scholarly journals Proposed Gas Turbine Procurement Standard: Gaseous and Liquid Fuels

1971 ◽  
Author(s):  
H. T. Holzwarth ◽  
G. S. Howard ◽  
T. E. Stott
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Operating Costs ◽  
Liquid Fuels

Since fuel comprises a fairly large percent of total gas-turbine operating costs, it is an extremely important subject to the user. This paper, one of a series (see Appendix), describes allowable specifications for gaseous and liquid fuels suitable for burning in gas turbines.

Development and Integration of the Dual Fuel Combustion System for the MGT Gas Turbine Family

2021 ◽  
Author(s):  
Bernhard Ćosić ◽  
Frank Reiss ◽  
Marc Blümer ◽  
Christian Frekers ◽  
Franklin Genin ◽  
...  
Keyword(s):  
Gas Turbine ◽  
Distribution System ◽  
Gas Turbines ◽  
Liquid Fuel ◽  
Fuel Injection ◽  
Liquid Fuels ◽  
Dual Fuel ◽  
Gaseous Fuels ◽  
Supply And Distribution ◽  
Industrial Gas Turbines

Abstract Industrial gas turbines like the MGT6000 are often operated as power supply or as mechanical drives. In these applications, liquid fuels like 'Diesel Fuel No.2' can be used either as main fuel or as backup fuel if natural gas is not reliably available. The MAN Gas Turbines (MGT) operate with the Advanced Can Combustion (ACC) system, which is capable of ultra-low NOx emissions for gaseous fuels. This system has been further developed to provide dry dual fuel capability. In the present paper, we describe the design and detailed experimental validation process of the liquid fuel injection, and its integration into the gas turbine package. A central lance with an integrated two-stage nozzle is employed as a liquid pilot stage, enabling ignition and start-up of the engine on liquid fuel only. The pilot stage is continuously operated, whereas the bulk of the liquid fuel is injected through the premixed combustor stage. The premixed stage comprises a set of four decentralized nozzles based on fluidic oscillator atomizers, wherein atomization of the liquid fuel is achieved through self-induced oscillations. We present results illustrating the spray, hydrodynamic, and emission performance of the injectors. Extensive testing of the burner at atmospheric and full load high-pressure conditions has been performed, before verification within full engine tests. We show the design of the fuel supply and distribution system. Finally, we discuss the integration of the dual fuel system into the standard gas turbine package of the MGT6000.

scholarly journals Radical Overshoot Phenomena in Liquid Fueled Gas Turbine Combustors

1977 ◽  
Author(s):  
R. Kollrack ◽  
L. D. Aceto
Keyword(s):  
Gas Turbine ◽  
Residence Time ◽  
Gas Turbines ◽  
Combustion Zone ◽  
Equivalence Ratio ◽  
Drop Size ◽  
Formation Rate ◽  
Liquid Fuels ◽  
No Production ◽  
No Formation

A detailed analysis is presented of the processes involved in the production of NO during the combustion of liquid fuels in gas turbines. With O and OH concentrations in excess of the equilibrium values the NO production rate displays a temporary overshoot within the primary combustion zone residence time. The contributions of temperature and reaction kinetics to this overshoot are assessed. This overshoot is strongly dependent on equivalence ratio and on pressure, with the minimum overshoot occurring at ϕ = 0.9. It increases more strongly for richer than for leaner combustion. Increasing drop size at lean or stoichiometric conditions tends to retard and diminish the overshoot of the NO formation rate while increasing its duration. At rich conditions, however, increasing drop size can cause overshoot increases. Changing degrees of premixedness for a given drop size, produces a timewise shifting of this overshoot. An assessment is made of the influences and interrelation of drop size distribution, degree of premixedness and staged fuel addition.

Evaluation of Combustion and Emissions Using Biodiesel and Blends With Kerosene in a Low NOx Gas Turbine Combustor

2010 ◽  
Author(s):  
Hu Li ◽  
Mohamed Altaher ◽  
Gordon E. Andrews
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Equivalence Ratio ◽  
Fuel Injection ◽  
Waste Cooking Oil ◽  
Industrial Applications ◽  
Liquid Fuels ◽  
Gaseous Emissions ◽  
Gas Turbine Combustor ◽  
Industrial Gas Turbines

Biofuels offer reduced CO2 emissions for both industrial and aero gas turbines. Industrial applications are more practical due to low temperature waxing problems at altitude. Any use of biofuels in industrial gas turbines must also achieve low NOx and this paper investigates the use of biofuels in a low NOx radial swirler, as used in some industrial low NOx gas turbines. A waste cooking oil derived methyl ester biodiesel (WME) has been tested on a radial swirler industrial low NOx gas turbine combustor under atmospheric pressure and 600K. The pure WME and its blends with kerosene, B20 and B50 (WME:kerosene = 20:80 and 50:50 respectively), and pure kerosene were tested for gaseous emissions and lean extinction as a function of equivalence ratio. The co-firing with natural gas (NG) was tested for kerosene/biofuel blends B20 and B50. The central fuel injection was used for liquid fuels and wall injection was used for NG. The experiments were carried out at a reference Mach number of 0.017. The inlet air to the combustor was heated to 600K. The results show that B20 produced similar NOx at an equivalence ratio of ∼0.5 and a significant low NOx when the equivalence ratio was increased comparing with kerosene. B50 and B100 produced higher NOx compared to kerosene, which indicates deteriorated mixing due to the poor volatility of the biofuel component. The biodiesel lower hydrocarbon and CO emissions than kerosene in the lean combustion range. The lean extinction limit was lower for B50 and B100 than kerosene. It is demonstrated that B20 has the lowest overall emissions. The co-firing with NG using B20 and B50 significantly reduced NOx and CO emissions.

scholarly journals Combustion and Oxidation Kinetics of Alternative Gas Turbines Fuels

2014 ◽  
Author(s):  
Pierre-Alexandre Glaude ◽  
Baptiste Sirjean ◽  
René Fournet ◽  
Roda Bounaceur ◽  
Matthieu Vierling ◽  
...  
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Ignition Temperature ◽  
Alternative Fuels ◽  
Flame Temperature ◽  
Liquid Fuels ◽  
Heavy Oils ◽  
Process Gas ◽  
Auto Ignition

Heavy duty gas turbines are very flexible combustion tools that accommodate a wide variety of gaseous and liquid fuels ranging from natural gas to heavy oils, including syngas, LPG, petrochemical streams (propene, butane…), hydrogen-rich refinery by-products; naphtha; ethanol, biodiesel, aromatic gasoline and gasoil, etc. The contemporaneous quest for an increasing panel of primary energies leads manufacturers and operators to explore an ever larger segment of unconventional power generation fuels. In this moving context, there is a need to fully characterize the combustion features of these novel fuels in the specific pressure, temperature and equivalence ratio conditions of gas turbine combustors using e.g. methane as reference molecule and to cover the safety aspects of their utilization. A numerical investigation of the combustion of a representative cluster of alternative fuels has been performed in the gas phase, namely two natural gas fuels of different compositions, including some ethane, a process gas with a high content of butene, oxygenated compounds including methanol, ethanol, and DME (dimethyl ether). Sub-mechanisms have specifically been developed to include the reactions of C4 species. Major combustion parameters, such as auto-ignition temperature (AIT), ignition delay times (AID), laminar burning velocities of premixed flames, adiabatic flame temperatures, and CO and NOx emissions have then been investigated. Finally, the data have been compared with those calculated for methane flames. These simulations show that the behaviors of alternative fuels markedly differ from that of conventional ones. Especially, DME and the process gases appear to be highly reactive with significant impacts on the auto-ignition temperature and flame speed data, which justifies burner design studies within premixed combustion schemes and proper safety considerations. The behaviors of alcohols (especially methanol) display some commonalities with those of conventional fuels. In contrast, DME and process gas fuels develop substantially different flame temperature and NOx generation rates than methane. Resorting to lean premix conditions is likely to achieve lower NOx emission performances. This review of gas turbine fuels shows for instance that the use of methanol as a gas turbine fuel is possible with very limited combustor modifications.

Field Experience With Pulse-Jet Self-Cleaning Air Filtration on Gas Turbines in a Desert Environment

1982 ◽  
Author(s):  
A. W. Anderson ◽  
R. G. Neaman
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Continuous Operation ◽  
Operating Costs ◽  
Air Filtration ◽  
Desert Environment ◽  
Ambient Concentrations ◽  
Self Cleaning ◽  
Sand Dust ◽  
Pulse Jet

This paper discusses the results of two years continuous operation of automatic self-cleaning air filtration systems designed to provide gas turbine protection in a desert environment subject to high ambient concentrations of sand, dust and salt. The condition of the gas turbines and associated pulse-jet air filtration systems, after two years continuous operation, are described. Filter operating costs are also analyzed.

Nox emission control in gas turbines for combined cycle gas turbine plant

1997 ◽  
Vol 211 (1) ◽  
pp. 43-52 ◽  
Author(s):  
M J Moore
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Catalytic Reduction ◽  
Water Injection ◽  
Emission Control ◽  
Combined Cycle ◽  
Liquid Fuels ◽  
Gas Combustion ◽  
Natural Gas Combustion

The increase, in recent years, in the size and efficiency of gas turbines burning natural gas in combined cycle has occurred against a background of tightening environmental legislation on the emission of nitrogen oxides. The higher turbine entry temperatures required for efficiency improvement tend to increase NOx production. First-generation emission control systems involved water injection and catalytic reduction and were relatively expensive to operate. Dry low-NOx combustion systems have therefore been developed but demand more primary air for combustion. This gives added incentive to the reduction of air requirements for cooling the combustor and turbine blading. This paper reviews the various approaches adopted by the main gas turbine manufacturers which are achieving very low levels of NOx emission from natural gas combustion. Further developments, however, are necessary for liquid fuels.

Experimental and Computational Analysis of an Additive Manufactured Vaporization Injector for a Micro-Gas Turbine

2019 ◽  
Author(s):  
Adamos Adamou ◽  
Ian Kennedy ◽  
Ben Farmer ◽  
Ahmed Hussein ◽  
Colin Copeland
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Front Surface ◽  
Liquid Fuels ◽  
Balance Model ◽  
Fuel Temperature ◽  
Ansys Fluent ◽  
Complete Combustion ◽  
Flamelet Model ◽  
Micro Gas Turbine

Abstract Vaporization injectors have been in existence for decades and are a well-proven method of preparing liquid fuels for combustion by heating them above the boiling point of their heaviest hydrocarbon ingredient. By doing so, it converts the fuels into a vapour prior to combustion. When attempting to apply this method of fuel vaporization to micro gas turbines, manufacturing difficulties arise, due to the small complex passages that are required to direct the fuel closer to the high-temperature zone in the combustion chamber and then back to a favourable injection location. This is where the use of additive manufacturing (AM) can prove advantageous due to the complex designs that can be achieved at much smaller scales and potentially at cheaper costs when compared to traditional subtractive manufacturing. The motivation behind the research is to improve the overall efficiency of micro-gas turbines, so they can be applied as range extenders in electric vehicles. Due to the increasing adoption of vehicle electrification. This paper covers the comparison of experimental results for two traditionally manufactured injectors and a third selective laser melted injector (SLM), which were tested in a swirl stabilised micro gas turbine can type combustor on the University of Baths gas stand. The operating range of the tests was 1–4 Bar and 30 to 630 °C inlet air. To the authors knowledge, this is the first such comparison to be made for a gas turbine in open literature, despite wide reports of AM being used in large gas turbines. From the tests, it was found that the 3 and 8 hole machined injectors could not produce stable combustion at the desired operating condition of 4 Bar and 630 °C. The SLM 8 hole injector, however, was able to sustain a stable and constant burn at this design point with low NOx, CO and THC emissions. It was also noticed that the flame colour changed from a yellow flame when testing the first two injectors, to a blue flame when testing the SLM injector suggesting more complete combustion was being achieved due to the lack of soot in burned products, this was assumed to be due to the fuel reaching its saturation conditions within the injector. A number of measurements were taken at various points around the combustor, which included temperatures, pressures and emissions readings. These results were then used to create and validate a non-premixed steady diffusion flamelet model in ANSYS Fluent for the AM injector case. The CFD results were found to overpredict the temperature by approximately 10% when compared to the thermocouple values. This was found to be similar to other studies with similar experimental and computational setups, so it was deemed acceptable. From the validated CFD model, the heat flux at the front surface of the injector was extracted, to be used in a simple heat balance model. Based on a conservative estimate of fuel temperature, the model found that the SLM injectors should have created very near saturation conditions in the nozzle. As this was a conservative analysis, it confirms the experimental findings that partially vaporized fuel was exciting the injector. The model also showed that the fuel in the traditionally machined, 8 hole injector would most likely exit as a liquid.

Application of Advanced Technology to In-Service Gas Turbines

1985 ◽  
Author(s):  
Robert Al Whittaker
Keyword(s):  
Gas Turbine ◽  
Power Output ◽  
Gas Turbines ◽  
State Of The Art ◽  
Fuel Efficiency ◽  
Advanced Technology ◽  
Operating Costs ◽  
Technical Issues

This paper discusses the technical issues and business considerations involved in the application of advanced technology to gas turbine replacement parts. Today’s gas turbine owners are facing increased demands on their older machines in the areas of increased fuel efficiency, increased power output, and reduced operating costs. These demands can only be met through the use of superior replacement parts, which is made possible through the application of state-of-the-art technology. This technology is being made available for most turbine, combustion, and controls replacement parts.

scholarly journals Volatile, Low Lubricity Fuels in Gas Turbine Plants: A Review of Main Fuel Options and Their Respective Merits

1998 ◽  
Author(s):  
M. Molière ◽  
F. Geiger ◽  
E. Deramond ◽  
T. Becker
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Alternative Fuels ◽  
Primary Energy ◽  
Liquid Fuels ◽  
Heavy Duty ◽  
Gas Condensates ◽  
Clear Identification

While natural gas is achieving unrivalled penetration in the power generation sector, especially in gas-turbine combined cycles (CCGT), an increasing number of alternative fuels are in a position to take up the ground left vacant by this major primary energy. In particular, within the thriving family of liquid fuels, the class of volatile products opens interesting prospects for clean and efficient power generation in CCGT plants. Therefore, it has become a necessity for the gas turbine industry to extensively evaluate such new fuel candidates, among which: naphtha’s; kerosines; gas condensates; Natural Gas Liquids (NGL) and alcohols are the most prominent representatives. From a technical standpoint, the success of such projects requires both a careful approach to several specific issues (eg: fuel handling & storage, operation safety) and a clear identification of technological limits. For instance, while the purity of gas condensates meets the requirements of heavy-duty technologies, it generally appears unsuitable for aeroderivative machines. This paper offers a succinct but comprehensive technical approach and overviews some experience acquired in this area with heavy duty gas turbines. Its aim is to inform gas turbine users/engineers and project developers who envisage volatile fuels as alternative primary energies in gas turbine plants.

Firing Low Viscosity Liquid Fuels in Heavy Duty Gas Turbines

2003 ◽  
Author(s):  
Jean-Pierre Stalder ◽  
Phil Roberts
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Electrical Energy ◽  
Thermal Capacity ◽  
Transport Infrastructure ◽  
Liquid Fuels ◽  
Light Cycle ◽  
Heavy Duty ◽  
Light Cycle Oil ◽  
Low Viscosity

Sustained economic growth has created a strong demand for electrical energy worldwide. Security of fuel supply and cost are therefore very often critical issues for thermal capacity additions. Also the distance from fuel sources and available fuel transport infrastructure is an important factor in the cost of generation. Many plant locations have only limited supplies of conventional gas turbine fuels, namely natural gas and distillate fuels, thus a drive to diversify the fuels involved. For other electricity producers, the optimal use of existing or potential fuel resources is a must for economical reasons. Therefore, the possibility of using alternative gas turbine liquid fuels, such as volatile and/or low viscosity fuels like naphtha, gas condensates, kerosene, methanol, ethanol, or low lubricity distillate fuels; refinery by-products such as BTX fuels (benzene-toluene-xylene mixtures), LCO-light cycle oil, or in the future synthetic fuels (GTL) are particularly interesting for their ability to be fired in heavy duty gas turbines. However, the practical use of these fuels creates specific issues such as low lubricity properties which can affect sensitive key components like fuel pumps and flow dividers. This paper addresses the many practical aspects of using fuel lubricity additives for reduced component wear in gas turbine fuel systems, and for reliability and successful plant operation on these alternative gas turbine liquid fuels. Also an overview of acquired experience is given.

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