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Gas Turbines: Industrial & Cogeneration

Available and Future Gas Turbine Power Augmentation Technologies: Techno-Economic Analysis in Selected Climatic Conditions

[+] Author and Article Information
Rakesh K. Bhargava

Mechanical Engineering Advisor,  Hess Corporation, 1501 McKinney, Houston, TX 77010bhargavar1951@gmail.com

Lisa Branchini1

 DIEM – Università di Bologna, Viale Risorgimento 2, 40136 Bologna, Italylisa.branchini2@unibo.it

Francesco Melino

 IMEM – Consiglio Nazionale delle Ricerche, Parco Area delle Scienze 37/A, 43124 Parma, Italyfrancesco.melino@imem.cnr.it

Antonio Peretto

 DIEM – Università di Bologna, Viale Risorgimento 2, 40136 Bologna, Italyantonio.peretto@unibo.it

1

Corresponding author.

J. Eng. Gas Turbines Power 134(10), 102001 (Aug 17, 2012) (11 pages) doi:10.1115/1.4007126 History: Received June 18, 2012; Revised July 11, 2012; Published August 17, 2012; Online August 17, 2012

There exists a widespread interest in the application of gas turbine power augmentation technologies in both electric power generation and mechanical drive markets, attributable to deregulation in the power generation sector, significant loss in power generation capacity combined with increased electric rates during peak demand period, and need for a proper selection of the gas turbine in a given application. In this study, detailed thermo-economic analyses of various power augmentation technologies, implemented on a selected gas turbine, have been performed to identify the best techno-economic solution depending on the selected climatic conditions. The presented results show that various power augmentation technologies examined have different payback periods. Such a techno-economic analysis is necessary for proper selection of a power augmentation technology.

Copyright © 2012 by American Society of Mechanical Engineers
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References

Figures

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Figure 1

Classification of the considered power augmentation strategies

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Figure 2

Gas turbine power augmentation technologies plant layout: (a) continuous cooling systems with compression chiller (CCC), (b) continuous cooling systems with absorption chiller (CCA), (c) traditional evaporative cooling systems (TEC), (d) fogging and/or overspray evaporative cooling systems (HPF and/or OS), (e) humid air combustion chamber injection systems (HAI), (f) steam combustion chamber injection systems (STIG)

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Figure 3

Yearly frequency distribution of air temperature for the two locations

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Figure 4

Yearly frequency distribution of RH for the two locations

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Figure 5

Power output, heat rate, and air mass flow rate versus ambient temperature for GE Frame 7EA

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Figure 6

Percentage error between direct method and interpolating method; (a) net power output and (b) net electric efficiency

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Figure 7

Yearly percentage net energy boost achievable with the PATs (reference: gasturbine without no PAT at 8760 h of operations)

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Figure 8

Percentage net energy boost achievable with the PATs (reference: gasturbine without no PAT at 5383 and 7697 operating hours respectively in Bologna and in Houston)

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Figure 9

Variation of yearly cash flow due to PATs

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Figure 10

Differential net present value due to PATs

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Figure 11

Differential net present value due to PATs for Fr7 in Houston

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Figure 12

Differential net present value due to PATs for Fr7 in Bologna

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Figure 13

Typical summer daily variation of dry, wet bulb temperature and relative humidity in Bologna

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Figure 14

Typical winter daily variation of dry, wet bulb temperature, and relative humidity in Bologna

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Figure 15

Typical summer daily variation of dry, wet bulb temperature, and relative humidity in Houston

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Figure 16

Typical winter daily variation of dry, wet bulb temperature, and relative humidity in Houston

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