WATER POLLUTION CONTROL RESEARCH SERIES • 16130EES11/70
RESEARCH ON
DRY - TYPE COOLING TOWERS
FOR THERMAL ELECTRIC
GENERATION
Part II
ENVIRONMENTAL PROTECTION AGENCY • WATER QUALITY OFFICE
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WATER POLLUTION CONTROL RESEARCH SERIES
The Water Pollution Control Research Series describes the
results and progress in the control and abatement of pollu-
tion of our Nation's waters. They provide a central source
of information on the research, development, and demon-
stration activities of the Water Quality Office, Environ-
mental Protection Agency, through inhouse research and grants
and contracts with Federal, State, and local agencies, re-
search institutions, and industrial organizations.
Inquiries pertaining to the Water Pollution Control Research
Reports should be directed to the Head, Project Reports
System, Office of Research and Development, Water Quality
Office, Environmental Protection Agency, Washington, D.C. 20242.
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RESEARCH ON DRY-TYPE COOLING TOWERS FOR
THERMAL ELECTRIC GENERATION: PART II
Computer Program Descriptions
by
R. W. Beck and Associates
600 Western Federal Savings Bldg.
Denver, Colorado 80202
for the
WATER QUALITY OFFICE
ENVIRONMENTAL PROTECTION AGENCY
Project # 16130 EES
Contract # 14-12-823
November 1970
For sale by the Superintendent of Documents, U.S. Government Printing Office, Washington, D.C. 20402 - Price $1
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EPA Review Notice
This report has been reviewed by the Water Quality Office,
EPA, and approved for publication. Approval does not signi-
fy that the contents necessarily reflect the views and poli-
cies of the Environmental Protection Agency, nor does mention
of trade names or commercial products constitute endorsement
or recommendation for use.
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TABLE OF CONTENTS
Page
TITLE PAGE
TABLE OF CONTENTS i
GENERAL 1
ECONOMIC OPTIMIZATION PROGRAM "OPTDCT" 1
Description of Program "OPTDCT" 2
General Description of Subroutine "DATCHK" 4
General Description of Subroutine "TBLUQ" 5
Description of Data File "TURBIN" 5
Description of Data File "SITEXX" 6
Format of External Data Files 7
Output Data File 7
Operating Instruction for "OPTDCT" 7
"OPTDCT" Flow Chart Description 10
TOWER OPTIMIZATION PROGRAM "TOWSIZ" 18
Description of Program "TOWSIZ" 18
Description of Subroutine "TBLUQ" 19
General Description of Subroutine "TWRPIP" 19
General Description of Subroutine "PIPSIZ" 19
Description of Data File "SIZDAT" 20
Output Data 20
Operating Instruction for "TOWSIZ" 20
"TOWSIZ" Flow Chart Description 20
Subroutine "TBLUQ" Flow Chart Description 22
Subroutine "TWRPIP" Flow Chart Description 23
Subroutine "PIPSIZ" Flow Chart Description 24
APPENDIX A - Program Listings 25
APPENDIX B - Sample Data 42
APPENDIX C - Output Samples 49
APPENDIX D - Flow Charts 53
APPENDIX E - Glossary 83
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DRY COOLING TOWER OPTIMIZATION
COMPUTER PROGRAMS
GENERAL
The study of dry-type cooling towers as described in the report Research on
Dry-Type Cooling Towers for Thermal Electric Generation was facilitated by the
development of two computer programs to aid in the analysis of the large quantity
of data. The writeup herein describes the two programs in detail and provides in-
structions for their operation.
The computer used was a CDC 6400 in the timesharing system of United
Computing Systems, Inc., of Kansas City, Missouri. Input was by paper tape on a
remote teletype terminal. Remote and local batch output by terminal was possible;
however, remote batch was primarily used due to the large amount of output infor-
mation. The programs were coded in FORTRAN IV.
The physical dimensions of a natural-draft dry cooling tower and its capital
cost are evaluated by the program titled "TOWSIZ". The economically optimum
dry cooling system is determined by the program titled "OPTDCT".
ECONOMIC OPTIMIZATION PROGRAM "OPTDCT"
The purpose of the program OPTDCT is to determine, for a given set of con-
ditions at a particular location, the economically optimum dry-type cooling system
for a large thermal-electric generating plant.
The size of the dry cooling system is a function of the initial temperature
difference (ITD) which is the difference between the turbine exhaust steam tempera-
ture and the ambient air temperature. The economically optimum dry cooling
system for a specific set of conditions is that which results in the lowest total annual
cost.
The annual costs which are affected by the ITD of the dry cooling system
and which, therefore, must be considered in the economic optimization analysisare
the annual capital costs, operation and maintenance costs, total generating plant
fuel costs, auxiliary power costs and the cost of replacing generating capacity lost
at high ambient air temperatures.
The economic optimization program OPTDCT requires the input from two
external data files, TURBIN and SITEXX. All other data required for the analysis
are either in data statements within the program or are created by the program and
then stored in arrays.
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The data file TURBIN contains the following data pertaining to the turbine:
nameplate rating; type of fuel (fossil or nuclear); the design heat rejection; limiting
values for the operating back pressure; the turbine output for back pressure from 1 .0
inch Hg to 18.0 inches Hg in steps of 0.5 inches; and corresponding values of tur-
bine heat rate, station heat rate and heat rejection for the three turbine operating
conditions of full throttle, 3/4 load and 1/2 load.
The data file SITEXX contains the following site related information: site
name, elevation, reason of peak electrical demand, fuel costs, fixed-charge rates,
a construction cost multiplier, the capital cost per kw for peaking units, a cutoff
temperature used in determining when the peaking unit is operated, the capital cost
per kw for auxiliary power, operation and maintenance cost data and ambient air
temperature duration data for the site.
Description of Program "OPTDCT"
The following is a detailed section by section explanation of the computer
program. A glossary of terms, used in the program, can be found in Appendix E.
The first section of the program, ending at line 01080, contains declaration,
data and comment statements. The data within this section does not change with
the exception of the following: AUX100 data line no. 00360, KWAX data line no.
00440, CAPCST data lines 00960-01020, and the TOWER data line no. 01060.
These blocks of data have to correspond to the tower and turbine being analyzed.
A further explanation of the above mentioned data is in the section on operating
instructions.
The next section, line 01100 to line 01260, is the section that creates the
air temperature and back pressure arrays. The first part creates the 32 values of air
temperature starting at 117°F and decreasing by 5° increments to -38°F. The
second part creates the back pressure data. These values start at 1 .0 inch Hg and
go to 18.0 inches Hg by 0.5 inch increments.
In the section beginning on line 01260 and ending on line 01580 the turbine
data from file TURBIN is read into the program. Also within this section the nom-
inal generation for the given set of operating conditions is calculated. This is done
in the statements on lines 01320 and 01340.
After the first eight lines of data have been read into the program, the data
check subroutine (DATCHK) is called and the data is checked to see if the right
number of values have been read. The next fifteen lines of data are read and the
subroutine is called again. This is done until all of the turbine data has been read
into the program.
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The next section of the program reads in the site data. An explanation of
how the site data files are set up is contained in the section on data files. After the
site data is read, subroutine DATCHK is called again to verify that the correct num-
ber of values were read into the program.
Also within this section, an indicator (IWSP) is set up to direct the computer
to the different calculations which are involved with the different peaking periods.
This section also finds the air temperatures corresponding to the first and last non-
zero temperature durations.
The site identification data is written to the output file in the next section.
This starts at line 02520 and ends at line 03040.
The section starting with line 03060 sets up variables that are used in calcu-
lating operating costs. These variables are used later in the program, mostly in
table look-up calculations.
The next section of the program deals with capital cost. The computer picks
the capital cost for a specific ITD and elevation of the site being analyzed from a
table of capital costs.
The capital cost is then multiplied by the construction cost index for the site.
The next section, line 03580 through line 03820, initializes variables that
are accumulative. These variables are cumulative for each different ITD.
Starting at line 03900, the coefficient A is determined in the equation
ITD = A*HREJ**Z. The value of the exponent Z used in the program was .75 for a
natural-draft tower and .91 for a mechanical-draft tower.
The calculations to find the operating back pressure for the different air
temperatures and for the different turbine loadings begin at line 04000. The back
pressures are found by the method of successive approximations and are calculated
from line 04120 to line 04660. A limitation has been set on the number iterations
it takes to arrive at the turbine operating back pressure. If the limitation is ex-
ceeded then the operating back pressure is set equal to the allowable maximum. If
the back pressure is found before the limitation is reached, the computer then
checks to see if it is within the designated limit. If the back pressure is within the
maximum and minimum limitations, then that pressure is used to determine the power
oo.put of the turbine and also its heat rate.
If the back pressure is not within the limiting values, the turbine operation
is adjusted to operate within the designated limits. These calculations are made
between lines 04680 and 04780.
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In the section beginning at line 04800 the annual fuel consumption (Btu) is
calculated. This value is calculated from the operating station heat rate and re-
flects the ambient air temperatures during the year and the generating plant loading
assumptions.
Starting at line 05000, the auxiliary power requirements for the varying
ITD1 s and air temperatures are calculated. The program is directed to the appro-
priate calculations depending upon the type of tower (natural draft or mechanical
draft). Auxiliary power and energy requirements for a mechanical-draft tower are
calculated between lines 05020 and 05440. Natural draft auxiliary power and
energy requirements are calculated between fines 05480and 05540.
The next section beginning at line 05560 is the section in which the loss or
gain of capacity is calculated. If the operating back pressure is greater than 3-1/2
inches Hg, then there is a loss of capacity and the amount is calculated in the part
beginning at line 05760. If there is a gain, the amount is calculated in the part
beginning at line 05620.
The loss of capacity occurring at the temperature equalled or exceeded 10
hours per year is calculated on line 05960.
The next section of the program, beginning at line 06080, writes into the
output file the information identifying each run.
The section beginning at line 06240 writes into the output file the column
headings for the program results.
The last section of the program, starting at line 06560, calculates the total
annual cost. This annual cost data is then searched by the computer to find the
minimum annual cost and therefore the optimum ITD. After the optimum ITD is
found the results are placed in the output file.
The remainder of the program consists of two subroutines used by the main
program. These subroutines, DATCHK and TBLUQ, are described in the next two
sections.
General Description of Subroutine "DATCHK"
The purpose of this subroutine is to check if the correct number of values of
data have been read into the main program. This check is accomplished by testing
to see if the data check number, 1 .OE50, is in its proper place within the data file.
Data check numbers can be found on lines 00180, 00340, 00500, and 00660
in the turbine data file TURBIN and on line 250 in the site data file. After the
data preceding the data check number is read into the program, subroutine DATCHK
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is called and it tests to see if 1 .OE50 is in its proper place. If there are some data
missing or if there are extra data within the file, the subroutine will read some other
number than 1 .OE50. Thus, not finding the data check number it prints out an error
message, indicating that the data has an incorrect number of values. The message
printed out by the computer is the name of the data file it is reading and also the
line of data that it read instead of the data check number.
After the message is printed out, the data file is reread by the subroutine to
find the data check number. After finding this number, the data file has been
placed in the proper position so that the remaining data can be read without the
error being carried through the file.
General Description of Subroutine "TBLUQ"
This routine is used to interpolate values from tables created by the program
or tables entered in data statements. It uses the method of determinant solution of
two second order equations.
The first variable in the call is a reference to the first column of the table,
which is specified as the second argument. The subroutine first determines whether
the requested value lies within the limits of the specified table column. If it does,
processing proceeds to the table search.
If the specified value is outside the column entry the program determines
whether it is above or below the table and sets indicators to extrapolate from the
appropriate end of the table. A return error flag is set and control is transferred to
the interpolation calculation.
The table search looks for successive elements of the reference column whose
values lie on either side of the requested value. Should an entry in the reference
column exactly equal the requested value, the corresponding entry from the look-up
column, the third argument, is returned as the subroutine value. Otherwise the
table search finds two bracketing values and checks whether they are the firstvalues
in the table. If they are, they are used in conjunction with the third variable for
interpolation. If they are not the first values, the bracketing values together with
the table entry preceding them are used for interpolation.
Description of Data File "TURBIN"
This external input file contains the data pertaining to the turbine perform-
ance for varying back pressures for program OPTDCT. Sample data for the fossil-
fueled and nuclear-fueled turbines are in Tables 5-B and 6-B of Appendix B.
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The first section of the data file TURBIN, starts with the nameplate capacity
of the generator (kw) and the type of fuel, specified as either FOSSIL or NUCLEAR.
Line 00110 is the nominal heat rejection of the turbine in thousands of Btu per hour.
Line 00120 contains the minimum and maximum values of back pressure (inches Hg)
at which the turbine is allowed to operate.
The next section, starting with line 00130, contains the 35 values of full
throttle generation (kw). These values correspond to back pressures from 1 .0 inch
Hg to 18.0 inches Hg in 0.5 inch increments. This set of data is followed by the
data check number on line 00180.
The next three sections, starting with lines 00190, 00350, and 00510 con-
stitute the main body of the file. These sections correspond to the turbine operating
conditions of full throttle, 3/4 load and 1/2 load, respectively. Each section ends
with the data check number 1 .OE50. This enables the program to check for the cor-
rect number of values.
Each section contains three sets, 35 values each of turbine heat rates (Btu/
kwh), plant heat rates (Btu/kwh), and heat rejection (10^ Btu/hr) at various back
pressures. The back pressures correspond to the array of back pressures set up in the
main program .
Description of Data File "SITEXX" (1)
The SITEXX data file contains the data for each location that the economic
optimization program analyzes. Each file consists of 16 lines of data, the last line
of data being the data check number. A sample of a site data file is shown in Table
7-B of Appendix B.
The first three lines of data include the site name, elevation and the season
of peak electrical demands. The name of the site has been limited to thirty charac-
ters. The elevation is in feet above sea level and the period of peak demand is
either summer or winter.
The next line of data, line 130, includes the number of base plant fuel costs
to be used in the analysis followed by the fuel costs in cents per million Btu. The
program is presently set up to take a maximum of three such fuel costs, but this
number can be increased by changing the array dimension.
Line 140 includes the number of fixed-charge rates to be used in the anal-
ysis followed by the fixed-charge rates. This line of data has been set for a maxi-
mum of five fixed-charge rates. It can be increased in the same manner as the
number of fuel costs. These values are entered as percentages.
(1) Where SITEXX is a file name of SITE01, SITE02, through SITE 27.
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The next two lines, 150 and 160, are the capital cost multiplier and the
capital cost of the peaking unit in dollars per kw respectively.
Line 170 contains the fixed-charge rates applicable to the peaking unit.
The same number of values are entered on this line as are entered on line 140.
These values are also entered as percentages.
The next four lines of data contain the peaking unit fuel costs in cents per
million Btu (line 180), the cutoff temperature for peaking generation in °F(line 190),
the capital cost of providing auxiliary power requirements in dollars per kw (line
200) and the operating and maintenance cost as a percentage of the capital cost (line
210). The number of peaking unit fuel costs corresponds to the number of base plant
fuel costs.
The next three lines of data (220, 230, 240) contain the 32 values of tem-
perature durations. These values are the percent of time during a year that the
corresponding air temperatures are expected to occur. The air temperatures corres-
pond to the array of air temperatures which are created in the main program.
The last line (250) contains the data check number 1 .OE50.
Format of External Data Files
Data input files TURBIN and SITEXX are desequenced files. These files can-
not have line numbers. The program reads each line starting with the first character.
The data files shown in Appendix B have line numbers. These are used only to enter
the data files in the computer and are used, in this case, only as reference numbers.
Once the files are entered in the computer they are desequenced.
Output Data File
Output file OPTOUT will contain the results of the computer runs. This file
must be created before the runs are made. To obtain the results from this file, list
file OPTOUT.
Operating Instructions for "OPTDCT"
Before running the computer program there are several items that need to be
checked to see if the data corresponds to the turbine and cooling system being ana-
lyzed. The items that need to be checked are:
1 . Auxiliary data
2. Capital cost data
3. Type of tower
4. Turbine data
5. Tower characteristics equations
6. Capital cost multipliers
7. Capital cost of auxiliary power requirements
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The auxiliary power requirements data should correspond to the type of cool-
ing tower (natural or mechanical draft) and the type of fuel (fossil or nuclear). The
auxiliary power requirements for each of the towers and turbine units are shown in
Tables 1-B and 2-B of Appendix B. These values correspond to ITD's of 30°F through
80°F in 10° increments. The values of auxiliary power requirements for a mechani-
cal-draft tower are entered on line 00360 and the values for a natural-draft tower
are entered on line 00440.
The mechanical-draft cooling tower data are entered in the following form
using data for a fossil-fueled unit:
DATA AUX100/32000. ,26000. ,21000., 17000., 14000., 12000./
The natural-draft cooling tower data are entered in the following form, again
using data for a fossil-fueled unit:
DATA KWAX/12000.,9000.,7000.,6000.,5000.,4000./
The auxiliary data (AUXTMP) on lines 00380, 00400, and 00420 do not
change. The values in the program listing (Appendix A) are generalized due to their
proprietary nature. Contact the manufacturer for specific information. These values
represent the air temperatures associated with the minimum (53%) and maximum
(100%) proportion of full auxiliary power requirements corresponding to ITD values
of 30°F to 80° F in 10 increments for a mechanical-draft tower. They also corres-
pond to full throttle, 3/4 load and 1/2 load operations of the turbine.
The capital cost data, shown in Tables 1-B and 2-B of Appendix B, corres-
pond to the type of turbine and also to the type of cooling system. Depending upon
the type of tower and turbine being analyzed the corresponding capital cost must be
used. The data are entered on lines 00960, 00980, 01000, and 01020 in the follow-
ing form:
DATA CAPCST/32610000.,22880000., 17200000., 14090000.,
+12040000.,10280000.,36150000.,24430000.,18220000.,
+14700000.,12500000.,10600000.,40500000.,26850000.,
+19770000.,15740000.,13260000.,11100000./
The data for sea level elevation is entered first, followed by the data for
elevation of 3,000 feet and 6,000 feet. These data represent three curves of capital
cost versus ITD for the three elevations.
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The type of tower being anal/zed is entered on line 01060 in the following
forms:
DATA TOWER/SHNATURALb, SHDRAFTbbb/
or
DATATOWER/8HMECHANIC,8HALbDRAFT/
These data are used later in the program in the output as well as in directing
the program to the auxiliary calculations that are associated with the type of tower
being analyzed.
The data file, TURBIN, containing the turbine data, corresponds to the type
of turbine that is being analyzed, either a fossil- or nuclear-fueled unit. These
data, along with the tower data determine rhe type of analysis that will be made.
The remaining data used in the calculations corresponds to these two sets of data.
The last item to be checked in the main program is the exponent in the tower
operating characteristics equations. The exponent must correspond to the type of
tower being used. The value of the exponent is 0.75 for natural draft and 0.91 for
mechanical draft. The three equations involving the exponent change are on lines
03680, 04140, and 04760. These equations are as follows for a natural-draft tower:
03680 A = THETA/HREJD**.75
04140 110 SATT = AIRT(NT) + A*HRJ**.75
04760 HREJMX = (PLITD*A)**(1 ./.75)
The last two items to be checked are in the site data. The first is the capital
cost multiplier and the second is the auxiliary capital cost.
The capital cost multiplier is to allow for variations in construction costs due
to local conditions. In areas subject to hurricane winds the construction cost will be
greater due to the requirement for stronger structures to resist the forces of these
winds. Therefore, a capital cost multiplier is used to provide for the resulting in-
crease in costs. The adjustment for hurricane winds is applied only to the analysis
of a natural-draft tower. The mechanical-draft towers are not sufficiently affected
by the high velocity winds to warrant an increase in the multiplier above the normal
construction cost index for that particular area.
The last item to be checked is the capital cost of auxiliary power. This
value depends on the type of unit (fossil- or nuclear-fueled). The capital cost of
auxiliary power is assumed to be $150/kw for a fossil-fueled unit and is assumed to
be $225/kw for a nuclear-fueled unit.
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After checking the above listed items, the program is ready to be run.
Each time that a different tower or turbine is used, the above checks must be re-
peated to insure that the correct data is in the program.
"OPTDCT" Flow Chart Description (1)
1 . Dimension variables for tables, temporary storage, etc. Define constants
and tables which are not dependent on the site or type of turbine.
Constants: Tables;
OPHRS AUXlOOvs. TBLITD
HRSPYR AUXTMPvs. TBLITD vs. PCTLOD
ASTER KWAX vs. TBLITD
TOWER P vs. T
SITE NO PCTTIMvs. PCTLD
CAPCST vs. TBLITD vs. TBLELV
Define ambient air temperatures for table of ambient air temperature vs.
annual duration, in percent, of that temperature (±2°F). AIRT ranges
from 117°F down to -38°F in steps of 5°F.
Define turbine exhaust pressures to associate with values at turbine heat
rate, plant heat rate, heat rejected by turbine, and full throttle kw which
are read from the turbine file. BP (back pressure) values range from 1 .0
inch Hg to 18.0 inches Hg in steps of 0.5 inch Hg.
2. Read the characteristics of the turbine used. This includes the rated kw,
whether fossil or nuclear, the design heat rejection and the minimum and
maximum back pressure allowable for operating the turbine. Also included
are values for tables of back pressure vs. full throttle kw, and values for
full throttle, 75% load and 50% load for tables of back pressure vs. net
heat rate, gross heat rate and heat rejection.
3. In several specific places the number 1 .OE50 must be.put into the data file.
A subroutine DATCHK is called to check that these numbers are In the
correct place in the data file. If they are not in the correct place, there
are too many or too few values in the data file. In this case the subroutine
prints an error message indicating the data file and the location in the file
where the error occurred.
(1) Numbers on these pages correspond to numbers
on the flow chart blocks in Appendix D.
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4. The nominal annual mwh is the amount which could be produced if
operated at the given conditions of load and amount of time specified for
that load.
5. Start a loop to cycle through each of the different sites printing a complete
set of output for each.
6. Read the information from the appropriate site file. This should include all
information that might change for different locations. Included is the name
of the site, the elevation, whether winter or summer peak, the fuel costs,
fixed-charge rates, capital cost multiplier, cutoff temperature for peak
generation, operation and maintenance percentage, and the duration in
percent of a year associated with each of the temperatures in AIRT.
7. Set an indicator for applicable winter or summer peaking period.
8. Find the first and last non-zero temperature durations and set a pointer to
each so that later processing can be confined to meaningful values.
9. Call the subroutine DATCHK while reading the site file to verify that the
right number of values are on the file.
10. Output information which identifies the site being processed, the type of
turbine, the type of dry cooling tower, the turbine operating hours per
year and the three combinations of percent time at a given percent load
which describe the annual demand on the turbine. All output except for
error message is done indirectly; i .e., it is written onto a data file during
the execution of the program and then the data file is tested after the pro-
gram is finished.
11.12. Compute several values for later use in interpolation of tables through the
13.14. use of subroutine TBLUQ. These include values of kw load for the maxi-
mum operating back pressure, kw load for the actual operating back pres-
sure, heat rejected by the turbine at the maximum operating back pressure,
the hours duration of the three highest temperatures, and the three highest
temperatures at that site. TBLUQ is a function subprogram that, given a
value in one column of a table, returns the corresponding value from the
second column of the table. If the given value is between values in the
table, a quadratic interpolation is done to arrive at the value to be re-
turned .
15. Find the air temperature which is equalled or exceeded 10 hours per year.
Use TBLUQ and the three valued table just computed of DUR vs. AIR.
11
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16. Set up a loop to perform the basic calculations with each ITD from 30°F to
80°F in 1 increments.
17. Convert the integer ITD into an equivalent real value THETA. The integer
I is the subscript which corresponds to each ITD. I ranges in value from 1
to 51 in increments of 1 .
18. Do two sets of table look-ups using TBLUQ to determine the capital cost of
the cooling system which is a function of both elevation and ITD. This
table is different for natural- and mechanical-draft towers and is deter-
mined outside of this program.
19. Multiply capital cost by capital cost multiplier.
20. The coefficient A must be calculated for each ITD. The given ITD and
design heat rejection are used to calculate A. Z is a given exponent and
is 0.75 for natural-draft towers and 0.91 for mechanical-draft towers.
Once A is computed this equation will give the ITD of a given tower for
all heat rejection values.
21 . Set up loop to cycle through each of the three loading conditions of per-
cent time vs. percent load.
22. Set up loop to cycle through each of the air temperatures between the
highest and lowest recorded at the given site.
23. Initialize iteration counter and two variables used for back pressures.
OPBP is initialized at BPMIN (minimum back pressure) because if the
operating BP is less than BPMIN it is possible to skip out of the loop be-
fore OPBT is computed. Skip to block 29 which calculates the heat re-
jected from the turbine.
24.- This group of blocks involves an iterative procedure to arrive at the actual
32. operating back pressure. Essentially what must be found is the intersection
of the turbine characteristic curve for the given load and the cooling tower
characteristic curve for the given air temperature. Both the turbine and
cooling tower curves are in terms of heat rejection vs. back pressure. The
turbine curve is arrived at from a table of values from the turbine data file
and the cooling tower curve is arrived at by using the equation Part Load
ITD = A x (Heat Rejection) , the ambient air temperature and the rela-
tion between saturation temperature and saturation pressure.
The solution is arrived at by first assuming a back pressure (the minimum
back pressure is used for a starting value). For this back pressure and the
given load the turbine will produce a certain amount of heat rejection.
12
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This heat rejection is used to calculate the part load ITD of the cooling
system. Adding the ambient air temperature and the ITD gives the satu-
rated steam temperature. This temperature corresponds to a saturated steam
pressure which is exhaust back pressure of the turbine. If the preceding
back pressure and the newly derived back pressure are within 0.01 inch Hg
of each other then that is the back pressure which is used in the analysis.
If the two values differ by more than 0.01 inch Hg then the newly calcu-
lated back pressure is used as the starting point of the calculation. If after
15 iterations a solution has not been found, an error message is printed, the
last back pressure calculated is used and processing continues.
33.34. If the calculated back pressure is less than the minimum, make it equal to
the minimum.
35. In order to calculate energy requirements, it is necessary to calculate the
total number of hours of the year that the plant runs at the given load and
air temperature.
36. Check to see if the calculated back pressure is greater than the maximum
allowed for the turbine and if so, the turbine output must be decreased to
an allowable level. Transfer to block 39 to do this.
37. For the computer back pressure, find the maximum possible output in kw of
the turbine.
38. Compare the maximum possible output with that required and use the
smaller as the actual turbine output. Skip to block 41 .
39. If the calculated back pressure exceeds the maximum, then plant output is
limited by the amount of heat the cooling system can reject at the maxi-
mum back pressure. Calculate this heat rejection by using the maximum
back pressure to arrive at a corresponding saturation temperature; this tem-
perature minus the air temperature gives the maximum part load ITD which
is possible; from this part load ITD the corresponding heat rejection can be
determined using the equation:
Heat Rejection
(\(1/Z)
Part Load ITD i
* /
40. By doing a table look-up (with TBLUQ) in a table of heat rejection vs.
load at the maximum back pressure and using the calculated heat rejec-
tion as one value in the table, the maximum turbine output can be found.
13
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41 . The station heat rate may now be found from the table of station heat rate
vs. back pressure vs. load, by four calls to TBLUQ - three calls to build a
table of load vs. station heat rate for a constant back pressure and another
call to find the station heat rate for given load.
42. Calculate and accumulate the total annual fuel requirement (Btu). The Btu
requirements for each load and temperature combination are calculated
from the station heat rate multiplied by the total hours for that condition,
and then added to the previous subtotal.
43. The next few blocks calculate the auxiliary power and energy requirements.
These steps differ depending on whether the tower is natural or mechanical
draft. This block tests to see if the tower is natural draft and skips to 47 if
it is.
44. The maximum auxiliary power requirement for each ITD is found by inter-
polating a table of auxiliary power requirements vs. ITD
45. A linear interpolation of another table gives the percent of maximum auxil-
iary power requirement used for a given air temperature, ITD and load.
46. Compute the annual auxiliary kwh for mechanical draft by applying the
above percentage to the product of the maximum auxiliary power require-
ment computed in block 44 and the number of hours per year at this condi-
tion. Skip to block 49.
47. Determine the auxiliary power requirements for the nature I-draft tower by
a call to TBLUQ using the ITD given and the table of ITD vs. KWAX.
48. Compute the auxiliary energy requirements by multiplying the auxiliary
power requirements by the number of hours at the given conditions.
49. Calculate and accumulate the total energy produced by the turbine. The
energy produced at the given conditions is computed by multiplying the kw
produced by the turbine times the number of hours at the given conditions.
50. If, at full throttle, the amount produced by the turbine is different than
the nameplate capacity, then a gain or loss of capacity and energy must
be computed.
51 .55. If there is a net gain, calculate that gain in kwh and Btu. The kwh gain
is calculated by taking the difference between the actual amount produced
and the amount required, times the number of hours at the given conditions.
The associated Btu requirement is computed by taking the kwh gain times
14
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the calculated station heat rate. A gain may only occur if the demand is
100% of nameplate and the turbine can produce more than that amount.
Skip to block 56.
52. If there is a loss, check whether the air temperature is above or below the
cutoff temperature.
53. If below the cutoff temperature, calculate the energy (kwh x hrs) and store
in KWHBLO. Skip to block 57.
54. If above the cutoff temperature, calculate the energy and store in KWHABV.
56. If processing one of the three highest temperatures, save the amount of
power loss or gain for later interpolation.
57.58. Go to next lower temperature and its duration, until all non-zero durations
have been used, then go back to block 23.
59.60. After making the calculations for all temperatures for a given load go to
the net load condition until calculations have been made for all load con-
ditions.
61 . The total energy produced in a year has now been calculated for the plant.
Save this value for each ITD.
62. Determine the capacity loss which occurs at the air temperature equalled
or exceeded 10 hours per year by interpolation of a table of the three
highest air temperatures and the corresponding kw losses or gains for those
temperatures.
63.64. All values which vary with ITD, for a given site and ITD, have now been
calculated and stored in arrays. Calculate the same values for the next
higher ITD until values have been computed for all ITD values up to and
including 80°F.
65. Set up counter to calculate annual costs using each of the fuel costs. Up
to three fuel costs may be used for each site.
66. Set up another counter to calculate the annual costs for each of the five
different fixed-charge rates.
67. Write the headings on the output file for the page of outputs. Along with
the column headings, the capital cost factors, the fuel costs, and the
capital costs per kw for peaking and auxiliary power are outputted in order
to identify the case being run.
15
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68.69. Set up loop to calculate and output annual costs and intermediate results
for each ITD.
70. The annual cost which is associated with the capital cost of the cooling
system is equal to the capital cost multiplied by the fixed-charge rate.
71 . Calculate the operation and maintenance cost of the cooling system (which
is a percentage of the total capital cost) and add this cost to the total
annual cost.
72. Compute the total annual cost of fuel by taking total annual Btu times the
fuel cost per million Btu.
73.74. Check whether peak is in winter or summer. For a summer peak compute
75. the capital cost of replacing the lost capacity and a cost for the energy
lost. For a winter peak, compute only the penalty for the lost energy since
the peak system demand would not occur during the months when the capa-
city losses would occur. The capital cost of replacement capacity is com-
puted as the capacity loss which occurs at the air temperature equalled or
exceeded 10 hours per year times a cost in $/kw for peaking power to re-
place it, plus an operation and maintenance cost assumed as a $1 .20 per
kw loss.
The operating cost is determined by multiplying the energy lost by the
appropriate heat rate and the appropriate fuel cost. This cost is divided
into two parts, operating cost associated with energy lost above the cutoff
temperature and operating cost associated with energy lost below the cut-
off temperature. Above the cutoff temperature the lost energy was re-
placed by a peaking unit; thus a higher heat rate and a higher fuel cost
was used. Below the cutoff temperature the lost energy was assumed to be
replaced by another large base load unit; thus the base load unit heat rate
and fuel cost were used .
76. Add the capital and operating costs for the penalty to get the total penalty
cost.
77. Add the kwh below the cutoff temperature to the kwh above the cutoff
temperature to get the total energy loss.
78. Capital cost of auxiliary power is computed by taking the maximum auxil-
iary power required times the $Aw cost of auxiliary power. The operating
cost of the auxiliaries is the auxiliary energy in kwh times the average
plant fuel cost in mills/kwh plus an operation and maintenance cost. The
total annual cost of the auxiliary power and energy is the sum of the
capital cost times a fixed-charge rate plus the operating cost.
16
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79. The annual cost of the cooling system is the summation of: annual capital
cost of the cooling system including an operation and maintenance charge,
the annual cost of the total plant fuel, the annual cost of replacing capa-
city and energy losses due to high turbine back pressure, the annual cost of
auxiliary power and energy, and the credit given for the generation of ex-
cess energy.
78.79. The optimum total annual cost is to be flagged in each case. Therefore, a
test must be made to save the lowest total annual cost and test with the
next one calculated. The ITD of the optimum value is also saved.
82. For each ITD the following values are saved on a temporary file for later
output:
a. ITD
b. Actual mwh produced
c. Credit energy in mwh
d. Penalty energy in mwh
e. Auxiliary energy in mwh
f. Capacity lost in kw
g. Auxiliary power in kw
h. Annual capital and operation and maintenance
cost of the dry cooling system
i. Annual cost of total plant fuel
j. Amount credited due to excess energy
k. Cost of replacing capacity and energy cost
I. Cost of auxiliaries
m. Total annual dollar cost
n. Total annual cost in mills/kwh
81 .82. Go back to block 68 and process with next ITD until ITD = 80°F; then
continue on.
85. Copy the temporary data file onto the permanent output file and look for
the ITD with the minimum annual cost. Before copying the line of data
associated with the optimum ITD, write the word "OPTIMUM" to indicate
that the next line is the optimum condition.
86.87. Calculate a whole new set of output values with a different fixed-charge
rate until all five fixed-charge rates have been used.
88.89. Calculate another set of five pages of output using the second set of fuel
costs, and the final set using the last set of fuel costs. This means that
there will be fifteen combinations of fixed-charge rates and fuel costs for
each site.
17
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90.91 . Now that all information for one site has been written onto the output file
go back and do the same thing with the next site until all 27 sites have
been processed. Once the program execution is finished the output file is
listed to obtain a printed copy of the printout.
TOWER OPTIMIZATION PROGRAM "TOWSIZ"
Program TOWSIZ computes the physical dimensions of a natural-draft dry-
type cooling tower and evaluates the capital cost of constructing the tower.
Six basic design parameters are required by the program as input. These
values are the ITD, range, heat refection, water flow, ambient air temperature and
elevation. Using these parameters, the program evaluates a number of intermediate
variables which contribute to the computation of the tower size (height, top dia-
mefer and bottom diameter).
After sizing the tower the program evaluates the capital cost of the cooling
system. The capital cost is divided into the areas of tower structure, condenser,
piping and valves and controls. The tower structure cost is the make-up of stack,
shed and coil costs. Piping and valves includes the cost for piping, valves, circu-
lating water pumps, cooling system filler pump and storage tank.
Within the subheading of structure costs, the dollar value of the tower it-
self is found by interpolation between curves for three evaluated tower diameters.
The shed cost is evaluated from the area difference between the base diameter and
top diameter charged at $7.60 per square foot. Coil cost is evaluated at $14,500
per coi I.
Condenser cost is arrived at from a table of cost vs. heat rejection.
The costs of piping, valves, pumps, and storage tanks are computed in sub-
routine TWRPIP. They are developed by computing the water flow needed to refect
the amount of heat produced by the plant at its design point. From the GPM re-
quired, the pipe and valve sizes and quantity of each are determined. The number
of pumps to handle the flow is figured and the required storage capacity is calcu-
lated. From cost tables in the subroutine, the costs of the atx>ve items are figured
and then summed. $500,000 is included for controls.
Description of Program "TOWSIZ"
The first section of the program ending at line 02380 contains declaration,
data and comments statements. The data within this section do not change.
18
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Beginning at line 02400, the intermediate results for determining the tower
size is computed. After the intermediate results are calculated, the actual physical
size of the tower is computed. Results are the tower height, upper diameter, bottom
diameter and the water flow rate .
The next section beginning at line 03340 calculates the capital cost of the
cooling system. The stack, shed, and coil costs are calculated. These constitute
the structure costs. Then the condenser cost is calculated beginning at line 03540.
Line 03620 is the statement which calls routine TWRPI P. This routine cal-
culates the costs of pipes, valves, circulating water pumps, filler pumps and storage
tank costs.
The section beginning on line 03640 and ending on line 04140 prints out the
results of the tower sizing program. A sample of the printout is shown in AppendixC.
Each line of data in data file SIZDAT will result in a size and cost analysis of a
cooling system for the specified data.
Description of Subroutine "TBLUQ"
This subroutine is identical to the one in the economic optimization pro-
gram. See prior description beginning on page 8.
General Description of Subroutine "TWRPIP"
This routine is used to calculate the cost of piping, valves, pumps, and
storage facilities. This routine uses subroutine PIPSIZ to calculate the size of pipes
and valves.
Once the sizes of the pipe and valves are determined, subroutine TWRPI P
calculates the quantity of each that is required and their costs. After calculating
all the piping and valve costs, the pumping requirements are calculated. After
arriving at the pumping costs, the cost of water storage facilities are calculated.
These costs of piping, valves, pumps and storage are then summed and
added to the other cooling system costs.
General Description of Subroutine "PiPSIZ"
This routine calculates the size of the pipe required for a given water flow
rate. After the pipe size is calculated, the corresponding pipe and valve costs are
determined from a table of pipe and valve costs.
-------
Description of Data File "SIZDAT"
This external data file is used by program TOWSIZ. A sample is shown in
Appendix B. There are six values on each line. The first value is the initial tem-
perature difference followed by water cooling range, heat rejection, water flow,
ambient air temperature and elevation. Each line of the file has corresponding data.
There is no maximum limit set on the number of lines of data within the file.
This data file is a desequenced file. The file is created with line numbers.
When it is entered into the computer it is desequenced. The file is read line by line
until the last line of data is read. On completion of reading the last line, the exe-
cution of the program is terminated.
Output Data
A sample of the output data is shown in Appendix C. The listing shows in-
put data for the particular run, the physical dimensions of the cooling tower and its
costs, the condenser cost, piping facilities cost, the cost of controls and the total
cooling system cost, including contingencies.
Operating Instruction for "TOWSIZ"
The program is ready to run once it and the data file SIZDAT are in the
computer. Check to make sure the data file has been desequenced.
"TOWSIZ" Flow Chart Description (1)
1 .01 Data statements are used in the program to define data tables in the pro-
gram which will be used to perform interpolation for various computations.
Included are tables of stack diameter, stack height, stack cost, tempera-
ture ranges, ambient air temperature height adjustment factors, altitudes,
altitude height adjustment factors, air flow, heat rejection, pressure drop
across the coil and water flow.
1 .02 Values of entered heat rejection and pressure drop tables are scaled to
proper dimensions for program use.
1.04 The input variables, initial temperature difference, range, heat rejection,
Go , ambient air temperature and elevation, are read for one case from
one line of the data file named "SIZDAT".
(1) Numbers on these pages correspond to the
numbers on flow chart blocks.
20
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1 .05 The number of cooling columns is calculated by dividing condenser flow by
Go . A temporary variable is then set to the remainder of the number of
coils divided by four. If the remainder is zero the calculated number of
coils is used. If it is not zero the number of coils is increased to the next
number evenly divisible by four. This action is taken to ensure the number
of deltas, which is one half the number of columns will be an even number.
1 .06 Seven curves of heat rejection versus air flow have been entered for seven
different values of water flow. The program compares the entered value of
water flow with the acceptable values corresponding to the curves. If no
match is found an error message is printed in block 1 .07. A match branches
to block 1 .10.
1 .07 The following message is printed: Go = XXXXX NO CORRESPONDING
CURVE. Case aborted.
1 .08 If there is still data in the input file, the program initiates the new case.
When no data is left, the program terminates.
1.10 Subroutine TBLUQ is called . If the error flag for data outside tables is set
in the subroutine, the main program will branch to block 1.11. A normal
subroutine execution will lead to block 1 .12.
1.11 The following message is printed: Lo OUTSIDE TABLE. Processing con-
tinues.
1.12 Pressure drop across the coil is found using air flow looking into air flow
and pressure drop tables.
1 .13, Velocities and losses are calculated.
1.14,
1 .15
1.16 Ambient air temperature is used to reference a table of temperatures and
adjustment factors; the reference temperature of 50.0° is used in the same
way; the site elevation references a table of elevations and adjustment
factors. The result of these calls to TBLUQ is a set of factors which are
used to adjust the tower draft height according to varying air densities at
temperatures other than 50.0° and elevations other than sea level.
1.17 Apply the factors from block 1 .16 to calculate adjusted draft height and
add 80.0 feet to obtain total tower height.
1.18 The final air temperature is used to find an adjustment factor for the tower
upper area.
21
-------
1.19 Compute the tower upper area and diameter and lower diameter.
1 .20 Test to find if lower diameter is less than upper diameter. If not, go to
1 .22, otherwise go to 1 .21 .
1 .21 Set lower diameter equal to upper diameter. Continue at 1 .22.
1 .22 The program finds two successive entries in a table of stack diameters which
bracket the calculated upper diameter. When these are found, go to step
1 .24. If no such entries are found, move to 1 .23.
1 .23 The following error message is printed: UPPER DIAMETER XXXX OUTSIDE
OF TABLES. Control is sent to block 1 .08.
1 .24 Routine TBLUQ is called twice, once for each of the two diameters found
in step 1 .22, using the total calculated tower height to find a tower cost
for each of the two diameters.
1 .25 The calculated upper diameter is used to perform a linear interpolation be-
tween the calculated costs from step 1.24.
1 .26 The roof cost is calculated as the difference between the cross-sectional
areas of the top and bottom stack diameters times $7.60 per square foot.
1 .27 Basic condenser costs are provided to the program in a table of water cool-
ing range vs. condenser cost in dollars per 10" Btu per hour. The range is
used through TBLUQ to find a basic condenser cost which is multiplied by
the heat rejection in 109 Btu per hour to get total condenser cost.
1 .28 The number of deltas is one half the number of cooling columns.
1 .29 Call Subroutine TWRPIP to compute all piping and associated costs.
1 .30 Print out summary for sizing and cost evaluation.
Subroutine "TBLUQ" Flow Chart Description
2.01 Checks to see if value is within the given table of values.
2.02 If value is not in table it checks to see if the value is less than the smallest
value in the table.
2.03 If value is less than the smallest value then it uses the first three values to
extrapolate for the desired value.
22
-------
2.04 If value is not in the table it checks to see if the value is greater than the
largest table value.
2.05 If value is greater than the largest table value then it uses the last three
table values to extrapolate.
2.06 Sets an error flag for any value outside the table.
2.07 Checks to see if value is equal to a table entry.
2.08 If value equals table value then it returns corresponding entry.
2.09, Checks for exact location in the table.
2.10
2.11, Uses three table entries to evaluate the value being looked up. If value is
2.12, between the first and second table entry then it uses the first three entries
2.13, for the evaluations. If value is between last two table entries it uses last
2.14 three table entries. Anywhere else in the table it uses the two table values
preceding and the one following the value.
2.15 Value is evaluated for from appropriate table values and returned to pro-
gram .
Subroutine "TWRPIP" Flow Chart Description
3.01 Calculate the water flow rate required for the transfer of the heat produced
by the turbine. This flow rate establishes the size and number of supply
lines required to pipe the water to the cooling tower.
3.02, Subroutine "PIPSIZ" is called to calculate the diameters of the pipe and
3.05, also pick the corresponding pipe and valve costs from a table of pipe and
3.09, valve costs.
3.12,
3.16
3.03, Calculate the quantity of pipe and valves required and the cost.
3.06,
3.10,
3.13,
3.17
3.04 Calculate the water flow rate for the header lines.
3.07 Calculate the number of cooling deltas per tower sector.
23
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3.08 Calculate the water flow rate for the sector drain pipe.
3.11 Calculate the water flow rate for the filler water pipes.
3.14 Calculate the number of bypass valves and their cost.
3.15 Calculate the water flow rate for the emergency drain pipe.
3.18 Calculate the number of circulating water pump setups and their cost.
3.19 Calculate the cost of filler pumps.
3.20 Calculate storage tank costs from a curve of gpm vs. tank cost.
3.21 Sum up the costs of piping, valves, pumps and storage tanks.
Subroutine "PIPSIZ" Flow Chart Description
4.01 Calculate the pipe size from the water flow rate.
4.02 Check to see if the diameter is less than or equal to the maximum size in
the table of pipe size vs. cost. If it is less than or equal to the maximum,
the program proceeds to 4.04.
4.03 If diameter is greater than maximum, add on another line and proceed to
4.01.
4.04 Find corresponding pipe and valve cost from table of pipe size vs. pipe
and valve cost.
24
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APPENDIX A
PROGRAM LISTINGS
25
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ECONOMIC OPTIMIZATION PROGRAM "OPTDCT"
00100 PROGRAM OPTDCT(OUTPUT*TAPE 1,TAPE2*TAPE3*TAPE4)
00120 REAL KW*KWH*NHR*KWL0SC3)*KWHABV<51)*KWHBLO(51)
00140 REAL T0TCAPC51)*CRDBTUC51)*T0TBTUC51)*SITEN0C27)
00160 REAL KWL0SSC51)*DURC3)*KWHL0S,CCFGTC5)
00180 REAL MILPKW*MWHC51)*L0ADC3)*HREJTC3)
00200 REAL PCTL0DC3)*TBLITDC6)*AUXKWHC51)
00220 REAL AUXKWC51)*L0AD 1C3)
00240 REAL KWHGAN(51)*TEMPC3)*KWAX(6)
00260 DIMENSION PC 56)*TC56)*AIRTC32)*TDURC32),SI TEC 5),FULCSTC3)
00280 DIMENSION BPC35)*FTKWC35)*GHRC35*3)*HREJC35,3)*CCFC5)*AUXTEMC2)
00300 DIMENSION PCTTIMC3)*PCTLDC3)*PFCSTC3)*TBLELVC3),CAPCSTC6,3)
00320 DIMENSION TOWERC2),AUX1OOC6),AUXTMPC2,6,3)*BC3)*AIRC3)
00340** AUXILIARY DATA CORRESPONDS TO FOSSIL OR NUCLEAR FUELED UNIT
00360 DATA AUX100 /4ROOO.* 39000.* 32000.* 26000.* 22000.* 18000./
00380 DATA AUXTMP /55.,65.* 45.* 55.* 30.* 45.* 15.* 35.* 5.* 25.* - 20.* 15.*
00400+ 60.*70.*50.*60.*45.*55.*35.*45.*25.*40.* 15.*30»*
00420+ 70.*75.*65.*75.*55.*65.*50«,60.,40.,55.,30.*50./
00440 DATA KWAX / 1 9000.* 14000.* 1 1000«* 9000.* 8000.* 7000./
00460 DATA SITENO / 6HSITEO1 *6HSITEOP*6HSITE03*6HSITE04,6HSITE05*
00480+ 6HSITE06*6HSITE07*6HSITE08* 6HSITE09*6HSITE10*6HSITE11*
00500+ 6HSITE12*6HSITE13,6HSITE14*6HSITE15*6HSITE16*6HSITE17,
00520+ 6HSITE18*6HSITE19*6HSITE20*6HSITE21*6HSITE22*6HSITE23*
00540+ 6HSITE24*6HSITE?5*6HSITE?6*6HSITE27 /
00560** STEAM TABLE DATA CSATURATION TEMPERATURES AND PRESSURES)
00580 DATA P / . 2* . 3* . 4, . 5* . 6* . 7* . 8* • 9* 1 . 0* 1. 1 , 1 . 2, 1 • 3, 1. 4, 1 . 5*
00600+ 1.6* 1.7* 1.8* 1.9,2.0*2. 1, 2. 2* 2.3*2.4,2.5,2.6*2.7*2.8*2.9*
00620+ 3.0*4.*5.*6.*7.*8.*9»* 10., 11•* 12., 13.* 14.,15., 16., 17., 18.*
00640+ 19.*20.*21.*22.*23.*24.*25.,26.*27.,28.,29.,29.921 /
00660 DATA T / 34.57*44.96*52.64,58.80,63.96*68.41*72.32*75.84*79.03*
00680+
00700+
00720+
00740+
00760+
00780+
00800
00820
00840
00860
00880
00900
00920
14, 182.05, 184.82* 187.45*
09,203. 08,205. 00*206.87*
81. 96* 84. 6 4* 87. 17* 8°. 5 1*^1. 72* 93. 8 1,95. 78, 97. 65, 99. 43,
101. 14, 102.77* 104. 33* 105.85* 107.30* 108. 71* 1 10.06* 1 1 1 .37*
1 12.63* 1 13.36* 1 15.06* 125.43, 133. 76* 140. 78* 146.86* 1 52.24, 157.09*
161. 49* 165.54* 169.28* 172. 78, 1 76.05* 1 79
189. 9 6* 192. 37* 194. 68* 196*90* 199. 03*201
208.67*210.43*212.00 /
DATA PCTTIM / 50.*50»*0. /
PCTLD / 100«*75.*50. /
PCTL0D / 100»*75.*50. /
0PHRS / 7500. /
HRSPYR / 8760. /
ASTER / 2H** /
T8LITD / 30. * 40. * 50. * 60. * 70. * 80. /
00940** CAPITAL C0ST DATA FOR VARIOUS ITD'S AND ELEVATIONS
00960 DATA CAPCST/ 50000000. * 36080000. * 269200CO .* 2 1 530000. * 1 7720000.*
00980+ 1587 0000., 54800000.* 37840000. * 282 1 0000. * 22340000. * 22340000. *
0 1 000+ 18-1 60000.* 16 220000.* 60000000., 4 125 0000., 2989 0000., 23 6 70000.,
0 1020+19100000., 1 681 0000. /
01040 DATA TBLELV /O. * 3000. , 6000. /
01060 DATA TOWER/8MNATURAL ,8HDRAFT /
01080 CALL RETR (1,6H0PT0UT)
DATA
DATA
DATA
DATA
DATA
DATA
26
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01100** SET UP AIR TEMPERATURES IN ARRAY *AIRT*
0 1 120 D0 10 I = 1*32
01140 AIRTCI) = 122-1*5
01160 10 CONTINUE
01180** SET UP BACK PRESSURE ARRAY
01200 DO 15 I = 1*35
01220 BPCI) = CI+ N)/2.
01240 15 CONTINUE
01260** READ TURBINE DATA FR0M FILE *TURBIN*
01280 CALL RETR (2,6HTURBIN)
01300 READ (2,) KW,ITYPE,HREJD,6PMIN,BPMAX
01320 KWH = KW*0PHRS*(PCTTIMC1)*PCTLD(1)+PCTTIM(2)*PCTLD(2)+
01340+ PCTTIM(3)*PCTLD(3))/1.0E4
01360 TMWH = KWH/1000.
01380** READ FULL THROTTLE KW
01400 READ (2,) (FTKW(I),I=1,35)
01420 CALL DATCHK(2)
01440** READ NET HEAT RATE, GR0SS HEAT HATE, AND HEAT REJECTION FOR
01460** FULL THROTTLE, 75 0/0 L0AD, AND 50 0/0 LOAD
01480 D0 20 IL = 1,3
01500 READ (2,) (NHR,I = 1,35)
01520 READ (2,) (GHRCI,IL),I=1,35)
01540 READ (2,) (HREJ(I,IL>,!=1,35>
01560 CALL DATCHK(2)
01580 20 CONTINUE
01600** READ SITE DEPENDENT INFORMATION FROM FILE *SITE*
01620 DO 500 ISITE = 1,27
01640 CALL RETR ( 3, SI TENO ( I SI TE) )
01660** READ SITE NAME
01680 READ (3,30) SITE
01700 30 FORMAT (5A6>
01720** READ IN SITE ELEVATION
01740 READ (3,) ELEV
01760** READ IN WHETHER WINTER OR SUMMER PEAKING PERIOD
01780 READ C3,> PEAK
01800 IWSP = 0
01820 IF CPEAK.E0.6HWINTER) IWSP = 1
01840 IF CPEAK.EQ.6HSUMMER) IWSP = 2
01860 IF (IWSP.EG.0) PRINT,
01880+ *PEAKING PERIOD NOT 'SUMMER1 0R 'WINTER1*
01900** READ IN THE NUMBER OF DIFFERENT BASE FUEL COST AND THE
01920** VARIOUS BASE FUEL COST
01940 READ (3,) NFUL,(FULCST(I),I=1,NFUL)
01960** READ IN THE NUMBER OF DIFFERENT CAPITAL COST FACTORS AND THE
01980** VARIOUS CAPITAL COST FACTORS
02000 READ (3,) NCCF,(CCF(I),I=1,NCCF)
02020** READ IN CAPITAL COST MULTIPLIER
02040 READ (3,) CCM
02060** READ IN PEAKING CAPITAL COST
02080 READ (3,) PCCST
27
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02100** READ CAPITAL COST FACTORS FOR GAS TURBINE
02120 READ (3,) ( CCF 'GTC I ) , I = 1 ,NCCF )
02140** READ IN PEAKING FUEL COST
02160 READ (3,) (PFCST ( I ) , I - ! , Nr Jl.)
02180**READ IN CUTCFF TEMPERATURE FOR PEAK GENERATION
02200 READ (3,) CUTOFF
02220** READ IN COST/KW FOR AUXILIARIES
02240 READ (3,) CPKWAX
02260** READ IN OPERATION AND MAINTENANCE PERCENTAGE
02280 READ (3,) OAMCT
02300** READ IN TABLE 0F TEMPERATURE DURATIONS
02320 READ (3,) (TDURCI),I=1,32)
02340** FIND FIRST
JRE DURATIONS
D0
IF
32
33
D0
IF
35
• NE.0.0) G0 TO 33
0.0) NTU = NT
AND LA;.H ;\j.JN-7.;:/<'.
32 NT = 1,32
(TDUR(NT)
CONTINUE
NTL = NT
35 NT = 1,32
(TDUR(NT).NE.
CONTINUE:
CALL DATCHK(3)
02520** WRITE OUT SITE IDENTIFYING DATA
02540 WRITE (1,360) SITE
360 FORMAT (//*SITE - *5A6)
WRITE (1,361) ELEV
361 FORMAT (*ELEVATI0N -*F5.0* FEET ABOVE SEA LEVEL*)
WRITE (1,362) PEAK
362 FORMAT(*PEAK PERIOD - *A6)
WRITE (1,364) KW,I TYPE
364 FORMAT (^TURBINE -*,F7.0,* K'.v *A7* UNIT*)
WRITE (1,365) 0PHRS,PCTTIM(1),(PCTLDd),PCTTIM(I),1=2,3)
365 FURMAT (* IN OPERATION -*F5.0* HRS/YR*/
* AT FULL THROTTLE*,F4.0* 0/0 0F THE TIME*
OF THE TIME*))
02360
02380
02400
02420
02440
02460
02480
02500
02560
02580
02600
02620
02640
02660
02680
02700
02720
02740+
GY -*r
.'H NOMINAL*)
02820
02840
02860
02880
*2A8)
02760+ 2(/* AT*F4.0* 0/0 LJAD*F5.0* 0/0
02780 WRITE (1,363) TMWH
02800 363 FORMAT (*TOTAL ANNUAL
WRITE (1,368) TOWER
368 FORMAT (*T0WER •
WRITE (1,931) OAMCT
931 FORM AT (* COOL ING
02900+F5.2* 0/0*)
02920 WRITE (1,366) HREJD,ASTER
02940 366 FORMAT (*DESIGN HEAT
WRITE (1,367) CCM
367 FORMAT (*CAPITAL
WRITE (],46R)CUTOFF
468 FORMAT(*CUT0FF TEMPERATURE FOR PEAKING GENERATION -*F4.0
F*)
SET UP VARIABLES USED IN CALCULATING OPERATING COSTS
02960
02980
03000
03020
03040+*
03060**
SYSTEM OPERATION AND MAINTENANCE COST -*
REJECTION -*,F5.0,* X 10*A2*6 BTU/HR*)
C3ST MULTIPLIER -*F5.2)
03080 L0AD(1)^TBLU0(BPMAX,BP,FTKW,35)
28
-------
KW*.75
KW*.50
= L0ADC2)
= L0AD(3)
= TBLUQCBPMAX*BP*HREJC1 * 1)* 35)
= TBLUOCBPMAX,8P,HREJC1, P), 35)
= TBLUOCSPMAX,BP»HREJC1, 3),3b)
T!>J,-XNTL)*HRSPY;;Y ICO.
'.)•}'> C 1 ) + T :J J; Cr-iTL-H ) - = :r :.';n\'.":/ ! r T'.
DURC 2) +TDUR CNTL + P) *HRSPYF =
L0AD1 <2>
LOAD1 (3)
HREJT( 1)
HREJT(P)
HREJTC3)
!j'JR( i ) -
DURC3) =
AIR(l) =
AIRC2) =
AIRC3) =
AIR10 = T
03600
03620
03640
03660
03680
03700
03720
03740
03760
03780
03800
03820
03840**
03860**
03880**
03900 A
03920**
03940**
03960**
03980**
04000 D0
04020
04040
04060
04080
TCTBTU(I) = 0.0
CRDBTUCI) =0.0
KWHBL0CI) = 0.0
KWHABVCI) = 0.0
KWHGANCI) = 0.0
AUXKWCI) = 0.0
AUXKWHCI) =0.0
KWH =0.0
IT = 0
KWL9SC1) = 0.
KWL0S(2) = 0.
KWL0SC3) = 0.
DETERMINE COEFFICIENT 0F "A"
EXPONENT "Z" CORRESPONDS T0
NATURAL DRAFT Z = .75 MECHANICAL DRAFT Z = .91
= THETA/HREJD**. 75
DETECT- !NE OPERATING BACK PRESSURE AS INTERSECTION 0F THE
CURVES 0F HEAT REJECTION VS. BACK PRESSURE F0R THE
TOWER AT A GIVEN AIR TEMPERATURE AND FOR THE TURBIN
AT A GIVEN LOAD
0F EQUATION:
TOWER TYPE*
MECHANICAL DRAFT
THETA = A*HREJ**Z
150 IL
DO 145 NT
ITER = 0
BPT =0.0
0PBP = BPMIN
= NTL,NTU
29
-------
04100 G0 T0 117
04120 110 SATT = AIRT(NT)+A*HRJ**.75
04140 IF CSATT-75O 120*115*115
04160 115 SATP = TBLUQ(SATT*T*P*56)
04180 0PBP = SATP
04200 IF CA8S(0PBP-BPT).LT.0.01) 60 T0 120
04220 BPT - 0PBP
04240 117 TEMP(l) = TBLUQ(0PBP,BP*HREJ(1 * 1>* 35)
04260 TEMP(2) = TBLUQ(0PBP*BP*HREJ(1*2)*35)
04280 TEMPO) = TBLUGK0PBP* BP* HREJ( 1* 3)* 35)
04300 HRJ = TBLUQ(PCTLD(IL)*PCTL0D*TEMP*3)
04320 ITER = ITER+1
04340 IF CITER.GT.15) PRINT,*M0RE THAN 15 ITERATIONS T0 FIND**
04360+ * 0PERATING BACK PRESSURE **/*ITD*AIRT(NT)*0PBP*HRJ
04380 IF (ITER.GT.15) G0 T0 120
04400 G0 T0 110
04420** MAKE OPERATING BACK PRESSURE N0T LESS THAN THE MINIMUM
04440** SPECIFIED IN THE FILE *TURBIN*
04460 120 0PBP = AMAX1C0PBP*BPMIN)
04480** CALCULATE THE NUMBER 0F H0URS AT THE GIVEN L0AD AND TEMPERATURE
04500 HRS = 0PHRS*TDUR(NT)*PCTTIM(IL)/1.0E4
04520** DETERMINE KW LEVEL 0F 0PERATI0N P0SSIBLE
04540 BPT = AMINK0PBP,BPMAX)
04560 FTKWT = TBLUQCBPT*BP*FTKW,35)
04580 IF (0PBP.GT.BPMAX) G0 T0 122
04600 IF (PCTLD(IL).EO.100.) TKW = FTKWT
04620 IF (PCTLD(IL).LT.100.) TKW = PCTLDCIL)*KW/100.
04640 IF (TKW.GT.FTKWT) TKW = FTKWT
04660 G0 T0 126
04680** ADJUST KW LEVEL IF BACK PRESSURE GREATER THAN ALL0WABLE
04700 122 SATT = TBLUGKBPMAX* P* T* 56)
04720 PLITD = SATT-AIRT(NT)
04740 HREJMX = (PLITD/A)**(1./.75)
04760 TKW = TBLUQ(HREJMX*HREJT*L0AD*3)
04780 0PBP = BPMAX
04800** CALCULATE THE T0TAL YEARLY BTU'S C0NSUMED F0R EACH 0F THE
04820** THREE L0ADINGS 0F 100* 75* AND 50 0/0
04840** DETERMINE GR0SS HEAT RATE F0R CALCULATED BACK PRESSURE
04860 126 TEMP(l) = TBLUQC0PBP*BP*GHR(1 * 1)*35)
04880 TEMP(2) = TBLUQ(0PBP*BP*GHR(1 * 2)* 35)
04900 TEMPO) = TBLUQ(0PBP* BP, GHR( 1 * 3) * 35 )
04920 L0ADK1) = TBLUGK0PBP, BP* FTK W* 35)
04940 0PGHR = TBLUGXTKW, L0AD 1* TEMP* 3)
04960 T0TBTU(I) = T0TBTU(I)+0PGHR*HRS*TKW
04980** DETERMINE AUXILIARY P0WER REQUIREMENTS F0R THE VARYING THETAS
05000 IF (T0WER(1).EQ.8HNATURAL ) G0 T0 1320
05020** AUXILIARY CALCULATI0NS F0R MECHANICAL DRAFT TOWER
05040 FULAUX = TBLUGKTHETA* TBLITD* AUX 1 00* 6)
05060 D0 1210 IJ = 1*5
05080 IF ((THETA.GE.TBLITD(IJ)).AND.(THETA.LE.TBLITD(IJ+1))) G0 T0 1220
30
-------
05100 1210 CONTINUE
05120 PAUSE 4910
05140 1220 Ul = IJ+1
05160 IJ2 = IJ
05180 AUXTEM(l) = AUXTMPC1,IJ2,IL)-CC(THETA-TBLITDCIJ))/10.)*
0 5 200+ C AUXTMP(1,IJ2*IL)-AUXTMP(1,IJ1,IL)))
05220 AUXTEMC2) = AUXTMP(2,IJ2,ID -C((THETA-TBLITD(IJ))/10.)*
05240+ (AUXTMP(2, IJ2, ID-AUXTMP( 2, IJI, ID))
05260 IF (AIRT(NT).LE.AUXTEM(1)) G0 TO 1240
05280 IF (AIRT(NT).GE.AUXTEM(2)) GO TO 1250
05300 PCT = 0.53+0.47*((AIRT(NT)-AUXTEM(1))/(AUXTEM(2)-AUXTEM(1)))
05320 G0 TO 1260
05340 1240 PCT = 0.53
05360 G0 TO 1260
05380 1250 PCT = 1.00
05400 GO TO 1260
05420 1260 AUXKWH(I) = AUXKWHCI) +FULAUX*PCT*HRS
05440 AUXKW(I) = FULAUX
05460 GO TO 1290
05480** AUXILIARY CALCULATIONS FOR NATURAL DRAFT TOWER
05500 1320 AUXKWCI) = TBLUOCTHETA>TBLITD*KWAX,6)
05520 AUXKWHCI) = AUXKWHCI)+AUXKWCI)*HRS
05540 1290 KWH = KWH + TKW*HRS
05560** CALCULATE LOSS OR GAIN 0F CAPACITY
05580 CAPLOS = KW*PC.TLD( ID/1 00.-TKW
05600 IF (CAPLOS.GT.0.0) GO TO 130
05620** GAIN IN CAPACITY CALCULATIONS
05640 KWHGAN(I) = KWHGAN(I)-CAPL0S*HRS
05660 CRDBTUCI) = CRDBTU(I)-CAPLOS*HRS*OPGHR
05680 132 IT = IT+1
05700 IF CIT.GT.3) GO TO 145
05720 KWL0SCIT) = CAPLOS
05740 GO TO 145
05760** LOSS OF CAPACITY CALCULATIONS
05780 130 IF(AIRT(NT).GE.CUTOFF) GO TO 131
05800 KWHBL0CI) = KWHBLO(I) + CAPL0S*HRS
05820 GO TO 132
05840 131 KWHABVCI) = KWHABVCI)+CAPL0S*HRS
05860 G0 TO 132
05880 145 CONTINUE
05900 150 CONTINUE
05920 MWH(I) = KWH/1000.
05940** CALCULATE LOSS OF CAPACITY AT THE 10 HOUR AIR TEMPERATURE
05960 KWLOSS(I) = TBLUGK AIR1 0> AIR* KWL0S, 3)
05980 IF ((KWLOS(2)+KWL0S<3)).EQ.O«0.AND.DURC1).LT.10.) KWLOSS(I) =
06000 200 CONTINUE
06020 DO 450 K = 1,NFUL
06040 DO 450 J = UNCCF
06060** WRITE OUT INFORMATION IDENTIFYING EACH RUN
06080 WRITE (1,370) CCF(J),CCFGT(J),CCF(J),FULCST(K),ASTER,PFCST(K),
06100+ ASTER*PCCST>CPKWAX
31
0.0
-------
06120 370 F0RMAT(*CAPITAL COST FACTORS:*9X*PLANT -*F3.0* 0/0*3X*PEAKING*
06140+* CAPACITY -*F3.0* 0/0*3X*AUXILIARIES -*F3.0* 0/0*/*PLANT FUEL *
06160+*C0ST -*F3.0* CENTS/10*A2*6 BTU*1OX*PEAKING FUEL C0ST -*F3.0
06180+* CENTS/10*A2*6 BTU*/*PEAKING CAPITAL C0ST -*F4.0* S/KW*16X
06200+*AUXILIARY CAPITAL COST -*F4.0* $/KW*/>
06220** WRITE 0UT C0LUMN HEADINGS F0R THE DATA OUTPUT
06240 WRITE ( U380)
06260 380 F0RMATC68X*ANNUAL*/68X*CAPITAL*3X*ANNUAL*/17X*EXCESS*45X*AND *
06280+*3+M*4X*FUEL*
06300+33X*T0TAL ANNUAL*/*IN IT.*3X*GR0SS*4X*ENERGY*47X*C0ST*5X*C0ST*3X
06320+*CHEDIT*23X*COST 0F C00LING*/*TEMP.*3X*ENERGY*3X*DUE T0*2X*CAPACI*
06340+*TY*2IX*MAXIMUM*8X*0F DRY*5X*0F*5X*F0R*3X*CAPACITY*13X*SYSTEM AND*
06360+* T0TAL*/*DIFF.*3X*800 MW*4X*EXTRA*3X*PENALTY*1X*AUXILIARY*1X*L0S*
06380+*S 0F*2X*AUXILIARY*6X*C00LING*3X*800 MW*2X*EXCESS*2X*PENALTY*1X
06400+*AUXILIARY*6X*PLAMT FUEL*/**4X*UNIT*3X*CAPACITY*2X*ENERGY*3X
06420+*ENERGY*3X*CAPACITY*3X*PGWER*9X*SYSTEM*4X*UNIT*3X*ENERGY*
06440+3X*C0ST*5X
06460+*C0ST*5X* = = = = = = = = = = " = = - = = = */*( F >*>4(4X*(MWH)*)* 5X*(KW)*6X*(KW)*
06480+1 1 X* C S) * 6X* ( S> ** H( 5X* < 3)>-- ? , 6X>- C 3> -X- (i; I LL/KNH) * )
06500 ITD = 29
06520 TANT = I.OE50
06540 REWIND 4
06560 D0 425 I = 1,51
06580 ITD a ITD+1
06600** DETERMINE ANNUAL CAPITAL COSTS F0R EACH CAPITAL C0ST FACTOR
06620 ANNCAP = T0TCAPCI)*CCF/1•OE4)*
06880+ (FULCSTCK5+1 . )
06900 G0 TO 138
06920** WINTER PEAKING CAPACITY LOSS CHARGES
06940 137 PENCAP = 0.0
06960 PEN0PR = ((KWHABVCI)+KWHBL3(I>)/1•OE4>*CFULCSTCK)*1 • )
06980** SUMMATION 0F CAPACITY L0SS CHARGES
07000 138 PENLTY = PENCAP+PEN0PR
07020 KWHL0S = KWHABVCI>+KWHBL0
-------
CORRESPONDING
07260 MILPKW =
07280** CHANGE
07300 KWHL0S =
07320 TAXKWH =
07340 TKWHGN =
07100 AUXCAP = AUXKWCI)*CPKWAX
07120** CALCULATE MILLS/KWH FIGURE F0R AUXILIARY KWH
07140 FCSTAX = ANNFUL/MWHCI)+ 0NM
07160 AUXOPR = AUXKWH(I)*FCSTAX/1000.
07180 AUXCST = AUXCAP*CCFCJ)/100.+AUX0PR
07200** COMBINE OPERATING C0STS AND CAPITAL C0STS F0R
07220** THETAS
07240 TANCST = ACCAOM+ANNFUL+PENLTY+AUXCST-CREDIT
TANCST/TMWH
ENERGY VALUES T0 MWH
KWHL0S/1000.
AUXKWHCI)/1000«
KWHGAN(I)/1000.
07360** DETERMINE THE OPTIMUM ITD
07380 IFCTANT.LT.TANCST) G0 T0 3
07400 TANT = TANCST
07420 ISAVE = ITD
07440** WRITE DATA IN 0UTPUT FILE
07460 3 WRITE(4,420)ITD*MWHCI)*TKWHGN*KWHL0S*TAXKWH*KWL0SSCI>*
07480+ AUXKWCI)* ACCA0M*AN.MFUL* CREDIT* PENLTY* AUXCST* TANCST* MILPKW
07500 420 FORMAT ( I 4* F 1 1 . 0* 3F9. 0* 2F 1 0. 0* F 1 4. 0* F9. 0* F 7. 0* F9 • 0*
07520+ F10.0*F12.0*F8.4)
07540 425 CONTINUE
07560 REWIND 4
07580 DO 1020 1=1*51
07600 READ C4*420)ITD*MWHCI)*TKWHGN*KWHL0S*TAXKWH*KWL0SSCI)*
07620+ AUXKWCI )*ACCA3M*ANNFUL*CREDIT*PENLTY*AUXCST*TANCST*MILPKW
07640 IF CITD.NE.ISAVE) G0 T0 1020
07660 WRITE C1* 61 1 >
07680 611 FORMAT C*GPTIMUM:*>
07700 1020 WRITE C1 * 420)ITD,MWHCI)*TKWHGN*KWHL0S*TAXKWH*KWL0SSCI)*
07720+ AUXKWCI)*ACCA0M*ANNFUL*CREDIT*PENLTY*AUXCST*TANCST*MILPKW
07740 450 CONTINUE
500 CONTINUE
ENDFILE 1
REWIND 1
CALL REPL C1*6H0PT0UT)
STOP
END
07880** DATA FILE CHECK SUBROUTINE
07900 SUBROUTINE DATCHKCNFIL)
DIMENSION LINEC24)
INTEGER FILEC3)*IDMTC3)
DATA FILE /6HSPVSST*6HTURBIN*6HSITE /
READ CNFIL*) DATA
ICNTCNFIL) = ICNTCNFID+1
IF CDATA-1 .OEbO) 20., 10* 20
10 RETURN
20 BACKSPACE NFIL
READ (NFIL*30) LINE
07760
07780
07800
07820
07840
07860
07920
07940
07960
07980
08000
08020
08040
08060
08080
33
-------
- ABOVE LINE*
08100 30 FORMAT (24A3)
08120 PRINT 40*LINE,FILE(NFIL>
08140 40 FORMAT (/24A3/*ERR0R IN READING FILE *A6*
08160+ * SHOULD BE DATA CHECK NUMBER (1.0E50)*/)
08180 REWIND NFIL
08200 NCNT = ICNT(NFIL)
08220 D0 50 I = 1*NCNT
08240 45 READ (NFIL*) DATA
08260 IF (DATA-1.OE50) 45*50*45
08280 50 CONTINUE
08300 RETURN
08320 END
08340** TABLE L00KUP SUBROUTINE USING A CURVILINEAR INTERPOLATION
08360**TABLE L00KUP ROUTINE USING A DETERMINANT SOLUTION 0F TWO
08361** SECOND ORDER EQUATIONS
08380 DIMENSION XTC100)*YT(100)
IF CCXTC1)-X)*(XT(NVAL)-X)) 3*3*2
2 IF CABSCX-XTC 1 ) ).LT. ABSCX-XKN VAL) ) ) N = 1
IF CABSCX-XTd)).GT.ABSCX-XTCNVAL))) N = NVAL-2
G0 T0 25
3 N = NVAL-1
00 10 I = 1*N
IF(X.NE.XTU)) GO TO 5
TBLUQ = YT(I)
RETURN
5 IF ((X.GT.XT(I)).AND.(X.LT.XT(I+1)))
08400
08420
08440
08460
08480
08500
08520
08540
08560
08580
08600
08620
08640
08660
08680
08700
08720
08740
08760
08780
08800
08820
08840
08860
08880
08900
08920
08940
08960
08980
09000
IF ((X.LT.XTCI )). AND. (X« GT.XT(I+1»)
10 CONTINUE
N = NVAL-2
GO TO 25
GO TO 15
GO TO 15
15
16
GO
20
25
X2 :
X3 :
Yl -
Y2 =
Y3 :
X1S
X2S
X3S
DET
A =
B =
C =
16*20*20
IF (1-3)
N = 1
TO 25
N = 1-1
XI = XT(N)
= XT(N+1)
= XT(N+2)
: YT(N)
= YT(N+1)
= YT(N+2)
= X1*X1
= X2*X2
= X3*X3
= X2S*X3-X3S*X2-X1S*X3+X3S*X1+X1S*X2-X2S*X1
(Y2*X3-X2*Y3-Y1*X3+Y3*X1+Y1*X2-Y2*X1)/DET
(X2S*Y3-X3S*Y2-X1S*Y3+X3S*Y1+X1S*Y2-X2S*Y1)/DET
(Y1*(X2S*X3-X3S*X2>-Y2*(X1S*X3-X3S*XI)+Y3*(X1S*X2-X2S*X1)
09020+ )/DET
09040 TBLUQ = A*X*X+B*X+C
09060 RETURN
09080 END
34
-------
TOWER OPTIMIZATION PROGRAM "TOWSIZ1
00100 PROGRAM TOWSIZCTAPE1>OUTPUT)
00120C
00140C
00160C
00180C
00200C
00220C
00240C
00260C
00280C
00300C
00320C
00340C
00360C
00380C
00400C
00420C
00440C
00460C
00480
00500C
00520C
00540C
00560C
00580C
00600C
00620C
00640C
00660C
00680C
00700C
00720C
00740C
00760C
00780C
00800C
00820C
00840C
00860C
00880C
00900C
00920C
00940C
00960C
00980
0 1000
0 1020
0 1040
0 1060
0 1080
DRY COOLING TOWER SIZING AND COST EVALUATION PROGRAM
6/30/70 PJB
PROGRAM
NAME
ITD
RANGE
HTREJ
GO
AMAIRT
ELEV
CONDF
N
00
CURVGO
LO
Q1TBL
LOTBL
DELTAP
DPTBL
AEXIT
EXITV
EXITLS
DRFTLS
TOTL0S
AIRHT
AIRDLT
FAIRTM
DRAFTH
ADRFTH
TOTALH
ADRT
ADRA
TEMPS
TFACTR
HEIGHT
AFACTR
UPAREA
UPDIAM
L0WDIA
PARAMETERS
USE
INITIAL TEMPERATURE DIFFERENCE
TEMP CHANGE OF CONDENSATE
HEAT REJECTION
AMBIENT AIR TEMPERATURE
ELEVATION
CONDENSATE FLOW
NUMBER OF COLUMNS
(7) TABLE OF CONSTANT GO TO IDENTIFY CURVE 1
(31,7) TABULAR COORDINATES FROM CURVE 1 PLOT
31) LO FOR CURVE 1 AND DELTAP
COIL LOSS
(31) TABLE OF DELTAP VALUES
AIR EXIT VELOCITY
CONSTANT (20 FT/SEC) EXIT VELOCITY
EXIT LOSSES
DRAFT LOSSES
TOTAL LOSSES
AIR HEAT GAIN
AIR TEMPERATURE INCREASE
FINAL AIR TEMPERATURE
DRAFT HEIGHT
ADJUSTED DRAFT HEIGHT
TOTAL DRAFT HEIGHT
AIR DENSITY RATIO - TEMPERATURE
AIR DENSITY RATIO - ELEVATION
( ) TEMPERATURE TABLE
( ) TEMP DENSITY RATIO TABLE
( ) ALTITUDE TABLE
( ) ALTITUDE DENSITY RATI3 TABLE
AREA OF TOWER TOP
DIAM OF TOWER TOP
DIAM OF TOWER BOTTOM
INTEGER STPTS(4)
REAL N,LO
REAL LOTBL,LOWDIA
REAL ITD
DIMENSION CURVGO(7),Q1TBL(31,7),LOTBL(31),DPTBL(31)
DIMENSION IENTR(7)
35
-------
01100 DIMENSION TEMPSC 1 R ) , TFACTRC 1 R ) , HEI GH1 ( 24 ) , AFACTR( 24)
0 1 120 DIMENSION ST UI AM ( 4) , STKHT C 5, 4) , STKCSK5* * ) * RTEMPC 6) * CNDCS'l ( 6)
01 MO DIMENSION DUMMYC31)
0 1 160 COMMON JJ
0 1 180 CCMM0N HTREJ*RANGE*DELTAS*L0WDIA,TPCST,TVCST,PC0ST, FPCSi
01200 COMMON STCS1,T0TPCS,GPM
01220 EOUI VALENCE(DUMMY<1)*011BLC1, 7))
01240 DATA STDIAM/217.* 312.*460.* 550./
01260 DATA STKH1 / 1 20. * 240- .» 3«7 . * 527 . * 793. * 1 26. * 283. * 463. * 603. ,
012RO+800.* 126.,283«,463.*603.*813.*200.*400.* 600.*800.* O.O/
01300 DATA STKCST/272466.* 574247.,897032.* 1470194.,3111314.*361950.*
01320+K94091. * 1565409.*2314192.* 3971000.* 516062.* 1264230.* 2067594.*
01340+3326040.* 5360366.*9R0000.* 2050000.* 3730000.* 5980000.* O./
01360 DATA STPTS/5,5,5,4/
013RO DATA RTEMP/5.0*10.0*20.0*30.0*40.0*50.O/
0 1400 DATA CNDC5-T/273000. * 256POO. , 22*000. ,208000.* 190000.* 1 67000. /
01420 DATA TEMPS /-20.* - 10.* 0.* 10.* 20.* 30.* 40.* 50.* 60.* 70.* 80.*
0 1440+90.* 100.* 1 10.* 120.* 130.* 140.* 150./
01460 DATA TKACTR /1.197,1.175*1.171,1.125*1.102,1.07R,1.057,1.037*
0 1 480-t- 1 . 01 8* 1 - 00* -9R6* .962* . 944, . 933, .914* .R99, .P84, . R 70/
01500 DATA HEIGHT /O.* 400.* 800.* 1200.* 1600.* 2000.* 2400.* 2800.* 3200.*
01520+3600.,4000.,4400.* 4ROO.,5200.* 5600.* 6000.* 6400.*6ROO.* 7200.*
01540+7600.*8000.*8400.,8800.*9200./
01560 DATA AFACTR /l.,.OR5 * .«72, .^58,.944,.93,.917,.904*.891 *.878,
01580+.864,.852*.832*.826,.81 3, .802,.788,.776,.755*.754,.74 3, .73,.719*
01600+.708/
01620 DATA IENTR / 3 1 , 3 1 , 31 , 3 1 * 27, 2 7, 3 1 /
01640 DATA. LOTBL /200. * 2 1 0., 220- * 230. * 240. * 250. * 260. * 270. * 280. * 290. *
01660+300.*310., 320., 33n.,340.,350.,360.* 370.* 380.* 390.*
01680+400.*410.* 420.* 430.* 440.* 450.* 460.* 470.* 480.* 490.* 500./
01700 DATA Q1TBL /35 . 6* 36. 6* 37 . 8* 38. 8* 3^ . °* 4 1 . */i2 . 1,/)3 . 2* 44. 3* 45. 3,
01720+46.4*47.4,4R.4,49.2*50. 1 * 51.,51.R*52.6* 53.4* 54.2* 54.9* 55.6*
0 1740+56.3* 57.* 57.6* 58.2*58.8* 59.4* 60.* 60.6* 61.2*
0 1760+34.6*35. 5*36.6* 37.7* 3R. 7* 39.8*40.8*41 . 7* 42. 7*43. 6* 44. 5*
0 1780+45.3* 46. 1,46.8*47.5* 4R.3*49.0*49.6*50.3* 51.0* 51.6* 52.2*
0 1800+52.8*53. 4, 54. 0* 54.6,55. 2* 55.8*56. 3* 56.8*57. 4*
0 1820+33. 7*34. 7*35.7*36. 7*37.7*38.6*39. 6*40.5,41.4*42.3*43. 1*
01840+43.9*44.7*45.4*46.1*46.8*47.5*4R.1*48.7*4C>.3*49.9*50.4*
0 1860+51 .0*51.6*52.2*52.7* 53.2*53.8*54.3*54.8*55.3*
0 1880+33. 1* 34. 0* 34.9*35.8* 36. 7,37.6*38. 4*39. 3*^0. 1* 40.8* 41 .6*
0 1900+42.3* 43. 0* 43.7,44. 4, 45. 0, 45. 6,46.2,46. 7,47.2, 47.7, 4R. 3,
0 1920+48.8,49.3,49.8*50.3,50.8*51.3*51.7*52. 1*52.5,
0 1940+32.2* 33.0*33.9*34.8*35. 6*36. 4,37.2* 38.0* 38. 7* 39.4,40.2*
0 1960+40.8* 41 . 4* 42.0*42.6* 43. 2*43.8*44.3*44.8,45.2, 45. 6, 46.0,
01980+46.5,46.9,47.3,47.6,48.0,48.4,48.8,49.1,49.4,
02000+31 .0* 31 . 7, 32. 4, 33. 1, 33. 7, 34 . 4, 35. 1 , 35. 8* 36. 4* 37. 0* 37. 6*
02020+38. 2* 38.R* 39. 3*39. 8* 40. 3*40. 7*41 . 1* 41 .5, 41.9*42.3,42. 7*
02040+43. 1*43.4*43.R*44.1*44.4*0.*0.*0.*0./
02060 DATA DUMMY/25.9,26. 4*26.9,27. 3* 27 . R, 28 . 2, 28. 6, 29. 0, 2^. 5, 29 . 9, 30. 3,
02080+30.6,30.9,31 • 2, 3 1 • 5, 3 1 • 7, 3 1 . 9, 32. 2, 32. 4, 32. 5, 32. 7, 32. 9,
02100+33. 1,33.2, 33. 4, 33. 6, 33. 7, 33. 8, 34.0, 35.1, 35. 2 /
36
-------
02120 DATA DPI BL / 1 8 . 5, 1 8. 7* 1 8. 9, 1 9. 1 , 1 9. 3* 1 9 . 5, 1 9 . 7, 1 9. 9, 20. 1,
021 40+20. 3, 20. 6, 20. «, 21 .0,2! .2,2! . /«* 2! . 6, ? 1 . 8* 22. 0, 22. 3, 22. 5,
02160+22.8,23. 0*23.2,23. 4,23.7*24.0*24.3*24. 6*24.8,25.2, 25.5 /
02180 DATA CURVUO/264480. * 220400. * 1 T F:'l , ELEV
COMPUTE INTERMEDIATE SIZING DATA
= HTREJ/RA,\GE
00
10
20
02240
02260
02280
02300
02320
02340
02360C
02380 50
02400C
02420
02440
02460
02480
02500
02520
02540
02560
02580
02600
02620
02640
02660
02680
02700
02720
02740
02760
02780
02800
02820
02840
02860
02880
02900
02920
02940
02960
02980
03000
03020
03040
03060
G0 TO 110
CORRESPONDING CURVE. CASE ABORTED.*
4
TEMP=AMGD(ISI* 4. 0)
If (TEMP. ME. 0. 0) iM=N-TEMP+'f. 0
00=(HTREJ/N)*0.252
Q1=GO/CITD*0. 55555)
90 DO 100 1=1*7
IF CGO.EO. CURVGOCI >>
100 CONTINUE
PRINT, *bO =*,GO** NO
G0 TO 9000
110 ICURV=I
LO = TBLUO(Q1,Q1TBL( 1, I CURV ) , LOTBL* T ENl R ( I CURV) , NFLAG)
IF (NFLAG. EQ. 2) PRINT* *LO OUTSIDE TABLE*
DELTAP=TBLUQ(LO*LOTBL* DPTBL* 31,NFLAG)/25
AEXIT = EXIT V
EXITLS=( (AEXIT/4005. )*60«0)**2
DRFTLS=O. IS*EXITLS
TOTL0S=DELTAP+EXITLS+DRFTLS
AIRHT = GO/CLO+555. /jOP)
AIRDLT=AIRHT/0.2A
FAIRTM=bO.O+AIROLT
DRAFTH = TOTLOS/<7. 659* ( 1. 0/510.-1 . 0/< AIK'Dl
ADRT=TBLUQ(AMAIRT*TEMPS*TFACTR* 18* NFLAG)
ADRT1=TBLUQ(50. 0, TEMPS* TFACTK* 18* NFLAG)
ADRA=TBLUO(ELEV,HEI bHl * AF ACT'-<* 24,NrLAb>
ADRFTH=DRAFTH*( (ADR1 1 / ADRT >**3) * ( ( 1 • 0/ADRA) **2)
TOTALH=ADRFTH+80. 0
ADRT = T BLUGKFAIRTM* TEMPS* TF ACT R* 18)
UPAREA=N*LO/
-------
T0WER SIZES
03080C COST EVALUATION SEGMENT
03100C VARIABLE USE
03120C STDIAM (3) TABLE OF C0ST EVALUATION
03140C STKHT (3*5) TABLE 0F STACK HEIGHTS
03160C STKCST (3*5) TABLE JF STACK COSTS
03180C STACK EVALUATEED C0ST 0F STACK
03200C DROOF EVALUATED COST JF DELTA R00F
03220C COILS COST OF COOLING COILS
03240C RTEMP C6> TEMP RANGE TABLE FOR CONDENSER COSTS
03260C CNDCST C6> COST TABLE FOR CONDENSER EVALUATION
03280C CPBTU CONDENSER COST PER BILLION BTU
03300C DNDNSR TOTAL CONDENSER COST
03320C TOWER STRUCTURE
03340 DO 2000 1=1,3
03360 IF CCUPDIAM.GE.STDIAMCI)).AND.(UPDIAM.LE.STDIAMC1+1>)) GO TO 2010
03380 2000 C'JNTINUE
03400 PRINT**UPPER DIAMETER = *,UPDIAM** OUTSIDE OF TABLES*
03420 G0 TO 9000
03440 2010 A1=TBLUGKT0TALH*STKHT< 1, I ), STKCST< 1*1 >,STPTSCI>*NFLAG>
03460 A2 = TBLUQCT:JTALH,STKH1 <1,I+1)*STKCST<1,I+ 1) * S 1 PTSC I •«• 1 >*NFLAG>
03480 STACK=A1+ , C J IL:>* TT0WER* CNDNSR
03820 1002 FORMAT C///*CJST EVALUATI0N*/4X*T0WER STRUCTURE*//9X
03840+*STACK COST*8X*F11.0/9X*SHED COST*9X,F11.0/9X*COIL C0ST*9X*
03860+F11.0//9X*TOTAL STRUCTURE*12X*F11.0///4X*C0NDENSER*//
038RO+9X*C0NDENSER C0ST*13X,F11.0)
03900 T0T=TOTPCS+TT0WER+CNDNSR+CONTHL
03920 PRINT 1 003* TPCST* TVCST* PC3ST* F PCST*'STCST, T0TPCS, C0NTRL* T0T
03940 1003 F0RMAT (///4X*PIPING* VALVES, ETC.*//9X*PIPE C0ST*9X*F11.O/
03960+9X**VALVE C0ST*8X*F11.0/9X*PUMP C0ST*9X*F11.0/9X*FILLER PUMP C0ST*
03980+2X,F11.0/9X*ST0RAGE TANK C0ST *F11.0//9X*T0TAL PIPING FACIL*
04000+*ITIES*4X*F1 1 . 0//4X*CJNTf*//9X*C-)NTR0L COST*15X,F1 NO///
04020+*C0MPLETE T0WER FACILITIES*///9X*T0TAL T0WER C3ST*9X,F13.O//)
04040 T0T=TOT*1.25
04060 PRINT 1004*T0T
04080 1004 FORMAT (*TOTAL TOWER COST AND COMTINGENCIES*F13.O///70C*-*))
38
-------
04100
04120
04140
04160
04180
04200
04220
04240
04260
04280
04300
04320
04340
04360
043RO
04400
04420
04440
04460
04480
04500
04520
04540
04560
04580
04600
04620
04640
04660
04680
04700
04720
04740
04760
04780
04800
04820
04840
04860+
04880
04900
04920
04940
04960
04980
05000
05020
05040
9000 IF CENDMLF. 1) 9100*50
9100 STOP
END
FUNCTION TBLUQ (X*XT*YT*NVAL*NFLAG)
DIMENSION XTC100)*YT(100)
IF CCXTC1)-X)*CXTCNVAL)-X)) 3*3*2
2 IF (ABS(X-XT<1)).LT.ABSCX-XTCNVAL)»
) • GT.ADS CX-XT(NVAL))) N
N = 1
= NVAL-?
IF (A3SCX-XTC 1
NFLAG=2
G3 T0 25
3 N = NVAL- 1
NFLAG=1
D0 10 I * 1*N
IF (X.NE.XTCI)) G0 T0 5
TBLUQ = YT(I)
RETURN
5 IF ((X.GT.XTCI ) ). AND. » G0 T0 15
IF CCX.LT.XTCI))
10 C0NTINUE
N = NVAL-2
G0 T0 25
15 IF (1-3)
16 N = 1
G0 T0 25
20 N = I- 1
25 XI = XTCN)
X2 = XTCN+1)
X3 = XTCN+2)
Yl = YT(N)
Y2 = YT(N+1)
Y3 = YT(N+2)
XI S = X1*X1
AND.CX.GT.XTU
G0 T0 15
16*20*20
X2S = X2*X2
X3S = X3*X3
DET = X2S*X3-X3S*X2-X1S*X3+X3S*X1+X1S*X2-X2S*X1
A = CY2*X3-X2*Y3-Y1*X3+Y3*X1+Y1*X2-Y2*X1>/DET
B = (X2S*Y3-X3S*Y2-X1S*Y3+X3S*Y1+X1S*Y2-X2S*Y1)/DET
C =
-------
05100
05120
05140
05 160
05180
05200
05220
05240
05260
05280
05300
05320
05340
05360
05380
05400
05420
05440
05460
05480
05300
05520
05540
05560
05580
05600
05620
05640
05660
05680
05700
05720
05740
05760
05780
05800
05820
05840
05860
05880
05900
05920
05940
05960
05980
06000
06020
06040
06060
06080
DATA GAPDEL*N0LEV*NSECPL/448«*2.*4./
DO 200 IR = 1*1
NDELPL = N0DEL*N0LEV*NSECPL
HPCST = HPLEN*HPD
NHV = 4.*NSECPL*N0LEV
HVCST = NHV*HVD
DELPSE = N0DEL/(N0LE\/*NSECPL)
DGPM = DELPSE*GAPDEL
CALL PIPSIZCDGPM,NDL»DPS*DPD, DVD)
DPLEN = BDIAFT*NSECPL*N0LEV
DPCST = DPLEN*DPD
NDV = 2.*NSECPL*N0LEV
DVCST = NDV*DVD
FGPM = DGPM/10.
CALL PIPSIZCFGPM*NFL,FPS,FPD,FVD)
FPLEN = DPLEN
FPCST = FPLEN*FPD
NFV = NDV
FVCST = NFV*FVD
NBPV = NMVAL/2.
BPVALS = MPS
BPVALD = MVD
BPVCST = NBPV*BPVALD
EDGPM = GPM/TNMSL/4.
CALL PIPSIZ(EDGPM,NEDL*EDPS»EDPD*EDVD)
NEDL = TNMSL
EDPLEN = BDIAFT*.75*NEDL
EDPCST = EDPLEN*EDPD
NEDVAL = NEDL
EDVCST = NEDVAL*EDVD
IPSETS = GPM/85000.-H. 5
PC0ST = IPSETS*300000.
IFPSET = FGPM/5500.+2.
FPCST = IFTSET*20000.
40
-------
06100
06120
06140
06160
06180
06200
06220
06240
06260
06280
06300
06320
06340
06360
12360.7+.16912*GPM
STLBS+.5
MPCST+HPCST+DPCST+FPCST+EDPCST
MVCST+HVCST+DVCST+FVCST+EDVCST+BPVCST
TPCST+TVCST
TPVCST+PC0ST+FPCST+STCST
STLBS =
STCST =
TPCST =
TVCST =
TPVCST=
TOTAL =
200 CONTINUE
RETURN
END
SUBROUTINE PI PSIZ(GPM,N0L,PDIA,DPRFT,DPRVAL)
REAL N0L,NSL
COMMON JJ
DIMENSION PSIZE(14),DPFT<2,14),DPVALC14)
DATA PSIZE/18.,22., 24., 26., 32., 36.,42.* 48.,54.,60., 72.,84.,96.*
06380+108./
06400 DATA DPFT/31• , 45.» 32.,49.,33.,51.* 36.,57.,40.,64.,42.,69.,52.,84.,
06420+57.,93.* 69., 109.,76., 121., 102., 155., 117., 178., 134.,203., 161.,238./
06440 DATA DPVAL/2960.,5350.,3720.,7330., 10480.,6380., 1 2670.,
06460+14520.,18650.,23650.,31280.,41370.*59340., 70920. /
06480 NSL = 1.
06500 10 DIA = SQRTC3.55E-4*GPM/NSL)*12.
06520 IFCDIA.LE. 108. )G0 T0 20
06540 NSL = NSL+1
06560 G0 T0 10
06580 20 DO 30 I = 1,14
06600 IFCDIA.LE.PSIZE (I)) GO T0 40
06620 30 CONTINUE
06640 I = 14
06660 40 N0L =NSL
06680 PDIA = PSIZECI)
06700 DPRFT = DPFTCJJ,I)
06720 DPRVAL = DPVAL(I)
06740 RETURN
06760 END
41
-------
APPENDIX B
SAMPLE DATA
42
-------
TABLE 1-B
Auxiliary Power Requirements for 800-Mw Natural -Draft,
Dry-Type Cooling Tower
ITD (°F)
30
40
50
60
70
80
Fossil-Fueled Turbine (kw)
12,000
9,000
7,000
6,000
5,000
4,000
TABLE 2-B
Nuclear- Fueled Turbine (kw)
19,000
14,000
11,000
9,000
8,000
7,000
Auxiliary Power Requirements for 800-Mw Mechanical-Draft,
Dry-Type Cooling Tower
ITD (°F)
30
40
50
60
70
80
Fossil -Fueled Turbine (kw)
32,000
26,000
21,000
17,000
14,000
12,000
Nuclear- Fueled Turbine (kw)
48,000
39,000
32,000
26,000
22,000
18,000
43
-------
TABLE 3-B
IIP (°F)
30
40
50
60
70
80
ITD (°F)
30
40
50
60
70
80
ipital Cost's for 800-Mw Natural -Draft,
Dry-Type Cooling Tower
FOSSIL UNIT
Elevation
Sea Level
$32,610,000
22,880,000
17,200,000
14,090,000
12,040,000
10,280,000
NUCLEAR
Sea Level
$50,000,000
36,080,000
26,920,000
21,530,000
17,720,000
15,870,000
3,000 Ft.
$36,150,000
24,430,000
18,220,000
14,700,000
12,500,000
10,600,000
UNIT
Elevation
3,000 Ft.
$54,800,000
37,840,000
28,210,000
22,340,000
18,160,000
16,220,000
6,000 Ft.
$40,500,000
26,850,000
19,770,000
15,740,000
13,260,000
11,100,000
6,000 Ft.
$60,000,000
41,250,000
29,890,000
23,670,000
19,100,000
16,810,000
44
-------
TABLE 4-B
IIP (°F)
30
40
50
60
70
80
ITD (°F)
30
40
50
60
70
80
al Costs for 800-Mw Mechanical-Draft,
Dry -Type Cooling Tower
FOSSIL UNIT
El eva ti on
Sea Level
$23,920,000
20,000,000
16,400,000
13,280,000
10,960,000
9,720,000
NUCLEAR
Sea Level
$35,280,000
29,480,000
24,120,000
19,640,000
16,160,000
14,240,000
3,000 Ft.
$24,460,000
20,450,000
16,770,000
13,580,000
11,210,000
9,940,000
UNIT
El evation
3,000 Ft.
$36,070,000
30,140,000
24,660,000
20,080,000
16,520,000
14,560,000
6,000 Ft.
$25,120,000
21,000,000
17,220,000
13,940,000
11,510,000
10,210,000
6,000 Ft.
$37,040,000
30,950,000
25,330,000
20,620,000
16,970,000
14,950,000
45
-------
TABLE 5-B
"TURBIN" Data File
(Fossil Fuel)
00100
o n 11 o
001 so
001 30
001 4Ci
0015 0
00160
00170
0 0 1 H 0
00190
00200
0 02 1 0
00220
00230
C0240
00250
00260
0 027 0
00280
002.90
00300
003in
00320
00330
00340
00350
00360
C0370
003HO
00390
00400
00410
00420
00430
00440
00450
00460
00470
00*80
00490
00500
00510
00520
00530
O0540
00550
00560
00570
00580
00590
00600
00610
00620
00630
00640
00650
00660
ROOOOO. FOSSIL
4oor.
i . o* ifl.n
Rr9975.*8O9470.,BPR966
79026R. * 784068.* 777499
74RS60.,743P49.*7381«2
713«46.*709170.*704555
68 4 150«* 680209. * 67 63 14
1.0E50
8)00.*3105.*«l!n.,813P
!=(302.*>=!368.*3439.*8509
8765.*8827.*88-'S.,8949
9191. , 0052. , 931 2. , 9368
9590.*9645.*97O1.*9756
9000.* 9 006., 90 I 1 . * 9034
9 225., 9 29 «., 9376., 9455
9 7 39.* o SO-:. > aK76.* 0943
10212. > 10280. i 10347. , i
10655.* 107 1 7. * 10779. * 1
3797. * 37 9 R. * 3H("'0. j 3*i i
3f?64.*3R85.*3907.*3929
4006. .4024., 4042. ,4059
4 1 2 5 . , /. 1 A 1 . * /; 1 5 6 . * 4 1 7 !
4226. ,4239.* 4253. / 4266
1 . OE50
.*RP6917.*Rn396C>.,ROOOOO.» 79559 I •
., 771039., 7651 35. * 759588.* 754034.
.*7331K3.*72R^51.*7233R5.*7I85R.4.
.*700377.*696249.*692168., 68*136.
., 672533. * 668657. , 66496 1 ., 66 1 1 70.
.*Rl61
.*R575
.*9009
. *9 423
.,98 1 2
. , 906g
., 9b 28
. , 1001
P/,ni. ,
0840. ,
• * 38 1 7
.,3950
. ,4075
• > <1 ! f ? 3
.. 4279
R99H.*9057.*CM15.*9174.,9231 .
934v7.,Q/,5g.,o:,C6.*9b60.,9607.
9760. *9R09.*9Rb9.,99n«., 9955., 1P005.* 10052.
,8201.,8247.
*R638.*f?701.
*9070.*9)30.
*9/j 79. ,9534.
, 9867 . * 9923.
* 9 1 12., 9 (63.
* 9597., 9668.
.* 10078. , 101/45.
r>470. * 10532.* 10594.
O902. * 1 0963., 1 1026.
* 383 1 • * 3846.
*396R.*39K7.
* 4092. , A 1O8.
-• '! 1 9 9 . , 42 1 2 •
* 429 1 .* 4304.
9473. * 9 b r, /,. * ° fc 3 7 . > ° ? \ 4 . , o 7 o ( . , o K f> i .
999K.* ! 0063.* !P1;?«. * !0 !'>;j. * "f'T":)?.* 1 0321 ., 1
10442.*10502.*!0562.*10622.*10675.,10735.,
10844., 10«99.* 10954., 1 !PP«., 1 i061.,!!?! 7.,
28^0. , 2^*3. * S^s. , yo i 5. . ,0030 . . :-'976. * 3022.
3067.*3112.* 3156.* 31«8.,323*.*3P77.,3315.
3351.*3386.*34?].*3-'o6.*349!.*3526.*3559.
3591.*3623.* 3656.* 3688.* 3716.*3749.*3778.
3«0*.*3*3?*., 3«67., 3897.* 3925.* 3955.* 3983.
1-OE50
8642.*86"1.*'<727.*R799.,891 1 . * <>oi 4. *9I 15.
9212.* 9300.,9387.,9473.,9555.,9632.,9709.
*9923.*°™'i.* 10062.* 10126.* 1019
031 hi. , 1 0375. * 1 043*.* 10493. * 10550.*
nVI 7.* 10773.* 10825.* 10876.* 10929.,
10236.* 0333.* 10/130.* 1P525.* 10616.* 10703.*
10K71.* 0«5I.* 1 1026.* 1 1104.* ! ! !HO., 1 1251.*
1 1 393. * 146 1 . * 11 5P7. * ! ! :59«'(. * \ ] 65«.* ! ' /I'M.*
11H46.* 1908.* I 1970.*12028.* 12094., 12144.*
2320.* 2355.* 2390.* 2424.*2457.*248R.*2518.
254».*2577.*2604.,2632. .2659.*2685. *2711.
2736.,2761.* 2785.* 2809.,2H32. , 2H55.*2878.
2899.* 2922.* 29/,4. , 29 65., 2985. , 3006., 302 6.
1.0E50
0383.
10789.
11168.
10254.,
10662.*
1.
10608.
10979.
107RR.
11323.
M7R7.
12199.
46
-------
TABLE 6-B
"TURBIN" Data File
(Nuclear Fuel)
OOIOO
001 10
00120
00130
00140
0015G
00160
00170
00180
00190
00200
00210
00220
00230
00240
00250
00260
00270
002RO
00290
00300
00310
00320
00330
00340
00350
00360
00370
003*0
00390
00400
00410
00420
00430
OC440
00450
00460
00470
00480
00490
00500
00510
00520
00530
00540
00550
00560
00570
00580
00590
00600
00610
00620
00630
00640
00650
00660
800000. NUCLEAR
6000.
2.0, 18.0
R136R7.,R13687.,813687.,P11636.,807175.,80000r., 789884.
77R425., 768844.,759-*27.,7b 09 7R.,7 42 715.,73392*., 726030-
7176R8..710078., 704520., 698465.t692455.* 687169.» 681962.
6773R1.,672321.,667869.,66347b.,659710.,654910.,65174R,
6*8617.,644968.,64 I 410.,638377. ,635373. ,631871. ,627937.
1.0E50
10390.,10390.,10390.,10416.,10474.,10568.,10703.
10861.,10996.,11132.,11257.,11383.,11519.,11644.
1780.,11906.,12000.,12104.,12209.,12303.,12397.
2481.,12574.,12658.,12742.,12815.,12909.,12971.
3034.,13108.,131RO.,13243.,13306.,13379.,13463.
0390.,10390.,10390.,10416.,10474.,1056R.,10703.
CR6 1 . ,10996.,11132.,11257.,11383.,11519.,11644.
1780., 1 1906., 12POO., 12104., 12209., 12303., 12397.
2481., 12574., 12658. , 12742., 12815. , 12909., 12971.
3034.,13108.,13180.,13243.,13306.,13379.,13463.
5677.,5677.,5677.,5684.,5699., 5724.,5758.
5797., 58 30., 5862., 5891., 59 19., 59 49 i, 59 76.
6005., 6031., 6050., 6070., 6091., 6109.,6127.
6142.,6159.,6175.,6190.,6203.,6219.,6230.
6240.,6253.,6265.,627b.,6286.,6298.,6311.
.OE50
0535., 0535.,10552.,10596.,10667.,10789.,10967.
11 5.2. , 13 01.,11 441. ,11567. ,11697. ,118 35. ,11961.
2093., 2215.,12307.,12409.,1251O.,12600.,126RR.
2761., 2846., 12922., I 3003., 13065.,13157., 1 32 1 1 .
13264., 3330.,13395.,13450.,13499.,13567.,13637.
10535., Pb35., 10552., 1C596., 10667.,10789., 1P967.
11152., 1301.,il441.,11567.,11697.,11«35.,11961.
12093., 2215., 12307.,12409., 12510.,12600., 12688.
12761., 28/<6. , 12922., 13003., 13D6b., 13157., 1321 1.
I 3264., 33.TO.,13395., 13450., 13499., 13567., 13637.
4273., 4273. ,4284., 431P.,4352.,4/i2b.,4532.
4644.,4733.,4P I 7.•4892.,^970.,5053.,5129.
5208.,528|.,b336.,b398.,54bR.,55l2.,5565.
5609.»566r.,57CS.,57b4.,b791.,5847.,5R79.
59II.,5950.,5989.,6022.,6051. ,6093.,6134.
• OE50
1085.,1 11?R., 1118 I., 11273.,11437.,11615., 11830.
2051.,12221.,12384.,12532.,12684.,12846.,12994.
31 49., 13293., 13398., 1351.8., 13635., 1 3736. , 1 3837.
3924.,14020.,141C3.,14193.,14269.,14368.,14432.
4490.,!4564.*14637.,!469b.,14748.,14821.,14895.
10P5.,11128.,11!R1.,11273.,11437.,11615.,11R30.
2051.,1222).,12384.,12532.,12684.,12846.,12994.
3149.,13293.,1339K.J!3D 18.,13635.,13736.,13837.
3924. , 14020. , 14103. , 14193. , ! 4P',9«* 14368., 14432.
4490.,14564.,14637.,14695.,14748.,14«2l.» 14895.
3069., 3086., 3 107., 3 14/<., 3210., 3281., 336 7.
3455.,3523-,35KK.,36A8.,3708.,3773.,3R32.
3894., 39 b 2., 39 9 4., 4042. , 4089. , 4129. , 41 70.
4204., 4243.,4276., 4312.,^3^3.,4382.,440R.
4431 ., 4460.,/(490., 451 3. , AS34. , 4563., 4593.
1.OE50
47
-------
TABLE 7-B
"SITEXX" Data File
100 DENVER COLORADO
110 5300
120 SUMMER
130 3,20.,30.,35.
140 5f8.,10.,12.,15.,18.
150 .95
160 100.
170 8.,10.,12.,15.,18.
180 40.,40.,40.
190 0.0
200 150.
210 1.0
220 O.,0.,0.,.01,.11,1.18,2.69,3.79,4.98,6.26,7.80,8.93
230 8.34,7.73,8.03,7.89,8.18,8.22,6.31,4.09,2.46
240 1.36,.89,.41,.25,.07,.01,0.,.01,0.,O.,0.
250 1.OE50
TABLE 8-B
"SIXDAT" Data File
57., 28.5, 5.0F.09, 220400., 50., 600.
57., 28.5, 5.0E09, 220400., 75., 600.
57., 28.5, 5.0E09, 220400., 95., 600.
62., 31.0, 5.0E09, 220400., 50., 600.
62., 31.0, 5.0E09, 220400., 75., 600.
62., 31.0, 5.0E09, 220400., 95., 600.
48
-------
APPENDIX C
OUTPUT SAMPLES
49
-------
TABLE 3-C
Tower Sizing Program "TOWSIZ"
Dry Cooling Tower Sizing and Cos!1 Evaluation
Design Parameters
ITD = 40° F Range = 20° F
Heat Rejection = 4.0E-H)9 Btu/hr.
Water Flow per Hour = 2.2E+05
Ambient Air Temp = 50°F
Elevation = 0 ft.
Tower Sizing
Tower Height = 631.4ft.
Upper Diameter = 421 .8 ft.
Bottom Diameter = 671.7ft.
Gallons per Minute = 399824
Cost Evaluation
Tower Structure
Stack Cost
Shed Cost
Coil Cost
Total Structure
Condenser
Condenser Cost
Piping, Valves, etc.
Pipe Cost
Valve Cost
Pump Cost
Filler Pump Cost
Storage Tank Cost
Total Piping Facilities
Controls
Control Cost
Complete Tower Facilities
Total Tower Cost
Total Tower Cost and Contingencies
$3311729
1631071
6583000
$2383132
1309700
1800000
40000
39989
$11525799
$ 912000
$ 5362921
$ 500000
$18300721
$22875901
50
-------
TABLE 1-C
Program OPTDCT Output
SITE - DENVER, COLORADO
ELEVATION - 5300 FEET ABOVE SEA LEVEL
PEAK PERIOD - SUMMER
TURBINE - 800000 KW FOSSIL UNIT
IN OPERATION - 7500 MRSAR
AT FULL THROTTLE 50 0/0 OF THE TIME
AT 75 0/0 LOAD 50 0/0 OF THE TIME
AT 50 0/0 LOAD 0 0/0 OF THE TIME
TOTAL ANNUAL ENERGY - 5250000 MWH NOMINAL
TOWER - NATURAL DRAFT
COOLING SYSTEM OPERATION AND MAINTENANCE COST - 1 .00 0/0
DESIGN HEAT REJECTION - 4000 X 10**6 BTU/HR
CAPITAL COST MULTIPLIER - .95
CUTOFF TEMPERATURE FOR PEAKING GENERATION -OF
51
-------
TABLE 2-C
Program OPTDCT Output
Ol
ro
PHUT FUEL COST •
mn.
TEHP.
DIFF.
( F 1
30
31
32
33
39
37
39
*1
*Z
*3
*9
*7
*6
*9
50
51
52
93
;*
55
OPTIHUMt
56
50
59
60
61
62
63
6*
65
66
67
60
69
70
71
72
73
7*
76
77
78
79
BO
6ROSS
ENERGY
800 HH
(NHHI
52»*576
528*268
5263928
5293562
92827*6
5201763
5200616
9279287
5278521
5277700
5275092
5273797
5272630
5271398
5270098
5260699
5265621
$263957
5262209
5260358
5256322
525*15*
5251091
'5T*950S~
52*6990
52*161*
5238758
5235767
5232639
522936*.
5225958
5222*3*
5218761
521*939
5210950
5206822
5198139
5193561
5168826
5183939
5178903
• 20 CENT?,
ftST^TOO
EXCESS
ENERGY
PLANT - 8 0/0
M0"6 BTU
PEAKING CAPACITY -
PEAKING FUEL COST -
EXTRA PENALTY AUXILIARY LOSS OF AUXILIARY
(KMHI
3*35*
3*056
33739
33051
32360
31535
30712
29797
28735
27001
27268
26677
260*8
255*5
2**23
23793
23118
22563
21**0
2080*
20 125
195*2 ~
190*7
17895
f7T58—
16665
16201
1567*
1*»9Z
13881
13*32
12915
12353
11106
10676
10189
9655
9080
(IWH)
**
86
130
177
306
597
919
1*25
2097
28*3
*00*
*628
5279
5960
68* T
8802
9836
10909
12205
isiir
16650
1823*
20038
. 220*9
26281
30099
"33561
36310
*Z058
1.5120
*B*93
51965
55530
(2966
71363
75716
80177
(HUH)
93375
9062*
17966
85*01
80550
76071
7196*
68229
C*866
6332*
61875
59256
58006
57009
56'0rt '
5*878
5272*
517T7
50756
*98*2
(Ml
5*7*
6636
7877
9199
12095
1535*
18912
227*2
26672
ZB.697
30696
3*662
366*1
3*627
*0610
*2689
*705*
*9297
51565
53899
*815D 58586
1.7378 609*1
1.6*50 63327
*586t
*5099
1.3656
*2321
1.169k
. »109»
39975
39*02
398*7
30309
37788
36799
26329
35977
35**2
35029
68286
73*32
76100
79816
01571
8*1.09
90253
91236
96253
9911*
101993
10787*
110906
113986
117161
120375
(KIO
12*50
12083
11729
11387
107*0
101*3
9595
9097
86*9
6250
7901
77*5
7601
7*70
7317
7030
6896
6767
66*6
6*20
6317
6220
6ll5
6013
5821
56*3
5559
5*79
5330
5180
5108
5038
4906
*8**
*78*
*726
*670
g o/o AUXILIARIES - B o/o
*0 CENTS/10"6 8TU
CAPITAL
COST
COOLING
ftl
3369773
3232*06
3100*75
2973901
2737302
2522369
2329182
21577*0
20080*5
1860095
1773891
17ZB9**
16«9*3*
1655359"
1610668
1529837
ANNUAL
COST CREDIT
800 n» EXCESS
(SI (II
9577609 623*9
957795* 61873
9578330 613*2
9579736 ..60769
9579633 5953*
9580682 5829*
9581913 56811
9583326 55332
~95BV1'0* — 5*5*5
958*938 53689
9585JJS 52771
9586793 51776
9588916 50100
-«WO«— V9175-
9591281 1.6078
"9592576 — *"S«5"~
959395* *60*2
9596982 **023
1*91698 9598606 *2890
1*57077 9600310 1.1671
1*2*973
1368316
132173*
1Z95*ZO
1270360
122*170
1193078
116**5*
11*7112
111627*
1078*06
1059878
19*1617
1005902
9B8**8
971263
937698
969210* *0673
9606030 38653
9610391 36263
TBlTt'M — WOT"
9615115 3*3**
9620358 32270
9626171 30051
9629299 29217
9632*01 20271
96392** . 261*1
96*678* . 2*231
9650733 2330?
965*838 22299
9663SS* 200*0
9668221 1SZ71
96731*0 16392
96833*5 16393
PENALTY AUXILIARY
(1)
S0619
61569
732*9
85692
113110
1**837
179503
217779
257967
299*65
3*2909
•"36*163"
3870*5
*09370
1.33822
1.85706
51Z55Q
5*0017
569101
629692
692010
— row—
760526
833261
910515
95182k
99**21
106267*
1176*85
12236*2
12711*8
1370237
1*2303*
1*76850
1S8B507
11)
318321
30VB01
300008
283003
267307
252921
2398*3
228077
217620
200*76
COST OF COOLING
PLANT FUEL
<«> (tULL/KNH)
132t>3b
-------
APPENDIX D
FLOW CHARTS
53
-------
FLOW CHART OF PROGRAM "OPTDCT"
c
START
OPTDCT
ASSIGN STORAGE
DEFINE CONSTANTS
AND TABLES
READ TURBINE
CHARACTERISTICS
FROMJFILE "TURBIN"
CALL DATCIIK
TO CHECK IF CORRECT
NUMBER OF DATA
VALUES READ
CALCULATE
NOMINAL ANNUAL
MWH
54
-------
ISITE = 1
V
READ SITE INFORMATION
FROM FILE SITKNO
(ISITE)
SET WINTER OR
SUMMKR PEAK
FIND FIRST NCN-7.ERO
AND LAST NCN-7ERO
TEMPERATURE DURATION
IN TABL.E OF DURATIONS
TDUR (NTL) AND TDUR (NTU)
i r
CAUL DATCHK
55
-------
CUT- PUT HEADINGS
IDENTIFYING SITE, TYPE
OF TOvVER, TYPE OF
TURBINE AND
OTHER INFORMATION
CALCULATE THE K A' LOAD
FOR FULL THROTTLE, 3/4 LOAD
AND 1/2 LOAD AT THE
MAXIMUM OPERATING BACK
PRESSURE FOR LATER USE
IN THE INTERPOLATION
OF TABLES (LOAD)
1 1
CALCULATE THE KW LCAD
FOR 3/4 LOAD AND 1/2 LOAD
AT THE CALCULATED BACK
PRESSURE (LOAD1)
DETERMINE HEAT REJECTION
AT VARIOUS LOADS BY
INTERPOLATION
13
56
-------
COMPUTE HOURS IN TH".EE
HIGHEST TEMPERATURE
DURATIONS
14
DETERMINE FIRST TEMPERATURE
FOR TEN HOURS DURATION
15
1TD = 30
16
G>
THETA - ITD
I = ITD -29
n.
DETERMINE CAPITAL COST
BY INTERPOLATION
18
MODIFY CAPITAL COST
BY CAPITAL COST FACTOR
19
57
-------
CALCULATE A IN
JTD = A* (HEATREJ)Z
20
SET LOOP CONTROL
FOR LOADS
21
SET LOOP CONTROL
FOR TEMPERATURES
22
INITIALIZE ITERATION COUNTER
(ITER = 0) AND BACK PRESSURES
(BPT = O, OPBP = BPMIN)
23
G>
0
CALCULATE COOLED WATER
TEMPERATURE
24
58
-------
FIND CORRESPONDING
PRESSURE FROM STEAM TABLES
ABS(OPBP-BPT) . LT. 0.01
INTERPOLATE TO FIND
HEAT REJECTION
AT BACK PRESSURE
1
f
k6A
59
-------
\t
ITER = ITER + 1
30
PRINT ERROR
MESSAGE
OPBP = BPM1N
YES
COMPUTE TOTAL ANNUAL
HOURS (HRS) AT GIVEN
LOAD AND TEMPERATURE
35
60
-------
INTERPOLATE TO FIND MAX.
KW AT CALCULATED BACK
PRESSURE
COMPUTE PLANT OUTPUT
SUBJECT TO MAX. CALCULATED
ABOVE
38
39
COMPUTE MAXIMUM HEAT
REJECTION
61
-------
CALCULATE REDUCED PLANT
OUTPUT BY TABLE LOCK-UP
40
INTERPOLATE TO FIND
STATION HEAT HATE
41
\r
ACCUMULATE TOTAL BTU's
USED FOR A YEAR'S OPERATION
42
NATURAL OR
MECHANICAL DRAFT
TO.VER
TABLE LOOK UP TO FIND
MAXIMUM AUXILIARY
REQUIREMENTS .
62
-------
45
LINEAR INTERPOLATION TO GET
ACTUAL AUXILIARIES AT GIVEN
ITD AND AMBIENT AIR
TEMPERATURE
COMPUTE AUXILIARY KWH
(AUXKWHj)
46
DETERMINE AUXILIARY POWER
(AUXKWHj) REQUIREMENTS AS A
FUNCTION OF ITD BY TABLE
LOOK-UP
47
COMPUTE AUXILIARY ENERGY
REQUIREMENTS (AUXKiVHj)
48
49
ACCUMULATE TOTAL ENERGY
PRODUCED BY PLANT (KWH)
63
-------
COMPUTE. CAPACITY LOSS
OR GAIN (CAPLOS)
50
I NO
COMPUTE ENERGY GAIN IN
KWH AND BTU's
AIRTNT .GT. CUTOFF
ACCUMULATE ENERGY
LOST IN KWHBL'O,
55
YES \ <
53
ACCUMULATE ENERGY
LOST IN KWHABV.
STORE KW LOSS FOR THREE HIGHEST
AIR TEMPERATURES IN
64
-------
SAVE TOTAL ANNUAL ENERGY
PRODUCED IN M»VH,
1 I
62
DETERMINE CAPACITY LOSS
AT AIR TEMPERATURE EQUALLED
OR EXCEEDED 10 HRS./YR.
65
-------
WRITE HEADINGS ONTO
OUTPUT FILE
1
i
ITD = 29
TANT = 1.OE50
I = 1
\
.
ITD = ITD + 1
68
69
66
-------
CALCULATE ANNUAL CAPITAL COST
AS A FUNCTION OF TOTAL
CAPITAL COST
70
CALCULATE ANNUAL OPERATION
AND MAINTENANCE COST. ADD TO
ANNCAP TO GET TOTAL
ANNUAL COST ON CAPITAL
INVESTMENT (ACCAOM)
71
CALCULATE ANNUAL
FUEL COST
WINTER OP
SUMMER PEAK
COMPUTE CAPITAL
AND OPERATING
PENALTY COSTS
COMPUTE OPERATING
COST PENALTY
COMPUTE TOTAL
PENALTY COST
76
67
-------
COMPUTE TOTAL
ENERGY LOSS
77
78
COMPUTE AUXILIARY CAPITAL
COST, FUEL COST AND
OPERATING COST. AND TOTAL
ANNUAL COST
SUM UP ALL
ANNUAL COSTS
TANT = TANCST
ISAVE = ITD
82
WRITE TEMPORARY
OUTPUT FILE
68
-------
/ 1=1+1
83
84
YES
85
COPY TEMPORARY OUTPUT
FILE ONTO ACTUAL
OUTPUT FILE
J = J
87
-------
90
KITE = ISITE + 1
70
-------
FLOW CHART OF PROGRAM "TOWSIZ"
DEFINITION OF CONSTANTS:
ALL VALVES TO BE USED
FOR TABLE LOOK UP
PROCEDURES IN PROGRAM
EXECUTION
1. 01
SCALE TABLE
ENTRIES
(TERMINATE!)
V RUN J
C
1.02
TOWER
SIZING
START
YES
1.03
1.04
1.08
NO
READ SITE DATA:
FROM ONE LINE OF FILE
"SIZDAT" READ ITD,
RANGE HTREJ, GO,
AMAIRT AND ELEV
COMPUTE INTERMEDIATE SIZING:
CONDENSATE FLOW, NUMBER OF
COOLING COLUMNS (ROUND TO
NEXT INTEGER DIVISIBLE BY 4),
Qo AND Qj
1.05
i NO CURVE
CORRESPONDING
TO ENTERED
1.06
LOOP TO
DETERMINE WHICH
G0 CURVE IS BEING USED
CORRESPONDING
71
-------
1.11
PRINT /Ql OUTSIDE
ERROR /OF ENTEREC
• 1"1- 3
"Ql TABLES
1.10
CALL ROUTINE "TBLUQ1
FIND
TO
L0 BY QUADRATIC
INTERPOLATION USING Q,
AND TABLES Qj AND LQ
VALUES.
NORMAL EXIT
1.12
CALL "TBLUQ" TO FINDAP
BY QUADRATIC INTERPOLATION
IN ENTERED TABLES.
1.13
COMPUTE EXIT VELOCITY,
EXIT LOSSES, DRAFT
LOSSES, TOTAL LOSSES
\
1.14
COMPUTE AIR HEATING,
AIR TEMPERATURE
CHANGE AND FINAL
AIR TEMPERATURE
1.15
COMPUTE TOWER
DRAFT HEIGHT
72
-------
SET LOWER
DIAMETER EQUAL
TO UPPER
DIAMETER
1.21
CALL "TBLUQ" TO FIND
HEIGHT ADJUSTMENT FACTORS
FOR AMBIENT TEMPERATURE
AND SITE ELEVATION
\
f
COMPUTE ADJUSTED DRAFT HEIGHT
FROM DRAFT HEIGHT AND
ADJUSTMENT FACTORS AND TOTAL
HEIGHT FROM ADJUSTED
HEIGHT PLUS 80 0 FEET
\
J
CALL "TBLUQ" FOR EXIT
VELOCITY ADJUSTMENT
IN UPPER DIAMETER
CALCULATION.
(
COMPUTE UPPER STACK AREA,
UPPER DIAMETER AND
LOWER DIAMETER
1
1.16
1.18
1.19
1.20
LOWER DIAMETER
LESS THAN
UPPER DIAMETER?
73
-------
4A
,1.23
NO SUCH
ENTRIES
FOUND
FIND —-^ 1-22
TNTRIES IN TABLE
5F STACK DIAMETERS WHICT
VLCULATED UPPER D1AMETEJ
FALLS BETWEEN
ENTRIES FOUND
CALL "TBLUQ" TO COMPUTE COST
OF STACK AT CALCULATED HEIGHT
FOR EACH OF TWO LIMITING
TABLE DIAMETERS
1
i
COMPUTE ACTUAL STACK
STRUCTURE COST BY
LINEAR INTERPOLATION OF
DIAMETER BETWEEN TWO
CALCULATED TABLE DIAMETERS
1
r
COMPUTE ROOF COST BY AREA
DIFFERENCE BETWEEN STACK
TOP AND BOTTOM. COMPUTE
TOTAL COIL COST
i
r
CALL"TBLUQ" TO FIND CONDENSE!
COST PER 109 BTU FROM
RANGE VALUE IN TABLE OF
CONDENSER COSTS. COMPUTE
TOTAL CONDENSER COST
i
1
1.24
1.25
1.Z6
\.n
74
-------
1.28
COMPUTE NUMBER
OF
DELTAS
1.29
CALL "TWRPIP" SUBROUTINE
TO COMPUTE ALL PIPING,
VALVE AND ASSOCIATED
COSTS
1.30
PRINT ONE PAGE
SIZE AND COST
SUMMARY
75
-------
FLOW CHART OF FUNCTION "TBLUQ"
START
TBLUQ
IS LOOK UP
VAL UE WITHIN LIMITS
OF GIVEN TABLE?
IS GIVEN
VALUE BELOW LOWEST
TABLE ENTRIES?
IS GIVEN
VALUE ABOVE HIGHEST
TABLE ENTRIES?-
SET RETURN
VALUE TO
CORRESPONDING
INTERPOLATION
TABLE ENTRY
IS ENTERED
VALUE EQUAL TO
THIS TABLE ENTRY?
ERMINAT
TBLUQ
;SET LOOP
THRU ALL
TABLE
ENTRIES
76
-------
YES
^ YES
IS ENTERED
VALUE GREATER THAN
THIS TABLE ENTRY AND
ESS THAN NEX
2.09
IS ENTERED
VALUE LESS THAN
THIS TABLE ENTRY AND
GREATER THAN
NEXT?
^
NO
2. 10
END OF
TABLE
CHECK
LOOP
WITHIN
FIRST TWO TABLE
ENTRIES ?
2. 12
- 2.11
INTERPOLATE WITH PRECEDING.
SUCCEEDING AND SECOND
SUCCEEDING VALUES.
EVALUATE QUADRATIC
INTERPOLATION
EXPRESSION AND SET
RETURN VALUE
2.15
^TERMINATES
YTBLUQ )
77
-------
FLOW CHART OF SUBROUTINE "TWRP1P"
c
START TWRPIP
CALCULATE WATER FLOW RATE
TO TOWER AND WATER FLOW
RATE PER LEVEL
3.01
\
CALL ROUTINE "PIPSIZ"
TO CALCULATE MAIN SUPPLY LINE
AND THE COST/FT PLUS
COST/VALVE
3.0Z
CALCULATE THE MAIN SUPPLY LINE
LENGTH AND COST. NUMBER OF
VALVES AND COST AND
NUMBER OF LINES
3.03
CALCULATE HEADER PIPE
WATER FLOW RATE
3.04
CALL ROUTINE "PIPSIZ" TO
CALCULATE HEADER PIPE SIZE,
ITS COST/FT AND CORRESPONDING
VALVE COST AND THE NUMBER
OF LINES
3.05
78
-------
0
CALCULATE PIPE LENGTH, PIPE
COST, NUMBER OF VALVES
AND VALVE COSTS
3.06
3.07
CALCULATE THE NUMBER OF
DELTAS PER SECTOR
3.08
CALCULATE DRAIN PIPE
WATER FLOW RATE
3.09
CALL PIPSIZ TO CALCULATE THE
DRAIN PIPE SIZE AND COST/FOOT.
THE NUMBER OF VALVES
AND COST PER VALVE
3.10
CALCULATE PIPE LENGTH AND
COST THE NUMBER OF VALVES
AND COST
79
-------
CALCULATE THE FILLER PIPE
WATER FLOW RATE
3. 11
CALL "PIPSIZ" TO CALCULATE THE
FILLER PIPE SIZE AND COST/FT
AND THE NUMBER OF VALVES AND
COST/VALVE
3.1Z
CALCULATE THE LENGTH OF PIPE
AND ITS COST AND THE NUMBER
OF VALVES AND THEIR COSTS
3.13
CALCULATE THE NUMBER OF
BY-PASS VALVES AND COSTS
3.14
CALCULATE THE EMERGENCY
DRAIN PIPE WATER FLOW RATE
3.15
CALL PIPSIZ TO CALCULATE THE
EMERGENCY DRAIN PIPE SIZE AND
COST/FT AND THE COST PER VALVE
3.16
80
-------
CALCULATE THE LENGTH OF
EMERGENCY DRAIN PIPE AND ITS
COST AND THE NUMBER OF VALVES
AND THEIR COSTS
3. 17
CALCULATE THE NUMBER OF
CIRCULATLNG PUMPS AND THEIR
COST
3. K
3. 19
CALCULATE FILLER PUMP COST
3.ZO
CALCULATE STORAGE TANK COST
3. 21
SUM UP PIPING, VALVES. PUMPS.
AND STORAGE TANK COSTS
c
TERMINATE TtfRPIP
81
-------
FLOW CHART OF SUBROUTINE "PIPSIZ"
CALCULATE PIPE SIZE
4.01
FIND THE CORRESPOND PIPE COST
AND VALVE COST
v
c
4.04
TERMINATE PIPSIZ
82
-------
APPENDIXE
GLOSSARY
83
-------
Glossary of Terms Used in the
Cooling Tower Optimization Program
"OPTDCT"
A - The coefficient of the equation
ITD = A x (Heat Rejection 10° Btu/hr)Z
which defines the operating characteristics of a dry cooling tower.
ABS - Absolute, Library function of the computer.
ACCAOM - Annual capital cost and operating and maintenance costs.
AIR - Variable used to store the three highest non-zero ambient air tem-
peratures for each site.
AIR10 - Variable used to store the air temperature which is equalled or
exceeded ten hours per year. (Sometimes called "the ten hour air
temperature".)
AIRT - An array that contains air temperatures corresponding to the table
of durations in the site data . Values from 117°F to -38°F in 5°
increments (117°, 112°, 107°, . . .-28°, -33°, -38°).
AMAX1 - Maximum, Library function of the computer.
AMIN 1 - Minimum, Library function of the computer.
ANNCAP - Annual capital cost determined by applying the appropriate (fixed-
charge rate) to the total capital cost for the given ITD.
ANNFUL - Annual fuel cost determined by applying the appropriate unit cost
of fuel to the total Btu's used for the given ITD.
ASTER - Variable used only in output format indicating a number raised to
a power.
AUX100 - Table of full auxiliary power requirements vs. ITD for mechanical-
draft towers.
AUXCAP - The capital cost of auxiliary power required in dollars.
84
-------
AUXCST - The total annual cost for the auxiliary power and energy necessary
to the cooling system.
AUXKW - The maximum power needed for the cooling system auxiliaries
(pumps and fans).
AUXKWH - Variable used to store the energy value for the auxiliary require-
ments of the cooling system.
AUXOPR - Annual operating cost incurred in supplying the necessary auxiliary
energy.
AUXTEM - Variable used to store the maximum and minimum air temperature
used in calculating the percentage of full auxiliary power require-
ments for a mechanical-draft tower for a given ITD.
AUXTMP - Table of air temperatures corresponding to the maximum (100%) and
minimum (53%) percentage of full auxiliary power requirements for
a mechanical-draft tower.
B - Variable used for temporary storage of capital costs for a given
ITD corresponding to elevations of sea level, 3,000 and 6,000 feet.
BP - An array which contains a table of back pressures which cover the
range of operation from 1 .0 inch Hg to 18.0 inches Hg in steps of
.5 inch Hg. Corresponds to values of full throttle kw, station heat
rate, and heat rejected to the cooling system. From the turbine
data file.
BPMAX - Maximum allowable turbine back pressure (inches Hg).
BPMIN - Minimum allowable turbine back pressure (inches Hg).
BPT - Variable used for temporary storage of the calculated back pressure
used in the calculations for finding the operating back pressure of
the turbine.
CAPCST - Variable used for storing and calculating the capital costs of the
cooling system
CAPLOS - Variable used in the calculation of the loss or gain of capacity
(kw) resulting from turbine operation above or below a back pres-
sure of 3-1/2 inches Hg.
85
-------
CCF
CCFGT
CCM
CPWAX
CRDBTU
CREDIT
CUTOFF
DUR
ELEV
FCSTAX
FTKW
FTKWT
FULAUX
FULCST
The capital cost factors (fixed-charge rates) applied to the cooling
system capital cost represents annual cost.
Capital cost factors (fixed-charge rates) applied to the capital cost
of peaking units used to replace capacity losses.
Capital cost multiplier. This variable is used to adjust for varia-
tions in construction cost.
Capital cost (in $/kw) of providing auxiliary power. ($150/kw for
fossil-fueled units and $225/kw for nuclear-fueled units).
Array used to retain the Btu of excess energy. Excess energy is
produced only under full throttle operation at back pressures below
3.5 inches Hg and in the energy resulting from power production in
excess of 800 mw. One value per given ITD.
Annual credit, in dollars, determined by applying the appropriate
fuel cost CRDBTU.
The air temperature at or above that at which the lost power and
energy is replaced by a peaking unit.
Variable used to retain the first three non-zero temperature dura-
tions corresponding to the three highest temperatures for each site.
Elevation (feet above sea level) of each site being studied.
Variable used for the incremental cost (mills/kwh) auxiliary energy.
This cost is the annual plant fuel in mills/kwh plus an operation
and maintenance allowance of 0.1 mill/kwh.
An array containing the full throttle capabilities of the turbine
corresponding to bac, pressures from 1 .0 inch Hg to 18.0 inches Hg
in 0.5 inch steps.
Variable used for temporary storage of full throttle output of the
turbine corresponding to the actual operating back pressure.
Variable used to store the full auxiliary power requirements (100%)
for a given ITD for a mechanical-draft tower.
The fuel cost for 800-mw unit for the given site in C/10 Btu.
86
-------
GHR
HREJ
HREJD
HREJ MX
HREJT
HRJ
HRS
HRSPYR
IJ, IJ2
IJ1
IK
IL
I SAVE
Plant heat rate with a value corresponding to each value of back
pressure.
Heat rejected by the turbine with a value corresponding to each
value of GHR.
Design heat rejection of the turbine (4 x 10? Btu/hr for a fossil unit
or 6 x 109 Btu/hr for a nuclear unit).
Maximum heat rejection obtainable when the turbine is backed
down to operate within its prescribed limits.
Heat rejection associated with the maximum allowable back pres-
sure for the three operating levels of full throttle, 3/4 load and
1/2 load.
Temporary value of heat rejected by the turbine for use in determin-
ing the operating back pressure.
Number of hours of operation for a given load (PCTTIM) at a given
air temperature (TDUR) based on the number of operating hours per
year (OPHRS).
The number of hours in a year. Assumed to be 8,760.
Variable subscript corresponding to values of ITD (1=1, ITD = 30;
I = 2, ITD = 31; etc.).
Variable subscript corresponding to curves of percent of full auxil-
iary power requirement vs. ambient air temperature for different
ITD for a mechanical-draft tower.
Variable subscript corresponding to the curve IJ + 1 of percent of
full auxiliary power requirement vs. air temperature for a mechan-
ical-draft tower.
Variable subscript associated with the capital cost curves corres-
ponding to elevations of sea level, 3,000 feet, and 6,000 feet.
Subscript used to cycle through the three combinations of percent
load (PCTLD) and percent tii-ne (PCTTIM).
Variable used to store the optimum ITD for each run.
87
-------
ISITE
IT
1TD,THETA -
ITER
ITYPE
IWSP
K
KW
KWAX
KWH
KWHABV
KWHBLO
Variable subscript used to denote the site on which the program is
operating.
Variable subscript used to associate the loss or gain of capacity with
the first three non-zero temperature durations.
Variable used interchangeably to indicate the initial temperature
difference which is the difference between the saturation tempera-
ture of the condensing steam and the ambient dry-bulb air temper-
ature .
Variable used as a counter to keep track of the number of iterations
needed to converge the operating back pressure.
The name of the basic type of fuel used for the turbine, either
fossil or nuclear.
Variable indicator relating to the peaking period for the site.
Peaking period being either winter (IWSP = 1) or summer (IWSP =
2).
Variable subscript used to denote the appropriate capital cost fac-
tor (fixed-charge rate) and capital cost factor for gas turbine asso-
ciated with each run.
Variable subscript used to denote the appropriate plant fuel cost
and peaking fuel cost associated with each run.
Turbine nameplate rating in kw.
Array of auxiliary power requirements for the natural-draft tower.
Six values corresponding to ITD values of 30°F, 40°F, 50°F/ 60° F,
70° F and 80° F.
Variable used twice, first for calculating the nominal energy pro-
duced by the plant (kwh) and secondly for calculating the energy
produced under given conditions (kwh).
The total energy loss occurring when the ambient air temperature
is equal to or above the cutoff temperature. One value for each
ITD (kwh).
The total energy loss occurring when the ambient air temperature
is below the cutoff temperature. One value for each ITD (kwh).
-------
KWHGAN
KWHLOS
KWLOS
KWLOSS
LOAD
LOAD1
MILPKW
MWH
NCCF
NFUL
NHR
NT
NTL
The excess energy produced when operating at full throttle and be-
low 3-1/2 inches Hg back pressure. One value for each ITD (kwh).
The energy lost when operating at full throttle and above 3-1/2
inches Hg back pressure. One value for each ITD (kwh).
Variable used in calculating the loss of capacity (KWLOSS) at the
ten hour air temperature. One value, in kw, for each of the thre,e
highest air temperatures.
The lost capacity associated with the ten hour air temperature. One
value, in kw, for each ITD.
The turbine output in kw corresponding to the maximum allowable
back pressure and the appropriate load condition (full throttle, 3/4
load and 1/2 load).
Three values of turbine output, the first value being the output at
the actual operating back pressure at full throttle and the remain-
ing two values corresponding to the output at the maximum allow-
able back pressure for 3/4 load and 1/2 load operation respectively.
Total annual cost of the cooling system and total plant fuel cost.
One value for each ITD (
Variable used to retain the amount of energy actually produced by
the turbine for a given set of operating conditions.
The number of capital cost factors (fixed-charge rates) to be used
for each si te .
The number of base fuel costs and the number of peaking fuel costs
to be used for each site.
Net heat rate of turbine. Not used in program calculations but
used to skip over net heat rate values on data file (Btu/kwh) in
order to leave data file general .
Variable subscript used to denote the 32 values of temperature dur-
ation and air temperatures.
Subscript of the first non-zero temperature duration in the array
TDUR.
89
-------
NTU - Subscript of the last non-zero temperature duration in the array
TDUR
OAMCT - Operating and maintenance cost as a percentage of capital cost.
ONM - Variable operation and maintenance cost (mills/kwh).
OPBP - Actual operating back pressure of the turbine for a given set of
conditions.
OPGHR - Actual operating station heat rate of the turbine for a given set of
conditions.
OPHRS - The number of hours per year of plant operation.
OPMAT - Operation and maintenance cost.
OPTDCT - Optimization of Dry Cooling Towers. The name of the program.
OPTOUT - The name of the file in which the program results are stored.
P An array which contains the saturation pressures for a table of
saturation temperatures (°F)vs. saturation pressures (inches Hg).
PAUSE - Library subroutine used if the program does not function correctly.
PCCST - Peaking unit capital cost ($Aw).
PCT - Percent of full auxiliary power requirement for a mechanical-draft
tower for a given ITD, air temperature and load.
PCTLD - Percent load at which the turbine is operating; i.e., 100% for full
throttle, 75% for 3/4 load, and 50% for 1/2 load.
PCTLOD - The three operating conditions of the turbine; 100% for full throttle,
75% for 3/4 load and 50% for 1/2 load.
PCTTIM - The percent of time the turbine will be operating at a specific load
level.
PEAK - Peaking period for each site (summer or winter).
90
-------
PENCAP
PENLTY
PENOPR
PFCST
PLITD
SATP
SATT
SITE
SITENO
T ANGST
TANT
TAXKWH
TBLELV
TBLITD
TBLUQ
TDUR
TEMP
Annual capital cost of replacing the generating capacity lost at the
air temperature that is equalled or exceeded ten hours per year.
The annual cost of replacing capacity and energy losses.
PENLTY = PENCAP + PENOPR.
Annual operating cost related to the replacement of the energy lost
due to operation at back pressures in excess of 3-1/2 inches Hg.
Peaking unit fuel cost ($/106 Btu).
Part load ITD.
Saturation pressure (inches Hg).
Saturation temperature (°F).
Variable used to store the site names.
An array that contains the names of the 27 data files containing
site information. SITE01, SITE02, , SITE 27.
An array which contains the saturation temperatures for a table of
saturation temperatures (°F) vs. saturation pressures (inches Hg).
Total annual cost of the cooling system and total plant fuel ($).
Variable used in finding the optimum ITD.
Auxiliary energy in mwh.
Table of elevations (0, 3,000, and 6,000 feet above sea level).
Table of ITD from 30°F to 80°F in 10° increments.
Table look-up subroutine used in the program.
Temperature durations in the site data. These durations are the
percent of time during a year that the ambient air temperature is
within a given 5° range.
Temporary variable used for storage in several locations in the
program.
91
-------
TKW
TKWGAN -
TMWH
TOTBTU
TOTCAP -
TOWER
TURBIN
The maximum output of the turbine under a given set of conditions
within the limiting values.
Excess energy, in mwh, produced when operating at full throttle and
below 3-1/2 inches Hg back pressure.
Nominal annual energy, in mwh, produced by the 800-mw generat-
ing plant for the given loading assumptions.
The total annual fuel consumption, in Btu, for the given loading
assumptions.
Capital cost corresponding to site elevation and 1TD.
Variable containing the type of tower used in the cooling system,
either "Natural Draft" or "Mechanical Draft".
Name of the data file containing the turbine data.
92
-------
DATCHK
FILE
INCT
NFIL
SITE
SPVSST
TURBIN
Glossary of Terms Used in Subroutine
"DATCHK"
Data check, name of the subroutine.
Variable containing the names of the data files.
Variable used as a counter.
The number of the tape the data file is on.
Name of the file containing the site data.
Variable used to hold space for a file name that could be inserted
at a later date.
Name of the file containing the turbine data.
93
-------
Glossary of Terms Used in Subroutine
"TBLUQ"
A - Coefficient of X2 in the equation TBLUQ = AX2 + BX + C.
ABS - Library function used to find the absolute value of a number or
function.
B - Coefficient of X in the equation TBLUQ = AX2 + BX 4- C.
C - Constant in the equation TBLUQ = AX2 + BX -f C .
DET - Variable used in the calculation of A7 B, and C.
I - Subscript.
N - Subscript.
NVAL - Number of X and Y values in the table which the value Is being
sought.
TBLUQ - Name of the subroutine and the value which is being sought.
X - The variable for a corresponding Y value.
XI ,X2,X3 - The three X values used in the interpolation from the table of
values being used.
X1S,X2S, - The XI, X2, and X3 values squared, respectively.
X3S
XT - The table of X values being used.
Yl ,Y2,Y3 - The three Y values used in the interpolation from the table of
values being used.
YT - The table of Y values being used.
94
-------
Glossary of Terms Used in the
Tower Optimization Program
"TOWSIZ"
ADRA - Air density ratio - elevation.
ADRFTH - Adjusted draft height.
ADRT - Air density ratio - temperature.
AEXIT - Air exit velocity.
AFACTR - Altitude density ratio table.
AIRDLT - Air temperature increase.
AIRHT - Air heat gain.
AMAIRT - Ambient air temperature.
CNDCST - Table of condenser costs.
COILS - Cost of heat exchangers.
CONDF - Condensate flow.
CPBTU - Condenser cost per billion Btu per hour.
CURVGO - Table of water flows.
DELTAP - Coil losses.
DNDNSR - Table of condenser cost.
DPTBL - Table of coil losses.
DRAFTH - Draft height
DRAFTLS - Draft losses.
DROOF - Cost of delta roof.
ELEV - Elevation.
95
-------
EXITLS
EXITV
FAIRTNI
GO (G0)
HEIGHT
HTREJ
ITD
LO (L0)
LOTBL
LOWDIA
N
P
QO (Qo)
Ql (Q})
Q1TBL
RANGE
RTEMP
STACK
STDIAM
STKCST
STKHT
TEMPS
Exit losses.
Exit velocity (20fps)
Final air temperature.
Water flow
Table of altitudes.
Heat rejection.
Initial temperature difference.
Air flow (metric tons/hr.).
Table of values of air flow.
Bottom diameter of tower.
Number of heat exchanger columns.
Pressure drop across the coi I .
Heat rejection per hour per column (Btu).
Heat rejection per hour per degree of ITD.
Table of values of heat rejection per hour per column per degree
ITD.
Temperature change of condensate .
Temperature range table for condenser cost.
Cost of stack .
Table of tower stack diameters.
Table of stack costs.
Table of stack heights.
Temperature table.
96
-------
TFACTR
TOTALH
TOTLOS
U PARE A
OPDIAM
Temperature density ratio table
Total draft height.
Total losses.
Tower area at top.
Top diameter of tower.
97
-------
Glossary of Terms Used in Subroutine
"TWRPIP"
BDIAFT
BPVALD
BPVALS
BPVCST
BTUPHR
DELHI
DELPSE
DGPM
DPCST
DPD
DPFT
DPLEN
DPRFT
DPRVAL
DVCST
DVD
EDGPM
EDPCST
EDPLEN
EDVCST
Diameter of the base of the cooling tower.
Cost per valve for bypass valves.
Bypass valve size (inches).
Bypass valve cost ($).
Btu per hour.
Delta Height (ft.).
Number of deltas per sector.
Drain flow rate (gpm)
Drain pipe cost ($).
Unit cost of drain pipe ($/ft.).
Table of pipe cost ($/ft.).
Length of drain pipe (ft.).
Pipe cost corresponding to pipe size ($/ft.).
Valve cost corresponding to valve size ($/valve).
Drain valve cost ($).
Unit cost of drain valves ($/valve).
Rate at which water must be drained in case of an
emergency (gpm).
Cost of emergency drain pipe ($).
Emergency drain pipe length (ft.).
Emergency drain valve cost ($).
98
-------
EDVD
FGPM
FPCST
FPD
FPLEN
FVCST
GAPDEL
GPM
GPMPL
HGPM
HPCST
HPD
HPLEN
HVD
HVCST
IFPSET
IPSETS
MPCST
MPP
MPLEN
MPS
MVCST
MVD
Cost per valve for emergency drain valves ($).
Flow rate at which cooling system is filled (gpm).
Filler pipe cost ($).
Cost per foot for filler pipe ($/ft.).
Length of filler pipe (ft.).
Filler valve cost ($).
Gallons of water per delta.
Flow rate for cooling condensate (gpm).
Flow rate per level (gpm).
Flow rate in header pipes (gpm).
Header pipe cost ($).
Cost per foot of header pipe ($/ft.).
Length of header pipe (ft.).
Cost per valve for header valves ($).
Cost of header valves ($).
Number of filler pumps required.
Number of circulating pumps required.
Cost of main supply line pipe ($).
Cost per foot for main supply line ($/ft.).
Length of supply line (ft.).
Size of main supply line (inches).
Cost of main supply line valves ($).
Cost per valve for main supply line valves ($).
99
-------
NBPV
NDELPL
NDV
NEDL
NEDVAL
NFV
NHSL
NHV
NMSL
NMVAL
MODEL
NOL
NOLEV
NSECPL
NSL
PCOST
PDIA
PI
PIPSIZ
PSIZE
STCST
STLBS
TNMSL
Number of bypass valves.
Number of deltas per level.
Number of drain valves.
Number of emergency drain lines.
Number of emergency drain valves.
Number of filler line valves.
Number of header supply lines.
Number of header valves.
Number of main supply lines.
Number of main supply line valves.
Number of cooling deltas.
Number of lines.
Number of levels of cooling deltas.
Number of sectors per level.
Number of supply lines .
Circulating water pump cost ($).
Diameter of the different pipe (inches).
3.14159.
Name of subroutine that calculates diameter.
Table of pipe sizes (inches).
Storage tank cost ($).
Weight of storage tank (Ibs.).
Total number of main supply lines.
100
-------
TPCST - Total pipe cost ($).
TPVCST - Total pipe and valve cost ($),
TVCST - Total valve cost ($).
101
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