg at a temperature of 540 °C and a pressure of 22 bar. Numerous contaminants also remained in the fuel gas, including approximately 100 ppmw particulate matter (coal dust of 3 μm average size), 2000–4000 ppmv ammonia, 2000–2500 ppmv H2S, and 0.5–1.0% vaporized tars, oils, phenols, and other condensible hydrocarbons. The fuel gas was burned with air at 6–7 bar pressure and 400 °C temperature in a gas turbine combustion system at overall fuel-air ratios up to 0.25 (overall equivalence ratio 0.36). Gaseous emissions were sampled in the exhaust stream and measurements made for O2, CO2, CO, unburned hydrocarbons, NOx, and SOx. The CO and unburned hydrocarbon emissions were both below 20 ppmv at full firing conditions, indicating acceptable combustion efficiency. The NOx levels measured were up to 500 ppmv, and were due to the of conversion of fuel-bound nitrogen (ammonia principally). The SOx emissions directly followed the oxidation of fuel-bound sulfur (H2S principally). At part-load conditions, emissions of CO and unburned hydrocarbons were observed to increase, as expected. Stable operation was maintained down to a combustion system temperature rise of approximately 350 °C.

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