Fundamental Impact of Firing Syngas in Gas Turbines

2007 ◽  
Author(s):  
Emmanuel O. Oluyede ◽  
Jeffrey N. Phillips
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Hydrogen Content ◽  
Firing Temperature ◽  
Power Output ◽  
Gas Turbines ◽  
Combustion Products ◽  
Metal Temperature ◽  
Turbine Component ◽  
The Impact

This paper addresses the impact of burning syngas in a large size, heavy-duty gas turbine designed to run on natural gas while maintaining hot section life. The process used to produce syngas is not discussed here; we mainly focus on analyzing the issues related to switching from natural gas to syngas on the gas turbine hot sections and the possibility of reducing the firing temperature in order to maintain the durability of the hot metal section life. The analysis indicate that the power output for a syngas-fired turbine plant could be increased as much as 20–25% when compared with the same turbine fired at the same metal temperature as the natural gas, however this increase in power output is also accompanied by an increase in the moisture content of the combustion products due largely to higher hydrogen content in the syngas and the increased turbine flow which contribute significantly to the overheating of turbine component parts. Correlations based on the hydrogen content as well as the lower heating value of the fuels were obtained in order to determine specific firing temperature reduction necessary to obtain durable metal temperature.

Effect of Variation of Fuel Composition on Gas Turbine Off-Design Performance

2014 ◽  
Vol 666 ◽  
pp. 194-198 ◽  
Author(s):  
Ye Suel Park ◽  
Saemi Park ◽  
Joong Seong Lee ◽  
Gyung Min Choi
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Turbine Blade ◽  
Power Output ◽  
Metal Temperature ◽  
Fuel Composition ◽  
Heating Value ◽  
Control Scheme ◽  
Control Schemes ◽  
Gas Fuel

The effects of fuel composition is investigated in a gas turbine for natural gas. Fuel composition is divided H/C ratio and heating value. There are three control schemes for gas turbine. In this study, TIT control and TET control is adopted. A full off-design analysis of the gas turbine was performed. Performance characteristics and maximum turbine blade temperature are the main interests. The power output is decreased while heating value of fuel is increased and H/C ratio of fuel is decreased both control scheme. As heating value of natural gas decreased and H/C ratio of fuel increased, turbine blade temperature is increased in TIT control. Otherwise, Blade metal temperature is little influenced by H/C ratio of fuel in TET control scheme.

Augmentation of Gas Turbine Power Output by Steam Injection

2001 ◽  
Author(s):  
August C. Fischer ◽  
Hans Ulrich Frutschi ◽  
Hermann Haselbacher
Keyword(s):  
Gas Turbine ◽  
Mass Flow ◽  
Power Output ◽  
Thermal Efficiency ◽  
Gas Turbines ◽  
Steam Injection ◽  
Simultaneous Increase ◽  
Exhaust Heat ◽  
Entire Amount ◽  
The Impact

Steam injection into the combustion chambers of gas turbines (GT) increases their power output. Additionally, the thermal efficiency can be raised, if steam is generated by exhaust heat. The types of steam injected gas turbines (STIG) are distinguished according to the kind of limit to the amount of steam that can be injected. A gas turbine is called partial STIG, if it cannot utilize the total amount of steam that could be generated by the gas turbine exhaust heat. The limit is given by the flow capacity of the turbine. If, on the other hand, the gas turbine is sized such that the entire amount of steam producible can be utilized, it is called full STIG. Three different partial STIG cooling models were selected to analyze the power output, the efficiency and the impact on two important components. Since the differences in the results for the three cycles are marginal, the following conclusion can be briefly summarized: Compressor surge turned out to be the strongest limit for overloading the gas turbine. At the point of maximum overload — where safe operation is still guaranteed — the steam mass flow amounts to one tenth of the nominal compressor air mass flow. At this operating point, the power output can be raised by more than 30% with a simultaneous increase in efficiency. Based on the gas turbine configurations used for the partial STIGs, the preliminary designs of two full STIG cycles have been developed. However, for full STIG operation by injection of the total amount of steam producible, either the compressor or the turbines of the original gas turbine have to be modified. In this case, the steam flow exceeding that required for cooling has to be injected into the compressed air in front of the combustor. Depending on whether the compressor is scaled down or the turbines are scaled up, the power output of full STIGs is 30 to 135% higher than that of the original gas turbine. The gross thermal efficiency is about 50.5.%.

Effect of Hydrogen Content on the Gas Turbine Combustion Performance of Synthetic Natural Gas

2013 ◽  
Author(s):  
Min Chul Lee ◽  
Seik Park ◽  
Uisik Kim ◽  
Sungchul Kim ◽  
Jisu Yoon ◽  
...  
Keyword(s):  
Natural Gas ◽  
Heat Release ◽  
Gas Turbine ◽  
Hydrogen Content ◽  
Gas Turbines ◽  
Combustion Instabilities ◽  
Synthetic Natural Gas ◽  
Natural Gases ◽  
Combustion Performance ◽  
Gas Turbine Combustion

This paper investigates the effect of hydrogen content on the gas turbine combustion performance of synthetic natural gases to determine whether they are adaptable to industrial gas turbines. Synthetic natural gases which are composed of methane, propane and varying amounts of hydrogen (0%, 1%, 3% and 5%), are tested in ambient pressure and high temperature conditions at the combustion test facility of a 60kWth industrial gas turbine. Combustion instabilities, flame structures, temperatures at nozzle, dump plane and turbine inlet, and emissions of NOx and CO are investigated for the power outputs from 35 to 60kWth. With increasing hydrogen content, combustion instabilities are slightly alleviated and the frequency of pressure fluctuation and heat release oscillation is increased. NOx and CO emissions are almost similar in trends and amounts for all tested fuels, and the undesirable phenomena from addition of hydrogen such as flashback, auto-ignition and overheating of fuel nozzle were not observed. Synthetic natural gas with less than 1% hydrogen showed no difference in gas turbine combustion characteristics, while synthetic natural gases containing hydrogen of over 3% showed a slight difference in combustion instability such as amplitude and frequency of pressure fluctuations and heat release oscillations. From these results, we conclude that the synthetic natural gas containing less than 1% hydrogen is adaptable without retrofitting any part of the combustor, and Korea coal-SNG Quality Standard Bureau is planning to establish the SNG quality standards, guaranteeing hydrogen content of up to 1%.

scholarly journals The Use of Air Turbine Heat Recovery Units for the Mod-ernization of Gas Pumping Units with Gas Turbine Drive

2019 ◽  
pp. 47-58 ◽  
Author(s):  
E.A. Manushin ◽  
A.I. Melnikov
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Heat Recovery ◽  
Significant Proportion ◽  
Combustion Products ◽  
Air Turbine ◽  
Gas Pumping ◽  
Pumping Units ◽  
Regenerative Cycle

One of the urgent tasks of further developing natural gas transportation systems is the need to increase fuel efficiency and to improve environmental performance of the gas turbine units (GTU) that are used to drive superchargers of gas pumping units. Outdated GTUs with low efficiency are being replaced by units of a new generation, including those of the regenerative cycle. However, this requires significant capital expenditures, thus, the possibilities of upgrading the existing units are also being investigated. A significant proportion of the energy generated by the gas combusted in driven GTUs is lost in the form of heat of the exhaust combustion products. These gases have a temperature not lower than 670 K. To utilize the heat of the exhaust combustion products, it is proposed to compliment the main GTU by an air turbine heat recovery unit (ATU) that is simple in design and inexpensive in production. This well-known idea has not yet been realized in practice, thus there are no recommendations on the use of a GTU-ATU as a drive for natural gas superchargers. It is shown that to ensure the possibility of upgrading drive gas turbines at a minimum cost, it is advisable to use an ATU that is kinematically independent of the GTU. The ATU’s power is used to cover the own needs of the compressor station and other purposes. The calculations show that under equal conditions, the combined GTU-ATU is inferior in efficiency to the GTU of the regenerative cycle. However, it provides a much smoother flow of the efficiency parameter depending on the operation mode, which is important for gas pumping units. The potential of using the ATU for the modernization of drive GTUs is estimated. It is noted that in addition to generating additional power, the use of ATU’s can decrease the flue gas temperature and the mass concentration of harmful emissions.

Decarbonizing Power Generation Through the Use of Hydrogen As a Gas Turbine Fuel

2019 ◽  
Author(s):  
Michael Welch
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Carbon Content ◽  
Gas Turbine ◽  
Co2 Emissions ◽  
Gas Turbines ◽  
High Hydrogen ◽  
Wide Range ◽  
Zero Carbon ◽  
The Impact

Abstract The power generation industry has a major role to play in reducing global greenhouse gas emissions, and carbon dioxide (CO2) in particular. There are two ways to reduce CO2 emissions from power generation: improved conversion efficiency of fuel into electrical energy, and switching to lower carbon content fuels. Gas turbine generator sets, whether in open cycle, combined cycle or cogeneration configuration, offer some of the highest efficiencies possible across a wide range of power outputs. With natural gas, the fossil fuel with the lowest carbon content, as the primary fuel, they produce among the lowest CO2 emissions per kWh generated. It is possible though to decarbonize power generation further by using the fuel flexibility of the gas turbine to fully or partially displace natural gas used with hydrogen. As hydrogen is a zero carbon fuel, it offers the opportunity for gas turbines to produce zero carbon electricity. As an energy carrier, hydrogen is an ideal candidate for long-term or seasonal storage of renewable energy, while the gas turbine is an enabler for a zero carbon power generation economy. Hydrogen, while the most abundant element in the Universe, does not exist in its elemental state in nature, and producing hydrogen is an energy-intensive process. This paper looks at the different methods by which hydrogen can be produced, the impact on CO2 emissions from power generation by using pure hydrogen or hydrogen/natural gas blends, and how the economics of power generation using hydrogen compare with today’s state of the art technologies and carbon capture. This paper also addresses the issues surrounding the combustion of hydrogen in gas turbines, historical experience of gas turbines operating on high hydrogen fuels, and examines future developments to optimize combustion emissions.

Simulation of Producer Gas Fired Power Plants With Inlet Fog Cooling and Steam Injection

2006 ◽  
Author(s):  
Mun Roy Yap ◽  
Ting Wang
Keyword(s):  
Natural Gas ◽  
Steam Turbine ◽  
Gas Turbine ◽  
Power Output ◽  
Gas Turbines ◽  
Power Plants ◽  
Steam Injection ◽  
Combined Cycle ◽  
Producer Gas ◽  
Cycle Systems

Biomass can be converted to energy via direct combustion or thermo-chemical 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 low calorific values (LCV), the power plants 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 (STIG) 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 back compressor pressure and produces increased power output due to increased fuel flow. Turbine nozzle throat area is adjusted to accommodate additional fuel flows to allow compressor operate within safety margin. The best performance occurs when the designed pressure ratio is maintained by widening nozzle openings, even though the TIT 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.

First Assessment of Biogas Co-Firing on the GE MS9001FA Gas Turbine Using CFD

2003 ◽  
Author(s):  
J. A. Lycklama a` Nijeholt ◽  
E. M. J. Komen ◽  
A. J. L. Verhage ◽  
M. C. van Beek
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Combustion Process ◽  
Geometrical Model ◽  
Electricity Production ◽  
Power Station ◽  
Complete Combustion ◽  
Air Mixing ◽  
The Impact

Replacement of fossil fuel by biomass-derived fuel is currently under study in the Netherlands within the context of CO2 -neutral electricity production. In view of this, co-firing biogas in the natural-gas fired Eems gas turbine power plant is being considered. This would entail extension of the power station with a biomass gasification plant for the production of biogas. The main unit of the Electrabel Eemshaven Power Station consists of five GE MS9001FA-gas turbines. A target is to replace up to 13% of natural gas consumption by biogas. The objective of the current project was to determine the impact of co-firing on the flame behavior. Therefore various options for biogas co-firing using combinations of pilot and premix burners have been studied. Computational Fluid Dynamics (CFD) simulations of the combustion process using a geometrical model of the complete combustion chamber have been performed. The flow conditions at the premix burner outlets were determined with a separate, detailed CFD model of the burner, simulating the fuel-air mixing with the required high accuracy. Advanced combustion modeling with help of the detailed GRI 3.0-reaction mechanism was used, as well as simpler models for fast chemical kinetics. A method was devised for calibrating the applied combustion models. Various firing strategies involving the premix and pilot burners were analyzed. Safe ranges for biogas co-firing have been determined in this first feasibility study.

scholarly journals Comprehensive Thermodynamic Analysis of the Humphrey Cycle for Gas Turbines with Pressure Gain Combustion

Energies ◽  
2018 ◽  
Vol 11 (12) ◽  
pp. 3521 ◽  
Author(s):  
Panagiotis Stathopoulos
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Combustion Process ◽  
Ideal Gas ◽  
Point Of View ◽  
Pressure Gain Combustion ◽  
Combustion Technology ◽  
Secondary Air ◽  
And Performance ◽  
The Impact

Conventional gas turbines are approaching their efficiency limits and performance gains are becoming increasingly difficult to achieve. Pressure Gain Combustion (PGC) has emerged as a very promising technology in this respect, due to the higher thermal efficiency of the respective ideal gas turbine thermodynamic cycles. Up to date, only very simplified models of open cycle gas turbines with pressure gain combustion have been considered. However, the integration of a fundamentally different combustion technology will be inherently connected with additional losses. Entropy generation in the combustion process, combustor inlet pressure loss (a central issue for pressure gain combustors), and the impact of PGC on the secondary air system (especially blade cooling) are all very important parameters that have been neglected. The current work uses the Humphrey cycle in an attempt to address all these issues in order to provide gas turbine component designers with benchmark efficiency values for individual components of gas turbines with PGC. The analysis concludes with some recommendations for the best strategy to integrate turbine expanders with PGC combustors. This is done from a purely thermodynamic point of view, again with the goal to deliver design benchmark values for a more realistic interpretation of the cycle.

Comparison Between Two-Shaft Simple and Single-Shaft Recuperated Brayton Cycles Using Different Types of Gaseous Fuels

2010 ◽  
Author(s):  
A. K. Malkogianni ◽  
A. Tourlidakis ◽  
A. L. Polyzakis
Keyword(s):  
Natural Gas ◽  
Gas Turbines ◽  
Alternative Fuels ◽  
High Efficiency ◽  
Heating Value ◽  
Gaseous Fuels ◽  
Oil And Natural Gas ◽  
Parametric Studies ◽  
The Impact ◽  
Lower Heating

Geopolitical issues give rise to problems in the smooth and continuous flow of oil and natural gas from the production countries to the consumers’ development countries. In addition, severe environmental issues such as greenhouse gas emissions, eventually guide the consumers to fuels more suitable to the present situation. Alternative fuels such as biogas and coal gas have recently become more attractive because of their benefits, especially for electricity generation. On the other hand, the use of relatively low heating value fuels has a significant effect to the performance parameters of gas turbines. In this paper, the impact of using four fuels with different heating value in the gas turbine performance is simulated. Based on the high efficiency and commercialization criteria, two types of engines are chosen to be simulated: two-shaft simple and single-shaft recuperated cycle gas turbines. The heating values of the four gases investigated, correspond to natural gas and to a series of three gases with gradually lower heating values than that of natural gas. The main conclusions drawn from this design point (DP) and off-design (OD) analysis is that, for a given TET, efficiency increases for both engines when gases with low heating value are used. On the contrary, when power output is kept constant, the use of gases with low heating value will result in a decrease of thermal efficiency. A number of parametric studies are carried out and the effect of operating parameters on performance is assessed. The analysis is performed with customized software, which has been developed for this purpose.

Fuel Flexibility Influences on Premixed Combustor Blowout, Flashback, Autoignition and Instability

2006 ◽  
Author(s):  
Tim Lieuwen ◽  
Vince McDonell ◽  
Eric Petersen ◽  
Domenic Santavicca
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Dynamic Stability ◽  
Current Understanding ◽  
Fuel Composition ◽  
Fuel Flexibility ◽  
Lean Premixed ◽  
Gas Fuel ◽  
The Impact ◽  
Underlying Processes

This paper addresses the impact of fuel composition on the operability of lean premixed gas turbine combustors. This is an issue of current importance due to variability in the composition of natural gas fuel supplies and interest in the use of syngas fuels. Of particular concern is the effect of fuel composition on combustor blowout, flashback, dynamic stability, and autoignition. This paper reviews available results and current understanding of the effects of fuel composition on the operability of lean premixed combustors. It summarizes the underlying processes that must be considered when evaluating how a given combustor’s operability will be affected as fuel composition is varied.

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