A TERA Based Comparison of Heavy Duty Engines and Their Artificial Design Variants for Liquified Natural Gas Service

2013 ◽  
Vol 136 (2) ◽  
Author(s):  
Matteo Maccapani ◽  
Raja S. R. Khan ◽  
Paul J. Burgmann ◽  
Giuseppina Di Lorenzo ◽  
Stephen O. T. Ogaji ◽  
...  
Keyword(s):  
Natural Gas ◽  
Risk Analysis ◽  
Value Chain ◽  
Gas Turbines ◽  
Research Collaboration ◽  
Global Solutions ◽  
Heavy Duty ◽  
Process Technology ◽  
Equipment Selection ◽  
Selection Of

The liquefaction of natural gas is an energy intensive process and accounts for a considerable portion of the costs in the liquefied natural gas (LNG) value chain. Within this, the selection of the driver for running the gas compressor is one of the most important decisions and indeed the plant may well be designed around the driver, so one can appreciate the importance of driver selection. This paper forms part of a series of papers focusing on the research collaboration between Shell Global Solutions and Cranfield University, looking at the equipment selection of gas turbines in LNG service. The paper is a broad summary of the LNG Technoeconomic and Environmental Risk Analysis (TERA) tool created for equipment selection and looks at all the important factors affecting selection, including thermodynamic performance simulation of the gas turbines, lifing of hot gas path components, risk analysis, emissions, maintenance scheduling, and economic aspects. Moreover, the paper looks at comparisons between heavy duty industrial frame engines and two artificial design variants representing potential engine uprates. The focus is to provide a quantitative and multidisciplinary approach to equipment selection. The paper is not aimed to produce absolute accurate results (e.g., in terms of engine life prediction or emissions), but useful and realistic trends for the comparison of different driver solutions. The process technology is simulated based on the Shell DMR technology and single isolated trains are simulated with two engines in each train. The final analysis is normalized per tonne of LNG produced to better compare the technologies.

Application of Aircraft Derivative and Heavy Duty Gas Turbines in the Process Industries

1979 ◽  
Author(s):  
M. C. Doherty ◽  
D. R. Wright
Keyword(s):  
Natural Gas ◽  
Fuel Consumption ◽  
Gas Turbines ◽  
Cooling Water ◽  
Offshore Platforms ◽  
Heavy Duty ◽  
Water Requirements ◽  
Process Industries ◽  
Gas Processing ◽  
Processing Plants

Typical applications of aircraft derivative and heavy duty gas turbines in petroleum production and refining, natural gas processing, ethylene, ammonia, LNG processing plants and offshore platforms are reviewed. Guidelines are included to illustrate how gas turbines can be applied to minimize fuel consumption and cooling water requirements and optimize space utilization.

Risk Analysis of Gas Turbines for Natural Gas Liquefaction

2011 ◽  
Vol 133 (7) ◽  
Author(s):  
Raja S. R. Khan ◽  
Maria C. Lagana ◽  
Stephen O. T. Ogaji ◽  
Pericles Pilidis ◽  
Ian Bennett
Keyword(s):  
Risk Assessment ◽  
Natural Gas ◽  
Risk Analysis ◽  
Firing Temperature ◽  
Gas Turbines ◽  
Technology Selection ◽  
Maintenance Cost ◽  
Technology Readiness ◽  
Technical Risk ◽  
Plant Equipment

Procurement of process plant equipment involves decisions based not only on an economic agenda but also on long term plant capability, which in turn depends on equipment reliability. As the greater global community raises environmental concerns and pushes for economic reform, a tool is evermore required for a specific and critical selection of plant equipment. Risk assessments based on NASA’s Technology Readiness Level (TRL) scale have been employed in many previous risk models to map technology in terms of risk and reliability. The authors envisage a scale for quantifying the technical risk. The focus of this paper is the technical risk assessment of gas turbines as mechanical drivers for producing liquefied natural gas (LNG). This risk assessment is a cornerstone of the technoeconomic environmental and risk analysis (TERA) philosophy developed by Cranfield University’s Department of Power and Propulsion in U.K. Monte Carlo simulations are used in order to compare the risks of introducing new plant equipment against existing and established plant equipment. Three scenarios are investigated using an 87MW single spool, typical industrial machine, a baseline engine followed by an engine with increased firing temperature, and finally an engine with a zero staged compressor. The results suggest that if the baseline engine was to be upgraded, then the zero staging option would be a better solution than increasing the firing temperature since zero staging gives the lower rise in total time to repair (TTTR) or downtime. The authors suggest a scaling system based on NASA’s TRL but with modified definition criteria for the separate technology readiness levels in order to better relate the scale to gas turbine technology. The intention is to link the modified TRL to downtime, since downtime has been identified as a quantitative measure of technical risk. Latest developments of the modeling are looking at integrating risk analysis and a maintenance cost and scheduling model to provide a platform for total risk assessment. This, coupled with emissions modeling, is set to provide the overall TERA tool for LNG technology selection.

Risk Analysis of Gas Turbines for Natural Gas Liquefaction

2010 ◽  
Author(s):  
Raja S. R. Khan ◽  
Maria Chiara Lagana ◽  
Steven O. T. Ogaji ◽  
Pericles Pilidis ◽  
Ian Bennett
Keyword(s):  
Risk Assessment ◽  
Natural Gas ◽  
Risk Analysis ◽  
Firing Temperature ◽  
Gas Turbines ◽  
Technology Selection ◽  
Maintenance Cost ◽  
Technology Readiness ◽  
Technical Risk ◽  
Plant Equipment

Procurement of process plant equipment involves decisions based not only on an economic agenda but also on long term plant capability, which in turn depends on equipment reliability. As the greater global community raises environmental concerns and pushes for economic reform, a tool is evermore required for specific and critical selection of plant equipment. Risk assessments based on NASA’s Technology Readiness Level (TRL) scale have been employed in many previous risk models to map technology in terms of risk and reliability. The authors envisage a scale for quantifying technical risk. The focus of this paper is the technical risk assessment of gas turbines as mechanical drivers for producing Liquefied Natural Gas (LNG). This risk assessment is a cornerstone of the TERA philosophy, a Technoeconomic and Environmental Risk Analysis developed by Cranfield University’s Department of Power and Propulsion in the UK. Monte Carlo simulations are used in order to compare the risks of introducing new plant equipment against existing and established plant equipment. Three scenarios are investigated using an 87MW single spool, typical industrial machine; a baseline engine followed by an engine with increased firing temperature and finally an engine with a zero staged compressor. The results suggest that if the baseline engine was to be upgraded then the zero staging option would be a better solution than increasing firing temperature since zero staging gives the lower rise in Total Time to Repair (TTTR), or downtime. The authors suggest a scaling system based on NASA’s TRL but with modified definition criteria for the separate technology readiness levels in order to better relate the scale to gas turbine technology. The intention is to link the modified TRL to downtime, since downtime has been identified as a quantitative measure of technical risk. Latest developments of the modelling are looking at integrating risk analysis and a maintenance cost and scheduling model to provide a platform for total risk assessment. This, coupled with emissions modelling, is set to provide the overall TERA tool for LNG technology selection.

scholarly journals A boil-off gas utilization for improved performance of heavy duty gas turbines in combined cycle

2018 ◽  
Vol 233 (1) ◽  
pp. 96-110 ◽  
Author(s):  
Stefano Mazzoni ◽  
Srithar Rajoo ◽  
Alessandro Romagnoli
Keyword(s):  
Heat Transfer ◽  
Natural Gas ◽  
Ambient Temperature ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Liquefied Natural Gas ◽  
Combined Cycle ◽  
Cooling Power ◽  
Heavy Duty ◽  
Cold Energy

The storage of the natural gas under liquid phase is widely adopted and one of the intrinsic phenomena occurring in liquefied natural gas is the so-called boil-off gas; this consists of the regasification of the natural gas due to the ambient temperature and loss of adiabacity in the storage tank. As the boil-off occurs, the so-called cold energy is released to the surrounding environment; such a cold energy could potentially be recovered for several end-uses such as cooling power generation, air separation, air conditioning, dry-ice manufacturing and conditioning of inlet air at the compressor of gas turbine engines. This paper deals with the benefit corresponding to the cooling down of the inlet air temperature to the compressor, by means of internal heat transfer recovery from the liquefied natural gas boil-off gas cold energy availability. The lower the compressor inlet temperature, the higher the gas turbine performance (power and efficiency); the exploitation of the liquefied natural gas boil-off gas cold energy also corresponds to a higher amount of air flow rate entering the cycle which plays in favour of the bottoming heat recovery steam generator and the related steam cycle. Benefit of this solution, in terms of yearly work and gain increase have been established by means of ad hoc developed component models representing heat transfer device (air/boil-off gas) and heavy duty 300 MW gas turbine. For a given ambient temperature variability over a year, the results of the analysis have proven that the increase of electricity production and efficiency due to the boil-off gas cold energy recovery has finally yield a revenue increase of 600,000€/year.

A Comparative Analysis of Single Nozzle and Multiple Nozzles Arrangements for Syngas Combustion in Heavy Duty Gas Turbine

2016 ◽  
Vol 139 (2) ◽  
Author(s):  
Shi Liu ◽  
Hong Yin ◽  
Yan Xiong ◽  
Xiaoqing Xiao
Keyword(s):  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Combined Cycle ◽  
Heavy Duty ◽  
Gas Turbine Combustor ◽  
Integrated Gasification Combined Cycle ◽  
Wide Range ◽  
Heavy Duty Gas Turbine ◽  
Integrated Gasification

Heavy duty gas turbines are the core components in the integrated gasification combined cycle (IGCC) system. Different from the conventional fuel for gas turbine such as natural gas and light diesel, the combustible component acquired from the IGCC system is hydrogen-rich syngas fuel. It is important to modify the original gas turbine combustor or redesign a new combustor for syngas application since the fuel properties are featured with the wide range hydrogen and carbon monoxide mixture. First, one heavy duty gas turbine combustor which adopts natural gas and light diesel was selected as the original type. The redesign work mainly focused on the combustor head and nozzle arrangements. This paper investigated two feasible combustor arrangements for the syngas utilization including single nozzle and multiple nozzles. Numerical simulations are conducted to compare the flow field, temperature field, composition distributions, and overall performance of the two schemes. The obtained results show that the flow structure of the multiple nozzles scheme is better and the temperature distribution inside the combustor is more uniform, and the total pressure recovery is higher than the single nozzle scheme. Through the full scale test rig verification, the combustor redesign with multiple nozzles scheme is acceptable under middle and high pressure combustion test conditions. Besides, the numerical computations generally match with the experimental results.

Evaluation of Arabian Super Light Crude Oil for Use in a F-Class DLN Combustion System

2014 ◽  
Author(s):  
Jeffrey Goldmeer ◽  
Richard Symonds ◽  
Paul Glaser ◽  
Bassam Mohammad ◽  
Zac Nagel ◽  
...  
Keyword(s):  
Power Generation ◽  
Natural Gas ◽  
Crude Oil ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Oil Prices ◽  
Combustion System ◽  
Heavy Duty ◽  
Global Trends ◽  
Heavy Liquids

Global trends in natural gas and distillate oil prices and availability continue to influence decisions on power generation fuel choice. In some regions, heavy liquids are being selected as gas turbine fuels. One particular crude oil, Arabian Super Light (ASL), has the potential to be used as a primary or back-up fuel in F-class heavy duty gas turbines. This paper presents the results of a set of tests performed on ASL to determine the potential of using it in a Dry Low NOx (DLN) combustion system for operation in an F-class gas turbine.

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

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

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

scholarly journals Full annulus numerical study of hot streaks propagation in a hydrogen-rich syngas-fired heavy duty axial turbine

2017 ◽  
Vol 231 (5) ◽  
pp. 344-356
Author(s):  
Eleni Ioannou ◽  
Abdulnaser I Sayma
Keyword(s):  
Natural Gas ◽  
Secondary Flow ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Secondary Flows ◽  
Fuel Composition ◽  
Heavy Duty ◽  
Turbine Stage ◽  
Computational Fluid Dynamics Analysis ◽  
Hot Streak

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.

Low CO2 Combustion System Retrofits for Existing Heavy Duty Gas Turbines

2008 ◽  
Author(s):  
Peter J. Stuttaford ◽  
Khalid Oumejjoud
Keyword(s):  
Power Plant ◽  
Natural Gas ◽  
Gas Turbine ◽  
Gas Turbines ◽  
Power Plants ◽  
Combined Cycle ◽  
Premixed Combustion ◽  
Combustion System ◽  
Heavy Duty ◽  
Fuel Processing

CO2 emissions generated by power plants make up a significant portion of global carbon emissions. Although there has been a great deal of focus on new power sources incorporating state of the art environmental protection systems, there has been little focus on addressing the issues of existing power plants. The purpose of this work is to address the options available to existing gas turbine based power plants to retrofit CO2 reduction measures cost effectively at the source of emissions, the combustor. Pre-combustion decarbonization is a highly efficient method of carbon removal, as only a small fraction of the gas turbine system flow needs to be addressed. This results in the requirement to burn a hydrogen based fuel, which presents challenges due to its highly reactive nature. The properties of hydrogen/syngas combustion are reviewed with emphasis on solutions for premixed combustion systems. Premixed combustion as opposed to diffusion combustion systems are key to retrofit solutions for existing gas turbines. Premixed systems provide the life cycle cost benefit, and heat rate benefit of not requiring the addition of diluent to the cycle to control emissions. Fuel flexibility is critical for retrofit systems, allowing operators to run on high hydrogen fuels as well as back-up standard natural gas to maximize power plant availability. Pre-combustion decarbonization may occur remote from the power plant at a centralized fuel processing facility, or it may be integrated into the combined cycle gas turbine power plant. Existing combined cycle power plants operating on natural gas could be modified to incorporate fuel decarbonization into the cycle, minimizing the parasitic loss of such a system while capturing carbon credits which are likely to become of increasing monetary value. An example cycle to address such integrated systems is presented. The focus of this work is to present a cycle to provide decarbonized fuel, cost effectively, from existing natural gas systems, as well as centralized coal/petcoke based fuel processing facilities. An additional focus is on the combustion system design requirements to burn such fuels, which are retrofitable to existing heavy duty gas turbine based power plants.

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