I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
BOGEY CURVES FOR PERFORMANCE CALCULATIONS
The following pages list the Bogey Curve data that should be supplied by the Customer to
perform all curvedependent calculations.
If any of these items are not provided, the related calculations can not be performed, and their
results will not be available.
Fixed values can be used where stated, but curve fits provide more accurate results in most
cases.
For curve data, based on one or two variables, data tables must be built. Forms are included
for providing these tables.
The forms allow up to 10 values for independent variables, but less than 10 is acceptable.
For curves based on two independent variables, the number of X and Y values can be
different.
i.e. 8 X values, 10 Y values, and 80 Z values is acceptable.
( No curves should be submitted. )
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
BOGEY CURVES FOR PERFORMANCE CALCULATIONS
FEEDWATER HEATERS
1. Expected terminal temperature difference (DEGF) as fixed value, function of gross
generation (MW), or function of feedwater flow to economizer (KPPH).
2. Terminal temperature difference heat rate deviation (BTU/KWH) as function of
feedwater flow to economizer (KPPH) and terminal temperature difference deviation
(DEGF).
3. Expected feedwater temperature rise (DEGF) as fixed value, function of gross
generation (MW), or function of feedwater flow to economizer (KPPH).
4. Expected Gross Unit Heat Rate as a function of gross generation (MW) or as a function
of feedwater flow to economizer (KPPH). (See Note 1)
5. Expected drain cooler approach temperature difference (DEGF) as fixed value, function
of gross generation (MW), or function of feedwater flow to economizer (KPPH).
6. Expected Boiler Efficiency as a function of gross generation (MW) or as a function
of feedwater flow to economizer (KPPH). (See Note 2)
Note 1 : Curve 4 is used to calculate Drain Cooler Approach Heat Rate Deviation
and is the same for all heaters. (Only provide once, not perheater.)
Note 2 : Curve 6 is also for DCA Heat Rate Deviation, and is only valid for the last
Heater(s) before the Economizer, i.e. the Highest Pressure Heater(s).
BOILER EFFICIENCY HEAT LOSS METHOD
1. Boiler Design Data values list. This is a set of fixed values for the following :
Percent Ash in the Fuel (PCT)
Percent Carbon in the Fuel (PCT)
Percent Sulphur in the Fuel (PCT)
Percent Moisture in the Fuel (PCT)
Percent Hydrogen in the Fuel (PCT)
Percent Nitrogen in the Fuel (PCT)
Percent Oxygen in the Fuel (PCT)
Higher Heating Value of the Fuel (BTU/LB)
Ambient Dry Bulb Temperature (DEGF)
lb. h2o / lb. dry air at Design Ambient Temperature and Relative Humidity
2. Reference Air Temperature from Boiler Design Data as function of gross generation
(MW).
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
BOILER EFFICIENCY HEAT LOSS METHOD (continued)
3. Expected flue gas temperature (DEGF) as fixed value, function of gross generation
(MW), or function of main steam flow (KPPH).
4. Flue Gas Specific Heat as function of Stack Gas Temperature (DEGF) and Carbon/
Hydrogen Ratio. (Standard Curve from ASME PTC 4.1 Figure 7 Foxboro supplied)
5. Radiation Losses (PCT) as function of boiler heat output (MBTU/HR).
(This a a portion of the ASME PTC 4.1 Figure 8 up to Maximum Continuous Output of
the Boiler. If desired, provide only Boiler MCR value and Foxboro will fill in table.)
6. Number of Boiler Waterwalls as fixed value. (To be used with previous curve.)
7. Expected excess air (PCT) as fixed value, function of gross generation (MW), or
function of main steam flow (KPPH).
8. Expected oxygen in flue gas (PCT) as fixed value, function of gross generation (MW),
or function of main steam flow (KPPH).
9. Main steam temperature heat rate deviation (BTU/KWH) as function of feedwater flow
to economizer (KPPH) and main steam temperature (DEGF).
10. Main steam pressure heat rate deviation (BTU/KWH) as function of feedwater flow to
economizer (KPPH) and main steam pressure (PSIG).
11. Hot reheat temperature heat rate deviation (BTU/KWH) as function of feedwater flow to
economizer (KPPH) and hot reheat temperature (DEGF).
12. Expected reheat pressure drop (PCT) as fixed value, function of gross generation
(MW), or function of main steam flow (KPPH).
13. Reheat pressure drop heat rate deviation (BTU/KWH) as function of feedwater flow to
economizer (KPPH) and reheat pressure drop (PCT).
STEAM TURBINES
1. Expected Turbine Efficiency (PCT) as fixed value, function of gross generation (MW),
or function of feedwater flow (KPPH).
2. Turbine efficiency heat rate deviation (BTU/KWH) as function of feedwater flow to
economizer (KPPH) and turbine efficiency (PCT).
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
CONDENSER
1. Condenser heat load (Million BTU/HR) as fixed value, function of condensate flow
(KPPH), function of gross generation (MW), or function of gross generation (MW)
and condenser exhaust pressure (IN HGA).
Note : If no data provided, this will be calculated from condensate flow using latent heat
of vaporization.
2. Heat Transfer Coefficient Constant from HEI standard based on tube size. (Foxboro
supplied based on Customer supplied condenser data)
3. Design correction factor from HEI standard. (Standard curve Foxboro supplied)
4. Expected Condenser back pressure (IN HGA) as a fixed value or as function of gross
generation (MW) and condenser circulating water inlet temperature (DEGF).
5. Exhaust Loss End Point (BTU/LB) as function of gross generation (MW) or function of
feedwater flow to economizer (KPPH).
6. Exhaust Loss (BTU/LB) as function of Annulus Velocity (FT/SEC).
7. Design Condenser back pressure (IN HGA) as a fixed value.
8. Change in Expansion Line End Point (BTU/LB) as function of condenser back pressure
(IN HGA). (Standard ASME curve Foxboro supplied).
9. Condenser back pressure heat rate deviation (BTU/KWH) as function of feedwater flow
to economizer (KPPH) and condenser back pressure (IN HGA).
10. Condensate makeup flow heat rate deviation (BTU/KWH) as function of feedwater flow
to economizer (KPPH) and makeup flow (KPPH).
AIR HEATERS
1. Reference Air Inlet Temperature (DEGF) as function of gross generation (MW).
2. Design Gas Inlet Temperature (DEGF) as fixed value at Full Load.
BOILER SECTION HEAT TRANSFER COEFFICIENT, AND
ELECTRIC BOILER FEED PUMPS
No bogey curves used for these sections.
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
TURBINEDRIVEN BOILER FEED PUMPS
1. Expected Pump efficiency (PCT) as function of feedwater flow to economizer
(GPM or KPPH).
BOILER EFFICIENCY INPUT/OUTPUT METHOD (OPTIONAL)
1. Constants for Reheat Flow calculation. This is a set of fixed values for the following :
Primary Superheat Pressure Drop (PCT)
Secondary Superheat Pressure Drop (PCT)
First Throttle Steam Packing Leak Constant
Second Throttle Steam Packing Leak Constant
Third Throttle Steam Packing Leak Constant
First Stage Packing Leak to IPT Constant
Combined HP Shaft Packing Leaks 5&6 Constant
Additional Packing Leak Constant (if needed)
UNIT CALCULATIONS
1. Expected Net Unit Heat Rate as function of gross generation (MW).
2. Heat rate correction (PCT) as function of main steam temperature (DEGF), as function
of feedwater flow (KPPH) and main steam temperature (DEGF), or as function of
gross generation (MW) and main steam temperature (DEGF).
3. Heat rate correction (PCT) as function of main steam pressure (PSIG), as function of
feedwater flow (KPPH) and main steam pressure (PSIG), or as function of gross
generation (MW) and main steam pressure (PSIG).
4. Heat rate correction (PCT) as function of reheat pressure drop (PCT).
5. Heat rate correction (PCT) as function of reheat temperature (DEGF), as function of
feedwater flow (KPPH) and reheat temperature (DEGF), or as function of gross
generation (MW) and reheat temperature (DEGF).
6. Heat rate correction (PCT) as function of condenser vacuum (IN HGA), as function of
feedwater flow (KPPH) and condenser vacuum (IN HGA), or as function of gross
generation (MW) and condenser vacuum (IN HGA).
7. Auxiliary power heat rate deviation (BTU/KWH) as function of feedwater flow to
economizer (KPPH) and auxiliary power usage (MW).
8. Expected superheat spray flow (KPPH) as fixed value or as function of feedwater flow
to economizer (KPPH).
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
9. Superheat spray flow heat rate deviation (BTU/KWH) as function of feedwater flow to
economizer (KPPH) and superheat spray flow (KPPH).
10. Expected reheat spray flow (KPPH) as fixed value or as function of feedwater flow to
economizer (KPPH).
11. Reheat desuperheat spray flow heat rate deviation (BTU/KWH) as function of
feedwater flow to economizer (KPPH) and reheat desuperheat spray flow (KPPH).
COOLING TOWERS
CharacteristicCurve Method Only
1. Tower Design Data values list. This is a set of fixed values for the following:
Water Flow (GPM)
Water Inlet Temperature (DEGF)
Water Outlet Temperature (DEGF)
Atmospheric Pressure (PSIA)
Atmospheric Dry Bulb Temperature (DEGF)
Atmospheric Wet Bulb Temperature (DEGF)
Fan Horsepower (BHP)
L/G Ratio, i.e. WatertoAir Flow Ratio (Unitless)
Cooling Range (DEGF)
2. Fixed Value that is the slope of the Characteristic Curve.
3. Design Approach Curve (KaV/L as function of L/G Ratio) for Design Approach Value,
which is Design Water Outlet Temperature – Design Wet Bulb Temperature.
Performance Curve Method Only
1. Tower Design Data values list. (Same as 1. for CharacteristicCurve Method Only)
2. Cold Water Temperature (DEGF) as function of Wet Bulb Temperature (DEGF) and
Cooling Range (DEGF) for lowest of 3 flows.
3. Cold Water Temperature (DEGF) as function of Wet Bulb Temperature (DEGF) and
Cooling Range (DEGF) for middle of 3 flows.
4. Cold Water Temperature (DEGF) as function of Wet Bulb Temperature (DEGF) and
Cooling Range (DEGF) for highest of 3 flows.
5. List of 3 Flow values (GPM) that correspond to above 3 curves.
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
Both Characteristic Curve and Performance Curve Methods
1. Tower Design Data values list. This is a set of fixed values for the following:
Water Flow (GPM)
Water Inlet Temperature (DEGF)
Water Outlet Temperature (DEGF)
Atmospheric Pressure (PSIA)
Atmospheric Dry Bulb Temperature (DEGF)
Atmospheric Wet Bulb Temperature (DEGF)
Fan Horsepower (BHP)
L/G Ratio, i.e. WatertoAir Flow Ratio (Unitless)
Cooling Range (DEGF)
2. Fixed Value that is the slope of the Characteristic Curve.
3. Design Approach Curve (KaV/L as function of L/G Ratio) for Design Approach Value,
which is Design Water Outlet Temperature – Design Wet Bulb Temperature.
4. Cold Water Temperature (DEGF) as function of Wet Bulb Temperature (DEGF) and
Cooling Range (DEGF) for lowest of 3 flows.
5. Cold Water Temperature (DEGF) as function of Wet Bulb Temperature (DEGF) and
Cooling Range (DEGF) for middle of 3 flows.
6. Cold Water Temperature (DEGF) as function of Wet Bulb Temperature (DEGF) and
Cooling Range (DEGF) for highest of 3 flows.
7. List of 3 Flow values (GPM) that correspond to above 3 curves.
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
Bogey Curve Data
BOGEY CURVES FOR PERFORMANCE CALCULATIONS
X Y Table format
INDEPENDENT ( X ) VARIABLE __________________________________
DEPENDENT ( Y ) VARIABLE __________________________________
X1 ____________ Y1 ____________
X2 ____________ Y2 ____________
X3 ____________ Y3 ____________
X4 ____________ Y4 ____________
X5 ____________ Y5 ____________
X6 ____________ Y6 ____________
X7 ____________ Y7 ____________
X8 ____________ Y8 ____________
X9 ____________ Y9 ____________
X10 ____________ Y10 ____________
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
I/A PERFORMANCE CALCULATION INPUT LIST
CENTRAL STATION
BOGEY CURVES FOR PERFORMANCE CALCULATIONS
X Y Z Table format
INDEPENDENT ( X ) VARIABLE ______________________________________
INDEPENDENT ( Y ) VARIABLE ______________________________________
DEPENDENT ( Z ) VARIABLE ______________________________________
X1 X2 X3 X4 X5 X6 X7 X8 X9 X10
______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Y1______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z1
Y2______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z2
Y3______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z3
Y4______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z4
Y5______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z5
Y6______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z6
Y7______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z7
Y8______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z8
Y9______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z9
Y10_____ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Z10 Z20 Z30 Z40 Z50 Z60 Z70 Z80 Z90 Z100
The Foxboro Company, 2009
All Rights Reserved. Rev. 1.8 03/27/09
