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Research Papers: Gas Turbines: Electric Power

Using Dynamic Simulation to Evaluate Attemperator Operation in a Natural Gas Combined Cycle With Duct Burners in the Heat Recovery Steam Generator

[+] Author and Article Information
Eric Liese

National Energy Technology Laboratory,
Department of Energy,
Systems Engineering and Analysis Division,
Morgantown, WV 26507
e-mail: eric.liese@netl.doe.gov

Stephen E. Zitney

National Energy Technology Laboratory,
Department of Energy,
Systems Engineering and Analysis Division,
Morgantown, WV 26507
e-mail: stephen.zitney@netl.doe.gov

Contributed by the Electric Power Committee of ASME for publication in the JOURNAL OF ENGINEERING FOR GAS TURBINES AND POWER. Manuscript received July 6, 2017; final manuscript received July 17, 2017; published online September 26, 2017. Editor: David Wisler.

J. Eng. Gas Turbines Power 140(1), 011801 (Sep 26, 2017) (6 pages) Paper No: GTP-17-1305; doi: 10.1115/1.4037709 History: Received July 06, 2017; Revised July 17, 2017

A generic training simulator of a natural gas combined cycle (NGCC) was modified to match operations at a real plant. The objective was to use the simulator to analyze cycling operations of the plant. Initial operation of the simulator revealed the potential for saturation conditions in the final high pressure superheater (HPSH) as the attemperator tried to control temperature at the superheater outlet during gas turbine loading and unloading. Subsequent plant operational data confirmed simulation results. Multiple simulations were performed during loading and unloading of the gas turbine to determine operational strategies that prevented saturation and increased the approach to saturation temperature. The solutions included changes to the attemperator temperature control setpoints and strategic control of the steam turbine (ST) inlet pressure control valve.

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References

Liese, E. , and Zitney, S. E. , 2014, “ A Dynamic Process Model of a NGCC—Model Development With Startup and Shutdown Simulations,” Energy Tech Magazine, pp. 20–26.
Liese, E. A. , and Zitney, S. E. , 2013, “ A Dynamic Process Model of a Natural Gas Combined Cycle—Model Development With Startup and Shutdown Simulations,” ASME Paper No. POWER2013-98179.
Lancaster, R. , 2013, “ Using a High-Fidelity Simulator to Study and Mitigate the Effects of Frequent Cycling and Extended Unit Shutdown on Large Coal Fired Units,” PowerPlantSim Conference, Tampa, FL, Jan. 28–30.
Pearson, J. M. , and Anderson, R. , 2007, “ Measurement of Damaging Thermal Transient in F-Class Horizontal HRSGs,” OMMI, 4(3), pp. 1–108.

Figures

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Fig. 1

Schematic showing location of duct burner in between RH superheaters

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Fig. 2

CT exhaust gas temperature profile during loading

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Fig. 3

Some relevant data from the plant during unloading of CT1. Note that the water flow rate is not dimensionally known.

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Fig. 4

Approach to saturation at the inlet to the final HPSH (after the attemperator)

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Fig. 5

TCV position that controls water flow to the HP attemperator

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Fig. 6

Controlled steam temperature at the final HPSH exit

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Fig. 7

Heat flux to the steam in the final HPSH

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Fig. 9

IPC engaging during the unloading

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Fig. 10

Some relevant plant data during loading of CT1. Note that the water flow rate is not dimensionally known.

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Fig. 11

MCV position with respect to load for the three cases

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Fig. 12

Approach to saturation at the inlet to the final HPSH (after the attemperator) and exit temperature of the final HPSH

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Fig. 13

Heat flux to the steam in the final HPSH

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Fig. 14

Steam mass flow rate through the final HPSH

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