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.
                                       8

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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.
                                     10

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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.

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 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

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 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

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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

-------
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

-------
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

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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

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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

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                       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

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                         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

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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

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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

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                      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

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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

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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

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TPCST      -   Total pipe cost ($).




TPVCST    -   Total pipe and valve cost ($),




TVCST     -   Total valve cost  ($).
                                     101

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