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)
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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.
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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
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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
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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
-------
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
-------
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
-------
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
00022
00023
00024
00025
00026
00027
00028
00029
00030
00031
00032
00033
00034
00035
00036
00037
00038
00039
00040
000*1
00042
00043
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
00129
00130
00131
00132
00133
001"H
00135
00136
00138
00139
00140
OOU1
00142
00143
00144
00145
00146
00147
0014B
00149
00150
001S1
00152
78
00154
00155
00156
00157
00158
00159
00160
00161
00162
00163
00164
00165
00166
00167
00168
00169
00170
00171
00172
00173
00174
00175
00176
00177
00178
00179
00180
00181
00182
00183
00184
00185
00186
-------
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
00190
00191
00192
00193
00194
00195
00196
00197
00199
00199
00200
00201
00202
00203
00204
00205
00206
00207
00208
00209
00210
00211
00212
00213
00214
00215
00216
0021 7
00218
00219
00220
00221
00222
00223
002P4
00225
0022&
00227
00228
00229
00230
00231
00232
00233
00234
00235
00236
00237
00238
00239
00240
00241
00242
00243
00244
00245
00246
00247
00248
-------
»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
00315
00316
00317
00318
00319
003?0
00321
00322
003?3
00324
00325
00326
00327
00328
00329
00330
00331
00332
00333
00334
00335
00336
00337
00338
00339
00340
00342
00343
00344
00345
00346
00347
00348
00349
00350
00351
00352
00353
00354
00355
00356
00357
00358
00359
00360
00361
00362
00363
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
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