Dual Fuel Application of SCR for Gas Turbines: LES Salt Valley

2003 ◽  
Author(s):  
John T. Langaker ◽  
Byron Bakenhus
Keyword(s):  
Gas Turbines ◽  
Kansas City ◽  
Catalytic Reduction ◽  
Combined Cycle ◽  
Fuel Oil ◽  
Field Site ◽  
Power Utility ◽  
Public Power ◽  
Electric System ◽  
The Public

Lincoln Electric System, the public power utility of Lincoln, Nebraska, will complete a multiple LM6000 gas turbine station project at the end of 2003 that features Selective Catalytic Reduction (SCR) for both combined cycle as well as simple cycle. Furthermore, the facility will be capable of meeting ultra low emissions levels of nitrogen oxides when firing both natural gas and Number 2 fuel oil. This discussion explores the selection and implementation of these emission control systems from procurement through first fire. Burns and McDonnell, of Kansas City, Missouri, led the design effort of this green field site and co-authors with members of the utility.

Combined Cycle Plants With Frame 9F Gas Turbines

1991 ◽  
Vol 113 (4) ◽  
pp. 475-481 ◽  
Author(s):  
P. Lugand ◽  
C. Parietti
Keyword(s):  
Power Generation ◽  
Flue Gas ◽  
Gas Turbines ◽  
Heat Recovery ◽  
Catalytic Reduction ◽  
Pressure Level ◽  
Combined Cycle ◽  
Size Factor ◽  
Nox Emissions ◽  
Steam Generators

The new 200 MW class MS 9001F gas turbines allow combined cycle plants to reach even higher output levels and greater efficiency ratings. Size factor and higher firing temperatures, with a three-pressure level steam reheat cycle, offer plant efficiencies in excess of 53 percent. Heat recovery steam generators have been designed to accommodate catalytic reduction elements limiting flue gas NOx emissions to as low as 10 ppm VD (15 percent O2). A range of steam turbine models covers the different possible configurations. Various arrangements based on the 350 or 650 MW power generation modules can be optimally configured to the requirements of each site.

Daesan Combined Cycle Power Plant: Successful Operating Experience on Low Sulphur Waxy Residual Fuel Oil

2001 ◽  
Author(s):  
Koen-Woo Lee ◽  
Hwan-Doo Kim ◽  
Sung-Il Wi ◽  
Jean-Pierre Stalder
Keyword(s):  
Power Plant ◽  
Gas Turbines ◽  
Capital Expenditure ◽  
Operating Experience ◽  
Combined Cycle ◽  
Fuel Oil ◽  
Heat Recovery Boiler ◽  
Particulate Emissions ◽  
Combined Cycle Power Plant ◽  
Residual Fuel Oil

This paper presents and discusses the successful operating experience and the issues related to burning low sulphur waxy residual (LSWR) fuel oil at the 507 MW IPP Daesan Combined Cycle Power Plant. The power plant was built and is operated by Hyundai Heavy Industries (HHI). It comprises four Siemens-Westinghouse 501D5 engines, each with a heat recovery boiler including supplementary firing and one steam turbine. This plant, commissioned in 1997, is designed to burn LSWR fuel oil. LSWR fuel oil was selected because of the lower fuel cost as compared to LNG and other liquid fuels available in Korea. By adding a combustion improver to the LSWR fuel oil it is possible for HHI to comply with the tight Korean environmental regulations, despite the tendency for heavy smoke and particulate emissions when burning this type of fuel oil. The successful operating experience, availability, reliability and performance achieved in Daesan, as well as the commercial viability (which by far offsets the additional capital expenditure and the additional related O&M costs) demonstrate that LSWR fuel oil firing in heavy duty gas turbines is rewarding. This is especially important in view of the growing disposal problems of residuals at refineries around the world.

Ultra Low Emissions Combustion and Control Systems: Installation Into Mature Power Plant Gas Turbines

2010 ◽  
Author(s):  
Jeffrey A. Benoit ◽  
Charles Ellis ◽  
Joseph Cook
Keyword(s):  
Power Plant ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Life Cycle Cost ◽  
Catalytic Reduction ◽  
Exhaust System ◽  
Combined Cycle ◽  
Combustion Systems ◽  
Regulatory Mandates ◽  
Technical Discussion

The search for power plant sustainability options continues as regulating agencies exert more stringent industrial gas turbine emission requirements on operators. Purchasing power for resale, de-comissioning current capabilities altogether and repowering by replacing or converting existing equipment to comply with emissions standards are economic-driven options contemplated by many mature gas turbine operators. One Las Vegas Nevada, USA operator, NV Energy, with four (4) natural gas fired W501B6 Combined Cycle units at their Edward W. Clark Generating Station, was in this situation in 2006. The units, originally configured with diffusion flame combustion systems, were permitted at 103 ppm NOx with regulatory mandates to significantly reduce NOx emissions to below 5ppm by the end of 2009. Studies were conducted by the operator to evaluate the economic viability of using a Selective Catalytic Reduction (SCR) system, which would have forced significant modifications to the exhaust system and heat recovery steam generator (HRSG), or convert the turbines to operate with dry low-emissions combustion systems. Based on life cycle cost and installation complexity, the ultra-low emission combustion system was selected. This technical paper focuses on a short summary of the end user considerations in downselecting options, the ultra low emissions technology and key features employed to achieve these low emissions, an overview of the conversion scope and a review and description of the control technology employed. Finally, a technical discussion of the low emissions operational flexibility will be provided including performance results of the converted units.

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 The Public Power Issue in Charlottetown: An Early Conflict

2013 ◽  
Vol 10 (3) ◽  
pp. 55-56 ◽  
Author(s):  
Harry T. Holman
Keyword(s):  
Electric Power ◽  
Power Utility ◽  
Public Power ◽  
The Public ◽  
Power Company ◽  
Municipal Ownership ◽  
The City

An electric-power utility was first established in Charlottetown in 1885, but less than fifteen years later the question of its municipalization was being considered. High rates and poor service brought the issue to a head in 1904, and the following year the citizens voted heavily in favour of public power when the question was submitted to them in a plebiscite. Civic politicians proved to be more interested in lower rates than in municipal ownership, however, and when the power company, under duress, promised better but cheaper service, the idea of direct ownership of the utility by the city was quickly forgotten.

scholarly journals Combined Cycle Plants With Frame 9F Gas Turbines

1990 ◽  
Author(s):  
P. Lugand ◽  
C. Parietti
Keyword(s):  
Power Generation ◽  
Flue Gas ◽  
Gas Turbines ◽  
Heat Recovery ◽  
Catalytic Reduction ◽  
Pressure Level ◽  
Combined Cycle ◽  
Size Factor ◽  
Nox Emissions ◽  
Steam Generators

The new 200 MW-class MS 9001F gas turbines allow combined cycle plants to reach even higher output levels and greater efficiency ratings. Size factor and higher firing temperatures, with a 3-pressure level steam reheat cycle, offer plant efficiencies in excess of 53 %. Heat recovery steam generators have been designed to accommodate catalytic reduction elements limiting flue gas NOx emissions to as low as 10 ppm VD (15 % O2). A range of steam turbine models covers the different possible configurations. Various arrangements based on the 350 or 650 MW power generation modules can be optimally configured to the requirements of each site.

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

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

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

Improvement of Selective Catalytic Reduction System Performance in Combined Cycle Power Plants

2003 ◽  
Author(s):  
Anatoly Sobolevskiy ◽  
Tom Czapleski ◽  
Richard Murray
Keyword(s):  
Selective Catalytic Reduction ◽  
Mass Flow ◽  
System Performance ◽  
Gas Turbines ◽  
Power Plants ◽  
Catalytic Reduction ◽  
Active Material ◽  
Combined Cycle ◽  
Nox Emissions ◽  
Scr System

Environmental regulations are very stringent in the U.S., requiring very low emissions of nitrogen oxides (NOx) from combined cycle power plants. Selective Catalytic Reduction (SCR) systems utilizing vanadium pentoxide (V2O5) as the active material in the catalyst are a proven method of reducing NOx emissions in the exhaust stack of gas turbines with heat recovery steam generators (HRSG) to 2–4 ppmvd. These low NOx emissions levels require an increase of SCR removal efficiency to the level of 90+ % with limited ammonia slip. The distribution of flow velocities, temperature, and NOx mass flow at the inlet of the SCR are critical to minimizing NOx and ammonia (NH3) concentrations in HRSG stack. The short distance between the ammonia injection grid and the catalyst in the HRSG complicates the achievement of homogeneous NH3 and NOx mixture. To better understand the influence of the above factors on overall SCR system performance, field testing of combined cycle power plants with an SCR installed in the HRSG has been conducted. Uniformity of exhaust flow, temperature and NOx emissions upstream and downstream of the SCR were examined and the results served as a basis for SCR system tuning in order to increase its efficiency. NOx mass flow profiles upstream and downstream of the SCR were used to assess ammonia distribution enhancement. Ammonia flow adjustments within a cross section of the exhaust gas duct yielded significantly improved NOx mass flow uniformity after the SCR while reducing ammonia consumption. Based on field experience, a procedure for ammonia distribution grid tuning was developed and recommendations for SCR performance improvement were generated.

A Review of the Experience Achieved at the Yugadanavi 300 MW CCGT in Sri Lanka: Increasing the Firing Temperature of Gas Turbines Using a Novel Vanadium Inhibitor

2017 ◽  
Author(s):  
Nuhuman Marikkar ◽  
Tharindu Jayath ◽  
Kithsiri Egodawatta ◽  
Matthieu Vierling ◽  
Maher Aboujaib ◽  
...  
Keyword(s):  
Sri Lanka ◽  
Firing Temperature ◽  
Gas Turbines ◽  
Combined Cycle ◽  
Fuel Oil ◽  
Specific Situation ◽  
Successful Operation ◽  
Heavy Fuel Oil ◽  
Joint Paper ◽  
Fast Development

In regions developing rapidly but deprived of natural gas, gas turbines (GT) in combined cycles (CC) fired on Heavy Fuel Oil (HFO) can represent effective and environmentally viable power generation options. The 300 MW Yugadanavi plant in Sri Lanka, which features two 9E GTs burning low-sulfur HFO, best exemplifies this specific situation. This project was fast-tracked in 2006, when the country started its fast development and the national grid needed fast power additions and frequency stability. Since 2008, it has been supplying 200 MWe to the Ceylonese grid, in simple cycle. Then in 2010, its capacity rose up to 300 MWe without any extra fuel consumption, after its conversion to a combined cycle. In November 2016, Yugadanavi has completed 55,000 hours of successful operation, has generated 6,000 TWh and burned 1 million tons of HFO achieving on average efficiency and reliability performances as high as 44% and 96% respectively. Starting 2010, LTL and GE joined their efforts in plant upgrade initiatives. In 2014 they demonstrated an efficient method to reduce the smoke emissions, using benign combustion catalysts. Within a next upgrade step, a new vanadium inhibition technology has been field-tested in 2015–2016, which enables improving the availability and energy performances of the plant by namely increasing the firing temperature of the gas turbines. After recalling the key milestones of this significant HFO project, the joint paper will outline the operation experience and positive environmental outcomes of the developments carried out within an LTL-GE collaboration, with a special emphasis on the most recent results obtained with the new inhibition technology.

Fuel Switchover at High Load, Integration Into an Engine Operation Concept

2014 ◽  
Author(s):  
Susanne Schell ◽  
Ghislain Singla
Keyword(s):  
Power Output ◽  
Gas Turbines ◽  
High Load ◽  
Combined Cycle ◽  
Fuel Oil ◽  
Load Range ◽  
Engine Operation ◽  
Fuel Gas ◽  
Standard Operation ◽  
Secondary Fuel

The capability to switch online from a main to a back-up fuel is a necessity for dual fuel gas turbines. The switching procedure is itself challenging; fuel gas, fuel oil and supporting systems need to be operated in parallel, with the safe start-up and shut-down of each system having to be ensured. Additionally, the requirements of gas turbine and combined cycle have to be considered; with the target to provide fast reliable fuel switching, without a major effect on the power output. Alstom’s GT26/GT24 High Load Fuel Switchover (HLFSW) fulfils these requirements. HLFSW is a concept which allows switching back and forth between fuel gas and fuel oil in the load range of base load down to 60 % relative GT load. A key feature of the HLFSW is the stable load during the complete duration of the fuel switchover process, ensuring nearly constant power output in combined cycle mode from the moment the fuel switchover is triggered until standard operation is achieved on the secondary fuel. In this paper the integration of the HLFSW into the engine operation concept is presented. It is shown, how the sequential combustion of the Alstom GT26/GT24 is transferred from primary to secondary fuel by sequential fuel switchover. The focus is on how the high load fuel switchover concept is embedded into the gas turbine’s engine operation concept, allowing a smooth transfer between the fuel gas standard operation concept and the fuel oil standard operation concept and vice-versa, resulting in a fuel switchover concept without any significant disturbances to the heat recovery steam generator (HRSG).

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