WATER POLLUTION CONTROL RESEARCH SERIES • 16130 DHS 01/71
              A SURVEY OF
        ALTERNATE METHODS FOR
      COOLING CONDENSER DISCHARGE
                WATER

       SYSTEM, SELECTION, DESIGN,
           AND OPTIMIZATION
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 pollution in our Nation's waters.  They provide a
central source of information on the research ,  develop-
ment, and demonstration activities in the Water  Quality
Office, Environmental Protection Agency, through inhouse
research and grants and contracts with Federal,  State,
and local agencies, research institutions, and industrial
organizations.

Inquiries pertaining to 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, Room 1108,
Washington, D. C.  20242,

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               A  SURVEY OF ALTERNATE METHODS

            FOR COOLING CONDENSER DISCHARGE  WATER


          SYSTEM,  SELECTION,  DESIGN, AND OPTIMIZATION
                                by
                     DYNATECH R/D COMPANY
             A Division of Dynatech Corportation
                Cambridge, Massachusetts  02139
                               for the

                      WATER QUALITY OFFICE
                ENVIRONMENTAL PROTECTION AGENCY

                       Project No.  16130 DHS
                      Contract No.  12-14-477
                          January,  1971
For sale by the Superintendent of Documents, U.S. Government Printing Office, Washington, D.C. 20402 - Price $1.00
                         Stock Number 5501-0142

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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 signify that the contents
necessarily reflect the views and policies 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

Section

  1        INTRODUCTION                                                 1

           1.1   Overall Program Goals                                    1
           1.2   Scope of Task I                                           1
           1.3   General Method                                           3

  2        POWER  PLANT MODEL                                         6

           2.1   General Description                                       6
           2.2   Input Data                                                6
           2.3   Preparation of Input Data Cards                            9
           2.4   Test Data                                               11
           2. 5   Power Plant Calculations in the Main Program              12
           2.6   Program Optimization                                    17

  3        ONCE-THROUGH COOLING                                      19

           3.1   General Description                                      19
           3.2   Assumptions                                             19
           3.3   Basic Equations                                          20
           3.4   Plume Anajysis                                          22
           3.5   Flow Diagram                                           27
           3.6    Results                                                 27
  4        COOLING POND                                                35

           4.1   General Description                                      35
           4.2   Assumptions                                             35
           4.3   Basic Equations                                          36
           4.4   Flow Diagram                                           36
           4.5   Results

  5        MECHANICAL DRAFT WET  COOLING TOWER                    44

           5.1   General Description                                      44
           5.2   Assumptions                                             44
           5.3   Basic Equations                                          45
           5.4   Flow Diagram                                           49
           5.5   Results                                                 49
  6        NATURAL DRAFT WET COOLING TOWER                        54

           g  i    General Description                                      54
           g 2   Assumptions                                             54
           g'3   Basic Equations                                          55
           6]4   Flow Diagram                                           56
           6' 5   Results                                                  56

          REFERENCES                                                  62

          APPENDIX                                                     65
                                     iii

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                                  Section 1
                               INTRODUCTION

1.1     Overall Program Goals

           In December 1968, Dynatech R/D Company undertook a program for the
  Federal Water Quality Administration (then the FWPCA) with the ultimate aim of
  performing a survey and economic analysis of alternate methods for cooling  conden-
  ser discharge water from thermal power plants.  The first phase of this program
  was to consist of a systematic  gathering of present state-of-the-art information in
  the areas of large scale heat rejection equipment, power plant operating characteris-
  tics,  and total community considerations. The second  phase of this program was to
  consist of work in the areas of:

           1.       Selection of input parameters and optimization  criteria.

           2.       Limitations and advances in heat rejection units.

           3.       Extensive modifications of present power cycles.

           4.       Advanced total community concepts.

This report will document the results of Phase II, Task  I of this program.

1.2     Scope of Task I

           The first task of the second phase of this program has as an overall goal
the quantitfication of cooling system costs as a function of various parameters,  the
definition of the interface requirements between the power plant and the cooling system.
and the optimization of the total power cost.

           A previous task,  as  reported in July 1969, (Ref.  1) presented,  in  detail,
considerations of alternate methods of transferring large quantities  of rejected heat
to the atmosphere.  The  results of this analysis led to the expected conclusion that,
for a given heat level and ambient conditions,the size and cost of the heat rejection
equipment decreases with an increase in process side temperature.  This cost re-
lationship is  shown as curve  A in Figure 1.1.
                                       1

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Plant Cost
 ($/kwhr)
Cooling Cost
 ($/kwhr)
                     Condenser Temperature (°F)
  Figure 1.1.   System Cost Versus Condenser Temperature

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            A later task, as reported in May 1970 (Ref. 2), described, in detail, the
 increase in power plant cost as a result of an increase in condenser temperature. This
 type of relationship is shown as curves B and C in Figure 1.1.  Curve B may be thought
 of as representing an existing power plant forced to operate at a higher than design
 condenser temperature while curve C represents a possible locus of costs for plants
 designed for various condenser temperatures.

            The goal of this task then is to quantify these curves, and to find a means of
 obtaining the minimum of the sum of the two  costs for a wide  range of ambient conditions
 and power plant parameters.

 1.3   General Method

            The general method of approach to this task has been the development of a
 computer program for the  calculation of both cooling system and power plant  costs
 and the determination of the minimum total cost for a given set of parameters.  To
 this end, the effect of various design parameters  have been studied to determine
 which have significant effects on the performance of the various cooling schemes
 and which parameters are  important to the calculation of power plant costs. Design
 equations based on these parameters have been developed for the cooling systems
 and power plant, and incorporated into a computer program through which the
 minimum total cost is calculated.

            A number of options are open  to the user of the program such as full
 time or part time use of the cooling system,  an open or closed cooling system,  a
 specified or "designed" condenser, and variable ambient conditions.   Also available
 is the  ability to match projected power plant operation at different capacities over
 varying time periods.

            Part time use of the cooling system is represented in Figure 1.2 and
 is applicable only to cooling systems that  use a water cooled condenser such as
 cooling towers and cooling  ponds.
           An open cooling system, or "topping" operation is  shown in Figure 1.3
and is  again applicable only to cooling systems that use a water cooled condenser.

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Power Plant
 External
  Cooling
                                                     Condenser Water Flow

                                                    	  Warm Months
                                                             Cool Months
       River or Estuary
       Figure 1.2.   Part Time Use of External Cooling
Power Plant
External
Cooling
                                                     Condenser Water Flow
                                                             Warm Months
                                                          —  Cool Months
        River or Estuary
  Figure 1.3.  Open or Topping Cooling System (Shown as seasonal
                operation—can be used as full time open
                          system also)

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           The water cooled condenser, as part of the external cooling system, may
be specified or it will be "designed" by the program.  This provides the option, for
existing power plants that must have external cooling systems added, of either building
an oversized external system to match the existing condenser or rebuilding the con-
denser such that the external cooling system and the condenser are matched and of
minimum cost.  Depending on the particular power plant, either method may result
in the least overall cost.

           Operation of the power plant and the cooling system at various ambient
conditions for different periods of time has been provided for in the program.  This
is because cooling systems are usually designed for adverse and seldom occurring
ambient conditions and do not operate under these  extreme conditions most of the time.
The program accounts for this in that it "designs" a cooling system for a given set of
ambient conditions (usually specified as the most severe) but calculates operating
costs of both the cooling system and power plant for up to five other sets of ambient
conditions with a specified operating time per year for each.

           Operation of the power plant at up to five off-design capacities for  a
specified  number of hours per year has  been provided in the program and is neces-
sary to simulate actual power plant practice. The  disadvantage to this is that plant
operating characteristics  (heat rate and auxiliary power) often are quite different
for off design operation,  and therefore must be specified for each capacity used.
This is simplified somewhat, however,  by available data such as contained in
GE 205OB, included in Reference 2.

           The remainder of this report, which describes the computer program,
is divided into five sections.  The first section describes the model of the power
plant and the input data that is required.   The following sections provide brief
descriptions of the input (interface) requirements for each cooling system,
review the general computational procedures, and  describe the output. The details
are obtainable from the program listings  themselves (included in the appendix)
which contain "comment"  cards for ease of interpretation.   A glossary of
variable names for the whole program is  also provided in the  Appendix.

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                                  Section 2
                          POWER PLANT MODEL

2.1    General Description

           As  indicated in Section 1,  the total design and optimization program consists
of providing a mathematical description of the operating characteristics and system
costs of the power plant itself,  a similar model for alternative cooling schemes, and
a means of interfacing these two subsystems and computing the total cost. Various
combinations are then searched to find a minimum cost solution.

           The first part of this program  contains not only the mathematical de-
scription of power plant operation but it is also the control program which provides
the interface information between the plant and the cooling system.  This is indicated
in a generalized flow chart of the program in Figure 2.1.

           Basically, the "Power Plant Model" carries out two functions.  First, it
receives and manipulates all of the required input information to the optimization
program.   These inputs include such items as plant design capacity, projected load
demands,  plant efficiency ratings, projected cooling requirements,  expected ambient
conditions, and relevant economic data.  A complete listing is given in Section 2.2.
These input data are then manipulated to put the data into a form directly useful in
the forthcoming computations.  This portion of the model is contained in the first
part of the main program.

           The second function of the Power Plant Model is accomplished in subroutine
PAFCST,  an operational subroutine, which simulates  power plant operation and pro-
vides heat rejection requirements and plant cost information to the cooling system
subroutines.

2.2    Input Data

           The data describing the power plant and the operation of it are read in
the first portion of the program and, in order of input, are as follows:

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                                                     MAIN PROGRAM

                                                 Input, Conversion, Control
 SUBPOLU
Once Through
  Cooling
 Subroutine
   SUBMDW
Mechanical Draft
 Cooling Tower
  Subroutine
 COND
Condenser
Subroutine
  SUBNDW
Natural Draft
Cooling Tower
  Subroutine
"SL^BPOND
  Cooling
   Pond
 Subroutine
                                                       PAFCST

                                                      Power Plant
                                                      Subroutine
                                                      Figure 2.1

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 Variable
 PSIZE
 CCPKW


 ANFCR

 FUCST
                   Description
 Power plant size—the maximum electrical output of the
 plant and the size for which the cooling systems are to
 be designed  (Mwe).

 Power plant capital cost including a standard once
 through condenser ($/kw).

 Annual fixed charge rate  (%/yr).

 Fuel cost (
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            Variable
                                              Description
           HRP(I, J)*
           TURBHR(I, J)*-
Condenser pressure for each heat rate at each capacity
(in.Hg.) (do not have to include PCMAX(I) and PCMIN(I))

Turbine heat rate corresponding to each condenser
pressure,  HRP(I,J),  for each capacity (Btu/kwhr).
           The following input data pertain more to the cooling systems than to the
 power plant but are included here since they are read in the same part of the program
 as the power plant data.
            TDB

            TWB

            TAVH2O

            PCBASE
            WIND
             RAD
 Design ambient dry bulb temperature (° F)

 Design ambient wet bulb temperature (° F)

 Design available water temperature (°F)

 Base condenser pressure—a base average condenser
 pressure at which the plant would operate if external
 cooling were not required (in. Hg.).

 Design wind velocity (MPH)
                               o
 Design radiation intensity  (Btu/ft /day)
            NH2O
            NTAMB

            TAMDB(I)

            TAMWB(I)
Type of cooling water to be used in the cooling system
-1  = Seawater
 0 = Untreated fresh water
+1  = Treated fresh water

Number of different ambient temperatures.

Various ambient dry bulb temperatures (° F)

Various ambient wet bulb temperatures (D F)
*These values are obtained from General Electric Heat Rate Tables (Ref. 2) or
other similar data.

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 Variable
 TAMRV(I)
 AMWIND (I)

 AMRAD (I)

 PCTAMB(I,J)
 WIDTH
 NSYSOP
NSPCON
TDISMX
UOVALL
AREAC
SPFLOW
NSUBS(I)
                      Description.
 Various river temperature (* F)
 Various wind velocities  (MPH)

 Various radiation fluxes (Btu/ft  /day)

 Percent of the cooling system use time,  COLPCT(I)
 x TOTLD(I), at each capacity,  that the cooling system
 operates at the specified ambient temperatures,
 TAMDB(I) and TAMWB(J)  (%/100).
 Width of river or estuary (ft).
 Type of cooling system operation
 0 = closed cycle operation
 2 = topping
 Whether or not the condenser is specified
 0 = no
 1 = yes
 Maximum water discharge temperature (only if topping
 used)(' F)
 Overall heat transfer coefficient  for the condenser
 (only if condenser is specified) (Btu/hr-ft -° F).
 Total heat transfer area (only if condenser is  specified)
 (ft2)
 Condenser water flow (only if condenser is specified)
 (Ibm/hr)
 Controls which of the cooling subroutines is called.
 If NSUBS (I) is zero, the  tth subroutine is not called.
_I_          Subroutine
 1            Listing of input data (part of main program)
 2            Once through cooling (SUBPOLU)
 3            Cooling Pond (SUBPOND)
 4            Mechanical Draft Wet Tower (SUBMDW)
 5            Natural Draft Wet Tower (SUBNOW)
                               10

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2.3
Preparation of input data cards
           All cards are required for each set of input conditions, although all
cooling options may be run with one set of plant and ambient data.  FORTRAN format
specifications are shown for each input card required.
           Card 1:   PSIZE,  CCPKW, ANFCR,  FUCST,  PRPAGR, NCAPS
           Card 2:   CAP (I) , I = 1,5
           Card 3:   TOTLD (I),  1=  1,5
           Card 4:   COLPCT (I), 1= 1,5
           Card 5:   NHRPTS (I), I = 1,6
           Card 6:   PCMIN  (I), 1=  1,6
           Card 7:   PCMAX (I), 1= 1,6
                                                            (5F10. 0,110)
                                                            (5F10. 2)
                                                            (5F10. 0)
                                                            (5F10. 2)
                                                            (6110)
                                                            (6F10. 2)
                                                            (6F10.2)
           Cards 8-X: NNCAP sets (a set for each capacity, plus one if design data
                      are input.  See Section 2. 4) of two cards each:
                       card A:  HRP (SET NUMBER, J), J -  1, 6
                       cardB:  TURBHR (SET NUMBER,  J), J= 1,6
           Card X + IrTDB.TWB, TAVH20, PCBASE, WIND, RAD, NH20,
                      NTAMB
           Card X + 2: TAMDB (I), 1=1, NTAMB
           Card X + 3:TAMWB(I), 1=1,  NTAMB
           Card X + 4: TAMRV (I), I - 1, NTAMB
           Card X + 5: AMWIND (I), I = 1,  NTAMB
           Card X + 6: AMRAD (I), I - 1, NTAMB
           Cards X + ' 7-Y:  NCAPS cards each with PCTAMB
                           (SET NUMBER, J), J =  1,  NTAMB             (5F10.2)
           Card Y +  1:     WIDTH, NSYSOP, NSPCON, TDISMX, UOVALL,
                           AREAC, SPFLOW                (F10. 0, 2110 , 4F10. 0 )
           Card Y +  2:     NSUBS (I), I =  1,5                           (5HO)
                                                            (6F10.2)
                                                            (6F10. 0)

                                                            (6F10. 0,2110)
                                                            (5F10. 0)
                                                            (5F10. 0)
                                                            (5F10. 0)
                                                            (5F10. 0)
                                                            (5F10. 0)
                                   11

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 2.4
        Test Data
            Four sets of input data have been used to obtain cooling system costs.
 These four data sets have been designated SUBD1, SUBD2, SUBD3, and SUBD4. All
 four sets contain the same power plant data and ambient temperature but each de-
 scribes a different type of cooling system operation as described below.
 SUBD1
 SUBD2
 SUBD3
  Condenser is specified and the cooling system is used for
  topping.

  Condenser is specified and the cooling system is a closed
  system.

  Condenser is "designed" and the cooling system is used
  for topping.
 SUBD4
Condenser is "designed" and the cooling system is a
closed system.
  Listings of these four sets of data are included in the Appendix, and the input data
 printout, when SUBD1 is used,  is shown in Table 2.1.
*Number of cards depends on number of capacities specified.
                                       12

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                           Table 2.1
PSIZE
200
CAP $
150
i win vf irj
ANFCR
.12
FUEL *
10
PRPAGR
looo
   CAPACITIES AND CORRESPONDING DATA
     (EXTRA VALUFS ARE DESIGN DATA)
 CAPACITY -
 MRS/YEAR -
 PCT COOLING -
 MIN P COND -
 MIN T CCND -
 MAX P CCND -
 MAX T CCND -
   CAPACITY FACTOR =  .82
   COOLING USE FACIOR =  .75
  1.00    .80    ,60    ,?5      0
   *>150   1750    800    700    360
    ,*0    .70    ,5Q    .30    .15
   1.50   1.00   1.00   1.00   1.00   U50
  91.72  79.04  79.04  79.04  79.04  Ql.72
   3.50   4.00   4.00   4,50   4,50   3,50
 120.55 125.41 125.41 129.77 129.77 12U.55
   CCNO PRESS AND CORRESPONDING DATA AT EACH CAPACITY
CAPACITY =1.03
 PRESSURE -
 T HEAT RATE -

CAPACITY = .80
 PRESSURE -
 T HEAT RATE -

CAPACITY B .60
 PRESSURE -
 T HEAT RATE -

CAPACITY * ,?5
 PRESSURE -
 T HEAT RATE -

CAPACITY =   0
 PRESSURE -
 T HEAT RATE -
   1.50    2.50    3.50
    7987    8037    8153
   1.00    2.00    3.00
    7974    8025    8l74
   1.00    2,00    3.00    3.50
    8055    8195    8430    8543
   1.00    2.00    3.00
    8828    9381    9815
   1.00    2.00    3.00
       000
   DESIGN VALUES (CAPACITY a PLANT SIZE)
 PRESSURE -
 T HEAT RATE -

  DRY BULB T
        85

  AVAIL H?0 T
         75
 BASE P CCND
       1.50
   1.50
    8000

WET BULB T
      75
2.00
 8009
2.50
 8042
   WIND SPEED
      10.0
 TYPE AVAILABLE H2C
         -1
  BASE T CCND
     91.7
3.00
 QOB9
3.50
 8l51
         RADIATION
            4000
                              13

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                       Table 2.1 (Concluded)
   VARIABLE AMBIENT TEMPERATURES

 DRY BULB -       70     BO     85
 WET BULB "       bO     70     70
 RIVER -          60     h5     70
 WIND           10.0   10.0   10.0
 RADIATION      4000   4000   4000
   PERCENT  OF COOLING SYSTEM TIME AT ABOVE
      AMBIENT CONDITIONS
 CAP  =  1.00 -    .25    .25    .50

 CAP  »   .80 -    .30    .30    .40

 CAP  =   .60 -    .^O    .30    .30

 CAP  =   ,?5 -    .bO    .25    .?5

 CAP  a     0 -      0      0   1.00
  RIVER WIDTH     TYPE COOLING (2=TCPPTNG)     cCND SPECIFIED (
      ?000               ?                          1

MAX DISCHARGE TEMP *   H5

  CONDENSER SPECIFICATIONS
OVERALL U =    350
TUBE AREA * ?.760E 05
H2C FLOW = 4.200E 07
                                14

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 2.5    Power Plant Calculations in the Main Program

            The first calculation that is performed in the main program,  after the data
 are read, is to check that the total load duration hours per year equals 8760 hours
 (including 0 capacity operation),  and that, for each capacity,  the total percent of
 operating time at the various ambient conditions equals 100.

            The design relative humidity,  RH, and the  variable ambient relative humi-
 dity, AMBRH(I), are then calculated from the wet bulb and dry bulb temperatures with
 the use of the Carrier equation (cf Ref. 3).

            Following the calculation of the relative humidities is  the quadratic curve
 fit of the heat rate points.   The curve fit is necessary to provide continuous heat rate
 values, at the various plant capacities, for condenser pressures between the specified
 points.  The actual curve fit is in terms of condenser temperature rather than pres-
 sure,  so that the specified condenser pressure input data is first converted to  satura-
 tion temperature.  Also,  immediately following this conversion, the maximum and
 minimum allowable condenser pressures and the base condenser pressure are
 converted to corresponding saturation temperatures.

            If "design" heat rate data is not included in the input,  then the program
 assumes that the 100 percent plant capacity data is to be used for  design.  This con-
 version is performed next in the program.  Either 100  percent plant capacity data
 or "design" data must be specified for the program to run. Both may be  specified
since it may be desirable to "design" the cooling system to match  plant operation
under special conditions such as above rated capacity ("valves wide open", overpressure,
and/or feedwater heaters shut down - see  Ref. 2).

           Plant capacity factor  and cooling system use factor are calculated from
the load data.  The  capacity factor  is a measure of the use of the plant relative to
its hypothetical maximum design  use,
                                      15

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                        total kwhrs output in year	
                        maximum design output
                        (plant at full design capacity for 8760 hours)

 The cooling system use factor is the average percent of plant output that is created
 while the cooling system is in use,
                       kwhrs output with cooling system in use
            UbJiFAC -      total kwhrs output in year,

            The capacity factor is  used to adjust capital cost to be in terms of
 actual  output (kwhrs) in a year, and the use factor is used to adjust cooling system
 operating cost to be in terms of total plant output in a year.

            If the computer system on which the program is to be run cannot
 handle all the code necessary for the main program and each of the  subroutines,
 the subroutines for cooling methods which will not be used can be omitted, and the
 references to them in the main program deleted.

2. 6  Program Optimization

           Following preliminary  calculations in the main program, control is
transferred to one of the operational subroutines, SUBPOLU, SUBPOND, SUBMDW,
or SUBNDW, where the optimum cooling system design is determined.  The method
of optimization used in these subroutines  is a complete search of all allowable
combinations of the design variables.  Obviously, however, when part of the cooling
system is specified, such as the condenser, the design variables describing them
are not varied.

           In the general case, there are two temperatures that are varied to
determine the optimum tower, the  condenser temperature and the water discharge
temperature from the tower or pond.  The condenser temperature is set to the
lowest possible value and tower costs are calculated for the full range of possible
discharge temperatures.  The condenser  temperature is then increased by 1* F and
the  calculations made again for the range of discharge temperatures.  The process
is repeated until the condenser temperature has been increased to its  maximum
                                      16

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 prescribed value.  During the whole process,  each time a combination of variables
 resulted in a tower cost less than the proceeding lowest one, the variables were
 "saved" for future comparison.  Therefore, after  all combinations have been tried
 the "saved" combinations will be the least cost and therefore the optimum.

            This optimization procedure is shown in more detail in Figures 3.2,
 4.1, and 5.3.
2.7    Subroutine PAFCST (Power and Fuel Cost)

           This subroutine, which is "called" by the cooling system subroutines,
calculates auxiliary power cost,  differential fuel cost, and heat rejected from the
power plant, for operation at a given capacity and condenser temperature.

           At each capacity a base heat rate,  HRBASE, is first calculated with the
quadratic coefficients, HRCOF2(I), HRCOF1(I), and HRCOF0(I), and the base con-
denser temperature. The actual  heat rate is then calculated at the desired condenser
temperature and the heat rejected, QREJ calculated by

              QREJ  = (HEATR-3413) X PSIZE X CAP(I)                     (2.1)
                                      17

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where     HEATR   = net heat rate - (Btu/kwhr)
           PSIZE    = total rated plant output (Mw)
           CAP(I)    = plant capacity of interest (%/100)

           Boiler efficiency (stack heat loss) is not included in the above equation
since the net heat rate used is defined as the heat adrted to the steam divided by the
net power output.
           The differential fuel cost is calculated by
           DELFC   =  FUCST x (HEATR-HRBASE)    (mills/kwhr)
where      FUCST   =  fuel cost (^/million Btu)
           HRBASE  =  base heat rate (Btu/kwhr)
                                                                           (2.2)
The auxiliary power cost is calculated by
    PWCST = FUCST x HEATR +
                                CCPKW x ANFCR
                                 CAPFAC x 8. 76
(mills/kwhr)
(2.3)
where      CCPKW  = plant capital cost ($/kw)
           ANFCR   = annual fixed charge rate (%/100)
           CAPFAC = capacity factor (%/100)
                                   18

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                                  Section 3
                         ONCE-THROUGH COOLING

3.1     General Description

           The calculations  and logic for the design of a once-through cooling are
contained in two subroutines, SUBPOLU and COND.  Subroutine SUBPOLU contains
most of the logic and about half of the cost calculations for this type of cooling. It is
divided into two parts, a design section in which the cooling system costs are calculated
for the design ambient conditions and power output, and an off-design section in which
the operating costs are recalculated using the specified variable capacities and ambient
conditions.  The condenser may be  specified as already existing, in which case the capital
cost is not included in the total system cost.

           Also included in subroutine SUBPOLU is a calculation and printout of river
temperatures  downstream of the plant.  This includes both mixed river temperatures
and plume temperatures,  and plume width for a specified river.  The equilibrium tem-
perature and plume temperature are determined from data and equations taken from
Reference 5.

           Subroutine COND, which is also used by other cooling systems requiring a
water cooled condenser,  contains the basic design  and cost calculations for the con-
denser itself.

3.2  Assumptions

           Variables and equations for which numerical  assumptions have been made
in the subroutine are listed below,  so that the cards may be changed if different
numerical values are desired.
                                        19

-------
 Variable (sequence or line f)            Comments and/or Recommended Values
                              Subroutine SUBPOLU
 WIND (255)
 QFLRIV (256)
 DEPTH (257)
 RAD (258
 PMPEF (259)
 WCOFA (264)
 WCOFB (265)
 DT2 (293)
 PLAC (306-310)
 PHEAD (315)
 COSMAI (319)
 PMPEF (1252)
 UALL (1257-1261)
                                                  4000 - 6000
                                                  0.8 - 0.85
                       Should be of the form used in Reference 5

                       Need not correspond to (not used for) specified condenser
                       1.5, 1.25,  1.0 for seawater, untreated fresh, and
                       treated fresh water, respectively.

                       Form of equation and percentages  both assumed
                                Subroutine COND
                                                  0.8 - 0.85
                       420., 340. ,  and 250 correspond to treated fresh
                       water, untreated  fresh water, and sea water,
                       respectively.
 CONCST (1270)
 CHEAD (1276)

 3. 3  Basic Equations
                       Form and coefficients of equation assumed.
                                                  35.
   is
where
            For the condenser the basic size equation for the total heat transfer area
                    ACOND =
                                   QREJ
                               UALL X DTLGM
                                                                (3.1)
  QREJ
  UALL
DTLGM
                      total heat rejected (Btu/hr)
                      overall heat transfer coefficient (Btu/hr-ft2-°F)
                      log mean temperature difference (°F)
                                      20

-------
           The capital cost equation for the condenser, derived from data in References
7, 12,  and 13 is
           CONCST =  20.x(1.05xACOND)°'9         ($)                   (3.2)

Added to this is $1/GPM for the cost of the water pumps.

           The condenser system cost is the sum of the capital cost (capital charge
per year) and the pumping costs , which are
            PMPCST  -
where      PHEAD =   assumed frictional pumping head (ft)
           PWCST =   power cost (mills /kwhr)
           PMPEF =   pump efficiency (%/100)
           PSIZE   =   plant size (Mw)

The above three equations are contained in the subroutine COND.

           In the subroutine SUBPOLU,  other costs are added to the condenser system
cost. These consist of the inlet and outlet water ducting costs ,  an  additional pumping
cost for this ducting, and a differential fuel cost obtained from the subroutine PAFCST,
due to power plant  operation at a condenser pressure higher than PCBASE.

           If the condenser is specified, then,  since the inlet water temperature is
known, the condenser temperature and outlet water temperature may be determined
by simultaneous solution of the following three equations.   From the power plant sub-
routine PAFCST,  we get
                        QREJ  -   f  (TC)                                 (3.4)

In addition,              QREJ =  SPFLOW x (Tl - T2) x C                 (3.5)
                                   21

-------
where    SPFLOW = specified water flow (Ibm/hr)
             Tl     = outlet water temperature (° F)
             T2     = inlet water temperature (° F)
             Cp     = specific heat of water = 1  (Btu/lbm-°F)
       and
                                          (T2 - TCI- (Tl - TC)             /3  6)
            QREJ  = UOVALL x AREAC  x  5	/T2 - TC\                 '
                                              £II(TI - TC j
                                                                      2
where   UOVALL   = specified overall heat transfer coefficient (Btu/hr-ft -°F)
                                                  2
          AREAC    = specified heat transfer  area (ft )

           Tl, TC, and QREJ are the only three unknowns, but since the function  f of
Equation (3.4) is a quadratic curve fit, the simultaneous solution to the three  equations
is performed by trial and error, in subroutine SUB POL U.

3.4 Plume Analysis

            The final computations performed in subroutine SUBPOLU describe the
 spread and dissipation of the stream of condenser discharge water,  or plume,  after
 it is returned to the flowing river. As was  indicated by Edinger   and Geyer
 (Reference 5), even  simple limiting models of the spread of warm light  water  into
 cold water defy a first-principles analysis at this time.  Therefore, the approach
 taken was to define an arbitrary spreading function which described  the increase
 in plume width with distance downstream  of the outfall.  This spreading  function was
 prescribed to meet  certain physical constraints.  These were:

            1.   the plume width at the outfall  was related to the overall
                width of the river by the ratio of the condenser discharge
                flow to the undisturbed river flow.  That is

                PLUME W ....     .. ....       QCON
                WIDTH    
                                     22

-------
where
           PLUME   -  width of plume (ft.)
           WIDTH    =   totalwidth of river (ft.)
           QFLRIV   =  total river now (ft3/sec)
                                                    o
           QCON     =  condenser discharge flow (ft /sec)

           20   the spreading rate is of an exponential form.
           3.   the plume width approaches the total river width
                smoothly.
A spreading function which satisfies these criteria is

           PLUMEW =  WIDTH x

where
                    1
     -(Ax XI + Cl)
1-e                                   (3.8)
           A =  a constant which can be interpreted as an inverse
                 mixing length (1/miles)
           XI =  distance downstream of the outfall (miles)
           Cl =  a constant evaluated so as to satisfy Equation 3. 7
                 at XI - 0.

           In order to obtain a reasonable approximation to some plume width data
in Reference 5,  the mixing length was chosen as   —— =  2.

Which yielded the final result
                                            .   XI
[
           PLUMEW -  WIDTH x    1 - e        *                           (3.9)

           This results in a description which can be interpreted physically according
to Figure 3.1,  as a two-dimensional unstratified model.
                                         23

-------
                 Plume
t
            outfall
                            '  unmixed portion
                          /    of river
                         unmixed portion of
                              river
                     View A-A
     Figure 3.1  Schematic of Plume-River Flow
                          24

-------
Both streams are subject to heat transfer with the environment and both approach the
environmental equilibrium temperature exponentially as derived in Reference 5.

           The temperature of the unmixed cold stream, TWREAL, is the easiest
to specify since it is by definition unaffected by the plume and simply approaches the
equilibrium temperature, TCALC, according to
                                                    ALPHA1
           TWREAL =  TCALC + (TAVH20 - TCALC) e
                                                             (3.10)
where
           TWREAL
           TCALC
           TAVH20
           ALPHA1
             unmixed stream temperature  (CF)
             equilibrium temperature (° F)
             temperature just upstream of plant (u F)
             decay constant
                                   XK xXI
                         DENSITYx DEPTH x VELREV
                                                      from Reference 5
           The temperature of the plume is most easily defined in terms of a mixed
river temperature,  TXDIST.  The hypothetical temperature is the temperature which
the river would be at any point if the plume and the unmixed portion were thoroughly
mixed.  This temperature,  which also approaches the environmental equilibrium
temperature, can be shown to be
           TXDIST-   TCALC + (TZERO - TCALC) e
                                                  ALPHA1
                                                             (3.11)
where
Therefore,
TXDIST  =
TZERO  =

TZERO  =
mixed river temperature at any downstream (  F)
mixed river temperature at the outfall (° F)

QCON x Tl +  (QFLRIV - QCQN) x TREAL
            QFLRIV
                                                                        (3.12)
                                      25

-------
The plume temperature,  PLUMT, is then computed on the basis of a simple energy
balance from the mixed river temperature (Equation 3.11} and the plume flow rate
(assumed proportional to plume width from Equation 3. 9).  Hence,

QFLRIV x TXDIST - Q PLUM x PLUMT + {QFLRIV -QPLUM) TWREAL     (3.13)

           PLUMT - TWREAL    QFLRIV     WIDTH                    ,,
           TXDIST - TWREAL ~  QPLUM     PLUMEW                  l  '
Then from Equation 3. 9

           PLUMT - TWREAL
           TXDIST - TWREAL      1 - e

where
          PLUMT  =  plume temperature (° F)
                                       - (XI/2 +  Cl)                  (3<15)
                                    26

-------
3.5     Flow Diagram

            Figures 3.2 and 3. 3 contain the flow diagram fc^r the subroutine SUBPOLU.
Some minor calculations and program checks have been omitted for clarity.

3.6     Results

            The  results using the data of SUBD2 and SUBD4, described in Section 2,
are shown in Tables 3.1 and 3.2.

            The  design values are printed first and consist of the following:

Q REJECT      -     The heat  rejected from the plant by the condenser
T CONDENSER  -     The temperature of the condensing steam
CONDENSER
FLOW          -     The condenser cooling water flow
PUMP POWER  -     The power required to pump the cooling water
EQUILIBRIUM
TEMP          -     The equilibrium temperature corresponding to the
                     design ambient conditions
RANGE         -     The cooling water temperature rise from inlet to exit.

            The  design costs are printed next. It should be pointed out here that
since the various cooling subroutines use common printing subroutines, PRTDS1,
PRTDS2, and  PRTOD, there are a few quantities in each print  out that are not
applicable to the cooling system being described.  Zeros (with no decimal point)are usually
printed as the value of such quantities and the term "not applicable" will be used
when describing the results.  An example of such a quantity is  the first design cost
printed, the CAPITAL COST.  The capital cost of the condenser is not printed out
but it is included in the condenser system cost,  described below.

            The  OPERATING COST result printed for this subroutine consists only of
the extra pumping costs associated with the inlet and outlet water ducting for the
condenser.  Other pumping costs are included in the condenser system cost.
                                    27

-------
               Statement No.
                yes
       40
       Determine TC, Tl
         and QRE J by
       Trial and Error
                                  Determination of
                              Equilibrium Temperature
                                  Start at Lowest
                              Condenser Temperature
                              Is Condenser Specified?
                                                         no
                             45
                                    Call COND
                                Calculate Total Cost
                                              30
                                                Assume 5°F Condenser
                                               Approach and Calculate
                                                       QREJ
yes
               yes
       Save Parameters
         and Cost
                no
      151
      |  Increase TC  ]
TC  <  TCMAX?[-
                                  Is Cost Lower
                               than Previous Cost?
                            156
                                         no
                              Is Condenser Specified?
                   no
                             200
                                     yes
                             Print Design Calculations
                             Print River Temperatures
                                                         Off-Design Calculations
          Figure 3.2  Flow Diagram for Design Portion of SUBPOLU
                                        28

-------
                     Initialize
                        I
           Calculate to Statement 350
                 for Each Capacity
 yes
yes
            Calculate to Statement 340
        for Each Set of Ambient Conditions
                 Start at Lowest
              Condenser Temperature
        301
           Calculate Correct Condenser
          Temperature by Trial and Error
            Is Condenser Temperature
               (pressure) Less Than
               Minimum Allowable ?
        315
           Calculate Operating Cost for
                 Particular Set of
                Ambient Conditions
        340
More Ambient Conditions?
                          no
           Calculate Operating Cost for
                Particular Capacity
        350
  Another Capacity?
                          no
           Calculate Average Operating
                 and Total Cost
                                                    400
    Figure 3.3    Flow Diagram for Off-Design Portion of SUBPOLU
                                29

-------
                              Table 3.1

              ONCE-THROUGH COOLING RESULTS USING SUBD2
                       (CONDENSER SPECIFIED)
                	STRAIGHT  CONDENSER  COOLING	

                    (WITH UNTREATED FRESH WATER)


         THE DESIGN VALUES AND COSTS ARE -

  o REJECT =    9.isiE oe BTU/HR  AT T CONDEMSER * 100
  CONDENSER FLOW =1.869E 02 CES  U.200E 07 L8/HR)   PUMP POWER  81»325E 02 HP
  EQULIBRIUM TEMP =  86       RANGE *  22


  CAPITAL COST  =    OE 00 DOLLARS
  CONDENSER AMD PUMP COST =    OE 00 DCLLARS/KW
  OPERATING COST =  .002 MILLS/KW-HR
  MAINTENANCE COST *  .000 MILLS/KW-HR
  CONDENSER SYSTEM COST =     0 MRLS/KW-HR
  DIFFERENTIAL FUEL COST =  .000 MILLS/KW-H*

    TOTAL SYSTEM COST  a  .002 MULS/KW-HR
              —RIVER TEMPERATURES —

DISTANCE-MILES   STREAM TEMP DEG.F   PLUME TEMP.-DEG.F   PLUME WIOTH-MI
                  NO PLANT  MIXED


         0       75.00     75,58      96.86            .0101
       1.0       75.66     76.21      77.01            .155?
       2-0       76.29     76.81      77.H            ,2432
       3.0       76.88     77.38      77.5?            .2965
       *«0       77-45     77,92      77.99            .3289
       5.0       77.98     78.43      78.47            =3485
       6,0       78.49     78.91      78.93            =3604
       7.0       78.97     79.37      79.38            .3677
       8.0       79.42     79.80      79.81            .3720
       9«0       79.86     80.22      80.22            .3747
      10.0       80.26     80,61      80,6l            ,3763
      20.0       83.35     83.56      83,56            .3788
                                30

-------
                     Table 3.1 (Concluded)
            VARIABLE AMBIENT CONDITIONS
     FCR CAP al.OO?
PC LESS THAN PC MIN

     FOR CAP =1.00?
PC LESS THAN PC MIN

     FCR CAP B .60?
PC LESS THAN PC MIN

     FOR CAP = ,2b?
PC LESS THAN PC MIN

     FOR CAP = ,2bi
PC LESS THAN PC MIN

     FOR CAP * .25?
                       T WB B   60»  AND  TC *
                      ASSUME PC MIN - CONTINUE
                       T WB
            70»  AND  TC
- ASSUME PC MIN . CONTINUE

   T WB *   60?  AND  TC «*
- ASSUME PC MIN - CONTINUE

   T WH =   60?/  AND  TC *
- ASSUME PC MIN - CONTINUE
                       T WB
            70»  AND  TC
                    - ASSUME PC MIN - CONTINUE
                            92
92
                                                79
                                                79
79
                       T WB =   70»  AND  TC =  79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE
  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -
OPERATING COST *  .001 MlLLS/KW-HR
DIFFERENTIAL FUEL COST =-0.000 MILLS/KW-HR

TOTAL SYSTEM COST =  .001 MlLLS/KW-HR
                            31

-------
                             Table a. 2

              ONCE-THROUGH COOLING RESULTS USING SUBD4
                        ("DESIGN" CONDENSER)

               ----- STRAIGHT CONDENSER COOLING——

                    (WITH UNTREATED FRESH WATER)


         THE DESIGN VALUES AND COSTS  APE -
  Q REJECT =   9.454E os BTU/HR  AT T CONDFNSFR * i?o
  CONDENSER FLO* =L059E 02 CFS (?.380F 07 LB/HR!   PUMP POWER »7.507E 01 HP
             TEMP =  8fl       RANGE *  40
  CAPITAL COST «    OE 00 DOLLARS
  CONDENSER AND PlIM? COST =5.093E 00 DOLLARS/KM
  OPERATING COST •  .001 MlLLS/KW-HR
  MAINTENANCE COST s  .OQl MILLS/KW-HR
  CONDENSER SYSTEM COST =  .112 MILLS/KW-HR
  DIFFERENTIAL FUEL COST a  ,OU MILLS/KW-HR

    TOTAL. SYSTEM COST *  .128. MILLS/KW-HR
              —RIVER TEMPERATURES--

DISTANCE-MILES   STREAM TEMP DEG.F   PIUME TEMP,«DEG»F   PLUME WIDTH-MI
                  NC PLANT  MIXED


         0       75.00     75«6Q     114.72            .0057
       1.0       75.66     76.23      77,08            .1525
       2.0       76.29     76.83      77«U            »2*15
       3.0       76.88     77.40      77.54            .2955
       4.0       77.45     77.93      78.01            .3283
       5.0       77-98     78.44      78.48            .348?
       6.0       78.49     78.92      78.9S            ;3&02
       7.0       78.97     79.38      79*39            .3675
       8.0       79«42     79e82      79.8?            »3720
       9.0       79.86     BO.23      BO.23            .3746
      10,0       80.26     80.62      80,62            .3763
      20,0       83.35     83»56      83«56            .3788


              VARIABLE AMBIENT  CONDITIONS


       FOR CAP  *  ,25i     T WB  «   60»   AND  TC •  79
  PC LESS  THAN  PC  MlN  -  ASSUME  PC MlN  - CONTINUE

       FOR CAP  s  .25?     T WB  s   70,   AND  TC »  79
  PC LESS  THAN  PC  MlN  -  ASSUME  PC MIN  - CONTINUE

   WITH THE  VARIOUS AMBIENT TEMPERATURES
   THE COSTS  ARE  -

  OPERATING COST  a  ,001  MILLS/KW-HR
  DIFFERENTIAL  FUEL  COST  •  ,004 MILIS/KW-H®

  TOTAL SYSTEM  COST  •   .118 MXLLS/KW-HR
                                    32

-------
           The MAINTENANCE COST result is a sum of fixed percentages of the
specific capital costs, the operating cost, and the condenser system cost.  The three
percentages are 0.1%, 10% and 1% respectively.

           The CONDENSER SYSTEM COST consists of a capital cost (converted to
a cost per output basis) and an operating cost, both described  in Section 3.2.  The
condenser system cost is set equal to zero if the condenser is specified.  This is true
in all the  cooling system subroutines.  The reason for this is that if an existing con-
denser is going to be  used, its cost should not be part of the optimization process,
and also the costs should already be  known.  When this cost is given (for the "design"
condenser case) it represents a total condenser system cost and is not the cost over
and above what a specified condenser might cost.

           The DIFFERENTIAL  FUEL COST is the added cost,  due to increased fuel
consumption, of operating the plant at a condenser pressure higher  than the specified
base pressure (input).

           The TOTAL SYSTEM COST is the sum of the capital, operating, main-
tenance, condenser system, and differential fuel costs.  This is the cost with which
the optimization is performed; the set of variables resulting in the lowest total sys-
tem cost is considered to be the best.

           The river temperatures and plume width were described in Section 3. 2
and the printout is self explanatory.

           The initial printout for the variable ambient conditions occurs during
calculation of the costs for each set of ambient conditions, and are non-fatal error
indications. The two  messages that  occur are that the condenser pressure, PC, is
less than the specified (in the input) minimum, PC MIN, or that the  discharge tem-
perature, T DIS, exceeds the maximum allowable, T DIS MAX. *  The reason for the
first type of message  is that the trial calculations for the off design  (variable ambient
conditions) condenser pressure start at  the specified minimum condenser pressure for
*This type of message does not occur for the once-through cooling system,  but is
 discussed here for continuity.
                                     33

-------
each capacity.  If the cooling system is able to handle the heat rejected at this first
trial point, it means that the actual operating point should be at a lower condenser
pressure.  However,  this point has been specified as the minimum possible pressure,
so it is assumed that the plant operates at this pressure and the operating cost is
calculated.  A large number of such messages may therefore mean that the "design"
ambient conditions are too severe compared to the actual variable conditions, or
that the minimum allowable condenser pressures have been set too high.
           The second type of message, concerning the discharge temperature from
an external cooling system,  may occur only when the system is used in a topping
operation.  The message is self explanatory,  and may indicate that the "design"
ambient conditions are not severe enough relative to the variable conditions.  When
the situation indicated by the message occurs (T DIS > T DIS MAX) the program
assumes the actual discharge temperature and calculates the operating cost.
           The average operating cost and average differential fuel cost for all  the
variable ambient conditions are calculated and printed out along with a new total  system
cost.  The new modified total system cost is a sum of the original capital, maintenance,
and condenser system costs, and the new averaged operating and differential fuel costs.
                                    34

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                                  Section 4
                              COOLING POND

4.1    General Description

           The equations and logic describing the design of a cooling pond are con-
tained in the subroutine SUBPOND.  This subroutine "calls" PAFCST for power plant
information and COND for condenser specifications. It is possible to have the con-
denser specified, in which case the cooling pond is sized to match the condenser.  If
the condenser is not specified, the subroutine "designs" a matched pond and condenser.
In both cases, options are available to have the pond used for a topping operation and/or
part time use.  Pond sizing,  in all cases,  closely follows the method described in
Reference 4.

           The subroutine is divided into two sections,  a design and an off-design
section,  similar to the once-through cooling system subroutine.

 4.2 Assumptions

           Variables and equations for which numerical assumptions have been made
 in the subroutine are listed below,  so ~that the cards may be changed if different
 numerical values are desired.
 Variable (sequence or line #)
 PMPEF (449)
 WCOFA (452 H
 WCOFB (453))
 DT2 (490)
 PHEAD (521)
 COSMAI (526)
Comment and/or Recommended Values
             0.8 - 0.85
Should be of the form used in Reference 5.
Need not correspond to (not used for) specified
condenser
Form of equation and percentages both assumed.
                                    35

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 4. 3    Basic Equations

            The equation for determining the size of the cooling pond necessary for
 given inlet and outlet water temperatures and ambient temperatures is taken from
 Reference 4.

                            24 x ALPHA x FLOW                          (4 l}
                                                     (      '              V    ;
                              XK X 43560

 where     FLOW  =  water flow (Ibm/hr)
             XK    =  exchange coefficient (Btu/day-ft2-°F)

 ALPHA is defined by the equation

                 AT PMA -    rnr   (T2  -  TCALC)                         /4  n\
                 ALPHA -  -LOG   (T1  _  TCALC)                         (    '

where     TCALC  - equilibrium temperature (° F)
              Tl   = inlet water temperature (° F)
              T2   = outlet water temperature (° F)

           The capital cost of the pond is  simply

                   CAPCOS  = AREAP  x  PRPAGR                        (4.3)
where   PRPAGR  = land and construction cost ($/acre)

4. 4    Flow Diagram

           The flow diagram for the subroutine SUBPOND is shown in Figures 4. 1
and 4.2.

4. 5    Results
           The results using the data of all four data sets are shown in Tables 4.1
through 4.4 and are described as follows:
                                36

-------
Q REJECT
    and
T CONDENSER

PUMP POWER

H2O EVAP

COND FLOW

T IN

RANGE

EQUILIBRIUM
TEMP

POND AREA


Q REJ POND
CAPITAL COST
described in Section 3.4

total pumping power required exclusive of condenser

water evaporation rate

condenser water flow  (Ibm/hr)

temperature at inlet to pond (exit of condenser) (°F)

AT from inlet to exit of pond (°F)


described in Section 3.4 (°F)

the designed surface area of the  pond


the amount of heat that is transferred from the pond  to the
atmosphere,  (different from total heat rejected only when
topping operation)

the capital cost of the  cooling pond,  exclusive of the  condenser
           The remaining data and costs are the same as those described in Section 3.4.
                                         37

-------
                                                        Initialize
                                                      Calculate the
                                                 Equilibrium Temperature
                                Statement
                                Number
       40
                  yes
no-| Topping Operation?

            41
                             yes
                   Determine Correct TC
                     by Trial and Error
                46
                  Call COND and Determine
                    Pond Heat Rejection
           45
             Call COND K-
       154
         Save Parameters
           and Cost
    157
      Topping Operation?
        Tnnrpasfi
yes
       TCS TCMAX?
                                 yes
                                                      Start at Lowest
                                                  Condenser Temperature
                                               TTRT
                                                 Is Condenser Specified?
                                                                             Set Inlet Temperature (to pond)
                                                                           5°F Above Condenser Temperature
                                                                                  •—  Topping Operation?
                                                                        Set Outlet T Equal
                                                                      to Maximum Allowable
                                                                          Temperature
Set Outlet T Equal
 to Equilibrium
Temperature ,(+1)
                                                            151
                                                                                    Does Inlet Temperature
                                                                                 Exceed Outlet Temperature
                                               47
                                                  Calculate Area of Pond
                                                     and Total Cost
                                                  Is Cost Lower
                                              Than Previous Cost?
                                               156
                                                  Is Condenser Specified?
                                               190
                                                                        —
                                                                                Topping Operation? |—^j Increase T2
                                                Print Design Calculations
                                                                                Off Design Calculations
                                  Figure 4.1.  Flow Diagram for Design Portion of SUBPOND
                                                         38

-------
                                Initialize
                        Calculate to Statement 350
                           for Each Capacity
                        Calculate to Statement 340
                    for Each Set of Ambient Conditions
                              Start at Lowest
                          Condenser Temperature
                             Calculate the>
                         Equilibrium Temperature
                              Call PAFCST
                      no
                            Topping Operation?
                       yes
Calculate Correct TC
 by Trial and Error
 for Closed System
                    315
                               Calculate Correct TC
                                by Trial and Error
                                 for Open System
                              (using river temperature
                                and maximum outlet
                                    tempature)
                       Calculate Operating Cost for
                             particular set of
                            Ambient Conditions
                    340
            yes
More Ambient Conditions?
                                   Ino
                        Calculate Operating Costs for
                            Particular Capacity
                            350
                    yes
                           Another Capacity?
                                   Ino
                        Calculate Average Operating
                              and Total Cost
                                                            400
        Figure 4.2.   Flow Diagram for Off-Design Portion of SUBPOND
                                       39

-------
                            Table 4.1
                 COOLING POND RESULTS USING SUBD1
                  (SPECIFIED CONDENSER, TOPPING)

               -.„— COOLING POND

         THE DESIGN VALUES AND COSTS ARE -
  Q REJECT =9.i8ic OB BTU/HR  AT T CONDENSER =  100
  FAN POWER *    OE 00 HP     PUMP POWER »R»047E 02 HP
  H20 EVAP »2.125E 00 CFS (5.199E 05 LB/HR)
  H20 8LOWDOWM *    OE 00 CFS (    OE 00 LR/HP)
  AIR FLOW RATE =    OE oo LB/HR
  CCND FLOW S4.200E 07    T IN »  97     RftMQE a  12
  EQULIBRIUM TEMP *  79     PCND AREA a     141 ACRES

  Q RF.J PCNO *5.Q61E Q& BTU/HR

  CAPITAL COST =1.4llE 05 DOLLARS
  CONDENSER AMD PUMP COST =    OE 00 DCLLARS/KW
  OPERATING COST =  »007 MlLLS/KW-HR
  MAINTENANCE C^ST *  .001 MlLlS/KW-HR
  CONDENSER SYSTEM COST =     0 MlLLS/KW-HR
  DIFFERENTIAL FUEL COST =  .000 MILLS/KW-HR

    TOTAL SYSTEM COST s  .021 MILLS/KW-HR
              VARIABLE AMBIENT CONDITIONS
THE PCND is LA^ER THAN NECESSARY FCRI.OO CAPACITY AND AMBIENT NC« i
COMPUTING COSTS ASSUMING MOST EFFICIENT CONDITION (PC=PCMIN)

THE POND IS LARGER THAN NECESSARY FCRl.OO CAPACITY AND AMBIENT NO. 2
COMPUTING COSTS ASSUMING MOST EFFICIENT CONDITION «PC=pCMlN}

THE POND IS LARGER THAN NECESSARY FOR .60 CAPACITY AND AMBIENT NO. 1
COMPUTING COSTS ASSUMING MOST EFFICIENT CONDITION (PCspCMIN)

THE POND IS LARGER THAN NECESSARY FOR .25 CAPACITY AND AMBIENT NO. 1
COMPUTING COSTS ASSUMING MOST EFFICIENT CONDITION (PCapCMlN)

THE POND IS LARGER THAN NECESSARY FOR .25 CAPACITY AND AMBIENT NO. 2
COMPUTING COSTS ASSUMING MOST EFFICIENT CONDITION
THE POND IS LARGER THAH NECESSARY FOR .25 CAPACITY AND AMBIENT NO. 3
COMPUTING COSTS ASSUMING MGST EFFICIENT CONDITION  «PC»pCMXN)

    WITH THE VARIOUS AMBIENT TEMPERATURES
    THE COSTS ARE -

  OPERATING COST s  «007 MlLLS/KW-HR
  DIFFERENTIAL FUEL COST a-0«000 MILlS/KW«HR

  TOTAL SYSTEM COST »  .020 MILLS/KW-HR

                              40

-------
                      Table 4. 2

          COOLING POND RESULTS USING SUBD2
         (SPECIFIED CONDENSER, CLOSED SYSTEM)
             ..... COOLING POND	


       THE DESIGN VALUES AND COSTS ARE -
Q REJECT =Q.351E 08 BTU/HR  AT T CONDENSE" »  115
FAN POWER =    OE oo HP     PUMP POWER =H.io7E 02 HP
H20 EVAP =3.438E 00 CFS  (8.4UE f)5 LR/HR)
H20 RLCWnOWM =    OE 00  CFS  (    OE 00 LP/HR)
AIR FLOW RATE =    OE oo LR/HR
CCND FLOW =4.2ooe 07     T IN = 112     RANGE =  22
EQULIBRIUM TEMP =  79     POND AREA 3     142 ACRES

CAPITAL COST =1.4l7E 05  DOLLARS
CONDENSER AMD PUMP COST  =    QE 00 DOLLAPS/KW
OPERATING COST =  .007 MlLLS/KW-HR
MAINTENANCE C^SJ =  «001 MILLS/KW-HR
CONDENSER SYSTEM COST =     0 MILLS/KW-HR
DIFFERENTIAL FUEL COST =  .007 MILLS/KW-HR

  TOTAL SYSTEM COST *  .027 MILLS/KW-HR
            VARIABLE AMBIENT CONDITIONS
  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST =   .007 MlLLS/KW-HR
DIFFERENTIAL FUEL  COST r   .005 MILLS/KW-HR


TOTAL SYSTEM COST  =   .025  MIM.S/KW-HR
                          41

-------
                          Table 4.3

               COOLING POND RESULTS USING SUBD3
                ("DESIGN" CONDENSER, TOPPING)
               —.— COOLING POND ——-

         THE DESIGN VALUES AND COSTS ARE -
  Q REJECT =9.454E 08 BTD/HR  AT t CONDENSED *   120
  FAN POWER *    OE oo HP     PUMP POWER =4»6?3E 02 HP
  H20 EVAP =2.564E 00 CFS (6.274E 05 LR/HR)
  H2o RLCWDCWN =    OE oo CFS (    OE oo LR/HRJ
  AIR FLOW RATE *    OE oo LB/HR
  CCND FLOW *2.380E 07    T IN » 115     RANGE -  30
  EQULIRRIUM TEMP =  79     PCND AREA B     129 ACRES

  0 REJ POND *7.074E 08 BTU/HR

  CAPITAL COST =6,432E 05 DOLLARS
  CONDENSER AMD PUMP COST =5.093E 00 DCLLARS/KW
  OPERATING COST =  ,00* MlLLS/KW-HR
  MAINTENANCE COST s  »005 MILLS/KW-HR
  CONDENSER SYSTEM COST s  ,091 MILLS/KW-HR
  DIFFERENTIAL FUEL COST »  .010 MILLS/KW-H«

    TOTAL SYSTEM COST •  .164 MRLS/KW-HR
              VARIABLE AMBIENT CC


THE POND IS LARGER THAN NECESSARY FOR .25 CAPACITY  AND  AMBIENT  NO.  1
COMPUTING COSTS ASSUMING MOST EFFICIENT CONDITION  (PC»pCMlM)

THE POND IS LARGER THAN NECESSARY FOR .25 CAPACITY  AND  AMBIENT  NO.  2
COMPUTING COSTS ASSUMING MOST EFFICIENT CONDITION  (PC=PCMIN)

    WITH THE VARIOUS AMBIENT TEMPERATURES
    THE COSTS ARE -

  OPERATING COST r  ,Q04 MiLLS/KW-HR
  DIFFERENTIAL FUEL COST =  .004 MILLS/KW-HR

  TOTAL SYSTEM COST »  .158 MILLS/KW-HR
                            42

-------
                    Table 4.4

        COOLING POND RESULTS USING STJBD4
       ("DESIGN" CONDENSER, CLOSED SYSTEM)
             	 COOLING POND 	

       THE DESIGN VAL1JF5 ANO COSTS ARE -
Q REJECT S^.^B^E OB BTU/HR  AT T CONDENSFR «  120
FAN POWER =    OE oo HP     PUMP POWER sft.aoaE 02 HP
H20 EVAP =3.5l^E 00 CFS  (8.59yE 05 LR/HR)
H?0 BLOWDOWM =    OE 00 CFS, (    OE 00 LR/HR)
AIR FLOW RATE =    OE 00 LB/HR
CCNn FLOW =3.509E 07    T IN = 115     RA^GE =  27
EQULIBRIDM TEMP a  79     POND AREA =     150 ACRES

CAPITAL COST =7.487E 05 DOLLARS
CONDENSER AND PUMP COST =6.27?E 00 DCLLARS/KW
OPERATING COST =  .00& MlLLS/KW-HR
MAINTENANCE COST *  .006 MILLS/KW-HR
CONDENSER SYSTEM COST *  ,n4 MILLS/KW-HR
DIFFERENTIAL FUEL COST =  .OlQ MILLS/KW-HR

  TOTAL SYSTEM COST =  .199 MILLS/KW-HR
            VARIABLE AMBIENT CONDITIONS
  WITH THE VARIOUS AMBIF.NT TEMPERATURES
  THE COSTS ARE -

OPERATING COST =  .006 MlLLS/KW-HR
DIFFERENTIAL FUEL COST =  .oOfl MILLS/KW-nR

TOTAL SYSTEM COST »  .196 MILLS/KW-HR
                         43

-------
                                 Section 5
                MECHANICAL DRAFT WET COOLING TOWER
5.1    General Description

            The calculations and logic for the design of a mechanical draft cooling
system are contained in the subroutine SUBMDW.  This subroutine "calls" PAFCST
for power plant information and COND for condenser  specifications. The condenser
may be specified or "designed, " the cooling system may be open or closed,  and part
time or full time use of the cooling system may be specified.

            The design method that is used is basically a trial  and error procedure
in which temperatures are varied over permissible ranges,and the total system cost
is calculated for each set of conditions. The set of parameters that represents the
lowest total system cost is then chosen.

            The subroutine is divided into two sections, a design and an off-design
section similar to the once through-cooling system subroutine.

 50 2  Assumptions

           Variables and equations for which numerical assumptions have been
 made in the subroutine are listed below,  so that the cards may be changed if different
 numerical values are desired.
Variable (sequence or line #)
FANEF (668)
PMPEF (669)
DT2  (703)

DECKHT (735O
PHT(736)     J

WLOAD (738)
CONCR (805)
CAPCOS (813)
                                       Comments and/or Recommended Values
                                       0.5-0.8
                                       0.8 - 0.85
                                       Need not correspond to (for not used) specified
                                       condenser

                                       Constants must correspond to form of
                                       equation - Reference 7
                                       2500.
                                       of Reference 1
                                        44

-------
5. 3     Basic Equations

             The equations for the size of the cooling tower are based on a calculation
of a tower "characteristic, " CHAR. Calculation of this characteristic is done with the
use of the Tchebycheff (cf Ref. 6)  numerical integral approximation,  such that
where

RDH1


RDH2

RDH3


RDH4
                       RA
            CHAR  =  ££• x [RDH1  + RDH2  + RHD3  + RHD4 ]
                                                               (5.1)
RA =  range =  (Tl -  T2)  ("F), and the RDH's are defined as follows;

      inverse of the difference between saturation enthalpy and actual
      enthalpy, evaluated at T2 + 0.1 x (Tl - T2) (Ibm/Btu)

      inverse of the difference between saturation enthalpy and actual
      enthalpy, evaluated at T2 + 0.4 x (Tl - T2)  (Ibm/Btu)
      inverse of the difference between saturation enthalpy and
      actual enthalpy,evaluated at Tl - 0.4 x (Tl  - T2) (Ibm/Btu)

      inverse of the difference between saturation enthalpy and
      actual enthalpy, evaluated at Tl - 0.1 x (Tl  - T2) (Ibm/Btu)
where       Tl   =  inlet water temperature (°F)
             T2   =  outlet water temperature (° F)
                                       45

-------
             The packing height in the tower required to give this characteristic is
calculated by (Ref.  7)

                          DECKHTx (CHAR - 0.7)                             ^
                   PHT=  	i	-o 54                             <5'2)
                           0.103 x (WART)

where      WART = water to air flow ratio
         DECKHT= deck spacing (ft)

             The capital cost of the tower is calculated by

                  CAPCOS =  3. x GPMT  x XK(IK)  x CWB                 (5.3)

where    GPMT   - total water flow rate (gal/min)
         XK(IK)   = cooling factor obtained from a curve fit of data
                    of Reference 8,  reproduced in Figure 5.1
         CWB    = wet bulb factor-obtained from Reference 8,
                    reproduced in Figure 5.2

             The coefficient, 3,  of Equation (5.3) is an average of data from Refer-
ences 8 and 9.
                                          46

-------
XK0K)
                                                       30
    Figure 5.1.  Cooling Factor as a Function of Range and Approach
                              (Ref. 8)
          1.4
          1.2
    CWB
          1.0
          0.8
              60         65         70         75

                   Wet Bulb Temperature (° F)
80
                 Figure 5.2.  Wet Bulb Factor  (Ref. 8)
                                   47

-------
 5.4    Flow Diagram

             The flow diagram for the design portion of the subroutine SUBMDW is
 shown in Figure 5.3.  A flow diagram for the off-design portion of the program has
 not been provided since it would be essentially the same  as the off design flow diagram
 for the cooling pond,  Figure 4.2.
5.5
Results
             The results using the data of all four data sets are shown in Tables 5.1
 through 5.4. The description of the results is the same as contained in Sections 3. 4
 and 4. 4 with the exceptions and additions noted below.
FAN POWER
H2O SLOWDOWN


AIR FLOW RATE
PRESSURE DROP
APPROACH
                the total fan power required for the tower
                the required water addition to maintain the specified
                concentration (cf Ref.  4, pg. 65)
                the total air flow rate through the tower
                the air pressure drop across the tower packing (inches of water)
                the difference between the water outlet temperature from the
                tower  and the wet bulb temperature
                                       48

-------
                                                   Start at Lowest
                                               Condenser Temperature
                                        yes
                                             100
                                               Is Condenser Specified?
      Topping Operation?
     44
yes
                             yes
                         Determine Correct TC
                          by Trial and Error
       Calculate Approach
             45
               Call COND r~
            47
             Calculate Range
             Save Parameters
                and Costs
      Topping Operation?
                           yes
               no
         Increase TC
        TC  ^  TCMAX?
                                                                      31
                                                                                      Topping Operation?
                      Set Approach Equal
                        to  Minimum
                                                                      50
                                            15
  Set Outlet T Equal
to Maximum Allowable
                        Calculate Outlet
                      Water Temperature
                                                   Calculate Range
                                                   and Approach
                                            46
                                              Call COND and Determine
                                               Tower Heat Rejection
   Calculate Approach
                                                                                51.
                                    Set Inlet Temperature
                                Equal to 5°F Above Condenser
                                        Temperature
                                                                                      Topping Operation?
                                                                                              yes
                                                Calculate Tower Size
                                                   and Total Cost
                                       yes
   Is Cost Lower
Than a Previous Cost?
                                       yes
                                               Is Condenser Specified1?
                                            190
                                                                        yes
                            Topping Operation?
      Increase Approach
                                              Print Design Calculations
                                 *  Off-Design Calculations
                         Figure 5. 3.  Flow Diagram for Design Portion of SUBMDW
                                                         49

-------
                      Table 5.1

     MECHANICAL DRAFT TOWER RESULTS USING SUBD1
            (SPECIFIED CONDENSER, TOPPING)
             	 MECHANICAL DRAFT WET TOWEP -

       THE DESIGN VALUES AND COSTS APE -
Q REJECT S^.IHIE os BTU/HR  AT T CONDENSED *   100
FAN POWER »4.770E 02 HP     PUMp POWER al«068E 03 HP
H20 FVAP al.955E 00 CFS  (4.784E 05 LB/HR)
H20 RLCWDCWN =5.l76E-01 CFS (1.267E 05 LR/HR)
AIR FLOW RATE =2.679E 07 LP/HR
PRESSURE DROP =  -3fl    COND FLOW =4.200E 07
RANGE *  12     APPROACH a  10

Q REJ TOWER =5.061E 08 BTU/HR

CAPITAL COST a5.6l2E 05 DOLLARS
CONDENSER AND PUMP COST a    QE 00 DOLLARS/KW
OPERATING COST =  .OH MILLS/KW-HR
MAINTENANCE COST =  .004 MILLS/KW-HR
CONDENSER SYSTEM COST =     0 MILLS/KW-HR
DIFFERENTIAL FUEL CCST a  .000 MlLLS/KW-nR

  TOTAL SYSTEM CCST =  .065 MILLS/KW-HR
            VARIABLE AMBIENT CONDITIONS
     FOR CAP al,00»    T WB =   60t  AND             TC *  9?
PC LESS THAM PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP Bl.OOt    T WB «   70»  AND             TC s  9?
PC LESS THAM PC MIN - ASSUME PC MIN . CONTINUE

     FOR CAP = ,60»    T WP *   60»  AND             TC *  79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP * ,25»    T WB »   60»  AND             TC «  79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP = ,25»    T WB s   70,  AND             TC a  79
PC LESS THAM PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP * .25f    T WB «   70»  AND             TC •  79
PC LESS THAN PC MIN - ASSUME PC MIN . CONTINUE

  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST a  .014 MlLLS/KW-HR
DIFFERENTIAL FUEL COST s-O.OOO MILLS/KW-HR

TOTAL SYSTEM CCST «  .064 MILLS/KW-HR

                             50

-------
                        Table 5.2

       MECHANICAL DRAFT TOWER RESULTS USING SUBD2
           (SPECIFIED CONDENSER, CLOSED SYSTEM)
                  • MECHANICAL DRAFT WET TOWER
                  VALUES AMD COSTS ARE -
o RFJECT =Q.43iE OH BTU/HR  AT T CONDENSER x  119
FAN POWER =?.749E 02 HP     PuMp PCWfR =9.667E 02 HP
H20 EVAP =3.527E 00 CFS  (8.631E 05 LB/HR)
H?0 RLOWDOWN =9.6^6E-01 CFS (2.360E 05 LB/HR)
AIR FLOW RATE =s.208E o? LB/HK
PRESSURE DROP =  -27    CCND FLOW =4.200(i 07
RANGE a  22     APPROACH =  19

CAPITAL COST =2.631E 05 DOLLARS
CONDENSER AND PUMP COST =    OE 00 DCLLARS/KW
OPERATING COST =  .011 MlLLS/KW-HR
MAINTENANCE COST =  .002 MILLS/KW-HR
CONDENSER SYSTEM CO$T s     0 MlLLS/KW-HR
DIFFERENTIAL FUEL COST =  ,OlO MILLS/KW-nR

  TOTAL SYSTEM COST =  .0^5 MILLS/KW-HR
            VARIABLE AMBIENT CONDITIONS


     FOR CAP sl.QOt    T WH =   (S0»  AND             TC =  9?
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP = ,?5»    T WB =   70»  AND             TC m  79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP = .25,    T WB *   70,  AND             TC a  79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST =  .Oil MlLLS/KW-HR
DIFFERENTIAL FUEL COST =-0.000 MILLS/KW-HR

TOTAL SYSTEM COST *  .035 MlLLS/KW-HR
                               51

-------
                       Table 5.3

     MECHANICAL DRAFT TOWER RESULTS USING SUBD3
             ("DESIGN" CONDENSER, TOPPING)
             	 MECHANICAL DRAFT WET TOWER 	—

       THE DESIGN VALUES AND COSTS ARE -
Q REJECT *9.454E OB BTU/HR  AT T CONDENSER «   120
FAN POWER =7.22iE 0? HP     PUMP PCWF.R =7»l48E  02  HP
H20 EVAP =2.650E 00 CFS  (6.485E 05 LB/HR)
H20 SLOWDOWN =7.235E-01  CFS  (1.770E 05 LR/HR)
AIR FLOW RATE "2.154E 07 LB/HR
PRESSURE DROP -  .72     CCND FLOW *2.380E 07
RANGE a  30     APPROACH a  10

Q REJ TOWER *7.074E 08 BTU/HR

CAPITAL COST =5.543E 05  DOLLARS
CONDENSER AMD PUMP COST  s5.Q93E 00 OOLLARS/KW
OPERATING COST a  .013 Mll.LS/KW-HR
MAINTENANCE COST »  .005 MILLS/KW-HR
CONDENSER SYSTEM COST •  ,091 MILLS/KW-HR
DIFFERENTIAL FUEL COST •  .010 MILLS/KW-HR

  TOTAL SYSTEM COST =  .166 MILLS/KW-HR
            VARIABLE AMBIENT CONDITIONS


     FOR CAP « ,25»    T WB *   60*  AND              TC  a  79
PC LESS THAN PC MlN - ASSUME PC MIN - CONTINUE

     FOR CAP = .25.    T WB «   70i  AND              TC  a  79
PC LESS THAM PC MIN - ASSUME PC MIN « CONTINUE

  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST a  .013 MILLS/KW-HR
DIFFERENTIAL FUEL COST a  .004 MILLS/KW-HR

TOTAL SYSTEM COST a  .159 MILLS/KW-HR
                              52

-------
                   Table 5.4

  MECHANICAL DRAFT TOWER RESULTS USING SUBD4
       ("DESIGN" CONDENSER, CLOSED SYSTEM)
             	 MECHANICAL OfcAFT WET TCWFR


       THE DESIGN VALUES AND COSTS ARE -
Q REJECT =9.^54E oe BTII/HR  AT T CONDENSER *   120
FAN POWER «3.953E 02 HP     PUMP PCWFR «g.780E 02 HP
H20 EVAP *3.536E 00 CFS  (R.652E 05 LB/HR)
H2Q RLOWDOWN =9.669E-01  CFS (2.366E 05 LB/HR)
AIR FLOW RATE =2.459? 07 LB/HR
PRESSURE DROP =  -35     COND FLOW =3.985E 07
RANGE =  24     APPROACH *  16

CAPITAL COST =5.523E 05  DOLLARS
CONDENSER AND PUMP COST  S6.70QE 00 DCLLARS/KW
OPERATING COST =  .013 MlLLS/KW-HR
MAINTENANCE COST =  .005 MlLLS/KW-HR
CONDENSER SYSTEM COST =  .122 MlLLS/KW-HR
DIFFERENTIAL FUEL COST =  .OlQ MlLLS/KW-nR

  TOTAL SYSTEM COST =  .197 MlLLS/KW-HR
            VARIABLE AMBIENT CONDITIONS



  WITH THE VARIOUS AMBIENT TEMPERATURES

  THE COSTS ARE -


OPERATING COST =  .012 MlLLS/KW-HR

DIFFERENTIAL FUEL COST «-0.000 MILLS/KW-HR


TOTAL SYSTEM COST =  .186 MlLLS/KW-HR
                       53

-------
                                 Section 6
                 NATURAL DRAFT WET COOLING TOWER

6.1    General Description

           The logic and calculations for the design of a natural draft cooling tower
system are contained in the subroutine SUBNDW.  This subroutine obtains power plant
information by "calling" PAFCST, and condenser specifications by "calling" COND.
The condenser may be specified or designed, the cooling system may be open or
closed, and part time or full time use of the coding system may be specified.

           The design method is the same as for the mechanical draft system,  in
that temperatures are varied over permissible ranges and the total system cost is
calculated for each set of conditions. The set of conditions  resulting in the lowest
total cost is then chosen as the design conditions.

           The subroutine is divided into a design and an off-design section similar
to  other cooling system subroutines.

 6.2  Assumptions

           Variables and equations for which numerical assumptions have been
 made in  the subroutine are listed below,  so that the cards  may be changed if
 different numerical values are desired.

 Variable (sequence or line#)            Comment and/or Recommended Values

 PMPEF  (966)                                      0.8 - 0.85
 HDRMAX (968)                                     1.  -1.75
 DT2 (1002)                             Need not correspond to (not used for)
                                       specified condenser
 WLOAD  (1014)                          Initial value needed
 VESf (1046)                                         2.  -  10.
 PPK (1055)                            Form of equation and constant - Reference 10
 PSP (1057)                             Form of equation and constants - Reference 16
 TPK  (1059)
 CAPCOS (1069)
 CONOR  (1070)                          of Reference 1

                                      54

-------
6-3     Basic Equations

            The equations for the size of the cooling tower are based on a calculation
of a tower "characteristic, » CHAR, and a tower height, THT, necessary to develop
the required pressure differential.

            The tower characteristic,  CHAR,  is calculated in the same manner as
for the mechanical draft system, Equation (5.1).

            The packing height required in the tower to give this characteristic is
calculated by (Ref. 10)
                       "DUTi     CHAR
                       PHT  = UNC-                                     (6-1)
where UNC is the characteristic per foot of packing and is  calculated by
                                             0.73
                                    /      \
                      UNC =  °-IX(WART)
where     WART  - ratio of water to air flow rates.

           The total tower height required is the sum of the sum of the chimney
height required for the pressure differential, the packing height,  the height of the
spray nozzles above the packing,  and the air inlet opening height. This is expressed
as
                    TPDP x VHDI                                         (6  3)
                                                                           l   '
                     DIN - DOUT

where     TPDP =   total pressure drop (air inlet velocity heads)
                                             2
           VHDI  =   inlet velocity head (Ibf/ft )
                                                    2
      DIN, DOUT =   inlet and exit air density (Ibm/ft )
           The capital cost of the tower is calculated from data on British towers
(Ref.  11) modified slightly to reflect United States prices.  The resulting equation
for the capital is
                                      55

-------
              CAPCOS  -  3.4  x  105  x  (HTDIA)'17                     <6'4)

 where     HTDIA =  height of tower times diameter of tower.

 6.4     Flow Diagram

            The flow diagram for the design portion of the subroutine SUBNDW is the
 same as that for the mechanical draft system subroutine SUBMDW, Figure 5.3. The
 off-design flow diagram is essentially the same as the off-design diagram for the
 cooling pond system,  Figure 4.2.  Therefore,  neither flow diagram is included in
 this section.

 6.5     Results
            The results using the data of all four data sets are shown in Tables 6.1
 through 6.4. The description of the results is the same as for the preceding cooling
 systems with the exceptions noted below.
                                                                    2
PRESSURE DROP  -    total air pressure diop through the tower (Ibf/ft )
TOWER HEIGHT   -    total height of the tower including opening and packing (ft)
TOWER
DIAMETER       -    base diameter of the tower (ft)
TOWER
CHARACTERISTIC-    the total tower characteristic (Ref. 6)

           ID. the variable ambient conditions error messages,

CHAR             -    tower characteristic required
THT              -    tower height required
           A fatal error message may occur within the off-design calculations for
closed systems when the cooling system cannot reject the required heat at any
coB.denser temperature between the specified limits.  A particular case would be if
the condenser temperature and ambient temperatures are the same as the  "design"
conditions, but the power plant is "operating" slightly off design and is less efficient
(the heat rate for 100% capacity is slightly higher than for "design").
                                       56

-------
                      Table 6.1

      NATURAL DRAFT TOWER RESULTS USING SUBD1
             (SPECIFIED CONDENSER, TOPPING)
             	 NATURAL DRAFT WET TC
          THE DESIGN VALUES AND COSTS ARE -
0 REJECT =9.1*1E 08 BTU/HR  AT T CONDENSER «  100
FAN POWER •    OE 00 HP     PUMP POWER »1.454£ 03 HP
H20 EVAP =3.546E 00 CFS  (8.677E 05 LR/HR)
H20 SLOWDOWN! =9.39QE-01  CFS  (2.298E 05 LB/HR)
AIR FLOW RATE «4.85gE 07 LB/HR
PRESSURE DROP =  1.2     CC^D FLOW *4.200E 07
   RANGE =  12     APPROACH =  10
TCWER HEIGHT =   470   TOWER DIAMETER *  315
WATER LCADIMG =    538 LBM/HR-FT2
TCWER CHARACTERISTIC = 1.38     PACKING HEIGHT*l2.4l

Q REJ TCWER =5.06lE 08 BTU/HR

CAPITAL COST «2.573E 06  DOLLARS
CONDENSER AND PUMP COST  *    OE 00 DCLLARS/KW
OPERATING COST s   .013 MlLLS/KW-HR
MAINTENANCE COST =  .014 MILLS/KW-HR
CONDENSER SYSTEM COST a     0 MlLLS/KW-HR
DIFFERENTIAL FUEL  COST =  .000 MILLS/KW-HR

  TOTAL SYSTEM COST =  .242 MILLS/KW-HR
            VARIABLE  AMBIENT  CONDITIONS
     FOR  CAP  =1.00»     T  WB  s    60»   AND   TC  *   92
PC LESS THAN  PC  MIN  -  ASSUME PC  MIN  - CONTINUE

     FOR  CAP  =1.00.     T WB «   70t  AND    TC  *   92
T DIS EXCEEDS T  DlS  MAX - CONTINUING

     FOR  CAP  * .80f     T WB s   70»  AND    TC  «   85
T DIS EXCEEDS T  DIS  MAX - CONTINUING

     FOR  CAP  * ,80»     T WB »   70t  AND    TC  *   90
T DIS EXCEEDS T  DIS  MAX - CONTINUING
                           57

-------
              Table 6.1  (Concluded)
     FOR CAP a .60.    T WR «   60t  AND   TC  =   79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP = .60.     T WB s  70t AND    TC  a   BO
T DIS EXCEEDS T DlS MAX - CONTINUING

     FOR CAP = .60.     T WB a  70t AND    TC  »   85
T DIS EXCEEDS T DIS MAX - CONTINUING

     FOR CAP a ,25.    T WB *   60»  AND   TC  a   79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP a .25.    T WB s   70*  AND   TC  a   79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

     FOR CAP * .25,    T WR =   70.  AND   TC  =   79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE
  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST r  .013 MlLLS/KW-HP
DIFFERENTIAL FUEL COST =-0.000 MILLS/KW-nS

TOTAL SYSTEM COST a  .341 MILLS/KW-HR
                        58

-------
                       Table 6.2

       NATURAL DRAFT TOWER RESULTS USING SUBD2
         (SPECIFIED CONDENSER, CLOSED SYSTEM)
             	 NATURAL DRAFT WET TOWER •

          THE DESIGN VALUES AND COSTS ARE -
Q REJECT sq.^54E OB BTU/HR  AT T CONDENSER *  120
FAN POWER =    OE 00 HP     PUMP POWER «1.200E 03 HP
H20 EVAP =3.537E 00 CFS  (8.654E 05 L8/HR)
H20 RLCWDCWNJ =<».669E-01  CFS (2.366E 05 LB/HR)
AIR FLOW RATE =2.114E 07 LB/HR
PRESSURE DROP =  1.5     COND FLOW =4.200F 07
   RANGE =  ?3     APPROACH a  20
TOWER HEIGHT =   235   TOWER DIAMETER *  207
WATER LOADINS =   1250 LBM/HR-FT2
TOWER CHARACTERISTIC =   -96     PACKING HElGHTal5.80

CAPITAL COST =2.129E 06  DOLLARS
CONDENSER AND PUMP COST  =    OE 00 DCLLARS/KW
OPERATING COST *  .Oil MlLLS/KW-HR
MAINTENANCE C^ST =  .012 MRLS/KW-HR
CONDENSER SYSTEM COST =     0 MiLLS/KW-HR
DIFFERENTIAL FUEL COST =   .010 MILLS/KW-HR

  TOTAL SYSTEM COST =  ,211 MiLLS/KW-HR
            VARIABLE AMBIENT CONDITIONS
     FOR CAP = .25.    T WB =   70»  AND  TC *  79
PC LESS THAN PC MlN - ASSUME PC MlN - CONTINUE

     FOR CAP = .25*    T WB a   70»  AND  TC =  79
PC LESS THAN PC MlN - ASSUME PC MlN . CONTINUE

  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST =  .Oil MiLLS/KW-HR
DIFFERENTIAL FUEL COST =  .008 MILLS/KW-HR

TOTAL SYSTEM COST «  .207 MILLS/KW-HP
                          59

-------
                      Table 6.3

       NATURAL DRAFT TOWER RESULTS USING SUBD3
            ("DESIGN" CONDENSER, TOPPING)
             	 NATURAL DRAFT  WET  TOWER  •

           THE  DESIGN  VALUES  AND COSTS ARE  -
o REJECT ag.^E OB BTU/HR  AT T CONDENSER  »   120
FAN POWER a    OE 00 HP     PUMP POWER *B»8ME  02  HP
H20 EVAP a3.542E 00 CFs  (8.66?E 05 LB/HR)
H20 BLOWDOWM =9.669E-01  CFS (2.366E 05 LB/HR)
AIR FLOW RATE =2.879E o? LB/HR
PRESSURE DROP =  1.2     CCND FLOW *2.380E 07
   RANGE *  30     APPROACH a  10
TOWER HEIGHT =   271   TOWER DIAMETER «   Ifl2
WATER LOADING =    911 LBM/HR-FT2
TOWER CHARACTERISTIC = 1.78     PACKING  HEIOHT*15.51

Q REJ TOWER a7.Q74E 08 BTU/HR

CAPITAL COST =2.135E 06  DOLLARS
CONDENSER AND PUMP COST  =5.093E 00 OOLLARS/KW
OPERATING COST s  .008 MlLLS/KW-HR
MAINTENANCE COST »  .01? MILLS/KW-HR
CONDENSER SYSTEM COST =  .091 MlLLS/KW-HR
DIFFERENTIAL FUEL COST =  ,QlO MILLS/KW-HR

  TOTAL SYSTEM COST =  .300 MILLS/KW-HR
            VARIABLE AMBIENT CONDITIONS
     FOR CAP sl.OOt     T WB a  70» AND   TC =  110
T DIS EXCEEDS T DIS MAX - CONTINUING

     FOR CAP = .80?     T WB *  70» AND   TC •  100
T DIS EXCEEDS T DIS MAX - CONTINUING

     FOR CAP = .80*     T WB *  70» AND   TC «  106
T DIS EXCEEDS T DIS MAX - CONTINUING

     FOR CAP « ,60f     T WB «  70» AND   TC «  92
T DIS EXCEEDS T DIS MAX - CONTINUING

     FOR CAP * ,60»     T WB a  70« AND   TC «  97
T DIS EXCEEDS T DIS MAX - CONTINUING

     FOR CAP « ,25?    T WB »   60»  AND  TC a  79
PC LESS THAN PC MIN - ASSUME PC MIN - CONTINUE

                        60

-------
           Table 6.3  (Concluded)
     FOR CAP = ,25t     T WR »  70»  AND    TC  «   79
T DIS EXCEEDS T DIS MAX - CONTINUING

     FOR CAP = ,25»     T WB =  70»  AND    TC  «   83
T DIS EXCEEDS T DIS MAX - CONTINUING

  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST =   .008 MlLLS/KW-HR
DIFFERENTIAL FUEL  COST =  .004  MILLS/KW-HR
TOTAL SYSTEM COST *   .293  MILLS/KW-HR
                       61

-------
                     Table 6.4
     NATURAL DRAFT TOWER RESULTS USING SUBD4
        ("DESIGN" CONDENSER,  CLOSED SYSTEM)
             	 NATURAL DRAFT WET TC
          THE DESIGN VALUES AND COSTS ARE -
o REJECT =o.454E oe BTU/HR  AT T CONDENSED *   120
FAN POWER =    OE oo HP     PUMP POWER =i.i40E 03 HP
H20 EVAP =3.546E 00 CFS  (8.678E Q5 IR/HR)
H20 SLOWDOWN =9f669E-01  CFS (2t366E 05 LR/HR)
AIR FLOW RATE =3.042E o? LB/HR
PRESSURE DROP =  1.4     CCND FLOW *2.980E 07
   RANGE =  32     APPROACH *   8
TOWER HEIGHT =   315   TOWER DIAMETER =  215
WATF.R LOADING «    820 LBM/HR-FT2
TOWF.R CHARACTERISTIC = 2.17     PACKING HEIGHT = 2l.33

CAPITAL COST =2.253E 06 DOLLARS
CONDENSER AND PUMP COST =5.759E 00 DCLLARS/KW
OPERATING COST =  .oil MlLLS/KW-HR
MAINTENANCE COST •  .013 MILLS/KW-HR
CONDENSER SYSTLM COST =  .1Q4 MlLLS/KW-HP
DIFFERENTIAL FUEL COST =  .010 MILLS/KW-nR

  TOTAL SYSTEM COST =  .326 MlLLS/KW-HR
            VARIABLE AMBIENT CONDITIONS
  WITH THE VARIOUS AMBIENT TEMPERATURES
  THE COSTS ARE -

OPERATING COST =  .010 MlLLS/KW-HR
DIFFERENTIAL FUEL COST =  .008 MILLS/KW-HR

TOTAL SYSTEM COST =  .323 MIlLS/KW-HR
                        62

-------
                                REFERENCES


 1.         Carey, J.H.,  Ganley, J.T., and Maulbetsch,  J.S., "A Survey and
            Economic Analysis of Alternate Methods for Cooling Condenser Discharge
            Water in Thermal Power Plants. Task I Report:  Survey of Large-Scale
            Heat Rejection Equipment, " Dynatech Report No.  849,  July 21, 1969.

 2>         Fuller,  W.D.  and Maulbetsch, J.S.,  "A Survey and Economic Analysis
            of Alternate Methods for Cooling Condenser Discharge  Water in Thermal
            Power Plants.  Task II Report:  Survey of Power Plant Operating Char-
            acteristics and Design Criteria, "  Dynatech Report No. 886, May 26,  1970,

 3-         Severns, W.H. and Fellows, J.R. , Air Conditioning and Refrigeration,
            Wiley &Sons,  Inc., N.Y.,  1958.

 4-         FWPCA, Industrial Waste Guide on Thermal Pollution,  September 1968.

 5.         Edinger, J. E. and Geyer, J. C., "Heat Exchange in the Environment, "
            Edison Electric Institute Publication No. 65-902, 1965.

 6.         Cooling Tower Institute, Cooling Tower Performance Curves, Millican
            Press, Ft. Worth, Texas, 1967.

 7.         Fraas, A. P.,  and Ozisik, M. N. , Heat Exchanger Design,  John Wiley
            &Sons,  Inc.,  N.Y.,  1965.

 8.         Lockhart, F.J. , Whitesell, J. M., and Catland, A. C.,  Jr.,  "Cooling
            Towers for the Power Industry, " American Power Conference,  1955.

 9.         Converse, A.O., "Thermal Energy Disposal Methods for the Proposed
            Nuclear Power Plant at Vernon, " Submitted to  the State of Vermont,
            November 1967.

10.         Lowe, H. J., and D. G.  Christie, "Heat Transfer and Pressure Drop Data
            on Cooling Tower Packings, and Model Studies of the Resistance of Natural
            Draught Towers to Airflow, " Int. Heat Transfer Conf., 1961, Vol. V-A.

11.         Kelly, A. G.,  and Lawless,  N.R., "Economic Sizing of Cooling Towers, "
            Combustion Engineering, August 1962.

12.         Bauman,  H. C.,  Fundamentals of Cost Engineering in the Chemical
            Industry,  Reinhold Publishing Co., N.Y.,1964.

13.         Perry,  J. H.,  Chemical Engineering Handbook,   3rd Edition, McGraw-
            Hill Book Co., N.Y. , 1960.
                                     63

-------
14.         Goodman, W.,  "The Evaporative Condenser-Theory and Characteristics,"
           Heating, Piping and Air Conditioning, V. 10, No. 3, March 1938.

15.         Kays,  W. M. and London, A. L.,  Compact Heat Exchangers, McGraw-
           Hill Book Co.,  N. Y. , 1958.

16.         Risch, R. F., "The Design of a Natural Draught Cooling Tower",
           London,  International Heat Transfer Conference, Denver,  1962.
                                   64

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APPENDIX
    65

-------
ACFM
ACOND
AFLR
AFLR1
ALDG
ALDGE
ALPACT
ALPHA
ALPHA1
AMBDFC (I)
AMBOPC (I)
AMBRH (J)
AMRAD
AMWIND
ANFCR
APPR

APPR1
APSAT
AREAC
AREAP
AREAP1
AVDFCS
AVOPCS
AVTCST
BETA

BOWRAT

BSA
CAIR
CAP(I)
CAPCOS
 Glossary of Variable Names
Air Flow Rate (ft3/min)
                 2
Condenser Area (ft )
Air Flow Rate (Ibm/hr)
AFLR corresponding to TOTCS1
Air Loading (mass velocity) (Ibm/ft -hr)
                                          O
An Equivalent Air Mass Flow Rate (Ibm/hr-ft )
The Actual ALPHA
Exponent for Exponential Temperature Decay
Exponent for Exponential Temperature Decay
Differential Fuel Cost for Operation at CAP (I) (mills/kwhr),
Operating Cost at CAP(I) (mills/kwhr)
Off Design Relative Humidities (%/100)
                                   e\
Off Design Absorbed Radiation  (Btu/ft -day)
Off Design Wind Velocity (mph)
Annual Fixed Charge Rate (%/100)
Approach - temperature difference between outlet
water and wet bulb (° F)
APPR corresponding to TOTCS1
Water Vapor Partial Pressure  (psi)
                                       o
Condenser Area for  Specified Condenser (ft  )
Cooling Pond Area (acre)
AREAP corresponding to TOTCS1
Average Off Design Differential Fuel Cost  (mills/kwhr)
Average Off Design Operating Cost (mills/kwhr)
Average Off Design Total Cost  (mills/kwhr)
The derivative of the saturation pressure with respect
to temperature, evaluated at the equilibrium tempera-
ture (psi/° F)
Bowen Ratio-Ratio of Conduction to Evaporation Heat
Transfer
                     2
Base Area of Tower (ft )
Heat Capacity Rate (Btu/hr° F)
Plant Capacity (%/100)
Capital Cost ($)
                                     66

-------
CAPCS1
CAPFAC
CCPKW
CHAR
CHAR1
CHEAD
CKWHRS

C01
COLPCT(I)

CONCR

CONCST
COSMA1
COSMAI
COSPKL
COSPKW
CWB
DECKHT
DELF1
DELFC
DELHR
DELHS
DELP
DEPTH
DFCOD
DH


DHM, DHP

DHPRIM

DIA
CAPCOS corresponding to TOTCS1
Average Power Plant Capacity Factor (%/100)
Plant Capital Cost ($/kw)
Tower Characteristic
CHAR corresponding to TOTCS1
Friction Pressure Drop in the Condenser (water side)
Total Power Output per year during which the cooling
system  is used (kwhr/yr)
Total Enthalpy Rise of Air Through Tower (Btu/lbm)
Percent of Operating Time,  TOTLD(I), that cooling
system  is used $/100)
Ratio of Circulation Water to Raw-Water Minerals
Concentration
Condenser Cost ($)
COSMAI corresponding to TOTCS1
Maintenance Cost (mills/kwhr)
COSPKW corresponding to TOTCS1
Specific Capital Cost ($/kw)
Wet Bulb Factor
Deck  Spacing (ft)
DELFC corresponding to TOTCS1
Differential Fuel Cost  (mills/kwhr)
Change  in Heat Rate (Btu/kwhr)
Change  in Saturation Enthalpy (Btu/lbm)
Packing Pressure Drop (inches of water)
Condenser Depth (ft)
Off Design Differential Fuel Cost (mills/kwhr)
Net Heat Transfer Rate from water to air - will
be zero when the equilibrium temperature  is
substituted into its defining equation (Btu/ft -day)
The Heat Transfer Rate from water to air  when
the water is 1° F below and above the equilibrium
temperature (assumed or  actual) (Btu/ft2-day)
The Derivative  of DH with Respect to Temperature
(Btu/day ft2-8 F)
Tower Diameter (at base) (ft)
                                    67

-------
DIA1
DIN
DOUT
DPI
DTI
DT2
DTLGM
DTRIV

ECOF
FANEF
FCFS
FLOW
FLOW1
FUCST
FUDGE
GPM
GPM1
GPMT
H(T)
HI

H2

HDR
HDR1
HDRMAX
HEATR
HOUT

HPF1
HP FAN
HPP1
HPPMP
DIA corresponding to TOTCS1
Inlet Air Density (lbm/ft3)
Exit Air Density (lbm/ft3)
DELP corresponding to TOTCS1
Condenser Temperature Difference =  TC - T2 (° F)
Condenser Temperature Difference (approach) =  TC -Tl (° F)
Log Mean Temperature Difference (° F)
Change  in total "mixed" river temperature between
upstream  and just downstream of condenser (° F)
Evaporation Coefficient (Btu/ft day mm Hg)
Fan Efficiency (%/100)
                 o
Condenser Flow (ft /sec)
Condenser flow (Ibm/hr)
FLOW corresponding to TOTCS1
Fuel Cost ((^/million Btu)
An Intermediate Cost Factor
Condenser Flow Rate (gal/min)
GPM corresponding to TOTCS1
Total  Flow Rate (gal/min)
Saturation Enthalpy at Temperature T (Btu/lbm)
Saturation Enthalpy corresponding to the Wet Bulb
Temperature (Btu/lbm)
Saturation Enthalpy corresponding to TAXT (except
SUBEVAP) — SUBEVAP only - Exit Air
Enthalpy (Btu/lbm)
Ratio  of Tower Height to Diameter
HOVD Corresponding to TOTCS1
Specified Maximum HOVD
Net heat rate (Btu/kwhr)
Saturation Enthalpy corresponding to Outlet Air
Temperature (Btu/lbm)
HPFAN  corresponding to TOTCS1
Fan Power (fap)
HPPMP corresponding to TOTCS1
Pumping Power (hp)
                                    68

-------
HR(I,J)
HRBASE
HRCOF2(I), HRCOFl(I)
HRCOF0(I)
HRP (I,J)
HTDIA
HWB1
IRE AD
ISUB
IRITE
IWL
NCAPS

NCAPS1
NH2O

NHRPTS (I)
NSPCON

NSUBS(I)
NSYSOP

NTAMB
NT COD

OPCOD
OPCOS
OPCS1
OPHT
OPHT1
P(T)
PBAR
Net Heat Rate Corresponding to HRP(I, J) (Btu/kwhr)
Base net heat rate corresponding to PCBASE (Btu/kwhr)
Quadratic Heat Rate Coefficients such that HEAT RATE =
HRCOF2(I) x (TC)2 + HRCOFl(I) x (TC) + HRCOF0
Condenser Pressure for each Heat Rate  Point.  THR(I, J)
at each CAP(J)  (in. Hg.)
                                    p
Tower Height times Tower Diameter (ft  )
HI corresponding to TOTCS1
Program Read Control Number
Program Subroutine Control Number
Program Print Out Control Number
Number of Iterations on WLOAD
Number of Plant Capacities (exclusive of "design"
capacity)
Subscript meaning "Design" Value
Type of Cooling Water Used (-1= seawater,  0=
untreated fresh water, + 1= treated fresh water)
Number of Heat Rates Input at each CAP(I)
Whether or not Condenser is Specified
(0= no, 1= yes)
Subroutine  Control Flags
Type of Cooling System Operation (0= closed cycle,
2= topping)
Number of Ambient Temperatures
An Index of the Condenser Temperature has
been Incremented
Off Design Operating Cost (mills/kwhr)
Operating Cost (mills/kwhr)
OPCOS corresponding to TOTCS1
Tower Inlet Air Opening Height (ft)
OPHT corresponding to TOTCS1
Saturation Pressure a T (psia)
Atmospheric Pressure (= 14. 696 psi)
                                69

-------
 PC BASE
 PCMAX(I)
 PCMIN(I)
 PCTAMB (I,J)
PHEAD
PHT
PKWA

PKWB

PLAC
PLAC1
PLANA
PLANA1
PLUMEW
PLUMT
PMPCST
PMPEF
PPK
PPK1
PRPAGR
PSIZE
PSP

PV
PWCST
QCON
QLAT
QREJ
 Base Condenser Pressure (in.  Hg.)
 Maximum Condenser Pressure for CAP (I) (in.  Hg.)
 Minimum Condenser Pressure  for CAP (I) (in. Hg.)
 Percent of Cooling System Use Time,
 (COLPCT(J) x TOTLD(J)), at each CAP(I) that
 the system operates at the specified ambient
 temperatures  (TAMDB(J), TAMWB(J)) (%/100)
 Frictional Pumping Head (ft.)
 Packing Height (ft)
 Packing Pressure drop with zero water flow
 (velocity heads/ft)
 Slope of packing pressure drop versus water loading
 curve (hr ft velocity heads/lbm)
 Cost of Condenser Cooling Water Ducting ($/kw)
 PLAC corresponding to TOTCS1
 Tower  Plan Area (ft2)
 PLANA corresponding to TOTCS1
 Plume Width (ft)
 Plume Temperature (° F)
 Pumping  Cost (mills/kwhr)
 Pump Efficiency (%/100)
 Pressure Drop Across Packing (inlet velocity heads)
 PPK corresponding to TOTCS1
 Cost of Land and Pond Construction ($/acre)
Rated Plant Output (MW)
Air Pressure Drop Across Water Spray
 (inlet velocity heads)
 Partial Pressure of Water Vapor (psia)
 Power cost (for auxiliaries) (mills/kwhr)
Condenser Water Flow (ft3/sec)
Latent (evaporation) Heat Transfer (Btu/hr)
Heat Rejected by Power Plant (Btu/hr)
                               70

-------
QREJT
QRJ1
QRJT1
RA
RA1
RAD
RDH1
RDH2


RDH3


RDH4


SPFLOW

SPHT
SYS1
SYSCST
Tl

Til
T2

T21
TA
TAMDB(J)
TAMRV(J)
TAMWB(J)
Heat Rejected by Cooling System (Btu/hr)
QREJ corresponding to TOTCS1
QREJT corresponding to TOTCS1
Condenser or cooling System Range (° F)
RA corresponding to TOTCS1
Absorbed Radiation (Btu/ft2 day)
Inverse of the difference between saturation
enthalpy and actual enthalpy, evaluated at
T2  +  0.1 (Tl - T2) (Ibm/Btu)
Inverse of the difference between saturation
enthalpy and actual enthalpy, evaluated at
T2  +  0.4 (Tl - T2) (Ibm/Btu)
Inverse of the difference between saturation
enthalpy and actual enthalpy, evaluated at
Tl  - 0.4 (Tl - T2) (Ibm/Btu)
Inverse of the difference between saturation
enthalpy and actual enthalpy, evaluated at
Tl  - 0.1 (Tl - T2) (Ibm/Btu)
Condenser Water Flow Rate for Specified
Condenser (Ibm/hr)
Distance of Spray nozzles above packing (ft.)
SYSCST corresponding to TOTCS1
Condenser System Cost (mills/kwhr)
Temperature of Water out of Condenser
(into cooling system) (° F)
Tl  corresponding to TOTCS1
Temperature of Water into Condenser
(from cooling system) (° F)
T2  corresponding to TOTCS1
Air Temperature (° F)
Off Design Dry Bulb Temperature (° F)
Off Design River of Estuary Temperature (° F)
Off Design Wet Bulb Temperature (° F)
                                 71

-------
TAVH2O
TAXT
TAXT1
TC
TCI
TCALC
TCALC1
TCBASE
TCMAX(I)
TCMIN(I)
TDB
TDFMIL
TDISMX
TG
THR(I,J)

THT
THT1
TKWHRS
TNEW
TOPMIL
TOTCOS
TOTCS1

TOTHP
TOTLD(I)

TOUTS
TPDP
TPDP1
TPIX
Available Water Temperature (° F)
Average of Inlet and Outlet Water Temperatures (° F)
TAXT corresponding to TOTCS1
Condenser Temperature (° F)
TC corresponding to TOTCS1
Equilibrium Temperature (° F)
TCALC corresponding to TOTCS1
Base Condenser Temperature (° F)
Maximum Condenser Pressure at CAP (I) (° F)
Minimum Condenser Temperature at CAP(I) (° F)
Design Dry Bulb Temperature (° F)
Total Differential Fuel Cost for Each Capacity (mills)
Maximum Water Discharge Temperature (° F)
An Initial Guess at the Equilibirum Temperature (° F)
Condenser Saturation Temperature corresponding to
HRP(I,J) (° F)
Total Tower height (ft)
THT corresponding to TOTCS1
Total Power Output per Year (kwhr/yr)
A New Guess at the Equilibirum Temperature (° F)
Total Operating Cost for each Capacity (mills)
Total System Cost (mills/kwhr)
The Minimum Total  System Cost  calculated up to
that point in the Program (mills/kwhr)
Total Auxiliary Power Required for Cooling System (hp)
Hours per year Operating at each corresponding
Capacity CAP (I) (hrs/yr)
Saturation Temperature of Outlet Air (° F)
Total Pressure Drop (inlet velocity heads)
TPDP corresponding to TOTCS1
Inlet and exit turning losses plus friction loss
(inlet velocity heads)
                                72

-------
TURBHR(I,J)

TWAV
TWB
TWREAL

TXDIST
TZERO
UA
UA1
UALL
UNO
UOVALL

USEFAC
VELRIV
VHDI
VIN
WACT
WART
WART1
WBDWN
WBDWN1
WCOFA, WCOFB
WEVAP
WEVAP1
WIDTH
WIND
WLMTD
WLOAD
WLOAD1
WNEED
Net Heat Rate corresponding to HRP(I, J) for
each CAP(I) (Btu/kwhr)
Average Water Temperature (° F)
Design Wet Bulb Temperature (° F)
River Temperature XI Downstream from Plant if no
heat were added  at plant (° F)
"Mixed"  river temperature XI Downstream from Plant (° F)
"Mixed"  river temperature just downstream of condenser (° F)
Heat Transfer Coefficient times Area (Btu/hr° F)
UA corresponding to TOTCS1
Overall Heat Transfer Coefficient (Btu/hr-ft2-0 F)
Characteristic per foot of packing
Overall Heat Transfer Coefficient for Specified
Condenser (Btu/hr-ft2-0 F)
Average  Cooling Use  Factor  (%/100)
River Velocity (ft/day)
Inlet Velocity Head (lbf/ft2)
Air Inlet Velocity (ft/sec)
Specific Humidity
Ratio of Water Flow to Air Flow
WART corresponding to TOTCS1
Water Flow Needed for Blowdown (Ibm/hr)
WBDWN  corresponding to TOTCS1
Coefficients such that ECOF  = WCOFA  + WCOFB x WIND
Water Evaporation Rate (Ibm/hr)
WEVAP corresponding to TOTCS1
Width of River or Estuary (ft)
Wind Speed (mph)
Log Mean Temperature of Cooling Pond (° F)
Water Loading (Ibm/hr/ft2)
WLOAD corresponding to TOTCS1
Total Makeup Water Required (Ibm/hr)
                                 73

-------
WNEED1                 WNEED corresponding to TOTCS1
XI                       Distance Downstream from Plant (mi)
XK                      Energy Exchange Coefficient (Btu/day ft-0 F)
XK (IK)                  Cooling Factor defined in Figure 5.1
XK1                     XK(IK) corresponding to TOTCS1

-------
    PROGRAM LISTINGS

Main Program
Subroutine SUBPOLU
Subroutine SUBPOND
Subroutine SUBMDW
Subroutine SUBNDW
Subroutine PAFCST
Subroutine COND
Subroutine PRTDS1
Subroutine PRTDS2
Subroutine PRTOD
Function H(I)
Function P(T)
Data SUBD1
Data SUBD2
Data SUBD3
Data SUBD4
          75

-------
200
201
202
203
2o4
205
210
      PROGRAM MAINFWP
      COMMON PSIZE.CCPKW,ANFCR«FUCST.NCAPS,CAP<6) »TCTLo<5> ,
       CCLPCT<5) tTCMIN(6) ,PCMIN(6) ,TCMAX(6) »PCMAX(6) »
       HPCCF2(6) .HRCCF1 (6) »HRCCFO<6) ,TDB»TwB,RH,TAVH2C,TCBA<;F:.
       NTAMB,AMBDFC<5)»AMBCPC(5) »TAMDB(5) tTAMWB(5) ,AMBpH(5)
       TAMRV<5) »PCTAMB<5,5) ,NSYSCp,TDlSMX,NSPCCN,UCVALL
       NH2>%wiDTH,PRPAGR,CAPFAC,USEFAC,TKWHRS,IRITE.lREAD»
     *  AMwiND(5) »AMRAD(5) »WIND,RAD
      DIMENSION NHRPTS(6) ,HRP(6,6) ,THR(6»6) ,TURBHR (6.6) »
     X  HR(6,6) tNSUBS(5)
      IRITFS31
      IP-EAD*30
      FORMAT(5F10.0»I10)
      FORMAT(frF10.2)
      FORMAT (6F10.0)
      FCRMAT(7IIO)
      FORMAT(6FlO.O»2llO)
      FORMAT(F10.0»2I10»4F10.0)
      REAO(IREAD.200)PSIZE»CCPKW»ANFCR,FUCST,PRPAGR.NCAPS
      NCAPSI=MCAPS*I
      READ (iREAO, 201) (CApm ,1-1,5)
      READ{IREAD»202) (TOTLD(I) »I*lt5)
      READ(IREAD»20l) (COLPCT(I) »I»1.5>
      READ ( iREAD»?o3) JNHRPTS 1 1 ) , 1*1 ( 6>
      RE AD (i READ* 201) (PCMINJI) .1*1,6)
      READ(IHEAD»20l> (PCMAX(I) .1=1,6)
      NNCAP»NCAPS
      IF(NHRPTS(NCAPSD ,6T, 0> NNCAP=NNCAP*1
      DC 210 I»1»NNCAP
       REAO(IREAO,201)  (HRP { I , J) » J«l .6)
      READ(IREAD»202) (TURBHR(I.J) ,J«1,6)
c
c
c

c
c
c
      READ (IREAD. 20*) TD8,TWB.TAVH2C»PCRASE, WIND, RAD, NH?C,NTAMB
      READ(1READ,202) (TAMDB(I)
      READ ( i READ* 202) (TAMWB ( i > . I=I,NTAMB)
      READ«IREAD»202) (TAMRV(I) .I^LNTAMB)
      «EAD(IREAD,202) (AMWIND(I) ,I«1,NTAMB)
      READ f IRE AD. 202) (AMRAD(I) »I=i,NTAMB)
    DO 216  lal
216  REAnaREAD»201) (PCTAMB(I.J) ,J»1,NTAMB)

    READ(IREAD,205)WlDTH.NSYSCP,NSPCCN,TolSMX,UCVALL,AREAC,SPFLCw
    READ«IREAD»203) (NSUBS(I) .1=1,5)
         LOAD DURATION HOURS  CHECK  -  TO STATEMENT
    TCTDURaOaO
    DC 243 lal.NCAPS
    TOTAM=0,0
         PERCENT AMBIENT  TIME CHECK - TO STATEMENT 242
    00 238 J»1»NTAMB
238  TCTAMsTCTAM*PCTAMB(I,J)
    IF( TOTAM .E0»  1») GO TO  2^2
    WRITEdRIfE. 239)1
         CALC Op RELATIVE HUMIDITY  -  RH AND AMBRH
239  FORMAT (* TOT PCT AMBIENT MRS NOT » 1»0 FOR CAP
    GS TO 5po
24?  CONTINUE
    TCTDUR»TOTDUR*TCTLD(I)
243  CONTINUE                          -,,
00001
00002
00003
00004
00005
00006
00007
00008
00009
00010
00011
00012
00013
0001*
00015
00016
00017
00018
00019
00020
00021
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00026
00027
00028
00029
00030
00031
00032
00033
00034
00035
00036
00037
00038
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000*1
00042
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OOO*4
00045
00046
000*7
00048
00049
00050
00051
00052
00053
00054
00055
00056
00057
00058
00059
00060
00061
00062

-------
      IF (TCTDUR ,EQ. 8760. ) GC TC 246
c
c
244  FORMAT** TOT LD MRS NCT • 8760 *)
    GC TC SOD
?46  CONTINUE

    PBARsU.696
    PVaP-(«PBAR-P
    DC 2n lal,NTAMB
 ?o  AMBRH ( i ) » 

- ( ( ) ) » X (TAMDR(I)-TAMWB(I) ) ) / (2831.-1 ,43*TAMWB II ) ) ) ) /PdAMDR (j ) ) QUADRADIC CURVE FIT CF HEAT RATpS (TC STATEMENT NNCAPaMCAPS CAP(NCAPSD»1. IF(NHRPTS(NCAPSi) .QT. 0> NNICAP = NNCAP*1 OC 9 1=1 ,NNCAP iF(NHRPTSd) .GT. 2) GC TC 7 WRITF(IPITE»6)I 6 FCRMAT(* LESS THAN 3 HEAT RATE*; FCR CAP NC ^,12) RC TC 500 r c C C M?aNMRPTS(I) DC 8 Jal ,M2 HR(I,J)rTURBHR(I,J) CALC CF 7SAT FRCM PRESS. (IN. HG) BLCG«ALCG(HRP(I|J) ) THR (I »J) =79, 035793 + 30. 462409*BLC6*1. 97404 16« X (BLCG)»»2*0.13124035«(BLCG)**3 X1=THR(I,J)*X1 X?=(THR(I.J)**2)+X2 Yl=HP(I,J)+Yl X3«(THR(I»J)«*3)+X3 8 X2Y«X2Y+(THRd»J)**2)*HR(I»J) OEN*X4»(R*X2-X1**2)-X3*(B»X3-X2«X1)»X2«(X3»X1-X2«*2) ANUM-X2Y»(8»X2-Xl»«2)"X3»(BixY-Xl*Yr)+X2*(XY»Xl-y2»Yi) RNUM=X4»(B*XY-Xl*Yl)-X2Y»(B»x3-X2»Xl)*X2«(X3»Yl-xY»X2) CNUM»X4»(X2*Yl-XY*xi)-X3*(X3*Yl-xY»X?)+X2Y»(X3*Xl-X2»»?) HRCCF?(I)«ANUM/DEN HRCCF1 (I)«BNUM/DEN HRCCFO(I)«CNUM/DEN 9 CONTINUE 100PCT CAPACITY HR (IF NCT 0> GO TO 45 C TC 42 MAKING DESIGN HR IF«HRCCF1(I) HRCCFO(NCAPSl> »HRCCFO(I) 77 00063 00064 00065 00066 00067 00068 00069 00070 00071 00072 00073 00074 00075 00076 00077 00078 00079 OOORO 00081 OOOB? 00083 00084 00085 OOOP6 00087 00088 00089 0009Q 00091 00092 00093 00094 00095 00096 00097 00098 00099 00100 00101 00*02 00103 00104 00105 00106 00107 00108 00109 00110 00111 00112 00113 PCMAX(NCAPSD"PCMAX(I) 00 1 V5 00116 00117 00118 00119 00120 00121 00122 00123 00124


-------
   45
      OC 11 I'l.NCAPSl
      BLCGsALCG(PCMlN(I)
c
c
    TCMIN( I) »79, 035793*30. 462409*BLCG* 1.97404 16*
   X (RLC6)**2*0.13J24035*(RLC6)**3
    BLCG*ALCG
    TCRASE«79, 035793*30. 462409*RLCG* 1.974041 6*
   X (BLCG)«*2*0.13124035«(RLCG)«»3

        CALC  CF AVG CAPACITY FACTOR AND CYCLING USE
    TKWHRS»6.0
    CKWHRSsO.O
    DC 47 TSI.NCAPS
    TKWHRSsTKWHRSMCAP(I)*TCTLD(I) )
 47   CKWHRS=CKWHRS*(CAP(I)*TCTLO*CCLPCT
    CAPFAC=TKWHRS/8760.
    USEFAC«CKWHRS/TKWHRS
C
C
      DO 60 ISUB»1»5
      IF(NSUBSdSUB) .EQ.O)GO TO 60
      GO TO (50.70.72,74,76)ISUB
   50 WRITE(IRITE*350)PSlZE»CCpKW,ANFCR»FUcST,PRPAGR
  350 FCRMAT(1H1»IOX»*	PRINTOUT OF INPUT OATA	
     X   /1H04X»*PSIZE    CAP $    ANFCR
     X5X,F5.0,F9.0.F8.2,F9.0»FlO.O//)
                                          FUEL $
                                                             /
      WRITE(I RITE,360) (CAP(I),1 = 1,NCAPS)
      WRITE(I RITE,361) (TCTLD(I),I«l,NCAPS)
      WRITE(I RITE,362) (CCLPCT(I)»I»1,NCAPS)
      WRITE(IRlTE,363)(PCMIN(I),Ial,NCAPSl»
      WRITE(IRITE,364)(TCMIN(I),I*l,NCAPSl)
      WRITE(IRITE,365)(PCMAX(I),I=1,NCAPS1)
      WRITE(I RITE,366) (TCMAX(I),I«1,NCAPS1)
  360  FORMAT(5*»*CAPACITIES  AND  CORRESPONDINfi
     XALUES ARE DESIGN DATA)*,//. 3*»*CAPACITY -
      FORMAT (*
      FORMAT {#
      FORMAT (*
      FORMAT u
      FORMAT (^
      FORMATS
               HRS/YEAR -
               PCT CCCLING -
               MIN
               MIN
               MAX
               MAX
P
T
P
T
CCND
CCND
CCND
CCND
*,5F7.o)
*,5F7.?)
^,6F7.?)
*,6F7.2>
*,6F7.?)
*,6F7.2)
361
362
363
364
365
366
370
    WRITE(IRITE,403)
403  FORMAT (SX.^CCN
   X*)
    DO 407 I»1.NCAPS
    WRITE(IRITE,404) CAP ( I >
404  FORMAT (/2X,*CAPACITY «<»F4.2)
      WRITE (IRITE, 370) CAPFAC.USEFAC
       FCRMAT(5X.#CAPACITY FACTOR s*»F5.2» /»5X ,#CCCLlN«  USE  FACTOR
                       PRESS  AND CORRESPONDING  DATA  AT  EACH CAPACITY
  405
    M2»NHRPTS(I)
    WRITE(I RITE»405) (HRP(I.J)»J«1»M2>
     FORMAT(3X.^PRESSURE -
                                                      001?5
                                                      001P6
                                                      00127
                                                      00128
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                                                      001"H
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                                                      OOU1
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                                                      0014B
                                                      00149
                                                      00150
                                                      001S1
                                                      00152
                                           78
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-------
    WRITE(IRITE,406)  (TURBHR(I»J).J«l
     FORMAT<3X.*T HEAT RATE -  *.6F8.0)
     IF(M2 ,EQ.  0)  GO TO 412
     WRITE(IRITE»*09)(HRP(NCAPSl,j),j«l,M2)
 409   FCRMAT(//5X,*DESIGN VALUES (CAPACITY « PLANT SI/E)*,//,  3X,
   XESSURE -    *»6F8.2»/)
     WRITF(IRITE,410)(TURBHR(NCApsl»J),J»1»M?)
 410   FCRMAT(3X,*T  HEAT RATE -  *,6F8.0»/)

 412   WRITE(IRITE,413)TDB»TWB,WIND,RAD,TAVH?C,NH2C
 413  FORMAT(*o   DRY BULB T    WET BULB T    WIND SPEF.U
    X  F12.0.F14.0»F13.1,F14.0/*0   AvAlL H20 T    TYpE
    X  F13.0,116)

     WRITE(IRITE,429)PCBASE,TCBASE
 429   FORMAT <3><»*BASE P CCND     _BASF T cCNi)*»/»7X»Fis»;
     WRITE(I RITE,414) (TAMDB(I),I*1,NTAMB)
 414   FORMAT(1H14X*VARIABLE AMBIENT TFMPERATHRES*,//3x»*D«Y 3'lLB -
    X  5F7.0,/)
     WRITE(I RITE,415) (TAMWB(I),I«1,NTAMB)
 415   FCRMAT(3X,*WET BULB -  *,5F7.0,/)
     WRITE(I RITE,416) (TAMRV(I),I»1,NTAMB)
 416   FCRMAT(3X,DRIVER -     *,5F7.0»/)
     WRITE (IRlTE, 1417)  (AMWINDd) ,I*l»NTAMp)
1417  FORMAT(*   WlND*8X,5F7.i)
     WRlTE(IRlTE,l418)  (AMRAO (I) M»l ,NTAMB)
1418  FORMATt*   RADIATION
                                                                 H2C    CONO s
                      ,/, 5x,F8.0,l4X.T2,24X,I2,/)

     IF(NSYSOP-2)424,421,424
 421   WRITE(IRITE»422)TDISMX
 422  FORMAT( 3X,*MAX DISCHARGE TEMP » *,F4.0/)

 424  IF(NSPCCN-1)428,425»*28      „„,„,.
 4?5  WRITE(IRITE»^26)UCVALL»AREAC»SPFLCW
 426  FORMAT(5X,5cCN0ENSER SPECIFICATIONS*,/, 3X,*cVEP*LL U =
    XO,/, 3X,*TUBE AREA . *,E9.4,/, 3x,*H2C FLOW = *,r9.<(   '

 4?8  CONTINUE
     GO TO 60

  70 CALL SUBPCLU
     GO TC 60
  72  CALL SUSPCND
     GO TC 60
  74  CALL SU8MDW
     GC TC 60
  76  CALL SUBNDW
  60 CONTINUE
 500  END                               7g
00187
001H8
00189
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0021 7
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002P4
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-------
                                                                      »TC
 SUBROUTINE SUBPCLU
 COMMON PSIZE»CCPKW,ANFCR»FUcST«NcAPStCAP(6>»TCTLn<5>» COl
XMIN<6> «PCMIN<6),TCMAX(6).PCMAX(A)»  HRCCF2(6),HR<"CFl(6)
XTDBtTW8,RH,TAVHaC,TCBASE,  NTAMB,AMBRFC(5)»AMBCPc (5),TA    ...
XR(«i» ,AM8RH(5) »  TAMRV<5» »PCTAMB(5«5» ,NSYSCP»TDISMX ,NSPrCNiUCVALL« A
XREAC.SPFLOW,  NHZCtWIDTH»PRPAQR.CAPFACtHSEFAC«TKwHRS,1*1TE.IREAO
 WIND«8.8
      RAD«5580.
      PMPEF=0»8
      TCTCSl»l,E3
c
c
c
CALCULATION OF THE EQULIBRIUM TEMPERATURE* TCALC,
STATEMENT } — EQUATJCN TAKEN FROM
      WCOF9»15
      ECCF=WCOFA*WCCFB*WIND
      TA»TDB
    7  OH»PAO-1801 .* (TG/460.*! . )*»4-ECOF»5\ t7» (P (TG) -RH*P  «.
     XF»(T«-TA)
      DHP»RAD°1801 .* ( ( T6*l . ) M6Qt *1 . ) *«4-EcSF*5 1 .7* < P < TG* 1 . ) -RH*P < TA ) ) -
     X.26«ECCF»«T6*1.-TA)
      DHM«RAO-l801 •* ( (TG-l . » M6o»*l . » *»4-EcCF*51 .7* (P 
-------
156
154
 CONTINUE
IF(N$PCCN.EQ.1)PLAC«0,0
SYSCST«SYSCST*PLAC»ANFCR/(CAPFAC»8,7A)
    ASSUME 5 FT OF PUMPING HEAD  (FRICTION)
PHEAO-5.
HPPMP»GPM*PHEAD/(3960,»pMpEF)
CAPCCSsO.O
OPCCS«(HPPMP«.7457/(PSIZE»1000.M»PWCST
COSMAI».001*CAPCCS/(PSIZE*1000.U.1*CPCCS».01«SY<;CST
TOTCCSsSYSCST*DELFC*OPCCS*CCSMAI
IF(TCTCOS-TCTCSl)154,156,156
 IF(NSPCCN.EQ.1)GC TO  190
 TC«TC*1.
IF(TQ-TCMAX(NCAPS*1))100,100,190
 PA1.RA
Tll-Tl
T21-T2
SYSUSYSCST
CAPCSl»CAPCOS
CCSP|$1«CCSPKW
CPCSUCPCCS
CCSMAlsCCSMAI
PLACI-PLAC
HPFUO.
HPPlsHPPMP
DELFl-OELFC
TCALC1-TCALC
QRjlsQREJ
FLCW'«FLCW
FCFS*FLOWl/224700.
GPMlaGPM
     TC1"TC
     TOTCSI*TOTCCS
     GO  TO  156
 190   IF(TOTCSl-leE3)200»195»2oO
 195   WRITE(IRITE»I96)TC,T1,RA
 196   FORMAT(/3X,    *FCR  THE  GIVEN  CONDITIONS A SOLUTION CANNCT Bf FCllN
   XD*»/,3X,*TC »*»F5«0»*    Ti **»F5.0»'t    RA »*,F5.0>
     GO  TO 400
 200   CONTINUE
     WRITE(IRITE,212)
 212   FORMAT (*l*l5X*	STRAIGHT CONDENSER COOLING—-—*t/i
     IF(NH20l220,228,230
 220   WRlTEtJRlTE»197)
 197   FC8MAT(20X*(WITH  SEA  WATER)*//)
     GO  TO ?3
 228   WRITE{IRITE»198)
 198   FCRMAT(20X*(WITH  UNTREATED FRESH WATER)*//)
     GO  TO 23
230   WRITFJJRITE»157)
 157   FORMAT(20X*(WITH  TREATED FRESH WATER)*//)
 23  WRltE(lRlTE,227)QRjl,Tci,FCFS,FLCWl,HPPl,TCALCl»RAi
227   FORMAT(10X*THE DESIGN VALUES  AND COSTS ARE -#•//,3X*Q RrJECT «
        1,4,* BTU/HR  AT  T CONDENSER •*,F4.0«/,3X*CCNnENSER FLOW »*,E9.
          CFS  <*E9.
   X4»* LB/HR)   PUMP  POWER  «*»E9.4»* HP*,/,3X*EOULIq«IUM TEMP «*,F4.0
   X,*       RANGE «*,F4.0»/>
     CALL PRTOS2(CAPCSiiOPCSitCCSMAl,SYSi,OELFl»TCTCSjiCOSPKI)
     WRITE(IRIT|,302)
302   FORMAT (//15X*—RIVER TEMPERATURES—**//,
   X1X,14HDISTANCE-MILES»3X,17HSTREAM TEMP DEG.F, 3X,17HPLtiME TEMP.-DE
                                     81
                                                                          00311
                                                                          00318
                                                                          00313
                                                                          00314
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                                                                        00364
                                                                        00365
                                                                        00366
                                                                        00367
                                                                        00368
                                                                        00369
                                                                        0037Q
                                                                        00371
                                                                        00372

-------
   XQ.F ,3X»14HPLUME WlDTH-Ml,/l9X»BHNC PLANT »2Xt5HMmD,//)              00373
         CALC CF PLUME TEMPS ANp WIDTH AND RIVER TEMpb-  TC  STAT  22        00374
    VELRIV«(QFLRIV/(WIDTH»DEPTH))*3600.»?4.                               00375
    DTRIV«i9RJl/QFLRIV)/<36oO.«62.4>                                      00376
    TZERO«TAVH2C*DTRIV                                                    00377
    I«-l                                                                  00378
307 I«I*1                                                                 00379
    IFd.EQ.11)1-20                                                       00380
    X1SI                                                                  003fll
    QCSN*FLSW1/(3600.*62.4)                                               00382
    C1«ALCG(QFLRIV/(QFLRIV-QCCN))                                         00383
    PLUMFW«WIDTH*U.-EXP(-(XI/2.*C1>))                                    003R4
    ALPHAl«-< ) ) *TWPEAL                  00389
    WRlTE'FLCW1)/(EXP(UA1/FLCW1)-1.>                                  004o7
    DT!*DT?*QREJ/FLCWI                                                    00408
    Tl=TC-Of2                                                             004Q9
    T2*TC-6tl                                                             00410
    IF(T2-TAMRV(J))3o4t305i3lO                                            004U
305  NTCCDal                                                              00*12
    QC TO 310                                                             00413
304  TC«TQilt                                                             00414
    NTCOp*!                                                               00415
    IF(TC ,LT» TCMAX(I))GC TO 301                                         00416
    WRITE(IRITE»309)PCMAX(I)»CAP(I)tTAMWB(J)                              00417
309  FORMAT {/»3X»*CCNDENSER PRESS MUST EXCEED  THE 6IVF.N  MAX  CFjt./ 8       00418
   XXtF*^*?1 FOR THE CAPACITY Cp*»F4.2»* AT T  WET BUi,B =*,F5.0»/.3X,*P   00419
   XRCQRAM  DISCONTINUING^)                                                00420
    GO TO 400                                                             00421
310  IF1NTCOP«6T.O)60 TO 315                                              00422
    WRITE                                   00429
    AMBDfC(D«AMBDFC(I) *DFCOD«Pcf AMB(J)                                   00430
340  CONTINUE                                                             00431
    TCPMIL«TOPMIL*AMBOPC (I) *TcT|nD < I) «CCLPCT (I) «CAP < I)                     00432
    TDFMlL-fDFMIL*AMBDFC  «COLPCT(I)*CAP(I)                     00433
350  CCNTIKJUE                                                             00434
                                      82

-------
AVCPCS-T3PMIL/TKWHRS
AVDFCS-TDFMJL'
 VTCST.ftVCPcS*
                                                                    00*39
END                                                                 00440
                                                                    00441
                                  83

-------
    SUBROUTINE SUBPCNO
    COMMON PSIZE,CCPKW,ANFCR»FUCST,NCAPS,CAP(6) ,TCTLn<5) ,  CCLPCT(5) .TC
   XMIN(6) ,PCMIN(6) ,TCMAX(ft) »PCMAX »T -.
   XF*(TG-TA)
    DHPsRAD-l801.*( (TG»l.
   X.26*ECCF«(TG*1.-TA)
    DHM=RAO-1801.*((TG-l.>/460.*l.)»»4-EcCF*51.7»(P(Hi-le)-RM»P(TA)
   X.26*ECCF»(TG-1.-TA)
    DHpRlM*(DHP-DHM)/2.
    IF(ABS(DH)-lt>l»2»2
  2  TNEW=T6-OH/DHPRIM
    TGaTNEW
    GO TO 7
  T  TCA^CsTS
    BETA*51.7*(P(TCALC*i.)-P(TCALC-l.))/2.
    XKsl«5.7*(0.26*BETA)»ECCF
100  CONTINUE
    IF(NSPCCN-l)30f40f3Q
 40  CALL PAFCST(NCAPS*I,TC»PWCST,DEI FC«QREJ»
    OT2» (QREJ/SPFLCW) / (EXP (UCvAl_L»AREAC/SPFLCW> -1 . )
    OTT»OT2*QREJ/SPFLCW
    Tl»Tc-DT2
 41   IF(TDISMX.LT.TCALClGC TO 197
    IF{DTl-{TC-TAVH2C))15,15t42
 4?   IF«TC-TCMAX«NCApS*D) 13, 190,190
 13   TC=TC*1
    GO TO 40
 15   T2»TDISMX
    RA»TT-T2
    IF(RA,LT.O.}GC  TO  19°
    GO TO 46
 44   T2»TC-DT1
    IF
-------
   47  RA-T1-T2
      ALPHA«-AL06«T2-TCALC)/(Tl-TCALC))
      AREAP»?4.»ALPHA»FLCW/(XK*43560.)
C         AL?G MEAN T DIF BETWEEN AIR AND WATER
      IF(T2-TDB)48»48,49
   48  WLMTD«(Tl*T2)/2.-TDB
      GO TO ?3
   49   WLMTD«(T1-T2)/ALCQ((Tl-TDR)/(T2-TDB))
c         BCWEN RATIO - RATIO OF CONDUCTION TO EVAPORATION
c      HEAT TRANSFER - MODIFIED FROM EDINGER AND GEYER
   53   TWAV«(Tl*T2)/2.
      BCWRAT*.26*WLMTD/<51.7*)>
      QLAT«{QREJT.(.173E-8*«TUT2)/2.»460.)««4-R AD/24.)
     *  43560.)/(l.*BCWRAT)
      WEVAP-QLAT/970.3
      GPMTaGPM*WEVAP/(8.34»60,)
C         ASSUME  30 FT OF PUMPING HEAD  (FRICTION)
      PHEAQ-3Q.
      HPPMP=QPMT*PHEAD/(396o.*pMPEF)
      CAPCCSsAREAP'PRPAGR
      DELFC*DELFC«USEFAC
      CPCCS* (HPPMP*.7457/ (PSIZEMOOO.))*PWcST«USEFAC
      COSMAla,OOl*CAPCCS/(PSIZE*loOO.)*.l«CPCCS*.01«SYsCST
      TCTCCSs(CAPCOS*ANFCR)/(PSlZE*1000.*CAPFAC*8.76) *OPCCS
     XCST*DEUFC
      IF(TCTCCS-TOTCS1)154t156*156
   156  IF(NSPCCN.EQ«DGO TO  1?7
      IF(NSYSCP.EQ.2)GC To 151
      T2»T2*1.
      GO TO 50
   157  IF(NSYSOP.EQ.2)GO TO  190
   151  TC»TC*1.
      IF(TC-TCMAX(NCAPS + 1))100* 100.190
   154  RA1*8A
      AREAPlsAREAP
    SYS1.SYSCST
    CAPCS1-CAPCCS
    COSPKl*CCSPKW
    CCSMiUcCSMAl
    HPFl«0,
    HPPlxHPPMP
    TCALCl«TCALC
    QRjlgQREJ
    QRJT1»QR,EJT
    FLOW1-FLCW
    OPMl«GPM
       WEVAPI-WEVAP
       TC1-TC
       TCTCS1-TOTCCS
       GA TM 156
   190  IF(TCTCSl-l.E3)200*195.200
   195        —	
   196
                               CONDITIONS A SOLUTION CANNOT  BE
                                                                        00504
                                                                        00505
                                                                        00506
                                                                        00507
                                                                        00508
                                                                        00509
                                                                        00510
                                                                        00511
                                                                        00512
                                                                        00513
                                                                        00514
                                                                        00515
                                                                        00516
                                                                        00517
                                                                        00518
                                                                        00519
                                                                        oosap
                                                                        00521
                                                                        00522
                                                                        00523
    00 TO
197  WRlTE(IRlTEfl98)
00525
00526
00527
00528
00529
00530
00531
00532
00533
00534
00535
00536
00537
00538
00539
00540
00541
00542
00543
00544
00545
00546
00547
00548
00549
00550
00551
00552
00553
00554
00555
00556
00557
00558
00559
00560
00561
00562
00563
00564
00565
                                       85

-------
198  FcRMAT(/,3x»*MAX ois T LESS THAN EQULIRRIUM T*>
    GO TO 4QO
?00  CONTINUE
     WRITEJIRITE.212)
212  FCRMAT«*l*»l5X,#-	COOLING PCND ——*,//,  loXt   *7HF;  DESIGN  V
   XALUES AMD COSTS ARE -*t//)
     CALL PRTDSl(QRJliTCl»HP>1 »HPP1»WEVAPl»WRDrtNl,AF|_Nl)
    WRITE(IRiTE»227)FLCWl«Tll»RAl.TCALCrtARF.APl
227  FORMAT (3X»*CCND FLOW M»E9.4t*    T IN a#,F4.0»<      "'AMGE  =<
   X,F
    TG«TA
    RAD»AMRAQ(J)
    ECCF*WCCFA*WCCFB*AMWINO(J)
 20  pH»RAD-180l.*(T6/460.»l.>«»4-Ecr!F«5l.7«(P
   XP(TA) )-.26»ECCF*(TG-l.-tA)
    DHPRlM»(DHP-DHM)/2.
    IF(ABS(DH)-1.)21»22«22
 22  TNEW»T6-DH/DHPRIM
    RO TO 20
 21  TCALCsTS
    BETA»5l.7*
-------
    QC TC 315                                                            00628
302  ALPHA»-ALC6( (T2-TCALO / (Tl-TCALO >                                  006?9
    IF (ALPHA.LT.ALPACT)GC TC 3l6                                         00630
304  TC«TC*1.                                                            00611
    NTCOn-1                                                              00632
    IF(TC .LT. TCMAX(I))6C TO  301                                        00633
    WRITE
-------
    SUBROUTINE  SUBMDW
    COMMON PSIZEtCCPKW,ANFCR»FUcST»NCAPS»Crtr *o.
   X COLPCT«S)»TCMIN«6).PCMIN(6),TCMAX*6}»PCMAX(6)«
   X  HRCOF2«6) »HRCCFJ (65 «HRCCFO(6» ,TDB»TWB,RHfTAVH2r:« TCBA^f
   X  NTAMB,AMBOFC(5i tAM8GPC«5>,TAMDR<5),TAMWB«5),AMpWH(5).
   X  TAMRV(5)»PCTAMB(5,5) .NSYSoPtTQlSMX', MSPCCNtUOVAt Lt AP«^»'
   X  NH?C,wiDTH»PRPAGR,CAPFAC»USEFAC»TKwHRS,lRITE»I»EAD
    p».akdir-ft.i^««vkR V*> a "3 f\ 1
    TCTCSl"lrE3
    TCsTCMINKNCAPS*!)
100  CONTINUE
    IF(NSPC5N-l)30»40i30
 40  CALt PAFCST!NCAPS*l»TC9PWCsT«DELFCeQREJ»
    OTgs (QREJ/SPFLCW) / 0C TO 151
    IF«APPR,GT.20»JGG TO 190
    GO TO 45
 30  IF(NSYSOP-2)3lt32t31
 31  APPP=7.
 50  T2«TWB*APPR
    IF(TC-T2)l51«15lt5l
 32  T2*TOISMX
    APPR*T?-TW8
    IF
    AFLR«QREJT/JH2-H1»
    WACT»RH»U622*P(TDB) )/
    ApSATaHWACT#l4,696)
00660
00661
00663
00663
00664
00665
00666
00667
00668
00669
00670
00671
00672
00673
00674
00675
00676
00677
00678
00679
006RO
00681
00682
00683
00684
00685
006P6
00687
00688
00689
00690
00691
00692
00693
00694
00695
00696
00697
00698
00699
00700
00701
007Q2
00703
00704
00705
00706
00707
00708
00709
00710
00711
00712
00713
00714
00715
00716
00717
00718
00719
00720
00721

-------
      WART»FLC*/AFLR
      T3*T2*.1»RA
      T4«T?*.4*RA
      T6«Tl-.l»RA
      COT=»WART«RA
      RDH2«1./(H(T4)-H1-.4«CC1)
      Rr>H3*l./(H
c
c
c
c
   CHARs(RA/4.)»2»2»370
 2   IF(IK-10)6,5,5
 6    GC TO (8,9)»(IK-7)
 7    XK(7)s.42626139*.30755494*RANGE".83222851E-o2*RANGr»*2+. 14
   GO TO ?5
 8   XK(8)=.53003286*.;
  X092005E-03*RANGE**3-.73568322E-06«RANGF»*4
   GO TO 25
 9   XK(9)s.27667o81*.27l25055»RANGF-.75042365E-o2*RANGF.»»2 + -12
  X884963E-03#RANGE*»3-.8002l9)tlOE-06»RANGE«*4
   GO TO 25
 5   AA*APPR/2.
   Z»0«
   lAsAA
   A8»IA
   IF(AB.EQ.AA)GC TO  (10,12»14,16,18»20),(AB-4. )
   GO TO <10»12tl*il6»iB)i(AB-4.)
21   Z»2.
   GO TO (12»14,16,18,20),(AB-4.)
10   XK(10)..87557520E-01*,25976379«RANGE-f69589515F-02»RANGE«»2
  X  «.11542869E-03«RANGE»«3-.69832755E-06«RANGE»*4
   IF(AB.EQ.AA)GC TO 25
   IF
-------
   1*   XK(16).-.433798Q5*.20785695»RANGE-f5lA72632E-02*RAMGF«#2            0(>7fl4
     X+,77o53656E-0**RANGE**3-.42ii9093E-06*RANGE«»4                        00785
      IF(AB.EQ,AA)GC TO 25                                                  00786
      IF(Z-2.)21»23»21                                                      00787
   18   XK(ift)»-.91434163*.238270o8«RANGE-.66floi246F:-02*KANGF*»2            007R8
     X*f10604073E-03*RANGE*»3-.6l338627E-06*RANGE»*4                        00789
      IF(AB.EQ.AA)GC TO 25                                                  00790
      IF(Z-2.)21»23»2l                                                      00791
   20   X(U20)a-.1225o402E*01*.25793956*RANGF_-,7655o59fr-02»pANfiE«<»2         00792
     X  *.12169709E-03*RANGE»*3-.70610963E-06*RANGE»*4                      00793
      IF(AB.EQ.AA)GO TO 25                                                  00794
      IF(Z-2»)21,23,21                                                      00795
   ?3   XK(IK)«(XK                                    00816
      TCTHP=HPFAN*HPPMP                                                     oosn
      DELFC»OELfrC*USEFAC                                                    00818
      CPCCS»(TOTHP«.7457/(PSIZE*1000.))«PWpST«USEFAC                        00819
      COSMAI=.001«CAPCOS/(PSIZE*1000.)+.1*CPCCS*.01»SYSCST                  00820
      TotCCS»(CAPCCS»ANFCR)/(PSlZE«1000t*CAPFAC«8.76) *CPCC<;                00821
     X *CCSMAi*SYsCST*DELFC                                                 00822
      IF(TcTccS-TcTCSi)154,156»156                                          00823
  156  IF(NSPCCN.EQ«1)GC TO 157                                             00824
      lF(NSYSCPtEQ.2)GC TO 151                                              OQ8?5
      APPRsAPPR*l.                                                          00826
      IF(APPR-20O50»50»151                                                 00827
  157  IF(NSYSCP.EQ»2)GC TC 190                                             00828
  151  TC«fC*l.                                                             00829
      IF(TC-tCMAX(NCAPS*l))100tl00.190                                      00830
  154  RAjf=RA                                                               00831
      CHAR^sCHAR                                                            00832
      PHTlsBHT .                                                             00833
      PLANAl«P|_ANA                                                          00834
      AELR1*AFLR                                                            00835
      DP1»DELP                                                              00836
      APPRla^PPR                                                            00837
      HWB1»H1                                                               00838
      SYSl-SYSCST                                                           00839
      CAPCSUCAPCCS                                                         00840
      CCSPgUcCSPKW                                                         00841
      OPCS1-CPCOS                                                           00842
      COSMA1«CCSMAI                                                         00843
      THPI«TQTHP                                                            00844
      HPFl-HPFAN                                                            00845
                                        90

-------
    QRJlsQREJ
    QRJTI«QREJ
    FLOVM.FLCW
FCRMAT(/3X,*FCR THE GIVEN CONDITIONS A SOLUTION CANNOT RE
          WART

    WEVAPUWEVAP
    WBDWNl*W9DWN
    WNEEDl»WNEED
    TCl*TC
    XKl-XB(IK)
    TOTCSl'TOTCCS
    G° TO 156
     IFTC,APPR,RA
     FC
   X FO
    SO TO 400
     CONTINUE
     WRlTEiIRlTEt2l2)
     FORMAT(*l*t l5X,^— — MECHANICAL DRAFT WET TOWEP ---- -*,//t 10
   XX.^THE DESIGN VALUES  AND COSTS  APE -*»//>
    CALL PRTDSI (QRJltTCl»HPFl»HpPl,WEVAPl»W8DWNl,AFLPl)
    WRITE d RITE > 227) DPI, FLCWI,RAI,APPRI
     FORMAT (3X»#PRESSURE  DROP =*tF5.2«*    CCND FLOW =*»E9.4,/,
   X 3X*RANGE »#»F4.0.*     APPROACH =^,F^.O)
    IF(N$YSOP-2)230»228,230
     WRITE(IRITE»229)QRJT1
     FCRMAT{/3X,*Q REJ TOWER «*,E9.4,* BTU/HR*)
     CALL PRTDS2(CAPCSl,CPCSl,CCSMAl,SYSi,DELFl,TOTCsl«CCSPKi)
    WRITE(IRITE,330)
     FCRMAT(//15X»^VARlABLF AMBIENT CONDI TIC
    IF(NTAMB.EQ.O)OC TO 400
    TOPMTL«0.0
190
195
196
200
210
212
227
22P
229
230

330
    DC 350 I*1»NCAPS
    IF(CAP(i) .EQ.O.JGC TO 350
    AMBCPC(I)«0.0
    AMBDFC(I)*0.0
    DO 340 J*1»NTAMB
    IF(PCTAMB(I,J).EQ.O.)GO TO
    TC«TCMIN(D
    NTCCD.=Q
     CALL oAFCST(ItTC,PwCST,DFCCD»OREJ)
    DT2* (ORE J/FLCWl ) / 
    DT1*DT2*QREJ/FLCW1
    Tl=Tc-DT2
    T2-TC-OT1
    IF(NSYSCP-2)3l6t303f316
     iF(f2-TAMWB(J))304t304,3o2
     IF(T2-TAMRV(J))304,305,306
     NTCOD.l
     T2-TDISMX               .
    IF(T?.GT.TAMWB(J))GC TO 3o2
    WRlTE(IRlTEt313)TAMWB(J)
     FCRMAT(3X*T DIS MAX LESS THAN(CP  «) T WB «^,F4.0»/»
   X 3X5
-------
307
308
304
T3»T2*.1»RA
T4=T2*«4»RA
T5«Tl-.4*RA
T6«Tl-.J.»RA
CCI=WARTI*RA
HirH(TAMWBU) )
H2=H(TAXT>
RDH1=1./(H-Hl-.4*CCl)
RDH3=1./(H(T5)-H2*.4*CC1>
PDH4=1./(H(T6)-H2*.1*CC1)
CHAR* 
-------
    SUBROUTINE SUBNDW
    COMMON PSIZE.CCPKW,ANFCR«FUcST.NcAPS,CAP(6> »TCTLn<5) .
   XMIN<6) ,PCMIN(6) ,TCMAX(6) »PCMAX(6) ,   HRCCF2(6) .HRcCFl (
   XTDB,TWB,3H,TAVH2C,TCBASE,   NTAMB,AMBOFC (5) »AMBOPr(5) ,
   XB(5) >AMBRH(5) »   TAMRV(5) »pCTAMB(5t5) ,NSYSCP»TDlSM* .NS
   XR£AC.SPFLOW»  NH2C»WlDTH«PRPAGR,cAPFAC»USEFAC«TKwHHS»
    PI-3.H159
    PMPEF-0.8
    TCTCS1-I.E3
    HDRMftXsl .5
                                                         COi.PCT(5) tTC
                                                                ,TAMW
                                                           TE» I RE AD
lOO
   TC«TCMIN(NCAPS*1)
    CONTINUE
    CALU PAFCST(NCAPS*i,Tc»PWCST,DELFC.OREJ)
   DT2«(QREJ/SPFLCW)/(EXP(UCVALL*AREAC/SPFLCW)-1 •)
41
4?
13

15
    T1=TC-DT2
    IF(NSYSCP-2)44,4l,..
     IF(nTi-(TC-TAVH2C))15.15,4?
     IF(TC-TCMAX(NCAPS*1))13.l9o,l90
     TC=TC*1
    flC TC 40
     T2*TDISMX
    APPR=T2-TWB
    IF(APPR.LT.7.)GC TC 190
    IF(APPR.GT.20»)GC TC 190
    RA«TT-T2
    lF(RAiLT.10.)GC TC 190
    GC TQ 46
     T2=TC-DT1
    APPR=T?-TWB
    IF(APPR.LT.7.)GC TC 151
    IF(APPR.GT.20.)GC  TC 190
    GO TO 45
     IF31»32.31
     APPR=7.
     T2=TWB*APPR
    IF(TC-T2)151,151,51
     T2«TQISMX
    APPR.T2-TWB
    IF(APPR.LT.7.)GC TC 190
    IFJAPPR.GT,20.)GC  TC
44
30
31
50

32

45
  «  CCSPKW)
   QREJT*QREJ

46 °CALL COND
  »  CCSPKW)
   OREjT«OREJ*(Tl-T2)/(Tl-TAVH2C)
47  RA-T1-T2
   IF(RA.LT.10.)GC TC  151
   WLCAD'1250.
       'INITIAL  WATER  LOADING   1250  LBM/FTZ/HR
   CONTINUE
   BSA-FLCW/WLCAD
   01A«SQRTF<4.»BSA/3.14159)
       TAXT - AIR EXIT TEMP -  FRAAS * CZlSIK
009^9
00960
00961
00962
009*1
00^64
00965
00966
00967
00968
00969
00970
00971
00972
00973
00974
00975
00976
00977
00978
00979
00980
009R1
009fi2
009R3
00984
00985
00986
00987
00988
00989
00990
00991
00992
00993
00994
00995
00996
009Q7
00998
00999
01000
                                                                         01002
                                                                         01003
                                                                         01004
                                                                         01005
                                                                         01006
                                                                         01007
                                                                         01008
                                                                         01009
                                                                         01010
                                                                         01011
                                                                         01012
                                                                         01013
                                                                         oiou
                                                                         01015
                                                                         01016
                                                                         01017
                                                                         01018
                                                                         01019
                                                                         01020

-------
c

c


c
c

c
c
c


c
r
   TAXT«!Tl»T2)/2.
   H1«H(TWP)
   HJ»«H(TAXT)
               OF  CHAR(TCTAL REQUIRED TC«ER CHARACTERISTIC)
      T3«T2*0.1*RA
      T4«T2*0.4*RA
      T5«Ti-0.4»RA
      T6«T1-0.1*RA
      CCT«WART»RA
      ROHi*l./(H(T3>-Hl-0.1»CCl)
      RpH2=l./(H(T4)-Hl-0.4«CCl)
      RDH3si./(H(T5>-H2*Ot4»CCl)
      RDH4sl./(H(f6)-H2*0.1»CCl)
                                                           S* CTI
              .
       UNC. •  CHAR/FT CF PACKING FROM LCwE  * CHRISTE
   UNC*0,1»(1./WART>**6.73
   PHT«CHAR/UNC
        WACT  - ACTUAL HUMIDITY
   WACT«RH»(0.622*P(T08) ) / (U.696-P (TDB» )
   APSAT*(WACT*1^.696)/(0.622*WACT)
             •  INLET  VELOCITY
        VHOI  -  INLET  VEL  HEAD
                               )/(53.35*(TAXT*460."
    CPHT««AELR/3600f)/(Pl»DlA»DIN»VIN)
          SPRAY  NOZZLES  ASSUMED  4  FT  ABOVE  PACKING
        PPX  -  DEL  P  OF PACKING  (VEL HEADS/FT)
        ASSUMED  LINEAR FUNCTION  CF WLOAD  -  SEE  LOWE  *
    PKWAa.5
            (PKWA*PKWB»WLCAD>
        PSP  -  DEL  P  OF SPRAY
    PSP»6.16»(OPHT*4.)«WART««i.32       .                   ti ,
        INLET  * EXIT TURNING LOSSES * FRICTION LOSS a TPIX VrL
    TPIX»2S.5
    TPDP«5PPKtPSP*TPIX
    HDP*THT/:DIA            _ .
    lF(H6R.LEtHD«MAX)QC TO 120
    WLOAD».9*WLCAD
    IWL«IWL*.l
    IFdWL.LE. 10)60 TO 48
120 HTDIA=THT»DIA
    CAPCCS=3.4E5*(HTDIA««.17)
       OLATaQREJ-AFLR».24* (T
       WEVAP«QLAT/970«3
       WBDWN« ( ,66»QREJ»62.4)
       WNEED*WEVAP*WBDWN
                          (500.»7.48* (CCNCR-1
    CPCCS« (HPPMP«.7457/ ?PSIZE*1000. ) ) *PWCST*USEFAC
    OELFC«OELFC«USEFAC     . ,                      „   ,
    COSMAI»,001»CAPCCS/JPSIZE«1000.)*,1*OPCCS*.01»SY5CST
    TCT|CCS* JCAPCOS»ftNFCR) / (PSIZE»1000.*CAPFAC*8.76)  *CPCCS
   X »COSMAI*SYSCST*DELFC
010P1
010^2
010P3
01024
01025
01026
01027
01028
01029
01030
01031
010^2
01033
01034
01035
01036
01037
01038
01039
01040
01041
01042
01043
01044
01045
01046
01047
01048
01049
01050
01052
01053
01054
01055
01056
01057
01058
01059
01060
01061
01062
01063
01064
01065
01066
01067
01068
01069
 01070
 01071
 01072
 01073
 01074
 01075
 01076
 01077
 01078
 01079
 01080
 01061
 01082
                                    91

-------
156
157
151

154
    IF (TCTCCS-TCTCSD 154*156i 156
     IF(NSPCON.EQ.1)6C TC 157
    lF(NSYSpP.EQ.2)GC TC 151
    APPR.APPR*!.
    IF(APPR.20.)50,50.151
     IF(NSYSCP.EQ»2)OS TC 190
     TC»IC*1.
    IF(TC-TCMAX(NCAPS+1) ) 100*100,190
     RAlgRA
    CHAB1-QHAR
    PHTl»PHT
    PPKl;PPK
    AFLR**AFLR
    APPRl»APPR
    HWBI-HI
    SYSl-SYSCST
    CAPCSl«CAPCCS
    COSPfcl*CCSPKW
    CCSMAl«CCSMAI
    HPFl»0.0
    HPP1.HPPMP
    DELF1«OELFC
    QRJlaQREJ
    QRJTl»OREJT
    FLCW1«FLCW
    GPMl.GPM
    WEVAPlaWEVAP
    WBDWNlrWBDWN
    WNEED1*WNEED
    DIAUDIA
    THTl»THT
    TAXTjsTAXT
    CPHTl-QPHT
    TPQP1»TPDP
    OPl«DELP
    TCTCSlaTCTCCS
    WLCADl«WLCAO
    GQ TO '56
190  IF(TCTCSl-ltE3)200*195*200
195  WRITE{IRITE»196>TC.APPR»RA
196  FCRMAT(/3X,    #FCR  THE  OIVF.N
                     ~    '     APPR
200

212
                                   CONDITIONS A
    GC TC
     CONTINUE

    WFcSMAT<5l*!?5?U
SOLUTION CANNOT  BE FOUN
RA **,F5.0)
               10X»*
                       • NATURAL DRAFT WET TOW£R -----1
                     v COSTS ARE -**//>
                     »HPF1,HPP1«WEVAPl»WBDWN1,AFLR1>
                     FLOW1,RA1*APPR1»THT1,DIA1,WLCAD1,CWAR1,PHT1
                      DROP -»»,F5.1,Jt    CCND FLOW «*,E9.4,/, 3X^
XRANGE M,F4.0t»«     APPROACH .*,F4,0,/.3X*TCWF.R HEIGHT •*•?*•<>'_ ^
X  *   TOWER DIAMETER MF5.0/*   WATER LOADING »"F7.0,* LBM/HR-FT?*
X/ I   T5WER CHARACTERISTIC .
-------
125

140
330
    IF(HORi,lE.HDRMAX)GC TO HO
    WRITE (I RITE, 125) HORl.HDRMAX
    FORMAT (*o  NOTE—
     * H/DMAX»*F5»2//)
                                 WHICH is GREATER
    WRITF(IRITE,330)
     FCRMAT(//15X»*VARIABLE
    IF»0,0
    DC 34Q Jal,NTAM8
    IF(PcTAMBU»J>.EQ.O.>f5C T
    TC«TCMIN(I)
    NTCCD*O
     CALU PAFCST(ItTCiPWCST.DFCCD»QREJ>
    DT2e(QREJ/FLCWl)/(EXP
    H2«H(TAXT)
    DOUTs<144t*(H.696-P(TAXT)
    AFLR»QREJ/
-------
    IF»TC                                   01208
312  FORMATt/8x,*FOR CAP «*,F
-------
 SUBRCUTIME PAFCST(I,TC,PWCST.DEt_FCtQREj)                             01229
 COMMON PSlZEtCCPKW,ANFCRiFUcST,NcAPS,CAP(6)tTcTLn(5) ,                01230
X CCLPCTJ5)»TCMIN<6)fPCMlN(6j«TCMAX(6)iPCMAX(6)»                      01231
X  HRCCF2(6)tHRCOFl(6),HRCCFO{6)»TOBfTWB,RHtTAVH2c»TCBASE,            01232
X  NTAMB,AMBbFC(5)»AMBCPC(5),TAMDB<5),TAMWB<5),AMflRH<5),              01233
X  TAMRV<5) tPCTAMB(5»5) «NSYSOP»TDlSMX,NSPCON»UCVA| U«ARE•^C,SPFLCW»     01234
X  NH2C,WIDTHtPRPAGR,CAPFAC.USEFAC»TKwHRStIRITF.tIPEAD                 01235
 HRBA«;E«HRCCF2(I)*TCBASE*»2*HRCCFl (I) *TCBASE*HRCCFO (I)                 01236
 HEATRaHRCCF2(I)*TC**2*HRCCFi(I)«TC*HPCCFo(I)                          01237
 QREJ*(HEATR-3*13.)«PSlZE*CAp(I)«1000.                                01238
 DELHR«HEATR-HRBASE_                                                  01239
 DELFC»FUCST«OELHR«i.E-5                                              01240
 PWCST»FUCST»HEATR*1.E-5»(CCPKW*ANFCR)/(CAPFAC»8.76)                  01241
 RETURN                                                               01242
 END                                                                  01243
                                     98

-------
c
c
10

15

20
?5
 SUgRsUTjNE CCND(TCCND,TIN,QREJ«PWCST,DT?,TOUT,UA,FLOW,*PM»
*  SYSCSTtCCSPKW)
 COMMON PSlZEtCCPKW,ANFCR»FUcST»NCAPS,CAP(6)»TCTLn(5),
X CCLPCT(5)»TCMIN(6),PCMlN<6),TCMAX(6)»PCMAX(6)•
X  HRCCF2(6).HRCCFl(6),HRCCFf)(6),TDB,TWB,RH,TAVH2o»TCBASE,
X  NTAMB«AMBDFC(5)*AMBOPC(5>,TAMDR(5),TAMWB(5),AMp«H(S),
X  TAMRV(5) ,PCTAMB(5,5) ,NSYSCP,TDlSMX,NSPCCN,UCVA|, L, AREftC,SPFuCW»
X  NH?C»WlDTH»PRPAGR,CAPFAC»USEFAC»TKwHRS,IRITr»lRE:AD
 PMPEF«,8
 IF(NSPCON.EQ.1)GC TO  30
      VARIATION  OF HEAT TRANSFER COEFFICIENT.  UALl» WITM TYPE
      OF WATER
 IF(NH20|20»10*15
   30
      GO TO
 GO TO 25
  UALL»256.
  CONTINUE
 DT1=TCONO-TIN
 TCUT=TCOND-DT2
 DELT.TOUT-TIN
       AU08  MEAN TEMPERATURE DIFFERENCE*  LMTO
 DTLGMa(OTl-pT2)/(ALCG(DTl/OT2) )
 ACOND»f5REJ/ (DTLGM«UALL)
 UA*UALL»ACOND
 CCNCST«26.»(ACCND*1,05)**.9
       65  PERCENT INCREASE |N_MATERIAL  COSTS  IF  SAuT WAT^W
 IF(NH2C.LT.6)CCNCSTsCCNCSf*1.65
 FLCWsOREJ/DELT
 GPM«FLOW/ (8.34*60.1
      ASSUME 35 FT OF  HEAD

 PMPCST^SPM»CHEAD*.7457*PWCST>'(3960.*PMPEF«PSIZF*1000.)
       1  DOLLAR PER GPM FOR COST OF PUMPS
 COSPKW»(CCNCST*1.*GPM)/(PSIZE*1.E3>
 SYSCST- (COSPKW*ANFCR) / (CApf AC«8.76)
 GO  TO 50
  UA*UCyALL*AREAC
 FLCW.SPFLCW
 GPMaFLOW/ (8.3A»60. )
 SYSCST»6.0
  RETURN
 END
01244
01245
01246
01247
01248
01249
01250
01251
01252
01253
01254
01255
01256
01257
01258
01259
01260
01261
01262
01263
01264
01265
01266
01267
01268
01269
01270
01271
01272
01273
01274
01275
01276
01277
01278
01279
01280
01281
01282
01283
01284
01285
01286
01287
                                          99

-------
   SUBROUTINE PRTDSl(QREj,TC,HPF»HPp,WEViWBO,AFLP)                      012R8
   COMMON PSIZE»CCPKWtANFCR»FUcST»NCAPS»CAP(6)»TCTLn<5> t CCl_pCT (5) «TC   01289
  XMIN(*),PCMIN(6),TCMAX(6) »PCMAX(6),  HRCCF2 (6) ,HRcCFl tf ) ,HRCCFO(6)»   01290
  XTDR,TWB,RH,TAVH2C,TCBASE.  NTAMB.AMBDFC (5) * AMftCPc (5> ,T*MnB (5) ,TAMW   01291
  XB(5> »AMBRH(5) .  TAMRV(5) »PCTAMB(?»5) ,MSYSCP»TDlSMX,NSPrCNtUCVALL. A   01292
  XRE/VC»SPFLCWt  NH2C« WIDTH »PRPAGR,cAPFAC»USEFAC»TKwHRS, I«ITEt I READ     01293
   WEVCFS.WEV/244700.                                                   01294
                                                                        01295
   WRITE (IR1TE, 10) QREj,Tc.HPFtHPPtWF.VCFS«WEV,WBDCFS,w80.AFLU            01296
10  FCRMAT(/»3Xt*Q REJECT a^,E9.4t* BTU/Hp  AT T CCMDENSF^ .*, F5.0     01297
  X./»3X»*FAN POWER »^,E9.4»^ HP     PUMP POWER s*tF9.4t< HP*,/, 3X,<   01298
  »H20 EVAP «*,E9.4»* C^S (*tE9.4»# LB/HR)*/                            01299
  »  *   H20 SLOWDOWN «^,E9.4t* CFS <*,F9.4,* LB/HR)*/                  nisoo
  •  *   AIR FLOW RATE «*tE9.4,* LB/HR*)                                 01301
   RFTURN                                                               01302
   END                                                                  01303
                                   100

-------
   SUBROUTINE PRTDS2(CAPCCStCPCOS.CCSMA!tSYSCCS.DELrCiTOTCCS»CCSPKW)     01304
   COMMON PSIZE»CCPKWiANFCR»FUCST»NCAPS,CAP(6>»TCTLn<5>.  CCLPCT(5>»TC   01305
  XMIN<6)»PCMIN<6)tTCMAX<6)»PCMAX(ft)»  HRCCF2(6)iHRcCFl(MiHPCCFO(6),   01306
  XTDR.TWBtRH»TAVH2C»TCBASEt  NTAMB,AMBDFC(5)»AMBCPc<5),TAMnB(5),TAMW   01307
  XB(«5) ^AMQRH(5) »  TAMRV(5) »PCTAMB(5»5) ,NSYSOPiTDlSMA iNSPCOMtUCVALL, A   01308
  XREAC.SPFLOW,  NH20fWlDTHfPRPAQR,CAPFACfUSEFAC,TKwHRS,I"lTE,lREAD     01309
   WRITE (JRlTEt 10)  CAPCCSiCCSPKW,CPcCStCSSMAI»SYSCC«5tDELFr.»TCTCCS       01310
10 FORMAT (^o  CAPITAL COST «^,E;q.4,^ DCLLAPS*/*   CcMDENSpR AND PUMP     01311
  •COST «*jE9.4»* OCLLARS/KW^/jt   OPERATING COST **,                    01312
  x       F6.3.# MILLS/KW-HR*./. sx,^MAINTENANCE COST »*,F6.3.^ MILLS   oisn
  X/KW-HR*t/t 3X»*CCNDENSEP SYSTEM  COST «*,F6.3i* MiLLS/Kw-H^"*/* 3Xt   01314
  X^DIFFERENTIAL FUEL COST MtFf,.3,* MlLLS/KW-HR^»//« 3X,^  TOTAL SYS   01315
  XT£M COST «*,F6»3»* MILLS/KW-HR*/)                                    0131&
   RETURN                                                               om/
   END                                                                  01318
                                     101

-------
   SUBROUTINE PRTCD                     „ O,.T
   COMMON PSIZE»CCPKW,ANFCRtFUcST»NcAPS,CAP<6>tTCTLn<5». CC|_PC
  XMIim) ,PCMIN(6) ,TCMAX<6) ,PCMAX .HRcCFl (*) »HRCw
  XTDB«TWB,*H,TAVH2C,TCBASE»  NtAMB.AMBDFC(5).AMBCPc<5),TAM08(5),TAMW    01322
  XB<5> .AMBRH(5)»  TAMRV (5) »PCf AMB (5»5) , NSVSCPtTDlSMX,NSPrOMi UwVALLt A
  XREAC.SPFUCW,  NH20,WIDTH.PRPAQR»cAPFACfUSEFAC.TKwHRS,!»ITE»IPEAD
   WRITE(IRITE,IO) CPCCD,OFCCD,TCCD                                        ,,
10  FCRMAT (/5X,*WITH THE VARIOUS AMBIENT TEMPERATURFi>*»/,                01326
  X 5X,*THE COSTS ARE -*t//»                                             n\
  X 3X,#CPERATING COST «*.F6,3,* MILLS/KW-HR*,/,                         01
  X 3Xi*OIFFERENTlAL FUEL COST «*.Fft,3,^ MILLS/KW-Ho*t/t
  X /»3X.*TCTA|_ SYSTEM COST »",F6.3»* MiL|_S/KW-HR*>
   RETURN
   EMD
                                       102

-------
         H


-------
FUNCTI!
                                                                     Qi339


                                                                     01340
                                                                     01341

                                                                     01342
                                  104

-------
DATA SUBD1
200
100
5150
80
3
150
350
150
7987
100
7974
100
S055
100
8828
100
0
150
8000
85
70
60
60
10
4000
25
30
40
50
00
2000
1
150
80
1750
70
3
100
400
250
8037
200
8Q25
200
8195
200
9381
200
0
200
8009
75
80
70
65
10
4000
25
30
30
25
00
2

.12
60
800
50
4
100
400
350
8153
300
8174
300
8430
300
9815
300
0
250
8042
75
85
70
70
10
4000
50
40
30
25
100
1
1
10
25
700
30
3
100
450
1000
0
360
15
3
100
450
                          5
                         150
                         350
    350
   8543
    300
   8089
    1.5
 350
8151
  10
  4000
-1
     85
      1
 350
   1
2.76E5
       105

-------
DATA  SUBD2
200
100
5150
80
3
150
350
150
7987
100
7974
100
8055
100
8828
100
0
150
8000
85
70
60
60
10
4000
25
30
40
50
00
2000
1
150
80
1750
70
3
100
400
250
8037
200
8Q25
200
8195
200
9381
200
0
200
8009
75
80
70
65
10
4000
25
30
30
?5
00
0
1
.12
60
800
50
4
100
400
350
8153
300
8174
300
8430
300
9815
300
0
250
8042
75
85
70
70
10
4000
50
40
30
25
100
1
1
        10
        25
       700
        30
         3
       100
       450
      350
     8543
      300
     8089
      1.5
1000
   0
 360
  15
   3
 100
 450
   5
 150
 350
 350
8151
  10
4000
                350
                  1
        2-76E5
           106

-------
DATA SUBD3
200
100
5150
ao
3
150
350
150
7987
100
7974
100
8055
100
8828
100
0
150
ROOO
85
70
60
60
10
4000
25
30
40
50
00
2000
1
150
flO
1750
70
3
100
400
250
8037
200
8025
200
8195
200
9381
200
0
200
8009
75
80
70
65
10
4000
25
30
30
25
00
2

.12
60
800
50
4
100
400
350
8153
300
8174
300
8430
300
9815
300
0
250
8042
75
85
70
70
10
4000
50
40
30
25
100
0
1
   10
   25
  700
   30
    3
  100
  450
  350
 8543
  300
 8089
  1.5
5000
   0
 360
  15
   3
 100
 450
   5
 150
 350
 350
8151
  10
4000
   85
    1
       107

-------
DATA SUBD4
200
100
5150
80
3
150
350
150
7987
100
7974
100
8055
100
8828
100
0
150
8000
85
70
60
60
10
4000
25
30
40
50
00
2000
1
150
80
1750
70
3
100
400
250
8037
200
8025
200
8195
200
9381
200
0
200
8009
75
80
70
65
10
4QOO
25
30
30
25
00
0
1
.12
60
800
50
4
100
400
350
8153
300
8174
300
8430
300
9815
300
0
250
8042
75
85
70
70
10
4QOO
50
40
30
25
100
0
1
       10      5000         5
       25         0
      700       360
       30        15
        335
      100       100       150
      450       450       350
      350
     8543
      300       350
      o«9      8151
      1.5        10      4000
       108

-------
     Accession Number
                            Subject Fie/d & Group
                               05E
SELECTED  WATER RESOURCES ABSTRACTS
       INPUT TRANSACTION  FORM
     Organization
     Dynatech R/D Company
  6  Tl
                           "A Survey  of Alternate Methods for Cooling Condenser Discharge
                              Water-- System Selection, Design, and Optimization"
10

22

Authors)
Smith, N.
Maulbetsch, John S.
16

21

Project Designation
FWQA Contract 12-14-477 Project # 16130 DHS
Note
Citation
Water Pollution Control Research Series isiao DHS 01/71
 23
     Descriptors (Starred First)
     *Power - electric; *Cost  analysis;  Condensers; *Heat exchangers; *Water cooling;
     Thermal power; economics
 25
     Identifiers (Starred First)
 27  Abstract
	A computer program  is described  for calculation of both cooling system and power plant
cost and the determination of the  minimum total  cost for a given set of parameters.  To
this end the effect of various design parameters have been studied to determine which have
significant effects on the performance of the various cooling schemes and which are
important to power plant casts.  Design equations based on these parameters are incorporated
into a computer program through which the minimum total cost is calculated.

This report was submitted in fulfillment of Contract No. 12-14-477 under the sponsorship
of the Federal  Water Quality Administration.  (Rainwater - EPA/WQO)
Abstractor r
f 1C
WR: 102 (REV
WRSI C
nk H
JULY
. Rainwater
Institution
EPA/WOO/National
1 969)
Thermal Pollution Research Program
SEND TO' WATER RESOURCES SC 1 E N T i~FYc INFORMATION
U S. DEPARTMENT OF THE INTERIOR
WASHINGTON. D. C 20240

CENTER
                                                                               * GPO: 1969-359-339

-------