A 'Reliability based Maintenance' Model for Industrial Gas Turbines in Natural Gas Transmission Process with Life Extension Prospects

2015 ◽  
Author(s):  
M. Salehi ◽  
A. Azari Barzandigh
Keyword(s):  
Natural Gas ◽  
Gas Turbines ◽  
Life Extension ◽  
Transmission Process ◽  
Natural Gas Transmission ◽  
Industrial Gas Turbines ◽  
Maintenance Model

scholarly journals A Performance Comparison of Aero-Derivative Gas Turbines and Electric Variable Speed Drives in Pipeline Compressor Duty on TransCanada’s Canadian Mainline

2000 ◽  
Author(s):  
Robert Betts ◽  
Guenther Duchon ◽  
David L. Williams
Keyword(s):  
Natural Gas ◽  
Gas Turbines ◽  
High Speed ◽  
Performance Comparison ◽  
Variable Speed ◽  
Variable Speed Drives ◽  
Natural Gas Transmission ◽  
Industrial Gas Turbines ◽  
Power Utilities ◽  
Drive Systems

Since the early 1960’s, the use of aero-derivative and industrial gas turbines on TransCanada’s natural gas transmission system has been the norm, with a total of 245 units installed to date. In 1996 and 1997 the company installed six high-speed, 30.6 MW, variable speed, electric drive systems. In the same time period eight aero-derivative gas turbines of similar power, with Dry Low Emissions, were installed. After an elapse of three years running time we now have enough data to compare the performance of the two different compressor drivers. A comparison of the performance of the two prime movers is made in a number of different ways. Operation and maintenance costs of the two different systems are considered, including the fuel costs of the natural gas and electricity, from three different Canadian electric power utilities.

Some Aspects of Operated Blades HCF Analysis: Rejuvenation and Life Estimation

2018 ◽  
Author(s):  
Sergey A. Ivanov ◽  
Maxim G. Guralnik ◽  
Alexander I. Rybnikov
Keyword(s):  
Shot Peening ◽  
Gas Turbines ◽  
Turbine Blades ◽  
Life Extension ◽  
Ultrasonic Shot Peening ◽  
Industrial Gas Turbines ◽  
Hcf Strength ◽  
Blade Failure ◽  
Metal Properties ◽  
The Cost

The lifecycle of modern industrial gas turbines can reach hundred thousand hours and usually the turbine blades need to be replaced. The use of super alloys and application of advanced coatings makes the cost of turbine lifecycle rather high. The methods for blade rejuvenation and life extension are based on the analysis of the main defects which can considerably reduce blade strength. The effect of long operation and typical defects in turbine blades has been studied in correlation with HCF. The decrease of blades HCF under the effect of operation has been considered as the result of influence of mechanical and thermal factors. The influence of FOD on the blade HCF strength is studied. Some random defects in turbine blades which resulted in HCF decreasing and blade failure are considered. The rejuvenation heat treatment for the blades of ZhS6K and EI893 and its positive effect on metal properties is demonstrated. The ultrasonic shot peening for operated blades have been considered. It is demonstrated that HCF strength of blades after shot peening is about 25–30% higher. Relaxation of compressing stresses in operation is shown as not essential. The remaining life of operated blades can be estimated using the correlation of endurance limit and run time.

Investigation of Hydrogen Enriched Natural Gas Flames in a SGT-700/800 Burner Using OH PLIF and Chemiluminescence Imaging

2014 ◽  
Vol 137 (3) ◽  
Author(s):  
Andreas Lantz ◽  
Robert Collin ◽  
Marcus Aldén ◽  
Annika Lindholm ◽  
Jenny Larfeldt ◽  
...  
Keyword(s):  
Natural Gas ◽  
Combustion Chamber ◽  
Flame Front ◽  
Gas Turbines ◽  
Dynamic Pressure ◽  
Pressure Fluctuations ◽  
Burner Exit ◽  
Planar Laser ◽  
Industrial Gas Turbines ◽  
Dynamic Pressure Measurements

The effect of hydrogen enrichment to natural gas flames was experimentally investigated at atmospheric pressure conditions using flame chemiluminescence imaging, planar laser-induced fluorescence of hydroxyl radicals (OH PLIF), and dynamic pressure monitoring. The experiments were performed using a third generation dry low emission (DLE) burner used in both SGT-700 and SGT-800 industrial gas turbines from Siemens. The burner was mounted in an atmospheric combustion test rig at Siemens with optical access in the flame region. Four different hydrogen enriched natural gas flames were investigated; 0 vol. %, 30 vol. %, 60 vol. %, and 80 vol. % of hydrogen. The results from flame chemiluminescence imaging and OH PLIF show that the size and shape of the flame was clearly affected by hydrogen addition. The flame becomes shorter and narrower when the amount of hydrogen is increased. For the 60 vol. % and 80 vol. % hydrogen flames the flame has moved upstream and the central recirculation zone that anchors the flame has moved upstream the burner exit. Furthermore, the position of the flame front fluctuated more for the full premixed flame with only natural gas as fuel than for the hydrogen enriched flames. Measurements of pressure drop over the burner show an increase with increased hydrogen in the natural gas despite same air flow thus confirming the observation that the flame front moves upstream toward the burner exit and thereby increasing the blockage of the exit. Dynamic pressure measurements in the combustion chamber wall confirms that small amounts of hydrogen in natural gas changes the amplitude of the dynamic pressure fluctuations and initially dampens the axial mode but at higher levels of hydrogen an enhancement of a transversal mode in the combustion chamber at higher frequencies could occur.

9 ppm NOx / CO Combustion System for “F” Class Industrial Gas Turbines

2000 ◽  
Author(s):  
Christian L. Vandervort
Keyword(s):  
Natural Gas ◽  
Gas Turbines ◽  
Water Injection ◽  
Steam Injection ◽  
Flame Stabilization ◽  
Emission Rates ◽  
Combustion System ◽  
Lean Premixed Combustion ◽  
Fuel Staging ◽  
Industrial Gas Turbines

The Dry Low NOx (DLN) - 2.6 combustion system has achieved emission rates of lower than 9 ppm NOx (dry, corrected to 15 percent O2) and CO from 50 to 100 percent load for the GE MS7001FA industrial gas turbine on natural gas. The system uses lean premixed combustion with fuel staging for low load stability. The first unit achieved commercial operation in March of 1996 with a firing temperature of 2350 F. As of September 9, 1999, it has accumulated over 11,800 hours of operation in peaking and base load service. Sixteen more units have since entered commercial service. Emissions data are shown for operation on natural gas. The DLN-2.6 system can operate on liquid fuel with water injection for NOx abatement. Power augmentation with steam injection is allowable while operating on natural gas. The premixed gas nozzles utilize swirl for flame stabilization. Aerodynamically shaped natural gas injectors are applied for flashback or flame-holding resistance.

Biomass Gasification Combined Cycle Opportunities Using the Future Energy SilvaGas® Gasifier Coupled to Alstom’s Industrial Gas Turbines

2003 ◽  
Author(s):  
Mark A. Paisley ◽  
Mike J. Welch
Keyword(s):  
Natural Gas ◽  
Power Systems ◽  
Gas Turbines ◽  
High Efficiency ◽  
Operating Experience ◽  
Clean Energy ◽  
Biomass Gasification ◽  
Combined Cycle ◽  
Solid Fuels ◽  
Industrial Gas Turbines

The last two decades have seen a rapid increase in the use of land based gas turbines. To a large extent, this use has been a result of the availability of natural gas at low prices which has in turn facilitated the development of high efficiency low-cost turbines designed to utilize this high value, clean energy source. Recent fluctuations in fuel prices, however, have rekindled interest in alternatives to these natural gas based systems. Transforming solid fuels such as biomass into gas so that they can substitute for natural gas provides the opportunity to enhance the efficiency of biomass based power systems by allowing the solid fuels to be used in high efficiency power generation cycles such as Integrated Gasification Combined Cycle (IGCC) processes. This paper discusses the use of Future Energy Resources’s (FERCO’s) SilvaGas® biomass gasification process as the key element in an advanced biomass power system based integrated with Alstom’s small industrial gas turbines in an advanced gas turbine combined cycle system. Operating experience with the SilvaGas process at commercial scale is discussed along with projected IGCC process efficiencies utilizing a range of biomass materials.

Hydrogen as a Pilot Gas to Improve Power Turndown in Simulated Ultra Low NOx Gas Turbine Combustion

2007 ◽  
Author(s):  
Gordon E. Andrews ◽  
Eduardo Z. Delgadillo ◽  
Mike C. Mkpadi ◽  
Gary Hayes
Keyword(s):  
Natural Gas ◽  
Atmospheric Pressure ◽  
Gas Turbines ◽  
Energy Input ◽  
Co2 Reduction ◽  
Flame Stability ◽  
Nox Emissions ◽  
Total Energy Input ◽  
Pilot Fuel ◽  
Industrial Gas Turbines

The use of a central pilot with a well mixed radial swirler combustor was investigated, at 600K and atmospheric pressure, to improve the power turn down of a low NOx combustor design. Hydrogen was compared with natural gas as the pilot fuel, using between 11 and 29% of the total energy input as hydrogen pilot fuel. With natural gas at low powers there was a hydrocarbon and CO emissions problem, but good flame stability was achieved and there was flame propagation from the pilot to the well mixed main combustion. The use of hydrogen as a pilot gas resulted in a 90% reduction in the HC and CO emissions at the simulated low power conditions. However, there was a significant increase in NOx emissions. The use of hydrogen as a pilot is a simple way to introduce hydrogen into existing industrial gas turbines so that the CO2 reduction credits of 11–29% can be claimed, if the hydrogen comes from a renewable or carbon sequestrated source.

Investigation of Hydrogen Enriched Natural Gas Flames in a SGT-700/800 Burner Using OH PLIF and Chemiluminescence Imaging

2014 ◽  
Author(s):  
Andreas Lantz ◽  
Robert Collin ◽  
Marcus Aldén ◽  
Annika Lindholm ◽  
Jenny Larfeldt ◽  
...  
Keyword(s):  
Natural Gas ◽  
Combustion Chamber ◽  
Flame Front ◽  
Gas Turbines ◽  
Dynamic Pressure ◽  
Pressure Fluctuations ◽  
Burner Exit ◽  
Planar Laser ◽  
Industrial Gas Turbines ◽  
Dynamic Pressure Measurements

The effect of hydrogen enrichment to natural gas flames was experimentally investigated at atmospheric pressure conditions using flame chemiluminescence imaging, planar laser-induced fluorescence of hydroxyl radicals (OH PLIF) and dynamic pressure monitoring. The experiments were performed using a 3rd generation dry low emission (DLE) burner used in both SGT-700 and SGT-800 industrial gas turbines from Siemens. The burner was mounted in an atmospheric combustion test rig at Siemens with optical access in the flame region. Four different hydrogen enriched natural gas flames were investigated; 0 vol.%, 30 vol.%, 60 vol.% and 80 vol.% of hydrogen. The results from flame chemiluminescence imaging and OH PLIF show that the size and shape of the flame was clearly affected by hydrogen addition. The flame becomes shorter and narrower when the amount of hydrogen is increased. For the 60 vol.% and 80 vol.% hydrogen flames the flame has moved upstream and the central recirculation zone that anchors the flame has moved upstream the burner exit. Furthermore, the position of the flame front fluctuated more for the full premixed flame with only natural gas as fuel than for the hydrogen enriched flames. Measurements of pressure drop over the burner show an increase with increased hydrogen in the natural gas despite same air flow thus confirming the observation that the flame front moves upstream towards the burner exit and thereby increasing the blockage of the exit. Dynamic pressure measurements in the combustion chamber wall confirms that small amounts of hydrogen in natural gas changes the amplitude of the dynamic pressure fluctuations and initially dampens the axial mode but at higher levels of hydrogen an enhancement of a transversal mode in the combustion chamber at higher frequencies could occur.

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