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Journal articles on the topic 'Gas turbine fuels'
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1
Wenglarz, R. A. "An Approach for Evaluation of Gas Turbine Deposition." Journal of Engineering for Gas Turbines and Power 114, no. 2 (April 1, 1992): 230–34. http://dx.doi.org/10.1115/1.2906577.
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An approach for estimating deposition in gas turbines is described. This approach extrapolates deposition data from lower cost experiments than turbine engine or cascade tests. The purpose is a method to screen candidate fuels and turbine protection methods so that only the most promising need be evaluated in turbine tests. The deposition approach is applied to estimate deposition maintenance intervals for a tested fuel, evaluate benefits of hot gas cleanup, and provide fuel screening criteria.
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Meier, J. G., W. S. Y. Hung, and V. M. Sood. "Development and Application of Industrial Gas Turbines for Medium-Btu Gaseous Fuels." Journal of Engineering for Gas Turbines and Power 108, no. 1 (January 1, 1986): 182–90. http://dx.doi.org/10.1115/1.3239869.
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This paper describes the successful development and application of industrial gas turbines using medium-Btu gaseous fuels, including those derived from biodegradation of organic matters found in sanitary landfills and liquid sewage. The effects on the gas turbine and its combustion system of burning these alternate fuels compared to burning high-Btu fuels, along with the gas turbine development required to use alternate fuels from the point of view of combustion process, control system, gas turbine durability, maintainability and safety, are discussed.
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Roy Yap, Mun, and Ting Wang. "Simulation of Producer Gas Fired Power Plants with Inlet Fog Cooling and Steam Injection." Journal of Engineering for Gas Turbines and Power 129, no. 3 (December 9, 2006): 637–47. http://dx.doi.org/10.1115/1.2718571.
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Biomass can be converted to energy via direct combustion or thermochemical conversion to liquid or gas fuels. This study focuses on burning producer gases derived from gasifying biomass wastes to produce power. Since the producer gases are usually of low calorific values (LCV), power plant performance under various operating conditions has not yet been proven. In this study, system performance calculations are conducted for 5MWe power plants. The power plants considered include simple gas turbine systems, steam turbine systems, combined cycle systems, and steam injection gas turbine systems using the producer gas with low calorific values at approximately 30% and 15% of the natural gas heating value (on a mass basis). The LCV fuels are shown to impose high compressor back pressure and produce increased power output due to increased fuel flow. Turbine nozzle throat area is adjusted to accommodate additional fuel flows to allow the compressor to operate within safety margin. The best performance occurs when the designed pressure ratio is maintained by widening nozzle openings, even though the turbine inlet pressure is reduced under this adjustment. Power augmentations under four different ambient conditions are calculated by employing gas turbine inlet fog cooling. Comparison between inlet fog cooling and steam injection using the same amount of water mass flow indicates that steam injection is less effective than inlet fog cooling in augmenting power output. Maximizing steam injection, at the expense of supplying the steam to the steam turbine, significantly reduces both the efficiency and the output power of the combined cycle. This study indicates that the performance of gas turbine and combined cycle systems fueled by the LCV fuels could be very different from the familiar behavior of natural gas fired systems. Care must be taken if on-shelf gas turbines are modified to burn LCV fuels.
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Moliere, M. "Expanding fuel flexibility of gas turbines." Proceedings of the Institution of Mechanical Engineers, Part A: Journal of Power and Energy 219, no. 2 (March 1, 2005): 109–19. http://dx.doi.org/10.1243/095765005x6818.
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Gas turbines are continuous-flow engines that develop steady aerodynamics and flame kinetics. These features reduce the constraints placed on fuel properties for combustion and provide a considerable margin for clean combustion. In particular, heavy-duty gas turbines can operate on a large number of primary fuels that are available in many branches of the industry. These accessible fuels include natural gas (NG) and diesel fuel (DF), as well as a number of industry byproducts generated by the refining and petrochemical sectors, coal and oil and gas activities, steel and mining branches, and by the agricultural industry (biofuels). This fuel flexibility enhances the existing qualities demonstrated by gas turbines, such as efficiency, reliability, versatility in applications [mechanical drive, simple and combined cycle, combined heat and power (CHP)], strong integration potential [integrated gasification combined cycle (IGCC), gas to liquid (GTL)], and low emissions. As a result, gas turbines that use local fuel resources, synfuels or industrial byproducts — and are deployed in simple or combined cycles or in CHP units — can play a prominent role in the creation of reliable, clean, and energy-efficient power systems. This article provides the energy community with comprehensive information about alternative gas turbine (GT) fuels, covering volatile fuels [naphtha, natural gas liquid (NGL), condensates], weak gas fuels from the coal/iron industry [coalbed gas, coke oven gas (COG), blast furnace gas (BFG)], ash-forming oils, and hydrogen-rich byproducts from refineries or petrochemical plants. The main technical considerations essential to the success of alternative fuel applications are reviewed and key experience milestones are highlighted. A special emphasis is placed on the combustion of hydrogen in gas turbines.
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Basha, Mehaboob, S. M. Shaahid, and Luai Al-Hadhrami. "Impact of inlet fogging and fuels on power and efficiency of gas turbine plants." Thermal Science 17, no. 4 (2013): 1107–17. http://dx.doi.org/10.2298/tsci110708042b.
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A computational study to assess the performance of different gas turbine power plant configurations is presented in this paper. The work includes the effect of humidity, ambient inlet air temperature and types of fuels on gas turbine plant configurations with and without fogger unit. Investigation also covers economic analysis and effect of fuels on emissions. GT frames of various sizes/ratings are being used in gas turbine power plants in Saudi Arabia. 20 MWe GE 5271RA, 40 MWe GE-6561B and 70 MWe GE-6101FA frames are selected for the present study. Fogger units with maximum mass flow rate of 2 kg/s are considered for the present analysis. Reverse Osmosis unit of capacity 4 kg/s supplies required water to the fogger units. GT PRO software has been used for carrying out the analysis including; net plant output and net efficiency, break even electricity price and break even fuel LHV price etc., for a given location of Saudi Arabia. The relative humidity and temperature have been varied from 30 to 45 % and from 80 to 100? F, respectively. Fuels considered in the study are natural gas, diesel and heavy bunker oil. Simulated gas turbine plant output from GT PRO has been validated against an existing gas turbine plant output. It has been observed that the simulated plant output is less than the existing gas turbine plant output by 5%. Results show that variation of humidity does not affect the gas turbine performance appreciably for all types of fuels. For a decrease of inlet air temperature by 10 ?F, net plant output and efficiency have been found to increase by 5 and 2 %, respectively for all fuels, for GT only situation. However, for GT with Fogger scenario, for a decrease of inlet air temperature by 10 ?F, net plant output and efficiency have been found to further increase by 3.2 and 1.2 %, respectively for all fuels. For all GT frames with fogger, the net plant output and efficiency are relatively higher as compared to GT only case for all fuels. More specifically, net plant output and efficiency for natural gas are higher as compare to other fuels for all GT scenarios. For a given 70 MWe frame with and without fogger, break even fuel price and electricity price have been found to vary from 2.2 to 2.5 USD/MMBTU and from 0.020 to 0.0239 USD/kWh respectively. It has been noticed that turbines operating on natural gas emit less carbon relatively as compared to other fuels.
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Sadig, Hussain, Shaharin Anwar Sulaiman, Mior A. Said, and Suzana Yusup. "Performance and Emissions of a Micro-Gas Turbine Fueled with LPG/Producer Gas in a Dual Fuel Mode." Applied Mechanics and Materials 695 (November 2014): 482–86. http://dx.doi.org/10.4028/www.scientific.net/amm.695.482.
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In this paper, a tubular combustor along with a single shaft micro-gas turbine system was experimentally tested with a producer gas fuels. In order to carry out the experiments, a low cost single shaft micro-gas turbine was developed. The system was characterized first with liquefied petroleum gas (LPG) and then tested with two producer gas fuels in a dual fuel mode. The tests were examined in terms of LPG fuel replacement, turbine entrance temperature, efficiency and emission characteristics at different LPG fuel replacement ratios. The study showed a maximum LPG replacement of 42% and 56% on energy basis for producer gas1 and producer gas2, respectively.
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Leung, E. Y. W. "A Universal Correlation for the Thermal Efficiency of Open Gas Turbine Cycle With Different Fuels." Journal of Engineering for Gas Turbines and Power 107, no. 3 (July 1, 1985): 560–65. http://dx.doi.org/10.1115/1.3239772.
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It is well known that, unlike the thermal efficiency of closed gas turbine cycles, the thermal efficiency of open gas turbine cycles varies with the fuel used in the combustion process. Presented in this paper is a thorough investigation of the effects of hydrocarbon fuels and alcohol fuels on the thermal efficiency of open gas turbine cycle. Among the open cycles with different fuels and otherwise identical specifications, the computed thermal efficiencies show a variation of about 2 percent between the extremes, which is appreciable. It was found that the thermal efficiency increases with a parameter of the fuel, c1 + c2, taken from the equation of reaction, c(Fuel)+O2→c1(CO2)+c2(H2O), and that the thermal efficiency of open gas turbine cycles is likely to be higher if the original fuel is replaced by a fuel which has a higher fuel parameter, c1 + c2. A universal correlation for both hydrocarbon fuels and alcohol fuels is presented in Fig. 1, plotting the thermal efficiency maximized from the pressure ratio variation, versus the parameter, c1 + c2. Alternatively, this correlation is also generalized by equation (2).
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Bozza, Fabio, Maria Cristina Cameretti, and Raffaele Tuccillo. "The Employment of Hydrogenerated Fuels From Natural Gas Reforming: Gas Turbine and Combustion Analysis." Journal of Engineering for Gas Turbines and Power 126, no. 3 (July 1, 2004): 489–97. http://dx.doi.org/10.1115/1.1691440.
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An integrated method for power plant analysis, including rotating component matching and CFD simulation of the combustion process, is applied to the study of gas turbines supplied with hydrogenated fuels originating from the natural gas reforming. The method proposed by the authors allows estimation of the power plant performance and emission in the gas turbine operating range. A comparison is then carried out between the plant behavior with conventional fuelling and with decarbonised fuel supply. Attention is also paid to the study of the combustion regimes with either natural gas or fuels with increasing hydrogen contents, in order to achieve a realistic insight of both the temperature distributions and the growth of nitric oxides throughout the combustion chamber.
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Ammar, Nader R., and Ahmed I. Farag. "CFD Modeling of Syngas Combustion and Emissions for Marine Gas Turbine Applications." Polish Maritime Research 23, no. 3 (September 1, 2016): 39–49. http://dx.doi.org/10.1515/pomr-2016-0030.
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Abstract Strong restrictions on emissions from marine power plants will probably be adopted in the near future. One of the measures which can be considered to reduce exhaust gases emissions is the use of alternative fuels. Synthesis gases are considered competitive renewable gaseous fuels which can be used in marine gas turbines for both propulsion and electric power generation on ships. The paper analyses combustion and emission characteristics of syngas fuel in marine gas turbines. Syngas fuel is burned in a gas turbine can combustor. The gas turbine can combustor with swirl is designed to burn the fuel efficiently and reduce the emissions. The analysis is performed numerically using the computational fluid dynamics code ANSYS FLUENT. Different operating conditions are considered within the numerical runs. The obtained numerical results are compared with experimental data and satisfactory agreement is obtained. The effect of syngas fuel composition and the swirl number values on temperature contours, and exhaust gas species concentrations are presented in this paper. The results show an increase of peak flame temperature for the syngas compared to natural gas fuel combustion at the same operating conditions while the NO emission becomes lower. In addition, lower CO2 emissions and increased CO emissions at the combustor exit are obtained for the syngas, compared to the natural gas fuel.
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Lukas, M. "Comparison of Spectrometric Techniques for the Analysis of Liquid Gas Turbine Fuels." Journal of Engineering for Gas Turbines and Power 115, no. 3 (July 1, 1993): 620–27. http://dx.doi.org/10.1115/1.2906751.
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High-temperature corrosion and fuel system fouling are major concerns that confront gas turbine users. Fuel treatment is a critical requirement for gas turbine operators burning alternative fuels, and even so-called “clean fuels.” Spectrometric fuel analysis is used to determine the amount of treatment required as well as the efficiency of the treatment. In most cases, analytical techniques developed by chemists for use in laboratory environments have been adopted for field use. This paper describes the various spectrometric techniques available to the gas turbine user to analyze fuels for contaminants such as sodium, potassium, vanadium, lead, calcium, silicon, etc., and additives such as magnesium compounds. Atomic absorption spectroscopy (AAS) and various atomic emission spectroscopy (AES) techniques will be discussed and compared.
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Edwards, Tim. "Advancements in Gas Turbine Fuels From 1943 to 2005." Journal of Engineering for Gas Turbines and Power 129, no. 1 (February 1, 2006): 13–20. http://dx.doi.org/10.1115/1.2364007.
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The first provisional jet fuel specifications were published in 1943 in England (RDE/F/KER/210) and 1944 in the U.S. (AN-F-32a). Jet fuel has undergone many changes in subsequent years, with current specifications for JP-5 and JP-8 for the military in the U.S. and Jet A/Jet A-1 for commercial use worldwide. Jet fuel specifications are subject to constant tension between performance requirements and availability/cost considerations. In this paper we will discuss how jet fuels have evolved over the years from the first engines to current gas turbine engines. Jet fuels derived from nonpetroleum sources will also be discussed.
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Sarnecki, Jarosław, Tomasz Białecki, Bartosz Gawron, Jadwiga Głąb, Jarosław Kamiński, Andrzej Kulczycki, and Katarzyna Romanyk. "Thermal Degradation Process of Semi-Synthetic Fuels for Gas Turbine Engines in Non-Aeronautical Applications." Polish Maritime Research 26, no. 1 (March 1, 2019): 65–71. http://dx.doi.org/10.2478/pomr-2019-0008.
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Abstract This article concerns the issue of thermal degradation process of fuels, important from the perspective of the operation of turbine engines, especially in the context of new fuels/bio-fuels and their implementation. The studies of the kerosene-based jet fuel (Jet A-1) and its blends with synthetic components manufactured according to HEFA and ATJ technology, were presented. Both technologies are currently approved by ASTM D7566 to produce components to be added to turbine fuels. Test rig investigations were carried out according to specific methodology which reflects the phenomena taking place in fuel systems of turbine engines. The mechanism of thermal degradation process was assessed on the basis of test results for selected properties, IR spectroscopy and calculation of activation energy. The results show that with the increase of the applied temperature there is an increment of the content of solid contaminants, water and acid for all tested fuels. Thermal degradation process is different for conventional jet fuel when compared to blends, but also semi-synthetic fuels distinguished by different thermal stability depending on a given manufacturing technology.
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Langston, Lee S. "Gas Turbines - Major Greenhouse Gas Inhibitors." Mechanical Engineering 137, no. 12 (December 1, 2015): 54–55. http://dx.doi.org/10.1115/1.2015-nov-5.
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This article explains how combined cycle gas turbine (CCGT) power plants can help in reducing greenhouse gas from the atmosphere. In the last 25 years, the development and deployment of CCGT power plants represent a technology breakthrough in efficient energy conversion, and in the reduction of greenhouse gas production. Existing gas turbine CCGT technology can provide a reliable, on-demand electrical power at a reasonable cost along with a minimum of greenhouse gas production. Natural gas, composed mostly of methane, is a hydrocarbon fuel used by CCGT power plants. Methane has the highest heating value per unit mass of any of the hydrocarbon fuels. It is the most environmentally benign of fuels, with impurities such as sulfur removed before it enters the pipeline. If a significant portion of coal-fired Rankine cycle plants are replaced by the latest natural gas-fired CCGT power plants, anthropogenic carbon dioxide released into the earth’s atmosphere would be greatly reduced.
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Larson, E. D., T. G. Kreutz, and S. Consonni. "Combined Biomass and Black Liquor Gasifier/Gas Turbine Cogeneration at Pulp and Paper Mills." Journal of Engineering for Gas Turbines and Power 121, no. 3 (July 1, 1999): 394–400. http://dx.doi.org/10.1115/1.2818486.
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Kraft pulp and paper mills generate large quantities of black liquor and byproduct biomass suitable for gasification. These fuels are used today for onsite cogeneration of heat and power in boiler/steam turbine systems. Gasification technologies under development would enable these fuels to be used in gas turbines. This paper reports results of detailed full-load performance modeling of pulp-mill cogeneration systems, based on gasifier/gas turbine technologies and, for comparison, on conventional steam-turbine cogeneration technologies. Pressurized, oxygen-blown black liquor gasification, the most advanced of proposed commercial black liquor gasifier designs, is considered, together with three alternative biomass gasifier designs under commercial development (high-pressure air-blown, low-pressure air-blown, and low-pressure indirectly-heated). Heavy-duty industrial gas turbines of the 70-MWe and 25-MWe class are included in the analysis. Results indicate that gasification-based cogeneration with biomass-derived fuels would transform a typical pulp mill into a significant power exporter and would also offer possibilities for net reductions in emissions of carbon dioxide relative to present practice.
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Khandelwal, B., J. Cronly, I. S. Ahmed, C. J. Wijesinghe, and C. Lewis. "The effect of alternative fuels on gaseous and particulate matter (PM) emission performance in an auxiliary power unit (APU)." Aeronautical Journal 123, no. 1263 (April 17, 2019): 617–34. http://dx.doi.org/10.1017/aer.2019.16.
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ABSTRACTThere is a growing interest in the use of alternative fuels in gas turbine engines to reduce emissions. Testing of alternative fuels is expensive when done on a large-scale gas turbine engine. In this study, a re-commissioned small gas turbine auxiliary power unit (APU) has been used to test various blends of Jet A-1, synthetic paraffinic kerosene (SPK) and diesel with as well as eight other novel fuels. A detailed analysis of performance, gaseous emissions and particulate emissions has been presented in this study. It is observed that aromatic content in general as well as the particular chemical composition of the aromatic compound plays a vital role in particulate emissions generation. SPK fuel shows substantially lower particulate emissions with respect to Jet A. However, not all the species of aromatics negatively impact particulate emissions. Gaseous emissions measured are comparable for all the fuels tested in this study.
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Ardeshiri, Sh. "The impact of physico-chemical properties of the jet fuel and biofuels on the characteristics of gas-turbine engines." Civil Aviation High Technologies 22, no. 6 (December 26, 2019): 8–16. http://dx.doi.org/10.26467/2079-0619-2019-22-6-8-16.
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The current development trend of global civil aviation is the growth of passenger and freight traffic, which entails the consumption of jet fuel. Under these conditions, increasing the efficiency of jet fuel used is of great importance. Global energy consumption is constantly growing, and, first of all, the question of diversification of oil resources arises, resources from which the bulk of motor fuels is produced. Other types of raw energy sources (natural gas, coal, bio-mass) currently account for only a small part. However, an analysis of the development of jet fuels indicates that work is underway to obtain these from other sources of raw materials, especially bio-fuels. Much attention is given to obtaining bio-fuels from renewable sources – such as algae. The issue of the mass transition of civil aviation to alternative fuels is complex and requires the solution of intricate technical as well as economic issues. One of these is the assessment of the impact of new fuels on GTE performance. It is important to give an objective and quick assessment of the use of various types of fuels on the main characteristics of the engine – i.e., throttle and high-speed characteristics. In this case, it is necessary to take into account chemical processes in the chemical composition of new types of fuel. To assess the effect of fuels on the characteristics of a gas turbine engine, it is proposed to use a mathematical model that would take into account the main characteristics of the fuel itself. Therefore, the work proposes a mathematical model for calculating the characteristics of a gas turbine engine taking into account changes in the properties of the fuel itself. A comparison is made of the percentage of a mixture of biofuels and JetA1 kerosene, as well as pure JetA1 and TC-1 kerosene. The calculations, according to the proposed model, are consistent with the obtained characteristics of a gas turbine engine in operation when using JetA1 and TC-1 kerosene. Especially valuable are the obtained characteristics of a gas turbine engine depending on a mixture of biofuel and kerosene. It was found that a mixture of biofuel and kerosene changes the physicochemical characteristics of fuel and affects the change in engine thrust and specific fuel consumption. It is shown that depending on the obtained physicochemical properties of a mixture of biofuel and kerosene, it is possible to increase the fuel efficiency and environmental friendliness of the gas turbine engines used.
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Moore, M. J. "Nox emission control in gas turbines for combined cycle gas turbine plant." Proceedings of the Institution of Mechanical Engineers, Part A: Journal of Power and Energy 211, no. 1 (February 1, 1997): 43–52. http://dx.doi.org/10.1243/0957650971536980.
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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.
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Roberts, Rory A., Jack Brouwer, Eric Liese, and Randall S. Gemmen. "Dynamic Simulation of Carbonate Fuel Cell-Gas Turbine Hybrid Systems." Journal of Engineering for Gas Turbines and Power 128, no. 2 (April 1, 2006): 294–301. http://dx.doi.org/10.1115/1.1852565.
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Hybrid fuel cell/gas turbine systems provide an efficient means of producing electricity from fossil fuels with ultra low emissions. However, there are many significant challenges involved in integrating the fuel cell with the gas turbine and other components of this type of system. The fuel cell and the gas turbine must maintain efficient operation and electricity production while protecting equipment during perturbations that may occur when the system is connected to the utility grid or in stand-alone mode. This paper presents recent dynamic simulation results from two laboratories focused on developing tools to aid in the design and dynamic analyses of hybrid fuel cell systems. The simulation results present the response of a carbonate fuel cell/gas turbine, or molten carbonate fuel cell/gas turbine, (MCFC/GT) hybrid system to a load demand perturbation. Initial results suggest that creative control strategies will be needed to ensure a flexible system with wide turndown and robust dynamic operation.
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Martone, J. A. "USAF Toxicology Research on Petroleum and Shale-Derived Aviation Gas Turbine Fuels." Journal of Engineering for Gas Turbines and Power 108, no. 2 (April 1, 1986): 387–90. http://dx.doi.org/10.1115/1.3239916.
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As one of the nation’s largest users of aircraft turbine fuels, the USAF has interest in assuring the safe use of these hydrocarbons by its military and civilian workers. This concern stimulated research to define potential adverse health effects and develop criteria for safe exposure limits for military aviation fuels. The first inhalation exposure to JP-4, the primary fuel used in USAF aircraft, was conducted in 1973. Since this initial subchronic study, the USAF has conducted numerous subchronic and one-year oncogenic inhalation studies to establish health criteria for aviation fuels. This paper summarizes the status of studies to define the toxicity of petroleum and shale-derived aircraft turbine engine fuels and discusses the preliminary findings of toxic nephropathy and primary renal tumors observed in male Fischer 344 rats.
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Kosowski, Krzysztof, Karol Tucki, Marian Piwowarski, Robert Stępień, Olga Orynycz, and Wojciech Włodarski. "Thermodynamic Cycle Concepts for High-Efficiency Power Plants. Part B: Prosumer and Distributed Power Industry." Sustainability 11, no. 9 (May 9, 2019): 2647. http://dx.doi.org/10.3390/su11092647.
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An analysis was carried out for different thermodynamic cycles of power plants with air turbines. A new modification of a gas turbine cycle with the combustion chamber at the turbine outlet has been described in the paper. A special air by-pass system of the combustor was applied, and in this way, the efficiency of the turbine cycle was increased by a few points. The proposed cycle equipped with an effective heat exchanger could have an efficiency higher than a classical gas turbine cycle with a regenerator. Appropriate cycle and turbine calculations were performed for micro power plants with turbine output in the range of 10–50 kW. The best arrangements achieved very high values of overall cycle efficiency, 35%–39%. Such turbines could also work in cogeneration and trigeneration arrangements, using various fuels such as liquids, gaseous fuels, wastes, coal, or biogas. Innovative technology in connection with ecology and the failure-free operation of the power plant strongly suggests the application of such devices at relatively small generating units (e.g., “prosumers” such as home farms and individual enterprises), assuring their independence from the main energy providers. Such solutions are in agreement with the politics of sustainable development.
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Langston, Lee S. "Piped Gas Fuels GT Power Plant Growth." Mechanical Engineering 143, no. 1 (January 1, 2021): 62–63. http://dx.doi.org/10.1115/1.2021-jan9.
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Abstract In the last 10 years the growth of America’s natural gas fueled, gas turbine power plants have flourished in its lower 48 states. They are replacing older coal-fueled steam turbine power plants, ending a century’s-old dominance of King Coal, for the nation’s electricity production.
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Zhang, Taiyan, Yongling Yao, Chengbin Lu, Bin Xu, and Dongyang He. "Biomass Derived Fuels for Gas Turbine Application." IOP Conference Series: Materials Science and Engineering 730 (February 11, 2020): 012043. http://dx.doi.org/10.1088/1757-899x/730/1/012043.
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Blakey, Simon, Lucas Rye, and Christopher Willam Wilson. "Aviation gas turbine alternative fuels: A review." Proceedings of the Combustion Institute 33, no. 2 (January 2011): 2863–85. http://dx.doi.org/10.1016/j.proci.2010.09.011.
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Wenglarz, R. A., and R. G. Fox. "Physical Aspects of Deposition From Coal-Water Fuels Under Gas Turbine Conditions." Journal of Engineering for Gas Turbines and Power 112, no. 1 (January 1, 1990): 9–14. http://dx.doi.org/10.1115/1.2906484.
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Deposition, erosion, and corrosion (DEC) experiments were conducted using three coal-water fuels (CWF) in a staged subscale turbine combustor operated at conditions of a recuperated turbine. This rich-quench-lean (RQL) combustor appears promising for reducing NOx levels to acceptable levels for future turbines operating with CWF. Specimens were exposed in two test sections to the combustion products from the RQL combustor. The gas and most surface temperatures in the first and second test sections represented temperatures in the first stators and rotors, respectively, of a recuperated turbine. The test results indicate deposition is affected substantially by gas temperature, surface temperature, and unburned carbon due to incomplete combustion. The high rates of deposition observed at first stator conditions showed the need for additional tests to identify CWF coals with lower deposition tendencies and to explore deposition control measures such as hot gas cleanup.
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Langston, Lee S. "Detonation Gas Turbines." Mechanical Engineering 135, no. 12 (December 1, 2013): 50–54. http://dx.doi.org/10.1115/1.2013-dec-4.
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This article focuses on various technical and functional aspects of detonation gas turbines. Detonation combustion involves a supersonic flow, with the chemical reaction front accelerating, driving a shock wave system in its advancement. In the 1990s, detonation-based power concepts began with pulse detonation engines (PDEs), and have now moved into the continuous detonation mode, termed rotating detonation engines (RDEs). Modern gas turbine combustors are compact, robust, tolerant of a wide variety of fuels, and provide the highest combustion intensities. The single-spool RDE gas turbine is represented by a detonation cycle, which accounts for the supersonic features of the heat addition, starting at station 2.5′. Continued research and development by the RDE technical community is needed to see if the promise of improved performance and downsized turbomachinery for a detonation cycle is real.
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Cherednichenko, Oleksandr, Valerii Havrysh, Vyacheslav Shebanin, Antonina Kalinichenko, Grzegorz Mentel, and Joanna Nakonieczny. "Local Green Power Supply Plants Based on Alcohol Regenerative Gas Turbines: Economic and Environmental Aspects." Energies 13, no. 9 (May 1, 2020): 2156. http://dx.doi.org/10.3390/en13092156.
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Growing economies need green and renewable energy. Their financial development can reduce energy consumption (through energy-efficient technologies) and replace fossil fuels with renewable ones. Gas turbine engines are widely used in transport and industry. To improve their economic attractiveness and to reduce harmful emissions, including greenhouse gases, alternative fuels and waste heat recovery technologies can be used. A promising direction is the use of alcohol and thermo-chemical recuperation. The purpose of this study is to estimate the economic efficiency and carbon dioxide emissions of an alcohol-fueled regenerative gas turbine engine with thermo-chemical recuperation. The carbon dioxide emissions have been determined using engine efficiency, fuel properties, as well as life cycle analysis. The engine efficiency was maximized by varying the water/alcohol ratio. To evaluate steam fuel reforming for a certain engine, a conversion performance factor has been suggested. At the optimal water/methanol ratio of 3.075 this technology can increase efficiency by 4% and reduce tank-to-wake emission by 80%. In the last 6 months of 2019, methanol prices were promising for power and cogeneration plants in remote locations. The policy recommendation is that local authorities should pay attention to alcohol fuel and advanced turbines to curb the adverse effects of burning petroleum fuel on economic growth and the environment.
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Silva, E. B., C. Bringhenti, M. Assato, and R. C. Lima. "GAS TURBINE PERFORMANCE ANALYSIS OPERATING WITH LOWHEATING VALUE FUELS." Revista de Engenharia Térmica 12, no. 2 (December 31, 2013): 08. http://dx.doi.org/10.5380/reterm.v12i2.62037.
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Usually, power plants work with gas turbine designed to fire natural gas; however, there are possibilities to use other types of gaseous fuels with different calorific values that may be available close to the power plant site. These fuels can be gases obtained from steel (from blast furnaces and coking plants), from gasification processes of coal or biomass, among others. In this work, a gas turbine performance was evaluated at different operational conditions in order to verify the technical feasibility of burning low calorific value fuels. A gas turbine designed to operate with natural gas was used as a reference, the model was built and the performance evaluated at design and off-design conditions using a commercial computer program, GasTurb 11®. A good agreement was obtained between the model operating with natural gas and the available data from open literature, at design and off-design conditions. The model was simulated using low heating value fuels under the same conditions established for natural gas. A reduction in compressor’s surge margin was identified when using low heating value fuels as well as an increase in power output. Therefore, for safe operation a strategy for recovering the surge margin was adopted. In this study the control strategy adopted was bleed air at the compressor discharge. This control strategy presents a technical viability and ensures that the gas turbine operates with the same surge margin level as when using natural gas.
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Spiro, C. L., S. G. Kimura, and C. C. Chen. "Ash Behavior During Combustion and Deposition in Coal-Fueled Gas Turbines." Journal of Engineering for Gas Turbines and Power 109, no. 3 (July 1, 1987): 325–30. http://dx.doi.org/10.1115/1.3240043.
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Chemical and physical transformations of coal ash during combustion and deposition in gas turbine environments have been studied. Extensive characterization of the coal-water mixture fuel and deposits obtained on deposition pins and turbine nozzle vanes has been performed. The behavior of alkali metals has been found to be much different from that for petroleum fuels, resulting in lower than expected deposition and probable reduced corrosion rates.
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Božo, Milana Guteša, and Agustin Valera-Medina. "Prediction of Novel Humified Gas Turbine Cycle Parameters for Ammonia/Hydrogen Fuels." Energies 13, no. 21 (November 2, 2020): 5749. http://dx.doi.org/10.3390/en13215749.
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Carbon emissions reduction via the increase of sustainable energy sources in need of storage defines chemicals such as ammonia as one of the promising solutions for reliable power decarbonisation. However, the implementation of ammonia for fuelling purposes in gas turbines for industry and energy production is challenging when compared to current gas turbines fuelled with methane. One major concern is the efficiency of such systems, as this has direct implications in the profitability of these power schemes. Previous works performed around parameters prediction of standard gas turbine cycles showed that the implementation of ammonia/hydrogen as a fuel for gas turbines presents very limited overall efficiencies. Therefore, this paper covers a new approach of parameters prediction consisting of series of analytical and numerical studies used to determine emissions and efficiencies of a redesigned Brayton cycle fuelled with humidified ammonia/hydrogen blends. The combustion analysis was done using CHEMKIN-PRO (ANSYS, Canonsburg, PA, USA), and the results were used for determination of the combustion efficiency. Chemical kinetic results denote the production of very low NOx as a consequence of the recombination of species in a post combustion zone, thus delivering atmospheres with 99.2% vol. clean products. Further corrections to the cycle (i.e., compressor and turbine size) followed, indicating that the use of humidified ammonia-hydrogen blends with a total the amount of fuel added of 10.45 MW can produce total plant efficiencies ~34%. Values of the gas turbine cycle inlet parameters were varied and tested in order to determine sensibilities to these modifications, allowing changes of the analysed outlet parameters below 5%. The best results were used as inputs to determine the final efficiency of an improved Brayton cycle fuelled with humidified ammonia/hydrogen, reaching values up to 43.3% efficiency. It was notorious that humidification at the injector was irrelevant due to the high water production (up to 39.9%) at the combustion chamber, whilst further research is recommended to employ the unburned ammonia (0.6% vol. concentration) for the reduction of NOx left in the system (~10 ppm).
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Cook, C. S., J. C. Corman, and D. M. Todd. "System Evaluation and LBTU Fuel Combustion Studies for IGCC Power Generation." Journal of Engineering for Gas Turbines and Power 117, no. 4 (October 1, 1995): 673–77. http://dx.doi.org/10.1115/1.2815452.
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The integration of gas turbines and combined cycle systems with advances in coal gasification and gas stream cleanup systems will result in economically viable IGCC systems. Optimization of IGCC systems for both emission levels and cost of electricity is critical to achieving this goal. A technical issue is the ability to use a wide range of coal and petroleum-based fuel gases in conventional gas turbine combustor hardware. In order to characterize the acceptability of these syngases for gas turbines, combustion studies were conducted with simulated coal gases using full-scale advanced gas turbine (7F) combustor components. It was found that NOx emissions could be correlated as a simple function of stoichiometric flame temperature for a wide range of heating values while CO emissions were shown to depend primarily on the H2 content of the fuel below heating values of 130 Btu/scf (5125 kJ/NM3) and for H2/CO ratios less than unity. The test program further demonstrated the capability of advanced can-annular combustion systems to burn fuels from air-blown gasifiers with fuel lower heating values as low as 90 Btu/scf (3548 kJ/NM3) at 2300°F (1260°C) firing temperature. In support of ongoing economic studies, numerous IGCC system evaluations have been conducted incorporating a majority of the commercial or near-commercial coal gasification systems coupled with “F” series gas turbine combined cycles. Both oxygen and air-blown configurations have been studied, in some cases with high and low-temperature gas cleaning systems. It has been shown that system studies must start with the characteristics and limitations of the gas turbine if output and operating economics are to be optimized throughout the range of ambient operating temperature and load variation.
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Bons, Jeffrey P., Jared Crosby, James E. Wammack, Brook I. Bentley, and Thomas H. Fletcher. "High-Pressure Turbine Deposition in Land-Based Gas Turbines From Various Synfuels." Journal of Engineering for Gas Turbines and Power 129, no. 1 (September 6, 2005): 135–43. http://dx.doi.org/10.1115/1.2181181.
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Ash deposits from four candidate power turbine synfuels were studied in an accelerated deposition test facility. The facility matches the gas temperature and velocity of modern first-stage high-pressure turbine vanes. A natural gas combustor was seeded with finely ground fuel ash particulate from four different fuels: straw, sawdust, coal, and petroleum coke. The entrained ash particles were accelerated to a combustor exit flow Mach number of 0.31 before impinging on a thermal barrier coating (TBC) target coupon at 1150°C. Postexposure analyses included surface topography, scanning electron microscopy, and x-ray spectroscopy. Due to significant differences in the chemical composition of the various fuel ash samples, deposit thickness and structure vary considerably for each fuel. Biomass products (e.g., sawdust and straw) are significantly less prone to deposition than coal and petcoke for the same particle loading conditions. In a test simulating one turbine operating year at a moderate particulate loading of 0.02 parts per million by weight, deposit thickness from coal and petcoke ash exceeded 1 and 2mm, respectively. These large deposits from coal and petcoke were found to detach readily from the turbine material with thermal cycling and handling. The smaller biomass deposit samples showed greater tenacity in adhering to the TBC surface. In all cases, corrosive elements (e.g., Na, K, V, Cl, S) were found to penetrate the TBC layer during the accelerated deposition test. Implications for the power generation goal of fuel flexibility are discussed.
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Newby, Richard A., Wen-Ching Yang, and Ronald L. Bannister. "Fuel Gas Cleanup Parameters in Air-Blown IGCC." Journal of Engineering for Gas Turbines and Power 122, no. 2 (October 20, 1999): 247–54. http://dx.doi.org/10.1115/1.483202.
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Fuel gas cleanup processing significantly influences overall performance and cost of IGCC power generation. The raw fuel gas properties (heating value, sulfur content, alkali content, ammonia content, “tar” content, particulate content) and the fuel gas cleanup requirements (environmental and turbine protection) are key process parameters. Several IGCC power plant configurations and fuel gas cleanup technologies are being demonstrated or are under development. In this evaluation, air-blown, fluidized-bed gasification combined-cycle power plant thermal performance is estimated as a function of fuel type (coal and biomass fuels), extent of sulfur removal required, and the sulfur removal technique. Desulfurization in the fluid bed gasifier is combined with external hot fuel gas desulfurization, or, alternatively with conventional cold fuel gas desulfurization. The power plant simulations are built around the Siemens Westinghouse 501F combustion turbine in this evaluation. [S0742-4795(00)00502-0]
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Braun-Unkhoff, M., E. Goos, T. Kathrotia, T. Kick, C. Naumann, N. Slavinskaya, and U. Riedel. "The Importance of Detailed Chemical Mechanisms in Gas Turbine Combustion Simulations." Eurasian Chemico-Technological Journal 16, no. 2-3 (April 8, 2014): 179. http://dx.doi.org/10.18321/ectj182.
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<p>This paper – in memory of Jürgen Warnatz – summarizes selected recent papers of the Chemical Kinetics Group at the German Aerospace Center in Stuttgart. It shows the need for detailed chemical reaction mechanisms to understand practical combustion systems. A comprehensive description of combustion processes based on detailed mechanisms is especially important in the design of new gas turbine combustion chambers and in the optimization of existing ones to improve efficiency and to reduce pollutant emissions, with fuel-flexibility and load-flexibility ever becoming more important. Different aspects of combustion processes where detailed reaction mechanisms provide useful insights will be covered in this paper: Fuels (alternative jet fuels, biomass based fuels), pollutants (soot), diagnostics (chemiluminescence), and thermochemistry. Furthermore, the underlying thermodynamics inevitably connected with detailed reaction schemes will be addressed. Exemplified results will be presented clearly demonstrating the predictive capabilities of detailed reaction mechanisms to be explored in computational fluid dynamic simulations to further optimize technical combustion systems.</p>
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Gokulakrishnan, P., G. Gaines, J. Currano, M. S. Klassen, and R. J. Roby. "Experimental and Kinetic Modeling of Kerosene-Type Fuels at Gas Turbine Operating Conditions." Journal of Engineering for Gas Turbines and Power 129, no. 3 (May 31, 2006): 655–63. http://dx.doi.org/10.1115/1.2436575.
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Experimental and kinetic modeling of kerosene-type fuels is reported in the present work with special emphasis on the low-temperature oxidation phenomenon relevant to gas turbine premixing conditions. Experiments were performed in an atmospheric pressure, tubular flow reactor to measure ignition delay time of kerosene (fuel–oil No. 1) in order to study the premature autoignition of liquid fuels at gas turbine premixing conditions. The experimental results indicate that the ignition delay time decreases exponentially with the equivalence ratio at fuel-lean conditions. However, for very high equivalence ratios (>2), the ignition delay time approaches an asymptotic value. Equivalence ratio fluctuations in the premixer can create conditions conducive for autoignition of fuel in the premixer, as the gas turbines generally operate under lean conditions during premixed prevaporized combustion. Ignition delay time measurements of stoichiometric fuel–oil No. 1∕air mixture at 1 atm were comparable with that of kerosene type Jet-A fuel available in the literature. A detailed kerosene mechanism with approximately 1400 reactions of 550 species is developed using a surrogate mixture of n-decane, n-propylcyclohexane, n-propylbenzene, and decene to represent the major chemical constituents of kerosene, namely n-alkanes, cyclo-alkanes, aromatics, and olefins, respectively. As the major portion of kerosene-type fuels consists of alkanes, which are relatively more reactive at low temperatures, a detailed kinetic mechanism is developed for n-decane oxidation including low temperature reaction kinetics. With the objective of achieving a more comprehensive kinetic model for n-decane, the mechanism is validated against target data for a wide range of experimental conditions available in the literature. The data include shock tube ignition delay time measurements, jet-stirred reactor reactivity profiles, and plug-flow reactor species time–history profiles. The kerosene model predictions agree fairly well with the ignition delay time measurements obtained in the present work as well as the data available in the literature for Jet A. The kerosene model was able to reproduce the low-temperature preignition reactivity profile of JP-8 obtained in a flow reactor at 12 atm. Also, the kerosene mechanism predicts the species reactivity profiles of Jet A-1 obtained in a jet-stirred reactor fairly well.
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Shabaninia, Fereidoon, and Kazem Jafari. "Using LQG/LTR Optimal Control Method to Improve Stability and Performance of Industrial Gas Turbine System." ISRN Electronics 2012 (August 16, 2012): 1–8. http://dx.doi.org/10.5402/2012/134580.
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The gas turbine is a power plant, which produces a great amount of energy for its size and weight. Its compactness, low weigh, and multiple fuels make it a natural power plant for various industries such as power generation or oil and gas process plants. In any of these applications, the performance and stability of the gas turbines are the end products that strongly influence the profitability of the business that employs them. Control and analyses of gas turbines for achieving stability and good performance are important so that they have to operate for prolong period. Effective control system design usually benefits from an accurate dynamic model of the plant. Characteristic component parts of the system are considered in this model. Gas turbine system is described by specified thermodynamic equations that can be used for defining its model. This paper introduces an optimal LQG/LTR control method for a gas turbine. Analysing the gas turbine dynamic in time and frequency domain by using proposed control compared to PID controller is followed. Applying this optimal control method can provide good performance and stability for the component parts of system.
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Simons, Emerald, and Valentin Soloiu. "Reduction of Aircraft Gas Turbine Noise with New Synthetic Fuels and Sound Insulation Materials." Transportation Research Record: Journal of the Transportation Research Board 2603, no. 1 (January 2017): 50–64. http://dx.doi.org/10.3141/2603-06.
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The need to reduce the sound and vibration characteristics in the aerospace industry is continuously increasing because of the need to meet FAA regulations, to reduce noise pollution, and to improve customer satisfaction. To improve customer satisfaction, aircraft and engine manufacturers must work to control sound and vibration levels so that passengers do not experience discomfort during a flight. Sound and vibration characteristics of a fixed-wing aircraft with jet engines are composed of complex-frequency contents that challenge engineers in the development of quiet engine designs, aerodynamic bodies, and advanced sound- and vibration-attenuating materials. One of the noisiest parts of an aircraft, the gas turbine, was analyzed in this research. In Part 1 of this project, the use of alternative fuels in a gas turbine engine was investigated to determine whether those fuels have negative effects on sound and vibration levels. Three types of fuels were used: Jet A as the reference fuel, natural gas–derived S-8, and coal-derived isoparaffinic kerosene (IPK). The alternative fuels, S-8 and IPK, are Fischer–Tropsch process fuels. Overall sound and vibration characteristics of the alternative fuels presented a similar pattern across the frequency spectrum to those of the reference fuel, with the alternative fuels being slightly quieter. In Part 2, the sound path was treated by introducing sound-absorbing materials and investigating their acoustic performance. A melamine-based foam and soy-based foam were used in this research. Melamine is very lightweight, has excellent thermal endurance, and is hydrophobic. The soy-based foam was selected for its potential application in the aerospace industry to work toward a greener aircraft, in an effort to promote environmental sustainability. The soy-based material reduced the sound level by more than 20 dB(A) and presented better performance than the melamine at high frequencies.
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Sztekler, Karol, Wojciech Kalawa, Łukasz Mika, Jarosław Krzywanski, Karolina Grabowska, Marcin Sosnowski, Łukasz Lis, Wojciech Nowak, Artur Łukasz Lis, and Tomasz Siwek. "Integration of adsorption chillers with combined cycle gas turbine." E3S Web of Conferences 128 (2019): 01004. http://dx.doi.org/10.1051/e3sconf/201912801004.
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More efficient use of the primary energy contained in fuels translates into tangible earnings for power plants while reductions in the amounts of fuel burned, and of non-renewable resources in particular, certainly have a favourable impact on the natural environment. The main aim of the paper is to investigate the contribution of theuse of adsorption chillers to improve the production energy efficiencyin combined cycle gas turbine. Simulation calculations were performed using Sim tech's IPSEPro software.
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Bee´r, J. M., and R. V. Garland. "A Coal-Fueled Combustion Turbine Cogeneration System With Topping Combustion." Journal of Engineering for Gas Turbines and Power 119, no. 1 (January 1, 1997): 84–92. http://dx.doi.org/10.1115/1.2815567.
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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.
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Craig, J. D., and C. R. Purvis. "A Small Scale Biomass Fueled Gas Turbine Engine." Journal of Engineering for Gas Turbines and Power 121, no. 1 (January 1, 1999): 64–67. http://dx.doi.org/10.1115/1.2816313.
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A new generation of small scale (less than 20 MWe) biomass fueled, power plants are being developed based on a gas turbine (Brayton cycle) prime mover. These power plants are expected to increase the efficiency and lower the cost of generating power from fuels such as wood. The new power plants are also expected to economically utilize annual plant growth materials (such as rice hulls, cotton gin trash, nut shells, and various straws, grasses, and animal manures) that are not normally considered as fuel for power plants. This paper summarizes the new power generation concept with emphasis on the engineering challenges presented by the gas turbine component.
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Gupta, K. K., A. Rehman, and R. M. Sarviya. "Bio-fuels for the gas turbine: A review." Renewable and Sustainable Energy Reviews 14, no. 9 (December 2010): 2946–55. http://dx.doi.org/10.1016/j.rser.2010.07.025.
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Jones, B. "Gas turbine fuels and their influence on combustion." Chemical Engineering Science 42, no. 11 (1987): 2804–5. http://dx.doi.org/10.1016/0009-2509(87)87044-6.
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Larson, E. D. "Biomass-Gasifier/Gas Turbine Cogeneration in the Pulp and Paper Industry." Journal of Engineering for Gas Turbines and Power 114, no. 4 (October 1, 1992): 665–75. http://dx.doi.org/10.1115/1.2906640.
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Increasing atmospheric carbon dioxide from fossil fuel combustion is raising new interest in using renewable biomass for energy. Modest-scale cogeneration systems using air-blown gasifiers coupled to aeroderivative gas turbines are expected to have high efficiencies and low unit capital costs, making them well-suited for use with biomass. Biomass-gasifier/gas turbine (BIG/GT) technology is not commercial, but efforts aimed at near-term commercialization are ongoing worldwide. Estimated performance and cost and prospects for commercial development of two BIG/GT systems are described, one using solid biomass fuel (e.g., wood chips), the other using kraft black liquor. At an energy-efficient kraft pulp mill, a BIG/GT cogeneration system could produce over three times as much electricity as is typically produced today. The mill’s on-site energy needs could be met and a large surplus of electricity would be available for export. Using in addition currently unutilized forest residues for fuel, electricity production would be nearly five times today’s level. The total cost to produce the electricity in excess of on-site needs is estimated to be below 4 cents per kWh in most cases. At projected growth rates for kraft pulp production, the associated biomass residue fuels could support up to 100 GW of BIG/GT capacity at kraft pulp mills worldwide in 2020 (30 GW in the US). The excess electricity production worldwide in 2020 would be equivalent to 10 percent of today’s electricity production from fossil fuels.
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Basha, Mehaboob, S. M. Shaahid, and Luai Al-Hadhrami. "Impact of Gas Turbine Frame Size on Efficiency of Gas Turbine Power Plants." Applied Mechanics and Materials 492 (January 2014): 447–52. http://dx.doi.org/10.4028/www.scientific.net/amm.492.447.
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A computational study to assess the effect of gas turbine (GT) frame size on efficiency of gas turbine power plant configurations is presented in this paper. The work includes the effect of relative humidity (RH), ambient inlet air temperature and frame size on gas turbine plant configurations with and without fogger unit. Investigation also covers economic analysis. 20 MWe GE 5271RA, 40 MWe GE-6561B and 70 MWe GE-6101FA frames are selected for the present study. GT PRO software has been used for carrying out the analysis including; net plant output and net efficiency, break even electricity price (BEEP) and break even fuel LHV price (BEFP), etc. The relative humidity and temperature have been varied from 30 to 45 % and from 80 to 100° F, respectively. Fuels considered in the study are natural gas, diesel and crude oil. Results show that variation of humidity does not affect the gas turbine performance appreciably for all GT frame size regardless of type of fuel. For a decrease of inlet air temperature by 10 °F, net plant output and efficiency have been found to increase by 4 and 1.7 %, 4.2 and 1.3 %, 4.7 and 1.8 %, respectively for 20 MW,40MW and 70MW for crude oil and for GT only situation. However, for GT with Fogger scenario, for a decrease of inlet air temperature by 10 °F, net plant output and efficiency have been found to further increase by 3.1 and 1.3 %, 3 and 0.9 %, 3.2 and 1.1 %, respectively for 20 MW,40MW and 70MW. For situations with and without fogger for crude oil, BEFP have been found to vary from 1.3968 to 1.3916, 2.13 to 2.0948, 2.387 to 2.4642 USD/MMBTU respectively for 20 MW, 40MW and 70MW and BEEP have been found to vary from 0.03142 to 0.0313, 0.02488 to 0.02504, 0.0229 to 0.0233 USD/kWh respectively for 20 MW, 40MW and 70MW.
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Ioannou, Eleni, and Abdulnaser I. Sayma. "Full annulus numerical study of hot streaks propagation in a hydrogen-rich syngas-fired heavy duty axial turbine." Proceedings of the Institution of Mechanical Engineers, Part A: Journal of Power and Energy 231, no. 5 (May 16, 2017): 344–56. http://dx.doi.org/10.1177/0957650917706861.
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This paper presents a study of the effect of fuel composition on hot streaks propagation in a high-pressure turbine using a full annulus unsteady computational fluid dynamics analysis of the first two stages. Hot streaks result from the inherent non-uniformities of temperature profiles at the exit of the combustion chamber. Variations in composition arise from current challenges requiring gas turbines to adapt to fuel variations driven by the need to reduce CO2 emissions through the use of synthetic hydrogen-rich fuels (syngas) typically generated from the gasification of coal or solid waste. Syngas containing 80% hydrogen has been used in this study in a heavy duty gas turbine modified to accommodate the low calorific value fuel. Calculations were conducted on the baseline gas turbine originally designed for natural gas for the comparative study. Applying combustor representative hot streak profiles, analyses were performed for different hot streak distributions and locations. Analysis of results focused on the segregation of cold and hot fluid patterns and the effects of hot streaks on secondary flows and temperature re-distributions up to the second turbine stage. The hot flow pattern is affected by the fuel composition, resulting in more concentrated thermal wake shapes for syngas when compared to the reference natural gas fuel. In effect, the interaction with the secondary flow leads to more intense flow turning of the pressure side leg of the horseshoe vortex in the first rotor passage. The higher temperature levels in the case of syngas, in combination with the effect of the enhanced secondary flow, result in higher radial spread of the hot fluid that tends to migrate towards the blade hub and tip with the effects being obvious further downstream the first turbine stage.
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Niszczota, Paweł, and Marian Gieras. "Effect of Adding Emulsifier to Fuel on Work Efficiency and Gas Turbine Emissions." Energies 14, no. 17 (August 25, 2021): 5255. http://dx.doi.org/10.3390/en14175255.
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In an effort to reduce the emissivity of transport and energy, numerous studies are being carried out on the impact of the combustion of alternative fuels on the emission and operating parameters of propulsion and energy units. One of the observed trends is the use of emulsion fuels. The addition of an emulsifier to an emulsion fuel reduces the interfacial tension between two liquids, which allows obtaining an emulsion fuel with the expected stability. The research conducted on self-ignition engines and gas turbines (TG) does not give an unambiguous answer as to the influence of the use of fuel-water emulsion on CO emissions. One of the reasons for the discrepancy in the obtained results may be the type and amount of the emulsifier used in the emulsion fuel. Tests were carried out on the GTM-120 gas turbine to compare the operating parameters and emissions between the cases in which TG was supplied with three fuel mixtures—the standard fuel for TG (DF) and DF with 2% and 5% emulsifier addition. It was shown that the addition of 2% of the emulsifier to DF causes an increase in CO emission, with the remaining measured parameters unchanged. On the other hand, increasing the amount of emulsifier in DF to 5% reduces CO emissions to the level observed in the case in which DF was burned reduces NOx emissions and reduces the thermal efficiency of TG.
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Ferreira, Sandro B., and Pericles Pilidis. "Comparison of Externally Fired and Internal Combustion Gas Turbines Using Biomass Fuel." Journal of Energy Resources Technology 123, no. 4 (June 15, 2001): 291–96. http://dx.doi.org/10.1115/1.1413468.
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There is a difference of opinion regarding the relative merits of gas turbines using biomass fuels. Some engineers believe that the internal combustion gas turbine coupled to a gasifier will give a higher efficiency than the externally fired gas turbine using pretreated biomass that is not gasified. Others believe the opposite. In this paper, a comparison between these schemes is made, within the framework of the Brazilian perspective. The exergetic analysis of four cycles is described. The first cycle is externally fired (EFGT), the second uses gasified biomass as fuel (BIG/GT), each of them with a combined cycle as a variant (EFGT/CC and BIG/GTCC). These four are then compared to the natural gas turbine cycles (NGT and NGT/CC) in order to evaluate the thermodynamic cost of using biomass. The comparison is carried out in terms of thermal efficiency and in terms of exergetic efficiency and exergy destruction in the main components. The present analysis shows that the EFGT is quite promising. When compared to the NGT cycle, the EFGT gas turbine shows poor efficiency, though this parameter practically equals that of the BIG/GT cycle. The use of a bottoming steam cycle changes the figures, and the EFGT/CC—due to its higher exhaust temperature—results in high efficiency compared to the BIG/GTCC. Its lower initial and maintenance cost may be an important attraction.
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Rocca, E., P. Steinmetz, and M. Moliere. "Revisiting the Inhibition of Vanadium-Induced Hot Corrosion in Gas Turbines." Journal of Engineering for Gas Turbines and Power 125, no. 3 (July 1, 2003): 664–69. http://dx.doi.org/10.1115/1.1456095.
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Since the 1970s, nothing substantially new has been published in the gas turbine community about the hot corrosion by vanadium and its inhibition, after the “inhibition orthodoxy” based on the formation of magnesium vanadate, was established. However, the experience acquired since the late 1980s with heavy-duty gas turbines burning ash-forming fuels in southern China, shows that the combustion of very contaminated fuels does not entail corrosion nor abundant ash-deposit on gas turbines buckets. Analyses of deposits collected from gas turbines fired with these crude oils showed that the ash-deposit contains a large amount of nickel. These new facts led to revisit the role played by nickel and envisage its possible inhibiting action against the vanadium-induced hot corrosion. A thorough review of the literature on the vanadium-induced corrosion have been carried out, and the study of the nickel effects with respect to magnesium effects on the ash deposit have been performed. Results show that nickel presents an interesting way to substitute magnesium for the inhibition of vanadium-induced hot corrosion. The advantages of nickel with respect to magnesium are to be efficient at alow Ni/V ratio, to produce less abundant, less adherent ash and to act, to some extent, as a self-cleaning agent for the blades of the turbine.
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Do¨bbeling, K., H. P. Kno¨pfel, W. Polifke, D. Winkler, C. Steinbach, and T. Sattelmayer. "Low-Nox Premixed Combustion of MBtu Fuels Using the ABB Double Cone Burner (EV Burner)." Journal of Engineering for Gas Turbines and Power 118, no. 1 (January 1, 1996): 46–53. http://dx.doi.org/10.1115/1.2816548.
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A novel combustion technique, based on the Double Cone Burner, has been developed and tested. NOx emissions down to very low levels are reached without the usual strong dilution of the fuel for MBtu syngases from oxygen-blown gasification of coal or residual oil. A limited amount of dilution is necessary in order to prevent ignition during the mixing of fuel and combustion air. The relevant properties of the fuel are reviewed in relation to the goal of achieving premixed combustion. The basic considerations lead to a fuel injection strategy completely different from that for natural gas. A high-speed premixing system is necessary due to the very short chemical reaction times of MBtu fuel. Fuel must be prevented from forming ignitable mixtures inside the burner for reliability reasons. A suitable fuel injection method, which can be easily added to the ABB double cone burner, is described. In common with the design of the standard EV burner, the MBtu EV burner with this fuel injection method is inherently safe against flashback. Three-dimensional flow field and combustion modeling is used to investigate the mixing patterns and the location of the reaction front. Two burner test facilities, one operating at ambient and the other at full gas turbine pressure, have been used for the evaluation of different burner designs. The full-pressure tests were carried out with the original gas turbine burner size and geometry. Combining the presented numerical predictive capabilities and the experimental test facilities, burner performance can be reliably assessed for a wide range of MBtu and LBtu fuels (residue oil gasification, waste gasification, coal gasification, etc.). The atmospheric tests of the burner show NOx values below 2 ppm at an equivalence ratio equal to full-load gas turbine operation. The NOx increase with pressure was found to be very high. Nevertheless, NOx levels of 25 vppmd (@ 15 percent O2) have been measured at full gas turbine pressure. Implemented into ABB’s recently introduced gas turbine GT13E2, the new combustion technique will allow a more straightforward IGCC plant configuration without air extraction from the gas turbine to be used.
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Mikielewicz, Kosowski, Tucki, Piwowarski, Stępień, Orynycz, and Włodarski. "Gas Turbine Cycle with External Combustion Chamber for Prosumer and Distributed Energy Systems." Energies 12, no. 18 (September 11, 2019): 3501. http://dx.doi.org/10.3390/en12183501.
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The use of various biofuels, usually of relatively small Lower Heating Value (LHV), affects the gas turbine efficiency. The present paper shows that applying the proposed air by-pass system of the combustor at the turbine exit causes tan increase of efficiency of the turbine cycle increased by a few points. This solution appears very promising also in combined gas/steam turbine power plants. The comparison of a turbine set operating according to an open cycle with partial bypassing of external combustion chamber at the turbine exit (a new solution) and, for comparison, a turbine set operating according to an open cycle with a regenerator. The calculations were carried out for different fuels: gas from biomass gasification (LHV = 4.4 MJ/kg), biogas (LHV = 17.5 MJ/kg) and methane (LHV = 50 MJ/kg). It is demonstrated that analyzed solution enables construction of several kW power microturbines that might be used on a local scale. Such turbines, operated by prosumer’s type of organizations may change the efficiency of electricity generation on a country-wide scale evidently contributing to the sustainability of power generation, as well as the economy as a whole.
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Waitz, Ian A., Gautam Gauba, and Yang-Sheng Tzeng. "Combustors for Micro-Gas Turbine Engines." Journal of Fluids Engineering 120, no. 1 (March 1, 1998): 109–17. http://dx.doi.org/10.1115/1.2819633.
Full textAbstract:
The development of a hydrogen-air microcombustor is described. The combustor is intended for use in a 1 mm2 inlet area, micro-gas turbine engine. While the size of the device poses several difficulties, it also provides new and unique opportunities. The combustion concept investigated is based upon introducing hydrogen and premixing it with air upstream of the combustor. The wide flammability limits of hydrogen-air mixtures and the use of refractory ceramics enable combustion at lean conditions, obviating the need for both a combustor dilution zone and combustor wall cooling. The entire combustion process is carried out at temperatures below the limitations set by material properties, resulting in a significant reduction of complexity when compared to larger-scale gas turbine combustors. A feasibility study with initial design analyses is presented, followed by experimental results from 0.13 cm3 silicon carbide and steel microcombustors. The combustors were operated for tens of hours, and produced the requisite heat release for a microengine application over a range of fuel-air ratios, inlet temperatures, and pressures up to four atmospheres. Issues of flame stability, heat transfer, ignition and mixing are addressed. A discussion of requirements for catalytic processes for hydrocarbon fuels is also presented.