Gas Turbine Flexibility With Carbon Constrained Fuels

2008 ◽  
Author(s):  
Klaus Payrhuber ◽  
Robert M. Jones ◽  
Marcus H. Scholz
Keyword(s):  
Energy Conversion ◽  
Gas Turbine ◽  
Synthesis Gas ◽  
Gas Turbines ◽  
Coal Gasification ◽  
Combined Cycle ◽  
Emissions Reduction ◽  
Hydrogen Energy ◽  
Fuel Gas ◽  
High Hydrogen

Over the next several decades, the power generation sector will face major landscape changes as CO2 management needs and hydrocarbon fuel options become limited. Uncontrolled carbon emissions from coal plants exceed natural gas fired alternatives by more than two to one due in large part to greater fuel carbon content and lower overall energy conversion efficiencies. In a carbon-constrained environment, power production from coal must realize improvements beyond incremental efficiency gains in order to have significant CO2 emissions reduction. Coal gasification and associated fuel gas process treatment units provide the mechanisms inherently needed to effectively separate carbon components on a “pre-combustion” basis, leaving essentially carbon free hydrogen fuel available for combustion within the combined cycle power plant. Gas turbines will play a significant role in meeting this generation challenge, not only from a fuel flexibility perspective, but also in the area of CO2 reduction where gas turbines will likely become the primary hydrogen energy conversion unit for the foreseeable future. Worldwide, GE gas turbines continue to demonstrate their proven, reliable performance on hydrogen bearing fuels, including installations with up to 95% hydrogen by volume. As the focus on pre-combustion carbon capture continues to grow, never has this experience with high hydrogen fuels been more relevant. Furthermore, GE continues to develop combustion designs to extend this experience to advanced gas turbine platforms, including F-class units operating on synthesis gas. The ever-present focus on efficiency improvement and emissions reduction, combined with improved gasification processes, will require future advanced combustion system designs that can achieve low emissions at higher firing temperatures with minimal to no dilution for NOx abatement. This paper discusses the challenge of low CO2 producing fuel for advanced gas turbines, firing hydrogen rich synthesis gas, in terms of gas turbine fuel and accessory system design.

scholarly journals Development of a Low-NOx LBG Combustor for Coal Gasification Combined Cycle Power Generation Systems

1989 ◽  
Author(s):  
M. Sato ◽  
T. Abe ◽  
T. Ninomiya ◽  
T. Nakata ◽  
T. Yoshine ◽  
...  
Keyword(s):  
Power Generation ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Coal Gasification ◽  
Combined Cycle ◽  
Generation System ◽  
Combustion Technology ◽  
Power Generation System ◽  
Combustion Tests ◽  
Power Generation Systems

From the view point of future coal utilization technology for the thermal power generation systems, the coal gasification combined cycle system has drawn special interest recently. In the coal gasification combined cycle power generation system, it is necessary to develop a high temperature gas turbine combustor using a low-BTU gas (LBG) which has high thermal efficiency and low emissions. In Japan a development program of the coal gasification combined cycle power generation system has started in 1985 by the national government and Japanese electric companies. In this program, 1300°C class gas turbines will be developed. If the fuel gas cleaning system is a hot type, the coal gaseous fuel to be supplied to gas turbines will contain ammonia. Ammonia will be converted to nitric oxides in the combustion process in gas turbines. Therefore, low fuel-NOx combustion technology will be one of the most important research subjects. This paper describes low fuel-NOx combustion technology for 1300°C class gas turbine combustors using coal gaseous low-BTU fuel as well as combustion characteristics and carbon monoxide emission characteristics. Combustion tests were conducted using a full-scale combustor used for the 150 MW gas turbine at the atmospheric pressure. Furthermore, high pressure combustion tests were conducted using a half-scale combustor used for the 1 50 MW gas turbine.

scholarly journals Conceptual Mean-Line Design of Single and Twin-Shaft Oxy-Fuel Gas Turbine in a Semiclosed Oxy-Fuel Combustion Combined Cycle

2013 ◽  
Vol 135 (8) ◽  
Author(s):  
Majed Sammak ◽  
Egill Thorbergsson ◽  
Tomas Grönstedt ◽  
Magnus Genrup
Keyword(s):  
Mach Number ◽  
Gas Turbine ◽  
Mass Flow ◽  
Rotational Speed ◽  
Gas Turbines ◽  
Combined Cycle ◽  
Fuel Gas ◽  
Power Turbine ◽  
Exit Mach Number ◽  
Line Design

The aim of this study was to compare single- and twin-shaft oxy-fuel gas turbines in a semiclosed oxy-fuel combustion combined cycle (SCOC–CC). This paper discussed the turbomachinery preliminary mean-line design of oxy-fuel compressor and turbine. The conceptual turbine design was performed using the axial through-flow code luax-t, developed at Lund University. A tool for conceptual design of axial compressors developed at Chalmers University was used for the design of the compressor. The modeled SCOC–CC gave a net electrical efficiency of 46% and a net power of 106 MW. The production of 95% pure oxygen and the compression of CO2 reduced the gross efficiency of the SCOC–CC by 10 and 2 percentage points, respectively. The designed oxy-fuel gas turbine had a power of 86 MW. The rotational speed of the single-shaft gas turbine was set to 5200 rpm. The designed turbine had four stages, while the compressor had 18 stages. The turbine exit Mach number was calculated to be 0.6 and the calculated value of AN2 was 40 · 106 rpm2m2. The total calculated cooling mass flow was 25% of the compressor mass flow, or 47 kg/s. The relative tip Mach number of the compressor at the first rotor stage was 1.15. The rotational speed of the twin-shaft gas generator was set to 7200 rpm, while that of the power turbine was set to 4800 rpm. A twin-shaft turbine was designed with five turbine stages to maintain the exit Mach number around 0.5. The twin-shaft turbine required a lower exit Mach number to maintain reasonable diffuser performance. The compressor turbine was designed with two stages while the power turbine had three stages. The study showed that a four-stage twin-shaft turbine produced a high exit Mach number. The calculated value of AN2 was 38 · 106 rpm2m2. The total calculated cooling mass flow was 23% of the compressor mass flow, or 44 kg/s. The compressor was designed with 14 stages. The preliminary design parameters of the turbine and compressor were within established industrial ranges. From the results of this study, it was concluded that both single- and twin-shaft oxy-fuel gas turbines have advantages. The choice of a twin-shaft gas turbine can be motivated by the smaller compressor size and the advantage of greater flexibility in operation, mainly in the off-design mode. However, the advantages of a twin-shaft design must be weighed against the inherent simplicity and low cost of the simple single-shaft design.

Operating Experience With the Latest Upgrade of Alstom’s Sequential Combustion GT26 Gas Turbine

2010 ◽  
Author(s):  
Matthias Hiddeman ◽  
Peter Marx
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Operating Experience ◽  
Business Case ◽  
Combined Cycle ◽  
Fuel Gas ◽  
Power Generators ◽  
Additional Degree ◽  
Performance Improvements ◽  
Main Driver

The GT26 gas turbine provides an additional degree of flexibility as the engine operates at high efficiencies from part load to full load while still maintaining low NOx emissions. The sequential combustion, with the EV burner as the basis for this flexibility also extends to the ability to handle wide fluctuations in fuel gas compositions. Increased mass flow was the main driver for the latest GT26 upgrade, resulting in substantial performance improvements. In order to ensure high levels of reliability and availability Alstom followed their philosophy of evolutionary steps to continuously develop their gas turbines. A total of 47 engines of this upgrade of the GT26 gas turbine have been ordered worldwide to date (Status: January 2010) enhancing the business case of power generators by delivering superior operational and fuel flexibility and combined cycle efficiencies up to and beyond 59%.

System Evaluation and LBTU Fuel Combustion Studies for IGCC Power Generation

1995 ◽  
Vol 117 (4) ◽  
pp. 673-677 ◽  
Author(s):  
C. S. Cook ◽  
J. C. Corman ◽  
D. M. Todd
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Coal Gasification ◽  
Flame Temperature ◽  
Combined Cycle ◽  
Gas Turbine Combustor ◽  
Gas Cleaning ◽  
Wide Range ◽  
Cycle Systems ◽  
Combined Cycles

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.

scholarly journals Analysis of operation of the gas turbine in a poligeneration combined cycle

2013 ◽  
Vol 34 (4) ◽  
pp. 137-159 ◽  
Author(s):  
Łukasz Bartela ◽  
Janusz Kotowicz
Keyword(s):  
Gas Turbine ◽  
Synthesis Gas ◽  
Combined Cycle ◽  
Air Separation ◽  
Electricity Production ◽  
Chemical Production ◽  
Integrated Gasification Combined Cycle ◽  
Fuel Gas ◽  
Separation Unit ◽  
Cooling Air

Abstract In the paper the results of analysis of an integrated gasification combined cycle IGCC polygeneration system, of which the task is to produce both electricity and synthesis gas, are shown. Assuming the structure of the system and the power rating of a combined cycle, the consumption of the synthesis gas for chemical production makes it necessary to supplement the lack of synthesis gas used for electricity production with the natural gas. As a result a change of the composition of the fuel gas supplied to the gas turbine occurs. In the paper the influence of the change of gas composition on the gas turbine characteristics is shown. In the calculations of the gas turbine the own computational algorithm was used. During the study the influence of the change of composition of gaseous fuel on the characteristic quantities was examined. The calculations were realized for different cases of cooling of the gas turbine expander’s blades (constant cooling air mass flow, constant cooling air index, constant temperature of blade material). Subsequently, the influence of the degree of integration of the gas turbine with the air separation unit on the main characteristics was analyzed.

Recent Experimental Results on Gasification and Combustion of Low BTU Gas for Gas Turbines

1974 ◽  
Author(s):  
W. B. Crouch ◽  
W. G. Schlinger ◽  
R. D. Klapatch ◽  
G. E. Vitti
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Electrical Power ◽  
Combined Cycle ◽  
Experimental Results ◽  
Fuel Oil ◽  
Cooperative Research ◽  
Fuel Gas ◽  
Gasification Process ◽  
Cycle System

A proposed system is presented for low pollution power generation by means of a combined cycle gas turbine system using low Btu fuel gas produced from high sulfur residual oil and solid fuel. Experimental results and conclusions are presented from a cooperative research program involving Texaco Inc. and Turbo Power and Marine Systems, Inc. whereby high sulfur crude oil residue was partially oxidized with air to produce a 100 to 150 Btu/scf sulfur-free fuel gas for use in a turbine combustor. An FT4 gas turbine combustion chamber test demonstrated that low Btu gas can be efficiently burned with a large reduction in NOx emissions. Gas turbine modifications required to burn low Btu gas are described and projected NOx emission compared to No. 2 fuel oil and natural gas are shown for an FT4 gas turbine. Integration of the gas turbine combined cycle system to a low Btu gasification process is described. The system provides an efficient method of generating electrical power from high sulfur liquid fuels while minimizing emission of air and water pollutants.

scholarly journals Thermodynamic Analysis of Advanced Gas Turbine Combined Cycle Integration with a High-Temperature Nuclear Reactor and Cogeneration Unit

Energies ◽  
2020 ◽  
Vol 13 (2) ◽  
pp. 400 ◽  
Author(s):  
Marek Jaszczur ◽  
Michał Dudek ◽  
Zygmunt Kolenda
Keyword(s):  
High Temperature ◽  
Energy Conversion ◽  
Gas Turbine ◽  
Coal Gasification ◽  
Nuclear Reactor ◽  
Electrical Energy ◽  
Combined Cycle ◽  
Point Of View ◽  
Hard Coal ◽  
The Eu

The EU has implemented targets to achieve a 20% share of energy from renewable sources by 2020, and 32% by 2030. Additionally, in the EU countries by 2050, more than 80% of electrical energy should be generated using non-greenhouse gases emission technology. At the same time, energy cost remains a crucial economic issue. From a practical point of view, the most effective technology for energy conversion is based on a gas turbine combined cycle. This technology uses natural gas, crude oil or coal gasification product but in any case, generates a significant amount of toxic gases to the atmosphere. In this study, the environmentally friendly power generation system composed of a high-temperature nuclear reactor HTR integrated with gas turbine combined cycle technology and cogeneration unit is thermodynamically analysed. The proposed solution is one of the most efficient ways for energy conversion, and what is also important it can be easily integrated with HTR. The results of analysis show that it is possible to obtain for analysed cycles thermal efficiency higher than 50% which is not only much more than could be proposed by typical lignite or hard coal power plant but is also more than can be offered by nuclear technology.

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

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

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

Design and Performance of Low Heating Value Fuel Gas Turbine Combustors

1996 ◽  
Author(s):  
Robert A. Battista ◽  
Alan S. Feitelberg ◽  
Michael A. Lacey
Keyword(s):  
Gas Turbine ◽  
Coal Gasification ◽  
Combined Cycle ◽  
Flame Stability ◽  
Load Range ◽  
Fuel Gas ◽  
Heating Value ◽  
Gas Turbine Combustors ◽  
Fuel Nozzle ◽  
Combustor Liner

General Electric Company is developing and testing low heating value fuel gas turbine combustors for use in integrated gasification combined cycle power generation systems. This paper presents the results of a series of combustion tests conducted at the pilot scale coal gasification and high temperature desulfurization system located at GE Corporate Research and Development in Schenectady, New York. Tests were performed in a modified GE MS6000 combustor liner operating at a pressure of 10 bar and over a wide load range (combustor exit temperatures from 760 to 1400°C). The primary objective of these tests was to compare and contrast the performance (emissions, flame stability, and combustor liner temperatures) of six different low heating value fuel nozzle designs, representing three distinct nozzle concepts. With 2200 to 4600 ppmv NH3 in the fuel, the conversion of fuel NH3 to NOx was roughly independent of fuel nozzle type, and ranged from about 70% at low combustor exit temperatures to about 20% at high combustor exit temperatures. For all of the fuel nozzles, CO emissions were typically less than 5 ppmv (on a dry, 15% O2 basis) at combustor exit temperatures greater than 980°C. Significant differences in CO emissions were observed at lower combustor exit temperatures. Some differences in liner temperatures and flame stability were also observed with the different nozzles. In general, nozzles which produced lower CO emissions and greater flame stability had higher fuel swirl angles and resulted in higher combustor liner temperatures. The nozzle with the best overall performance (consisting of concentric axial air and fuel swirlers and an air cooled mixing cup) has been selected for use at a commercial site.

FlameSheet™ Combustor Engine and Rig Validation for Operational and Fuel Flexibility With Low Emissions

2016 ◽  
Author(s):  
Peter Stuttaford ◽  
Hany Rizkalla ◽  
Khalid Oumejjoud ◽  
Nicolas Demougeot ◽  
Justin Bosnoian ◽  
...  
Keyword(s):  
Gas Turbine ◽  
Gas Turbines ◽  
Combined Cycle ◽  
Heavy Duty ◽  
Load Range ◽  
Fuel Gas ◽  
Combustion Dynamics ◽  
Operational Profile ◽  
Fuel Flexibility ◽  
The Future

Flexibility is key to the future success of natural gas fired power generation. As renewable energy becomes more widely used, the need for reliable, flexible generation will increase. As such, gas turbines capable of operating efficiently and in emissions compliance from extended low load to full load will have a significant advantage. A wider range of gas fuels, including shale gas and refinery/industrial byproduct gas, is becoming increasingly available, with the opportunity to further reduce the cost of electricity. A combustion system capable of operating with wider ranges of heavy hydrocarbons, hydrogen and inerts will have an advantage to accommodate the future fuel gas trends and provide value to gas turbine operators. The FlameSheet™ combustor incorporates a novel dual zone burn system to address operational and fuel flexibility. It provides low emissions, extended turndown and fuel flexibility. FlameSheetTM is simply retrofittable into existing installed E/F-class heavy duty gas turbines and is designed to meet the energy market drivers set forth above. The operating principle of the new combustor is described, and details of a full scale high pressure rig test and engine validation program are discussed, providing insight on rig and engine emissions, as well as combustion dynamics performance. The FlameSheetTM implementation and validation results on a General Electric 7FA heavy duty gas turbine operating in a combined cycle power plant is discussed with emphasis on operational profile optimization to accommodate the heat recovery steam generator (HRSG), while substantially increasing the gas turbine normal operating load range.

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