Text

Application to Amend License DPR-67 by Upgrading Rated Power from 2,560 MW to 2,700 Mw.Forwards Proposed Tech Spec Changes & Supporting Matl
	ML17266A362
Person / Time
Site:	Saint Lucie
Issue date:	11/14/1980
From:	Robert E. Uhrig; Florida Power & Light Co
To:	Eisenhut D; Office of Nuclear Reactor Regulation
Shared Package
ML17266A363	List: ML17266A362; ML19351D860;
References
	L-80-381, NUDOCS 8011200255
	Download: ML17266A362 (827)
	v • d • e

P.O. BOX 529100 MIAMI,F L 33152 6

FLORIDA POWER & LIGHT COMPANY Office of Nuclear Reactor Regulation Attention: ttr. Darrell G..Eisenhut, Director Division of Licensing U. S. Nuclear Regulatory Commission washington, D. C. 20555

Dear Nr. Eisenhut:

Re: St. Lucie Unit 1 Docket No. 50-335 Proposed Amendment to Facilit 0 eratin License DPR-67 In accordance with 10 CFR 50.30, Florida Power 8 Light Company submits herewith three (3) signed originals and forty (40) copie of a request to amend Facility Operating License DPR-67 by upgrading rated power from 2560 tlwt to 2700 that.

The proposed changes are shown on the accompanying Operating License and Technical Specification pag s bearing the date of this letter in the lower right hind corner. The Operating License change is Attachment 1, the Technical Specification changes are AttachIIIent 2, the supporting analysis is Attachment 3, and the Stretch Power Environmental Report is Attachment 4.

The proposed amendment has been reviewed by the St. Lucie Facility Review Group and the Florida Power 5 Light Company Nuclear Review Board. They have concluded that it does not involve an unreviewed safety question.

FPL has determined that this is a Class II Amendment in accordance with 10 CFR 170.22. A check in the amount of S12,300 is enclosed.

Very truly yours,

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,.;~ ~cgy S8+

j(2.00 g.bS Robert E. Uhrig ;,'~g~ Qf QQQllNQA~

Vice President lI-jgI >>QP] t'I9CKH $ P E Advanced Systems 8 Technology REU/HAS/ah Attachments (4) cc: J. P. O'Reilly, Region II Harold F. Reis, Esquire PEOPLE... SERVING PEOPLE

STATE OF FLORlDA )

) ss.

COUNTY OF DADE )

Robert E. Uhrig, being first. duly sworn, deposes and says:

That. he is a Vice President of Florida Power 6 Light Company, the Licensee herein; That he has executed the foregoing document; that the state-ments made in this said document are true and correct to the best of his knowledge, information, and belief, and that he is authorized to execute the document on behalf of said Licensee.'obert E. Uhrig 1~

I c

~ > )

Subscribed and sworn to before me this

~laay oS lead NOTARY PUBL , in and for the county of Dade,,

State of Florida Ny commission expires:

O P

DPR-67 PAGE 3 C. This license shall be deemed to contain and is subject to the conditions specified in the following Commission regulations in 10 CFR Chapter I: Part 20, Sections 30.34 of Part 30, Section 40.41 of Part 40, Section 50.54 and 50.59 of Part 50, and Section 70.32 of Part 70; and is subject to all applicable provisions of the Act and to the rules, regulations, and orders of the Commission now or hereafter in effect; and is subject to the additional conditions specified or incorporated below; (1) Maximum Power Level The licensee is authorized to operate the facility at steady state reactor core power levels not in excess of 2700 megawatts (thermal), provided that the construction items, preoperational tests, startup tests, and other items identified in Enclosure 1 to this license have been completed as specified in Enclosure 1- Enclosure 1 is an integral part of, and is hereby incorporated in this license.

(2) Technical S ecifications The Technical Specifications contained in Appendices A and 8, as revised through Amendment No. 35 are hereby incorporated in the license. The licensee shall operate the facility in accordance with the Technical Specifications-(3) Fire Protection The licensee may proceed with and is required to provide a schedule for and to complete the modifications and evaluations identified in Paragraphs 3.1 through 3.15 of the NRC's Fire Protection Safety Evaluation, dated August 17, 1979 for the facility. If any modifications or evaluation cannot be completed on schedule the'icensee shall submit a report explaining the circumstances together with a revised schedule.

The licensee is required to implement the administrative controls identified in Section 6 of the Safety Evaluation. The administrative controls shallbe in effect within 90 days from the date of issuance of this amendment.

D- The licensee shall maintain in effect and fully implement all provisions of the Commission-approved physical security plan, including amendments and changes made pursuant to the authority of 10 CFR 50.54(p) ~ The approved security plan consists of documents withheld frcm public disclosure pursuant to 10 CFR 2.790(d), referred to as the St. Lucie Unit I Security Plan dated October- 18, 1978, with Revision No. I dated February 20, 1979.

ATTACHMENT 2 Re: St. Lucie Unit 1 Docket No. 50-335 Stretch Power TECHNICAL SPECIf ICATION CHANGES soli S00 g~'~g

FLORIDA POWER 8, LIGHT CONPANY ST, LUCIE UNIT 1 STRETCH POWER APPLICATION AND ENVIRONMENTAL REPORT

ATTACHMENT l Re: St. Lucie Unit l Docket No. 50-335 Stretch Power Paragraph Z.C.(l) of Operating License DPR-67 is revised as shown on the next page.

TABLE 1 St. Lucie Unit 1 - Stretch Power Technical S ecification and Bases Chan es

~Pa e S ecification ~Chan e Remarks 1.3 Change rated thermal power from 2560 Hwt to 2700 hat.

2-2 Figure 2.1-1 Replace this figure with a The Thermal Limit Lines have been changed to revised figure. reflect 2700 f4t full power operation.

2-4 Table 2.2-1 Change the "steam generator The "steam generator pressure-low" setpoint is pressure-low" setpoint from being increased to minimize the consequences of

>500 psia to >600 psia. a Steam Line Break event.

2-5 Table 2.2-1 Add a "steam generator pressure A trip for Asyaeetric Steam Generator pressure difference-high" setpoint. has been added to minimize the consequences of the Loss of Load to One Steam Generator event.

2-5 Table 2.2-1 Change the "steam generator The "steam generator pressure-low" trip 'bypass pressure-low" trip bypass from has been increased to be consistent with the 585 psig to 685 psia. new trip value.

2-7 Figure 2.2-2 Replace thi s fi gure wi th a The LPD LSSS is being changed to reflect operation revised figure. at 2700 %t with higher radial peaking factors.

These limits were generated using a fuel centerline melt limit of 21.7 kw/ft.

2-8 Figure 2.2-3 Replace this figure with a The TH/LP LSSS is being changed to reflect opera-revised figure. tion at 2700 l4vt with higher radial peaking factors.

11-14-80

TABLE 1 continued

~pa e S ecification ~Chan e Remarks 2-9 Figure 2.2-4 Replace this figure with a The TH/LP LSSS is being changed to reflect opera-revised figure. tion at 2700 Hwt with higher radial peaking factors.

82-1,82-3 82.1, 82. 2 Change the "H-3 DNB correlation" The DNB correlation used in the Cycle 4 analysis 82-5,82-7 to "CE-1 DNB correlation", and is the CE-1 correlation and the minimum DNBR has change the minimum DNBR value been reduced to 1.23.

from 1.30 to 1.23.

82-4 82.2.1 Editorial change for clari fi-cation.

82-5 82.2.1 Change "steam generator The basis of the "steam generator pressure-low" pressure-low" setpoint from trip setpoint has been changed to be consistent 500 psia to 600 psia. with Table 2,2-1.

82-7,82-8 82.2.1 Add a function description for the asynmetric steam generator transient protective trip.

82-7 82.2.1 Revise the Ttt/LP Trip descrip- The TM/LP Trip description has been revised to tion. (

reflect the change in methodology from COSMO/H-3 to statistical TORC/CE-1 and the CEAM recategori-zation.

3/4 1-1 3/4.1.1.1 Change the Shutdown Hargin The shutdown margin has been increased to yield for T-avg >200 F from acceptable consequences from a Steam Line Break 3.3@k/k to 4.30k/k, event due to the mon. negative NTC allowed in Cycle I

ll-l4-80

TABLE 1 continued

~P ey IfI ~Chan e Remarks 3/4 1-3 3/4.1,1.2 Change the Shutdown Margin The shutdown margin has been increased to lengthen for T-avg below 200 F from the operator action time required in a boron dilu-1.0&k/k to 2.0%ok/k. tion event.

3/4 1-5 3.1.1.4 Change the NTC 1 imi t to The most negative MTC permitted for Cycle 4 "less ne~ative )han has been made more negative for longer cycle

-2.5X10 hk/k/ F." lengths.

3/4 1-10 3.1.2.2 Change the Shtudown Margin The required shutdown margin has been increased equivalent at 200 F to at to be consistent with Specification 3/4.1.1.2.

least 2@k/k.

3j'4 1-18 3.1.2.8 Change the Shutdown Margin The required shutdown margin has been increased equivalent to at least 2@k/k to be consistent with Specification 3/4.1.1.2.

3/4 1-30 Figure Replace this figure with a The PDIL is being changed Ln be consistent, wi Lh 3.1-2.'/4 revised figurp. the new LPD and TH/LP LSSS.

2-3 Figure 3.2-1 Change the allowable peak Increase the allowable peak linear heat rate to linear heat rate from 14e68 15.0 kw/ft to be consistent with the KCCS analysis kw/ft- to 15.0 kw/ft. value.

11-14-80

TABLE 1 continued

~pa e S ecification ~Chan e Remarks 3/4 2-4 Figure 3.2-2 Replace this figure with a The kw/ft LCO is changed to reflect the new LOCA revised figure. limit of 15.0 kw/ft and the higher radial peaking factors.

3/4 2-5 Figure 4.2-1 Replace this figure with a The incore monitoring system augmentation factors revised figure. have been increased due to the higher enrichment fuel and uncertainty in the power distributions of future cycles.

3/4 2-6 3.2.2 Change th~ maximum calcu- The curves of Fr and Fxy vs. power are being lated Fxy from 1.627 to 1.70. changed to reflect operation at 2700 Hwt with higher radial peaking factors, new LPD LSSS, new TH/LP LSSS, new DNB LCO, and new LHR LCO.

3/4 2-8 Figure 3.2-3 Replace this figure with a Same remarks as for the preceding entry..

revised figure.

3/4 2-9 3.2.3 Change the maximum calcu- Same remarks as for the preceding entry.

lated FrT from 1.64 to 1.70.

3/4 2-14 Table 3.2-1 Change maximum cold leg The cold leg temperature has been increased for temperature to 549 F. Cycle 4 stretch power operation.

3/4 2-15 Figure 3.2-4 Replace this figure with a The DNB LCO is being changed to reflect operation revised figure. at 2700 Hwt with a 549 F inlet temperature and higher radial peaking factors.

3/4 3-2 Table 3.3-1 Add "steam generator pressure The asyranetric steam generator pressure trip has difference-high" description been added to the Table.

to Table.

11-14-80

TABLE 1 continued Change Remarks 3/4 3-4 Table 3.3-1 Change the "steam generator The "steam generator pressure-low" trip bypass has pressure-low" trip bypass from been increased to be consistent with the new trip 585 psig to 685 psia. value.

3/4 3-6 Table 3.3-2 Add "steam generator pressure The asyametr ic steam generator pressure trip difference-high" response time. has been added to the Table.

3/4 3-7 Table 4.3-1 Add "steam generator pressure The asymmetric steam generator pressure trip difference-high" surveillance. has been added to the Table.

3/4 3-'l2 Table 3.3-3 Change the "steam generator The trip bypass has been increased to be consistent pressure-low" trip bypass for with the new trip value.

the Hain Steam Line Isolation function from 585 psig to 685 psia.

3/4 3-14 Table 3.3-4 Change the "steam generator The ESF setpoint has been increased to be consistent pressure-low" setpoint for the with the reactor trip setpoint.

Hain Steam Line Isolation function to 600 psia.

3/4 4-1 3.4.1 Replace the entire page. The shutdown margin requirement has been increased to yield acceptable consequences for a Steam Line Break event during one-loop operation due to the more negative NTC permitted during Cycle 4. Nodes 4 and 5 shutdown margin has been increased to 4.3$ ak/k.

11-14-80

'TABLE 1 continued

~Pa e S ecification ~Chan e Remarks 83/4 1-1 83/4.1.1.1 Change minimum Shutdown Hargin The shutdown margins in the Bases have been 83/4.1.1.2 from 3.3%ok/k to 4.3%hk/k, and increased to be consistent with Spec'ifications from 1.0$ hk/k to 2.0Xhk/k. 3.1.1.1 and 3.1.1.2.

-4 oF.

83/4 l-l 83/4.1.1.4 Change NTC to -2.5X10 ak/k/ ; The most negative NTC permitted has .been changed in the Bases to be consistent the Specification 3.1 .1.4.

83/4 1-2 83/4.1.1.4 Change shutdown margin to The shutdown margin has been increased in the 2.0CAk/k after xenon decay Bases to be consistent with Specification 3.1.1.2.

and cooldown to 200 F.

83/4 2-2 83/4.2.5 Change minimum DNHR to 1.23. The minimum DHBR has been decreased to bq consistent with Specification 82.1.

83/4 4-1 83/4.4.1 Change minimum Dt/BR to 1.23. Spme remarks as for preceding entry.

I 83/4 7-1 83/4.7.1.1 Steam flows are revised to 83/4 7-2 reflect '2700 bQt.

s ( i 11-14-80

1.0 DEFINITIONS DEF INED TERMS 1.1 The DEFINED TERMS of this section appear in capitalized type and are applicable throughout these Technical Specifications.

THERMAL POWER 1.2 THERMAL POWER shall be the total reactor core heat transfer rate to the reactor coolant.

RATED TERMAL POWER 1.3 RATED THERMAL POWER shall be a total reactor core heat transfer rate to the reactor coolant of 2700 MWt.

OPERATIONAL MODE 1.4 An OPERATIONAL MODE shall correspond to any one inclusive combination of core reactivity condition, power level and average reactor coolant temperature specified in Table 1.1.

ACTION 1.5 ACTION shall be those additional requirements specified as corollary statements to each principle specification and shall be part of the specifications.

OPERABLE - OPERABILITY 1'.6 A system, subsystem, train, component or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified function(s).

Implicit in this definition shall be the assumption that all necessary attendant instrumentation, controls,'lectric power, cool'ing or seal water,

'lubrication or other auxiliary equipment that are required for the system, subsystem,, train, component or device to perform its function(s) are also capable of performing their related support function(s).

REPORTABLE OCCURRENCE 1.7 A REPORTABLE OCCURRENCE shall be any of those conditions specified in Specifications 6.9.1.8 and 6.9.1 ST. LUCIE - UNIT 1 11-14-80

600 UNACCEPTABLE OPERATION 580 REACTOR OPERATION LIMITED TO LESS THAN 500 F BY ACTUATION OF THE UNACCEPTABLE MAIN STEAM LINE SAFETY VALVES. OPERATION 560 VESSEL FLOW LESS MEASUREMENT UNCERTAINTIES 370,000 GPM FOR PRE-CLAD COLLAPSE OPERATION ONLY O

) 540 LIMITS CONTAIN NO ALLOWANCE l OO O

FOR INSTRUMENT ERROR OR I FLUCTUATIONS "8 Ig VALID FOR AXIAL SHAPES AND

~ 520 INTEGRATED ROD RADIAL PEAKING FACTORS LESS THAN OR EQUAL TO I

O W A THOSE ON FIGURE B 2.1-1

~ xg O O I O l~

500 H o4 5 ACCEPTABLE I OPERATION lQ OR iPg I R 480 115~.

460

!f 0 0.20 0.40 0.60 0.80 1. 00 1.20 1.40 1.60 1. 80 FRACTION OF RATED THEIQfAL POWER Figure 2.1-1 REACTOR CORE THERMAL MARGIN SAFETY LIMIT FOUR REACTOR COOLING PUMPS OPERATING

TABLE 2.2-l REACTOR PROTECTIVE INSTRUMENTATION TRIP SET POINT LIMITS FUNCTIONAL UNIT TRIP SET POINT ALLOWABLE VALUES

1. Manual Reactor Trip Not Applicable Not Applicable

2. Power Level - High (1)

Four Reactor Coolant Pumps < 9.61$ above THERMAL POWER, < 9. 614 above THERMAL POWER, Operating with a minimum set-point of 15$ and a minimum setpoint of 15$ of RATED of RATED THERMAL POWER, and a THERMAL POWER and a maximum of maximum of < 107.0$ of RATED < 107.0X of RATED THERMAL POWER THERMAL POWER.

3. Reactor Coolant Flow-Low (1)

Four Reactor Coolant Pumps > 95K of design reactor coolant > 95K of design reactor coolant Operating flow with 4 pumps operating* flow with 4 pumps operating*

4. Pressurizer Pressure-High < 2400 psia < 2400 psia

5. Containment Pressure-High < 3.3 psig < 3.3 psig

6. Steam Generator Pressure- > 600 psia > 600 psia Low (2)

7. Steam -Generator Water Level- > 37.0$ Water Level - each . > 37.0$ Water Level - each steam steam generator

'. generator Low Local Power Density - High Trip setpoint adjusted to not Trip setpoint adjusted to not (3) exceed the limit lines of exceed the limit lines of Figures 2.2-1 and 2.2-2 Figures 2.2-1 and 2.2-2.

~ Design reactor coolant flow with 4 pumps operating is 370,000 gpm.

.TABLE 2. 2-1 CONTINUED REACTOR PROTECTIVE INSTRUMENTATION TRIP SETPOINT LIMITS FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES I

n 9. Thermal Margi n/Low m Pressure (1)

Four Reactor Coolant Pumps Trip setpoint adjusted to not Trip setpoint adjusted to not Operating exceed the limit lines of exceed the limit lines of Figures 2.2-3 and 2.2-4. Figures 2.2-3 and 2.2-4.

9a. Steam Generator Pressure < 135 psid < 135 psid Difference-High (1)

(Logic in TM/LP)

10. Loss of Turbine--Hydraulic > 800 psig > 800 psig Fluid Pressure - Low (3)

11. Rate of Change of Power- < 2.49 decades per minutes < 2.49 decades per minuts High (4)

TABLE NOTATION (1) Trip may be bypassed below 1$ of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER is > 1'X of RATED THERMAL POWER.

(2) Trip may be manually bypassed below 685 psia; bypass shall be automatically removed at or above 685 psia.

(3) Trip may be bypassed below 15$ of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER is > 15K of RATED THERMAL POWER.

(4) Trip may be bypassed below 10 "X and above 15$ of RATED THERMAL POWER.

I CO C)

1~4 1.2 UNACCEPTABLE (0.0, 1.17) UNACCEPTABLE OPERATION OPERATION 1.0 (-.145, 1.0) (0.2, 1.0) 0.8 QRZ (-0;4, 0 70) (0.4,0..70) 0.6 ACCEPTABLE OPERATION 0.4 0.2 0.0

-0.6 -0.4 -0.2 0.0 0.2 0.4 0.6 AXIAL SHAPE INDEX, Yl FIGURE 2.2-2 Local Power Density-High Trip Setpoint Part 2(QR2 Versus Yl)

ST. LUCIE UNIT 1 2-7 11-14-80

1 5 Al FUNCTION 1.4 POLAR 2061 'l ~

QRl + 15.85 TIN 8950 1.3 1.2 1.0

-0.6 -0.5 -0.4 -0.3 -0.2 -0.1 0.0 0.1 0.2 0.3 0.4 0.5 0.6 AXIAL SHAPE INDEX, Yl FIGURE 2.2-3 Thermal Margin/Lov Pressure Trip Setpoint ST. LUCIE - UNIT 1 2-8 11-14-80

0 PVAR

~ 2061 Al ~

QRl + 15,85 TIN 8950 QRl FUNCTION 1.2 e 1.0

(.972,.972)

(.781, .863) 0.8 QR1 0.6 0.4 (0, .235}

0.2 0.2 0.4 0.6 0.8 1.0 1.2 FRACTION OF RATED THERMAL POWER FIGURE 2.2-4 Thermal Margin/Low Pressure Trip Setpoint Part 2 (Fraction of RATED THERMAL POWER Versus QRy)

ST. LUCIE - UNIT 1 2-9 11-14-80

2.1 SAFETY LIMITS BASES 2.1.1 REACTOR CORE The restrictions of this safety limit prevent overheating of the fuel cladding and possible cladding perforation which would result in the release of fission products to the reactor coolant. Overheating of the fuel is prevented by maintaining the steady state peak linear heat rate below the level at which centerline fuel melting will occur. Overheating of the fuel cladding is prevented by restricting fuel operation to within the nucleate boiling regime where the heat transfer coefficient is large and the cladding surface temperature is slightly above the coolant saturation temperature.

Operation above the upper boundary of the nucleate boiling regime could result in excessive cladding temperatures because of the onset of departure from nucleate boiling (DNB) and the resultant sharp reduction in heat transfer coefficient. DNB is not a directly measurable parameter during operation and therefore THERMAL POWER and Reactor Coolant Temperature and Pressure have been related to DNB through the CE-I correlation. The CE-I DNB correlation has been developed to predict the DNB flux and the location of DNB for axially uniform and non-uniform heat flux distributions. The local DNB heat flux ratio, DNBR, defined as the ratio of the heat flux that would cause DNB at a particular core location to the local heat flux, is indicative of the margin to DNB.

The minumum value of the DNBR during steady state operation, normal operational transients, and anticipated transients is limited to 1.23. This value corresponds to a 95 percent probability at a 95 percent confidence level that DNB will not occur and is chosen as an appropriate margin to DNB for all operating conditions.

The curves of Figure 2. 1-1 show the loci of points of THERMAL POWER, Reactor Coolant System pressure and maximum cold leg temperature with four

'eactor Coolant Pumps operating for which the minimum DNBR is no less than 1.23 for the family of axial shapes and corresponding radial peaks shown in Figure B 2.1-1. The limits in Figure 2.1-1 were calculated for reactor coolant inlet temperatures less than or equal to 580'F. The dashed line at 580'F coolant inlet temperature is not a safety limit; however, operation above 580'F is not possible because of the actuation of the main steam line safety valves which limit the maximum value of reactor inlet temperature.

Reactor operation at THERMAL POWER levels higher than 112% of RATED THERMAL POWER is prohibited by the high power level trip setpoint specified in Table 2.1-1. The area of safe operation is below and to the left of these lines.

ST. LUCIE - UNIT 1 B 2-1 11-14-80

SAFETY LIMITS BASES The conditions for the Thermal Margin Safety Limit curves in Figure 2.1-1 to be valid are shown on the figure.

The reactor protective system in combination with the Limiting Conditions for Operation, is designed to pr event any anticipated combination of transient conditions for reactor coolant system temperature, pressure, and thermal power level that would result in a DNBR of less than 1.23 and preclude the existence of flow instabilities.

2.1.2 REACTOR COOLANT SYSTEM PRESSURE The rest< iction of this Safety Limit protects the integrity of the Reactor Coolant System from overpressurization and thereby prevents the release of radionuclides contained in the reactor coolant from reaching the containment atmosphere.

The'eactor pressure vessel and pressurizer are designed to Section III of the ASME Code for Nuclear Power Plant components which permits a maximum transient pressure of llOX (2750 psia) of design pressure. The Reactor Coolant System piping, valves and fittings, are designed to ANSI 8 31. 7, Class I which permits a maximum transient pressure of 110$ (2750 psia) of component design pressure. The Safety Limit of 2750 psia is therefore consistent with the design criteria and associated code requirements.

The entire Reactor Coolant System is hydr otested at 3125 psia to demonstrate integrity prior to initial operation.

ST. LUCIE - UNIT I B 2-3 11-14-80

2.2 LIMITING SAFETY SYSTEM SETTINGS BASES'.2.1 REACTOR TRIP SETPOINTS The Reactor Trip Setpoints specified in Table 2.2-1 are the. values at which the Reactor Trips are set for each. parameter. The Trip Values have been selected to ensure that the reactor core and reactor coolant system are prevented from exceeding their safety limits. Operation with a trip set less conservative than its Trip Setpoint but within its specified Allowable Value is acceptable on the basis that the difference between each Trip Setpoint and the Allowable Value is equal to or less than the drift allowance assumed for each trip in the safety analyses.

Manual Reactor Tri The Manual Reactor Trip is. a redundant channel to the automatic protective instrumentation channels and provides manual reactor tri p capability.

~1-Hi h

'\

The Power Level-High trip provides reactor- core protection against reactivity excursions which are too rapid to be protected by a Pressurizer Pressure-High or Thermal Margin/Low Pressure Trip.

The Power Level-High trip setpoint is operator adjustable and can be set no higher than 9.61$ above the indicated THERMAL POWER level. Operator action is required to increase the trig setpoint as THERMAL POWER is increased. The trip setpoint is automatically decreased as THERMAL POWER decreases. The trip setpoint has a maximum value of 107-0$ of RATED THERMAL POWER and a minimum setpoint of 1SX of RATED THERMAL POWER. Adding to this maximum value the possible variation in trip point due to calibration and instrument errors, the maximum actual'HERMAL POWER level at which a 'trip would be actuated is 112%%d of RATED THERMAL POWER, which is consistent with the value used in the safety analysis.

Reactor Coolant Flow-Low The Reactor Coolant Flow-Low trip provides core protection to pr event DNB.

in the event of a sudden significant decrease in reactor coolant flow.

Provisions have been made in the reactor protective system to permit operation of the reactor at reduced power if one or two ST. LUCIE - UNIT I B 2-4 11-14-80

2.2 LIMITING SAFETY SYSTEM SETTINGS BASES Reactor Coolant Flow-Low continued reactor coolant pumps are taken out of service. The low-flow trip setpoints and Allowable Yalues for the various reactor coolant pump combinations have been derived in consideration of instrument errors and response times of equipment involved to maintain the DNBR above 1.23 under normal operation and expected transients. For reactor operation with only two or three reactor coolant pumps operating, the Reactor Coolant Flow-Low trip setpoints, the Power Level-High trip setpoints, and the Thermal Margin/Low Pressure trip setpoints are automatically changed when the pump condition selector switch is manually set to the desired two- or three-pump position- Changing thse trip setpoints during two and three pump operation prevents the minimum value of DNBR from going below 1.23 during normal operational transients and anticipated transients when only two or three reactor coolant. pumps are operating.

Pressurizer Pressure- Hi~h The Pressurizer Pressure-High trip, backed up by the pressurizer code safety valves and main stream line safety valves, provides reactor coolant system protection against overpressurization in the event of loss of load without reactor trip- This trip's setpoint is 100 psi below the nominal lift setting (2500 psia) of the pressur izer code safety valves and its concurrent operation with the power-operated relief valves avoids the undesirable operation of the pressurizer code safety valves.

Containment Pressure- Hi h The Containment Pressure-High trip provides assurance that a reactor trip in. initiated concurrently with a safety injection.

Steam Generator Pressure - Low The Steam Generator Pressure-Low trip provides protection against an excessive rate of heat extraction from the steam generators and subsequent cooldown of the reactor coolant. The setting of 600 psia is sufficiently below the full-load operating point of 800 psig so as not ST- LUG IE - UNIT I B 2-5 11-14-80,

LIMITING SAFETY SYSTEM SETTINGS BASES

~hd i /L The Thermal Margin/Low Pressure trip is provided to prevent operation when the ONBR is less than 1.23.

The trip is initiated whenever the reactor coolant system pressure signal drops below either 1887 psia or a computed value as described below. whichever is higher, The computed value is a function of the higher of hT power or neutron power, reactor inlet temperature, the number of reactor coolant pumps operating and the AXIAL SHAPE INOEX. The minimum value of reactor coolant flow rate, the maximum AZIMUTHAL POWER TILT and the maximum CEA deviation permitted for continuous operation are assumed in- the generation of this trip function. In addition, CEA group sequencing in accordance with Specifications 3.1.3.5 and 3.1.3.6 is assumed. Finally, the maximum insertion of CEA banks which can occur during any anticipated operational occurrence prior to a Power Level-High trip is assumed.

The Thermal Margin/Low Pressure trip setpoints include appropriate allowances for equipment response time, calculational and measurement, uncertainties, and processing error. A further allowance of 30 psia is included to compensate for the time delay associated with providing effective termination of the occurrence that exhibits the most rapid decrease in margin to the ONBR limit.

As mmetric Steam Generator Transient Protective Tri Function'SGTPTF The ASGTPTF consists of steam generator pressure inputs to the TM/LP calculator, which causes a reactor trip when the difference in pressure between the two steam generators exceeds the trip'setpoint. The ASGTPTF is designed to provide a reactor trip for those events associated. with the secondary system which result in asymmetric primary loop coolant temperatures. The most limiting event is the loss of load -to one steam generator caused by a single main steam isolation valve closure.

The equipment trip setpoint and allowable values are calculated to account for instrument uncertainties, and will ensure a trip at or before reaching the analysis setpoint.

ST. LUCIE - UNIT 1 B 2-7 11-14-80

LIMITING SAFETY SYSTEM SETTINGS BASES Loss of Turbine A Loss of Turbine trip causes a direct reactor trip when operating above 15% of RATED THERMAL POKIER. This trip provides turbine protection, reduces the severity of the ensuing transient and helps avoid the lifting of the main steam line safety valves during the ensuing transient, thus extending the service life of these valves. No credit was taken in the accident analyses for operation of this trip. Its functional capability at the specified trip setting is required to enhance the overall reliability of the Reactor Protection System.

Rate of Change of Power-Hi~h The Rate of Change of Power-High trip is provided to protect the core during startup operations and its use serves as a backup to the administratively enforced startup rate limit. Its trip setpoint does not correspond to a Safety Limit and no credit was taken in the accident analyses for operation of this trip. Its functional capability at the specified trip setting is required to enhance the overall reliability of the Reactor Protection System.

ST. LUCIE - UNIT 1 B 2-8 11-14-80

3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 BORATION CONTROL SHUTDOWN MARGIN - TAVG >200'F LIMITING CONDITION fOR OPERATION 3.1.1.1 The SHUTDOWN MARGIN shall be > 4.3$ hk/k.

APPLICABLITY: MODES 1, 2, 3, and 4.

ACTION:

With the SHUTDOWN MARGIN < 4.3% ~ k/k, immediately initiate and continue boration at > 40 gpm of 1720 ppm boron or equivalent until. the required SHUTDOWN MARGIN is restored.

SURVEILLANCE RE UIREMENTS 4.1.1.1.1 The SHUTDOWN MARGIN shall be determined to be > 4.3% 6 k/k:

a. Within one hour after detection of an inoperable CEA(s) and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter while the CEA(s) is inoperable. If the inoperable CEA is immovable or untrippable, the above required SHUTDOWN MARGIN shall be increased by an amount at least equal to the withdrawn worth of the immovable or untrippable CEA(s).

b. When in MODES 1 or 2 , at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months by verifying that CEA group withdrawal is within the Power Dependent Insertion Limits of Specification 3.1.3.6.

c. When in MODE 2 ~, at last once during CEA withdrawal and at least once per hour thereafter until the reactor is critical.

d. Prior to initial operation above 5% RATED THERMAL POWER after each fuel loading, by consideration of the factors of e below, with the CEA groups at the Power Dependent Insertion Limits of Specification 3.1.3.6.

" See Special Test Exception 3. 10. 1.

4 With Keff > 1.0.

84 With Keff < 1.0 ST. LUCIE - UNIT I 3/4 1-1 11-14-80

REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGI N Tav < 2 ~ OX < k/k +

LIMITING CONDITION FOR OPERATION 3.1.1.2 The SHUTDOWN MARGIN shall be > 2.0X bk/k.

APPLICABILITY: MODE 5.

With the SHUTDOWN MARGIN < 2.0% gk/k, immediately initiate and continue boration at > 40 gpm of 1720 ppm boron or equivalent until the required SHUTDOWN MARGIN is restored.

SURVEILLANCE RE UIREMENTS 4-1.1.2 The SHUTDOWN MARGIN shall be determined to be > 2.0X gk/k:

a. Within one hour afer detection of an inoperable CEA(s) and at least once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter while the CEA(s) is inoperable. If the inoperable CEA is immovable or untrippable, the above required SHUTDOWN MARGIN shall be increased by an amount at least equal to the withdrawn worth of the immovable or untrippable CEA(s).

b- At least once per 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months by consideration of the following factor s:

1 ~ Reactor coolant system boron concentration,

2. CEA position,

3. Reactor coolant system average temperature,

4. Fuel burnup based on gross thermal energy generation,

5. Xenon concentration, and

6. Samarium concentration.

ST. LUCIE - UNIT I 3/4 1-3 11-14-80

REACTIVITY CONTROL SYSTEMS MODERATOR TEMPERATURE COEFFICIENT LIMITING CONDITION FOR OPERATION 3.1.1.4 The moderator temperature coefficient (MTC) shall be:

a. Less positive than 0.5 x 10 hk/k/'F whenever THERMAL. POWER is

< 705 of RATED THERMAL POWER,

b. Less positive than 0-2 x 10 6 k/k/'F whenever THERMAL POWER is > 70% of RATED THERMAL POWER, and

c. Less negative than -2.5 x 10 hk/k/'F at RATED THERMAL POWER.

APPLICABILITY: MODES 1 and 2"0 ACTION:

With the moderator temperature coefficient outside any one of the above limits, be in HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

SURVEILLANCE RE UIREMENTS 4.1.1.4.1 The MTC shall be determined to be within its limits by confirmatory measurements. MTC measured values shall be extrapolated and/or compensated to permit direct comparison with the above limits.

With K ff > 1.0.

PSee Special Test Exception 3.10.2 ST. LUCIE - UNIT I 3/4 1-5 11-14-80

REACTIVITY CONTROL SYSTEMS FLOW PATHS - OPERATING LIMITING CONDITION FOR OPERATION 3.1.2.2 At least two of the following three boron injection flow paths and one associated heat tracing circuit shall be OPERABLE:

a. Two flow paths. from the boric acid makeup tanks via either a boric acid pump or a gravity feed connection and a charging pump to the Reactor Coolant System, and

b. The flow path from the refueling water tank via a chargi ng pump to the Reactor Coolant System.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With only one of the above required boron injection flow paths to the Reactor Coolant System OPERABLE, restore at least two boron injection fl'ow paths to the Reactor Coolant System to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or make the reactor subcritical within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and borate to a SHUTDOWN MARGIN equivalent to at least 2K hk/k/ at 200'F; restore at least two flow paths to OPERABLE status within the next 7 days or be in COLD SHUTDOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE RE UIREMENTS 4.1.2.2 At least two of the above required flow paths shall be demonstrated OPERABLE:

a. At least once per 7 days by:

1. Cycling each testable power operated or automatic valve in the flow path through at least one complete cycle of full travel.

ST. LUCIE - UNIT I 3/4 1-10 11-14-80

REACTIVITY CONTROL SYSTEMS BORATED WATER SOURCES - OPERATING LIMITING,CONDITION FOR OPERATION 3.1.2.8 At least two of the following three borated water sources shall be

OPERABLE,

a. Two boric acid makeup tanks and one associated heat tracing circuit with the contents of the tanks in accordance with Figure 3.1-1, and

b. The refueling water tank with:

1- A minimum contained volume of 401,800 gallons of water, 2- A minimum boron concentration of 1720 ppm, 3- A minimum solutio'n temperatur e of 100'F, 4- A minimum solution temperature of 55'F when in MODES 1 and 2, and 5- A minimum solution temperature of 40'F when in MODES 3 and 4.

APPLICABILITY: MODES 1, 2, 3 and 4.

ACTION:

With only one borated water source OPERABLE, restore at least two borated water sources to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months or make the reactor subcritical within the next 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and borate to a SHUTDOWN MARGIN equivalent to at least 2$ hk/k at 200'F; restore at least two borated water sources to OPERABLE status wihin the next 7 days or be in COLD SHUTDOWN within the next 30 hours3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months .

SURVEILLANCE RE UIERMENTS 4.1.2.8 At least two borated water sources shall be demonstrated OPERABLE:

a. At least once per 7 days by:

1. Verifying the boron concentration in each water source.

ST. LUCIE - UNIT 1 3/4 1-18 11-14-80

1. 00 0.90 g

R 0.80 82$ .70) 0.70 (68,.75) a 0.60 l

< 0.50 l POWER DEPENDENT'INSERTION L/MIT LONG TERM O STEADY STATE aO 0.40 f INSERTION H LIMIT

0. 30 HORT TERM STEADY STATE INSERTION LIMI 0.20 0.10 GROUPS 3 0 27 55 82 109 137 0 27 55 82 109 137 0 27 55 82 109 137 6

0 27 55 82 109 137 0 27 55 82 109 137 CEA INSERTION (INCHES)

Pigure 3.1-2 CEA Insertion Limits vs THERMAL POWER with 4 Reactor Coolant Pumps Operating

UNACCEPTABLE OPERATION A

15. 0 15.0 O

O ACCEPTABLE OPERATION

14. 0 13.0 BOL EOL CYCLE LIFE FIGURE 3.2-1 Allowable Peak Linear Heat Rate vs Burnup ST. LUCIE -'NIT 1 3/4 2-3 11-14-80

1.2 1.1

~~ 1.0 REGION OF UNACCEPTABLE OPERATION o

~ 0.9 O (-0.05, 0.82) (0.15, 0.82)

~ 0.8 REGION OF UNACCEPTABLE OPERATION

~ 0.7 O

O M

REGION OF 5 0.6 (-0.3,0.58)

ACCEPTABLE OPERATION (0.3, 0.58) 0.5 0.4

-0.6 -0.4 -0.2 0.0 0.2 0.4 0.6 PERIPHERAL AXIAL SHAPE INDEX FIGURE 3.2-2 AXIAL SHAPE INDEX vs. Fraction of Maximum Allowable Power Level Per Specification 4.2.1.3 ST. LUCIE UNIT 1 3/4 2-4 11-14-80

1. 10

~

1. 08 r

1 34.7,1.071

~ 118.6,1.067 F4 106.5,1.063 gC3 1.06 ~ 90.5 1.057 o 0 74.4, 1.050 62.3, 1.045

~ ~

I I 1.04 46.2, 1.035

~ ~

4J4 0

3 0.2$ 1.025

1. 02

~ 18. 1, 1. 017

1. 00

~ 2.0, l. 00 0 14 28 42 56 70 84 98 112 125 140 DISTANCE FROM BOTTOM OF CORE, INCHES I

I CO FIGURE 4.2-1 C)

AUGMENTATION FACTORS vs DISTANCE FROM BOTTOM OF CORE

POWER DISTRIBUTION LIMITS TOTAL PLANAR RAD IAL PEAKI NG FACTOR F LIMITING CONDITION FOR OPERATION 3.2.2 The calculated value FT defined as FT = F (1+T ), shall be limited to < 1.70.

APPLICABILITY: MODE 1*.

ACTION:

With FT >1.70, within 6 hours either:

a. Reduce THERMAL POWER to bring the ccmbination of THERMAL POWER and FT to within the limits of Figure 3.2-3 and withdraw the full length CEAs to or beyond the Long Term Steady State Insertion Limits of Specification 3.1.3-6; or

b. Be in HOT STANDBY.

SURVEILLANCE RE UIREMENTS 4.2.2.1 The provisions of Specifications 4.0.4 are not applicable.

4.2.2.2 FT shaii be calculated by'he expression FT = p (1+iI when xy xy xy in non-LOAD FOLLOW OPERATION and by the expression FT = 1 03 xy Fxy (1+Tq) when in LOAD FOLLOW OPERATION. F xy shal 1 be determined to be within its limit at the following intervals:

a. Prior to operation above 70 percent of RATED THERMAL POWER after each fuel loading,

b. At least once per 31 days of accumulated operation in MODE 1, and c Within four hours i f the AZIMUTHAL POWER TILT (Tq) is

> 0.03.

See Special Test Exception 3.10.2.

ST. LUICIE - UNIT 1 3/4 2-6 11-14-80

1.0 1.7, 1.0) UNACCEPTABLE OPERATION REGION 0.9 (1.78,0.9) 0.8 ACCEPTABLE OPERATION REGION 0.7 0.6

1. 70 l. 71 1.72 1.73 1.74 1.75 1.76 1.77 1.78 T T Heasured P>, P FIGURE 3.2-8 Allowable Combinations Of Thermal Power And F<, P XJJ

POWER DISTRIBUTION LIMITS TOTAL INTEGRATED RADIAL PEAKING FACTOR FT r

LIMITING CONDITION fOR OPERATION 3-2.3 The calculated value of F r', defined as FT = F (1+T ), shall be q

to < 1..70. 'imited APPLICABILITY: MODE 1*-

ACTION:

With FT > 1.70, within 6 hours either:

a. Be in at least HOT STANDBY, or

b. Reduc~ THERMAL POWER to bring the combination of THERMAL POWER and F to within the r limits of Figure 3.2-3 and withdraw the full length CEAs to or beyond the Long Term Steady State Insertion Limits of Specification 3.1.3.6. The THERMAL POWER limit determined from Figure 3.2-3 shall then be used to establish a revised upper THERMAL POWER level limit on Figure 3.2-4 (truncate Figure 3.2-4 at the allowable fraction of RATED THERMAL POWER determined by Figure 3.2-3) and subsequent operation shall be maintained within the reduced accceptable operation of Figure 3.2-4.

SURVEILLANCE RE UIREMENTS 4.2.3.1 The provisions of Specification 4-0.4 are not applicable.

4.2.3.2 FT r shall be calculated by the expression FT = F r r (1+T q ) when in non-LOAD FOLLOW OPERATION and by the expression r ' F (1+T q )

F = 1.02 when in LOAD FOLLOW OPERATION. F shall be determined to be within its limit at the following intervals-

a. Prior to operation above 70 percent of RATED THERMAL POWER after each fuel loading.

b At least once per 31 days of accumulated operation in MODE 1, and

c. Within four hours if the AZIMUTHAL POWER TILT (Tq) is > 0.03.

"See Special Test Exception 3.10.2.

ST. LUCIE - UNIT 1 3/4 2-9 11-14-80

TABI E 3.2-1 DNB MARGIN LIMITS Four Reactor Coolant Pumps Parameter 0 eratin Cold Leg Temperature < 549'F Pressurizer Pressure > 2225 psia*

Reactor Coolant Flow Rate > 370,000 gpm AXIAL SHAPE INDEX Figure 3.2-4

Limit not applicable during either a THERMAL POWER ramp increase in excess of 5X of RATED THERMAL POWER or a THERMAL POWER step increase of greater than lOX of RATED THERMAL POWER.

ST. LUCIE - UNIT 1 3/4 2-14 11-14-80

1.1 1.0 (-0.08,1.00)

( .15 1.00)

UNACCEPTABLE UNACCEPTABLE OPERATION OPERATION REGION REGION 0.9 g

0.8 A ACCEPTABLE OPERATION

< 0,7 (-0.3, 0.70) REGION (0.3, 0.70)

O O

M 0.6 0.5 0.4

-0.4 -0.4 -0.2 0.'0 0.2 0.4 0.6 PERIPHERAL AXIAL SHAPE INDEX (Yl)

FIGURE 3.2-4 AXIAL SHAPE INDEX Operating Limits With 4 Reactor Coolant Pumps Operating ST. LUCIE - UNIT 1 3/4 2-15 11-14-80

TABLE 3.3-1 REACTOR PROTECTIVE INSTRUMENTATION MINIMUM TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP OPERABLE MODES ACTION

1. Manual Reactor Trip 1, 2 and *

2. Power Level - High 2(a) 3(f) 1, 2

3. Reactor Coolant Flow - Low 4/SG 2(a)/SG 3/SG 1, 2 (e)

4. Pressurizer Pressure - High 1, 2

5. Containment Pressure - High 1, 2

6. Steam Generator Pressure - Low 4/SG 2(b)/SG 3/SG 1, 2

7. Steam Generator 'llater Level - Low 4/SG 2/SG 3/SG 1, 2

8. Local Power Density - High 2(c) 3

9. Thermal Margin/Low Pressure 2(a) 1,2 (e) 9a.Steam Generator Pressure Difference

-High 2(a) 1,2 (e) 10.Loss of Turbine- -Hydraulic Fluid Pressure Low 2(c)

TABLE 3. 3-1 CONTINUED TABLE NOTATION

With the protective system trip breakers in the closed position and the CEA drive system capable of CEA withdrawal.

The provisions of Specificatin 3.0.4 are not applicable.

(a) Trip may be bypassed. below 15 of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER is > 15 of RATED THERMAL POWER.

(b) Trip may be mannually bypassed below 685 psia; bypass shall be automatically removed at or above 685 psia.

(c) Trip may be bypassed below 155 of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER IS > 15$ of RATED THERMAL POWER.

(d) Trip may be bypassed below 10 5 aod above 15K of RATED THERMAL P)WER; bypass shall be automatically removed when THERMAL power is > 10 5 or <

15$ of RATED THERMAL POWER.

(e) Trip may be bypassed during testing pursuant to Special Test Exception 3.10.3.

(f) There shall be at last-two decades of overlap between the Wide Range Logarithmic Neutron Flux Monitoring Channels and the Power Range Neutron Flux Monitoring Channels.

ACTION STATEMENTS ACTION 1 With the number of channels OPERABLE one less than required by the Minimum Channels OPERABLE requirement, restore the inoperable channel to OPERABLE status wihin 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and/or open the protective system trip breakers-ACTION 2 - With the number of OPERABLE channels one less than the Total Number of Channels, STARTUP and/or POWER OPERATION may proceed provided the following conditions are satisfied:

a. The inoperable channel is placed in either the bypassed or tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . For the purposes of testing and maintenance, the inoperable channel may be bypassed for up to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months from time of initial loss of OPERABILITY; however, the inoperable channel shall then be either restored to OPERABLE status or placed in the tripped condition.

ST. LUCIE - UNIT 1 3/4 3-4 11-14-80

TABLE 3.3-2 n REACTOR PROTECTIVE INSTRUMENTATION RESPONSE TIMES.

m FUNCTIONAL UNIT RESPONSE TIME

1. Manual Reactor Trip Not Applicable

2. Power Level - High < 0.40 seconds"0 and < 8.0 seconds88 3.= Reactor Coolant Flow - Low < 0.65 seconds Pressurizer Pressure - High < 0.90 seconds

5. Containment Pressure - High < 1.40 seconds

6. Steam Generator Pressure Low < 0.90 seconds

7. Steam Generator Water Level - Low < 0.90 seconds

8. Local Power Density - High < 0.40 seconds"f and < 8.0 seconds8P

9. Thermal Margin/Low Pressure < 0.90 seconds*8 and < 8.0 secondsft 9a. Steam Generator Pressure Difference - High < 0.90 seconds

10. Loss of Turbine- -Hydraulic Fluid Pressure - Low Not Applicable

11. Wide Range Logarithmic Neutron Flux Monitor ~

Not Applicable

Neutron detectors are exempt from response time testing. Response time shall be measured from detector output or input of first electronic component in channel.

Response time does not include contribution of RTDs.

I CX)

CD IIII RTD response time only. This value is equivalent to the time interval required for the RTDs output to achieve 63.2tl of its total change when subjected to a step change in RTD temperatur e.

TABLE 4.3-1 REACTOR PROTECTIVE INSTRUMENTATION SURVEILLANCE RE UIREMENTS CHANNEL MODES IN WHICH CHANNEL CHANNEL FUNCTIONAL SURVEILLANCE FUNCTIONAL UNIT CHECK CAL IBRATION TEST REIEUIRB

1. Manual Reactor Trip N.A. N.A. S/U (I ) N.A.

2. Power Level - High

a. Nuclear Power '

D(2), M(3),g(5) M 1, 2 B. ~T Power D(4)' 1

3. Reactor Coolant Flow - Low .S 1, 2

4. Pressurizer Pressure - High 1, 2

5. Containment Pressure - High 1, 2

6. Steam Generator Pressure - Low 1, 2

7. Steam Generator Water Level - Low 1, 2

8. Local Power Density - High

9. Thermal Margin/Low Pressure 1, 2 9a. Steam Generator Pressure Difference - High 1, 2

10. Loss of Turbine Hydraulic Fluid Pressure - Low N.A- N.A. S/U(1) N.A.

ll. Wide Range Logarithmic Neutron Flux Monitor N.A. S/U(l) 1, 2, 3, 4, 5 and*

12. Reactor Protection System Logic N.A. N.A. M and S/U(l) 1, 2 and *

13. Reactor Trip Breakers N.A. N.A. M 1,2and*

TABLE 3.3. -3 CONTINUED TABLE NOTATION (a) Trip function may be bypassed in this MODE when pressurizer pressure is

<1725 psia; bypass shall be automatically removed when pressurizer

. pressure is > 1725 psia.

(b) An SIAS signal is first necessary to enable CSAS logic.

(c) Trip function may be bypassed in this MODE below 685 psia; bypass shall be automatically removed at or above 685 psia..

The provisions of Specification 3.O.4are not applicable, ACTION STATEMENTS ACTION 8- With the number of OPERABLE channels one less than the Total Number of Channels, restore the inoperable channel to OPERABLE status within 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months or be in at least HOT STANDBY within the next 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months and in COLD SHUTDOWN within the following 30 hour3.472222e-4 days 0.00833 hours 4.960317e-5 weeks 1.1415e-5 months s-ACTION 9- With the number of OPERABLE channels one less than the Total Number of Channels, operation may proceed provided the following conditions are satisfied:

a- The inoperable channel is placed in either the bypassed or tripped condition within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months . For the purposes of testing and maintenance, the inoperable channel may be bypassed for up to 48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months from time of initial loss of OPERABILITY, however, the inoperable channel shall then be either restored to OPERABLE status or placed in the tripped condition.

b. Within one hour, all functional units receiving an input from the inoperable channel are also placed in the same condition (either bypassed or tripped, as applicable) as that required by a. above for the inoperable channel.

c. The Minimum Channels OPERABLE requirement is met; however, one additional channel may be bypassed for up to,48 hours5.555556e-4 days 0.0133 hours 7.936508e-5 weeks 1.8264e-5 months while performing tests and maintenance on that channel provided the other inoperable channel is placed in the tripped condition.

ST. LUCIE - UNIT I 3/4 3-12 11-14-80

TABLE 3.3-4 ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP VALUES FUNCTIONAL UNIT TRIP SETPOI NT ALL014ABLE VALUES

1. SAFETY INJECTION (SIAS)

a. Manual (Trip Buttons) Not Applicable Not Applicable

b. Containment Pressure - High < 5 psig < 5 psig

c. Pressurizer Pressure - Low > 1600 psia > 1600 psia

2. CONTAINMENT SPRAY (CSAS)

a. Manual (Trip Buttons) Not Applicable Not Applicable

b. Containment Pressure High - High < 10 psig < 10 psig

3. CONTAINMENT ISOLATION (CIS) a- Manual (Trip Buttons) Not Appl icabl e Not Applicable

b. Containment Pressure - High < 5 psig < 5 psig

c. Containment Radiation - High < 10 R/hr < 10 R/hr

4. MAIN STEAM LINE ISOLATION (MSIS)

a. Manual (Trip Buttons) Not Applicable Not Applicable

b. Steam Generator Pressure - Low > 600 psia > 600 psia

5. CONTAINMENT SUMP RECIRCULATION (RAS)

a. Manual RAS (Trip Buttons) Not Applicable Not Applicable

b. Refueling Mater Tank - Low 48 inches above 48 inches above tank bottom tank bottom

3/4.4 REACTOR COOLANT SYSTEM REACTOR COOLANT LOOPS LIMITING CONDITION FOR OPERATION 3-4.1 Four reactor coolant pumps shall be in operation.

APPLICABILITY: As noted below, but excluding MODE 6.

ACTION:

MODES 1 and 2:

With less than four reactor coolant pumps in operation, be in at least HOT STANDBY within 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months .

MODE 3 Operation may proceed provided a) Two reactor coolant loops are in operation with either both or just one reactor coolant pump(s) in each loop or b) At least one reactor coolant loop is in operation with an associated reactor coolant pump and the Shutdown Margin requirement of Specification 3.1.1.1. is increased to and maintained at > 5.1% L k/k.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

MODES 4 and 5:

Operation may proceed provided at least one reactor coolant loop is in operation with an associated reactor coolant pump or shutdown cooling pump.

The provisions of Specifications 3.0.3 and 3.0.4 are not applicable.

SURVIELLANCE RE UIREMENTS 4.4.1 The Flow Dependent Selector Switch shall be determined to be in the 4 pump position within 15 minutes prior to making the reactor critical and at last once per 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months thereafter.

All reactor coolant pumps and shutdown cooling pumps may be de-energized for up to 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months , provided no operations are permitted which could cause dilution of the reactor coolant system boron concentration.

ST- LUCIE - UNIT 1 3/4 4-1 11-14-80 0

3/4. 1 REACTIVITY CONTROL .SYSTEMS BASES 3/4. 1 .1 BORATION CONTROL 3/4. 1 .1. 1 and 3/4 l. l. 2 SHUTDOWN MARGIN A sufficient SHUTDOWN MARGIN ensures that 1) the reactor can be made subcritical from all operating conditions, 2) the reactivity transients associated with postulated accident conditions are controllable within acceptable limits, and 3) the reactor will be maintained sufficiently subcritical to preclude inadvertent criticality in the shutdown condition.

SHUTDOWN MARGIN requirements vary throughout core life as a function of fuel depletion, RCS boron concentration, and RCS Ta ~ The most restrictive condition occurs at EOL, with Tav at no load opera$ fng temperature, and is associated with a postulated steal line break accident and resulting uncontrolled RCS coo'Idown. In the analysis of this accidents a minimum SHUTDOWN MARGIN of 4.3Ã ~k/k is required to control the reactivity transient. Accordingly, the. SHUTDOWN MARGIN required by Specification 3.1.1.1 is based upon this limiting condition and is consistent with FSAR accident and analysis assumptions. For earlier periods during the fuel cycle, this value is conservative. With Tav < 200'F, the reactivity transients resulting from any postulated accident ar3 minimal and a 2X Lk/k shutdown margin provides adequate protection.

3/4. 1. l. 3 BORON DILUTION AND ADDITION A minimum flow rate of at least 3000 GPM provides adequate mixing, prevents stratification and ensures that reactivity changes will be gradual during boron concentration changes in the Reactor Coolant System. A flow rate of at least 3000 GPM will circulate an equivalent Reactor Coolant System volume of 11,400 cubic feet in approximately 26 minutes. The reactivity change rate associated with boron-concentration changes will be within the capability for operator recognition and control.

3/4-1. 1- 4 MODERATOR TEMPERATURE COEFFICIENT MTC The limiting values assumed fog- the MTC used in the accident and transient analyses were + 0.5 x 0 ak/k/'F for TWERWRL POWER levels < 70f. of RATED THERMAL POWER, + 0.2 x 10 $ ~k/k/'F for THERMAL POWER levels ) 70% of RATED THERMAL POWER and - 2e5 x 10 ~k/k/'F at RATED THERMAL POWER-Therefore, these limiting values are included in this specification.

Determination of MTC at the specified conditions ensures that the maximum positive and/or negative values of the MTC will not exceed the limiting values.

ST. LUCIE UNIT 1 B 3/4 1-1 . 11-14-80

REACTIVITY CONTROL SYSTEMS BASES 3/4-1.1.5 MINIMUM TEMPERATURE FOR CRITICALITY The MTC is expected to be slightly negative at operating conditions.

However, at the beginning of the fuel cycle, the MTC may be slightly positive at operating conditions and since it will become more positive at lower temperatures, this specification is provided to restrict reactor operation when Tav is significantly below the normal operating temperature.

3/4 1. 2 BORATION SYSTEMS The boron injection system ensures that negative reactivity control is available during each mode of facility operation. The components required to perform this function include 1) borated water sources, 2) charging pumps, 3) separate flow paths, 4) boric acid pumps, 5) associated heat tracing systems, and 6) an emergency power supply from OPERABLE diesel generators-With the RCS average temperature above 200'F,. a minimum of two separate and redundant boron injection systems are provided to ensure single functional capability in the event an assumed failure. renders one of the systems inoperable. Allowable out-of-service periods ensure that minor component repair or. corrective action may be completed without undue risk to overall facility safety from injection system failures during the repair period.

The boration capability of either system is sufficient to provide a SHUTDOWN MARGIN from all operating conditions of 2.05 Lk/k after xenon decay and cooldown to 200'F. The maximum boration capability requirement occurs at EOL from full power equilibrium xenon conditions and requi res 7,925 gallons of 8.0$ boric acid solution from the boric acid tanks or 13,700 gallons of 1720 ppm borated water from the refueling water tank.

The requirements for a minimum contained volume of 401,800 gallons of borated water in the refueling water tank ensures the capability for borating the RCS to the desired level- The specified quantity of borated water is consistent with the ECCS r equirements of Specification 3.5.4. Therefore, the larger volume of borated water is specified here too.

With the RCS temperature below 200'F, one injection system is acceptable without single failure consideration on the basis of the stable reactivity condition of the reactor and the additional restrictions prohibiting CORE ALTERATIONS and positive reactivity change in the event the single injection system becomes inoperable.

ST. LUCIE - UNIT I B 3/4 1-2 11-14 POWER DISTRIBUTION LIMITS BASES used in the analysis establishing the DNB Margin LCO, and Thermal. Margin/Low Pressure LSSS setpoints remain vapid dyeing ogeration agthe yarious allowable EA.arnulf'nsertion. n limits. If.F'xy " r or io exceed ~ err mastic smitqah6~ns, operation may continue under the ddditional restrictions imposed by the ACTION statements since these additional restrictions provide adequate provisions to assure that the assumptions used in establishing the Linear Heat Rate, Thermal Margin/Low Pressur e and Local Power Density - High LCOs and LSSS setpoints remain valid. An AZIMUTHAL POWER TILT ) 0.10 is not expect'ed and if it should occur, subsequent operation would be restricted to only those operations required to identify the cause of this unexpected tilt.

The value of Tq that must be used in the equation FT F (1 +T ) and F

=

Fr (1+Tq) is the measured tilt.

T T The surveillance requirements for verifying that F xy, F r and T are within their limits provide assurance that the actual values of F , F and T do not exceed the assumed values. yerifying F an "T r xy fuel loading prior to exceeding 75K of RATED THERMAL POWER provides additional assurance that the core was properly loaded.

3/4.2.5 DNB PARAMETERS The limits on the DNB related parameters assure that each of these parameters are maintained within the normal steady state envelope of operation assumed in the transient and accident analyses. The limits are consistent with the safety analyses assumptions and have been analytically demonstrated adequate to maintain .a minimum DNBR of 1.23 throughout each analyzed transient.

The 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months periodic surveillance of these parameters through .instrument readout is sufficient to ensure that the parameters are restored within their limits following load changes and other expected transient operatin. The 18 month periodic measurement of the RCS total flow rate is adequate to detect flow degradation and ensure correlation of the flow indication channels with measured flow such that the indicated percent flow will provide sufficient verification of flow rate on a 12 hour1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months basis-ST. LUCIE - UNIT 1 B 3/4 2-2 11-14-80

3/4.4 REACTOR COOLANT SYSTEM BASES 3/4.4-1 REACTOR COOLANT LOOPS The plant is designed to operate with both reactor coolant loops and associated reactor coolant pumps in operation, and maintain DNBR above 1.23 during all normal operations and anticipated transients. STARTUP and POWER OPERATION may be initiated and may proceed with one or two reactor coolant pumps not in operation after the setpoints for the Power Level-High, Reactor Coolant Flow-Low and Thermal Margin/Low Pressure. trips have been reduced to their specified values. Reducing these trip setpoints ensures that the DNBR will be maintained above 1.23 during three pump operation and that during two pump operation the core void fraction will be limited to ensure parallel channel flow stability within the core and thereby prevent premature DNB.

A single reactor coolant loop with its steam generator filled above the low level trip setpoint provides sufficient heat removal capacity for core cooling while in NODES 2 and 3; however, single failure considerations require plant cooldown if component repairs and/or corrective actions cannot be made within the allowable out-of-service time.

3/4.4.2 and 3/4.4.3 SAFETY YALVES The pressurizer code safety valves operate to prevent the RCS from being pressurized above its Safe y Limit of 2750 psia. Each safety valve is designed to relieve 2 x 10 lbs per hour of saturated steam at the valve setpoint. The relief capacity of a single safety valve is adequate to relieve any overpressure condition which could occur during shutdown. In the event that no safety valves are OPERABLE; an operating shutdown cooling loop, connected to the RCS, provides overpressure relief capability and will prevent RCS overpressurization.

During operation, all pressurizer code safety valves must be OPERABLE to prevent the RCS from being pressurized above its safety limit of 2750 psia.

The combined relief capacity of these valves is sufficient to limit the Reactor Coolant System pressure to within its Safety Limit of 2750 psia following a complete loss of turbine generator load while operating at RATED THERMAL-POWER and assuming no reactor trip until the first Reactor Protective System trip setpoint (Pressurizer Pressure-High) is reached (i.e. no credit is taken for a direct reactor trip on the loss of turbine) and also assuming no operation of the pressurizer power operated relief valve or steam dump valves.

ST. LUCIE - UNIT 1 B 3/4 4-1 11-14-80

~,

v,r 3/4.7 PLANT SYSTEMS BASES 3/4. 7.1 TURBINE CYCLE 3/4 "7. 1.1 SAFETY VALVES The OPERABILITY of the main steam line code safety valves ensures that the secondary system pressure will be limited to within 110$ of its design pressure during the most severe anticipated system operational transient. The maximum relieving capacity is associated with a turbine trip from 1005 RATED THERMAL POWER coincident with an assumed loss of condenser heat sink (i-e. no steam bypass to the condenser).

The specified valve lift settings and relieving capacities are in accordance with the requirements of Section III of the ASME Boiler and Pressure Code, 1971 Edition and ASME Code for Pumps and Valves, Class'I. The to)al relieving capacity for a11 valves on all of the steam lines is 12.38 x 10 lbs/hr which is 102-8 percent the total secondary steam flow of 12.04 x 10 lbs/hr at 100$ RATED THERMAL POWER. A minimum of 2 OPERABLE safety valves per steam generator ensures that sufficient relieving capacity is available for removing decay heat.

STARTUP and/or POWER OPERATION is allowable with safety valves inoperable within the limitations of the ACTION requirements on the basis of the reduction in secondary system steam flow and THERMAL POWER required by the reduced reactor trip settings of the Power Level-High channels. The reactor trip setpoint reductions are derived on the following basis:

For two loop operation SP X - Y V x (106. 5)

X where:

SP = reduced reactor trip setpoint in percent of RATED THERMAL POWER V = maximum number of inoperable safety valves per steam line '

ST. LUCIE - UNIT 1 B 3/4 7-1 11-14-80

PLANT SYSTEMS

.0 BASES 106.5 = Power Level - High Trip Setpoint for two loop operation X = Total relieving capacity of ail safety vaives per steam line in lbs/hour (6.192 x 10 lbs/hr.)

Y = Maximum relieving ca~acity of any one safety valve in lbs/hour (7.740 x 10 lbs/hr.)

3/4.7.1.2 AUXILIARY FEEDWATER PUMPS v

The OPERABILITY of the auxiliary feedwater pumps ensures that the Reactor Coolant System can be cooled down to less than 325'F from normal operating conditions in the event of a total loss of off-site power.

Any two of the three auxiliary feedwater pumps have the required capacity to provide sufficient feedwater flow to remove reactor decay heat and reduce the RCS temperature to 325'F where the shutdown cooling system may be placed into operation for continued cooldown.

3/4.7.1.3 CONDENSATE STORAGE TANK I

The OPERABILITY of the condensate storage tank with the minimum water volume ensures that sufficient water is available for cooldown of the Reactor 0

Coolant System to less than 325'F in the event of a total loss of off-site power. The minimum water volume is sufficient to maintain the RCS at HOT STANDBY conditions for 9 hours1.041667e-4 days 0.0025 hours 1.488095e-5 weeks 3.4245e-6 months with steam discharge to atmosphere.

3/4- 7.1. 4 ACTIVITY The limitations on secondary system specific activity ensure that the resultant off-site radiation dose will be limited to a small fraction of 10 CFR Part 100 limits in the event of a steam line rupture. The dose calculations for an assumed steam line rupture include the effects of a coincident 1.0 GPM primary to secondary tube leak in the steam generator of the affected steam line and a concurrent loss of offsite electrical power-These values are consistent with the assumptions used in the acc'ident analyses.

11-14-80 ST. LUCIE UNIT 1 B 3/4 7-2

ATTACHMENT 3 Re: St. Luci e Unit 1 Docket No. 50-335 Stretch Power SAFETY EVALUATION

Oesign and Safety Report for St. Lucie Unit 1 Cyc1e 4 at 2700 NMt

Table of Contents Section Oescri tion I introduction and Summary Operating History of the Reference Cycle General Oescription Fuel Oesign 6 Nuclear Oesign 6 Thermal-Hydraulic Oesign @e<sebs, Sections 1-6 T

8 9

Transient Analysis KCCS A alysis t')

Ref. Section 7 f

Ref. Section (R S 8)

Reactor Protection Sys'em: Asymmetri'c Steam Generator Transient Protection System

I. INTRODUCTION AND SUGARY This report. provides an evaluation of the design and performance for the operation of St. Lucie-I during its fourth fuel cycle at a full power, stretch rating of 2700 felt; Cycles I, 2 and 3 were at a full power rating of 2560 Nlt. Other changes evaluated are an increase in the full power inlet temperature to 549 F and the addition of an asymmetric steam generator trip function. The core will consist of pr esently operating Batch C, 0 and E assembli.es together with fresh Batch F assemblies.

System requirements have created a ne d for flexibility in the Cycle 3 burnup length ranging from 7250 to 8250 iv~tl0/T. The Cycle 4 loading pattern described in this report has been designed to accommodate this range of shutdown points. ln performing analyses of postulated accidents, determining limiting safety system settings and establishing limiting conditions for operations, values of key parameters were chosen to assure that expected conditions are enveloped within the above Cycle 3 burnup range, The sleeving o CBL guide tubes caused by wear of the CEA fingers follows the same procedure as reported in Reference I. For Cycle 4 operation, only sleeved assemblies will be. placed under CEAs and all 88 Batch F assemblies will be sleeved.

The evaluations of the reload core characteristics have been examined with respect to the safety analyses describing Cycle 3 (Reference 2) hereafter referred to as the reference cycle. ln all cases, it has been concluded that the revised analyses at Z700 L~IMt presented in this report continue to show acceptable results.

Mhere dictated by variations from the reference cycle, proposed modifications to the plant Technical Specifications are provided and are justified by the. analyses reported herein.

2.0 OPERATING HISTORY OF THE REFERENCE CYCLE Cycle 3 is the designated x'eference cycle for this report.

St. Lucie Unit 1 operated dux'ing its third fuel cycle utilizing Batch B, C, D, and E fuel assemblies at or near a licensed core power level of 2560 Mwt. Cycle 3 terminated on March 15, 1980 at 8:42 pm with a buxnup of 6050.91 EFPH or 7730 MND/T. The texmination was within the range of burnups between 7250 and 8250 I'D/T anticipated for Cycle 3.

3., GENERAL OESCREPTlOW The Cycle 4 core ~iill consist of the numbers and types of assemblies from the various fuel batches as described in Table'3-1. The primary change to the cor e for Cycle 4 is the removal of'he remaining 21 Batch 8 assemblies and 6 7 of the 68 Batch C assemblies. These assemblies will be replaced by 40 8atch F (3.65 vi/o enrichment) and 48 8atch F>> (.3.03 w/o "ennchment J assemblies. The 4U lour enrichment 8atch F" assemhlies contain burnable poison pins with 12 pins per assembly., The location of poison pins within the lattice is the same as that for poison pin assemblies present >n the reference cycle. The fuel management pattern developed for Cycle 4 allovis for flexibility in Cycle 3 burnup length bet:ieen 7250 and 8250 tMO/T. The loading pattern is shown in Figure 3-1.

The Cycle 4 core loading pattern is 90 degrees rotatinnally symmetric.

That is, if one quadrant of the core vier e rot ted g0 degrees i to 'ts neighboring quadrant, each ass ably would overlay a similar assembly.

This similarity includes batch tyre, number of fuel rods, initial enrichment and begi.nning o" cycle burnup distribution.

Figure 3-2 shows the beginning or Cycle 4 assembly burnup distribution For a Cycle 3 burnup length of 7750 Hhl0/T. The initial enrich;,. nt or each assembly is also shown.

Tahl oQ1 St. Lncie Unit 1 Cvcle 4 Core Loadin lleginning of Cycle 4 Batch average Oul nup fl'.!0/hTU initial.

Initial tlumber- Shim Total-Assembly t(umber of Enrichment (NC 3 of Loading Total Fue <

Desi"n~tion Assembl ies a./o 0-235 7750 flh0(T) Shims slo BaC Shims Rods 2.82 24,800 0 176

$0 3.03 15,700 0 0 7,090 t

20 2.73 17,700 0 0 3,520 3.03 C300 0 0 , 7,0>s0 2.73 9)00 0 0 4,928 40 3.CS 0 0 0 7,040 3.03 0 12 3. 03 576 7,872 576 37,616 li~ ~

F F F F'y Fo D F

E Dg D E Dy F;: D Fo D Fg D E D D E D E=

F Ftw D

F D Fq D C St. Lucie FlgUl e Nuclear Power Station CYCLE -4 LOADS!UG PATTERN Unit No. 1 3-1

XXXX BQC 4 BURNUP (MM/D/T)

Y. YY INITIALENRICHMENT, NIT U-235 0.0 0.0 3.65 . 3.65 0.0 0.0 0.0 8,700 . 15,800 3.65 3.65 3.03 2.73 3.03 0.0 5, 500 8,500 7, 100 7, 300 0.0 3.65 3.03 2.73 3.03 3.03 3.03 0.0 0.0 18, 000 0.0 17, 400 0.0 18, 300 3.65 3. 03 2.73 3.03 3. 03 3.03 2.73 0.0 5, 500 18, 000 6, 200 14, 600 5, 600 17, 100 9, 700 3.65 3.03 273, 3.03 3.03 3.03 2. 73 s 2. 73 0.0 8, 600 0.0 14, 900 0.0 14, 500 0.0 16, 000 3.65 2.73 3.03 3.03 3.03 3.03 3.03 3. 03 0.0 7, 100 17, 400 5, 600 14, 600 6, 200 15, 800 9, 800 0.0 3. 03 3.03 3.03 3.03 3.03 3.03 3.03 2.73 3.65 8, 700 , 7,300 0.0 17, 100 0.0 15, 900 0.0 9, 800 0.0 2.73 3.03 3. 03 2. 73 3. 03 3. 03 3. 03 2.73 15 900 0.0 18, 300 9, 800 15, 800 9, 700 9, 800 24, 800 3.03 3. 03 2.73 2. 73 3. 03 2. 73 2.73 2.82 St. Lucie CYCLE 4 - ASSEMBLY AVERAGE BURNUP AND Fi(;ure Nuclear Power Station Unit No. 1 INITIALENRICHMENT DISTRIBUTION 3-2

4.0 FUEL OKSIGH 4.1 Hechanical Qes ign The fuel assembly complement for Cycle 4 is gi'ven in Table 3-1.

The mechanical design of the reload fuel assemblies, Batch F, is identical to St. Lucie-I Batch E fuel.

C-E has performed analytical predictions of cladding creep collapse time for all St. Lucie-1 fuel batches that will be irradiated during Cycle 4 and has concluded that the collapse resistance of all fuel rods is sufficient to preclude collapse during their design lifetime. This 'lifetime will not be exceeded by the Cycle 4 duration.

Predicted times to cladding collapse for the fuel batches that will be irradiated during Cycle 4 are given in Table 4-1.

The .analyses utilized the CJAPAN computer code (Refer ence 3) and included as input conservative values of internal pressure, cladding dimensions, cladding temperature and neutron flux.

a Table 4-1 Cladding Collapse information Calculated End of Cycle 4 Predicted Time Hatch 0 eration EFPH) to Collaose EFPH C 33,608

~40,000 0 24;002 321600 E 17,628 27,800 F Il,193 >27,000

4. 2 l{ardware /lodifications to Mitigate Guide Tube !Hear All Batch C, E, and F fuel assemblies installed in CEA locations for Cycle 4 have stainless steel sleeves installed in the guide tubes in order to mitigate tube wear.

A detailed discussion of the design of the sleeves and its effects on reactor operation is contained in Reference 4.

4.3 Thermal Oesign Using the FATES model (Reference Sj, the thermal performance or the various types of fuel assemblies has been evaluated ~i th r'espect to their Cyc'.es l, 2, and 3 burnups, proposed burnups during Cycle 4, their respective fuel geometries, and expected flux levels during Cycle 4, The Oatch E fuel has be n deternined to be the limiting fuel batch viith respect to stored energy.

Ournuo dependent ruel performance calculations were used in ECCS ruel per'ormance calculations perrorr,ed in Section 8, ECCS Analysis.

C Chemical Oesign he metallurgical requirements of the fuel cladding and the uel assembly structural members for the Batch F. fuel have not been changed from the original Cycles l, 2, and 3 designs. Thererore, the chemical or metallurgical performance of the Batch F fuel Mill be unchanged from that of the original core fuel and discussions in the FSAR, Reference 6, are still val id.

0.5 Onera ting Experience ruel assemblies incorporating the same design features as the St. Lucie Unit l, Oatch F fuel assemblies have had operating experiences at Calvert Cliffs l and 2, Fo! t Calhoun l, Hillstone I(

and previous reload cycles for St. Lucie-l. The opera ting experience has oeen successful with the implementation oT stainless steel sleeyes to mi-'.igate the CV guide tube wea>>, problem as discussed in Section 4,2,

5,0 NUCLEAR OESiGH 5.1 Physics Characteristics 5.1.1'uel Haiiagement The Cycle 4 fuel mana gement employs a mixed central region as described assemblies ','.

in Section 3, Fi'g ure 3-1.- . T he fresh 8atch F is comprised of two sets of each having a unique enrichment in order to minimize radial power peaking. Theree are 40 assemblies with an enrichment or 3.65 wt; U-235 and 48 assemblies wi.th an enrichment or 3 03 t" U-235 and 12 poison shims per.assembl y.. With 'his loading, the Cycle 4 burnup capacity for full power operation is expected to be between 14,300 HMO/T and 14,900 tlWO/T, depending on the final Cycle 3 termination point. The Cycle 4 core char t characterisiics have been examined ror Cycle 3 terminations between

' 'ror the safety analyses.

. 7250 and 8250 tlWO/T and limiting values es bl is ed 'a The loading oattern (se S ction 3} is applicable to any Cycle 3 temina-tion point between the stated xt. ames.

Physics characteristics including reac ivi"y coe co ricients for Cycle 4 f'y are listed in Tablea 5-1 along with the corresponding values from the reference cycle. Please note tha't the values of par amete. s actuall employed in safety analyses are different than those displayed in Table 5-1 and are tgp'icall c hosen to conservatively bound predicted values with accommodation for appropr'iate uncertainties and allowanc e s e Table 5-2 presents a summary of CFA shutdown worths and reac:ivity allowances ror Cycle 4 with a corn comparison to reference cycle data. Table 5-2 react't generally characterizes the changes in reactivity that h occur during a trip from full'ower with a corres ond-'sponding change in core parameters to the zero power state. tt is not intenended to represent any particular limiting AGO or accident, although the quantit sshown own as a "Required Shutdown 7~a.gin" represents the numerical value of the worth whic which isi applied to the hot zero power steam line break accident. For thee analysis or any specific acc;dent or ACQ,

conservative or ",most I imiting" values are used. The power dependent insertion limit (POLL) curve for Cycle 4 is shown in Figure S-..l The CEA group identification ranains the same as in the reference cycle. Table 5-3 shows the reactivity worths of various CEA groups calculated at full power conditions fog Cycle 4 and the reference. cycle.

5.1.2 Power Oi stribution Figures 5-2 through 5-4 illustrate the all rods out (ARO) planar radial power distributions at BOC 4, MOC 4 a'nd EOC 4 that are characteristic of the high burnup end of the Cycle 3 shutdown window. These planar radial- power peaks are characteristic of the major portion of the active core length between about 20 and 80 percent of the fuel height. The higher burnup end of ~he Cycle 3 shutdown window tends to increase the po~er peaking in this central reqion of the core.

c Figure 5-5 illustrates the olanar radial oower distribution within the upper 1,5 to 20 percent. of the core produced wi th the insertion of the first CKA regulating group, Hank 7. This power distribution, calculated at

,is oasea upon the low burnup end of the Cycle 3 shutdown window, providing an illustration of maximum power peaking expected for this configuration. Higher burnup Cycle 3 shutdown points tend to reduce power peaking in this upper region or the cor e with 8ank 7 inserted. It is a characteristic of both ARO and Hank 7 inserted conditions that the Cycle 4 peaks are highest near 80'C.

The radial power distributions described in this section are calculated data without uncer tainties or other allowances. However, single rod power peaking values do include the increased peaking that ls characteristic of fuel rods adjoining the water holes in the fuel assembly lattice. For both ON8 and kw/ft safety and setpoint analyses in either rodded or unrodded configurations, the power peaking, values actually used are higher than those expected to occur at any time during Cycle 4. These conservative values, which are used in Section 7 of this document. establish the allowable limits for power peaking to be observed during operation.

The range of allowable axial peaking is defined by the limiting conditions for operation of the'axial shape index (AS[). Within these AS[ limits, the necessary ONBR and kw/ft margins are maintained.

for a wide range of possible axial shapes. The maximum three-dimensional or total peaking factor anticipated in Cycle 4 during normal base load, all rods out operation at full power is 1.65 ~not including uncertainty allowances and augmentation factors.

5. 1.3 Safety Related Oata 5.1.3.1 Ejected CEA maximum reactivity worths and planai radial power peaks associated C'he with an ejected CEA event are shown in Table 5-4 for Cycle 4 and the reference cvcle. .The Cvcle 4 values encompass the worst conditions anticioated durino Cycle 4 and are safety analysis values, which are conservative with respect to the actual calculated. values.

5.1.3.2 Oropped CEA The limiting parameters o dropped CEA reactivi ty worth and maximum increase in radial peaking factor are shown in Table 5-5 for Cycle 4 pnd the. reference cvcle. The values shown for Cycle'4 are the safety analysis values, which are conservative with respect to the actual calculated values.

5.1.3.3 Scram Reactivity Scram reactivities are calculated using the space-time kinetics code F[ESTA described in Reference 13.

C 5.'l.g Augmentation Factors Augmentation facto s have been calculated for the Cycle 4 core using the calculational model described in Reference 5. The input information required for the calculation of augmentation factors that 's specific to, the core under consideration includes the fuel densification characteristics, the radial pin power distribution and the single gap peaking factors. Augmentation factors for the CCycle cl .4 core have been conservatively calculated by combining ror input the largest single gap peaking factors

'with the most conservative (flattest} radial pin power distribu-tron. The calculations yield non-collapsed clad augmentation factors showing a maximum value of 1.048 at the top of the core.

The calculated values were increased to create 'conservative augmenta-tion factors to b e used in the i'-core monitoring system. The

'I augmentation -actors used for Cyc1e 4 are compared to those or the reference cycle in Table 5-6.

5.2 PHYSICS AHALYSIS HETHQQS S.Z. 1 Un cer~aint'es in Measured Pointer Oistributions The power distribution measurement uncertainties which are applied to Cycie 4 ar :

Fq = 7.0 percent vihere iq = F xy X p z, local power dens i ty Fr' 6.0 percent C These values ar e to be usedu d ror moni tor ing po:;er di stribu tlon paramet r s during operation.

5.2. 2 i'luclear Qesign i'methodology Tne analyses have b n performed in th e same manner and with the same methodologies used For th refer ence cycle analyses exc pt for th<<se or the o, FiESTA (Reference 13)

TABLE 5-1 St. Lucie Unit 1 Cycle 4 Physics Characteristics Units Reference- ~C<le S C ale Oissolved Boron Dissolved Boron Content for Criticalit CEAs 'Aithdrawn Hot full power, equilibrium 850 1077 xenon, BOC Boron Worth Hot Full Power BOC PPH/5hp. 90 104

'ot Full Power EOC PPH/Xhp 80 83 Reactivi ty Coefficients CEAs Mithdr aun Moderator Temperature Coeffi-cients, Hot Full Power Beginning of Cycle (Equilibrium Xe) 10-4 ap/'F -0. Z 0.0 End or Cycle 10-4 ap/'F -1.8 -2.06 Doppler Coefficient Hot BOC Zero Power'ot 10"5 ap('F -1.44 -1. 64 BOC Full Power 10 6(F -1.13 -1.26 Hot EOC Ful 1 Power 10>>5 gp/'F -1. ZZ -1.39 Total Oelayed Neutron Fraction, aeff 8eginning of Cycle .0060 .0063 End of Cycle .0051 .0051 Neutron Generation Time BOC 10-6 sec 28 24 EOC 10-6 sec 33 29

T/,.2 5-2 St. Lucie Unit 1 Limiting Yalues of Cycle 4 CEA

. REACTr Yr TV WORTi<s nnO ALLOIIWCES, ahp DOC EOC Reference Cycl e Reload Cycle Reference Cycle Reload Cycle lforth Ava ilabl e*

Ilorth of all CEAs inserted 10. 5 9.4 ll;4 10.6 Stuck CEA allowance 2.7 2.4 3.1 2.9 Itort.h of all CEAs less highest worth 7.8 7.0 7.7 CEA stuck out ttortb Repaired Allowaoces)

Power defectHF,P to ll2P (Ooppler, Tavg, 1.7 1.9 2-2 2.4 redistribution)

Hoderator voids 0.0 0.0 0.1 0.1 CEA bite, boron deadband and maneuvering 0.5 0.6 0.6 band 0.6'.3 Required six tdown ttergin (Xhp) 4.3 3.3 4.3 Total reactivity required 5.6 6.7 6.2 7.4 Available IIorth Less Allowances Hargin available 2.2 0.3 2.1 0.3

For every accident or AOO considered in the safety analysis, a calculational uncertainty of 10K is deducted from the ~orth available.

d TABLE 5-3 A

ST. LUCIE UHtT l CYCLE 4 REACTIVITY WORTH OF CEA REGULATING GROUPS AT HOT FULL POWER,

<<Mo Be innin of C cle ~Ed dc Regu1 a ting Reference Reference CEAs ~Ce 1 e ~Cele 4 ~Ce1 e ~Cele 4

, Group T 0.78 0.57 0.84 0.80 Group 6 0.52 0.51 0.56 0.60 Group 5 0.39 0.32 0.46. 0.44

~d Note Yalues shown assume sequential group insertion.

TABLE 5-4 ST. LUCIE UNIT I CYCLE 4 CEA EJECTION DATA Limiting Value Reference Cycle Cycle 4 Safety Safet Anal sis Value Analysis Value Haximum Radial Power Peak full power with Bank 7 inserted; worst CEA ejected 3. 60 3.60 2ero power with Banks 74645 inserted; worst CEA ejected 8. 34 .9.40 Haximum E ected CEA l/orth Xhp)

Full power with Bank 7 inserted; worst CEA ejected .29 .28 lero power with Banks 7+64 5 inserted; worst CEA ejected .65 .63 Notes: l) Uncertainties and allowances are included in the above data .

2) The Cycle 4 safety analysis values are conserv"tive kith respect to the actual Cycle 4 calculated values.

TABLE 5-5 St. Lucie-1 Cycle 4 Full Length CEA Orop Oata Limiting Yalues Reference C cle ~cele s Minimum Morth ap .04 .04 Maximum Percent Increase in Radial Peaking Factor l7 Nates:

'l) CEAs are either fully withdrawn or fully inserted radial calculations.

for (2) These are Cycle 4 safety analysis values ~hich with respect to Cycle 4 calculated values.

are'onservative

TA8LE 5-6 St. Lucie Unit 1 Augmentation Factors and Gap Sizes

'for Cycle 4 and Referenc Cycle Refer ence C cl e Ccle4 Cor e Core Noncollapsed Gap Honcollapsed Gap Height Height Clad Augmen- Size Clad Augmen- Size

~Percent) ~)nches ) tation Fector ~Inch'es ) tation Factor ~)nenes )

98. 5 134. 1.058 2. 04 1.071 1.74 7'18.

86. 8 6 1.053 1. 80 1.067 1. 54 77.9 106. 5 1.050 '.62 1.063. 1 . 38

66. 2 90.5 1 .044 1.38 1.057 1.18 54.4 74.4 1. 038 1.14 1.050 0. 97 45.6 62.3 .1.033 0.96 1.045 0.82 33.8 46. 2 1. 026 0.?2 t.a3s 0.62 22.1 30. 2 1. 018 Q.48 1 .azs 0.41 13.2 18. 1 1. 013 0.30 1.017 0.26 1.5 2.0 1. 003 O.Q6 1.004 0.05

1) Values are based on approved model described in Reference 5.

2) The Cycle 4 in-core monitoring system values are conservative with resaect to the actual Cycle 4 calculated values.

a CA Q Pt CD CQ 8

1.00 I

0. 90 I CL I

I C) 0. 80

~l 0.70

~~l POWER DEPENDENT INSERTION LIMIT o-)

I 0. 60

'I 0.50 CV 0.40 ~)C)

QJ +l~

FJ o

~l~

C) 0.30 0.20 L+

0. 10 0

BANKS 0 20 40 60 80 100 6

Vo OF CEA INSERTION

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s ~

4

~

~ ~

~

I e I ~ ~

le I~

~ ~

THfMNL HYQRAUl.LC OESlGf(

I OflBR Analyses i Steady state OilGR analyses of Cycle 4 at the rated power level of 2700 ttwt have be n performed using the TORC computer code (Ref. 10) and the CK-1 critical heat flux corre1ation (Ref. 11).

Table 6-1 contains a list of pertinent thermal-hydraulic design parameters used for both safety analyses and for generating reacto~

protective system setpoint information. Also note, that the calculational factors (engine ring neat flux factor, engineering factor'nn hot channeI heat input and rod pitch, bowing and clad diameter factor) listed in Table 6-1 have been combined statistically with other uncertainty factorscd'.a.95/96 confidence!probabili.ty l.evel (Ref. 12) to define a new design limit on CE-1 minimum GNBR0.23)cqhen iterating on power as discussed in Ref, 12.

Investigations have been made to ascertain the effect of the C'A guide tuoe wear proolem and the sleeving repair on 0!RR margins as establ i shed by thi s type of anal ysi s. The findings were reported to the tiRC in Reference 4 which concluded. that the wear problem and the sleeving repair do not adversely affect OilBR margin.

fr>acts of Fuel Rod Bowing on OiIBR ttargin Effects of fuel rcd bowing on OilBR margin have been incorporated in the safety and sc:tpoint analyses in t;tie same manner as discussed in Reference 8. This re ercnce contains penalties on mininumi OilBR due to fuel rod bo;iing as a function of burnup 9 neratad using .')PC guidelines contained in Reference 9.

Table 6-1 St. Lucie Unit I Thermal-H draulic Parameters 'at Full Power Reference General Characteri s ti cs Uni t ~Cele 3 ~Cele 4 Tatal Heat Output (core only) 2560 2700 10'TU/ht 8737 9215 Fraction of Heat Generated in ,975 .975 Fuel Rod Primary System Pressure Nomina I psia 2250 2250 Minimum in steady s ate psia 2200 2200 Haximum in steady state psi a 2300 2300 Design InIet Temperature OF 544 549'70,000 Total Reactor Coolant Flow gpm 370,000 (minimum steady state) 106 lb/hr 140.2" 139,3>

Coolant Flow Through Cor 106 lb/hr 135.0" 134.10 Hydr aulic Diameter ft 0.044 0.044 (nominal channel)

Average Mass Velocity 06 lb/hr-ft 2. 53" 2. 51*

Pressure Orop Across Core psi 10. 3 10.4 psi (minimum steady state flaw irreversible ap over entire II fuel asse, bly)

Total Pressure Orop Across Vessel psi 33.5 33.6 psi (based on nominal dimensions t and miiiimum steady state ilaw),

Core Average Heat Flux (accounts for BTU/hr -ft 174,400 183,843 above fraction of heat generated in fuel rod and axial densification factor)

Total Heat Transfer Area (accounts for 48~860 48,872 axial densificatian factor)

~ ~ ~

Film Coefficient at Average Conditions

~

BTU/hr-ft F 5820 58ZO

~

Haximum Clad Surface Temperature aF '51 657 Average Film Temperature Oifference oF 31 33 Average Linear Heat Rate of Updensified -.

kw/ft S. 83 6.14 Fuel Rod (accounts for; above fraction of heat generated in fuel rod)

Average Core Enthalpy Rise BTU/lb 68.7*

'Calcula culated at design inlet temperature, nominal primary system pr ssure.

Table 6-1 (cont.) ~ ~

e~cul ational Factors Referenc

~Cele 3 ~Cele 4 0

Engineering Heat Flux Factor ~ 1. 03 1. 03 Engineering Factor on Hot Channel Heat Input

1.03 1 Inlet Plenum .'(onuni form Oistribution 1.05 .Hot applicable Rod Pitch, Bowing and Clad Oiameter** 1.065 1.065 Fuel Oensification Factor (axial) ~

1.01 1.002 Fuel Rod Bowing Augmentation Factor on Fr 1.018 1.018

Based on "Asbuilt" information.

- For cycle 4 these factors have been combined statistically with our uncertainty factors at 95/95 confidence/probability level (Ref. 12) to define a new design limit on CE-1 minimum OMBR when iterating on power as discussed in Reference 12.

1 REFEREilCES (Sections 1 through 6)

,~ CEN-79-P, "Reactor Operation with Guide Tube Ilear", February 3, 1978

2. Letter, Robert E. Uhrig (FPKL) to Victor Stello (NPC), dated February 22, 1979, "St. Lucie Unit 1 .Oocket No. 50-335 Proposed Ame'ndment to Facility Operati'ng License OPR-67"

3. CENP0-187, "CEPAll:method of Analyzing Creep Collapse of Oval Cladding",

June, 1975.

4. CEN-80(N)-P, "ttillstone Unit 2 Reactor Operation with Modified CEA Guide Tubes", February 8, 1978

5. CENP0-139, "C-E Fuel Evaluation i~fodel Topical Report", July 1, 1974

6. St. Lucie Nuclear Power Plant (Formerly Hutchinson Island) Unit One, Final Safety Analysis Report, in support of Oocket No. 50-335 7 ~ (fhere is no Reference 7)

8. Supplement 3-P (Proprietary) to CENPO 225P, "Fuel and Poison Rod 8owing",

June 1979

9. Letter from 0. B. Vassallo (NRC) to A. E. Scherer (C-E) dated June 12, 1978

'. CENP0-161-P, E "TORC Code, A Computer Code for Oetermining the Thermal Hargin or a Reactor Core", July 1975 ll. Critical Heat Flux Correlation for C-E Fuel Assemblies with Standard Spacer Grids Part 1, Uniform Axial Power Qistribution, CBtPO-162-P-A

. (Proprietary) and CEilPO-162-A (Ncn-Proprietary), April, 1975

12. CEN-124 (8)-P, "Statistical Combination of Uncertainties, Part 2",

January, 1960

13. CEN-122(F), "FIESTA", November, 1979.

~ '

7.0 TRAHSIEt)T ANALYSIS The purpose of this section is to present the results of Florida Power and Light St. Lucie Unit 1, Cycle 4 t<on-LOCA safety analysis at 2700 t1/Jt.

The Design Bases Events (DBEs) considered in the stretch power safety analyses are listed in Table 7-1. These events can be categorized in the following groups:

l. Anticipated Operational Occurrences for which the intervention of Reactor Protective System (RPS) is necessary to prevent exceeding Acceptable Limits.

2. Anticipated Operational Occurrences for which the intervention of the RPS trips and/or initial steady state thermal margin, maintained by Limiting Conditions of Operation (LCO), are necessary to prevent exceeding Acceptable Limits.

3. Postulated Accidents.

For all DBEs so indicated in Table 7-1, an explicit analysis was performed tn determine the conseauences of these events during stretch power operation.

A few events were not reanalyzed (See Table 7-1). These events are eliminated by Technical Specification restrictions.

TABLE 7-1 ST. LUCIE UNIT 1 CYGLE 4 DESIGN BASIS EVENTS CONSIDERED IN STRETCH POWER SAFETY ANALYSIS Anal sis Status 7.1 Anticipated Operational Occurrences for which intervention of the RPS is necessary to prevent exceeding acceptable limits:

7.1.1 Boron Dilution "

Reanalyzed 7.1.2 Startup of an Inactive Reactor Coolant Pump Not Reanalyzed 7.1.3 Excess Load Reanalyzed 7.1.4 Loss of Load Reanalyzed 7.1.5 Loss of Feedwater Flow Reanalyzed 7.1.6 Excess Heat Removal due to Feedwater Malfunction Reanalyzed 7.1. 7 Reactor Coolant System Oepressurization Reanalyzed 1

7.1.8 Control Element Assembly Withdrawhl Reanalyzed 7.1. g Loss of Coolant Flow Reanalyzed 7.1.10 Loss of AC Power Reanalvzeh 7.1.11 Transients Resulting from the Malfunction of One Reanalyzed Steam Generator3 7.2 Anticipated Operational Occurrences for"which RPS tri'ps and/or sufficient initiat steady state thermal margin, maintained by the LCOs, are necessary to prevent exceeding the acceptable limits:

7.2. 1 Control Element Assembly Withdrawal Reanalyzed 7.2.2 Loss of Coolant Flow Reanalyzed 7.2.3 Loss of AC Power Reanalyzed 7.2.4 Full Length CEA Drop Reanalyzed 7.2.5 Part Length CEA Drop Not Reanalyzed 7.2.6 Part Length CEA Malpositioning Not Reanalyzed 7.2.7 Transients Resulting from the Malfunction of One Reanalyzed Steam Generator 7.3 Postulated Accidents:

7.3.1 CEA Ejection Reanalyzed 7.3.2 Steam'ine Rupture Reanalyzed 7.3.3 Steam Generator Tube Rupture Reanalyzed 7.3.4 Seized Rotor Reanalyzed 1

Requires High Power and Variable High Power trip; event is discussed in Section 7.2.

2 Requires Low Flow trip 'vent is discussed in Section 7.2.

3 Requires hP across ,the Steam Generator Trip; event is discussed in Section 7.2.

7.1 ANTICIPATED OPERATIONAL OCCURRENCES FOR HHICH THE RPS ASSURES NO VIOLATION OF 'LIMITS The events in this category were analyzed for stretch power operation of Florida Power and Light St. Lucie Unit 1, Cycle 4 to determine that Acceptable Limits on DNBR, CTt1, Reactor Coolant System (RCS) upset pressure, and 10CFR100 site boundary dose rate guidelines will not be exceeded.

Each of the event writeups in the section identifies which criterion the event in question addresses. Protection against violating these limits will continue to be assured by the Reactor Protection System (RPS)

Limiting Safety System Settings (LSSS) setpoints. The setpoints will be modified (as necessary) to include chanqes necessitated by the results of the stretch power analyses of these events. The methodology used to generate the Limiting Safety System Settings (LSSS) for the THlLP and ASI RPS trips is discussed in CEN-123 (F)-P, (Refer ence 14).

For those events in this section where ONBR or CTH values were calculated and quoted, the calculations were performed using the nominal values of key NSSS parameters listed in Table 7.2. Uncertainties were accounted for in determining the values of DNBR or CTt4 by applying appropriate values of aggregate uncertainties identified in CEN-123 (F)-P to the limiting rod power. For those events analyzed to determine that the RCS upset pressure limit or 10CFR100 dose limits are not exceeded, the methods used are the same as previously reported in the FSAR or subsequent reload licensing submittals. Effects of NSSS parameter uncertainties on these limits are not assessed statistically. Instead, applicable uncertainties are to occur simultaneously in the most adverse direction. When values'ssumed of the NSSS parameter used in evaluation of the RCS pressure and dose limits differ from those given in Table 7.2, they will be specifically noted.

The results of the analyses are provided in the following sections.

7.1.1 BORON DILUTION EVENT The Boron Dilution event was reanalyzed for Cycle 4 to determine if sufficient time is available for an operator to identify the cause and to terminate an approach to criticality for all subcritical modes of operation. It is also analyzed to establish corresponding shutdown margin requirements for modes 3 through 5 as they are defined by the Technical Specifications.

An inadvertent boron dilution adds positive reactivity, produces power and temperature increases, and during operation at power (for mode 1 and

2) can cause an approach to both the DNBR and CTN limits. Since the TH/LP trip system monitors the transient behavior of core power level and core inlet temperature at power, the TM/LP trip will intervene, if necessary, to prevent the DNBR limit from being exceeded. for power increases within the settino of the Variable High Power Level trip. For more rapid power excursions the Variable High Power Level trip initiates a reactor trip. The approach to the CTt1 limit ~s terminated by either the Local Power Density trip, Variable High Power Level trip, or. the DNBR related trip discussed above. The trip which is actuated depends on the rate of reactivity resulting from the dilution event. For a boron dilution initiated from hot zero power, critical, the power transient resulting from the slow reactivity insertion rate is terminated by the Variable High Power Level trip prior to approaching the limits.,

Table 7.1.1-1 compares the values of the key transient parameters assumed in each mode of operation for Cycle 4 and the reference cycle. The conservative input data chosen consists of high critical boron concentrations and low inverse boron worths. These choices produce the most adverse effects by reducing the calculated time to criticality. The time to criticality was determined by using the following expression:

C

= ln Initial

~tcrit ~BD cri t where outcr,.t = Time interval to dilute to critical

= Time constant BD crit = Critical boron concentration (ppm)

Initial = Initial boron concentration (ppm)

Table 7.1.1-2 compares the results of the analysis for Cycle 4 with those

~

for Cycle 2. The key results are the minimum times required to lose prescribed negative reactivity in each operational mode. As seen from Table 7.1.1-2, sufficient time exists for the operator to initiate appropriate action to mitigate the consequences of this event.

TABLE 7.1.1-1 KEY PARNIETERS ASSUHEO IH THE GOROf) OILIITIOH AtlALYSIS Reference

~Cc1 e* ~Cela 4 Critical Boron Concentration, PPN (All Rods Out,'Zero Xenon)

P Power Opera ti on (fiode 1) 1200 1330

< Startup (Node 2) 1300 1420 Hot Standby (Node 3) 1300 1420 Hot Shutdovn (trode 4) 1300 1420" Cold Shutdown (Hode 5) 1300 1420 Refueling (Hode 6) 1200 1280 Inverse Boron i!orth, PPH/"hp Power Operation 70 95 Startup 65 90 '.

Hot Standby 55 70 Hot Shutdown 55 70

'old Shutdown:i> '55 70 Refuelinq. 55 ~

70 tNnimum Shutdown ltargin Assumed, "4tIp Power Operation Startup 303 -'4. 3 Hot Standby 31 3 -4.3 Hot Shutdown 3~3 -4.3 Cold Shutdown <<1.0 -2.0 Refueling -9.45 -6.28

" 'ycle 2 - l as t de ta i 1 ed analysis presented

TAOLE 7.1 ..1-2 RESULTS OF T}lE BORON'( DILUTt0t) EVE!)T.

Criterion For t)inimum Time to Lose Time to Lose Prescribed Shutdown Prescribed Shutdown Node )lar in (l')in)

~Cele 2 ~Cele e Startup 128..9 15

)!ot Standby 69.3 '02.8 15

)lot Shutdovm 102. 8 Cold Shutdown .22.6 25.0 Refueling 56e0 46,5 30

7.1.2 STARTUP OF AN INACTIVE REACTOR COOLANT PUMP EVENT The Startup of an Inactive Reactor Coolant Pump event was not analyzed for Cycle 4, stretch power operation because the Technical Specifications do not permit operation at power (modes 1 and 2) with less than 4 Reactor Coolant pumps operating.

7.1.3 EXCESS LOAD EVENT The Excess Load Event was reanalyzed to deternine that the DNBR and CTM design limit are not exceeded during Cycle 4.

The high power level and Thermal Margin/Low Pressure (TM/LP) trips. provide primary protection to prevent exceeding the DNBR limit during this event.

Additional protection is provided by other trip signals including high rate of change of power, low steam generator water level, and low steam qenerator pressure. In this analysis, credit is taken only for the action of the high power trip in the determination of the minimum transient DNBR, since this delays the reactor trip and allows the greatest change in ONBR. The approach to the CTM limit is terminated by either the Local Power Density trip, Variable High Power Level trip or the ONB related trip discussed above.

As presented in the FSAR, the most limiting load increase events at full power and at hot standby are due to the complete opening of the steam dump and bypass valves. Of these two events only the full power case is analyzed since it is the more limiting (i.e., approaches closer to the acceptable ONBR limit) case.

The Excess Load event at full power was initiated at the condigions given in Table 7.2. A floderator Temperature Coefficient of -2.5X10 Lp/F was assumed in this analysis. This MTC, in conjunction with the decreasing coolant inlet temperature, enhances the rate of increase of he'at flux at the time of reactor trip. A Fuel Temperature Coefficient (FTC) corresponding to beginning of cycle conditions with an uncertainty of 155 was used in the analysis since this FTC causes the least amount of negative reactivity change for mitigating the transient increase in core heat flux. The pressurizer pressure control system was assumed to be inoperable because this minimizes the RCS pressure during the event and therefore reduces the calculated ONBR. All other control systems. were assumed to be in the manual mode of operation and have no impact on the results of this event.

The Full Power Excess Load event results in a high power trip at 7.8 seconds.

The minimum ONBR calculated for the event at the conditions specified is 1.54 compared to the design limit of 1.23. The maximum local linear heat generation rate for the event is 18.3 KH/ft compared to the design CTM limit of 21.7 KM/ft (steady state linear heat rate to fuel centerline melt). Table 7.1.3-1 presents the sequence of events for this transient.

Figures 7.1.3-1 to 7.1.3-5 show the NSSS parameters for power, heat flux, RCS temperatures, RCS pressure, and steam generator pressure.

For the complete opening of the steam dump and bypass valves at hot standby conditions the minimum transient DNBR would be greater than 2.0.

The results of the Excess Load event demonstrate that with intervention of the RPS trips, the acceptable ONBR and CTM limits will not be violated.

TABLE 7.1.3-1 SEQUENCE OF EVENTS FOR THE EXCESS LOAD EVENT AT FULL POWER TO CALCULATE MINIMUM DNBR h

~Time Sec Event Set oint or Value 0.0 Complete Opening of Steam Dump and Bypass Valves at Full Power 7.8 High Power Trip Signal 110% of full power generated 8e2 Trip Signal Reaches CEA Holding Coil 8.7 CEA's Begin to Drop Into Core 9.1 Maximum Power 113e6 9.1 Maximum Local Linear Heat Rate Occurs, KW/ft 18.3 9.6 Minimum DNBR Occurs 1.54 Note: The Reference Cycle for this event is the FSAR.

120 100 CD 80

'O LL

~O

((

60 F C) I Q

C) 40 20 0 '.

0 10 20 30 40 TIME, SECONDS FLORIDA EXCESS LOAD EVENT Figure POWER 8 LIGHT CO.

St. Lucie Plant CORE POWER vs TIME Unit 1 7.1.3-1

120 100 80 C4 C)

@0 60 40 C)

CD 20 0 10 20 30 40 TIME, SECONDS FLORIDA Figure POV/ER 8 LIGHT CO. EXCESS LOAD EVENT St. Lucie Plant CORE AVERAGE HEAT FLUX vs TIME 7.1.3-2 Unit 1

620 600 590 OUTLET CO

~" 580 570 e 560 AVERAGE 550

'40 530 INLET 520 510 500 0 10 20 30.

TIME, SECONDS FLORIDA Figure POWER 8 LIGHT CO. EXCESS LOAD EVENT St. Lvcie Plant RCS TEMPERATURES vs TIME Unit I 7.1.3-3

2300 2200

0 2100 2000

. 1900 1800 170 10 20 30 40 TIME, SECONDS FLORIDA Fiqure

'OVIER 8 LIGHT CO, EXCESS LOAD EVENT St, Lucia Plant RCS PRESSORE vs TIME Uiiit 1 7.1.3-4

1Q50 900 750 600 CC C)

CC C9 450 300 150 0

0 1Q 20 . 30 40 TIME, SECONDS rLORloA Figure POWER 8 LIGHT CO. EXCESS LOAD EVENT St. Lucia Plant STEAM GENERATOR PRESSURE vs TIME Unit 1 7. 1. 3-.5

7.1.4 LOSS OF L'OAO EVENT The Loss of Load event was reanalyzed to determine that the ONBR limit and the RCS pressure upset limit of 2750 psia are not exceeded during Cycle 4.

The assumptions used to maximize RCS pressure dur ing the transient are:

a} The event is assumed to result from the sudden closure of the turbine stop valves without a simultaneous reactor trip. This assumption causes the greatest reduction in the rate of heat removal from the reactor coolant system and thus results in the most rapid increase in primary pressure and the closest approach to the RCS pressure upset limit.

t b) The steam dump and bvpass system, the pressurizer'spray system, and the power operated pressurizer relief'alves are assumed not to be operable. This too maximizes the primary pressure reached during the transient.

The Loss of Load event was initiated at the conditions shown in Table 7.1.4-1. The combination of'arameters shown in Table 7.1.4-1 maximizes the calculated peak RCS pressure. As can be inferred from the table, the key parameters for this event are the initial primary and secondary pressures, the moderator and fuel temperature coefficients of reactivity.

The methods used to analvze this event are identical to those described in the FSAR except TORC/CE-1, rather than COSNO/'H-3, was used to calculate ONBR's.

The initial core average axial power distribution for this analysis was assumed to be a bottom peaked shape. This distribution is assumed because it minimizes the negative reactivity inserted during the initial portion of the scram following a reactor trip and maximizes the time requited to mitigate the pressure and heat flux increases . The tioderator Temperature Coefficient (MTC) of >.5X10-4'/'F was assumed in this analysis. This tiTC in conjunction with the increasing coolant temperatures, enhances the rate of change of heat flux and the pressure at the time of reactor trip. A Fuel Temperature Coefficient (FTC) corresponding to beginning of cycle conditions was used in the'analysis, This FTC causes the least amount of negative reactivity feedback to mitigate the transient increases in both the. core heat flux and the pressure. The uncertainty on the FTC used in the analysis is shown in Table 7.1.4-1. The lower limit on RCS pressure is used to maximize the rate of initial change of pressure, and thus peak pressure, following trip.

The Loss of Load event, initiated from the conditions given in Table 7.1.4-1, results in a high pressurizer pressure trip signal at 7.7 seconds. At 11.0 seconds, the primary pressure reaches its maximum value of 2572 psia.

This compares to an FSAR value of 2513 psia. The increase in secondary pressure is limited by the opening of the main steam safety valves, which open at 5.1 seconds. The secondary pressure reaches its maximum value of 1057 psia at 11.2 seconds after initiation of the event.

The event was also analyzed with the initial conditions listed in Table 7.2 to demonstrate that the acceptable ONBR limit is not violated. The minimum transient OflBR calculated for the event is 1.48 as compared to the design limit of 1.23.

Table 7.1.4-2 presents the sequence of events for this event. Figures 7.1.4-1 to 7.1.4-5 show the transient behavior of power, heat flux, RCS coolant tenperatures, the RCS pressure, and the steam generator pressure.

The results of this analysis demonstrate that the Loss of Load event will not produce ONBR's or peak RCS pressures which exceed the DNBR limit or the upset pressure limit.

TABLE 7.1.4-1 KEY PARAMETERS ASSUMED IN THE LOSS OF LOAD ANALYSIS TO MAXIMIZE CALCULATED RCS PEAK PRESSURE Reference*

Parameter Units ~Cc1 e ~Cele 4 Initial Core Power Level MWt 2611. 2754 Initial Core Inlet Coola'nt Temperature oF 544 551 Core Coolant Flow X10 ibm/hr 134.9 138.3 Initial Reactor Coolant System Pressure psia 2250 2200 Initial Steam Generator Pressure psia 848 820 Moderator Temperature Coefficient X10 hp/'F +.5 +.5 Doppler Coefficient Multiplier .85 .85 CEA Worth at Trip 'f.hp -2.4 -4.7 Time to 90K Insertion of Scram Rods sec 3.0 3.1 Reactor Regulatinq System Operating Mode Manual Manual Steam Dump and Bypass System Operating Mode Inoperative Inoperative

FSAR

TABLE 7.1.4-2 SE(UENCE OF EVENTS FOR THE LOSS OF LOAD EVENT'O HAXIHIZE CALCULATED RCS PEAK PRESSURE Time sec Event Set oint or- Value 0.0 Loss of Secondary Load 5.1 Steam Generator Safety Valves 1010 psia Open 7.8 High Pressurizer Pressure Trip 2422 psia Signal Generated 9.0 Pressurizer Safety Valves Open 2500 psia 9.2 CEAs Begin to Drop Into Core 11.0 Maximum RCS Pressure 2572 psia 11.2 Naximum Steam Generator Pressure 1057 psia 13.5 Pressurizer Sal'ety Valves are 2500 psia Fully Closed

120 110 100 90 5 80 70 C4 60 50 C) 40

.C)

~ 30 20 10 0

0 80 120 160 200 TIME, SECONDS LOSS OF LOAD EVENT Figure FLORIDA

POWER 8 LIGHT CO. 7.1.4-1 CORE POWER vs TIME St. Lucie Plant

120 110 100 90 80

~ 70 60 oc g0 30 20 10 0

0 80 120 160 200 TIME, SECONDS LOSS OF LOAD EVENT Figure FLORIDA POWER 8 LIGHT CO. CORE AVERAGE HEAT FLUX vs TIME 7.1.4-2 St. Lucie Plant

630 620 610 5 600 OUT

~ 590

~ 580

~ 570 AVERAGE

~~ 560

~ 550 530 0 80 120 ~ 160 200

-TIME, SECQNOS LOSS OF LOAO EVENT Figure FLORIDA POWER 8 LIGHT CO.

St. Lucie Plant REACTOR COOLANT SYSTEM tEMPERATURE vs TIME 7.1.4-3

2700 2600 2500

~ 2400 m" 2300 cn 2200 cn 2100 2000 1900 1800 1700 0 80 120 160 200 TIME, SECONDS FLORIDA LOSS OF LOAD EVENT Figure POWER 8 LtGHT CO.

St. Lucie Plant REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.1.4-4

1080 1040

~ 1000 960

~~- 920 880 800 80 120 160 200 TIME, SECONDS figure f LOR!DA LOSS OF LOAD EVENT POWER 8 LlGHT CO.

St. Lucie Plant STEAM GENERATOR PRESSURE vs TIME 7.1.4-5

7.1.5 LOSS OF FEEDWATER FLOW EYENT The Loss of Feedwater Flow event was reanalyzed to determine that the ONBR limit and RCS upset pressure limit of 2750 psia are not exceeded during Cycle 4. In addition, the event was analyzed to demonstrate that the water inventory remaining in the steam generators following trip is sufficient to provide at least,ten minutes for the operator to initiate auxiliary feedwater before steam generator dryout occurs.

The analysis was performed assuming an instantaneous reduction in main feedwater flow to the steam generators without a corresponding reduction in steam flow. The result of this mismatch is a reduction of the steam generator liquid inventories.

The initial conditions presented in Table 7.'1.5-1 were used to analyze the event to demonstrate that the RCS upset pressure limit is not exceeded.

Initiating the event from the conditions presented in Table 7.1.5-1 results in a high pressurizer pressure trip at 28.8 seconds. Low initial RCS and steam generator pressures lead to the maximum rate of change of pressure and thus a higher overshoot following trip. Since the goal was to maximize the calculated RCS pressure, no credit was taken for the low steam generator water level trip which would have occurred earlier.

The pressurizer pressure reached a maximum value of 2506 psia at 32.8 seconds.

The sequence of events is given in Table 7.1.5-2. The transient behavior of core power, core'verage heat flux, RCS coolant temperatures and RCS pressure are presented in Figures 7.1.5-1 to 7.1'.5-4.

The initial conditions listed in Table 7.1.5-3 were used to analyze the event to demonstrate that at least 10 minutes are available to the operator to initiate auxiliary feedwater flow before steam generator dryout occurs. The steam dump and bypass valves, the pressurizer spray svstem, and the. pressupi'zer relief valves were assumed to be in operation since this maximizes the steam flow from the steam generators and the rate of decrease of the water inventory in the steam generators. An

=

inoperative pressurizer sp~ay system and relief valves could potentially lead to an earlier reactor trip on high pressurizer pressure. An initial secondary pressure of 893 psia was also assumed tn maximize steam releases from the steam generators via the secondary 'safety valves. The analysis shows that a reactor trip on low steam generator level occurs at 12.8 seconds. This corresponds to a water level which is 60 inches below the normal operating level. The analysis shows that the water remaining in the stean generators following trip is sufficient to provide at least 15 minutes for the operator to initiate auxiliary feedwater. Figure 7.1.5-5 presents the water inventory in the steam generators as a function of time.

The event was also analyzed with initial conditions listed in Table 7.2 to demonstrate that the acceptable ONBR limitwill not be exceeded. The minimum transient ONBR calculated for the event is 1.53 as compared to the design ONBR limit of 1.23.

TABLE 7.1;5-1 KEY PARAMETERS ASSUHED IN THE LOSS OF FEEDWATER FLOW ANALYSIS TO MAXIMIZE CALCULATED RCS PEAK PRESSURE Reference*

Parameter Units ~Ccl e ~Cele 4 Initial Core Power Level MWt 2611 2754 Inlet Coolant Temperature oF 544 551 Core Mass Flow Rate X10 ibm/hr 134.8 )'38.3 Reactor Coolant System Pressure psia 2250 2200 Steam Generator Pressure psia 841 815 Moderator Temperature Coefficient X10 hp/'F

'.5 Dopp'ler Coefficient Multiplier .85 .85 Reactor Regulating System Operating Mode Manual Manual Steam Dump and Bvpass System Operating Mode Auto Inoperati ve**

Feedwater Regulating System Operating Mode Inoperative Inoperative~

Auxiliary Feedwater System 0'perating Hode Manual Manual Pressurizer Pressure Control System Operating Hode Auto Inoperative**

Pressurizer Level Control System- Operating Mode Auto Inoperative~

FSAR These modes of control system operation maximize the peak RCS pressure.

TABLE 7.1. -2 SEQUENCE OF EVENTS FOR LOSS'F FEHjÃ4TER FLQlf ANAL'(SIS TO MAXIMIZE CALCULATED RCS PEAK PRESSURE Time (sec Event Set oint or Value 0.0 Loss of Main Feedwater'igh 28.8 Pressurizer Pressure Trip 2422 psia Signal Generated 30.2 CEAs Begin to Drop into Core 30.9 Steam Generator Safety Valves 990 psia Begin to Open 32.4 Primary Safety Valves Begin 2500 psia to Open 32.8 Maximum RCS Pressure 2506 psia 36.0 Maximum Steam Generator Pressure 1046 psia

TABL'E 7;1.'5-3 KEY PARAt1ETERS ASSUMED IN THE LOSS OF FEEDWATER FLOW ANALYSIS TO t1IN01IZE CALCULATED.STEAM. GENERATOR DRYOVT TIME Reference*

Parameter U'nl ts ~Cele ~Cele 4 Initial Core Power Level N<t 2611 2754

. Ihlet Coolant Temperature oF 544 551 Coze Mass Flow Rate X10 ibm/hr 134.8 138.3 Reactor Coolant System Pressure psia 2250 2200 Steam Generator Pressure psia 841 893 Moderator Temperature Coefficient X10 hp/'F +.5 +.5 Doppler Coefficient Multiplier .85 .85 Reactor Regulating System Operating Mode Manual Manual **

Steam Dump and Bypass System Operating Mode Auto Auto Feedwater Regulating System Operating Mode Inoperative Inoperative ~

Auxiliary Feedwater System Operating Mode Manual Manual ~

Pressurizer Pressure Control System Operating Mode Auto Auto Pressurizer Level Control System Operating Mode Auto Auto *"

FSAR

- These modes of control system operation minimi,ze the steam generator dropout time,

120 110 100 90 80 8

70 C) 60 50 gC) 40 30

,20 10 0

0 10 20 30 50 TIME, SECONDS LOSS OF FEEDWATER FLOW EVENT Figure FLORIDA POWER 8 LIGHT CO. CORE POWER vs TIME 7.1.5-1 St. Lucie Plant

120 110 100 90

0 80 CD

70 C) e 60 X

50 1 i

Q cY 30 20 10 0

0 10 20 30 TIME, S ECONDS 50 0

LOSS OF FEEDWATER FLOW EVENT Figure FLORlDA POWF.R 8 l.lGHT CO. CORE AVERAGE HEAT FLVX vs TIME 7.1.5-2 St. Lucie Plant

650 CORE OUTLET 600 CORE AVERAGE CORE INLET

~~ 550

~ 500 CD 450 400 0 10 ZO 30 50 TIME, SECONDS Figure FLORIDA LOSS OF FEEDWATER FLOMI EVENT POWER 8 LIGHT CO.

St. Luci'e Plant REACTOR COOLANT SYSTEM TEMPERATURE vs TIME 7.1.5-3

2600

~ 2400

~ 2200 0- 2000 w 1800 1600 1400 0 10 20 30 50 TIME, SECONDS fLORIDA LOSS OF FEEDWATER FLOW EVENT Figure POWER 8 LIGHT CO.

St. Lucie Plant REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.1.5-4

140000 120000

~~ 100000

~0 80000 a 60000 Q 40000 20000 0

0 300 600 900 TIME, SECONDS Figure FLORIDA LOSS OF FEEDWATER FLOW EVENT POWER 8, LIGHT CO. 7.1.5-5 STEAM GENERATOR WATER MASS vs TIME St. Lucie Plant

7.1.6 EXCESS HEAT REMOVAL OUE TO FEEOllATER HALFUNCTION EVENT The Excess Heat Removal was reanalyzed to demonstrate that the ONBR limit is not exceeded during Cycle 4. The event is assumed to result from the instantaneous loss of the high pressure feedwater heaters which reduces the temperature of the main feedwater supplied to the steam generators and leads to increased heat extraction from the orimary coolant. The event has the same effect on the primary system as a small increase in turbine demand which is not matched by an increase in core power. The loss of the high pressure feedwater heaters is the most adverse feedwater malfunction event in terms of cooling action on the RCS. The analysis methods as well as the conclusions are the same as presented in the FSAR. The minimum transient CE-1 ONBR during the event is less limiting than the minimum transient CE-1 ONBR for the Excess Load event (see Section 7.1.3). Consequently the results of the Excess Heat Removal event are not presented.

7.1.7 RCS OEPRESSURIZATION EVENT The RCS Oepressurization event was reanalyzed for Cycle 4 to determine the pressure bias factor for the Tt1/LP trip setpoint.

The RCS Oepressurization event is one of the DBEs analyzed to determine the maximum pressure bias factor input to the Tti/LP trip. The methodology used for Cycle 4 is the same as that used for Cycle 3 and is described in References 2 and 14. The pressure bias factor accounts for margin degradation attributable to measurement and trip system processing delay times. Changes in core power, inlet temperature, RCS pressure and axial shape index during the transient are monitored by the Tti/LP trip directly. Consequently, with TH/LP trip setpoints and the bias term deternined in this analysis, adequate. protection will be provided for the Depressurization Event to prevent acceptable DNBR design limit from being exceeded.

The assumptions used to maximize the rate of pressure decrease and, consequently, the fastest approach to ONBR limits are:

1) The event is assumed to occur due to an inadvertent. opening of both pressurizer relief valves while operating at rated thermal power. This results in a rapid drop in the RCS pressure and, consequently, a rapid decrease in ONBR.

2) The initial axial power shape and the corresponding scram worth versus insertion used in the analysis is a bottom peaked shape.

This power distribution maximizes the time required to terminate the decrease in ONBR following a trip.

3) The charging pumps, the pressurizer heaters, and the pressurizer backup heaters are assumed to be inoperable. This maximizes the rate of pressure decrease and, consequently, maximizes the rate of approach tn the ONBR limit.

The analysis of this event shows that a pressure bias factor of 30.0 psia is required. This is greater than that input from other events. Hence, the use of the pressure bias factor determined by this event in conjunction with the TN/LP trip, will prevent exceeding the ONBR design limit for.

A00's which require TN/LP trip protection.

7.2 ANTICIPATED OPERATIONAL OCCURRENCES WHICH ARE DEPEHDBiT ON INITIAL OVERPOWER MARGIN'AND/OR RPS TRIPS FOR PROTECTION AbAIIIST'VIOLATIONOF'L'IHITS The events in this category were analyzed for stretch power operation of Florida Power and Light St. Lucie Unit'1, Cycle 4, to determine the initial margins that must be maintained by the Tech Spec LCO limits such that acceptable DNBR, CTH.and upset pressure limits will not be exceeded during any of these events. The initial marqin required to prevent the appropriate limits from beinq exceeded for any of these events was determined by analyzing them using the initial conditions specified in Table 7-2. These conditions were chosen to assure that sufficient initial overpower margin is available at the initiation of the most limiting AOO in this category. The method of generating Limitinq Conditions for Operation (LCO) is discussed in Reference 14.

As noted in Section 7.1, initial conditions used in the evaluation of upset pressure limit and dose rates may diffe~ from those given in Table 7.2, since for these limits the effects of HSSS parameter uncertainties are not combined statistically.

7.2.1 CEA WITHDRAWAL EVENT The CEA Withdrawal event was reanaIyzed for Cycle 4 to detemine the initial margins that must be maintained by the LCOs such that in conjunction with the RPS (Variable High Power Trip) the ONBR and fuel centerline to melt (CTH) design limits will not be exceeded.

As stated in CEN-126 (F)-P, (Reference 13), the CEA Withdrawal event is now classified as one for which the acceptable DHBR and centerline to melt limits are not violated by virtue of sufficient initial steady state thermal margin provided by the ONBR and Linear Heat Rate (LHR) related Limiting Conditions for Operations (LCO's). Depending on the initial conditions and the reactivity insertion rate associated with the CEA

'llithdrawal, either tlie 'Var'iable Hioh Power Level or Thermal Wargin/Low Pressure (Tt1/LP) trip, in conjunction with the initial steady state LCOs, prevents OHBR limits from being exceeded. An approach to the CTM limit is terminated by either the Variable High Power Level Trip or the Local Power Density Trip. The analvsis only took credit for the Variable High Power Trip to determine the required initial overpower margin for DNBR.

The zero power case was analyzed to demonstrate that acceptable ONBR and centerline to melt I~mits are not exceeded. For the zero power case, a reactor trip, initiated by the variable high power trip at 25K (15"

+ 10'~ uncertainty) of rated thermal power, was assumed in the analysis.

The kev parameters for the cases analyzed are reactivity insertion rate due to rod motion, moderator temperature feedback effects, and initial axial power distribution. The input values selected maximize the power increase and thus the margin degradation. The range qf reacti,yity insertion rates constdered tn tlie OnyI~i'.z'iz giyen i'n TybIe 7.2.1-1.

The values of other key parameters used tn the anqlysis of'his event're also presented in Table 7,2.1-1.

The zero power case ini'tiated at the limiting conditions of operation results in a minimum CE-I DHBR of 1.86, Also, the anqIysis shows that the fuel-centerline temperatures are well below those corresponding to the acceptable fuel centerline meIt limit, The sequence of events for the zero power case is presented in Table 7,2.1-2 Figures 7,2,1-1 to 7.2.1-4 present the transient behayior of core power, core average heat flux, RCS coolant temperatures, and the RCS pressure for the zero power case.

Protection against exceeding the DNBR limit for a CEA Withdrawal at full power is provided by the iiiitial steady state thermal margin wJitch ts maintained by adhering to the Tecfeical $ pecifications'COs on DHBR margin and by tlie response of'he RpS which proytdes qn automatic reactor tri.p on high power level. The minimum DHBR for thts event, when iiiitiated from the extremes of the LCgs, is I, 52 . The analysis shows th'at the fuel centerline temperatures are well below those corresponding to the acceptable CTtf Iimtt. The sequence of events for the full power case i's presented in Table 7.2.1-3. Ftgures 7.2,1-5 to 7,2.1-8 present the transient behavior of core power, core average heat flux, RCS coolant temperatures, and the RCS pressure for the full power case.

The event initiated from the Tech Soec LCOs (in conjunction with the Variable High Power Trip if required) will not lead to a ONBR or fuel temperature which exceed the ONBR and centerline to melt design limits.

TABLE 7-2 ST. LUCIE 1 CORE PARAtiETERS INPUT TO SAFETY ANALYSES FOR DNB AND CTM (CENTERLINE TO MELT) DESIGN LIMITS Reference Cycle 4 Ph sics Parameters Units C cle Values Values Radial Peaking Factors For DNB Margin Analyses (F )

Unrodded Region 1.59 1.65

Bank 7 Inserted 1.80 1.90 For Planar Radial Component (F )

of 3-D Peak (CMT Limit Analyses)

Unrodded Region 1.58 1.653 Bank 7 Inserted 1.82 1.90 j Maximum Augmentation Factor 1. 071 1.071 Moderator Temperature 10 hp/'F -2.5 ~ +.5 -2.5 + +.5 Coefficient Shutdown tiargin (Value assumed in -4.1/-3. 3 -5.1/~4.3 Zero Power SLB) (1 loop/2 loop)

Safet Parameters Power Level Mitt 2611 2700 Maximum Steady State Core Inlet DF 544 549

Temperature Minimum Steady State RCS psia 2200 '2225

Pressure Reactor Coolant Core Flow 10 lb/hr 134.9 '138;3" Negative Axial Shape Index LCO I ~ 23 - ~ 11*

extreme assumed at'ull Power Maximum CEA Insertion at 5 Insertion of 25 25 Full Power Bank 7 Maximum Initial Linear Heat Kl]/ft 16.0 16. 0 Rate for .transient other than L.OCA Steady State Linear Heat KH/ft 21.0 21.7 Rate to Fuel Centerline Melt CEA Drop Time from Removal sec 3.1 3.1 of Power to Holdino Coils to 90K Insertion For DNBR calculations, effects of uncertainties on these parameters were accounted 'for statistically.

- For CTti calculations, effects of uncertainties on these parameters are accounted for statistically. t<umerical values of these uncertainties and the procedures used in the statistical combination of uncertainties as they pertain to DNB and CTM limits are detailed in Reference 14.

TABLE 7.2.1-1 KEY PARAMETERS ASSUMED IN THE CEA WITHDRAWAL ANALYSIS Parameter Units Reference*

~Cc1 e ~Cele 4 Range of Initial Core Power Level MWt 0 - 1025 of 2560 - lOOX of 2700

,0 Core Inlet Coolant Temperature 532-544 532-549 Reactor Coolant System Pressure psia 2200 2225 Moderator Temperature Coefficient 10 hp/'F +.5 -2.5 to +0.5 Doppler Coefficient Multiplier .85 .85 CEA Worth at Trip - FP 10 hp -4.32 -4.70 CEA Worth at Trip - ZP 10 hp 3~3 -4.3 Range of Differential Rod Worth X10 hp/in 0 to -2.6 0 to -3.2 CEA Group Withdrawal Rate in/min -30 30 Holding Coil Delay Time sec 0.5 0.5 CEA Time to 90 Percent Insertion sec 3.1 3.1 (Including Holding Coil Delay)

Cycle 3

TABLE 7.2.1-2 SEQUENCE OF EVENTS FOR CEA WITHORAWAL FROM ZERO POWER Time Sec Event Set o1nt or Value 0.0 CEA Withdrawal Causes Uncontrolled Reactivity Insertion 26.8 High Power Trip Signal Generated 25K of 2700 MWt 27.2 Reactor Trip Breakers Open 27.7 CEAs Begin to Orop Into Core 27.8 Maximum Core Power 145$ of 2700 MWt 29.1 Maximum Heat Flux 60.8 of 2700 MWt 29.1 Minimum CE-1 DNBR 1.86 32.5 Maximum Pressurizer Pressure, psia 2397

TABLE 7.2.1-3 SEQUENCE OF EVENTS FOR CEA WITHDRAWAL FROM FULL POWER Time Sec Event Set oint or Value 0.0 CEA Withdrawal Causes Uncontrolled Reactivity Insertion 2.4 High Power Trip Signal Generated 110% of 2700 Mwt 2e8 Reactor Trip Breakers Open 3.3 CEAs Begin to Drop Into Core 3.6 Maximum Core Power 115.4~~ of 2700 MWt 4.1 Maximum Heat Flux 106.3 of 2700 HWt 4.1 Minimum CE-1 DNBR 1.52 Maximum Pressurizer Pressure, psia 2260

150 140 130 120 110 100 80 70 cc 50 40 30 20 10 0

0 20 40 60 80 100 TIME, SECONDS FLORtDA Figure POWER 8 LlGHT CO. CEA WITHDRAWALEVENT St. Lucie Plant CORE POWER vs TIME Unit 1 7.2. 1-1

120 110 100 8 90 80 70 60 50 40 30 20 10 0

0 20 40 60 80 100 TIME, SECONDS "FLORIDA Fiqure POWER 8l LIGHT CO. CEA WITHDRAWALEVENT St. Lvcie Plant CORE AVERAGE HEAT FLUX vs TIME Unit I 7.2.1-2

600 590 580 o

570 560 OOTLET 550 TAVERAGE

~

Q 540 CC 530 TINLET 520 510 500 0 .20 40 60 80 100 TIME, SECON.DS FLORIDA Figure POWER 8 LIGHT CO. CEA WITHDRAWALEVENT St. Lucie Plant REACTOR COOLANT SYSTEM TEMPERATURES vs TIME Unit I 7.2.1-3

2420 2400 2380 2360 2340 g 2320 a 2300 2280 2260 2240 2220 2200

, 40 60 80 100 TIME, SECONDS FLORIDA Figure POWER 8, LIGHT CO. CEA WITHDRAWALEVENT St. Lucie Plant

'nit 1 REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.2.1-4

120 110 100 90 8

8P C) 70 60 5p 40 30 20 10 0 I 0 10 20 30 40 50 60 70 80 90 100 TIME, SECONDS FLORIDA Figure POWER 8 LIGHT CO. CEA WITHDRAWALEVENT St. Lvcie Plant CORE POWER vs TIME 7.2.1-5 Unit I

120 110 100 90 80 C) 70 OC 60 5p 4p 30 20 10 0 10 20 30 40 50 60 70 80 90 100 TIME, SECONDS.

FLORIDA Fiqure POWER 8 LIGHT CO. CEA WITHDRAWALEVENT St. Lvcie Plant CORE AVERAGE HEAT FLUX vs TIME 7.2. 1-6 Unit I

610 590 ~

OUTLET L 580

~

570 ~ AVERAGE 560 g+ 550 540 INLET 530 520 510 500 0 10 20 30 40 50 60 70 80 90 100 TIME, SECONDS l'LOR iDA Figure POWER 8 LIGHT CO. CEA WITHDRAWALEVENT St. Lvcie Plant REACTOR COOLANT SYSTEM TEMPERATURES vs TIME 7.2.1-7 Unit l

~

)

~ g f ~

$ Q i ~ ~

7.2.2 LOSS OF COOLANT FLOW EVENT The Loss of Coolant flow event was reanalyzed for Cycle 4 to determine the minimum initial margin that must be maintained by the Limiting Conditions for Operations (LCOs) such thht in conjunction with the'PS (low flow trip), the DNBR limit will not be exceeded.

The methods used to analyze this event are consistent with those discussed in Reference 14.

The computer code TORC (Reference 5) was used for all DNBR calculations.

This is consistent with methods used by C-E, and approved by NRC, to calculate the DNB margin requirements.

The 4-Pump Loss of Coolant Flow produces a rapid approach to the DNBR limit due to the rapid decrease in the core coolant flow. Protection against exceeding the DNBR limit for this transient is provided by the initial steady state thermal margin which is maintained by adhering to th'e Technical Specifications'COs on DNBR margin and by the response of the RPS which provides an automatic reactor trip on low reactor coolant flow as measured by the steam generator differential pressure transmitters.

The transient is characterized by the flow coastdown curve given in Figure 7.2.2-1. Table 7.2.2-1 lists the key transient parameters used in the present analysis.

Table 7.2.2-2 presents the NSSS and RPS responses during a four pump loss of flow initiated at the most negative shape index (-.1 1) allowed by the DNBR related shape index LCO. The low flow trip setpoint is reached at .86 seconds and the scram rods start dropping into the core 1.15 seconds later. A minimum CE-1 DNBR of 1.23 is reached at 2.5 seconds.

Figures 7.2.2-2 to 7.2.2-5 present the core power, heat flux, RCS pressure, and core coolant temperatures as a function of time. Figure 7.2.2-6 presents a trace of hot channel DNBR vs. time for the limiting case that is characterized by an axial shape index = -.11.

The event initiated from the Tech Spec LCOs in conjunction with the Low Flow Trip will not exceed the design DNBR limit.

TABLE 7.2.2-1, KEY PARAMETERS ASSUMED IN THE LOSS OF COOLANT FLOW ANALYSIS Parameter Units Reference C cle* ~Cele 4 Initial Core Power Level MWt 2611 2700 Initial Core Inlet Coolant 549 Temperature.

Initial Core Mass Flow Rate 10 'bm/hr 134.9 138.3 Reactor Coolant System Pressure psia 2200 2225 Moderator Temperature 10 hp/f +.5 +.5 Coefficient Doppler Coefficient Multiplier .85 00*~

LFT Response Time sec 0.65 0.65 CEA Holding Coil Delay sec 0.5 0.5 CEA Time to 90% Insertion sec 3.1 3.1

( Including Holding Coil Delay)

CEA Worth at Trip (all rods out) 10 Lp 5 '1 ** -5.60*~

Total Unrodded Radial Peaking 1 70**

Factor (FT) r 4-Pump RCS flow Coastdown Figure 7.3-1 of Figure 7.2.2-1 Reference 1

'ycle 3 The most limiting of the allowed full insertion cases is used to establish LCO limits.

Since this is a second order effect and the most limiting doppler multiplier varies during the transient, a nominal value is used.

TABLE 7.2.2-2 SEQUENCE OF EVENTS FOR LOSS OF FLOW Ti~e (iSec Event Set oint or Value 0.0 Loss of Power to all Four Reactor Coolant Pumps 0.86 Low Flow Trip Signal Generated 934 of 4-Pump Flow 1.51 Trip Breakers Open 2.01 Shutdown, CEAs Begin to Drop into Core 2.5 Minimum CE-1 DNBR 1.23 5.26 Maximum RCS Pressure, psia 2326 I

1.0 4 PUMP COASTDOWN 0.8 C) 0.6 C) 0.4 C) 0.2 0

0 8 12 16 20 TIME, SECONDS FLORIDA Figure POWER 8 LIGHT CO. LOSS OF COOLANT FLOW EVENT St. Lvcie Plant CORE FLOW FRACTION vs TIME Unit 1 T.2.2-1

110 100 90 CD CD 70

~CI 60 50 0

40 CC 30 20 10 0

0 4 6 10 TIME, SECONDS FLORIDA LOSS OF COOLANT FLOW EVENT Fiqure POWER 8 LfGHT l O.

St.. Lucie Plant CORE POWER vs TIME Unit 1 7 2.2.2

110 100 90 80 70 C) 60 OC 50 40 30 20 10 0 4 6 10 TIME, SECONDS FLORIDA Figure POWER 8 LIGHT CO.

lOSS OF COOLANT FLOVI EVENT St. Lucie Plant Unit CORE AVERAGE HEAT FLUX vs TIME I

7.2. 2-3

630 620 610 OUTLET 600 590 580 AVERAGE 570 560 TINLET 550 540 530 0 4 6 10 TIME, SECONDS FLORIDA Fiqure POWER 8 LIGHT CO. LOSS OF COOLANT FLOVI EVENT St. Lvcie Pla'nt REACTOR COOLANT SYSTEM TEMPERATVRE vs TIME Unit 1 7.2.2-4

2330 r

2320 2310 2300 2290 2280 2270 2260 2250 2240 2230 2220 2210 0' 6 TIME, SECONDS FLORIDA fiqure POV/ER 8 LIGHT CO. LOSS OF COOLANT FLOW EVENT St. Lvcie Plant Unit 1 REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.2. 2-.5

2.2 2.0 I

1.8 CD f

C) 1.6 1.4 1.2 1.0 0 4 6 TIME, SECONDS FLORIDA Fiqure POWER 8 LIGHT CO. LOSS OF COOLANT FLOW EVENT St. Lucie Plant MINIMUMLOT CHANNEL CE-1 DNBR vs TIME IJnit 1 7.2. 2-6

7.2.3 LOSS OF ALL NON-EMERGENCY A-C POHER EVENT Identification of Cause The Loss of all Non-Emergency A-C Power event was reanalyzed for Cycle 4 to deterniine that the DHBR limit wi'll not be exceeded and the site boundary doses will not exceed the 10CFR109 guidelines.

The loss of non-emergency AC causes the loss of electrical power to the station auxiliaries such as the reactor coolant pumps and the main circulating water pumps. Under such circumstances, the plant would experience a simultaneous loss of load, loss of feedwater flow, and loss of forced reactor coolant flow.

The loss of all non-emergency power is followed by automatic startup of the emergency diesel generators. The power output of each diesel is sufficient to supply electrical power to all engineered safety features and to provide the capability of achieving and naintaining the plant in a safe shutdown condition.

Subsequent to reactor trip, stored heat and fission product decay heat must be dissipated. In the absence of forced reactor coolant flow, convective heat transfer through the core is maintained by natural circulation.

Initially, the residual water inventory in the steam generators is used and stean is released to the atmosphere via the steam generator safety valves.

Subsequent to the availability of standby power, auxiliary feedwater is manually initiated and plant cooldown is controlled via remotely-operated atmospheric steam dump valves.

Anal sis of Effects and Conse uences The site boundary dose analysis was performed with an initial power level of 2754 NNt and core inlet temperature of 551'F. The DNBR was evaluated usinq the same assumotions as given in Section 7.2.2. The following additional assumptions have been made for this transient:

A. At time zero, when all electrical power is lost to the station auxiliaries, the following assumptions are made:

1. The turbine stop valves close, and the area of the turbine admission valves is instantaneously reduced to zero;

2. The steam generator feedwater flow to both steam generators is instantaneously reduced to zero;

3. The reactor coolant pumps begin to coast down. Following coastdown, the coolant flow necessary to remove decay heat is maintained by natural circulation.

4. Emergency diesel generators start automatically after the loss of all non-emergency A-C power.

0

B. Manual action is taken to:

l. Initiate auxiliary feedwater flow 15 minutes subsequent to initiation of the event; .

2. Actuate the steam generator atmospheric steam dump valves 15 minutes subsequent to initiation of the event to initiate plant cooldown to 325'F; To determine the maximum possible radioactivity release associated with a loss of all non-emergency A-C power, the following additional assumptions are made:

l. A-C offsite power is not restored and action is initiated to put the plant in a cold shutdown condition;

2. The Reactor Coolant System specific activity equals the Technical Specification limit of 1.0 uCi/gm (I-131 Dose Equivalent Curies);

3. The secondary system specific activitv equals the Technical Specification limit of O.l pCi/gm (I-131 Dose Equivalent Curies);

4. The primary to secondary leak rate is the Technical Specification linit of 1 GPti (0.5 per steam generator).

5. Atmospheric steam release is required until the reactor coolant

'temperature is reduced to the point where shutdown cool-ing can be initiated at 325'F.

6. Cooldown is .undertaken at the maximum allowable rate of 100'F/Hr.

7. The shutdown cooling system is then employed to remove decay heat, terminating release of steam through the atmospheric dump valves.

All of these assumptions increase the total steam release calculated and thus maximize the predicted doses. In 'determining the site boundary dose, the thyroid and whoIe body doses were conservatively calculated. For the purpose of the thyroid dose calculation, it is assumed that all leakages and releases during a given period of time occur instantaneously at the end of the period. In addition, the concentration in the steam generators is based on the minimum liquid mass occurring during that period. In this analysis the major periods of time for radiological releases are:

0 -'2 hour accident condition;

l. 0 - 15 min - Releases from steam generator safety valves.

2. 15 - 120 min - Releases from atmoshperic steam dump valves and steam driven auxiliary feedwater pump turbine.

The concentration of I-131 in the steam generators was calculated by the following equation:

Concentration during period (Ci/lb)=

Initial Conc. (Ci/lb) + [Amount of activity leaked to steam generators assuming Tech Spec primary to secondary leak rate -',

minimum steam generator liquid mass during period].

The thyroid dose is then calculated using the following equation:

Dose (REM) = Concentration of I-131 (dose equivalent curie)

X amount of steam released X Steam Generator Partition Factor X Breathing Rate X the 0 - 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months atmospheric dispersion coefficient X dose conversion factor In determining the whole body dose, the major assumption made is that all noble gases leaked to the steam generators will be released to the atmosphere. The major periods of time for noble gas releases are the same as those indicated for the thyroid dose. Therefore, the whole body dose is calculated by the following equation:

Dose (REM) = 0.25 X average energy of betas and gammas per disintegration X primary coolant activity concentration X amount of primary to secondary leak during period X the 0 - 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months atmospheric dispersion coefficient The radiological release criterion for this analysis is that the 2-hour dose at the site boundary should not exceed 10CFR100 guidelines.

Table 7.2.3-1 shows the assumptions used in the site boundary dose analyses and Table 7.2.3-2 summarizes the assumptions used in the calculation of radiological release.

A Moderator Temperature Coefficient (MTC) of +.5X10 hp/'F was used in the analysis since this causes a positive reactivity change during the initial portion of the transient. This positive reactivity change results in a slight increase in the power level which maximizes the steam released through the steam generator safety valves. An end of cycle fuel temperature coefficient (FTC) was used since this FTC results in the slowest rate of change in the decay power. The slowest rate of change in decay power maximizes the steam released during the cooldown period.

Figures 7.2.3-1 to 7.2.3-5 show the NSSS response during the transient and Table 7.2.3-3 presents the Sequence of Events for this event. For the first few seconds of the transient, the Loss of All Non-Emergency AC Power event behaves like the complete loss of forced primary coolant flow event. Hence, the transient DNBR variation for this event is the same as that reported for the Loss of Flow event.

Table 7.2.3-4 lists the steam releases during a Loss of All Non-Emergency AC event. Based on the releases, the 0 - 2 hr site boundary doses are:

Thyroid (DEQ I-131) 0.6 1lhole Body (DEQ XE-133)

REM'7X10-3 REM

From the analysis it can be concluded that the loss of All Non-Emergency A-C power event, initiated at the conditions given in Table 7.2, would lead to a hot channel CE-1 DtfBR during the transient of not less than the design limit of 1.23. The radiological consequences for. this event are a small fraction of 10CFR100 guidelines.

TABLE 7.2.3-1 KEY PARAMETERS ASSUMED IN THE LOSS OF ALL NON-EMERGENCY AC POWER FOR THE DETERtiINATION OF. SITE BOUNDARY DOSES FSAR Cycle 4 Parameter 'Units Value Value Initial Core Power Level MWt 2611 2754 Core Inlet Coolant Temperature 551 6

Core Mass Flow Rate X10 ibm/hr 117.5 133,8 Reactor Coolant System Pressure ps1a 2250 2300*

Steam Generator Pressure ps1a 841 ' 909 Moderator Temperature Coefficient X10 hp/'F +.5 +.5 Doppler Coefficient Multiplier .85 CEA Worth at Trip -4.6 -5.3 Reactor .Regulating System Operating Mode tianual Manual Steam Bypass System Operating Mode Inoperative Inoperative Auxiliary Feedwater System Operating Mode Manual Manual

With the set of assumptions used to determine dose rates, these are limiting.

TABLE 7,2.3-2 ASSUMPTIONS FOR THE RADIOLOGICAL EVALUATION FOR THE LOSS OF ALL NON-EMERGENCY AC POWER Parameter Uut ta Value Primary to Secondarv Leak Rate GPH 1.0 Reactor Coolant System Volume (excluding Ft 9601.

Pressurizer)

Reactor Coolant System Haximum Allowable pCi/gm 1.0 Concentration (DE/ I-131)1 Steam Generator Maximum Allowable pCi/qm Concentration (DE/ I-131)<

1 Reactor Coolant System Maximum Allowable pCi/gm 100 Concentration of Noble Gases (DE( Xe-133)

E Steam Generator Par tition Factor 0.1 Atmospheric Dispersion Coefficient sec/H 8.55X10 Breathing Rate M /sec 3.47 X10 Dose Conversion Factor (I-131) REM/Ci 1.48 X 10 Tech Spec limits 0 - 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months accident condition

TABLE 7.2.3-3 SEQUENCE OF EVENTS fOR THE LOSS OF ALL NON-EMERGENCY A-C POWER

~Time Sec Event Set oint or Value 0.0 Loss of All Non-Emergency AC Power Oe86 Low Flow Trip Signal; X of 4 Pump Value 93.0 1.51 Trip Breakers Open 2.00 Steam Generator Safety Valves Start 990 psia to Open 2.01 CEAs Begin to Drop Into Core 6.4 Haximum Steam Generator Pressure 1034 psia 7.4 Maximum RCS Pressure 2534 psia 900.0 Operator Initiates Plant Cooldown by Initiating Auxiliary Feedwater and Remotely Opening the Atmospheric Dump Valves 900.0 Steam Generator Safety Valves Close 950 psia 9007 Shutdown Cooling Initiated RCS Average Temperature 325'F

TABLE 7.2.3-4 STEN. RELEASES DURING A LOSS OF ALL NON-EMERGENCY AC EVENT Inte rated Steam Releases Value Steam Release Through Safety Valves le63X10 ibm Steam Release Through Atmospheric Steam Dump Valves 5.90X10 lb01 and Feedwater Pump Turbines Atmospheric Dump Valves Total Amount of Steam Released OuNng 0 - 2 hr 7.53X10 ibm Total Amount of Steam Released Until Shutdown Cooling is 9.03X10 ibm Initiated (325'I:)

120 100 CD CD

.80 C)

~O 60 40 20 0

150 300 . 450 600 7.50 900 TIME, SECONDS FLORIDA LOSS OF NORMAL ON-SITE OFF-SITE Figure POWER 8, LIGHT CO.

St. Lucie Plant ELECTRICAL POWER E(/ENT CORE POWER vs TIME

.Unit 1 7.2. 3-1

100 80 CO 60 OC 40 CO 20 150 450 600 750 900 TIME, SECONDS FLORIDA LOSS OF NORMAL ON-SITE OFF-SITE Figure POWER 8, LIGHT CO.

St. Lucie Plant ELECTR ICAL POWER ENT Unit I CORE AVERAGE HEAT FLUX vs TIME 7 2.3-2

640 620 LJ 600 OUTLET 580 AVERAGE .

540 INLET 520 0 150 300. 450 600 750 900 TIME, SECONDS FLORIDA LOSS OF NORMAL ON-SITE OFF-SITE Figure POV/ER 8 LIGHT CO.

St. Lvcie Plant ELECTRICAL POV/ER 0/ENT Unit REACTOR COOLANT SYSTEM TEMPERATURES vs TIME I

?.2. 3-3

2600 2400 2200 2000 1800 1600 1400 0 150 300 450 600 750 900 TlME, SECONDS FLORIDA LOSS OF NORMAL ON-SiTE OFF-SITE Figure POWER 8 LIGHT CO.

St. Lucie Plant ELECTRICAL POWER EVENT Unit 1 REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.2. 3-4

1040 1030 1010

~, 1000

. 990

.Ri 980

'Jl 970 950 940 930 920 910 I I 900 0 150 300 450 600 750 900 TIME, SECONDS FLORIDA LOSS OF NORMAL ON-SITE OFF-SITE Figure POWER 8 LIGHT CO.

ELECTRICAL POVl ER St. Lvcie Plant Unit 1 STEAM GENERATOR PRESSURE vs TIME 7.2.3-5

7.2.4 FULL LENGTH CEA DROP EVENT The Full Length CEA Drop event was reanalyzed for Cvcle 4 to determine the initial thermal margins that must be maintained by the Limiting Conditions for Operation (LCOs) such that the DNBR and fuel centerline melt design limit will not be exceeded.

The methods used to analyze this event are consistent with those discussed in Reference 14.

Table 7.2.4-1 lists the kev input parameters used for Cycle 4 and compares them to the reference cycle values. Conservative assumptions used in the analysis include:

1. The most negative moderator and fuel temperature coefficients of reactivity (including uncertainties), because these coefficients produce the minimum RCS coolant temperature 'decrease upon return to 1005 power level and lead to the minimum DNBR.

2. Charging pumps and proportion'al heater systems are assumed to be inoperable during the transient. This maximizes the pressure drop during the event.

3. All other systems are assumed to be in manual mode of operation and have no impact on this event.

The event is initiated by dropping a full length CEA over a period of 1.0 second. The maximum increases in (integrated and planar) radial peaking factors in either rodded or unrodded planes were used in all axial regions of the core once the power returns to the initial level. Yalues of 16%

were assumed for these peak increases. The axial power shape in the hot channel is assumed to remain unchanged and hence the increase in the 3-0 peak for the maximum power is directly proportional to the maximum increase in radial peaking factor of 16~. Since there is no trip assumed, the peaks will stabilize at these asymptotic values after a few minutes as the secondary side continues to demand 100% power.

Table 7.2.4-2 presents the sequence of events for the Full Length CEA Drop event initiated at the conditions described in Table 7.2.4-1. The transient behavior of key NSSS parameters are presented in Figures 7.2.4-1 to 7.2.4-5.

The transient initiated at the most negative shape index LCO (-.1'1) and at the maximum power level allowed by the LCO, results in a minimum CF.-1 DNBR of 1.29. A maximum allowable initial linear heat generation rate of 17.9 Klf/ft could exist as an initial condition without exceeding the acceptable fuel centerline melt limit of 21.7 KW/ft durinq this transient.

This amount of margin is assured by setting the Linear Heat Rate related LCO's based on the more limiting allowable linear heat rate for LOCA.

The event initiated from the Tech Spec LCOs will not exceed the DNBR and centerline to melt design limits.

TABLE 7.2.4-1 KEY PARAMETEPS ASSUMED IN THE FULL LENGTH CEA DROP ANALYSIS Parameter Units ~lt

C1 4 Initial Core Power Level MMt 2611 2700 Core Inlet Temperature OF 549 Reactor Coolant System Pressure psia 2200 2225 Core Mass Flow Rate x10 ibm/hr .138.3

!moderator Temperature Coefficienf x10 -.hp/ F -2.5 -2.5

.oppler Coefficient Multiplier 1.15 1.15 CEA Insertion at Maximum Allowed ~ Insertion of Bank 7 25 Power Dropped CEA Morth g5p unrodded -. 10 w 04 PDIL -.04 - 04 Maximum Allowed Power Axial Shape -.21 Index at Negative Extreme uf LC0 Band Integrated and Planar Radial Peaking Unrodded Region 1.17 1 ~ 16 Distortion Factor Hank 7 Inserted Reqion 1.17 1.16

Cycle 2

SEQUENCE OF EVENTS FOR FULL LENGTH CEA OROP Time Sec)., Event Set oint or Value 0.0 CEA Begins to Orop into Core 1.0 CEA Reaches Full Inserted Position 100% Inserted 1 .2 Core Power Level Reaches Minimum and 91.7 of 2700 tiwt Begins to Return to Power due to Reactivity Feedbacks 150.0 Reactor Coolant System Pressure Reaches 2205 psia a Minimum Value 170.0 Core Inlet Temperature Reaches a Minimum Value 547.5 200.0 Core Power Returns to its Maximum Value 100>> of 2700 HNt 200.0 Hinimum ONBR is Reached 1.29

120 110 100 90 CO 70 C)

~O 60 CY-50 CL CC C) 30 20 10 0

0 20 40 60 80 100 120 140 160 180 200 TIME, SECONDS Figure FLORIDA FULL LENGTH CEA DROP POWER 8 LIGHT CO.

St. Lucie Plant CORE POWER vs TIME 7.2. 4-1

120.

110 100

~ 90

~ 80 CO 7p Cl'o 6p OC gp co 30 20 10 0

0 20 40 60 80 100 120 140 160 180 200 TIME, S ECONDS Figure FLORIDA POWER 8 LIGHT CO. FULL LENGTH CEA DROP St. Lucie Plant CORE AVERAGE HEAT FLUX vs TIME 7.2. 4-2

600 TOUTLET

~ 590

~ 580 AVERAGE

~ 570 C)

CD 560 g

550 INLEt' 20 40 60 80 100 120 140 160 180 200 TIME, SECONDS Figure FLORIDA POVIER 8 LIGHT CO. FULL LENGTH CEA DROP St. Lvcie Plant REACTOR COOLANT SYSTEM TEMPERATURES vs TIME 7.2.4-3

2260 2250 Cll

'240 2230 2220 g 2210 2200 2190 CD o 2180

~ 2170 2150 0 20 40 60 80 100 120 140 160 180 200 TIME, SFCONDS Figure

~ FLORIDA POVIER & LIGHT CO. FULL LENGTH CEA DROP St. Lucie Plant REACTOR COOLAMt SYSTEM PRESS URE vs TIME 7.2. 4-4

2.2 2.0 1.8

~~ 1.6

~~ 1.4 1.2 1.0 0 40 80 120 160 200 TIME, SECONDS FULL LENGTH CEA DROP Figure FLORlDA POWER & LlGHT CO. MINIMUMDNBR (CE-1) vs TIME 7.2. 4-5 St. Lucie Plant

7.2.5 PART LENGTH CEA OROP The Part Length CEAs have been removed; hence, this event was not analyzed.

7.2.6 PART LENGTH CEA tlALPOSITIONING The Part Length CEAs have been removed; hence, .this event was not analyzed.

7.2.7 AOO'S RESULTING FROM THE MALFUNCTION OF ONE STEAM GENERATOR The transients resulting from the malfunction of one steam generator were analyzed for Cycle 4 to determine the initial margins that must be maintained by the LCO's such that in'onjunction with the RPS (asymmetric steam generator protective trip) the ONBR and fuel centerline melt design limits are not exceeded. The methods used to analyze these events are consistent with those reported in Section 7.2.3 of Reference 2, except TORC/CE-1 was used insteadiof COSMO/W-3 to calculate the DNBR. In addition, the Asymmetric Steam Generator Protective Trip (ASGPT) replaces 1:aw steam generator level trip as the primary trip to mitigate this event.

A description of this addition to the RPS'is described in Section 9.0.

The four events which affect a single generator are identified below:

1. Loss of Load to One Steam Generator

2. Excess Load to One Steam Generator

3. Loss of Feedwater to One Steam Generator

4. Excess Feedwater to One Steam Generator Of the four events described above, ft has been detemined that the Loss of Load to One Steam Generator (LL/1SG) transient is the limiting asymmetric event. Hence, only the results of this transient are reported.

The event is initiated by the inadvertent closure of a single main steam isolation valve. Upon the loss of load to the single steam generator, its pressure and temperature increase to the opening pressure of the secondary safety valves. The intact steam generator "picks up" the lost load, which causes its temperature and pressure to decrease, thus causing the core average inlet temperature to decrease and enhancing the asymmetry in the reactor inlet temperature. In the presence of a negative moderator temperature coefficient this causes an increase in core power and radial peaking. Thus, the most negative value of this coefficient is used in the analysis. With this assumed sequence of events, the LL/1SG event results in the greatest asymmetry in core inlet temperature distribution and the most limiting DNBR for the transients resulting from the mal-function of one steam generator.

The LL/1SG was initiated at the initial conditions given in Table 7.2.7-1 at. a shape index =-.11.. A reactor trip is generated by the Asymmetric Steam Generator Trip at 2.5 seconds based on high differential pressure between the stean generators.

Table 7.2.7-2 presents the sequence of events 'for the Loss of Load to One Steam Generator. The transient behavior of key NSSS parameters are presented in Figures 7.2.7-1 to 7.2.7-5. The minimum transient DNBR calculated for this LL/1SG event is 1.42, as compared to the acceptable ONBR limit of 1.23.

A maximum allowable initial linear heat generation rate of 18.5 Kl</ft could exist as an initial condition without exceeding the acceptable fuel to centerline melt of 21.7 KW/ft during this transient. This amount of margin is assured by setting the Linear Heat Rate LCO based on the more limiting allowable linear heat rate for'OCA.

The event initiated from the extremes of the LCO in conjunction with the ASGPT protective trip will not lead to DNBR or centerline fuel temperatures which exceed the DNBR and centerline to melt design limits.

TABLE 7.2.7-1 KEY PARAMETERS ASSUMED IN THE ANALYSIS OF LOSS OF LOAD To ONE STEAM GENERATOR*

Reference Parameter Uence '~Cele ~Cele 4 Initial Core Power tilt 2611 2700 Initial Core Inlet Temperature 'F 544 549, Initial Reactor Coolant 2200 2225 System Pressure Moderator Temperature hp/'F -2.5X10 -2.5X10 Coefficient Doppler Coefficient 0.85 0.85 Multiplier

This event was not analyzed in the FSAR, but was evaluated in CENPD-199-P (Reference 2). Thus Reference 2 is the Reference Cycle.

TABLE 7.2.7-2 SEQUENCE OF EVENTS FOR LOSS OF LOAD TO ONE STFAM GENERATOR

~Time eec Event Set oint or Value 0.0 Spurious closure of a single main steam isolation valve 0.0 Steam flow from unaffected steam generator increases to maintain turbine power 2.5 ASGPT* setpoint reached (differential pressure) 175 psid 2.6 Safety valves open on isolated steam 1010 psia generator 3.0 signal generates signal to open

'SGPT dump and bypass valves to condenser and to trip turbine 3.4 Trip Breakers open 3.9 CEAs begin to drop into core 6.0 Minimum DNBR occurs 1.42 9.6 Maximum steam generator pressure 1063 psia

ASGPT - Asymmetric Steam Generator Protection Trip

120

. 110 100 90 80 70 8

60 C)

~ so CL 40 30 CD .

20 10 0

0 80 120 160 TIME, SECONDS LOSS OF LOAD/1STEAM GENERATOR EVENT Figure FLORIDA POWER 8, LIGHT CO. 7.2.7-1 CORE POWER vs TIME St. Lucie Plant

120 100 80 8

C)

@0 20 0

0 80 120 160 200 TIME, SECONDS Figure FLORIDA OF LOAD/ISTEAM GENE RATOR EVENT St. Lucie Plant'OSSCORE AVERAGE HEAT FLUX vs TIME POWER 8 LIGHT CO.

7.2.7-2

2200

~ 2100

~1

~2000

~

CD 1900 1800 1700 0 80 120 160 TIME, SECONDS FLOR1DA LOSS OF LOAD/1STEAM GENERATOR EVENT Figure POWER 8 LLGHT CO.

Sl. Lucie Plant REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.2.7-3

620 600

~ 580 AVERAGE

~ 560 OUTLET INLET 520 0 80 120 160 TIME, SECONDS LOSS OF LOAD/1STEAM GENERATOR EVENT Figure FLORIDA POWER 8, LIGHT CO. REACTOR COOLANT SYSTEM TEMPERATURE vs TIME 7.2. 7-4 St. Lucie Plant

0 g ~

y

~ g ~ ~ ~

Q

7.3 POSTULATED ACCIDENTS The events in this category were analyzed for stretch power operation of St. Lucie Unit 1,- Cycle 4 to ensure acceptable consequences. For these transients some amount of fuel failure is acceptable provided the predicted site boundary dose rates meet 10CFR100 guidelines.

The following sections present the results of the analyses.

7.3.1 CEA EJECTION EVENT The CEA Ejection event was reanalyzed for Cycle 4 to determine the fraction of fuel pins that exceed the criteria for clad damage.

The analytical method employed in the reanalysis of this event is the NRC approved Combustion Engineering CEA Ejection method which is described in CENPD-190-A, (Reference 8). As stated in the Cycle 2 license submittal, (Reference 7), results generated with th'is approved methodology are less conservative than the methods used and described in the FSAR.

The key parameters used in this event are listed in Table 7.3.1-1. With these key parameters, selected to add conservatism, th'e procedure outlined in Figure 2.1 of Reference 8 is then used to determine the average and centerline enthalpies in the hottest spot of the rod. The calculated enthalpy values are compared to threshold enthalpy values to determine the amount of fuel exceeding these thresholds. These threshold enthalpy values are (References 9, 10, and 11).

Clad Damage Threshold:

Total Average Enthalpy = 200 cal/gm Incipient, Centerline Melting Threshold:

Total Centerline Enthalpy = 250 cal/gm Fully Molten Centerline Threshold:

Total Centerline Enthalpy = 310 cal/gm To bound the most adverse conditions during the cycle, the most limiting of either the Beginning of Cycle (BOC) or End of Cycle (EOC) parameter values were used in the analysis. A BOC Doppler defect was used since it produces the least amount of negative reactivity feedback to mitigate the transient.

A BOC moderator temperature coefficient of +0.5X10 4hp/'F was used because a positive HTC results in postive reactivity feedback and thus increases coolant temperatures. An EOC delayed neutron fraction was used in the analysis to produce the highest power rise during the event.

The zero power CEA ejection event was analyzed assuming the core is initially operating at 1 MWt. At zero power, a Variable Overpower trip is conservatively assumed to initiate at 25'A (15Ã + 105 uncertainty) of 2700 MWt and terminates the event.

1 The full and zero power cases were analyzed, assuming the value of 0.05 seconds for the total ejection time, which is consistent with the FSAR and previous reload submittals.

Table 7.3.1-1 lists all the key parameters used in this analysis.

The power transient produced by a CEA ejection initiated at the maximum allowed power is shown in Figure 7.3.1-1. Similar results for the zero power case are shown in 7.3.1-2.

The results of the two CEA ejection cases analyzed (Table 7.3.1-2) show that the maximum total energy deposited during the event is less than the criterion for clad damage (i.e., 200 cal/gm). Also, an acceptably small fraction of the fuel reaches the incipient centerline melt threshold.

Consequently, no fuel pin failures occur.

TABLE 7.3.1>>1 KEY PARAMETERS ASSUMED IN THE CEA EJECTION ANALYSES Reference Cycle Parameter Units Cele 3 ~Cele 4 Full Power Core Power Level MMt 2754 2754 Core Average Linear. Heat KM/ft 6.29 6.43 Generation Rate at 2754 MNt Moderator Temperature 10 hp/'F +.5 +.5 Coefficient Ejected CEh Worth .29 .31 Delayed Neutron Fraction, 6 .0047 .0044 Post-Ejected Radial Power Peak 3.6 3.6 Axial Power Peak 1.39 1.35**

CEA Bank Worth at Trip -3.0 -3.0

+

Tilt Allowance, 1.03 Doppler Multiplier 0.85 0.85 Zero Power Core Power Level Milt 1.0 1.0 Ejected CEA Worth Xhp .65 .63 Post-Ejected Radial Power Peak 8.34 9.40 Axial Power Peak 1.59 1.75 CEA Bank Worth at Trip -1.47, -1.50 Tilt Allowance 1.10 1.10 CEA Drop Time*

Doppler Multiplier 0.85 0.85

See Table 7-2.

The axial peak has decreased because the axial shape index band has decreased.

T

+ Included in F r limits stated in Table 7.2.

TABLE 7.3.1-2 CEA EJECTION EVENT RESULTS Reference Cycle Cele 3 ~Cele 4 Full Power Total Average Enthalpy of Hottest Fuel Pellet 194.0 166.0 (cal/gm)

Total Centerline Enthalpy of Hottest Fuel 289.0 280.0 Pellet (cal/gm)

Fraction of Rods that Suffer Clad Oamage (average Enthalpy > 200 cal/gm)

Fraction of Fuel Having at Least Incipient .028 .040 Centerline Melting (Centerline Enthalpy > 250 cal/gm)

Fraction of Fuel Having a Fully Molten Center-line Condition (Centerline Enthalpy > 310 cal/gm)

Reference Cycle C cle 3 ~Cele C Zero Power Total Average Enthalpy of Hottest fuel. Pellet 186.0 140.0 (cal/qm)

Total Centerline Enthalpy of Hottest fuel 209.5 218.0 Pellet (cal/gm)

Fraction of Rods that Suffer Clad Oamage ~

0 (Average Enthalpy > 200 cal/gm)

Fraction of Fuel Having at Least Incipient Center line Melting (Centerline Enthalpy > 250 cal/gm)

Fraction of Fuel Having a Fully Molten Centerline Condition (Centerline Enthalpy > 310 cal/gm)

'ULL POWER 3.0 CD 2.0 5

a 1.0 0

1.0 2.0 . 3.0 4.0 5.0 TIME, SECONDS Figure FLORIDA POWER 8 LIGHT CO. CEA EJECTION EVENT St. Lucie Plant CORE POWER vs TIME 7.3. 1-1

ZERO POWER, 10.0 8

1.0 CD cC

~1 CD CD CD 0.1

0. 03 0 1.0 2.0 3.0 4.0 5.0 TIME, SECONDS FLORIDA Figure POWER 8 LIGHT CO. CEA EJECTION EVENT St. Lucie Plant CORE POWER vs TIME 7.3. 1-2

7.3.2 STMi LINE RUPTURE EVENT The Steam Line Rupture event was reanalyzed for Cycle 4,to determine that the critical heat flux will not be exceeded during this event.

The analysis assumed that the event is initiated by a circumferential rupture of a 34 inch (inside diameter) steam line at the steam generator-main steam line nozzle. This break size is the most limiting from the standpoint of potential return to power, since it results in the greatest rate and magnitude of temperature reduction in the reactor core region.

The analysis of the Steam Line Rupture event was performed with the methodology reported in the FSAR. The three steam line rupture events considered during stretch power operation were:

1) 2 Loop Full Load - 2754 51llt

2) 2 Loop - no load

3) 1 Loop - no load The one-loop case for operation at power has not been analyzed since this operating condition is precluded by the Technical Specifications (paragraph 3.4.1). The 2-loop no load case analyzed with the associated 2-.loop Technical Specification required shutdown margin of -4.3%6p is more adverse (i.e., closer approach to criticality) than the l<<loop no load case with the associated 1-loop Technical Specification required shutdown margin of -5.leap. Consequently, only the 2-loop no load results are presented.

Two-Loo - 2754 )St The Two Loop - 2754 MN case was initiated at the conditions listed in Table 7.3.2-1. The Moderator Temperature Coefficient (HTC) of reactivity assumed in the analysis corresponds to end of cycle, since this l1TC results in the greatest positive reactivity change during the RCS cooldown caused by the Steam Line Rupture. Since the reactivity change associated with moderator feedback varies significantly over the moderator temperature covered in the analysis, a curve of reactivity insertion versus temperature (i.e., moderator cooldown curve) ~ather than a single value of O'C is assumed in the analysis. The moderator cooldown curve used in this analysis is given in Figure 7.3.2-1. It is associated with an HTC of-2.5X10"4dp/'F at hot full power conditions. The reactivity defect associated with fuel temperature decreases is also based on end of cycle Ooppler defect. The end of cycle Fuel Temperature Coefficient (FTC), in conjunction with the decreasing fuel temperatures, causes maximum positive reactivity insertion during the Steam Line Rupture event.

The uncertainty on the FTC assumed in the analysis is given in Table 7.3.2-1. The 9 fraction assumed is the maximum absolute EOC value includinq uncertainties. This is conservative since it maximizes the contribution of delayed neutron multiplication to the total positive reactivity insertion during cooldown.

The minimum CEA worth assumed to be available for shutdown at the time of reactor trip at the maximum allowed power (2754 Hl<t) is 6.251.. This

shutdovrn vrorth incl<<dos an allowance for the mo"t reactive CEA being stuck in i.he fully witiidrawn position during a scram; The analysis conservatively assumed that the boron injected from the safety injectian tank is worth -1.OX'er 105 PPH.

Table 7.3.2-2 presents the sequence of events for the case initiated at the limitinq conditions qiven in Tahl'e 7,3.2-1. The reactivitv insertion as a function of time is qiven in Figure 7.3.2-2. As seen from the figure, the Steam Line Ruoture event initiated at the maximum allovred povrar level (2754 t<tlt) remains at least 064~hp subcritical during the event compared to -.43hhp for Cycle 2. The transient behavior of care power, heat flux, RCS pressure, RCS temoeratures, and stean generator pressure are, presented in Figures 7.3.2-3 to 7.3.2-7.

Two Loo - Ha Load

- no load case vras initiated at the conditions given in

'he.Tvro-Loop Tab>e 7.3.2-3. The moderator coaldovrn curve given in Figure 7.3.2-1 corresponds to .an initial NTC of >>2.5Y10"4'/ F. The end of cycle t(TC was used for the reasons given in the two loop - 2754 case. The FTC used in the analysis also corresponds to end of cycle for the reasons previously given for the two loop - 2754 N'ft case.

The minimum CEA shutdown worth available is conservatively assumed to bo -4.3Khp. A maximum inverse boron vrorth of 100 PPll/Xbp was conservatively assumed for the no load case for the time interval subsequent to vlheo the safety injection has been actuated.

The sequenc of events for the tvro-loop no load case is given in Table 7..3.2-4.. The reactivity inser tion as a function of time is given in Figure 7.3.2-8. The results of the analysis show. a peak total reactivity of -.o38 lg during the even't in comparison to -.12'Xhp for the FSAR. Since the peak total reactivity is negative, there is no return to pcvrer during a tvro loop-no load Steaim Line Rupture event initiated at zero powe, for stretch power-long cycle operations. The transient behavior of the core power, core average heat flux, PCS pressure, RCS coolant temperatures, and steam qenerator pressures are presented 'in Fiqures 7.3.2-9 to 7.3.2-12.

Conclusions The results nf the full povrer and zero povr=-r Steamline Rupture indicate that the core remains suhcritical by .064~ap and 0,03@ap, respectively.

Since there is na return to criticality for both the full'ower and zero power cases, the results confirm that, the critical heat flux ~rauld

.nat be exceeded.

TABLE'7;3.2-1 KEY PARNiETERS ASSUHED IN THE STEN LINE RUPTURE ANALYSIS 2 LOOP - 2754 fiWt Reference*

Parameters Uetts C cle ~cele 4 Initial Core Power 2700 2754 0;

Initial Core Coolant Inlet 544 551 Temperature Initial RCS Pressure psia 2250 2300 Initial Core Pass Flow Rate X10 ibm/hr . 116,'8 133o8 Initial Steam Generator Minimum CEA Worth Pressure Available psia 841.3

-5.2 909

-6.25 0

at Trip Ooppler multiplier 1.15 1.15 tioderator Cooldown Curve See Figure 7.3.2-1 See Figure 7.3.2-1 Inverse Soron Worth PPM/%hp 92 105 Effective NTC X10 'F/Xh'p -2. 2 -2.5 8 fraction (including uncertainty) .0045 .0060

Cycle 2

TABLE ?.3.2-2 SE(UEttCE OF EVEttTS FOR STEN4 LIttE BREAY, IttSIOE COHTAIf(tlEt(T UHILE OPERATItiG AT FULL POllER, 2 LOOP COtioITIOnS Event Va1ue

.0.0 Steam Line Break Occurs 1.3 Low Steam Generator Pressure Alarm Actuated 678 psia 0

2.-3 Steam Generator Low Pressure Trip Signal Generated 578 psia 3.2 Hain Steam Isolation Valves Begin to Close

~

.Trip Breakers Open for Trip on Low Steam Generator Pressure 3.7 Shutdown CE'As Begin to Orop into Reactor Core Peak Power Resulting from Overshoot Following 108.4 5 of 2710 Wt Reactor Trip 3.95 Peak Heat Flux Resulting from Overshoot Following 102.9 ~

~ ~

Reacto~ Trip

'.2 Main Steam Isolation Valves are Closed 15.7 Pressurizer Empties 16.8 Safety Injection Actuation Signal is Actuated 1578 psia 62.1 Ruptured Steam Generator Blows Ory 14.7 psia

~ 65.1 Peak Total Reactivity -.064 ~~hp 6 5,.6 Peak Power Following Reactor Trip of 2700 HMt

'6.75

TABLE 7.3.2-3 KEY PARAMETERS ASSUMED IN THE STEAM LINE RUPTURE ANALYSIS 2 LOOP - NO LOAD Parameter Unlcs FSAR ~cele e Initial Core Power Level MHt 1.0 1.0 Iniital Core Coolant Inlet oF 532 532 Temperature Initial RCS Pressure psia 2250 2300 Initial Core Mass, Flow Rate X10 ibm/hr 118".6 1'37'.2 900 900 Initial Steam Generator Pressure psia Minimum CEA tlorth Available -2.45 -4.3 at Trip Doppler Mul ti pl i er" .85 1.15*

Moderator Cooldown Curve See Figure 7.3.2-1 See Figure 7.3.2-1 Inverse Boron Worth PPM/Qp 87 100 Effective HTC X10 'F/Xhp -2.2 -2.5 8 fraction (including uncertainty) .0045 .0060

In the FSAR analysis there was a return-to-power and the 0.85 Doppler Multiplier was used to maximize the return-to-power. For Cycle 4 since there is no return-to-power the 1.15 Doppler Multiplier is used since it maximizes the Doppler feedback.

TABLE 7.3.2>>'4 SE(UENCE Of EVENTS FOR ZERO POllER (tl0 LOAD), 2 LOOP OPERATIOll FOR A SLB ItlSIDE t;ONTAItlt1EtlT 0

Time Event . Ya1ue 0.0 Steam Line Rupture occurs Low Steam Generator Pressure Alarm Initiated 678 psia 2.4 Steam Generator Low Pressure Signal Generated '578 psia 3.3 'Hain Steam Isolation Valves Actuation Signal ~

Trip Breakers Open for Trip on Low Steam Generator Pressure 3.8 Shutdown CEAs Begin to Drop Into Reactor. Core 9.3 Hain Steam Isolation Ualves are Closed 11.3 Pressurizer Empties 16.2 Safety Injection Actuation Signal Initiated 1578 psia 105.2 Ruptured Steam Generator Blows Dry 14.7 p ia 108. 7 Peak Total Reactivity - ~ 038) dp 109. 4 Peak Power Following Reactor Trip .252 tl'lt

70 0 6.0 5.0 CYCLE 4 - FULL POWER 4.0

~O CYCLE 4 0 3.0 ZERO POWER O

FSAR - ZERO POWER 2.0 1.0

-1. 0 300 350 400 450 500 550 600

~

AVERAGE MODERATOR TEMPERATURE, F Figure FLORIDA STEAM LINE RUPTURE EVENT POWER 8 LIGHT CO.

St. Lucie Plant MODERATOR COOLDOWN CURVE 7.3.2-1

2-LOOP FVLL LOA D INITIALCONDITIONS 10 MODERATOR

~ca

~\

4 z 2 DOPPLER CD SAFETY INJECTION 0 p O

TOTAL

-4 CEAs 80 120 160 200 TIME, SECONDS STEAM LINE RUPTURE EVENT Figure FLORIDA POWER 8 LIGHT CO.

St. Lucie Plant REACTIVITYCHANGES vs TIME 3.2-2

-e Z-LOOP FVLL LOAD INITIALCONDITIONS 120 110 100'0 80 g 70 60

~%I

~" 50 n- 40 0 o 30 20 10 0

80 120 160 TIME, SECONDS STEAM LINE RVPTVRE EVENT Figure FLORIDA POWER 8 LIGHT CO..

Sl. Lucie Plant CORE POWER vs TIME 7.3.2-3

2-LOOP FULL LOAD INITIALCONDITIONS 120 110 w 100 90 80 70 60 C)

~O 40 30 C) 20 10 0

80 120 160 200 TIME, SECONDS Figure FLORIDA STEAM LINE RUPTURE EVENT POWER L LIGHT CO.

St. Lucie Plant CORE AVERAGE HEAT FLUX vs TIME 7.3.2-4

-0 2-LOOP FULL LOAD INITIALCONDITIONS 2400

~'000 1600 1200 800 4QQ 0

80 120 160 200 TIME, SECONDS STEAM LINE RUPTURE EVENT Figure FLORIDA POWER 8, LIGHT CO, REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.3.2-5 St. Lucie Plant

2-LOOP FULL LOAO INITIALCONDITIONS 700

.OUT TAVG

~ 500 IN

~ 400 TOUT CORE OUTLET COOLANT TEMP TAVG CORE AVERAGE COOLANT TEMP 300 TIN CORE INLET COOLANT TEMP 80 120 160 TIME, SECONDS Figure FLORIDA STEAM LINE RUPTURE EVENT POWER 8, LIGHT CO.

St. Lucie Plant TEMPERATURE vs TIME 7.3.2-6

2-LOOP FULL LOA D INITIALCONDI HONS 1050 S'tEAM GENERATOR ISOLATED FROM RUPTURE 875

~ 700 525 C)

~ 350 PAM GENERATOR WITH UPTURED LINE

'75 0

0 80 120 160 TIME, SECONDS STEAM LINE RUPTURE EVENT Figure FLORIDA POWER 8 LIGHT CO.

St. Lucie Plant STEAM GENERATOR PRESSURE vs TIME 73 2-7

2-LOOP NO LOAD INITIALCONDITIONS MODERATOR DOPPLER SAFETY INJECTION TOTAL

-4 CEAs 40 80 120 160 200 TIME, SECONDS STEAM LINE RUPTURE EVENT Figure FLORIDA POWER 8 LIGHT CO. REACTIVITYCHANGES vs TIME 7.3.2-8 St. Lucie Plant

-0 2-LOOP NO LOAD INITIALCONDITIONS-120 110

~~ 100 90 80 C) 70 60 C)

~ So OC 30

~ 20 10 0

80 120 TIME, SECONDS 160 0 STEAM LINE RUPTURE EVENT Figure FLORIDA POV/ER & LIGHT CO. 7.3.2-9 CORE AVERAGE HEAT FLUX vs TIME St. Lucie Plant

2-LOOP NO LOAD INITIAL CONDITIONS 2400 w 2000

~ 1600 cn 1200 800 400 80 120 160 200 TIME, SECONDS STEAM LINE RUPTURE EVENT Figure FLORIDA POWER 8 LIGHT CO. REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.3.2-1 St. Lucie Plant

2-LOOP NO LOAD INITIALCONDITIONS 550 TOUT CORE OUTLET COOLANT TEMP TAVG CORE A VERA GE COOLANT TEMP 500 TIN CORE INLET COOLANT TEMP OUT AVG m 450 TIN g 400 350 300

.0 80 120 160 200 TIME, SECONDS STEAM LINE RUPTURE EVENT Figure FLORIDA POWER & LIGHT CO. 7.3.2-21 St. Lucie Plant KS TBVFPA'ltd vs TIE

2-LOOP NO LOAD INITIALCONDITIONS 1050

~~ 700 STEAM GENERATOR ISOLATED FROM RUPTURE cr. 525 C)

~ 350 STEAM GENERATOR WITH RUPTURE LINE 175 0

0 80 120 160 200 TIME, SECONDS Figure FLORIDA STEAM LINE RUPTURE EVENT POWFR 8 LIGHT CO, St. Lucie Plant STEAM GENERATOR PRESSURE vs TIME 7.3.2-12

7.3.3 STEN GENERATOR TUBE RUPTURE EVENT The Steam Generator Tube Rupture (SGTR) event was reanalyzed for Cycle 4 to verify that the site boundary doses will not exceed the guidelines of 10CFR100. The design basis SGTR is a double ended break of one steam generator U-tube. Table 7.3.3-1 lists the key transient related parameters used in this analysis. In the analysis, it is assumed that the initial RCS pressure is as high as 2300 psia. This initial RCS pressure maximizes the amount of primary coolant transported to the secondary steam system since the amount of leak is directly proportional to the difference between the primary and secondary pressure. In addition, the higher pressure delays the low pressurizer pressure trip. This too maximizes the primary to secondary leakage.

For this event, the acceptable ONBR limit is not exceeded due to the action of the Thermal tiargin/Low Pressure (TM/LP) trip which provides a reactor trip to maintain the ONBR above 1.23. Therefore, no fuel failure occurs during the transient and the activity in the reactor coolant is assumed to be initially at the maximum allowable Tech Spec values.

The Thermal 11argin/Low Pressure trip, with conservative coefficients which account for the limiting radial and axial peaks, maximum inlet temperature, RCS pressure, core power, and conservative CEA scram characteristics, would be the primary RPS trip intervening during the course of the transient.

However, to maximize the coolant transported from the primary to the secondary and thus the radioactive steam releases to the atmosphere, the analysis was performed assuming the reactor does not trip until the minimum setpoint (floor) of the Thermal Margin/Low Pressure trip is reached. This prolongs the steam releases to the atmosphere and thus maximizes the site boundary doses. The methodology to calculate the site boundary doses for Steam Generator Tube Rupture is identical to the procedure used for Loss of All non-Emergency A-C Power (See Section 7.2.3).

The sequence of events for this transient is given in Table 7.3.3-2. Figures 7.3.3-1 through 7.3.3-6 present the transient behavior of core power, core heat flux, the RCS pressure, the RCS coolant temperatures, the steam generator pressure and the ruptured tube leak rate.

The results of the analysis are that 63,200. lbs. of primar coolant are transported to steam generator secondary side. Based on this mass transport and values in Table 7.3.3-3, the site boundary doses calculated are:

Thyroid (OEg I-131) : 5.3X10 REM Whole Body (OEg XE-133) : 0.06 REM These results compare with the respective values quoted in the FSAR of 9.8X10 and 0.0344 REM ~espectively.

The reactor protective system (TM/LP) is adequate to protect the core from thermal damage in the event of the complete severance of a steam generator U-tube. The doses resulting from the activity released as a consequence of .a double-ended rupture of one steam generator tube, assuming the maximum allowable Tech Spec activity for the orimary concentration at a core power of 2700 Milt, are significantly below the guidelines of 10CFR100.

TABLE 7.3.3-1 KEY PARAMETERS ASSUMED IN THE STEAM GENERATOR TUBE RUPTURE EVENT Reference Cycle* Cycle 4 Parameter Unsus Value Value Initial Core Power Level MWt 2611 2754 Core Inlet Temperature 544 551 Initial RCS Pressure psia 2300 2300 Core Mass Flow Rate X10 1 bm/hr 117o5 133 8 Initial Steam Generator psia 841 810 Pressure CEA Worth at Trip -4.8 -4.7 Moderator Temperature Xl 0 ~LILp -2.5 -2.5 Coefficient Doppler Multiplier 1.15 1.15

FSAR

TABLE 7.3.3-2 SEQUENCE OF EVENTS FOR THE STEIN GENERATOR TUBE RUPTURE EVENT T.ime sec Event Set oint or Value 0.0 Tube Rupture Occurs 552.2 Pressurizer Empties 539.6 Low Pressurizer Pressure Trip, 1853 psia Signal Generated 539.6 Dump Valves Open 539.6 Bypass Valves Open 541. 0 CEAs Begin to Drop into Core 550.0 Maximum Steam Generator Pressure 903 psia 552.2 Safety Injection Actuation Signal 1578 psia Generated 554. 6 Dump Valves Close 592.6 Bypass Valve Closes 1800.0 Operator Initiates Appropriate Action and Begins Cooldown to 325'F 8892.0 RCS Average Temperature 325'F Operation Initiates Shutdown Cooling

TABLE 7.3.3-3 ASSUMPTIONS FOR THE RADIOLOGICAL EVALUATION FOR THE STEAM GENERATOR TUBE RUPTURE Cvcle 4 Parameter Units Value Reactor Coolant System Maximum pCi/gm 1.0 Allowable Concentration (DE( I-131)

Steam Generator Maximum Allowable pCi/gm Concentration (OEg I-131 ) 1 Reactor Coolant System Maximum Allowable pCi/gm , 100/Z Concentration of Noble Gases (DE/ Xe-133)

Steam Generator Partition Factor Air Ejector Partition Factor .0005 Atmospheric Dispersion Coefficient sec/M B.SSX10 Breathing Rate M /sec 3.47X10 Dose Conversion Factor (I-131) REM/Ci 1.48X10 Tech Spec limits 0 - 2 hour2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months accident condition

For the FSAR the combined Partition Factor of the Steam Generator and Air Ejector was 2.0X10-6.

120 110 100 90 80 70 o 60

~1 50 40 CC

~ 30 20 10

'0 ~

600 1200 1800 TIME, SECONDS Figure FLORIDA STEAM GENERATOR TUBE FAILURE EVENT POWER 8 LIGHT CO.

St. Lucie Plant CORE POWER vs TIME T.3.3-1

lf

~

I al I

ol o II II :II I

~ 0

~'

g

~

~ ~

~

~ II e II

~' p g

~

s

~

610 OUTLET 600 c 590 TAVERAGE 580

~ 570 g 560 INLET 5550 C)

C)

~ 540 530 520 510 600 . 1200 1800

. TIME, SECONDS S'RAM GENERATOR TUBE FAILURE EVENT Figure FLORlDA POWER 8 LLGHT CO.

St. Lucie Plant REACTOR COOLANT SYSTEM TEMPERATURE vs TIME 7.3.3-4

910 900 890

~ 880 u" 870

~ 860

~ 850

~ 840

~ 830

~ 820 810 800 790 600 1200 1800 TIME, SECONDS Figure FLORIDA STEAM GENERATOR TUBE FAILURE EVENT POWER & LIGHT CO.

St. Lucie Plant STEAM GENERATOR PRESSURE vs TIME 7.3.3-5

tl

~

I ol el I

I I oil II all

~ ~ 0

~'

g

~ g

~ t

~

e ~ a l i

7.3.4 SEIZED ROTOR EVENT The Seized Rotor event was reanalyzed for Cycle 4 to demonstrate that the RCS upset pressure limit of 2750 psia will not be exceeded and onlv a small fraction of fuel pins are predicted to fail during this event.

The single reactor coolant pump shaft seizure is postulated to occur as a consequence of a mechanical failure. The single reactor coolant pump shaft seizure results in a rapid reduction in the reactor coolant flow to the three-pump value. A reactor trip for the seized rotor event is initiated by a low coolant flow rate as determined by a reduction in the sum of the steam generator hot or cold leg pressure drops. This signal is compared with a setpoint which is a function of the initial number of operating reactor coolant pumps. For this event a trip will be initiated when,'. or before, the flow rate 'drops to 93 percent of initial flow.

The initial conditions for the Seized Rotor event are listed in Table 7.3.4-1.

These conditions are. consistent with the initial conditions assumed for the LOF event (see Section 7.2.2). Other assumptions on key parameters are also listed in this table.

The analysis was performed in the following steps:

A. Upon initiation of this transient, core flow rate is assumed to drop immediately to the asymptotic three pump core flow value of 77.25 of four pump flow. For conservatism in the analysis, it is assumed that the flow at the core in'let is instantaneously reduced to the =

three pump core flow value.

B. The resultant flow is used as input to CESEC, a digital computer code described in Reference 4 which simulates the NSSS to demonstrate that the reacto~ coolant system (RCS) pressure will remain below the upset limit of 2750 psia (110% of design).

C. The RCS flow coastdown, the limiting axial power distribution for the most negative axial shape index allowed within the full power shape index LCO, and a consistent scram reactivity curve is input to STRIKIN II (see description in Reference 6) to determine the hot channel and core average heat fluxes versus time during the transient. LSee Reference 14 for the procedures used to determine the assumed 'axial power distribution].

D. TORC/CE-1 was used for calculation of the minimum DNBR for the transient. The seized rotor transient is initiated at the Limiting Conditions for Operation'o determine the minimum DNBR.

E. In determining the predicted number of fuel pin failures, the TORC code is used to calculate the DNBR versus radial peaking factor.

An integral fuel damage calculation is then carried out by combining the results from TORC with the number of fuel rods having a given radial peaking factor. The number of fuel rods versus radial peaking factor is taken from a cumulative distribution of the fraction

of fuel rods with nuclear radial peaking factors in a given range.

This yields a distribution of the fraction of pins with a particular ONBR as a function of ONBR. This information is then convoluted with a probability of burnout vs. ONBR to obtain the amount of fuel failure.

This method is discussed in detail in. CENPD-183, "C-E Methods for Loss of Flow Analysis" (Reference 12)'. It is totally consistent with the method described in thattopical:report and with methods previously used and approved for St. Lucie Untt 1, Cycle 3 (Reference 1).

The methods used to analyze the Seized Rotor event are consistent with the methods previously used and approved for Calvert Cliffs (Reference 15) and t1illstone Point 2, Cycle 3 (Reference 16).

In Table 7.3.4-2, the NSSS and RPS responses are shown for the seized rotor event initiated from an axial shape index value of -.11. The pressurizer pressure reached a maximum value of 2306 psia at 3.75 seconds.

Figures 7.3.4-1 through 7.3.4-5 show core power, core average heat flux, RCS pressure, and coolant temperatures during the transient.

A conservatively "flat" pin census distribution (a histogram of the number of pins with radial peaks in intervals of 0.01 in radial peak normalized to the maximum peak) is used to determine the number of pins that experience DNB. The results show that the number of fuel pins predicted to fail is equal to 1.06% in comparison to .99K for Cycle 3. This is a slight increase over Cycle 3, and remains a small fraction of the total number of fuel pins.

For the case of the loss of coolant flow resulting from a seizure of a reactor coolant pump shaft, a trip on low coolant flow is initiated to limit the predicted fuel failure to only a small fraction 'of the total number of pins. Based on the low probability of this event, the small number of predicted fuel pin failures will be acceptable. In addition, the maximum RCS pressure experienced during the event will be well under the upset pressure limit of 2750 psia.

TABLE 7.3.4-1 KEY PARAHETERS ASSUHED IN SEIZED ROTOR ANALYSIS Parameter Units ~Cele 3 ~Cele 4 Initial Core Power Level 2754 2700*

Core Inlet Coolant Temperature 544 549*

4 Pump Core Hass Flow Rate 10 ibm/hr 134.9 138.3" 3 Pump Core Hass Flow Rate 10 ibm/hr 104.1 106.8" Reactor Coolant System Pressure psia 2200 2225 Hoderator Temperature Coefficient X10 dp/'F +.5 Doppler Coefficient t1ultiplier .85 .85 CEA 'l(orth on Trip -5.4 -5.6 Integrated Radial Peaking 1.64 1.70*

Factor with Tilt; FT Axial Shape Index - ~ 23 ~ )1*

Uncertainties on these parameters were combined using the methods discussed in Section 7.2 and are consistent with LOF.

TABLE 7.3.4-2 SEQUENCE OF EVENTS fOR SEIZED ROTOR Time Sec Event Set oint or Value 0.0 Seizure of One Reactor Coolant Pump 0.0 Low Coolant Flow Signal 93Ã of Initial 4-pump Flow Generated 0,65 Trip Breakers Open 1.15 CEAs Begin Dropping into Core 3.75 Haximum RCS Pressure, psia 2306

120 110 100 K

80 CD 70 CO 60 50 40 CD 30 20

'00 8 12 16 20 TIME, SECONDS FLORtDA Fiqure POW ER 8 LLG HT CO. SEIZED ROTOR EVENT St. Lucie Plant CORE POWER vs TIME Unit l 7.3.4-1

120 110 90 So 70

~CI 60 50 40 30 20 10 0

0 8 12 16 20 TIME, SECONDS FLORIDA Figure POW ER 8 LIG HT CO. SEIZED ROTOR EVENT St. Lucie Plant CORE AVERAGE HEAT FLUX vs TIME Unit I 7.3. 4-2

2400 2300 2200 2100 2000 1900 1800 0 8 12 16 20 TIME, SECONDS FLORIDA Figure POWER 8 LIGHT CO. SEIZED ROTOR EVENT St. Lvcie Plant REACTOR SYSTEM PRESSURE vs TIME Unit 1 7.3.4-3

630

'20 0VTLET 610 660 C) cn 590 TAVERAGE 580 570 cn 560 550 540 530 520 0 8 12 16 20 TIME, SECONDS FLORIDA Fiqure POWER 8 LIGHT CO. SEIZED ROTOR EVENT St. Lucie Plant REACTOR COOLANT SYSTEM TEMPERATURES vs TIME 7.3.4-4 Unit 1

REFERENCES

l. Letter, Robert E. Uhrig, (FPSL) to Victor Stello (NRC); dated February 22, 1979, "St. Lucie Unit 1 Docket No. 50-335 Proposal Amendment to Facility Operating License DPR-67".

2. CENPD-199-P, "C-E Setpoint Methodology," April, 1976.

3. CENPD-98, "COAST Code Description," April, 1973.

4, CENPD-107, "CESEC- Digital Simulation of a C-E Nuclear Steam Supply System," April, 1974.

5. CENPD-161-P, "TORC Code - A Computer Code for Determining the Thermal Margin of a Reactor Core," July, 1975.

6. CENPD-135-P, "STRIKIN II, A Cylindrical Geometry Fuel Rod Heat Transfer Program," August 1974.

7. Letter, Robert E. Uhrig, (FPSL) to Victor Stello (NRC), dated March 22, 1978, "St. Lucie Unit 1 Docket No. 50-335 Proposal Amendment to Facility Operating License DPR-67".

8. CENPD-190A, "CEA Ejection, C-E Method for Control Element Assembly Ejection," July, 1976.

9. GEMP-482, H. C. Brassfield, et. al., "Recommended Property and Reactor Kinetics Data for Use in Evaluating a Light Water-Cooled Reactor Loss-of-Coolant Incident Involving Zircaloy-4 or 304-SS, Clad U02," April, 1968.

10. Idaho Nuclear Corporation, Monthly Report, Ny-123-69, October, 1969.

Idaho Nuclear Corporation, Monthly Report, Hai-127-70, March, 1970.

12. CENPD-183, "C-E Methods for Loss of Flow Analvsis," July, 1975.

13. CEN-126 (F)-P, "CEAW, Method of Analyzing Sequential Control Element Assembly Group Withdrawal Events for Analog Protection Systems,"

November, 1979.

14. Statistical Combination of Uncertainties Methodology, CEN-123 (F)-P, February 1980.

15. Letter, A. E.. Lundvall (BG8E), to R. Reid (NRC); dated February 23, 1979, "Calvert Cliffs Unit 1 License Amendment," Docket No. 50-317, DPR>>53.

16. Letter, W. G. Counsil (NNECO) to R. Reid (NRC), dated February 12, 1979, "Millstone Point-2 License Amendment, Power Uprating," Docket No. 50-336, DPR-65.

SECTlOtl 8.0

~ I Large Break St. Lucie Unit LOCA ECCS 1 Cycle 4 Performance Resul ts 1.0 !tlTROOUCTlO(l AflO SUfifiARY 0

A large. break loss-of-coolant accident ECCS performance evaluation For St. Lucie 1, C yce,pee~

1 4 r s rted herein demonstrates conformance wi th the Acceptance Cri ter >a for Light-'plater -Cooled Reactors as presented in 10CFR50.46 (1) . Conformance is summarized in Section 4.0. The evaluation demonstrates acceptable ECCS performance For St. Lucie 1 during Cycle 4 at a reactor power level of 2754 flwt and a peak linear heat generation rate,(PL) lGR) of 15.0 kw/ft. The nethod of analysis and results are presented in the following sections.

2.0 HETH00 OF AllALYSIS The calculations performed for this evaluation used the HRC approved C-E Large Break Evaluation Hodel which is described in References 2 through 8.

Blowdown, r ef1 1/ref load, and temperature calculations were perFormed to 1

incorporate the Cycle 4 fuel characteristics and reactor power level of 2754 Hwt into the CCCS performance evaluation. The blowdown hydraulic calculations were performed with the CEF'ASH-4A code while the ref>ll/

ref lood hydraulic calculations were performed with the COHPERC-l! co e.

The hot rod clad temperature and clad oxidation calculations viere performed with the STRIK!N-f! and PARCH codes. Core wide clad oxidation calculations were also performed in this analysis.

The ECCS analysis assumptions are the same as those stated in Reference 9.

The core and system parameters which differ from the previous analysis are shown in Table Al which is. consistent vri th the PLHGR of 15.0 kw/Ft.

The containment parameters pertinent to this analysis are listed in Table AZ.

0 l

~ All possible break locations are considered in a LOCA analysis.

lt was demonstrated in Reference Z that ruptures in the .cold leg pump discharge location produce the highest clad temperatures.

This is due to the minimization of core flow for this break location. Since core flow is a function of the break size, the St. Lucie.Unit 1 Cycle 4 large break calculations have been performed for the cold leg pump discharge breaks For both guillotine

. and slot breaks over a. range of break sizes frorr 5.89 ftZ to twice the flow area of the cold leg.

S.O RESULTS I

Included in the Cycle 4 cire are 88 fresh Batch F fuel asserrrbliesi along with previously irradiated assemblies: 68 Batch K assemblies, 60 Batch 0 assemblies and one Batch C assembly. Burnup'dependent calculations for the various fuel types

-were performed with the FATES and STR?KIN-II codes. The resul ts deiron-strated that the most limiting fuel rod during Cycle 4 operation is a rod in 3'.

one of the partially depleted Batch K assemblies retained from Cycl'e For the limiting Batch E assembly rod, clad rupture was predicted to occur during the ref lood period. As a consequence, this analysis was performed at the time of minimum fuel-clad gap conductance, warren the fuel stored energy is at a maxirrrum. The fuel pin pressure was not high enough 'to cause rupture during blowdown for any break size. Therefore, all break sizes were analyzed

.at the time of maxirrrurrr fuel stored energy.

'The break spectrum ana.lysis described in Section Z.Q wa's performed for the limiting Batch E asserrrbly'od. It was determined from this analysis that the allowable peak linear heat generation rate (PLHGR) for the K assembly rod is 15 0 k>(1ft with the limiting break size identified as the 1.0 OEG/PO break.

<<OEG/PO = Oouble-girded Guillotine at Piimp Oischar ge . 0

The 1.0 OEG/PD trask produced the highest peak clad tonperatura (2176'P) and the highest local clad oxldatlon percentage (<16.0X). The 1.0 DKG/PO also resulted in the highest core wide clad. oxidation which was less than 0.74". The PLHGR of 15.0 kw/ft is therefore demonstrated to be an acceptable limit for Cycle 4 operation.

~

The times of interest for each of the breaks are presented in Table A3. The clad rupture times are included in Table A4, which contains a sumary of the'peak

'lad temperatures and oxidation percentages for the break spectrum. Table AS contains a list of the pertinent variables. plotted for each break in this analysis.

Table A6 contains a list of additional parameters plotted for the limiting break

(.1.0 OKG/PO break). 4!ass and energy reIease to the containment during blowdown is presented in Table A7 for the worst break. Also presented in this table i' the steam expulsion data during ref lood. Figure A7 shows the peak clad tem-perature plotted versus break size and type, demonstrating that the worst break is the 1.0 OKG/PO rupture. The KCC water spillage and containment spray flow rates are presented graphically in Figure AS.

4.0 CONCLUS ION The results of the KCCS performance evaluation for St. Lucie I, Cycle 4 demonstrated a peak clad temperature of 2176 F, a. peak local clad oxidation percentage of less than 16.0'" and a peak core wide clad oxidat'ion percentage of Iess than 0.74%. The acceptance crite. ia are, resp ctively, 2200'F, 17.0 and 1.0 .

Based on these KCCS performance results, it. is concluded that operation of St. Lucie I at a reactor power level of 2754 f'rwt and a PLHGR of 15.0 kw/ft is acceptable for Cycle 4.

5.0 COMPUTER COOK VERSION IOENTIFICATION The fol1owing NRC approved code versions were used in this ana1ysis:

CEFLASH-4A Version 76041 CONPERC-IL Version 75097 STRluN-II Version 77036 PARCH Version 77004.

6.0 Refarances Acceptance Critaiia fnr Biargency Core Cooling Systems for Light-l:atar Cooled Huclear Polar Reactors, Federal Register, Yol. 39, tlo. 3-Friday, January 4, 1974.

2. CENP0-132, "Calculativd Hathods for the CE Large Graak LOCA Evaluation Hcdel", August 1974 (Proprietary).

CBlPO-I32, Supplement I, Updated Calculative flathods for the CE Large Break LOCA Evaluation Hodel", December 1974 (Proprietary),

3. CBlPO-I32, Supplemant 2, "Calculational Vathods for tha CE Large Break LOCA Evaluation L'todeI", July 1975 (Proprietary).

4.. CB(PO-I33, "CEFLASll-4A, A FORTRAH IV Digital Computar Program for Reactor GIo.vdovin Analysis", Apr il 1974 (Proprietary).

CBPD-I33, Supplamant 2, "CEFLASH-4A, A FORTPAtl IY. Digital Computer Program for Raactor Glovdown Ana'.ysis (flodification)", Oecamber 1974, (Proprietary).

5. CAPO-I34, "COllPERC-II, A Program for Eoieigency Refill-Reflood of the Core", April 1974 (Proprietary).

CENPD-I34, Supplamant I, "COi1PERC-II, A Program ror Emergency Refill-Reflood of the Cora (Hodification)", Oacembar 1974 (Proprietary).

6. CEBP0-135, "STRIKI>l, A Cylindrical Geometry Fual Rod lleat Transfer Program, April 1974 (Proprietary)."

CENP0-135, Supplament 2, "STRIKIH-II, A Cylindrical Gaoretry Fue1 Rod Heat Transfer Program (flodification)", Fabruary 1975.

~ C

Cf:NPU-135, Supplement 0, "STRIf:IN-1I, A Cvl indrical Goomet.ry Fuel Rod Heat Transfer Prngran", August 1976 (ProprieLary).

CENP0-135, Supplement 5-P, "STRtYIN-It, A Cylindrical Geometry Fuel Rod Heat Transfer Program", April, 1977 (Proprietary).

7, CKNPO-1 39, "CK Fuel Evaluation ttode1", July 1974 (Pr oprietary) .

8 ~ CENP0-138, and Supplement I "PARCfl, A FORTRAN tV Oigital Program .

to Fvaluate Pool 8oiling, Axial Rod and Coolant Hea tup",

February, 1975.

CENPO-I38, Supplement 2, "PARCH, A FORTRAN IV Oigital Program to Evaluate Pool Boiling, Axial Rod and Coolant Heatup", January, 1977.

St. Lucie Nuclear Power Plant Unit I, Final Safety Analysis Repor t in Support of Oocket No. 50-335, License No. OPR-67.

TABLE Al St. Lucie Unit 1 Cycle 4 Core Parameters

~uantit Value Core Popover Level (1025 of Nominal) 2754 Met Average Linear Heat Rate (102'A of Nominal) 6.427 kl;I/ft Peak Linear Heat Generation Rate (PLHGR) 15.0 kn/ft

. Core inlet Temperature 551 0F Core Outlet Temperature 602 OF System Flow Rate (total) 138.Sxl0 ibm/hr Core Floh Rate 133.8xl0 ibm/hr Gap Conductance at PLHGR 1602 BTU/hr-ft2 - o F Fuel Centerline Temperature at PLHGR 3538 OF Fuel Average Temperature at PLHGR 2203 OF Hot Rod Gas Pressure 1088 psia Hot Rod Burnup 1522 NllD/NTU

Table A-2 St. Lucie 1 Cycle 4 Containment Physical Parameters Het Free Yolvme 2.5111 x 10 Ft I

Containment Initial Conditions:

Humidity 1004 Containment Temperature 60 F Enclosure Building Temperature 38 F Initial Pressure 14.6 psia Initial Time For:

.Spray Flow 25 seconds Fans (4) ~

0.0 seconds Containment Spray Mater:

Temperature 55 F Flow Rate (Total', both pumps) 6750 gpm Fan Cooling Capacity (per fan)

Ya or Temoerature F Ca acit BTU/Sec 60 0.0 120'80 3472.0

.?388.8 220 11611.1 264 20833.3 Heat Transfer Coef'cient a0 Containment structure to enclosure building atmosphere heat transfer coefficient - 13.0 BTU/hr-ft2 - 0 F.

~2 - 0 F.

b. Sump to base slab - l0 BTU/hr-ft Co Containment atmosphere to sump - 500 BTU/hr-ft2 - 0 F.

Table A-2 Continued St. Lucie 1 Cycle 4 Passive Heat Sink Inform'ation k pC Thickness 't Area BTU Exposure Exposure Material Ft2 HH~ft HF Ft -OF Side 1 Side 2

l. Containment Steel .1171 86700 25.9 53.57 Cont. Vapor Annulus Shel 1 Floor Slab Concrete 20.0 12682 1.0 34.2 Cont. Vapor Insul ate<

3. Hisc. Concrete Concrete 1.5 87751 1.0 34.2 Cont. Vapor Insulate<

~:.. Cial vani zed S teel Zinc Steel 0.0005833 0.01417 130000 64.0 25.9 40.6,

53. 57 Cont. Vapor Insulate<

Carbon Steel 0.03125 25000 30.0 53.8 Cont. Vapor Insulatei Steel Stainless Steel 0.0375 22300 9.8 54. 0 Cont. Vapor Insul ates Steel Hisc. Steel Steel 0.0625 40000 . 25.9 53.57 Cont. Vapor Insul ate.

~p Hisc. Steel Steel 0.02083 41700 25.9 53.57 Cont. Vapor Insulate Hisc. Steel Steel 0.17708 7000

'5.9 53.57 Cont. Vapor Insulate Imbedded Steel 0.0708 18000 25.9 53.57 Cont. Vapor Insulate Steel Concrete 7.00 1.0 34.2

i .<' I ~

' ~ "

I ~ ~ ~

i'<'

L

~

i <<i <

~

I < I iI I < ~ ~ <

~

TABLE A3 St. Lucie Unit 1 Cycle 4,

(

TIMES-OF INTEREST SECONDS) .. II

~

I START OF TIME OF ANNULUS CONTACT TIME SAFETY BREAK . SAFETY INJECTION DOIINFLOH TIME INJECTION TANKS EMPTY 1.0 DES/PD 17.2 20.3 34.60 61. 5 0.8 DES/PD 17.7 20.8 35.12 62.0 0.6 DES/PD 19.2 22.4 36. 71 63. 6 1.0 DEG/PD 17. 2 20.4 34. 72 61. 6 0.8 DEG/PD 18.1 21.2 35.51 62.4 0.6 DEG/PD 20.1 23.3 37.62 64.5

TABLE A4 St. Lucie Unit 1 Cycle 4 Hot Rod Rupture Peak Local Core-Mide Break Peak Clad Temperature ( F) Time (sec) Clad Oxidation (C) Clad Oxidation (X) 1.0 x DES/PD 2174 52. 13 < 15.33 < .72

< 15.26 < .70 0.8 x DES/PD 2173 53.52

< .65 0.6 x DES/PD* 2161 59.89 < 14.62 2176 51.24 < 15.44 < .74 1.0 x DEG/PD

< 15.36 < .74 0.8 x DEG/PD 2175 52.13

< 14.16 < .61 0.6 x DEG/PD* 2057 61.8

Tab'le A5 St. Luci'e Unit 1 Cycle 4 Variables Plotted as a Function of Time for Each Large Break in the Spectrum . 0 I Figur e f Variabl e DBS~Clllc".f:10n I

Core Po:;er

~

p, ' ~ ~ ~

Pressu:e in Cenier )lot.Assembly Node Leal: Flo';I lloi: f(sse;.,bly Flo.v (b lo~i ho~ pot) D-l Hot Assembly Flo'..I (above hot spo )

Asser..bly t;ual ity

'ion f

~ f Cont@i!rri,en'ressur D.2':lass e

fv3d=d .to Cove During Pef1ood Pe'4k~ Cl i'0 e off a'Qra \ ure f~ ~

f 0

~

0

~ ~

0

Table A6 St. Luci e Unit 1 Cycl e 4 Additional Variables Plotted as a Function of Time for the Large Break Having the Highest Clad Temperature Figure Variables Desionation

'0

~

l i ~ .~ ~, ~

0 'W

~ ~

Mid Annulus Float Qualities Above.and Beloved the Core Core Pressure Drop Safety Injection Tank Floe< into Intact Discharge Legs Mater Level in Downccmer During Ref lood Hot Spet Gap Conductance Peak Local Clad Oxidation', 0 3I Cad Tem"erature, Centerline Fuel Temperature, Average Fuel Temperature and Coolant Temp.rature for Hottest trode

'I

~

Hot Spot Heat Transfer Coefficient Q Containment Temoerature R Sump Temperature Hot Rod Internal Gas Pressure Core Bulk Channel Flo:i Rate

TABLE A7 IME, SEC I

)

MASS FLOW LBI4/SEC ENER GY RELEASE BTU'/SEC

" 'BM INTEGRAL 0~

MASS FLOW TNTEGINL OF ENERGY RELEASE BTU I

I I

do ~

.0 '4P o-ov~zWo~ o H S8a.9'

+. ro Mo~ L .I o~~M8 I

.r5'zz .

ohio

~ 4'

~ gy~'

I I

I 4~~O ~

I OJC

>. ~nGPZ l Qp~ x~

M>>>>-

.~/NC '

>,sC~s, dH3o F'J'z.

g.'Doz88o. ~

l cs z .Z Z>>o4TJ I

4E&o z <sic'<

I

.'H,cerW:

~d.>44o 4'..8 X. 7Z7Z-. Z.4~8

>>C ~~ 'o/H

~oo/'o why k%<4 I

gP i. OO 44F.,

I I

vZwx. >,MP7 Mi oorg )

A r.o7& xdc

TABLE A7 CONT' e I TIME I I MASS FLOW ENERGY RELEASE 'ASS NTEGRAL OF FLOW

. INTEGRAL OF ENERGY RELEASE SEC ,'BH/SEC BTU'/SEC LBM BTU I I I L aa.a~tio.'z x~o~.r<Ws.xylo i I RIroo~ o~~oui

. ro+

~ZdPS Z~d I

/ d.d g~.~d~wszz. ~

Mo'rx"8 x ro M g r/Sg ~C.88 le r'

.g~ao'Zd oz7dP

~az8 M 4~M 7CZ+

J'.o /~144~

I. C 8 TIME OF ANNULUS DOWNFLOW I

'ALUES B ELOW ARE FOR STEAM ONLY)

START OF REFLOOD Jd.

cP7 JC QP 147..=.

r PPd.P.

-gJ'OdP

r. S77r.

~ Mszo.

seb') Jro LI

TABLE A7 CONT'0

'NTEGRAL 0 ~TEGRAL OF ENERGY RELEASE MASS FLOW ENERGY RELEASE TIME MASS FLOW " '"LBM BTU SEC LBM/SEC BTU/SEC e h

~+ND~d?~4A.>>

I Z~ ~ ~ ~4o/ '~~p+

I Maacc HDFC i

w/+W~8~I M. 87gg

FIGURE I,l-A ST LUCIE UNIT I STRETCH POHER 1,0 x DOUBLE ENDED SLOT BRM IN PUMP DISCHARGE LEG CORE POWER 1.2001 1 GGGG

~ 8GGG 6GGG I

ZGGG 0 GGQg (3 C3 C3 C7 D C3 C3 CD CD C3 C3 CD CD C)

C) P)

TIME, SECONDS

FIGURE I;1-B ST LUCIE UNIT I -STRETCH POWER 1,0 x DOUBLE ENDED SLOT BREAK IN PUHP DISCHARGE LEG PRESSURE IN CENTER'HOT ASSES)BLY NODE 2400 0 2000 0 1600 0 I

I cn s

Cg.

1200 0 Cl7'iJ.

CC CL

'00. 0 400 0 CD C3 CD CD CD CD CD CD Q CD C3 CD CD CD LO CD sJ 7 C) le ~ I C' TINE, SECONDS

FIGURE I,l-C ST LUCIE UNIT I STRETCH POllER 1,0 x DOUBLE ENDED SLOT BREAK IN PUilP DISCHARGE LEG LEAK FLO>l 120000 100000.

80000.

UJ CA 60000.

CD 40000 20000 0 ~

CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD tD n LQ CD CU U3 CU TINE, SECONDS

FIGURE I,l-D,1 ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED SLOT BREAK IN PUNP DISCHARGE LEG FLOW IN HOT ASSB'lBLY-PATH 16, BELO>f HOT SPOT 30 000 20.000 10 000 g . 0.000

-10 000

-20 000

-30 000 CD CD CD CD CD CD CD C) CD I

CD CD CD CD CD CD n CD CD io CD tD CD UD CU CJ TINE, SECONDS

FiGURE I'1-D.2 ST LUCIE UNIT I STRETCH POttIER LEG 1,0 x DOUBLE ENDED SLOT BREAK IN PUI"1P DISCHARGE FLOW IN HOT ASSENBLY-PATH 17, ABOVE HOT SPOT 30 000 I 10.000 0.000 CD

-10.000

-20.000

-30 000 CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD LO CD Li)

CD tD CU CU TINE, SECONDS

FIGURE I,l-E ST LUCIE UNIT I STRETCH POMER 1,0 x DOUBLE ENDED SLOT BREAK IN PUHP DISCHARGE LEG.

HOT ASSB'lBLY QUALITY NODE 13, BELOW HOT SPOT NODE 14, AT HOT SPOT

"'-'-,NODE 15, ABOVE HOT SPOT l,o I

( i I JI ( I

~

I I t(

~

I g

I Ii I 0,8 I I

I

/

0,6 e I J

I

~ ~

/

l 0,4 0..2 0,0 0,0 5,0 10,0 15.0 20,0 25,0 TINE, SECONDS

FIGURE I,l-F.

ST LVCIE UNIT I STRETCH POWER l,0 x DOUBLE ENDED SLOT BREAK IN PUl'tP DISCHARGE LEG CONTAINNENT PRESSURE 60 . rOrr 50 GOO 40 000 30 OGO

'0'OOG 10 000 0'. 000 Q Q Q Q Q Q Q Q Q Q Q

Q Q Q Q Q Q Q Q Q Q Q OJ P) LD TINE AFTER RUPTURE, SECONDS

FIGURE I,1-G ST LUC I E UNIT I STRETCH POWER 1,0 x DOUBLE ENDED SLOT BREAK IN PUNP DISCHARGE LEG HASS ADDED TO CORE DURING REFLOOD

2OGGG lOGGGC ~

8oooo SOCGO 40GCO.

20000 0 ~

CD CD CD CD CD lD C) CD CD CD CD CD C) CD CD n 'D CD CD CD 5J n tD CD LD TIflE AFTER CONTACT, SECONDS

FIGURE I,l-H ST LUCIE UNIT I STRETCH POtlER 1,0 x DOUBLE ENDED SLOT BREAK IN PUflP DISCHARGE LEG PEAK CLAD TEHPERATURE 2200 2000 1800 1600 0

'400 1200 0 j.ooo 800 600

- 300 400 500 600 0 100 200

FIGURE I,2-A ST LUCIE UNIT I STRETCH POl'(ER 0.8 x DOUBLE ENDED SLOT BREAK IN PVNP DISCHARGE LEG CORE POMER 1 2001 1.000G

~ 8GGG CD

.GG00

(

CD I

. 4000

.20GG 0 GCGg~ .CD CD , CD C3 CD CD CD C3 C'3 C3 C3 C.)

n n C3 n C)

CD Cd TINE, SECONDS

FIGURE I,2-8 ST LUC IE UNIT I STRETCH POWER 0,8 x DOUBLE ENDED SLOT BREAK IN PUjtP DISCHARGE LEG PRESSURE IN CENTER HOT ASSH'lBLY NODE 2il00 ~ 0 2000 0 16GG 0 UJ C/l 1200 0

~

QJ C1 8GG 0 0 0

~

C3 C3 C) C3 C3 C3 C3 n C3 C)

C) C'4 TINEA'ECONDS

FIGURE I,2-C ST LUCIE UNIT I STRETCH POtIER 0,8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG, LEAK FLOW 1200GO 100000 8GGOO 6GGGG.

4000G 20GOO 0 ~

nn nn C) n a n CD n CD n CD n CD a n n LQ n v) nC4 Cd TINE, SECONDS

FIGURE I,2-D,1 ST LUCIE UNIT I'STRETCH POItfER 0,8 x DOUBLE ENDED SLOT BREAK IN PUflP DISCHARGE LEG FLOW IN HOT ASSEf1BLY-PATH 16, BELOW HOT SPOT 30.000 20 000 10.000 o.ooo

-10 000

-30.000 CD CD CD CD CD CD CD CD CD CD CD nC3 CD CD CD LO n v)

TINE, SECONDS

FIGURE I,2-D,2 ST LUCIE UNIT I STRETCH POLIER 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEHBLY-PATH j.7, ABOYE HOT SPOT 30 000 20 000 10 GGG O.OOG

-10 OGG

-20 000

-30 000 CD CD n nnn n CD CD CD CD ri n d3 in Cd TIME, SECONDS

FIGURE I,2-E ST LUCIE UNIT I STRETCH POtlER 0,8 x DOUBLE ENDED SLOT BREAK IN PUf'IP DISCHARGE LEG HOT ASSBlBLY QUALITY 13, BELOW HOT SPOT

--- NODE NODE 14, AT HOT SPOT

' NODE 15, ABOYE HOT SPOT 1,0 I

I I

0.8 I

l'V I

rr /

0,6 (

I

~

lP

/

0,0 0,2 0,0 0,0 5;0 10,0 15,0 20,0 25.0 TINE, SECONDS

FIGVRf- r,2-F ST LUCIE UNIT I STRETCH POWER 0,8 x DOUBLE ENDED SLOT BREAK IN PUi"IP DISCHARGE LEG CONTA INHENT PRESSURE 60 GGO SO OGO 40 OQG 30 OGO

'0 OGG 10.000 O.OGO CD C) CD nn CD CD n CD C) CD CD n CD n

CD nC) CD n CD CD C) LO TINE AFTER RUPTURE, SECONDS

FIGURE I,2-G ST LUCIE UNIT I STRETCH POWER 0,8 x DOUBLE ENDED SLOT BREAK IN PUf'iP DISCHARGE LEG MASS ADDED TO CORE DURING REFLOOD

~

~rr g

~O VVVS ~

laGGGO 8GGQO.

CD I

5 sccoa.

40GGO

'2QOGO

a. CD CD CD CD CD CD CD CD CD CD 4 4 n CD CD CD CD CD CD CD CD CD CD lQ TINE AFTER CONTACT, SECONDS

FIGURE I,2-H ST LUCIE UNIT I STRETCH POttER 0,8 x DOUBLE ENDED SLOT BREAK IN PUNP DISCHARGE LEG PEAK CLAD TEHPERATURE 22Cu ZQCu ~

)SG0 u

O r sOQ Li3

~l 7.00 1003 8C 60t 0 .>00 200 300 400 Soo 600 TINE, SECONDS

FIGURE I,3-A ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED SLOT BREAK IN PUi'1P DISCHARGE LEG CORE POt'tER 1.2001 1'000 800G 6000

~ 40GO 2000 0 OGG~~

~

nn n nn nn nn nCD CD CD n .nn nCD n N P)

TINEA'ECONDS

FIGURE I,3-B ST LUCIE UNIT I STRETCH POWER 0,6.x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG PRESSURE IN CENTER HOT ASSH'1BLY NODE 2400 0 2000 0 ie00.0 s

O 1200.0

'J CA C/0 CC O

800.0 400 0 0 0

~

o oo CD no CD CD C3 nn nn CD o o n o n LQ o n LO CU CU TIME, SECONDS

FIGURE I,5-C ST LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED SLOT BREAK IN PUttP DISCHARGE LEG LEAK FLOW 120000 100000 8000G UJ CQ 60000 F) 4000G ZOOQG.

0 ~

n nC) CD C7 CD CD CD C7 n

CD n LO n C4 TIPIE, SECONDS

'IGURE I,3-D,1 ST LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG FLOM IN HOT ASSEf'ABLY-PATH 16, BELOW'OT SPOT 30 000 20 000 10 000 0 ~ 000

-10 OGO

-20 OGG',

-30 000 CD n nn C3 CD CD CD C) CD CD CD CD CD CD CD LD CD CD LQ CV TIME. SECONDS

.5

FIGURE I,B-D,2 ST LUCIE UNIT I STRETCH POlIER 0,6 x DOUBLE ENDED SLOT BREAK IN PUlltP DISCHARGE LEG FLOM IN HOT ASSBIBLY-PATH 17, ABOYE HOT SPOT

'30.000 20.000 10 000 0.000

-10.000

. -20 OOG

-30.000 C) CD CD CD

. n CD CD'D CD CD CD CD CD CD C)

CD CD CD CD LO CD LD CV TINE, SECONDS

FIGURE I,Z-E ST LUCIE UNIT I STRETCH P01'tER 0,6 x DOUBLE ENDED SLOT BREAK IN PUNP DISCHARGE LEG HOT ASSENBLY QUALITY NODE NODE 13, BELOW HOT SPOT 10, AT HOT SPOT NODE 15, ABOVE HOT SPOT 1.0

)I tlI

~

l I

I I rr

/

I r I 0,6 I I~ rI v ~~ I I

~

/

1 0,2 0,0 5,0 10,0 15.0 20,0 25,0 TINE, SECONDS

FIGURE I,B-F ST LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED SLOT BREAK IN PUHP DISCHARGE LEG CONTAINi'1ENT PRFSSURE 6G 000 5G 000 40 OOQ 30 000 Q

'0.000 10.000 CD

.CD CD n n CD .

n CD CD CD CD CD CD CD CD CD CD CD C) CD CD (D CU LQ TIi"lE AFTER RUPTURE, SECONDS

FIGURE I,3-G ST LUCIE UNIT I STRETCH POt(ER 0,6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG MASS ADDED TO CORE DURING REFLOOD j'AC'I'l C VVaV 100000 80000 BGGOG I

g 40000.

20000 0 ~

Q CD CD Q Q CD Q Q Q ~

CD ~

Q Q CD Q Q Q Q

Q CD n nlD TIME AFTER CONTACT, SECONDS

F I6URE I,3'-H ST LUCIE UNIT I STRETCH POHER 0,6 x DOUBLE ENDED SLOT BREAK IN PUHP DISCHARGE LEG PEAK CLAD TENPERATURE

."oo Ol 8GQ 1600 1400 LQ

~ 1200 lGGG 8GG 600 0 100 ZGO .

300 480 600 TINE, SECONDS

FIGURE I,Q-A ST LUCIE UNIT I STRETCH POl'IER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG CORE POllER 1 200j 1.0000

.saoc

.6000

'4000

.2000 c.oaoq (D C3 C3 Q.

C) C) C) C7 C3 C) tD CD C)

C) tD C7 C) C)

C) (M P) LD TIf'lE,- SECONDS

FIGURE I 0-B ST LUCIE UNIT I STRETCH POMER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUI'1P DISCHARGE LEG PRESSURE IN CENTER HOT ASSEC'1BLY NODE 2400 0 2000 0 1600 0 1200 0 O

800 0 400.0 0 0

~

CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD lD CD lD CD . LD CU CU TINE, SECONDS

FIGURE I,Q-C ST LUCIE UNIT I STRETCH POMER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG LEAK F.LOM PUMP SIDE REACTOR YESSEL SIDE 120000 100000, 80000, 60000, CC

. CO 40000.

20000 0.

0,0 5,0 10.0 15,0 20,0 25,0 TIgE, SECONDS

FIGURE I,O-D,1 ST LUCIE UNIT I STRETCH POWER 3..0 x DOUBLE ENDED GUILLOTINE BREAK IN PUf'IP DISCHARGE LEG FLOH IN HOT ASSENBLY-PATH 16, BELOlV HOT SPOT 30 000 20 000 10 000 0.000 CC CD

-io.OOO

-2O.OOO

-30 000 lD C3 C)

C) CD C) C) C)

C) tD C)

C)

C) a C)

C) LD LD C) tD TINE, SECONDS

FIGURE I,4-D,2 ST LUCIE UNIT I STRETCH POWER, 1.,'0 x DOUBLE ENDED GUILLOTINE BREAK IN POMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 17, ABOYE HOT SPOT

30. 000 20.000 10 000 0 000 CD IJ

-10 000

-20.000

-30 000 CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD lD CD LO LD CU TIME, SECONDS

FIGURE I,O-E ST LUCIE UNIT I STRETCH POHER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG HOT ASSB]BLY QUALITY NODE 13, BELOM HOT SPOT NODE 10, AT HOT SPOT NODE 15, ABOVE HOT SPOT 1,0

~1 tl o$

f(

0.8 .I 0.6 0,0 0.2 0,0 0 10 20 TINE, SECONDS

FIGURE I, 4-F ST LUCIE UNIT I STRETCH POMER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG CONTAINMENT PRESSURE 6G.GGG 50 GGG 40.0GG 30 GGG

'0.00G 10.000 n

n n

'n n n,

nn nn nn nn CO nn nQ nn n

n LD TIME AFTER RUPTURE, SECONDS

FIGURE I, C=G ST LUCIE UNIT I STRETCH POMER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUPiP DISCHARGE LEG BASS ADDED TO CORE DURING REFLOOD 120000.

100000.

800GG CD I 'I 60000.

40000.

20GGG 0 ~

CD CD CD CD CD CD CD CD CD CD ~ ~

CD CD -CD 'D CD C) tD CD CD CD lD CD C4 CO LD TINE AFTER CONTACT, SECONDS

FIGURE I,Q-H ST LUCIE UNIT I STRETCH POWER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUf1P DISCHARGE LEG PEAK CLAD TEf"IPERATURE 2200 2000 L

L 1SOO .

1600 o

1000 PEAK CLAD TENPERATU E NODE RUPTURE N DE 1200 1000 800 600 0 100 200 500 400 500 600 T It'lE, SECONDS

FIGURE I,4-I ST, LUCIE UNIT I STRETCH POhER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IW PUI'1P DISCHARGE LEG l'1ID ANNULUS FLOH ISQOO IOOOO saoo.

g o.-

cK

-sooa.

-10000

-Isooo C3 Cl C) C3 C) C7 C) C3 C) C3 C3 C) C) C) C3 C)

C3 C3 0 C) lQ C) LD LO 04 04 TIr<E, SECONDS

FIGURE I,O-J .

ST, LUCIE Ui'lIT I STRETCH POMER 1,0 x DOUBLE Ei'>DEu GUILLOTINE BREAK IN PUf'IP DISCHARGE LEG QUALITIES ABOVE AND BELOM THE CORE ABOVE THE CORE

- - - BELOL'( THE CORE 1,0 Ii ) I HI I)

I I I I

I I I

I 0,8 l' I

I I'

I 0,6 I

I I

I 0,4 l

I

/

I I g 0,2 I g I

I lr/

I I

I 0,0 0,0 5.0 10,0 15,0 20,0 TIf'lE, SECONDS

FIGURE I,O-K

~

ST, LVCIE UNIT I STRETCH POWER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUf'1P DISCHARGE LEG CORE PRESSURE DROP 30.000 20 000

'10 OGG 0.000 I

-IO.QQG

-20 000

-30 GOO CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD lO CD LD CD ID CV OJ TIt]Ei SECONDS WRY

~5 FIGURE I.4-L ST. LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG SAFETY INJECTION TANK FLOLC INTO DISCHARGE LEGS 8000 6000 4000 2000 0, 10. 20, 30. 40, 50. 60, 70, 80.

TINE, SECONDS

~ q ~ ~ = 1 wa ', + = ~bl: 'it+w'44IVj>JsiA 4 r, we'A 1+ I 1 6 0+'x w(vA ~ ) ~ 1' rv ' w-'- 'I> .

' ~I'M<<'wW)'so t '

~ '1 I<i'+ 1swso 1ON

I FIGURE I,G-H ST, LUCIE UNIT I STRETCH POWER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUt1P DISCHARGE LEG WATER LEVEL IN DOWNCOI'1ER DURING REFLOOD 18 OGO 15 OGC 12 OGG

a. Oa.

6 000 3.QGO O.OGG C) C) C) C) C3 C3 C) C3 C3 C)

C3 C3 C) C3 C3 C)

C) C) CD C3 C)

C3 M cn lD TINE AFTER CONTACT, SECONDS

FIGURE I,4-N ST LUCIE UNIT I STRETCH POl'vER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IH PUYiP DISCHARGE LEG HOT SPOT GAP CONDUCTANCE 300 700 600 500 400 300 200 100 0 100 200 300 400 500 600 TINE, SECONDS

C 1 i 4 8 ' ~ 4 4 I ~

FIGURE I.Q-O ST, LUCIE UNIT I STRETCH POhER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUttP DISCHARGE LEG PEAK LOCAL CLAD OXIDATION 16 12 PEAK CLAD TEf'tPERATU E NODE RUPTURE N DE 10 OC .

CD 0 100 200 300 LIOO 500 600 70i Tlf'lE, SECONDS

r iuuxt= i, ~-r ST, LUCIE UiNIT I STRETCH POKER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUf1P DISCHARGE LEG CLAD TENPERATURE, CENTERLINE FUEL TEf1PERATURE, AVERAGE FUEL TEf1PERATURE AND COOLANT TEf'IPERATURE FOR HOTTEST NODE 4000 3500 3000 2500 F EL CENTER INE UJ 2000 AVERAGE F EL C D UJ I

1500 1000 500 CO LANT 100 200 300 400 500 600 TIf'1E, SECONDS

FIGURE I,4-Q ST, LUCIE UNIT I STRETCH POWER 1,0 x DOUBLE Ei<DED GUILLOTINE BREAK IH PUf1P DISCHARGE LEG HOT SPOT HEAT'RANSFER COEFFICIENT 000 350 300 250 200 150 100 50 0

0 100 200 300 000 500 600 70i TIl"jE, SECONDS

FIGURE I.4-R ST, LUCIE UNIT I STRETCH POWER 1,0 x DOUBLE ENDED t UILLOTINE BREAK IN PUl"iP DISCHARGE LEG CONTA Iidi'lENT TH1PERATURE 300 250 200 150 100 50 0

0 100 200 300 400 500

- "TINE, SECONDS

~ ' '

FIGURE I,O-S ST, LUCIE Ui<IT I STRETCH POWER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG SUi'1P TENPERATURE 300 250 200

'100 50 0

0 100 200 300 400 500 TINE, SECONDS

FIGURE I,4-T ST, LUCIE UNIT I STRETCH POWER 1,0 x DOUBLE ENDED GUILLOTINE BREAK IN PUI'1P DISCHARGE LEG HOT ROD INTERNAL GAS PRESSURE 1200 P =1087,7 r IA 1000 PTURE=51, 4 sec gR 800 600 400 200 0

0 20 40 60 80 100 TIf1E, SECONDS

FIGURE I,O-U ST, LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG CORE BULK CHANNEL FLOW RATE CORE INLET

- - - - CORE EXIT 30000, 20000.

l 10000,

) I I(

l I

4~

0,

-10000.

BULK CHANNEL REPRESENTS 98X OF TOTAL CORE FLOL'1 AREA

-20000,

-30000, 0,0 5,0 10,0 15,0- 20,0 25,0 TINE, SECONDS

FIGURE I,5-A ST LUCIE UNIT I STRETCH POMER 0,8 x DOUBLE ENDED GUILLOTINE BREAK IN PUHP DISCHARGE LEG CORE POWER 1 2001 1 0000 8000 LlJ CD GL 6000 CD 2000 000q aa aaa aaa aaa aaa 0

aa aa a a a n a a N Li3 TIl'lE, SECONDS

FIGURE I,5-B ST LUCIE UNIT I STRETCH rOWeR 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG PRESSURE IN CENTER HOT ASSEL'lBLY NODE 2400.0 2000.0 1600 0 1200.0 800.0 4oa.o 0 ~0 C7 CD C) CD CD CD CD 'CD CD CD CD C7 CD CD CD C)

CD CD CD tD CD ~ J3 CD LD N N TIf'lE. SECONDS

FIGURE I .5-C ST LUCIE UNIT I STRETCH PONER 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG LEAK FLOtt PUNP SEEEE REACTOR YESSEL SIDE 120000.,

100000 80000, 60000.

CD 00000, 20000.

0.

0,0 5.0 10,0 15,0 20.0 25.0 TINE, SECONDS

FIGURE I.S-D,j.

ST LUCIE UNIT I STRETCH POWER 0,8 x DOUBLE ENDED GUILLOTINE BREAK IN PUI'tP DISCHARGE LEG FLOtl IN HOT ASSBIBLY-PATH 16, BELOW HOT SPOT 30.000 20 000 10.000 0.000 CD

-10 000

-20.000

-30 000 CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD e e CD .LO CD

'O tD TINE, SECONDS

FIGURE I,5-9,2 ST LUCIE UNIT I STRETCH POWER 0,8 x DOUBLE ENDED GUILLOTINE BREAK IN PUHP DISCHARGE LEG FLOH IN HOT ASSENBLY-PATH j.7, ABOVE HOT SPOT 30.000 20.0GG 10.000 0.GOO

-10 000

-20.000

-30. 000 CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD LD CD LQ CD tD N CU TINE, SECONDS

FIGURE I,5-E ST LUCIE UNIT I STRETCH POWER 0,8 x DOUBLE ENDED GUILLOTINE BREAK IN PUl'1P DISCHARGE LEG HOT ASSH"lBLY QUALITY NODE 15. BELOW HOT SPOT NODE 14, AT HOT SPOT NODE 15'BOVE HOT SPOT 1,0 I )~

lI

~ g It I

) 4 I f I tJ I

1, 0,8 l'

~

li

~

g JJI ~

II

/

0,6 l" 1 4

/

0,0 f

i r' I

i 0.2 I I

0,0 0,0 5,0 10.0 15,0 20,0 25.0 TINE, SFCONDS

FIGURE I,5-F ST LUCIE.UNIT I STRETCH POWER 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUflP DISCHARGE LEG CONTAINHENT PRESSURE 60 000 5G 000 40.000 30 OGG CL

'0.000

10. 000 0'. OGO C) C) nn nC) C)

C) C) n C)

CI C) C) C) oP) C) nC) n n C)

M CI tD TINE AFTER RUPTURE, SECONDS

FIGURE I.5-6 ST LUCIE UNIT I STRETCH POINTIER 0,8 x DOUBLE ENDED GUILLOTINE BRM IN PUl'1P DISCHARGE LEG MASS ADDED TO CORE DURING REFLOOD

'QPQG aOGGGC.

8GCGO.

g GOGGO.

C=l

'0CGQ

a. CD CD CD CD CD CD CD CD CD CD ~ ~

CD CD CD CD CD CD ~

CD CD CD CD CD CD CU P) LO TIME AFTER CONTACT, SECONDS

FIGURE I 5-H ST LUCIE UNIT I STRETCH POWER 0,8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG PEAK CLAD TEMPERATURE 2200

', .2000 1800 j600 o

~1400

~~ l 200 1000 800 6GG

'00 0 100 200 300 400 TIMEi SECONDS

FIGURE I,6-A ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUfkP DISCHARGE LEG CORE POWER 1 20G1 1.GGGG r

.8000

~

~ .GGGG CD

.2000 O.QGOg CD n CD CD n

CD CD CD CD CD CD CD CD CD CD CD CD

<<D CD CD a CD CD CD LD TINEA'ECONDS

FIGURE I,6-B ST LUCIE UNIT I STRETCH POHER 0,6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG PRESSURE IN CENTER HOT ASSB1BLY NODE

'h 4 (QQ IQ

~

2aco.a 1600 G 1200 0 saa.o 400.0 0 0~

D CD CD CD CD CD D CD CD CD CD CD CD D CD CD CD CD CD 'd3 CD U3 CD LD CU TINE, SECONDS

FIGURE I,6-C ST LUCIE UNIT I STRETCH POMER 0,6 x DOUBLE ENDED GUILLOTINE BREAK IN PUl'"1P DISCHARGE LEG LEAK FLOtd I

PUNP SIDE

. REACTOR VESSEL SIDE 120000,

.100000, 80000, C

60000.

CD Ll L$ 0000, 20000, 0,

0,0 5,0 10,0 15,0 20,0 25,0 TINE, SECONDS

FIGURE I,6-D', j.

ST .LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG FLOW IN HOT ASSH'lBLY-PATH 16; BELOW HOT SPOT 30 000 20.00G IO.OOG 0 000 CD

-10 000.

-20 000

-30 000 CD tD C3 C) C3 C3 O CD C) lD C) tD O C3 C)

C)

C) LD C) 'd3 C) LD CU CU TINE, SECONDS

FIGURE I,6-9,2 ST LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED GUILLOTINE BREAK IN PUPIP DISCHARGE LEG FLOM IN HOT ASSENBLY- PATH 17, ABOVE HOT SPOT 30 GGO 20 000 L

10 000 0.000 I

CO

-10.0GG

-20.000

-30.000 CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD e e CD LO CD LO CD ID CU TINE, SECONDS

FIGURE I.6-E ST LUCIE UNIT I STRETCH POHER 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUilP DISCHARGE LEG HOT ASSH'IBLY QUALITY NODE NODE 13, 14, BELOW HOT SPOT AT HOT SPOT NODE 15, ABOVE HOT SPOT I

t I J,'l ~

lg

~

l',

I I t

I o J;

0.8 I lt I rr J I

lt l

,I I

/

Ct 0.6 J h I I t

~

I /

~

4 t t . r'o 0.0 I l /

I I

Og

/

I t

I I

0,2 0,0 o.o 5,0 10,0 15,0 20,0 25,0 TINE. SECONDS

FIGURE I,6-F ST LUCIE UNIT I STRETCH PONER 0,6 x DOUBLE ENDED GUILLOTINE BRM IN PUMP DISCHARGE LEG CONTAINMENT PRESSURE 6o.oee SG.GGG 40 OGG 30 OGG

'0 OOG 10 000 0 000 CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD CD P)

TIME AFTER RUPTURE, SECONDS

FIGURE I.6-G ST LUCIE UNIT I STRETCH POMER P,6 x DOUBLE ENDED GUILLOTINE BREAK IN PUNP DISCHARGE LEG MASS ADDED TO CORE DURING REFIOOD

20GGG LOOGGO SGOGO.

I 6GGGG 40GCO.

20000 0 ~

- CD n CD CD Q

.n, CD nn CD'D CD CD CD CD CD CD CD CD C)

OJ n

(f) a CD LQ TINE AFTER CONTACT, SECONDS

FIGURE I,6-H ST LUCIE UNIT I STRETCH PO>lER 0,6 x DOUBLE ENDED GUILl OTINE BREAK IN PUNP DISCHARGE LEG PEAK CLAD TENPERATURE 2000 1600 1400 o

~~ 1200

+1000 600 400

>00 :00 300 400 500 600 TINE, SECONDS

FIGUPL". 1.7 ST. LUCIE UNIT I STRETCII PO'HLR PEAK CLAD TEYiPERATURE vs, BREAK AREA 2200 2100 2000 0 DISCHARGE- LEG SLOTS ClDISCHARGE LEG GUILLOTINES 1900 1800 DISCHARGE LEG BREAKS U3 OQ CD CD CD 1700 0

BREAK AREA, FT

. Tab'le 1 Characteristics of St. Lucie 1 and Millstone 2

~ !

St. Lucie I St. Lucie I Millstone 2

\

Full power, level, Hwt {102~ of Homina1) 2754 2754 Peak linear heat rata, kvl/ft 16.0 16.0 Average 1'inear heat rate, h~/ft 6.43'51 6.40 Core in1et temperature, 'F 551 Core outlet ~perature, 'F 602 602 Active core height, ft 11.39 11.39 Fuel rod OD, in 0.44 0.440 Number of cold 1egs '.

4 t/umber of hot legs '2 Cold leg diam ter, in 30 30 Hot 1eg diameter, in 42 42 Total primary system volume,

~

ft 10,867 10e853 Active core vo1ume, ft 655 653

~

Primary system va'la=.a abave tap af care. ft 8280 8129 Low pressurizer pressure scram setpoint, psia 1750 1750 Enitial system pressure, psia 2250 2250 Safety injection actuation signal setpoint, psia 1600 1600 Setpoint uncertainties, psi +22 +22 Safety injection tank pressure/liquid volume, 215/1090 215/ll07 psia/ft3 High pressure safety injection pump runout flow, 640eeslr 655" gpm High pressure safety injection pump flow at 31 5~

steam generator secondary relief valve setpoint, (985 psig), gpm High pressure. safety injection pump shutoff head, 1245 1225 psia Low pressure safety injection pump runout flow, 4000 3750.

gpm Low pressure safety injection pump shutoff head, 207 psfa

~ "IncIudes charging pmnp flow.

~Excludes charging pump flow.

o

~ ~

Section 9 I

I ST. LUCIE UNIT 1 REACTOR PROTECTION SYSTEM ASYNMETRLC STEN$ GENERATOR TRANSIENT PROTECTION TRiP FUNCTION L'ICENSlNG OESCRLPTiON 0

1.0 INTROOUCTION This document describes the Reactor Protection System (RPS) Asymmetric Steam Generator Transient Protection Trip Function (ASGTPTF) and its design bases.

The ASGTPTF is designed to protect against Anticipated Operational .Occurrences (AOOs) associated with secondary system malfunctions which result in asymmetric primary loop temperatures. The most limiting event is the Loss of Load to One. Steam Generator (LL/lSG) caused by a single thain Steam. Isolation Valve (NSIY) closure.

The St. Lucie I RPS presently employs an analog thermal margin trip calculator as part of the Thermal Margin/Low Pressure (TH/LP) trip function. To provide a reactor trip for asymmetric design basis events, pressure in each of the two steam generators will be monitored and these signals input to the thermal margin calculator. Secondary pressure imbalances between the two genej.ators wi11 be calculated and a corresponding factor applied in the Tl</LP calculator to generate a trip signal.

H P>otection against exceeding the ONBR and maximum Kw/Ft Speciried Acceptable Fuel Oesign Limits (SAFOL's) during the LL/1SG event is presently provided by the Low Steam Generator Level reactor trip in conjunctioh with sufficient initial margin maintained by the Limiting Conditions for Operation (LCO's).

'he ASGTPTF will result in a reactor trip sooner than the Low Steam Generator Level trip and, hence, will produce a smaller margin degradation during this event. The additional margin gain allows full advantage to be taken of margin recovery programs designed to achieve stretch power, and 18 month.

fuel cycles for St. Lucie 1, Cycle 4, by assuring that the asymmetric .

transients would not be limiting AOO's for establishing the LCO's.

2e 0 SYSTEM OESCR IPTIOH 2.1 GeneraI The ASGTPTF consists of:

Existing s.earn generator pressure sensors -(one for each steam generator per channel} and associated process equipment.

2. Existing Thermal Margin/Low Pressure (TH/LP) calculator~ modified to inc1ude a bistable with an input of the absolute value of the press'u're difference between the t>>o steam generators )P - P [ Th of the bistable signa1s- the TN/LP calculation when trip conditi n z ons are reached.,

3. Existing RPS trip logic and Reactor Trip Switchgear.

Modifications to the existing TN/LP calculator>>i11 he discussed next as

. the rest of the system consists of previously licensed instal'led equipment.

A functional block diagram of this portion. of the system'is provi pro d e d in

i Figure l.

2.2 TM/LP Modifications

~ 4 A steam, generator oressure signal is input to each of the TH/LP calculators from each steam generator. fn each Ti</LP calculator, the difference bet>>een the t>>o pressure signals is calculated. tf the difference exceeds' set amount, a bias is input to the Tit/LP calculation. This will result, in a reactor trip. Tne additional bias input'to the Tt1/LP i 1 I ymme ric factor signal (Fas). This will raise the setpoint to a high enough level to ensure a trip i f the steam genera" or oress ures d irrer b y more than the set point i value. Figure 2 illustrates the functional relationship

~

between the absolute value of the pressure difference (P - P SGZI,

~, an d the Sal asytnttetric factor signal, Fas.

3.0 OESIGN BASES 3.1 Cesi n Basis Events The ASGTPTF is designed to provide a reactor trip for those design basis events associated with secondary system malfunctions which result in asymmetric primary loop coolant temperatures. The most limiting event is the LL/lSG caused by a single Hain Steam Isolation Valve I,'HSLY) closure..

LZ ~lh t C f The ASGTPTF is designed to the following criteria to ensure adequate performance of its trip function:

a. The trip function is designed in compliance with the applicable criteria of the General Oesign Criteria for Nuclear Po~er Plants, Appendix A of 10 CFR 60, July 15,=1971..

b. Instrumentation, function and operation of the trip logic conform to the requirements of IEEE Standard 279-1968, Criteria f'r Protective Systems

'or Nuclear Power Plants.

c. The trip. function is designed consistent with the recommendations of Regulatory Guide 1.53, Application of the Single-Failure Criterion to Nuclear Power Plant Protective Systems, and Regulatory Guide I..22, Periodic Testing of Protection System Actuation Functions.

d. , Four independent measurement channels are provided, C

e. The prot ctive system ac po~er is supplied from. four separate vital instrument buses.

f. The ASGTPTF cart be tested with the reactor in operation or shut down.

g. Trip signal is preceded by a pretrip alarm to alert the operator of undesirable operating conditions in cases where operator action can correct the abnormal condi tion and avoid a reactor trip.

h. The ASGTPTF components which will be used are of the same type presently in use at SLl, and will meet the same industry standard as applied'o the original RPS (i.e., ?EEE-279, August 1968}. Tne operation of the ASGTPTF is not required during or subsequent to any Oesign Basis Event which significantly alters the containment environment (LOCA, Hain Steam fine Break or Feedkater Line Break) . Therefore, i t is not required that additional in-containment equipment installed specificaIIy for the ASGTPTF be qualified for the adverse environments associated with these events.

The trip function is designed so that protective action will not be initiated due to normal operation of the generating station.

A11 equipment will be designed in accordartce with the gAGi4l. Vendor quality control will be irt accordance with C-E Procedure NgC 11. 1, Revision 0.

C

k. Modification to the TH/LP CaIculator For the ASGTPTF will not jeopardize previous qualification of this equipment.

3.3 Performance Re uir ements The selection of a trip setpoint is such that adequate protection is provided when all sensor and processing, time delays and inaccuracies are taken into account. Final determination of an equipment setpoint is based on equipment characteristics, operating environment, NSSS performance and safety analysis.

The nominal setpoint, uncertainties and response time are provided in Table 1.

TAOLE $

t ASYHMETRIC STEAN GENERATOR TRANSIENT PROTECTlON TRlP FUNCT!ON NOHfNAL CHARAGTERlSTfCS Hominal System Accuracy f35 psi Analysis Setpoint 4175 psid Homioal Equipment Setpoint +140 psid Hominal Pretrip Setpoint +100 psid Nominal System Response Time. < 9 seconds Homiqal: Expected value only. Final values are to be. determined later, and included in the plant Technical Specifications as appropriate.

~ ~

S3 ) FLOW DEPENDENT SETPOINT rC SELECTOR SWITCH IN RPSCIP POSlTIONS- l. 4 PUMPS 4 R Inured

2. 3 PUMPS S3 (RPSCIP) 3. 2 PUMPS-OPP. LOOPS

~

4. 2 PUMPS-LOOP l T P CAL 5. 2 PUMPS-LOOP 2 X

X D TC+KC (RPSCIP)

U KC QA AXIAL AXIAL FNCT OFFSET (RPSCIP)

Y 0

0-QA I-cl (Cont 0 QRI TCAL Rj- R.

QRl DNB' <'bNB . Beloved) l I /

I Q I Ps>;, ) 53 (RPSCIP)

CEA FNCT I I Fis Prig I i Psr- P44.) l I L I P

VAR MAX VAR 'R (Abpve) ALARMs QONB+P ICAL+ R SEI. gh4se -T +

P(P PRETRIP T

CAL C K

C B

'. Q. MAX(f B)

TRIP Z UNlT TRIP VAR MIN PRETRIP TRIP: 1 I

7 MIN P = PRIMARY TRIP I'RETRIP TRIP PRESSURE TH/LP ftodi fication for Asymmetric SG Transient Protection (Changes to the TH/LP Calculators are shown in dashed lines).

FIGURE l

>2500 Setpoint

~

SGI S62~

FIGURE 2 ASYMMETRIC as vs. lI'SGI - I'S62l FACTOlt SIGHAl

ATTACHMENT 4 ST. LUCIE UNIT I STRETCH POWER ENVIRONMENTAL REPORT

TABLE OF CONTENTS Pacae Section 1 - INTRODUCTION Section 2 - THE SITE AND ENVlRONMENTAL INTERFACES 2.1 Site Location and Description 2 2.2 Population 2 2.3 Land and Water Use 2 2.4 Meteorology 2 2.5 Ecology 2 2.6 Hydrology 2 2.7 Geology 3 2.8 Regional Historic Features 3 Section 3 THE PLANT 3.1 External Appearance 4 3.2 Reactor and Steam Electric System 4 3.3 Plant Water Use and Heat Dissipation 4 3.4 Radwaste System 4 3.5 Chemical'nd Sanitary- Wastes 4 3.6 Electrical Distribution 4 Section 4 ENVIRONMENTAL EFFECTS OF PLANT OPERATIONS 4.1 Non-Radiological Eff'ects 4.2 Radiological Effects 5 - EFFLUENT MONITORING

'ection 5.1 Non-Radiological Monitoring 6 5.2 Radiological Monitoring 6 Section 6 - ENVIRONMENTAL EFFECTS OF ACCIDENTS 6' Loss of External Load Accident and/or Turbine Stop Valve Closure 6.2 Excess Load Accident 12 6.3 Major Reactor Coolant System Pipe Rupture (Loss-of-Coolant Accident) 16 6.4 Waste Gas Decay Tank Leakage or Rupture 16 6.5 Steam Generator Tube Failure 16 6.6 Control Element Assembly Ejection Accident 23 6.7 Steam Line Break Accident 29 Section 7 - ALTERNATE ENERGY SOURCES 35

ATTACHMENTS St. Lucie Unit 2 Environmental Report Operating License, Sections 2.1.1, 2.1.2 and 2.1.3, St. Lucie Unit 2 Final Safety Analysis Report, Section 2.1.2 St. Lucie Unit 2 Final Safety Analysis Report, Section 2.3 St. Lucie Unit 2 Environmental Report Operating License, Section 2.2 St. Lucie Unit 2 Environmental Report Operating License, Section 2.4 St. Lucie Unit 2 Environmental Report Operating License, Sections 3.3 and 3.4 St. Lucie Unit 2 Environmental Report Operating License, Section 6.1

Section 1 INTRODUCTION The Florida Power & Light Company has prepared this document in support of an application to the U.S. Nuclear Regulatory Commission to increase the generating capacity of St. Lucie Unit 1 by 40 Mwe (electric) in order to assess the environmental impacts associated with such an increase.

Currently, St. Lucie Unit 1 operates at 2560 Mwt (thermal) core power in accordance with Operating License DPR-67 obtained March 1, 1976. It is planned to increase (stretch) core power to a level 5.4% greater than the present level, i.e., from 2560 Mwt (thermal) to 2700 Mwt (thermal).

The primary objective in obtaining a stretch rating is to reduce some future capacity additions to FPL's system and to allow a reduction in the amount of petroleum consumed by FPL. The stretch power developed at St. Lucie Unit 1 would save approximately 450,000 barrels of oil per year thus providing-economic benefits to FPL's customers and as'sist the nation towards the goal of energy self-reliance. The economic benefits can be shown by comparing the cost of generating electricity with oil versus nuclear fuel. Differential fuel costs for 1980 are approximately 30 MILS per KWHr using low sulfur oil. A savings to consumers of 98.5 million per year could be realized at this differential by increasing the generating capacity of St. Lucie Unit 1.

The following report demonstrates that stretch power at St. Lucie Unit 1 will have no adverse impact on the environment.

Section 2 THE SITE AND ENVIRONMENTAL INTERFACES 2.1 Site Location And Description A comprehensive description of the St. Lucie site and its location is given in Se'ction 2.1.1 of the St. Lucie Unit 2 Environmental Report Operating License. (See Attachment 1) 2.2 Population A study of the distribution of the present and projected resident population within 50 miles of the St. Lucie site and the transient population within 30 miles of the site is given in Section 2.1.2 of the St. Lucie Unit 2-Environmental Report Operating License. (See Attachment 1) 2.3 Land And Water Use A detailed description of present and projected land and water uses within 50 miles of the plant. site is given in Section 2.1.3 of the St.

Lucie Unit 2 Environmental Report Operating License. (See Attachment 1)

The authority and control of land and water uses within the site boundary lines is summarized in Section 2.1.2 of the St. Lucie.Unit 2 Final Safety Analysis Report. (See Attachment 2) 2.4 Meteorology Discussions of regional climatology, local meteorology and onsite meteorological measurement. program and estimates of short-term and long-term diffusion of airborne contaminants are presented in Section 2.3 of the St. Lucie Unit 2 Final Safety Analysis Report. (See Attachment 3) 2.5 Ecology Section 2.2 of the St. Lucie Unit 2 Environmental Report - Operating License discusses- the ecological aspects of the vicinity of the St. Lucie Units 1 and 2 site. The discussion includes detailed descriptions of the terrestrial vegetation, wildlife, and aquatic ecology of Hutchinson Island and the surrounding area. (See Attachment 4)

2. 6 Hydrology The Atlantic Ocean, east of the plant site, provides most of the water required for plant operation, and receives liquid wastes and waste heat from plant operation. Surface water hydrology and water quality characteristics of the Atlantic Ocean in this area are described in Section 2.4 of the St. Lucie Unit 2 Environmental Report - Operating

License. (See Attachment 5) The groundwater regime at the St. Lucie site and in the surrounding region is described in Section 2.5 of the St. Lucie Unit 2 Environmental Report Construction Permit.

2.7 Geology A description of the major geological aspects of the St. Lucie and surrounding environs is presented in Section 2.4 of the St. Lucie Unit 2 Environmental Report Construction Permit.

2.8 Regional Historic Features The regional historic, archeological, architectural, scenic, cultural, and natural features of the area surrounding St. Lucie Unit 1 will not be impacted by stretching core power.

Section 3 - THE PLANT 3.1 External Appearance No change ia plant external appearance will occur due to increased power level.

3.2 Reactor And Steam Electric System A comprehensive description of the reactor and steam electric system is presented in Sections 4.0 and 10.0 of the St. Lucie Unit 1 Final Safety Analysis Report. Operation at stretch power will not require design modifications to the reactor and power generation system. The NSSS thermal power level will be increased from 2570 to 2710 Mwt. Electrical power generating capacity will increase to 879 Mwe. Saturated steam flow (full load) will increase to 11.9 x 106 1b/hr. Secondary steam pressure will remain essentially unchanged at 815 psia. Other operating parameters will not Be affected by operation at stretch power.

3.3 Plant Water Use And Heat Dis'sipation A description of plant water uses and the heat dissipation system is given in Section 3.3 and 3.4 of the St. Lucie Unit 2 Environmental Report

- Operating License. (See Attachment 6) There will be no change in plant water use due to operation at stretch power. Since circulating cooling water flow'ill remain unchanged while heat re)ection is increased during operation at stretch power, the delta T of the cooling water will increase from 24' to about 25.5' at full circulating. water flow (1150 cfs).

No modification in the heat dissipation system is required to accommodate the increased po~er level. The environmental impact of the thermal discharge is discussed in Section 4.1 below.

3.4 Radwaste System As described in Chapter ll of the St. Lucie Unit 1 Final Safety Analysis Report, the radwaste systems have been designed to accommodate reactor operation at 2700 Mwt. Thus no modification of the radwaste system is required for operation at stretch power.

3.5 Chemical And Sanitary Wastes Operation at stretch power will not affect chemical and sanitary waste .

systems at St. Lucie Unit l.

3.6 Electrical Distribution Operation at stretch po~er will not require any modification to ithe existing distribution facilities.

Section 4 -'NVIRONMENTAL EFFECTS OF PLANT OPERATION 4.1 Non-Radio1ogical Effects Applied Biology, Inc (1978)* analyzed the effects of thermal discharge for St. Lucie Uni't 1. The analysis describes the effects of thermal discharges of up to a delta T of 28' at full circulating water flow and up to 32' at reduced circulating water flow. Operation of St. Lucie Unit 1 at stretch power will result in a delta T of 25.5' (See Section 3.3 above). Thus the results of the analysis of Applied Biology, Inc (1978) are. conservative with respect to the thermal discharge at stretch power. Operation at stretch power will not require modification of. the existing NPDES Permit for St. Lucie Unit 1, which specifies a maximum delta T for the circulating ~ater of 26'.

4.2 Radiological Effects As indicated in Section 3.4, modification of the radwaste system is not to support operation at stretch power, and no significant 'equired increases in radiological releases are expected to occur. All releases are made in accordance with the dose design objectives of 10 CFR 50, Appendix I.

Applied Biology, Inc. 1978. Effects of Increased Water Temperature on Marine Biota of the St. Lucie Plant Areas. December, 1978.

Section 5 - EFFLUENT MONITORING 5, 1 Non-Radiological Monitorimg Non-radiological monitoring programs for St. Lucie 1 are described in the St. Lucie Unit 1 Technical"'Specifications- and NPDES permit, and in Section 6.1 of the St. Lucie Unit 2 Environmental Report Operating License.

(See Attachment 7) Operation at stretch power will not require any modifications to existing non-radiological monitoring programs.

5.2 Radiological Monitoring The Operational Radiological Environmental Surveillance Program is conducted to measure radiation levels and radioactivity in the environs, and to assist in verifying any projected or anticipated radioactive releases resulting from plant operations. The, ongoing program is described in detail in the St. Lucie Unit 1 Environmental Technical Specifications.

No change to the program is expected due to the operation of St. Lucie Unit 1 at stretch power.

Section 6 ENVIRONMENTAL EFFECTS OF ACCIDENTS In order to insure that the exposure requirements of 10CFR100 and the various Standard Review Plans. (SRP"s) are met during stretch power operation, the following accident analysis is presented. Emphasis has. been placed'n tliose more severe accidents that could result in the release of radioactive materials and could have significant radiological consequences involving the general public. Although this type of analysis is presented in the St. Lucie Unit 1 Environmental Report,".the realistic postulated accident assumptions of Regulatory Guide 4.2, Revision 2 have not been used. Rather, applicable accident assumptions presented in the various Regulatory Guides and SRP's for use in the Safety Analysis Report have been used as identified herein. Evaluations of accidents are performed at an assumed power level of 2764 Mwt, which represents 102% of the NSSS thermal power level of 2710 Mwt. Brief descriptions of each accident, taken from the St. Lucie Unit 1 FSAR, are provided here. More detailed accident scenarios are given in Chapter 15 of the St. Lucie Unit 1 FSAR.

6.1 Loss of External Load Accident and/or Turbine Stop Valve Closure A large rapid reduction of power demand on the reactor while operating at full power can cause a corresponding reduction in the rate of heat removal from the reactor coolant system. The most probable cause of this accident i',s a turbine trip. This accident can also be postulated to result from abnormal variations in network frequency.

The plant is. designed to accept a 45% step reduction in load without actuating a reactor trip signal. In the event of a complete loss of load, the steam dump and bypass system is normally available to remove energy from the reactor coolant system. When no credit is taken for the steam dump and bypass system or the pressurizer power operated relief valves as was 'done for this analysis, the pressurizer and main steam safety valves function to ensure that neither the reactor coolant system nor the steam generator pressures exceed their design limits.

The sequence of events for this accident is given in Table 6.1-1. The assumptions used to calculate the radiological consequences are provided in Table 6.1-2, the calculated radionuclide releases are presented in Table 6.1-3. As shown in Table 6.1-4, the offsite doses which result from this accident are small fractions of the 10CFR100 exposure limits.

TABLE 6. 1-l Se uence of Events for a Loss of Load Accident TMe sec) Event 0.0 Complete loss of secondary load 5.l Secondary safety valves open 7.8 High pressurizer pressure reactor trip (2422 psia)

PORV's fail to open. S.team Dump and Bypass valves fail to open. Feedwater flow ramps to 5Z.

9.0 Primary safety valves open (2500 psia) 9.2 CEAs stax't to drop into the core safety valves close 'rimary 380. Secondary safety valves close l800 Plant cooldown initiated using steam dump to atmosphere.

o 9000 Avex'age reactor coolant tempexature < 325 F, shutdown cooling initiated

TABLE 6.1-2 AssumD eions Xnitial Power (including ptznp haae) 2764 We Xnit'al RCS Pressure 2200 psia Xnitial. Main Steam Pressure 820 psia Moderator Temperature Coefficient +O.5(-4}aP/ F Pressurizer..PORVs ara not operable Steam Dump and Bypass System is not operable '

Operator initiates plant cooldown procedure at 30 minutes.

DEC of X-131 Reactor Coolant 60 uCi/gm

'econdary Coolant 0t,uCi/gm Noble Gas"Conc. in Reactor Coolant FSAR Table 11.1-1 Primary-eo-Secondary Leakage Atmospheric Diffusion 0-2 Hour at the EAB 1.2(-4)sec/m 3 0-8 Hou at ehe LPZ 6. 6(-5) sec/m 3.

Breathing Rate 3.47(-4)m 3 /sec Mass of Steam Released Secondary Safety Valves 0 30 minutes 112000 ibm Atmospheric Dump Valves O.S-2.0 hours0 days 0 hours 0 weeks 0 months 529000 ibm 2.0-2.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months 166000 ibm

TABLE 6.1-3 Radionuclide Releases Release (Curies)

Q-2 hours Duration I-131 DEC 5.6 7.1 ~

Kr-85m 6.8(-1) 8.5(-1)

Kr-85 4.O(-1) 5.O(-1)

3. 7(-l} 4.6(.-l) 1.5 Xe-L33m 6.7 (-1) 8. 4 C-1)

Xe-133 8.2(+1) 1.O(+2)

. Ze-135 3.4 4.3 Xe-138 .1.6(-1) 2.Q(;1)

TABLE 6. 1-4 Radiolo ical Consequences of a Loss oi External Load Accident Dose R~

At the EAB

%hole Body That'oid

%hole Body Thyroid

6.2 Excess Load Accidents.

An excess load accident is defined as any rapid, increase in steam generator steam flow other than a steam line rupture. Such rapid increases in steam flow result in a power mismatch between core power and steam generator load demand. Consequently, there is a decrease ia reactor coolant temperature and pressure. Under these conditions a negative moderator temperature coefficient of reactivity causes an increase im core power.

The high power level trip provides protection against damage to the core as a consequence of an excessive load increase since the high power trip set point is a function of initial power level. Additional protection is provided by other trip signals including high rate-of-change of power, thermal margin, low steam generator level, and..low steam generator pressure.

The specific excess load accident analyzed was the inadvertent opening of a power operated atmospheric dump valve, while at hot standby'con-ditions. TIie assumptions used to calculate the radiological conse-quences're presented in Table 6.2-1, the radionuclide releases cal-culated are presented in Table 6.2-2. The offsite doses which result from this accident, shown in Table 6.2-3, are small fractions of the 10CFR100 exposure limits, TABLE 6.2-1 Assume tions Initial Power 1.0 Hwt (2 loop, no load) 534'P Core chalet Temperature Secondary Pressure 915 psia Atmospheric Dump Valve Plowrate 85 lbs/sec Credit was not taken for the reduction in secondary pressure during J

the event which would reduce the atmospheric dump valve flowrate.

No reactor trip occurs due to the increased steam flow. The event is terminated by remote manual closure of the valve by the operator.

DEC of I-131 Reactor Coolant 60 uci/gm Secondary Coolaat 0.1 uCi/gm Noble Gas Reactor Coolant PSAR Table 11.1-1 Primary to Secondary Leakage 1 agpm Atmospheric Diffusion 3 0-2 hours at the EAB 1.2(4)sec/m 0-8 hours at the LPZ 6.6(-5)sec/m3 Breathing Rate 3.47(-4)m 3 /sec Mass or Steam Released Atmospheric Dump Valves 0-10 minutes 51000 ibm TABLE 6.2-2 Radionucli.de Releases Release (Cuzies)

I-131 DEC 4.. 6(-1)

Kr-85m 5.6( 2)

Kx'-85 3.4(-2)

Kr-87 3.1( 2)

Kx'-88 9.8(-2)

Xe-132m 5.6(-2)

Xe-133 6.9 Xe-135 2.9(-1)

Xe-138 1.4(-2) 14-

TABLE 6.2>>3 Radiolo ical Consequences of An Evcess Load Accident Dose Rem)

At the EAB Whole Body z.o (-s)

Thyroid 2.8.. (-2)

A,t the LPZ Whole Body l.l'-5)

Thyroid 1.6:(-2)

- 15

6,3 Major Reactor Coolant Syst~ Pipe. Rupture (Loss-of-Coolant Accident)

The radiological consequences. og a major reactor coolant system pipe rupture (LOCA)'ave not b'een recalculated for the stretch power case. This was not done because the analysis- presented in the FSAR.was based"upon Regulatory Guide 1.4 assumptions and was performed't a 2700 Mwt core power level.

Regulatory Guide 1.4 assumes standard radionuclide core release fractions into the containment which are independent of power level ('100% of the noble gases and 50% of the iodines). Therefore, even if stretch power operation has an effect on plant parameters (temperature, pressure, etc) following a LOCA, any effect on the core release fractions assumed.

it will not have Also, Regulatory Guide 1.4 assumes that the containment-leaks at its Technical Specification limit following a large LOCA (1/2 the Tech Spec limit after one day) regardless of the post LOCA containment'ressure.

The power level assumed in the analysis of a large LOCA would have an effect on the core radionuclide inve'ntory. This in turn may

,have an effect on the radiological consequences of such an accident.

The FSAR assumed core power level of 2700 Mwt is within about 2% of the stretch NSSS thermal power level of 2764 Mwt. This is well within the uncertainty of this type of calculation.

6.4 Waste Gas Decay Tank Leakage or Rupture As with the LOCA, the radiological consequences of a waste gas decay tank rupture have not been reana'lyzed for the stretch power case.

This was not done because changes in plant parameters (temperature, pressure, etc) which may occur due to stretch power operation are expected to have little effect on the radiological activity release for this type of accident.

Since the FSAR assumed core power level of 2700 Mwt is within about 2%

of the stretch NSSS thermal power level of 2764 Mwt, the radionuclide inventory of the waste gas decay tanks is expected to change by only this amount. Two percent is wel'1 within the uncertainty for this type of calculation.

6.5 Steam Generator Tube Failure The steam generator tube failure is a penetration of .the barrier between the reactor coolant system and the main steam system. The integrity of this .barrier is significant from the standpoint of radiological safety in that a leaking steam generator tube allows for the transfer of reactor coolant into the main steam system. Radioactivity contained in the reactor cool'ant mixes with water in the shell side of 16-

the affected steam generator and is transported by steam to the turbine and then to the condenser, or directly to the condenser via the main steam dump and bypass system. Noncondensible radioactive gases in the condenser are discharged to the atmosphere by the condenser air ejector.

For this analysis, an area equivalent to a double-ended break of one steam generator tube is assumed. At normal operating conditions the leak rate through the double-ended rupture of one tube is greater than the maximum flow available from three charging pumps. Consequently, the reactor coolant system pressure decreases and a low pressurizer pressure trip occurs; Following this trip, the reactor coolant average temperature is reduced by exhausting steam through the main steam dump and bypass system.

The sequence of events for this accident are given in Table 6.5-1.

The assumption used to calculate the radiological consequences of a steam generator tube failure are provided in Table 6.5-2, with the radionuclide releases being given in Table 6.5-3. The radiological consequences presented in Table 6.5-4 are well within the 10CFR100 exposure limits for this accident.

TABLE 6.5-1

.'Se 'uence 'of Events Of A

'"Steam Generator 'Tube'Failure 4

'Time 'sec) 'vent 0 Rupture occurs 540 Low pressurizer pressure trip (1853 psia),

rods drop. Steam dump and bypass valves quickly open. Feedwater flow ramps down to 5% of flow.

552 Pressurizer empties. Safety injection initiated (1578 psia) 592 ,Steam dump and bypass valves close I

944 Pressurizer begins to refill 1800 Plant cooldown initiated using steam dump to'ondenser.

9000 Average reactor coolant temperature <325'F, shutdown cooling initiated.

18-

TABLE 6.5-2 As sumo tions Xnitial Power 2764 MRt (including pump heat)

Xnitial RCS Pressure 2300 psia Initial Main Steam Pressure 810 psia Qow initial steam pressure leads to slightly greater releases)

A double ended rupture of one steam generator tube occurs instantaneously.

The discharge rate thzough the break is assumed to be proportional to the square root of the pressure differential between the prim'Lxy side and the secondary side.

Under full load operating conditions, the steam mixture containing reactor coolant passes through the turbine and condenser, Following the reactor and turbine trip, the main steam dump and bypass system is automatically actuated for removal of decay heat fzom the reactor coolant system.

The reactor- coolant pumps are left in operation even after safety infection occurs.

At the end of 30 minutes the reactor operator has diagnosed the problem and has isolated the damaged steam generator by closing the main steam isolation valve. Plant cooldown procedures are then initiated.

DEC of X-131 Reactor Coolant 60 uCi/gm Secondary Coolant 0.1 uCi/gm Noble Gas Concentration PSAR Table 11.1-1 in Reactor Coolant No credit was taken for the reduction oi the specific fission produce inventory in the reactor coolant system resulting from dilution, safety infection and charging flow.

Primary- to-Secondary Leakage e 6. 3 (+4) ibm Steam Generator Xodine Decontamination Factor 10 19-

TABIZ 6;5-2 CCont'd)

Assumotions Atmospheric Diffusion 0-2 Hours at the EAB 1,2(-4) sec/m 33 0-8 Hours at the LPZ 6.6(-5) sec/m 3

Breathing Rate 3.47(W) m /sec Mass of Steam Released Condenser'ia the Turbine (NOD Hour 1810000. ibm Condenser vXa the SD&3 Valves 0-03 Hour 46000 1bm 0.5-24 Hours 549000 ibm 2.0-2. 5 Hours 158000 1bm 20-

TABLE 6.5-3 Radionuclide Releases Release Curries)

T-131 DEC X.8(+1)

Kr-85m O.3(+1)

Kr-85 2.5(+1)

Xe-87 2.3(+1)

Q-88 7.4(+1)

Xe-131m a.2(+1)

Xe-133 5,2(+3)

Xe-135 2.2(+2)

Xe-138 1.O(+1)

Radiolo ical Consequences Of A Steam Generator Tube Failure

~0z an Dose (Rem)

At the EAB Whole Body Thyroid ht the LPZ Whole Body 7.1.(<<3)

Thyroid 6,2 22

6.6 Control Element Assembly Ejection Accident Rapid ejection of a control element assembly (CEA) from the core would require a complete circumferential break of the control element drive mechanism (CEDM) housing or of the CEDM nozzle on the reactor vessel head. The CEDM housfng and CEDM nozzle are an extension of the reactor coolant boundary and designed and manufactured to Section III of the ASME Boiler and Pressure Uessel Code. Hence, the occurrence of such a failure is considered highly unlikely.

A typical CEA ejection transient behaves in the following manner:

After ejection of a CEA from a full power or zero power (critical) initial condition's, the core power rises rapidly for a brief period.

The rise is terminated by the Doppler effect. Reactor shutdown is initiated by the high power level trip, and the power transient is then completed. The core is protected against severe fuel damage by the allowable CEA patterns and by the high power trip.

The radiological consequences of this. type of accident have been determined for two types of radionuclide pathways: 1) leakage via the containment building and 2) leakage through the secondary system.

The assumptions used to calculate these consequences are provided in Table 6.6-1, with the radionuclide releases provided in Table 6.6-2.

Although the resulting doses in case of an actual accident would be a composite of the doses computed for releases via the containment building and through the secondary system both sets of doses are pre-sented in Table 6.6-3. As shown in Table 6.6-3, the offsite radiological consequences of the CEA ejection accident are well within the guidelines of 10CFR100.

23-

'764 TABLE 6.6-1 Assumo tions Power .

'nitial MRt Q.ncluding pump heat)

DEC of I-131 Reactor Coolant 60 uCi/gm Secondary Coolant 0~1 uCi/gm Noble Gas Reactor Coolant PSAR Table 11.1-1 Fuel Rods in which:

Centerline Melting is Experienced Cladding is Breached Atmospheric- Diffusion 0-2 hours at the EAE 1. 2(-4),sec/m3 0-8 hours at the LPZ 6.6(-5)sec/m3 8-24 hours at the LPZ 1.2(-5) sec/m3 Breaching Rat'e 3. 47 (W) mP/sec Releases from the Containment Primary Coolant" Released to the Containment 5. 2(+5) ibm (total imrentory)

Containment Lesk Rate O.SX/day Iodine Composition:

Inorganic Iodines 90K Organic Iodines 10K SBVS Filter E"ftciency Inorganic Iodines Organic Iodines 90'0'X Noble Gases TABLE 6.6-1 (Cont'd)

As sumo tions Released from the Secondary Side Core Inlet Temperature 551. F Initial RCS Pressure 2200,psia Hain Steam Pressure 893.psia CEA E)ection Time 0.5 seconds of Egected CEA,

'orth

<.3'P (bounding. worth of an e]ected CEA, at full power)

Pressurizer power operated relief valve are inoperative Ho rupture of CZDM housing followiag the CEA e]ection; this maximizes steam release from the secondary system.

Automatic trip for this event is initiated by a high power Level trip signal.

Cooldowa Rate 100 F/hr (Tech Spec)

Primary-to-Secondary Leakage 1 gp Hass of Steam Released Steam Dump aad Bypass to Condenser 0-30 minutes 128500 Lbm 0.5-2.0 hours0 days 0 hours 0 weeks 0 months 518000 ibm 2.0-2.46 hours5.324074e-4 days 0.0128 hours 7.60582e-5 weeks 1.7503e-5 months 148000 ibm SG Safety Valves to Atmosphere 0-30 minutes 18000 ibm Turbine to Condeaser 0-30 minutes 500 ibm 25-

'LSD 6.6-2 Radionuolide Releases-Released Prom the Containment Release (Curies) 0 2 hours 0-8 hours 0-24 hours I-131 DEC 7.I,(-1) 2.8 8.5 Kr-85M 1. 5(-1) Se9(-L) 1.8 Kr-85 8.7{-z) 3eS(-1) 1.0 Kr-87 8.0(-z) 3.2{-1) 9.6(-1)

Kr-88 z.6(-1) 1;0 3,1 L.S(-1) 5.8(-1) 1.8 Xe-13'e-133 1.8(+L) 7.1(+1) z.l(+z)

Xe-135 7.4C-L) Z.O 8.9 Xe-138 3. 6 (-2) 1.4(-l) 4.3{-l)

TABIZ 6.6-2 .Cont'd}

Releases From the Seconda Side Release (Curries) 0-2 hours 2-2.46 hours5.324074e-4 days 0.0128 hours 7.60582e-5 weeks 1.7503e-5 months I-131 1.3 Kr-85m 6.8(-1) 1.6(-1)

Kr-85 a.o(-1) 9.2(-2)

Kr-87 3.7(-1) 8.5(-2)

Kr-88 3.. 2(-1) 2.7 (-1)

Xe-131m 6.7(-.1) 1.5(-1)

Xe-133- 8.2(+1) 1.9(+1)

Ze<<135 7.9(-1)

Xe-138 i.6(-1) 3.8(-Z) 27

TABLE 6.6-3 Radiolo ical Conse uences of a Control Element Assembly E ection Accident Doses From the Containment Release

~Or aa Dose (Rem)

At the EAB Whole Body 4..6(-5)

Thyroid 4.4(-2)

At the LPZ Whole Body 1.4(>>4)

Thyroid 1.3(-1)

Doses Prom the Secondary Side Releases Organ Dose (Rem).

At the EAB Whole Body Thyroid At the LPZ Whole Body Thyroid 6.7 Steam Line Break Accident A break in the main steam system increases the rate of heat extraction by the steam generators and causes cooldown of the. reactor coolant.

With a negative coefficient of.-reactivity, the cooldown will produce a positive reactivity addition.

Following a steam line break accident the reactor will trip on low steam generator pressure and both main steam isolation valves will close. Although the main steam isolation signal on either steam generator will also initiate closure of the feedwater isolation and feedwater pump- discharge valves on both steam generators, a five percent flow has been conservatively assumed. If the break occurs between the steam generator and the isolation ~alve, blowdown of the affected steam generator continues. Flow from the intact steam generator stops with closure of both isolation valves, either of which is capable of stopping flow'.

Since the steam generators are designed to withstand reactor coolant system operating pressure on the tube side with atmospheric pressure on the shell side, the continued integrity of the reactor coolant system barrier is assumed.

The sequence of events for this accident is given in Table 6.7-1.

The assumptions used to calculate the radiological consequences are provided in Table 6.7-2. The calculated radionuclide releases are presented in Table 6.7-3. As shown~ in Table 6.7-4, the offsite doses from this accident are small fractions of the 10CFR100 exposure limits.

- 29

TABLE 6 ~ 7-1 Sequence of Events for a Steam Line 3reak Accident Time (sec) Event Steam line rupture. occurs.

7.9 Steam generator pressure -'ow trip signal is generated (578 psia) . Main steam isolati.on valves begin to close.

8 ' Trip breakers open for trip on low steam generator pressure.

9.3 Shutdown,CEAs begin to drop into the reactor core, 14.8 Main steam isolation valves are closed; intact steam generator is isolated.

17,5 The pressurizer empti.es .

22.8 Safety in)ection actuation signal act~ted on low RCS pressure(1578 psia) .

182.4 Affected steam generator blows dry.

1800 Plant cooldown initiated using atmospheric dump valves.-

7200 Average reactor coolant temperature (

325 F, shutdown cooling ini.tiated.

30

TABLE 6.7-2 Assume tions Initial Power 1.HWt Required Shutdown Hargin &.3%AP Only one of the three HPSI pumps is assumed to be available.

Ho credit was taRen for charging and letdown flows.

The break assumed.is a double ended rupture of a main steam line outside containment and upstream of a MS'.

Blowdown from the affected steam generator is saturated steam; no credit is taken for moisture carryover, I'utomatic trip of the reactor for this event is initiated by a Low Steam Generator Pressure Trip Signal.

Ho credit is taken for the check valve in the main steam isolation valve assembly of the ruptured steamline which terminates the blowdown from the steam generator with intact steamline.

The reactor coolant pumps are left in operation even after safety injection occurs.

At 30 minutes the operator initiates plant cooldown'via atmospheric dump valves.

DEC of I-131 Reactor Coolant 60. uCi/gm Secondary Coolant O.l.uCi/gm Noble Gas Reactor Coolant FSAR Table 11.1-1.

~ Pr~zy-to-Secondary Leakage Upon entering the affected steam generator, all of the leaking coolant is assumed to instantaneously flash to steam which is released to the atmospher e.

Atmospheric Diffusion 0-2 hour at the EAB 1.2{-4) sec/m3 0.-8 hour at the LPZ 6.6(-5)sec/m3 31-

TABLE 6 7-2 (Cont "d)

Assume talons Breath,ng Rate 3.47(-4)m 3 /sec Nass of Steam Released Intact Steam Generator OW.5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months 41314 ibm 0.5-2.0hours 175936 ibm Affected S team Generator 0 WS hours 246181 ibm

0. 5-2.0 hours 1084 ibm

."32-

TABLE '." 7-3 Radionuclide Releases Release Curries) j-131 DEC 1.S(+2)

Kr-85m 3.4 Kr-85 2,0 Kr-87 1.8 Kr>>88 5.9 Xe-.13Im Xe-133 Xe-135 Xe>>138 TABLE 6.7-4 Radiological Consequences oz a Steam Line Break Accident an ~Dase Rem)

~0s At the EAB Whole Body Thyroid 9a$

At the LPZ Whol-e .Body 7.5(,W)

Thyroid S.l 34-

Section 7 - ALTERNATE ENERGY SOURCES There are several alternate energy sources available to replace the stretch power of St. L'ucie Unit 1. 'urchased power, new coal fired generation and base loading some peaking units are among the major considerations. All of these options involve the increased use of fossil fuels and by a fuel cost analysis alone, render them inferior to the St. Lucie Unit 1 stretch power. Other considerations are; capital requirements, environmental impact and potential for the reduction of oil consumption which is the primary goal of the National Energy Policy'. All of these considerations results in the St. Lucie Unit 1 stretch power. option as the superior choice.

35-

ATTACHMENT 1 ST. LUCIE UNIT 2 ENVIRONMENTAL REPORT - OPERATING LICENSE, SECTIONS 2.1.1, 2.1.2 AND 2.1.3

SL2-ER-OL 2.1 GEOGRAPHY AND DEMOGRAPHY 2.1.1 SITE LOCATION AND DESCRIPTION 2.1.1.1 S eci fication and Location Florida Power & Light Company's (FP&L) St Lucie site is located on Hutchinson Island St Lucie County Flor ida. o St Lucie Unit 2 is located at ]at i tude 27 20'5" north and longitude 80 o 14'7" west; the Universal Trans-verse Mercator (UTM) coordinates are 3025150 meters north and 574500 meters east in Zone 17. Approximately 300 feet to the north of St Lucie-Unit 2 is FP&L's St Lucie Unit 1, which has been operational since 1976. The coordi-nates for St Lucie Unit 1- are latitude 27 o 20'8" north and longitude 80" 14'8" west; the UTM coordinates are 3025250 meters north and 574450 meters east.

I The eastern boundary of the site is the Atlantic Ocean and the western boundary is the Indian River, a. tidal lagoon. Other prominent natural features wi thin 50 miles of, the site include Lake Okeechobee, 30 mi les to the west-southwest of the site and a portion of the Everglades approxi-mately 24 miles to the south of the site. Figure 2.1-1 shows the site in relation to the region within 50 miles. Figure 2.1-2 shows the area within five miles of the site.

Prominent, cities within ten miles of the site include Fort Pierce, approxi-mately seven miles to the northwest of the site; Port St Lucie, 4.5 miles to the south-southwest of the si te; and Stuart, 8.0 miles to the south of the site. The largest urbanized area within 50 miles of the site is West Palm Beach located 36 miles to the south southeast. All distances are straight

'ine measurements fran the site to the closest boundary of each city or 'area.

Transportation facilities within five mi les of the site include U S Highway 1; State Roads (SR) A1A, 712 and 707; the Florida East Coast Railroad, ship-ping on the Atlantic Ocean and the Intracoastal Waterway which is located in the Indian River. SR AlA, the major north<<south route on Hutchinson Island, traverses FP&L's property to the'ast of St Lucie Units 1 and 2. Figure 2.1-2 shows the location of these transportation faci ties.li 2.1.1.2 Si te Descri t ion A map of FP&L's St Lucie site is shown in Figure 2.1-3, entitled Site Area Map. This map includes plant property lines, site boundary, principle plant structures and boundary lines of the exclusion area and low population zone.

FP&L owns approximately 1132 acres'f land. The site is generally flat, and has dense vegetation characteristic of Florida coastal mangrove swamps. At the ocean shore, the land rises slightly to a dune or ridge approximately 19 feet above mean sea level.

Figure 3.1-1 shows the location and orientation of the principal plant facilities for St Lucie Units 1 and 2. The area preempted by the plant~

is about 300 acres, or 27 percent of the total land owned by FP&L.

2. 1-1

SL2-ER-OL There are no industrial, commercial, institutional,, recreational or resi-dential structures within the plant area. SR AlA"traverses FP&L's property approximately 1,000 feet east of the St Lucie Unit 2 containment building.

The exclusion area and the low population zone are shown in Figure 2.1-3.

The radius of the exclusion area is 0.97 miles from the St Lucie Unit 2 containment building. The low population zone includes that area within approximately one mile, of the St Lucie Unit 2 reactor.

2.1.1.3 Boundaries for Establishin Effluent Release Limits The minimum boundary distance Eor establishing gaseous effluent release limits is that noted on Figure 2.1-4, Property Plan, directly north of the St Lucie Unit 2 reactor containment building. Also indicated in Figure 2.1-4 are other boundary line distances fran plant liquid and gasesous re-lease points. The restricted area,'s defined in )OCFR20 includes the fenced area shown in Figure 2.1-5.

2.1 ~ 2 POPULATION DISTRIBUTION 2.1.2.1 Po ulation Within Ten Miles Table 2.1-1 and Figure 2.1-6 show the distribution .if present and projected population within ten miles of St Lucie Unit 2. The estimated 1978 popula-tion wi thin ten miles of the plant is 71,051 persons, concentrated in the cities of Fort Pierce and Stuart which are the seats of government and centers of a<<tivity for St Lucie and Hartin Counties, respectively. Host of the area within ten miles of St Lucie Unit 2 is in St Lucie County; only annular sectors S and SSW between the five and ten mile radii, fail within Hartin County. The (~)al population in 1978 for St Lucie County is estimated to be 75,500 persons . The 58,095 residents of St Lucie County, within the ten mile radius, represent 75.9 percent of the county total. In the same manner, the 12,956 residents of Hartin County, within the ten mile radius, comp~j~e 24.4 percent of the total estimated county population of 53,100 in 1978 ~

2.1.2..1.1 Cities, Towns and Settlements Cxties, towns and settlements within ten miles of St Lucie Unit 2 are shown in Figure 2.1-7. All or part of several incorporated areas fail within the ten mile radius. The largest of these i s the city of Fort Pierce, with an estimated 1978 population of 33,083. The mainland portion oE Fort Pierce fails in sectors NW and NNW, while the section of Fort Pierce on the northern end oE Hutchinson Island is in sector NNW. This area, called South Beach, is linked to the mainland by South Bridge, a continuation of State Route (SR) A1A.

Nearly all of Fort Pierce's population is located witnin tne tive to ten mile annulus. A part of the Fort Pierce incorporated area, a long narrow extension to the southeast, comes wi thin 4.1 miles if St Lucte Unit 2; How-ever, most of this area consists oE the Savannahs Recreation Area and has Eew residents.

2. 1-.2

SL2- ER- OL The second incorporated area in St Luc'ie County'within the ten mile radius is the city of Port St Lucie. (2 'Pe total population for Port St Lucie in 1978 is estimated to be 6,465 . Approximately 75 percent of the in-corporated area falls within ten miles of St Lucie Unit 2, extending from the S to W sectors. Although lots have been platted and sold in many sec-tions, residential development ip3)978 is conceritrated in annular sector SW five to ten and WSW five to ten, In 1978, that part of Port St Lucie east of US Highway4), (US 1) within five miles of the site, has nn residen-tial development A portion of the incorporated area of the city of Stuart falls within an-nular five Sector to ten. The estimated 1978 population for the city of Stuart is 10,760 persons. As in the Fort Pierce area, the city of Stuart offers residents services and employment, proximity to the Atlantic Ocean and beaches, and access to Hutchinsnn Island. Two of the three means of access to Hutchinson Island, the Jensen Beach Bridge and Stuart Causeway, are located in annular sector SSE five to ten.

The town of Ocean Breeze Park is located in Martin County, north of the city of Stuart, on the western shore of the Indian River in annular sector SSE five to ten. Ocean Breeze Park adjoins the crmmunity of Jensen Beach, located at the intersection of SR 707 and the Jensen Beach Causeway (SR A1A) to Hutchinson Island. Also, in the SSE sector is a portion of the Town of Sewall's Point, which occupies the peninsula separating the St Lucie River from the Indian River.

Along the western shoreline of the Indian River (paralleling S(2/7 east of the Florida East Coast Railroad) is a ridge of dry sandy soils ~

area, which is predominately low density residential throughout the five mile radius, includes the unincorporated settlements of Eden, Walton, and Ankona. A development called Indian River Estates is located in sectors W and WNW, between three and, five miles of St Lucie Unit 2. Approximately 40 percent of its land was developed for residential use in 1978 . Collins Park Estates, also in annular sector WNW four to five, is west of Indian River Estates and is smaller in area but more densely settled . Together, these developments contain about 500 dwelling units.

Spanish Lakes is another major development in the unincorporated county insi(g)the five mile radius. This mobile home community, which has 1387 lots , is located in annular sector WSW four to five, east of US l.

To the west of VS 1, in sector WSW, the developers of. Spanish Lakes have cnnplg~d a second project called Riverfront, which has a total of 620 units . In both projects, a significant proportion of dwelling units are owned or occupied by seasonal vistors rather than residents.

There are extensive areas of vacant land south of Indian River Estates between VS 1 and the coastal ridge. Portions of this area are beep acquired by the State of Florida for the Savannahs State Preserve On Hutchinson Island, in 1978, all resident population within. the five mile radius was limited to annular sector SSE four to five. The 1928 persons in SSE four five included residents of Nettles Island, a trailer park of

(~ ) most of which are located in a man-made is land reached by 1588 lots ~

2. 1-3

SL2- ER- OL a short causeway. Many of the lots are nwned or rented by persons whn are seasonal vistnrs.

2.1.2.1.2 Population by Annular Sectors, The most heavily populated annular sectors are those which cnver the towns and developments mentinned above. The most heavily populated annular sector in 1978 was NW five to ten, which includes much of the city of Fnrt Pierce with an estimated 36,483 residents.

2.1.2.1.3 PopuLatinn by Annuli In 1978, the annuLus between five and ten miles of St Lucie Unit 2 was mnre densely pnpulated than the area within five miles. Population density fnr the five to ten mile annulus (excluding the seven sectors over the Atlantic Ocean) has 473 persons per square mile. Inside five miles, the four 'tn five mile annulus has a density of 427 persons per square mile.

In 1978, the area within four miles of the plant was sparsely pnpulated, with an overall density of 46.1 persons per square mile (excluding the five sec-tors over the Atlantic Ocean). Within two miles of St Lucie Unit 2, there was an estimated total of 97 residents, a populatinn density nf approx-imately 11 persons per square mile. The entire area within nne mile of the plant is nwned by FP&L and is included in the exclusion area and lnw popula-tion zone. Much of the area in the one tn twn mile annulus is over water.

2.1.2.1.4 Pnpulation by Sectors The most populous sector within ten miles of St Lucie Unit 2 is the NW sector which, because of the large cnncentratinn of resident popuLation in the city of Fort 'Pierce, contains 36,657 persons. The second most heavily populated sector is SSE, which has 8140 persons and includes Hutchinsnn Island, the AtLantic Coast in the vicinity of Stuart, and Nettles Island . The adjacent sector, S, is third highest with 7179 residents in 1978.

2.1.2.1.5 Projected Population The population within ten miles of St Lucie Unit 2 is expected to more than doubLe during the life nf the plant, frnm 71,051 in 1978 tn 158,851 in 2030. This represents an increase of 123.6 percent over the 52 year period,'n average annual rate of growth of 2.4 percent. The State of Florida is expected to grow by an average annyyL8yate of 2.1 percent, or by 88 the period from 1978 to 2020 ' as discussed .in Sectinn percent'ver 2.,1.2.2.5.

It is expected that in the year 2030, as in 1978, sector NW will have the highest pnpulation of all sectors, 54;756 persnns, but will have the slow-est rate of grnwth, 49.4 percent over 52 years. Likewise, annular sector NW five to ten is expected tn grnw from 36,483 tn 54,497, a gain of 49.4 percent. In 2030, the second highest population by sector is expected tn be in sector WSW, which will grow by 268.7 percent from 6691 residents in 1978 'to 24,669 in 2030.

2. 1-4

SL2-ER-OL Within the ten mile radius, the sector's expected to experience the highest growth rate are sectors SW and SSW. They are estimated to grow by more and from 1,434 to 19,i27, tinuedd1200 percent, from 812 to 13,971 residents, than respectively. Both sectors will show an increase from the expected con-growth of Port St Lucie .

The Fort Pierce area will maintain a significant share of the total popula-tion within ten miles of St Lucie Unit 2. However, Port St Lucie vill, gain in its share of total county residents as absentee lot owners build homes and move to Port St Lucie, as promotion of lot and home sales continues, and as long as Port St Lucie offers more moderately priced housing than traditionally available at beachfront locations.

Port St Lucie is one of the strongest growth areas in St Lupi County. To illustrate, between 1970 and 1978, Fort Pierce grew from 29,721 persons to 33,083, an increase of 11 percent. During the same period, Port St Lucie grew from 330 to 6465 persons, an increase of approximately 1800 percent.

If building permit activities of 1975, 1976 and 1977 were to continue, it is possibly that Port St Lucie would reach a population of 36,000 by the year 2000 Within the <<ity limits of Port()) Lucie, a proposed development of 2,200 dwelling units, called Midport , has be~y0a~~~oved under State Develop-ment of Regional Impact (DRI) regulations ' Its estimated population of approximately 5000 people will reside in annular sectors SSW and SW be" tween 3.5 and 5.5 miles of St Lucie Unit 2. It is expected that Midport wi ll be cnnpieted and fully occupied by 1983. Therefore, the 1983 population estimates include the Midport project.

Also; the developers of Spanish Lakes and Riverfront have started development of a third mobile home community called Golf Village. The development as planned wi ll add 740 dwelling units to annular sector SW four to five. As in many of the residential developments in this region, many of the homes will be occupied by seasonal visitors rather than residents'The part of Hutchi nson Island which falls within the five mile radius is another area expected to undergo considerable growth. In 1978, there was a total of 1,928 residents; this population is expected to reach 2,678 by 2030, a gain of 39 percent. These residents will prooaoly represent only a fraction of the island's future population since .aany new dwelling units for seasonal visitors and tourist accommodations will be constructed on this highly valued beachEront property.

In annular sector SE one to two, a project called Sand Dollar Vi llas is under construction and sched~f~) for compfetinn in 1980. It wi ll have 203 apartments and 32 townhouses . While it is likely that development will continue to occur in the form of projects such as Sand Dollar Viilas, it is impossible to predict the size and location of such projects until they are initiated.

County planning officials have indicated that congestion of the b~j)g~g>

fran the mainland to Hutchinson Island could restrict development A bridge has been proposed which would cross the Indian River at SR 712 2.1-5

SL2-ER OL and Li~(3)S 1, the Florida Turnpike, and Interstate.95 to lfutchinson Island ~ An additional river crossing would induce development on the Island. However, it is uncertain if, when, or Dere another r>ver crossing will be constructed because the y~)~rs of the >n~ian iver in this area are part of an aquatic preserve 2.1.2.1.6 Age Distribution The age distribution of the projected population for the year 2000', within ten miles of St Lucie Unit 2, is presented in Table 2.1-2. In each annular sector, the number of people under 11 years of age; between 12 and 18; and over 18 have been estimated, )~~ed on the distribution of these age groups in the United States in 1970 2.1.2.2 Po uLation Between Ten and 50 Miles Table 2.1-1 and Figure 2. 1-8 show the distribution of the estimated 1978 population between ten and 50 miles of St Lucie Unit 2. The estimated 1978 popuLation is 412,714 persons (see Section 6. 1.4.2, Methodology) and repre-sents 85.3 percent of the total population within 50 miles of the plant.

This population is confined to sectors SSE through NNW since sectors N through SE, beyond the ten mile radius, include only the Atlantic Ocean.

The major concentration of population occurs in annuLar sector SSE 40-50, which includes the city of West Palm Beach. West Palm Beach is the northern limit of the Florida Gold Coast development extending north from Miami through Dade and Broward Counties into Palm Beach County. The 126,615 resi-dents in annular sector SSE 40-50 live nn approximately 48 square miles of land (the eastern three quarters of annular sector SSE 40-50 extends over the Atlantic Ocean). Annular sectors S 40-50 and SSE 33-40 have the socond and third highest populations, respectively, per annular sector, and reflect that Palm Beach, County is more highly developed than anv other part of 'the region. In the 1970 Census, Palm Beach County was one of the nine Standard Metropolitan Statistical Areas (SMSA's) in Florida. Of the total 525,200 residents of Palm Beach County in 1978, 277,881 lived within 50 miles of St Lucie Unit 2.

2.1.2.,2.1 Ci.ties and Towns Between Ten and 50 Miles Table 2.1-3 lists towns, cities, and:communities wi th a 1978 population of more than 5,000 persons (see Figure 2.1-9). There are eight towns with a population of more than 10,000, the Largest of which is West Palm Beach, with a 1978 population of 62,616 (see Methodology, Section 6.1.'4.2). The second largest zs the city of Fort Pierce, with 33,083 persons; the third largest is Riviera Beach 'xn Palm Beach County,- with 27,735 persons; and the fourth Largest is Vero Beach, seat of government for Indian River County, wi th 16,800 persons. Of the eight largest towns five are in the West Palm Beach Urbanized Area (as'defined by the US Census ). In addition to West Palm Beach and Riviera Beach, the five include North Palm Beach (15,014 persons), Palm Springs (11,300 persons), and Palm Beach Gardens (10,792 persons). Stuart, the largest ci ty in Martin Coun'ty, has an estimated 1978 populat ion nf 10, 760.

2. 1-6

SL2-ER-OL Of the eight towns with populations between 5,000 and 10,000, four are within the Hest Palm Beach Urbanized Area. These include the towns of Palm Beach, wi th 9,952 persons; Lake Park, wi th 8,652 persons; Greenacres City, with 6,773 persons; and Royal Palm Beach, with 5,598 persons. Pahokee, with an estimated 1978 population of 5,864, is also in Palm Beach County but ss located in the northwestern quarter of the county, on the shore of Lake Okeechobee.

There are three other towns with populations between 5,000 and 10,000 persons. These include Gi ffnrd, located in Indian River County, with an estimated 1978 population of 9,485; Jupiter in Palm Beach County with 9,156~gyople; and Port St Lucie, in St Lucie County with 6,465 resi-dents ~

2, 1-7

SL2- ER" OL 2.1.2.2.2 Population by Annular Sectors The most heavily populated annular sectors between ten and 50 miles from St Luci,e Unit 2 are those which encompass the cities and towns with the greatest populations as discussed in Section 2.1.2. i.l. The nost populous annular sector, SSE 40-50, includes West Palm Beach, Palm Beach Shores, Riviera Beach, and Palm. Beach (see Figure 2.1-S).

Immediately to the west of annular sector SSE 40-50 lies the second most populous annular sector, S 40-50, including Greenacres City (6,773 persons) and Haverhill (1,004 persons estimated for 1978), aclyll as numerous large residential developments of up to 7,400 acres The third most populous annular sector between ten and 50 miles from St Lucie Uni.t 2 lies north of West Palm Beach nn the Atlantic Coast (SSE 30-40). Although its land area is less than half of the 137 square miles which comprise the annular sector, it includes Lake Park, North Palm Beach, Juno Beach, portions of Riviera Beach, Palm Beach Gardens, and the town of Jupiter, all of which are heavily populated.

When the above three annular sectors are combined; they comprise 59.6 percent of the total population between ten and 50 miles of the St Lucie Vni t 2.

2.1.2.2.3 Population by Annuli Populations by annuli between ten and 50 miles of St Lucie Unit 2 range in number of residents from the largest, with a total of 211,061 persons (the 40"50 miles annulus), to the smallest, with 51,504 persons (the ten to 20 mile annulus). The annulus between 30 and 40 miles has the second largest population of 83,240, while the annulus between 20 and 30 mi les contains 66,909 persons (see Figure 2.1-8).

The 40-50 mil,e annulus has not only the largest population (211,06> ) and the greatest overall area (approximately 1,590 square miles, excluding the seven sectors over the Atlantic Ocean), but also the highest population density in the region. The population density of the 40-50 mile annulus is 133 persons per square mile. Ninety"one percent of the population is located on 22 percent of the total annulus area, in ~ectors SSE and S, which include West Palm Beach and environs.

2.1.2.2.4 Population by Sectors The most populous sectors between ten and 50 miles of St Lucie Unit 2 are those which cover the West Palm Beach area and the Atlantic Coast. Sectors SSE and S have estimated 1978 populations of 206,199 and 90,040, respective-ly, and densities of 483 persons per square mile and 183 persons per square mi.le, respectively. Sector NNW has a population of 51,541, and a density of 109 persons per square mile; sector NW, the next one inland, has a total population of 19,037 and a density of 40 persons per square mi l.e. The five remai.nx.ng sectors have densities which range from two to 31 persons per square mile.

The sparseness of population in the five interior sectors can be attributed to extensive acreage covered by wetlands and surface water (Lake Okeechobee),

2. 1>>8

SL2-ER-OL inaccessibility to population centers, and the extent of range and cropland.

2.1.2.2.5 Projected Population Figure 2.1-8 shows the projected residential population between ten 'and 50 miles of St Lucie Unit 2. Total population between ten and 50 miles is expected to grow by 121.3 percent between 1978 and 2030, or from 412,714 to 913,463. The average annual growth rate for this area would be 2.14 percent Eor the 52 year period. This rate of growth can be compared to the rate Eor the Stat~ of Florida, which is expected tobe 2.1 percent per year Erom 1978 to to 2025 (

'nd 1, )

)))0 Florida 0.76 percent per year Eor the United States from 1978 is presently one of the most rapidly growing states xn,the US.. Between 1970,and 1977, the state grew by-28 percent, a net addition of almost two millj~p people. Ninety percent of this growth was attributed to net migration 2.1.2.2.6 Areas of Development The principal area of development between ten and 53 miles of St Lucie Unit 2 occurs in Palm Beach County in the sectors including and -djacent to the Atlantic Coast, Major development activity outside of palm Beach is con-centrated in what can be called the "Atlantic Corridor", the five to ten mile area between the Atlantic Ocean 'and either Interstate 95 or the Florida Turnpike in Hartin, St Lucie, Indian River', and southern Brevard Counties.

Land to the west of this region is mostly used Eor pasture, agricultural production (citrus, sugar cane, and truck farming), or remains un-developed ~ Access is limited and population sparse. In a few widely scattered sites, tracts of land have been platted and sold as home sites or proposed for such development. No significant development of any nE these projects which lie west of the, Atlantic corridor has yet taken place.

Development is Eocused in the At lant ic corridor for reasons such as the folio wi ng:

Proximity to existing population centers and services; I

2) Access to the Atlantic Ocean and Indian River, and the amenities they provide: scenic beauty, sports and re-creation, tourist industry potential;

3) Presence of soils suitable Eor development on the coastal ridge;

4) Zoning and planning policies developed by county and regional agencies which permit development xn these areas; and

5) Availability of land suitable for development.

Only three significant clusters of development occur outside the Atlantic corridor between ten and 50 miles of St Lucie Unit 2. Two are on or near the shores of Lake Okeechobee (which covers 400 square miles in sectors SW and MSM between 30 and 50 miles of the plant). On the southeastern shore nf the

2. 1-9

SL2 ER<

2. 1-10

OL

2. 1-11

2. 1-12

2. 1-'4

2. 1-15

2. 1-16

2. 1.L.3. 4 Enro 1 lment at Haj or Co 1 lege s Two major colleges are located inside the 30 mile radius. Estimates and projections of their enrollments are presented in Table 2.1-7. In annular sector SSE five to ten Florida Institute of Technology-Jensen Beach (42J has a peak enrollment of 900 students with dormi tor i es ac<<

2. 1-17

2. 1-18

passengers wi use the West Palm Beach International Ai rport in 1990 . Plans are underway for con-struction nf new terminal, runway, and road facilities. In addition tn passengers, airpnrt oEficials estimated that in 1978 there were 1,800 workers at the airport on a peak day, and that passengers were accnmpanied nn the average by two persons ea<<h prior tn departure and upon arrival. If passengers, workers and persons accompanying passengers are totalled fnr 1978, the average daily number nf persnns at the West Palm Beach Interna-tinnal Airport Enr 1978 would be 6,992. Estimates and projections nf average daily passengers are included i n Table 2.1-9. 2.1-20 .0 SL2-ER-OL 2.1.3 USES OF ADJACENT LANDS AND WATERS Existin Land Uses on A licant's Pro ert The St Lucie site boundaries, exclusion area boundary, and station perimeter, are shown in Figures 2.1-3 and 2.1<<5. A map showing existing land uses on this property is given in Figure 2.2-1. Acreages of each category of land use within the property boundaries are given in Table 2.2-1. Table 4.1-1'lists the various uses and the respective acreages required for the St Lucie site. A detailed discussion of the site area breakdown is given in Section 4.1. 2.1.3.2 Land Uses Within The Excbusion Area The exclusion area falls within FPGL property boundaries, and encompasses the area within a one mile radius of the plant (See Figure 2.1-3). Apart from the utility facility itself, the only other principal land uses/land cover within the exclusion area are SR AlA, undeveloped mangrove, sandy beaches and dirt trails along the eastern coast oi Hutchinson Island. 2.1.3.3 *8 There are no proposed land uses within the applicant's property boundaries other than the structures and facilities related to St Lucie Unit 2. Apart from the three acres required for the discharge canal extension and head-wal'l, no disturbance to existing land is expected. Power generated by St Lucie Unit 2 will be transmitted by existing switchyard and transmission lines constructed for St Lncie Unit 1. Therefore, land use changes on the applicant's property will be minimal. 2.1.3.4 Nearest Residences and A ricultural Activities Table 2.1-11 gives the location of the nearest cow, goat, meat animal, vegetable garden (greater than 500 square feet in area), and residence found within five miles of St Lucie Unit 2. The location of these items is giga f~ ~~gular sectbr. The following is a discussion of this Table The nearest milk cows are located outside the five mile radius, 14 miles W of the site. These milk cows are found in a dairy opera-tion close to the Martin County line. The dairy is one of four in St Lucie County. The nearest milk goat is located 2.2 miles SW from the site. It is also the nearest grazing animal to the plant. The nearest meat animal: is located 3.2 miles W of St Lucie Unit 2'. The ground survey showed the nearest vegetable garden of 500 square feet or greater to be located 1.9 miles WSW of the facility. The nearest residence lies 1.9 miles WSW of the plant site.
2. 1-21
SL2- E R- OL 2.1.3.5 Existin Land Uses Within Five Miles of St Lucie Unit 2 Table 2.1-12 lists each land use found within five miles of St Lucie Unit 2 with the acreage involved for each figure 2.1-16 is a map showing the distribution of these landcategory~uses . The site survey and land use classification methodologies are discussed in Section 6.1.4'.2.1. a A detailed discussion of existing land uses within five miles of St Lucie Unit 2 is given below. 2.1.3.5.1 Land Use/Land Cover b USGS Cate pries a) Residential The residential category of Land use includes single fami.iy units, multipLe famiLy units, group quarters, mobile home parks, and tran' sient lodgings, (mote'ls and hoteLs) . Permanent residents live, for the most part, in single family units consisting of free standing houses and mobile homes. Transient accommodations incLude residential units which are rented out, motels, hotels-and individual housing units which are visited by friends or relatives. Housing developments on the mainland are clustered along US Highway 1 (US 1) and SR 707 (along the western coast of Indian River). Housing facilities on Hutchinson Island are located at the shoreline and are, for the most part, transi.ent accommodations. These residential units are used by, seasonaL visitors throughout the year and include motel rooms, condominiums and mobile home park facilities. Residential developments within five miles of St Lucia Unit 2 are discussed below. See Figure 2.1-7 for their location. Mainland Residential Units Indian River Estates, located between three and five miles of St Lucie Unit 2, east of US 1, and just south of Fort Pierce, is a . single fayH~ housing development designed primarily for permanent residents . Althouth streets and plots. were laid out for this development many years ago, only roughly 40 percent of the land within Indian'River Estates was occupied in early 1978. Collins Park Estates, just west of Indian River Estates, occupies less land area than does Indi. an River Estates, bii( much densely settled. Most of the residents are permanent j~ more Taken together, these developments contain more than 500 dwelling units (Section 2.1.2). Spanish bates is a mobile home tommnnity east ot US 1 and tontains 1,387 lots 75) . Although most of the occupants are permanent residents, a significant number of dwelling units are owned or occupied by seasonal visitors. West of Spanish Lakes and US 1 is a mobile home project known as Riverfront. A smalL portion of this development extends= into the area within five miles of St Lucie Unit
2. Like Spanish Lakes, it accommodates both permanent and transient
~ residents. 2.1-22 SL2-ER-OL Along US 1, there are a number of individual dwelling units which are scattered between, adjacent to, or atop commercial establishments. These residential units are used by both"permanent residents and seasonal visitors. Paralleling a strip of individual houses on the shore of SR 7(j6js. the Indian River Typically, these houses sit on lots which extend back from 'the shoreline approximately ]000 ft. Most of the people residing in this area are permanent residents. The area is primarily low density and includes the settLements of Ankona, Walton, and Eden. There are a few isolated houses in 'the largely undeveloped area between .the Florida East Coast Railroad and the housing developments adjacent to US 1. These are also predominantly owned and occupied by permanent residents. The multiple housing units built on the mainland are primarily Located alongside US l. Hutchinson Island Residential Units In February 1978, most of the residential units on Hutchinson Island were concentrated in an area four to five miles from St Lucie Unit 2. The principal residential developments on the Island are described below. Extending into the Indian River is a large, densely populated, mo-bile home park knoqg~ Ne'ttles Island. It has 1588 lots (see Section 2.1.2.1.1) . Many of the lots are used by seasonal visitors. Across from Nettles Island on the ocean are three Lodg-ings: Hutchinson Island Inn (21 room~)7 ))craton Resort Inn (122 rooms) and Oceana (]26 condominiums) Under construction are a housing development called Sand Dollar Villas f and an expansion o Oceana. Sand Dollar Vi Llas is 1.4 miles from the plant site and will contain 203 apartments and 32 town-houses on the ocean. It is expected to attract seasong0~isitors. Sand Dollar Villas is scheduled for compl'etion in 1980 . The condominium development known as Oceana is currently being expanded to add another 160 condomiyj~s. This expansion is scheduled for com-pletion by December, 1979 Commercial and Services The commercial and service category includes areas used for the sale of products and services as well as institutions such as schools, medical centers and churches. A total of 28 acres with'in five miles of St Lucie Unit 2 faLL within this category. Commercial Of the total area under consideration, only 22 acres consist, of commercial and service establishments. Most of these facilities, such as drycleaners and supermarkets, serve Local residents. There are two shopping centers within five miles of St Lucie Unit 2,
2. 1-23
SLZ-ER-OL located on US 1.. Most other commercial establishments are reLated to the automotive industry (gas stations, used car lots, mechanic' shops) or tourists. There are few commercial and service establ.ishments on Hutchinson Island. For the most part, they are special. ized facilities such as beauty shops, and bait and tackle shops. As a result, people on the island have to cross over to the mainland Eor most supplies and ser-vices required . The principal commercial centers serving the area are Fort Pierce and Stuart. A smaller commercial center is located in Jensen Beach. All three centers are located outside the Eive mile radius. Institutional - Schools, Medical Facilities, Churches The classification of commercial and services, includes institutional land uses such as schools and hospitals. There are no schools located within five miles of St Lucie Unit 2. The nearest school, White City Elementary School, is about six miles WNW from St Lucie Unit 2. There is one medical faciLity, approximately five miles WSW from the plant site, called the Port St Lucie Medical Center. Several churches EaLl within the five mile radius and include the Kingdom Hall of the Jehovah's Witnesses and the New Testament Baptist Church. Roughly six acres fall within this category. c) Industrial The General Development Corporation (GDC) owns approximately 32 acres, used as a smaLl industrial park located off US 1, roughly . four and a half miles WSW of the plant. One of the tenants is FP&L, one is a surgical and dental equipment Eirm and one is a plumbing supplier. The 18 acres leased by FP&L is classified as utility use. The remaining 14 acres, I.eased by other firms is classified as I.ight industrial. d) Trans ortation, Communications, and Utilities This category encompasses major transportation routes, such as high-ways and railways, and communications and utilities areas, "such as those involved in process'~~) treatment, and transportation of water, gas, oil, and electricity Within five miles of St Lucie Unit 2, 964 acres can be cLassified as transportation, communications, or utiLity use, representing about two percent of the total acreage. Nearly three quarters of this (704 acres) is given over to utility structures and Eacilities.. Al.l of these are owned and operated by FP&1.. Most of this acreage supports St Lucie Units 1 and 2, and related structures. However, as mentioned above, FP&L Leases an 18 acre storage and maintenance yard in GDC's Industrial Park. 2.1-24 SL2-ER-OL Trans ortation The principal transportation corridors on'he mainland are US 1, SR 707, and the Florida East Coast Railroad. US 1 is a four lane divided highway which runs from north to south. SR 707 is a two lane road which parallels the Indian River. The Florida East Coast Railroad is a two track installation for most of its length, except for a. section between Ankona and a point approximately 1.3 miles south of Weatherbee Road, where it narrows to a single track. Secon-dary transportation routes on the mainland include Walton Road 'two lane), which runs due west from WaLton; Weatherbee Road, (two lane) which runs due west from White City Station; and Route 712, also known as White City Road (two lane), which also runs east to west (Figure 2. 1-2) . The only major paved road on Hutchinson Island is SR A1A. It has a width of two to three lanes and transects the entire length of the is land. Communications With the exception of an underground telephone line which transects the western rim of the five mile area, there are no communications areas within five miles of St L>>cie Unit 2. There are no major pipelines located within five miles of St Lucie Unit 2. Utilities Roughly 704 acres falL within the utilities category. Of this total, approximately 300 acres on Hutchinson Island are committed to FP&L's Units 1 and 2 and their related structures. RoughLy 386 acres accommodate the transmission lines which extend from the plant site to the circumference of the area within five miles. For most of its length, the transmission line right of way is 660 feet in width; however, for a short distance jp~diately adjacent to the Indian River, the width is 1,200 feet . The remaining 18 acres support a utility storage area within the GDC Industrial Park. Urban or Built-U Land Included in this category are miscellaneous urban land uses such as cemeteries, urban parks, undev'eloped urban Land, and recreational facilities. Approximately 235 acres (or less than L/2 percent) have been classified as urban or built"up land. Forty-seven of these acres comprise both a cemetery off SR 707, and pockets of undeveloped urban land contingent to US l. A total of 188 acres are given over to both p>>blic and private recreationaL facilities. The private facilities consist of the golf course within the Spanish Lakes com-pound and the Tu Bahd Saddle CLub. The, public estabLishments are the southern end of the Savannahs Recreational Area (a park in the NW quadrant, owned by the City of Fort Pierce and used for picnicking, boating and camping) and public picnicking and beach facilities on
2. 1-25
SL2-ER-OL Hutchinson Island. Recreational beach usage is discussed in Section 2.1.3.9.2. f) A ricultural Land Approximately 541 acres of agricultural land (or less than one per-cent) fall within five miles of St Lucie Unit 2. Most of this land supports citrus groves. In 1(f)3y 1977, 73,912 acres were in citrus production in St Lucie County . Several nurseries comprise part of the agricultural acreage and produce ornamentals for local use. Forest Land and Wetlands Approximately 16 percent of the area under consideration can be identified as pine flatwood forest/fresh water marsh. This land cover consists of a mixture of pine, sawgrass marsh, and palmetto. The soils underlying this area are nearly level, poorly draine( sandy, and belong to the Myakka-Immokalee-Basinger Association Much of the undeveloped land between the Florida East Coast Railroad and US 1 is marshy, and supports a scattering of pine trees. The ridge along SR 707 has dri~~ coils and supports a denser forest canopy consisting mostly of pines . The fores(gyjthin five miles of St Lucie Unit 2 is not commercially logged The other principal vegetation community within five miles of St Lucie Unit 2 is the mangrove community located on Hutchinson Island. For a discussion of this community, see Section 2.2. l. h) Water Most of the area within five miles of St Lucie Unit 2 is covered with water, and accounts for more than two-thirds of the total area; most of this consists of the Atlantic Ocean. One-third is a section of the Indian River, and the remainder is mainland water bodies. The Indian River is a brackish tidal lagoon. Most of the water on the mainland is concentrated in a string of lakes running from north to south at the eastern edge of the Savannahs. The boundaries of these lakes vacillate with seasonal flooding and often merge with the surrounding marsh. The rest of the water is concentrated in small man made ponds and canals located towards the western boundary of the five mile perimeter. Barren Land The classification system considers barren land as land which has a limited ability to support life. Beaches are an example. There are three types of barren land within five miles of St Lucie Unit 2. The first type is located at the site of the sand mining operation, just west of the Florida East Coast Rail, road tracks and on either side of Weatherbee Road. Roughly 195 acres serve this ex-traction operation.
2. 1-26
SI 2-ER- OL J The seco'nd type of barren land is found along the Atlantic Coast nf Hutchinson Island in the form of beacHes. Almost 100 acres of beaches occur within five miles of St Lucie Unit 2. The third type of barren land is found within the so-called transi-tionaL areas. "The Transitional Areas category is intended Enr those a[g~~ which are in transition from one land use activity to another ." There are three transitional areas within five miles of St Lucie Unit 2. Two of these are Located north of Weatherbee Road and appear to have once supported agricultural activity. The third is Located near the southern boundary nf the five mile circumference. It contains land which has been cleared and drain~)7jor a commercial/residential development known as "Midport" 2.1.3.6 Future Land Uses Within Five Miles of St Lucie Unit 2 To determine future land uses within five miles of St Lucie Unit 2, the St Lucie Count Growth Mana ement Plan (The Plan) and other critical Qa~gjng documents, such as The Plan for Hutchinsnn Island, were examined In addition, projects under construction or in the process of obtaining per" mits were considered, as well as growth trends in St Lucie County, and local site suitability characteristics. Figures 2.'1-17 and 2.L-LS present the pro-posed Land uses. The PLan states, "After adopting a plan, local governments and their agen-cies may not issue buiLding permits, approve zoning changes or subdivision requests, undertake public development projects or approve development ,actions that are inconsistent 'with the plan Eor the area. In addition, the adoption or amendment oE land development regulat irma (e.g., zoning, sub.- division regulations) shag)be consistent with the adopted comprehensive plan or element thereof" Anticipated future land uses, by USGS land use categories, are di scussed below: Residential The greatest increase in Land use is expected to occur in residential development. Projected population increases suggest that housing con-struction activity will be necessary to accommodate popul~tinn >>~~h. (See Tables 2.1-1 and 2.1-5). ( Most of the land area within five miles of St Lucie Unit 2 is undeveloped pine fiatwond/fresh water marsh. It is anticipated that with the projected increase in population, much nf this land wilL be cLeared and drained to accommodate new dwelling units. In the following di scussinn of. future residential deveL pment, separate consideration is given tn the mainland and to Hutchinson Island.
2. 1-27
SL2 ER-OL a) Future Residential Develn ment nn the Mainland According to The PLan, 'land abutting the eastern right nf vay nf US 1, south nf GeneraL Develnpment Cnrpnrat inn's (GDC) Industrial Park, vill be set aside for medium and lnw density residential use. It is expected that thnse areas designated for residential. develop-ment by The Plan will suppnrt dwelling units in the Euture. In addition, residential deveinpment is anticipated in nther areas. Hnst nf the undeveLoped land extending from US 1 tn the western border oE the Flcrida East Cnast Railroad right nE way is designated in The Pian for Agricultural Use. In practice, hovaver, parti ne of this 'agricultural" land have already teen etsssitted fnr residential use. Gnlf Yiilage, for example, is an apprnved prnject nf 740 mnbi Le hnme units which wilf )e cnnstructed by the managers nf Spanish Lakes and Riverfrnnt 7 . It vill be Lncated snuth c f GDC's Industrial Park and east nf US 1. Annther example nf the pressure being placed nn "agriculturaL" land Enr residential. use is the prnject knnwn as Hidpnrt. Nidpnrt is Lccated nnr th and sc uth c E Waltnn Rnad and east nf US 1 ~see Section 2.1.2.1.5). It vill introduce 2,201 )gt7l ling units which vali. be both single and mult iple fami Ly units . Much nf the Hidport development vilL fall within the five mile area, aLthnugh it is difficult tc specify exactly hnw many resident ial units vi ll be built vithin five males nE St Lucie Unit 2. The Hidport P~nj)ct has been issued a DRI (Develnpment of Regional Impact) permit 8 The Lncat arms of bnth GoLE Yil.lage and Hidpnrt are shnwn nn Figure 2.1-7. b) Future Residential. Develn ment c n Hutchinsnn Island That portann nf Hutchinsnn Isl.and which falls within the Eive mile radius is expected to experience cnnsiderable develnpment. Specif-ical.ly, the 197S estimated populatinn nf 1,928 is expected tn grnv tn 2,678 by the year 2030 (see TabLe 2.1-1). These pre jectinns reflect the fact that most of the Atlantic Cnast nf Hutchinsnn Island is undeveloped, and the demand for beach frnnt prnperty is grnwing. In recngnxtir n nf this, The Plan has designated mnst c E the land area within five miles c f St Lucie Unit 2 as Lnw nr medium density residential. However, there are some cnnsideratinns which may af Eeet the rate at which demand fnr Hutchinsnn Island prnperty vill increase. For exampLe, there are nn Eresh 'water wells nn Hutchinsnn IsLand; therefore, all pntable water has tc be piped in Ernn the mainland. In the past, the city nf Fnrt Pierce has supplied potable water tn the Island. Hnvever,:at this time, the distributinn system supply-ing the island has reached its capacity. Unti 1 this(~g~tem is expanded, devel,npment nn the island wi lL be hampered
2. 1-28
SL2-ER-OL In general, it 'is anticipated that residential development wi thin five miles of St Lucie Unit 2 will consist of a mixture nf single family and multiple famil,y units. It is also expected that the~e units wiLL hnuse bnth permanent residents and seasonal visitors. Commercial and Services a) Commercial Commercial estabLishments on the mainland are concentrated along VS 1. It is expected that there vill be an increase in commercial land uses in cnnj unction with the predicted increase in residential land use, and that this increase will occur adjacent tn US 1 on the mainland. As is currentLy the case, it is anticipated that nev commercial establishments vill serve both local residents and high-way travellers. Two car dealers, Buick and Cadillac, are planning to move(jg)n the area, and other automotive related services may follow On, Hutchinson Island, it is expected that the new residential pro-jects vill house commercial establishments such as beauty shops, sports equipment outlets, etc. In additinn, nther commercial es-tablishments may be constructed along SR ALA. In fact, The Plan has zon'ed pockets of land on Hutchinson Island for such commercial deveLopment. b) Institutions At the present time, there are nn plans to construct any schools nr medical facilities vithin five miles of St Lucie Unit 2. How-ever, pressure has been brought by incal citizens on the General. Development Corpnratinn and other develnpers tn provide schnol facilities fnr children residing vithin develnpments. Fnr exampLe, Port St Lucie, a development run by the GDC, hp~~sked that schools be built to accommodate their chiLdren's needs' GDC has pro-vided land fnr three schnnls vithin the Hidpnrt develnpment. If these schools are built, a middle schnnl-high schoni vill be located about 3.5 miles south-west nf St Lucie Unit 2, and an elementary school will be lncated abnut 4.5 miles snuth southwest nf the plant. Indus t ri a 1 Currently there is very Little industrial Land use (rnughly 14 acres~ within five miles of St Lucie Unit 2. It is not expected that a signifi-cant amnunt of new industrial activity will, be initiated in this area. According to The Plan, only the area currently abutting the GDC Industrial Park (roughly 180 acres) vill be zoned light industrial. According tn local planning officials, there a~g ~n new firms currently seeking tn re-locate within the 1SO zoned acres ~
2. 1-29
SL2-ER-OL Trans ortation, Communication, and Utilities Within the transportation, communications and utilities classification, limited growth is, anticipated.,The Plan calls for the widening of roads currently intersecting with limited access highways. The Plan indicates that these roads could be expanded to four lanes. Within the five mile area, this objective would affect White City Road and 'SR A1A. In June 1978, a traffic study of Hutchinson Island was published for the St Lucie Board of County Commissioners. The report concluded that the three existing connecting structures - South Bridge, Jensen Causeway, and Stuart Bridge - were inadequate to handle existing traffic volumes. The report recommended that a fourth bridge be constructed at SR 712 (White City Road) which wou)$ )ink US 1, the Florida Turnpike, and Interstate 95 to Hutchinson Island . However, it is uncertain if, when, or where another river crossing vill be constructed because Qe waters of the Indian River in this area are part of an aquatic preserve No expansion of the communications category is anticipated at this time. Future utility land use associated with the construction of St Lucie Unit 2 is discussed in Section 2.1.3.3. Other Urban, and BuiLt-Up Land The other urban and built-up land category encompasses miscellaneous urban land uses, such as urban parks, and recreationaL facilities. A major land use change which will occur is the estabLishment of the State Savannahs Preserve. Using state funds, 3372 acres of land located at the western edge of the Florida East Coast Railroad right'of way ~g))paral-leling SR 707 have been purchased for a conservation preserve It is intended that the property which is event>>ally included in this preserve will be restricted to public access, and will serve primarily as a wildlife refuge. According to the Recreation and Parks Division of the Natural Resources Department, most of the Land which wj//)be included in the State Savannahs Preserve has been purchased to date With the increase in residential and commerciaL land uses, it that some growth in private recreational facilities will also occur. New. is expected residential complexes will probably include such recreational amenities as tennis courts, swimming pools, and possibly golf courses. Other urban land uses will probably increase as the aiea becomes more developed. For example, it can be expected that urban land, such as that given over 'to urban parks and water control structures, may be expanded in the future. At this time, there are no specific plans for such development; therefore, it is not possible to predict where such development will occur. However, it is likely that most of this type of development will occ>>r along US 1 and other major roads, such as White City Road and WaLton Road. A ricult<<ral Land There are currently roughLy 450 acres of actively used agricult<<ral Land within five miles of St Lucie Unit 2. It is unlikely that there will be an expansion of agricultural activities in the f>>t<<re. According to the
2. 1-30
SL2- ER-OL local County Agricultural Agent, the expansion of agricultural activities is lj)y)y to occur to the west of US 1 and not within the five mile area . The soils found within five miles of the plant, belonging to the Myakka-Immokolee-Basinger Association, have low potential for citrus production, y)jrh is the primary agricultural activity within five miles of the plant According to The Plan, "Prime agricultural, especially citrus, land should be 'preserved for continued production and benefit to the County economy". In spite of this stated concern for the preservation of agricultural land, it is expected that pressure to develop this land for residential or commercial use will be intense. Typically, the agricultural land within five miles of the plant which has been drained, is located near existing transportation corridors, and is easy to develop. Therefore, it is prime developable land in an area which will experience considerable development pressure in the future. Other Land Uses Little change is expected to occur in the Euture in the following USGS land cover/land use categories: forest land, water, and barren land. Some of the pine forest scattered on the mainland will probably be cleared to accommodate new residential and commercial development. However, it is not anticipated that a significant percentage of the total forested acre-age will be affected. At this time, no. major changes are projected within the barren land cate-gory. The transitional areas will eventually support one or more other Land uses. Specifically, the transitional land north of Weatherbee Road, which was once agricultural, will probably evolve back into forested land. 2.1.3.7 A riculture and Fisheries Within 50 Miles of St Lucie Unit 2 2.1.3.7.1 Introduction This section consists principally of tabulated data concerning agricul-tural, livestock, and commercial and recreational marine landings within 50 miles of the St Lucie Unit 2 nuclear generating Eacility. Data have been compiled on a county basis from fieLd surveys and from in-formation provided by federal, state, and county. agencies, and reporting services. All or parts of ten counties are included within the 50 mile radius. These are St Lucie, Indian River, Brevard, Martin, Palm Beach, Okeechobee, Osceola, Glades, Highlands and Hendry counties. All of Indian River, St Lucie and Martin counties faLl within the fifty mile radius. Approximately 75 percent of Okeechobee County, 50 percent of Palm Beach County and 20 percent of Brevard County Eall within the 50 mile radius. Less than five percent of Osceola, Highlands, Glades and Hendry Counties " are contained within the 50 mile area. Agricultural data Eor those counties whose land area is not compl.etely within the 50 mile area was allocated to the 50 mile area in the EoLlowing manner:
2. 1-31
~ SL2-ER" OL The area of the entire county was analyzed using 1972 US Geological Survey Maps (Scale 1:250,000) to exclude those areas where agricuLture or l.ive-stock farming could not occur. This would include water, wetland, urban recreation or "forested areas". The'emaining "open" lands have been analyzed to determine what percentage falls within the 50 mile radius. This'percentage is then applied to the county data to calculate what pro-portion of agr'cultural production falls within 50 miles of the site. For fisheries production, data on marine landings for each county are used since data on fishing locations are not available.
2. 1.3.7. 2 Beef Production Beef cattle production is one of the primary agricultural activities in southeastern Florida counties, with a production of appr'oximately 137,000 head within the 50 mile study area. Tabl.e 2.1-13 shows Okeechobee, Martjn and St Lucie coun)j~~ as the major beef producers, producing 10,020 x 10 kilograms in 1977 PresentLy there are 77 beef cattle ranches in St Lucie County, occupying 200,000 acres or 57 percent of the county area. Of this, 80,000 are im-proved pasture and 45,000 acres are highly improved pasture. By 1980-85, it is expected that beef cattle production will increase in the county along an intensification in the cultivation of improved grasses and clover ~j@
The grazing season for beef cattle in the study area begins in February, peaks in April, May and June, and ends by mid-November. During. this period, bahia and pangola grasses are the princ j~g) pas'ture feeds; hay grasses rank second, and bermuda grasses, third . In the cooler months from mid-November through January, smaL1. grains, hay and grass silage are necessary feed supplements, though in some are~~5)he avaiLa-bility of white clover alLows year around pasture feeding 2.1.3.7.3 Milk Production Milk production we))jn the study area totaLed approximateLy 151 x 10 kilograms in 1977 . Okeechobee ounty accounted fo~9g)out two-thirds of this total, producing 102.5 x 10 $ kilograms in 1977 . Within the Okeechobee area, corn and grass silage are the principal dairy cow feeds, although State figures show that commercial mixed feeds consisting of -corn, cotton seed meal, wheat br~g6~horts and alfalfa pellets, are fed on the avera g e at 16 p ounds p er da y Table 2.1-14 identifies dairy herds and milk production within 50 miles of the proposed facility. Table 2.1-15 shows that approximately 97.5 percent of the annuaL milk produced within the 0-50 miLe radius study area is sold to plants for manufacturing dairy products. Of the remaining, approxi-mately 0.6 percent is used raw on the farm for mi)$ cream and butter; 0 3 ~ is fed to calves; and 1.5 percent is sold Local.ly 6
2. 1-32
SL2-ER-OL 2.1.3. 7.4. Egg Production Egg production, from poultry farms wjQjn the study area, accounts for less than nine percent of the s)ate total . Within th~ study area there are approximately 109 x 10 layers producing 26 'x 10 eggs. Indian , River, Martin and St Lucie counties are the largest egg producers in the 50 mile area. Each of these counties has 25,000 layers producing on the average of 16,250 eggs per day. Table 2.1-16 is a breakdown by county of the egg production within 50 miles of St Lucie Unit 2.
2. 1-33
SL2-ER-OL 2.1.3.7.5 Commercial Vegetables, Fruit and Sugarcane Crops Commercial vegetables and citrus fruits are the main agricultural products in the area. Table 2.1-17 provides vegetable harvest statistics for the 0-50 mile radius area. Tomatoes and watermelon are the principal produce within 50 miles of the site, accounting for apgg~l harvests of approxi-mately 3,000 'acres and 650 acres respectively . Table 2 '-18 pro-vides yield statistics Eor those counties in the southeastern part of the state; Table 2.1-19 shows state"wide yield statistic's. Citrus crops are grown throughout the study area. Table 2.1-20 lists, by county, the amounts and types of citrus crops grown in the 50 mile area. St Lucie and Indian River Counties are the largest producers in the area. In 1977,8St Lucie County'roduced 3.7 x 10 kilograns of oranges and 3.3 x 10 ki lo~rams of grapefruit. In the same year Indian River pro-duced x 10 kilograms of oranges and 3.3 x 10>>logrsm>>f grape-Erui t )9) . These two counties accounted for 73 percent of the tota)100) citrus produced in the study area and 13 percent of the state total Flor'ida statistics show a net decline in Florida citrus acreage since 1970 ~ In 1977, 21,538 acres were removed from production. St Lucie and Hartin Counties were major contributors to the decline, while Hendry and Palm Beach Counties were the only two counties within the study area (and two of thre~lg~nties within the State) showing significant gains in citrus acreage Sugarcane is produced in the Everglades in the south and southwest portion of the study area in Glades, Martin, and Palm Beach counties. Table 2.1-21 list~lN~arcane production in Florida was produced in the 50 mile study area 2.1.3.7.6 Commercial Fish and Shellfish Landings Commercial landing statistics of fish and shellfish for the coastal coun-ties within 50 miles nf St Lucie Unit 2 (Brevard, Indian River, St Lucie, Martin, and Palm Beach counties) are presented by total landing in 1976 and principal species in Table 2.1-22. Whjfglflorida east coast landings in 1976 dropped by four percent from 1975 , total fish and shellfish landings Eor the coastal counties within 50 miles of the site showed a marked increase. Total landings for these counties were up approximately 18.6 percent from 1975 (See Table 2.1-23). The increape was the result of a 33.6 percent increase in fish landings from 7.1 x 10 'ilograms in 1975 to 9.5 x 10 kilograms in 1976. (otal shellfish landings however, declined by 36.9 percent from 1.9 x 10 kilograms in 1975 to 1.2 x 10 in 1976. Brevard was the only county which experienced a decline in both fxsh and shellfish landings, with a S.9 percent decrease in fish land-ings and 26.1 percent decrease in shellfish landings between 1975 and 1976. Table 2.1-23 compares 1976 to 1975 total fi sh and shellfish marine landings for Brevard, Indian River, St Lucie, Martin and Palm Beach counties. Ap-proxima'tely 90 percent of the fish caught is consumed by h~mans (See Table 2.1-24). Twenty percent of fish catch is consumed locally T02) pal finfish species taken were black mullet, menhaden, Spanish mackeral, bluefish, pompano and red snapper. The major commercial ports within this
2. 1-34
SL2-ER-OL area include Fort Pierce in St Lucie County, Port Salerno in Martin County, and Riveria Beach and Jupiter in Palm Beach County. According to the National Marine Fisheries Service, future commercial fish and shellfish landings are difficult to project, since catch is dependent largely on weather conditions, and the statistics are influenced by report-ing estimates. Nonetheless, the trend in Florida marine landings over the past s~y~~~l years has been a decline of from two to Eour percent an-nual ly 2.1.3.7.7 Recreational Fishing Prxncipal sport fishing areas within 50 miles of the plant site include the waters off Hutchinson Island, where pompano, bluefish, false albacore, kingfish, sailfish, dolphins, amberjack, flounder, mackerel and barracuda are common, and the St Lucie Inle( by snook, tarpon, redfish, ~predominated spotted sea trout and bottom fish Shore fishing occurs along the beaches of Hutchinson Island in the vicinity of St Lucie Unit 2. Access along the beach is= not restricted, so it is .possible for someone to fish directly on shore front of the discharge pipe-line. However, information is not available concerning the quality of the fishing i'n the area. The variety of species of fish which may be caught while ~hore fishing in-41047 elude kingfish, pompano, palometa and spot fin mojarra 2.1.3.7.8 Hunting Statistics Hunting statistics have been tabulated for the J W Cnrbett WildliEe Manage-ment Area and are shown in Table 2.1-25. The J W Corbett Wildlife Manage-ment Area occupies approximately 500 square miles of the western portion of the study area, mainly in Palm Beach County. Hunting season lasts from September 10 throu~:- March 26; the second week of January through the end of February eac) >>7'r is small game season and the month of March is spring turkey season ~ . Quail,, snipe and duck are the most common fowl (~)en while deer, hogs and squirrels are the prin-cipal wild animals taken . The game biologist Eor the J W Corbett Wildlife Management Q~~ assumes that 100 percent of the wild game harvest is consumed locally 2.1.3.8 Surface Water Use 2.1.3.8.1 Consumptive Use This xs no potable water use water resource which would be affected by St Lucie Unit 2 discharge gf any . Since drinking water supplies .are brought to Hutchinson Island by pipeline and since groundwater flows are from west to east toy~~) the ocean, no contamination of drinking water is considered plausible ' Therefnre, no analyses of cnnsumptive surface wa t er use were pe r fo rmed. 2~ 1-35 'L2-ER-OL 2.1.3.8.2 Recreational Water Use Since the discharge of St Lucie Unit 2 is'into the Atlantic Ocean, only those recreational uses associated w'ith saltwater activities have been con-sidered; These include beach activities, fishing, boating, and surfing, as defined in Outdoor Recreation in Florida 1 )a publication of the State of Florida Department of Natural Resources It is difficult to estimate accurately the number and location,of people involved in these activities because of the lack of information nn the places at which people take part in recreatjgM) pursuits. However, by utiLizing the results of state user surveys , a general order oE magnitude estimate of saltwater recreational activities with 50 miles of St Lucie Unit 2 can be generated. Statewide 1975 annual per capita par-ticipation rates for each saltwater related activity were modified tn re-flect average daily recreati'onal use (see Table 2.1-26 for methodology). These average daily per capita participation rates were applied to the projected population (resident and tourist) within >0 miles of St Lucie Unxt 2 (see Section 2.1.2) to estimate the average daily number of recrea-tional saltwater users. The results of these calculations are shown in Table 2.1-26. These projections are based on the Eollowing assumptions: a) Recreational users will pursue their activities only within 50 miles of St Lucie Unit 2. Residents and tourists in this area will sometimes journey out of the area for saltwater recreation, and, in turn, people from outside this area will enter it for these pur-p'oses. However, it is felt that these movements largely counter-balance one another, and because of the lack of more specific data, the numbers shown in Table 2.1-26 reflect a reasonable estimate nf recreational saltwater use. b) Recreational participation rates will not change over time. As stated in Outdoor Recreation In Florida 19261)such factors "have not been accurately estimated and quantified" . Because of this assumption, recreational use varies directly with the projected population. c) Participation rates for only Region X (southeast Florida from St Lucie to Dade Counties) would apply in the study area. Indian River and Brevard Counties Eall in a different Region, where parti-cipation rates are considerably lower. However, it was felt that using the Region X rates would result in a more conservative esti-mate, taking into account possible future increases in participa-tion. A 1978 average daxiy total of 110,431 recreational saltwater users is esti-mated within 50 miles of St Lucie Unit 2. This is expected to increase to 246,908 by 2030. Each category oE saltwater recreational activity is discussed in the following paragraphs: 2.1-36 SL2-ER-OL Beach Activities Beach activities include saltwater swimming, sunbathing, relaxing, beach-combing and shell collecting. These activities account for 60 percent of all saltwater reLated recreational use . The density of these users will vary according to whether or not access is available to the beach, and whether or not the beach is public (i.e., has Li fepII~~ds). For example, according to a survey of beaches in Hartin County performed in 1978, guarded beaches had an average density of 0.9 persons per lineal font, while unprotected areas had as few as 0.0036 people per linear font. In a survey of )Mg)es within two miles nf St Lucie Unit 2 conducted by FP&L in July, 1975, the average density was 0.0122 people per lineal foot nn the July 4th weekend. On other weekends this density was as low as 0.0025 people per lineal foot. The beaches near St Lucie Unit 2 have reLatively few access points. n The differences in user density along the coast within 50 miles of St Lucie Unit 2 can be shown generally by mappj,~s t)e public beaches and ac-cess points. This is done in Figure 2.1-19 ' . .The public beaches to the St Lucie Unit 2 discharge are nn Hutchinson Inland about 'losest four miLes NNW of the plant. Average daily usage at ttet~~y beaches was 656 persons between October 1, 1977 and September 30, 1978 1n generaL the public beaches tend to be clustered near bridges over the Indian River. Saltwater Fishin Saltwater fishing activities account for 18.4 percent of recreational water users within 50 miles of St Lucie Unit 2. These activities can include surf casting, crabbing, and deep sea fishing. No information on distribu- ~ tion of these users is available. ~Bnatin Boating includes both power boating and sailing. Power boating is a con-siderably more popular activity than sailing, occupying 17.9 percent of the recreational saltwater users, as opposed to only 1.4 percent for sailing. Boating activity takes place in conjunction with marinas and boat ramps, and the greatest density of this activity probably take place in the vicin-ity nf these facilities. Marinas within 50 miles of St Lucie Unit 2 are shown in Figure 2.1-19. Host nf these facilities are located near the populated areas and the Indian River inlets. The nearest pubLic marina to St Lu~jy2)nit 2 is approximately six miLes south of the St Lucie plant . It can also be expected that extensive pleasure boating takes place in most other areas of the Indian River as'well, as the nearby areas of the Atlantic Ocean. ~Barf in Surfing is a relatively unimportant activity in this area, with only 1.8 percent of the recreational saltwater users involved in this pursuit.
2. 1-37
SI 2-aR-OI. 2.1.3.9 Groundwater Use Field permeability tests at the plant site have indicated a seepage or flow of about 15,000 Eeet per year in the top 30 feet of the sand deposits. Taking the highest permeability coefficient obtained and a hydraulic gra-dient'E 100 percent, any discharge introduced into the ground at the plant sate would reach the Indian River in about a day. The discharge would then be greatly diluted. Because of the width of Indian River and presence of a continuous flow of groundwater toward the coastline, there is nn possi-bility of subsurface flow from the site to the mainland. This preclud~~L> any intrusion of plant releases into the mainland groundwater supplies In addj$ j)n, nO successful fresh water wells have been found on Hutchinson Island . For these reasons, no analysis of groundwater users has been made.
2. 1-38
SL2-ER-OL SECTION 2.1: REFERENCES Smith, Stanley- K. "Projections of Florida Population by County, 1980-2020". Bureau of Economic and Business Research, Division of Population Studies, Bulletin 44, July 1978 2~ City of Port St Lucie .City Planning Department, Comprehensive Plan-ning Program, "Population Estimates and Projections", February 1978
3. Aerial Photograph Indices, Florida Depaxtment of Transportation, 1969, 1974

4. Aerial. Photographs by Aerial Cartographics Inc, Orlando, Florida, October 21 and November 2 1978

5. Sales Office, Spanish Lakes, Port St Lucie, Florida, Lettex Dated January 5,,1979

6. "Savannahs State Presexve", Base Map Prepared by Department of Natural Resources, Division of Recreation and Parks, October 12, 1978 7~ Representative, Homer Colson Real Estate, Inc, Jensen Beach, Florida, Letter Dated December 5, 1978

8. 1960 Population Census and Population Estimates 1970-1985, for Florida and Florida Counties, Issued June 9, 1978 - Florida Depart-ment of Administration, Tallahassee, Florida

9. "Master Development Plan, Midport - City of Port St Lucie, Florida,"
(Map H4) Prepared by General Development Corp, Environmental Plann-ing Department, April 1978
10. Rules of the Department of Administration, Administration Commis-sion, Chapter 22F-2, Land Planning, Part II, Developments Presumed to be of Regional Impact. Undated.
DRI Coordinator, Treasure Coast Reg. Planning Council, Stuaxt, Florida, Letter Dated January 29, 1979, and Personal Communication, May 22, )979.
12. Sales Offices, Sand Dollar Villas, Personal Communication, January 15, 1979.

13. The Plan for Hutchinson Island - Prepared for the St Lucie Board of-County Commissioners bv RMBR Planning/Design Group, Tampa, Florida, August 1973

14. Tipton Associates, Inc., Hutchinson Island Traffic Stud, Prepared for Board of County Commissioners, St Lucie County, Florida, June 1978

2. 1-39
SL2-ER-OL SECTION 2.1: REFERENCES (Cont'd)
15. US Department of Commerce, Bureau of Census, Florida; 1970 Census of Population, Number of Inhabitants. Issued July 1971

16. "Major Developments Activity (Residental Only)", - Map Prepared by Area Planning Board of Palm Beach County, March 1976, Revised April
. 1977.
17. US Department of Commerce, Bureau of Census, "Projections of the Population of the US, 1977-2050". Current Po ulation Reports (P-25), No. 704, July 1977. (Series II Projections Used)

18. P"diect Manager <<PGA Complex, Florida Realty Building Company, Letter Dated December 11, 1978

19. Regional Planner, Treasure Coast Regional Planning Council, Stuart, Florida, Meeting on October 13, 1978

20. Planner, Martin County, Planning and Zoning Department, Meeting on October 12, 1978

21. St Lucie County Area Coordinator, Fort Pierce, Florida, Personal Communication, September 18, 1978

22. Treasure Coast Re ional Profile - 1977, Prepared bv Treasure Coast Regional Pl.arming Council, Stuart, Florida, September 1977 23; Director of Building and Zoning Department, Okeechobee County, Okeechobee, Florida, Personal Communication, September 1978

24. Planner Responsible for Existing Land Use Map of Glades County, L G Smith & Associates, Tampa, Florida, Personal Communic'ation, September 13, 1978

25. Land Use Policy Plan Summary, Southwest Florida Regional Planning Council, Fort Myers, Florida,. 1978. (Includes Glades County)

26. "Osceola County Development Areas Map", Osceola County, Board of Co'unty Commissioners. (No Date)

27. "Average Daily Beach Usage, Martin County, Florida", prepared by the Martin County Planning and Zoning Department, Stuart, Florida, November, 1978

28. Supervisor. of E1.ections, Glades County More Haven, Florida-Letter Dated December 8, 1978

29. Planner, Osceola County Board of County Commissioners, Kissimmee, Florida, Letter Dated November 3, 1978

30. Planner Responsible for Existing Land Use Map of Highlands County; Candeub, Fleissig & Associates, Newark, New Jersey, Letter Dated Noveber 3, 1978 2,1-40
SL2-ER-OL SECTION 2.1: REFERENCES (Cont'd) 31.. "Existing Land Use, Highlands County, F1.orida", Prepared foz High-lands County Zoning Department by Candeub, Fleissig & Associates, Planning Conshltants, 1978
32. "General Development Plan, Highlands County, Florida 1972", Pre-pared for the Highlands County Planning Commission by Candeub, Sun, August 31, 1972

33. Central Florida Regional Planning Council, Existin and Pro'ected Land Use, Central Florida Re ion, 1976-1955, June 1978

34. "Population Studies", in Waste Water En ineerin, Metcalf & Eddy, Inc, New York, McGraw-Hill Book Company, 1972, pp 16-25

35. Outdoor Recreation in Florida 1976 - State of Florida, Department of Natural Resources, Division of Recreation and Parks, Tallahassee, F1.orida, May 1976

36. Superintendent of Recreation, St L<<cie County, Ft Pierce, Florida, Letter Dated .December 5, 1978

37. Director of Lifeguards for Martin County, Hobe Sound, Florida, Personal Communication, November 16, 1978

38. Supervisor of Special Facilities, St Lucia County Civic Center, Fort Pierce, Florida, Letter Dated November 17, 1978

39. Chairman, Art-on-the-Green Festival, Fort Pierce, Florida, Letter Dated November 17, 1978

40. Executive Director,, Jensen Beach Chamber of Comme'rce, Jensen Beach, Florida, Letter Dated November 17, 1978

41. Dizector, Stuart/Martin County Chamber of Commerce, Stuart, Florida, Letter Dated November 22, 1978

42. Student Activities Office, Florida Institute of Technology - Jensen Beach Campus, Jensen Beach, Florida, Personal Communicatioii, November 27, 1978

43. Finance Office, Indian River County Schools, Vero Beach, Florida, Letter Dated November 27, 1978

44. Office of the Vice President, Indian River Community College, Fort Piezce Campus, Fort Pierce, Florida, .Letter Dated November 28, 1978

45. Personnel Department, Piper Aircraft Corporation, Vero Beach, Florida, Letter Dated December 4, 1978

46. Fair Secretary, St Lucie County Fair, Fort Pierce, Florida, Letter Dated November 20, 1978
SL2-ER-OL SECTION 2.1: REFERENCES (Cont'd)
47. Fair Secretary, Hartin County Fair Association, Stuart, Florida, Letter Dated November 20, 1978

48. Personnel Department, Gruman Aerospace, Stuart, Florida, Letter Dated November 30, 1978

49. Maintenance Foreman, St Lucie County School Board, Fort Pierce, Florida, Letter Dated November 28, 1978

50. Executive Secretary, Sandy Shoes Festival (1979), Fort Pierce, Florida, Letter Dated November 27, 1978

51. South Florida Fair, Palm Beach County Fairgrounds, West Palm Beach, Florida, Personal Communications, November 21 and 27, 1978

52. Employment Office, Pratt 6 Whitney Airczaft, Government Products Division, Palm Beach County, Florida, Personal Communication, November 30, 1978 Average Daily Traffic Counts, Bureau of Planning, State of Florida,
'3. Department of Tran'sportation, Tallahassee, Florida, February 20, 1978
54. State of Florida, Department of Transportation, Division of Trans-portation Planning, 'Florida Interstate System Bi-Monthly Progress Report, Tallahassee, Florida, September 1978

55. State of Fl'orida, Department of Transportation, Map of "Alternate Corridor Locations". (Undated)

56. U S Army Corps of Engineers, Waterborne Commerce, Jacksonville Dis-
.trict, pp 135, 137, 145, 197
57. Lockmaster, St Lucie Canal - Okeechobee Waterway, Personal Communi-.
cation, September 14 and October 10, 1978
58. Route Analvst - Eastern Routes Marketing Research, Amtrak, Washing-ton, D.C., Letter Dated November 30, 1978

59. Manager - Eastern Routes - Marketing Research, Amtrak, Washington D.C., Personal Communication, May 22, 1979

60. Airport Manager, St Lucie County Airport, Fort Pierce, Florida, Personal. Communi.cation, December 6, 1978 6]. Director of Public Relations, Allegheny Airlines - Allegheny Com-muter Service, Washington National Airport, Washington, D.C., Letter Dated December 6, 1978

62. Alla henv Commuter Passen er Traffic Statistics, 1970 - 1977, Allegheny Axrlxnes, Washington National Airport, Washington, D.C.

2. 1-42
SL2>>ER-OL SECTION 2.1: REFERENCES (Cont'd)
63. Directox'f Planning, Palm Beach International Airport, West Palm Beach, Florida, Letter Dated November 30; 1978

64. St Lucie County Development Coordinator - Map of E'lanning Units, Prepared fox Population Count, 1978

65. U S Dept. of Commerce, Bureau of the Census. l970 Census, Characteristics of the Po ulation, U S Summarv. Issued June, 1973

66. Letter L-76-416, to D L Ziemann, Chief Operating Reactors Branch 82 Division of Operating Reactors, USNRC, Washington D C, from R E Uhrig, Vice President of Floxida Power and Light, December 7, 1976.

67. Letter FLO-1376, to L Tsakiris, Project Manager, Ebasco Services from C S Kent, Project Managex, Florida Power and Light, March 14, 1979.

68. Florida Power & Light Company, St Lucie Unit 1, Docket No 50-335, Annual Radiological Environmental Monitoring Report, 1978.

69. United States Geological Survey, "A Land Use and Land Cover Classi-fication System for Use with Remote Sensor Data." Geological Survey Professional Paper 964. United States Government Printing Office, Washington, 1976.

70. U S Department of the Interior, Geological Survey, U S Department of Commerce, National Ocean Suxvey, Coastal Ma in Handbook, U S Government Printing Office, Washington, 1978.

71. Florida Department of Administration, Bureau of Compxehensive Plann-ing Generalized Soils Map of St Lucie County, Florida.

72. Davis, J, "The Natural Features of Southern Florida", Geological Survey Bulletin No. 25, Florida Department of Conservation, 1943.

73. Representative, Allen Real Estate, Port St Lucie, Personal Communi-cation, February 27, 1979.

74. Representative, Hoyt C Murphy Realty, Inc, Port St Lucie, Personal Communication, February 27, 1979.

75. Sales Office, Spanish Lakes, Port St Lucie, Florida, letter dated January 5, 1979.

76. Aerial Photographs by Aerial Cartographics Inc, Orlando, Florida, October 21 and November 2, 1978.

77. Representative, Hutchinson Island Inn, Hutchinson Island, Personal Communication, April 10, 1979.

78. Representative, Sheraton Resort Inn, Hutchinson Island, Personal Communication, April 10, 1979.

2. 1-43
SL2-ER-OL SECTION 2.1: REFERENCES (Cont'd)
79. Representative, Oceana, Hutchinson Island, Per'sonal Communication, April 10, 1979. 'I

80. Sales Office, Sand Dollar Villas, Personal Communica'tion, January 15, 1979.

81. Florida Power and Light Company, St Lucie Plant Unit'o. 2 Environmental Report - Construction Permit, Vol 1, 1973.

82. Field Inspection, March 1979.

83. County Agricultural Agent, Personal Communication, April 4, 1979.

84. St Lucie County Growth Mana ement Plan - Prepared for the St Lucie County Board of County Commissioners by the Planning/Design Group, Florida, 1978.

85. The Plan for Hutchinson Island - Prepared for the St Lucie Board of County Commissioners by RMBR Planning/Design Group, Tampa, Florida, August 1973.

86. The Savannas Plan - Prepared for the St Lucie Board of County Commissioners by the Planning/Design Group, Tampa, Florida, undated.

87. Representative, Treasure Coast Regional Planning Council, Stuart, Florida, Personal Communication, April 10, 1979.

88. Superintendent, Water Distribution and Wastewater Collection, Fort Pierce, Florida, Personal Communication, March 12, 1979.

89. Tipton Associates, Inc. Hutchinson Island Traffic Study, Prepared for the Board of County Commissioners, St Lucie County, Florida, June, 1978.

90. "Savannas State Preserve", Base Map Pz'epared by the Depaztment of Natural Resouxces, Division of Recreation and Parks, October 12, 1978.

91. Representative, Department of Natural Resources, Recreation and Parks Division, April 10, 1979.

92. County Agricultural Agent, St Lucie County, Personal Communication, March 12, 1979.

93. l977 Flozida and USDA official estimates from, "Florida Agricultural Statistics - Livestock Summary, 1977", Florida Crop and Livestock Reporting Service, Or/.ando, Florida.

94. South Florida Water Management District, Water Use Plan, Volume II, Appendix A, 1977.

2. 1-44
SL2-ER-OL SECTION 2.1: REFERENCES (Cont'd)
95. University of Florida, Beef Cattle in Florida, Bulletin 28, provided by T Boxdelon of Florida Crop and Livestock Repoxting Ser-vice in a personal communication to G Jandegian, Envixosphere Company, March 1979.

96. Florida Crop and Livestock Reporting Service, "Florida Agricultural Statistics - Dairy Summary, 1977", Orlando Florida.

97. Florida Crop and Livestock Reporting Service, "Pou1,try Summary 1977 - Agricultural Statistics," Orlando, Florida.

98. Florida Crop and Livestock Reporting Service, "Vegetable Summary 1977 - Floxida Agricultural Statistics," Orlando, Florida.

99. Florida Department of Agriculture and Consumer Services, "Commercial Citrus Tree Inventory Prel.iminary Report" Orlando, Florida, August 251 1978.
100. Florida Crop and Livestock Reporting Service, "Field Crops Summaxy 1977 - Florida Agricultural Statistics," Orlando, Florida. 101. Florida Department of Natural Resources, Division of Marine Re-sources, Summar of Florida Commercial Marine Landin s, Tallahassee, Florida, 1976. 102. J E Snell, Supervisory Fishery Reporting Specialist, National Marine Fisheries Service, Miami, Florida, Personal Communication, Januaxy 1979. 103. Stuart/Martin Co. Chamber of Commerce, Stuart Resort and Business Guide, 1978. 104. Applied Biology Inc, St Lucie Plant Annual Non-Radiolo ical Moni-105. B Lusander, J W Corbett Mild Life Management District, Personal Communication, January 1979. ) hie Outdoor Recreation in Florida 1976, State of. Florida Department of Natural Resources, Division of Recxeation and Parks, Tallahassee, Florida, May 1976. 107. Martin County Planning and Zoning Department, "1978 Survey of Aver-age Beach Usage," Letter dated November 22, 1978. 108. Florida Power & Light Company, St Lucie Plant Unit No. 2 EnvironmentaL Report - Construction Permit, Amendment 8, p 10.7-40, June 4, 1976. 109. Re ional Profile, Treasure Coast Regional Planning Council, Stuart, Florida, September, 1977. 2.1-45 SL2-ER-OL SECTION 2.1: REFERENCES (Cont'd) 110. Florida Department of Natural Resources; Division of Recreation and Parks, Letter Dated May 2, 1979. Superintendent of Recreation, St Lucie County, Ft Pierce, Florida, letter dated December 5, 1978. 112. Boatin Almanac, Vol 6, Boating Almanac Co., Inc, Severni Park, Maryland, 1978. 113. Florida Crop and Livestock Reporting Service, "Citrus Summary 1977-Florida Agricultural Statistics," Orlando, Florida.
2. 1-46
SL2-ERAL ThBLE 2.1-1 Sheet 1 of 8 RESIDENT POPULhTION WITNIN 50 HILES OP ST LUCIE UNIT 2 1978 hnnular
Total *

Total Total Sector 0" 1 1-2 2-3 3-4 4-5 5"10

0-10

10-20 20-30 30-40 40-50

10-50 0-50 0 0 0 0

0+ 0

0 e NNE 0 0 0

p* 0

0*
0 0 0 Q 4 P
0

0e ENE 0 0 0 Q

P

Q e Q*
0 0 0 p
p e P

Q

ESE 0 0 0 p

p e 0 e 0*
SE 0 0 0 0
0* 0

0+
SSE 0 0 0 0 1928 6212
8140

750& 18119 53957 126615

206199

214339 0 0 0 21 2 223 6744

7179

17948 568 6274 65250

90040

97219 SSW 0 0 104 0 1330 + 1434 e 1752 3452 158 4044

9406' .10840 SW 0 19 70 723

812

1752 1646 74 11029

14501

15313 WS'W 0 59 0 11 2767 3854

6691

9120 566

9686

16377 0 19 44 532 517 482

1594

1913 0 8360 1223

11496

13090.
WNW 0 0 108 382 1229 3302
5021,

689 0 119

808

5829 0 0 0 33 141 36483

36657 + 15799 1079 2159 0

19037

55694 NNW 0 0 0 0 0 3523

3523

4143 42045 3138 2215

5)541 + 55064 Total 0 97 326 1170 6805 62653

71051

51504 66909 83240 211061

412714

483765
SL2-ER-OL ThBLE 2.1-1 Sheet 2 of 8 RESIDENT POPULATION MITHIN 50 HILES OF ST LUCIE UNIT 2 1980 hnnu lar Total Total Total Sector 0-1 1-2 2-3 3-4 4.<<5 5-10 + 0-10
10-20 20"30 30-40 40-50

10-50

0-50 0 17 0 0 0 0

17* 0

0

17 0 0 0 0 0 Q

Q

0

Q e HE 0 0 0 0 0 0 + 0* 0 0

0

ENE 0 0 0 0 0 0 + 0* 0

Q*
0 0 0 0 0 0
0* 0

0+
ESE 0 0 0 0 0 Q
0

0

0

0 15 0 0 0 0

15* Q e Q

15 SSE 0 10 0 29 1983 6487

8509

8385 19776 60385 132498

221044

229553 0 0 0 218 240 6965

7423

20043 633 7022 73024

100722

108145 SSH 0 0 112 208 520 2754

3594

1957 3885 171 4378

10391

13985 0 20 74 93 2543 2717

5447'* 1957 1838 83 11941

15819 * . 21266 WSH 0 63 5 22 2878 '938

8906 * '0 10032 608

10640 + 19546 0 20 51 560 559 738

1928

2070 0 9196 1343

12609

14537 0 0 114 402 1309 3414

5239

745 129

874

6113 0 0 0 34 146 37962

38142

17084 1159 2318 0

20561

58703 0 8 12 10 16 3619

3665

4471 45154 3322 2272 55219

58884 Total 0 153 368 1576 10194 70594

82885

56712 72445 92529 226193

447879

530764
SL2-ER<L TABLE 2.1-1 Sheet 3 of 8 RESIDENT POPULATION MITHIN 50 HILES OP ST LUCIE UNIT 2 )983 Annular Total Total Total Sector 0-) 1-2 2-3 3-4 4-5 5-)0
0-)0 ) 0-20 20-30 30-40 40-50 + )0-50

0-50 0 25 0 0 0 0>> 25* 0 a 0>> 25 NNE 0 0 0 0 0 0>> 0>> 0

0*
NE 0 0 0 0 0 0
0* 0

0*
0 0 0 0 0 Q
P

0

0*
0 0 0 0 Q P
Q

0

0*
ESE 0 0 0 0 0 p
p

0

0*
0 22 0 0 0 0
22>> 0

0* 22 SSE 0 14 0 44 2006 6719

8783

9&72 22043 68820 140290 >> 240825

249608 0 0 0 221 248 7107

7576

23)19 728 8002 83224

115073

122649 SSM 0 0 115 218 549 3063

3945

2257 4446 )88 48)8

11709 >> )5654 0 21 76 )02 2574 2886

5659

2257 2120 96 )3140 * )76)3

23272 0 65 8 27 2933 6834 >> 9867 >> 0 11232 670 >> l)902 >> 2)769 0 20 54 573 578 850 >> 2075

2278 0 )0296 )501 >> 14075

16150 0 0 117 4) 2 1346 3496 >> 537) >> 820 143

963

6334 0 0 0 35 )48 38698

38881

18778 )264 2528 0 >> 22570

6145)
NNH 0 )2 16 )4 23 3681
3746

4903 49244 3566 2349 >> 60062

63808 Total 0 179 386 1646 10405 73334

85950

64084 79845 )04728 246)35

494792 >> 580742
SL2-ER-OL TA8LE 2.1-1 SReet 4 of 8 RESIDENT POPULATION MITHIH 50 HILES OF ST LUCIE UNIT 2 1990 Annular Total Tocal Tocal Sector 0-1 1-2 2-3 3-4 4-5 5-10 e 0-10
10-20 20-30 30-40 40-50

10-50

0-10 0 68 0 0 0 0

68* Q

Q

68 HalE 0 0 0 0, 0 p A p e Q e p

HE 0 0 0 0 0 Q

Q

0

0*
0 0 0 0 0 p a Q e Q e p
0 0 0 0 0 Q

Q

p

p ESE 0 0 0 0 0 0

0* P

Q

0 60 0 0 0 0 + 60+ Q k Q + 60 SSE 0 38 0 119 2144 7155

9456 e 11369 25837 84538 155048 c 276792

286248 0 0 0 237 291 7582 + 8110

2717S 855 9830 102232 a 140092

148202 SSM 0 ~ 0 133 269 700 5022

6124

2653 5226 220 5641 e 13740

19864 S'M 0 25 86 146 2730 3955

6942

2653 2492 113 15385

20643

27585 MSM 0 75 21 54 3214 12495

15859 + 0 13296 783 e 14079

29938 0 21 71 641 680 1563 + 2976

2668 0 12188 1774 a 16630

19606 0 0 133 461 1542 3685 + 5821 + 960 168

1128 + 6949 0 0 0 39 160 41058

41257

21980 1472 2944 0

26396

67653 HNM 0 30 42 38 62 3898

4070

5731 57342 4115 2650

69S38

73908 Tocal 0 317 486 2004 11523. 86413

100743 % 75189 93224 127244 283681

579338

680081
SL2-ER-OL ThBLE 2.1-1 Sheet 5 of 8 RESIDENT POPULATIOH HITHIH 50 HILES OF ST LUCIE UNIT 2 2000 hnnular Total Total Total Seator 0-1 1-2 2-3 3-4 4-5 5-10
0-10

10-20 20-30 30-40 40-50

10-50 * . 0-50 0 115 0 0 0 + 115* + 0+ 115 0 0 0 0 0 Q e Q 4 0

0*
0 0 0 0 0
Q e 0

0>>
ENE 0 0 0 0 0
0* 0

0*
0 0 0 0 Q e Q 4 0' 0 e 0* ESF. 0 0 0 0 0
Q

0

0*
SE 0 102 0 0 0
102

0

0

102 SSE 0 64 0 201 2295 7345

9905

13207 30012 101810 171690

316719

326624 0 0 0 254 335 7712 e 8301

31569 994 11838 123119

167520

175821 SSM 0 0 154 326 867 8010

9357 + 3082 6071 255 6552

15960

25317 0 28 97 195 2904 5523

8747

3082 2895- 131 17870

23987

32725 MSW 0 86 37 84 3525 20000

23732

0 15447 911

16358

40090 0 23 90 717 792 2702

4324

3099 0 14160 2062

19321

23645 0 0 150 516 1758 3790

6214

1115 195

1310 e 7524 0 0 0 42 173 41806

42021

25533 1711 3422 0 + 30666

72687 HNW 0 52 70 64 105 3927

4219 + 6658 66653 4782 3078

81171 e 85390 Total 0 470 598 2399 12755 100815

117037 + 87345 108336 151845 325477 673003 790040
SL2"ER-OL ThBLE 2.1-1 Sheet 6 of 8 RESIDENT POPULATION MITHIH 50 HILES OF ST LUCIE UHIT 2 2010 hnnular Total Total Tocal Sector 0-1 1-2 2-3 3-4 4-5 5-10
0-10 * , 10-20 20-30 30-40 40-50 e 10"50

0-50 0 155 0 0 0

155 Q

Q e 155 HNE 0 0 0 0 0 0

0* 0 0 P

Q*
HE 0 0 0 0 0 e Q e 0 - 0 P ~ 0* 0 0 0 0 Q
Q e 0

0*
0 0 0 0 p e Q* 0 + 0* ESE 0 0 0 0 p
p* 0' Q

Q

0 0 137 0 0 0

137

Q

Q* 137 SSE 0 85 0 272 2421 8163

10941 e 14758 33537 116302 185967

350564

361505 0 0 0 268 375 8551

9194

35277 1111 13524 140645 .

190557 * ,199751 SSM 0 0 172 374 1009 11)03

12658 e 3444 6784 285 7322

17835

30493 SM 0 32 107 237 3049 6863

10288

3444 3236 146 19969 e 26795 * ~ 37083 MSM 0 - 96 49 110 3788 20000

24043

0 17262 1019

18281

42324 0 25 106 781 887 3343

5142

3463 0 15823 2304 e 21590 + 26732 MHM 0 0 164 562 1942 4200 + 6868

1247" 218 + 1465 e 8333 0 0 0 46 183 46391

46620 e 28533 1912 3824 0

34269

80889 HNM 0 70 94 85 140 4348

4737

7441 74482 5344 3439

90706

95443 Tocal 0 600 692 2735 13794 112962

1 30783

97607 121062 172510 360883

752062

882845
SL2 ER"OL ThBLE 2.1-1 Sheet 7 of 8 RESIDENT POPULhTIOH WITHIN 50 MILES OP ST LUCIE UNIT 2 2020 hnnnl ar Total Total Total Sector 0-1 1-2 2"3 3-4 4"5 5-10
0-10

10-20 20-30 30-40 40"50

10-50

0-50 0 194 0 0 0

194

194 NHE 0 0 0 0

p* Q

P

NE 0 0 0 0

Q>> Q

P

EHE 0 0 0 0 0>> 0* 0

0>>
0 0 0 0 Q
Q* 0

0*
0 0 0 0 Q
Q

Q

Q

SE 0 171 0 0 0>> 171* 0

0* 171 SSE 0 106 0 339 2543 8865

11853

16266 36964 130364 199908

383502

395355 0 0 0 282 413 9272

9967

38882 1223 151'59 157649 >> 212913 >> 222880 SSW 0 0 189 421 1146 14126

15882

3796 7477 314 8070

19657

35539 SW 0 35 116 277 3191 8500

12119

3796 3566 161 22010

29533

41652 0 105 62 135 4044 '0000

24346 * .0 0 19026 1123

20149

44495 0 26 122 844 980 4424 >> 6396

3816 0 17440 2539

23795

30191 0 0 178 607 2120 4555

7460

1374 240 >> 1614

9074 HW 0 0 0 49 196 50317

50562

31449 2108 4215 0

37772

88334 NHW 0 87 117 106 175 4715

5200

8201 82094 5890 3791

99976

105176 Total 0 724 784 3060 14808 124774

144150

107580 133432 192569 395330

828911

973061
SL2-ER"OL ThBLE 2.1-1 Sheet 8 of 8 RESIDENT POPULhTION MITIIIH 50 HILES OF ST LUCIE UHIT 2 2030 hnnu lar Total Total Total Sector 0-1 1-2 2-3 3-4 4"5 5" 10 + 0-10 10-20 20-30 30-40 40-50.
10-50

0-50 0 237 0 0 0

237 e Q

Q

237 NNE 0 0 0 0 0

p 4 0

0*
NE 0 0 0 0 0 p
p e 0

0*
ENE 0 0 0 0 0 0
0* P

Q

0 0 0 0 0 0

0* Q

Q

ESE 0 0 0 0 0 Q

Q e e Q

0 209 0 0 0 0

209

0 0 0 + 0* 209 SSE 0 )29 0 414 2678 9869 e 13090

17925 40735 145878 215143

419681

432771 0 0 0 298 456 10306

11060

42848 1349 16963 17641)

237571

248631 SSM 0 0 208 473 1298 17148

19127

4183 8240 346 8893 e 21662

40789 0 38 )26 322 3349 10136

13971

4183 3930 177 24255

32545

46516 MSW 0 115 76 152 4326 20000 e 24669 a 0 20966 1237

22203

46872 0 28 )39 9)2 1082 5506

7667

4206 0 19219 2798

26223

33890 WNM 0 0 194 656 2316 5066

8232

15)4 265

1779

10011 0 0 0 52 207 54497 a 54756

34657 2323 4645 0

41625

96381 HNW 0 108 )43 129 214 5239

5833

9038 90468 649) 4177 + 110174

116007 Total 0 864 886 3408 15926 )37767

158851

118554 147045 214685 433179

913463

1072314
SL2-ER-OL TABLE 2.1-2 AGE DISTRIBUTION OF THE PROJECTED POPULATION FOR THE TEAR 2000 MITHIH TEH MILES OF ST LUGIE UNIT 2 Total Total 0-10 O-l miles 1-2 miles 2-3 miles 3-4 miles 4-5 miles 5-10 mile's 0-10 miles miles ~ Sector 12* )2-)8** )8**+ )2 )2-18 )8 12 12-18 18 12 12-18 18 12 12-18 18 12 12-18 IB 12 12-18 18 4~II s ss )8 83 0 0 0 0 0 0 0 0 0 0 0 0 29 18 83 130 N 0 0 0 29 NNE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ENE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ESE 0 0 0 0 0 0 0 0 0 0 0 0 0 26 15 74 115 SE 0 0 0 26 )5 74 0 0 16 10 45 0 0 0 5) 30 146 521 316 1 500 1 731 1 048 4<<982 2 ~ 319 1 <<404 6 673 10<<396 SSE 0 0 0 ~ ~ S 0 0 0 0 0 0 0 0 0 58 35 166 78 47 225 1 ~ 777 1 ~ 076 5 ~ 115 1<<913 1 ~ 158 5 506 8,577 SSM 0 0 0 0 0 0 36 22 103 35 21 100 )03 62 296 1 ~ 852 1 121 5<<333 2<<026 1 <<226 5 832 9,084 SM 0 0 0 6 4 19 22 14 65 30 18 87 )07 64 307 1,078 652 3 '02 l<<243 752 3 '80 5,575 MSM 0 0 0 20 )2 58 9 6 27 2) 13 60 808 489 2,327 4,460 2,700 12,840 5,318 3,220 15,312 23,850 M 0 0 0 5 3 16 21 13 62 165 100 475 184 112 531 767 465 2<<210 I ~ 142 693 3 294 5,129 MMM 0 0 . 0 0 0 0 35 21 99 119 72 342 407 246 1,172 878 531 2<<528 1 ~ 439 870 4 141 6,450 0 0 0 9 6 28 39 24 114 9<<618 5 ~ 822 27 689 9 ~ 666 5<<852 27 831 43 ~ 349 HM 0 0 0 0 0 0 HNM 0 0 0 )3 8 38 17 11 50 16 9 46 27 16 77 901 545 2 593 974 589 ~2884 4 367 0 0 115 70 333 140 87 406 504 304 1,450 2,274 1,376 6,549 23,062 13,960 66,392 26,095 15,797 75,130 l)7,022
Persons eleven years of age or younger.

Persons bet3<<een and including tuelve to eighteen years of age.

Persons nineteen years of age or older.
SL2-ERAL ThBLE 2.1-3 CITIES TOWNS hND COHHUNITIES OF OVER 5 000 PERSONS WITHIN 50 HILES OF ST LUCIE UNIT 2 ESTIHhTED FOR 1978 a) Communities of over 10,000 Persons 1976 1978 1970 Population Population es Cit or ToMn ~taunt ~Po i tion (Estimated) (Estimated)* West Palm Beach Palm Beach 57,375 61>236 62,616 Fort Pierce Sc Lucie 29>721 32,182 33,083 Riviera Beach*** Palm Beach 21,401 25,892 27,735 Vero Beach Indian River 11,908 15,303 16,800 North Palm Bglgh*** Palm Beach 9,035 13,026 15,014 Palm Springs ** Palm Beach 4,340 8,437 11,300 Palm Beach Cardens Palm Beach 6,102 9,182 10,792 Stuart Hartin 4,820 8,479 10,760 b) Communities of betueen 5,000 and 10,000 Persons 1976 1978 1970 Population e Population ss Count or Tovn ~to nt ~PO i tton 4 (Estimated)* (Estimated)** Palm Beach* Palm Beach 9,086 9,724 9,952 Cifford Indian River 3,509 5,772 9,485 Lake Park ** Palm Beach 6,993 8 >182 8,652 Creenacres City Palm Beach 1,731 4,447 6,773 Pahokee ++ Palm Beach 5,663 5,813 5,864 Porc St Lucie St Lucie 330 4,463 6,465 Royal Palm Beach Palm Beach 475 2,380 5,598 Treasure Coast Regional Planning Council, Re ional Profile, September 1977, Table 30. Hethodology discussed in Section 6.1.4.2. Part of West Palm Beach Urbanized brea, 1970 Census, Florida, Number of Inhabitants, Table 11 and Figure 11-45. 1978 population estimated on basis of annual average grovth rate from the 1960 population of 3,509 to the 1970 populacion of 5,772 (1970 Census, Florida, Niaaber of Inhabitants, Table 6) because 1976 estimate vas not available. ++ "Population Estimates and Projections", Com rehensive Plannin Pro ram, prepared by the City Planning Dept, Porc St Lucre, F or@de, February 1978. SL2-ER-OL ThBLE 2.1-4 hGE DISTRIBUTION OF THE PROJECTED POPULhTION FOR THE YEhR 2000 BETWEEN TEH hHD 50 NILES OF ST LUCIE UNIT 2 Tocal 10-50 10-20 miles 20>>30 miles 30-40 miles 40-50 miles Total 10-50 miles miles Bettor 12* l2-18+* 18*** 12 12 )8 18 12 12-18 18 12 12 18 18 12 12-18 18 4~III 2 ss NNE NE 0 EHE 0 ESE 0 0 0 0 0 SSE 2,945 1,783 8,479 6,693 4,052 19,267 228704 138744 658362 388287 238178 1108225 708629 428757 2039333 3168719 7,040 4,262 20,267 222 134 638 2 ~ 640 1 8598 7 ~ 600 278455 16 ~ 621 79 043 37 ~ 357 22 615 1078548 167 ~ 520 SSW 687 416 1,979 1 8354 820 36897 57 34 164 1,461 885 4,206 3,559 2,)55 10,246 )5,960 SW 687 416 1,979 646 391 1,858 29 18 84 3,985 2,412 11,473 58347 3 237 15 ~ 394 23,978 'WSW 38445 28085 9 ~ 917 203 123 585 3,648 2,208 10,502 16,358 691 418 1,990 3,158 1,912 9,090 460 278 1,324 4,309 2,608 12,404 19,321 249 150 716 26 126 292 176 842 1,310 5,694 3,447 16,392 382 231 1,098 763 462 2,197 6,839 4,14D 19,687 30,666 NHW ~1485 899 ~4274 ~14 864 ~8998 ~42 791 ~1066 646 ~3070 686 416 I 916 18 181 ~18 959 52 Ill 81 lll 19 ~ 478 1 1 ~ 791 56 076 24 ~ 161 14 ~ 626 69 ~ 549 ~ 33 862 20 ~ 499 97 484 72 ~ 580 43 ~ 939 208 ~ 958 1508081 90 ~ 855 432 067 673 003
Persons eleven years of age or younger.

Persons becveen and inoluding tMelve to eighteen years of age.

Persons nineteen years of sge or older.
SL2-ER-OL TABLE 2.1-5 Sheet 1 of 8 PEAK DAILY TOURISTS AND SEASONAL VISITORS WITHIN 30 MILES OF ST LUCIE UNIT 2 1978 Annular Total Total Total Sector 0-1 1-2 2-3 3-4 4-5 5-10
0-10 + 10-20 20-30

10-30

0-30 0 0 0 0 Q *

Q a 0 0 0 0

Q *

Q

NE 0 0 0 0

p

4 p* 0 ENE 0 0 0 0 Q *

Q*
0 0 0 0
Q *

p*
ESE 0 0 0 0
Q

p

0 0 0 0 0

p*

p* 0 SSE 0 0 0 0 5133 6439

11572 + 3407 8348

11755

23327 0 0 0 42 44 1680

1766

6814 190

7004

8770 SSW 0 0 20 0 0 1861

1881

572 1125

1697

3578 0 4 14 0 142

160

572 536 1108

1268 WSW 11 0 . 2 544 757

1314 *

0

1314 4 9 105 102 95

315

649 0

649* 964 0 21 75 773 866

1735

234

234* 1969 0 6 154 7644

7804

3845 437

4282

12086 0 0 0 0 50 1582

1632

2467 16993

19460

21092 TOTAL 0 19 64 230 6800 2)066

28179

18560 27629

46189 a 74368
SL2-P.R-OL ThBLE 2.1-5 Sheet 2 of 8 PEhK DhlLY TOURISTS hND SEhSOHhL VISITORS WITHIN 30 NILES OF ST LUCIE UHIT 2 )980 hnnular Total Total Total Sector 0"1 1-2 2-3 3-4 4-5 '-10
0-10 + 10-20 20-30 + 10-30

0"30 0 0 0 0 0

Q *

Q

NNE 0 0 0 0 D

0*

Q

0 0 0 0 e Q *

Q

ENE 0 0 0 0

Q *

p

0 0 0 0

Q*

p 0 0 0 0

Q

0 0

p e 0 0 0

Q *

p a SSE 0 0 0 0 ) D160 7326

17486

4470 9014

13484

30970 0 0 0 49 52 1840

1941

7962 )94

8156

10097 SSW 0 0 24 0 0 1585

1609

586 )153 1739

3348 D 4 17 0 447 167

635

586 550

1136

1771 0 13 0 2 638 889

1542 *

Q

1542 0 4 10 123 119 111 367

660

66D* 1027 0 0 24 88 )335 935

2382

237 237 + 2619 0 0 0 7 162 8989

9158

4693 478 5171

14329 NNU 0 0 0 0 )02 1717

1819

3471 18599

22070

23889 TOThL 0 21 75 269 13015 23559

36939

22665 29988

52653

89592
SL2-ER-OL TABLE 2.1-5 Sheet 3 of 8 PEAK DAILY TOURISTS AND SEASONAL VISITORS 'MITNIN 30 HILES OF ST LUCIE UNIT 2 1983 Annular 'Total Total Total Sector 0-1 )-2 2-3 3-4 5-10
0"10

10-20 20"30

10-30

0"30 0 0 0 0 Q
= e Q *
Q

0 NNE 0 0 0 0 0 Q *

Q

0 0 0 0 0 0

Q*

Q

ENE 0 0 0 0

Q Q

Q *

0

0
'
0

0 0 0 0 0 ESE 0 0 0 0

Q *

Q *
' * *
Q*
SE 0 0 0 0 Q SSE 0 0 0 12799 9228 + 22027
5631 11355

16986 e 39013 0 0 0 62 65 2317 2444

10030 237

10267

12711 SSM 0 0 29 0 0 1997

2026

738 1453

2191 e 4217 S'M 0 5 21 0 . 564 210 800 + 738 692 1430

2230 MSM 0 16 3 804 1120 + 1943 *

0

1943 0 5 13 156 151 140 '* 465

831 0

831 * , 1296 0 0 31 111 1681 1179

3002

299

299* 3301 0 0 9 )68 11326

11503 + 5910 540

6450 * "
17953 NNM 0 0 0 0 129 1919
2048

4372 21008

25380

27428 TOTAL 0 26 94 341 16361 29436

46258

28549 35285

63834

110092
SL2" ER-OL ThBLE 2.1 5 Sheet 4 of 8 PEhK DhILY TOURISTS hND SEhSOHhL VISITORS MITHIH 30 HILKS OF ST LUCIE UNIT 2 1990 hnno)ar Tot el Total Total S ctor 0-I 1-2 2-3 3"4 4-5 5-10
0-10

10"20 20-30

10-30

0"30 0 0 0 0

0 *

0

NHE 0 0 0 0

0 e

Q

0 0 0 0

Q *

Q

EHE 0 0 0 0

0*

Q*
0 0 0 0
Q*

Q e KSE 0 0 0 0

0* Q e 0 0 0 0

Q*

Q

SSE 0 0 0 0 16562 11941

28503

7286 14693 + 21979

50482 0 0 0 80 84 2998

3162

12978 316

13294

16456 SSH 0 0 38 0 0 25&4

2622

955 1880

2835

5457 0 7 27 0 730 271

1035

955 896

1851 + 288&
0 21 0 4 1040 1449 2514 e e Q
2514 7 17 201 195 181

601

1075

1075

1676 0 40 )44 2176 1526

3886 *. 388

388

4274 0 0 1) 217 14654

14882

7648 699

S347

23229 0 0 0 0 167 2484

2651

5658 27183

32841

35492 TOThL 0 35 )22 440 21)71 38088

59856

36943 45667

82610

142466
SL2-ER-OL ThBLK 2.1-5 Sheet 5 of 8 PEhK DhILY TOURISTS hND SEhSONhL VISITORS MITNIH 30 NILKS OF ST LUCIE UNIT 2 2000 hnnular Total Total Total Sector 0-1 1-2 3-4 4-5 5-10
0-10

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0-30 N 0 0

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8968 )8085

27053 + 62136 0 99 103 3690

3892 a 15974 389

16363 + 20255 SSM 0 0 47 P 0 3180

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1176 2313

3489

6716 9 33 0 898 334

1274 a 1176 1103

2279

3553 MSM 0 27 0 4 1280 1784 3095

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3095 0 9 21 247 240 223

740

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2064 0 0 49 177 2678 1877

4781

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28592

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'5 0 0 0 0 205 3057 + 3262 6965 33458 43689 0 150 541 26057 46880
73673

45474 56208 *101682

175355
SL2-ER-OL ThBLE 2.1-5 Sheet 6 of 8 PEhK DhILY TOURISTS hND SEhSONhL VISITORS NITNIN 30 BILES OF ST LUCIS UNIT 2 2010 hnnular Total Total Total Sector 0-1 1-2 2-3 4-5 5-10 0-10
10-20 20-30

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0 *

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3972

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35193 0 0 0 0 252 3762

4014

8572 41182

49754

53768 TOThL 0 54 185 666 32076 57701

90682

55969 69186 *125155 e 215837
SL2- ER-OL ThBLE 2.1-5 Sheet 7 of 8 PEhX DhILT TOURISTS hND SEhSONhL YISITORS MITHIH 30 HILES OP ST LUCIE UNIT 2 2020 hnaular Total Total Total Sector 0-1 1-2 2-3 3-4 4-5 5-10
0-10

10"20 20-30 + 10-30 e 0"30 0 0 0 0 0

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0 * '688 0 13 32 374 364 339

1122

2005 2005

3127 MHM 0 74 268 4057 2843

7242

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723* 7965 0 0 21 405 27327

27753

14261 1303

15564

43317 HHM 0 0 0 0 310 4631 4941

10550 50692

61242

66183 TOThL 0 66 227 820 39478 71025 *111616

68887 85158 *154046

265662
SL2-ER-OL ThBLK 2.1-5 Sheet 8 of 8 r PEhK DhILY TOURISTS hHD SEhSOHhL VISITORS llITNIN 30 NILES OF ST LUCIE UNIT 2 2030 hnnular Total Total Total Sector 0-1 1-2 2-3 3"4 4-5 5"10
0-10

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0-30 0 0 0 0 a Q* Q

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1381 e 2468

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17554 1604

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6083

12986 62391

75377 * . 81460 TOThL 0 81 280 1010 48592 87420 *137383

84795 104814 *189609

326992
SL2-ER-OL TABLE 2. 1-6 Sheet 1 of 4 TRANSIENT POPULATION: ATTENDANCE AT ATTRACTIONS AND EVENTS 1978-2030 Number of Persons 1978 Tots or'vents Annular Time of (of more Peak Sector Location Year ~th n o e da ) ~Dail Haximum 1980 1983 1990 2000 2010 2020 2030 i A. Attractions and Events Mithin 10 Hiles of St Lucie Unit 2 5-10 Indian River January 40000 20000 20948 21422 25688 30428 35168 39908 44600
1. Art on t)~ green NM Festival Hemorial Park, Fort Pierce 5-10 Jensen Beach July 4th 10000 10000 10000 10000 10000 10000 10000 10000

2. Jensen Be~/ SSE Fireworks Causeway 5-10 Fort Pierce Fall- Football 6000 6000 6000 6000 6000 6000 6000 6000 6000

3. Lawnwood Stadium hM (St Luci~ (ounty Schools) 5-10 of October 2000 2095 2142 2569 3043 3517 3991 4460

4. Leif )rikson S Town Day Jensen Beach 5-10 Town'of Harch 5000 2500 2619 2678 3211 3804 4396 4989 5575

5. Outdoor 8 Festival fg Jensen Beach 5-10 St Lucie 10000 7000 7332 7498 8991 10650 12309 13968 15610

6. Sailfisl~ 8 Hay Regatta River Fort Pierce 20000 5700* 20948 21422 25688 30428 35168 39908 44600

7. St Lucjg1County Civic NM 5-10 March 40000 Center 5-10 Fort Pierce January 7900 1500* 1607 1713 1962 2318 2673 3029 3384

8. Sandy Shy~ NM Festival & Fairgrounds 5-10 Jensen Beach June 1500 1571 1607 1927 2282 2638 2993 3345

9. Sea T~gle SSE Match

See Sheet 4 for sources of information.

Haximum seating capacity. Forty thousand attended an Auto Show on a walk-through basis over two days.
+a* 1977 attendance. No festival was held in 1978 ' SL2 ER-OL TABLE 2.1-6 Sheet 2 of 4 TRAHSIENT POPULATIOH: ATTENDANCE AT ATTRACTIONS AND EVENTS 1978-2030 Number of Persons 1978 Total or Events Annular Time of (of more Peak Sector Location Year ~than nna d ) ~hail Haximum 1980 1983 1990 2000 2010 2020 2030 B. Attractions and Events Betueen 10 and 30 Hiles of St Lucia Unit 2
10. Dodgerc~g Sports NNM 20-30 Vero Beach Harch 7405 10000 7541 7712 9248 10000 10000 10000 10000 Complex ll. Jai hi~I of Fort a
MHM 10-20 Fort Pierce Year-Round 3200 4000 3352 3428 4000 4000 '4000 4000 4000 I Pierce
12. Marcj~ County S 10-20 Martin Harch 27000 7559 7917 8096 9709 11500 13292 15083 16857 Fair County Fair-grounds, in Stuart

13. Hartin County 8 10-20 Stuart Fall Football 4500 4500 4500 4500 4500 4500 4500 4500 School Stadium (jQ

14. St County NM 20-30 St Lucia February 20800 8300 8693 8890 10660 12628 14595 16562 18509 FairL~~j~ County Fair-grounds, in Port Pierce

15. Vero Beach Senj~~ High NM 20-30 Vero Beach Fall Pootball '8000 8000 8000 8000 8000 8000 8000 8000 School Stadium

c. Actraccions and Events Betveen 30 and 50 Miles of st Lucie Unit 2

16. Fish Fry, Volun(eg NM 40-50 Grant February 30000 15000 15711 16778 19266 22821 26375 2&931 33450 Fire Department Brevard County

17. Norse 8 40-50 Palm Beach Year-Round 2000 2095 2142 2569 3043 3517 3991 4460 C 1-"4 Fairgrounds

18. Labor Day Rodeo and MSM 30-40 Okeechobee September 12000 10000 10474 10711 12844 15214 17584 19954 22300 Bluegrass Convention (15) City
SL2-ER-OL ThBLE 2.1-6 Sheet 3 of 4 TRhNSIENT POPULATION: hTTENDhNCE hT hTTRhCTIONS hND EVENTS 1978-2030 Humber of Persons 1978 Total for Events hnnul sr Time of (of more Peak Sector Location Year ~than nna a i ~Dail Maximum 1980 19S3 1990 2000 2010 2020 2030 C. htcraccions and Events Betueen 30 snd 50 Miles of St Lucie Unit 2 (Cont'd)
19. Lion Co~~gy S 40-50 Route 441 Year-Round Safari Palm Beach County

20. Offshore Syqy5 Fishing NhM 30-40 Sebastian May"June 500 524 536 642 761 879 998 1150 Tournament Inlet and htlantic Ocean

21. P.G.h. SSE 30-40 Palm Beach Year-Round under construction soooo"soooo soooo soooo soooo soooo I (18) Gardens 22.
23. Pahokee Fireuorks Palm Be~~lg huto SM S 40-50 40-50 Hoover Dike in Pahokee Flam Beach Fairgrounds 'uly 4th Year-Round 3000 1000 3000 1047 3000 1071 3000 1284 3000 1521 3000 1758 3000 1995 3000 2230 huccion
24. Palm Beat) fairgrounds SSE 40-50 Palm Beach Year-Round 8000 8000 8000 8000 8000 8000 8000 8000 1
Speeduay Fairgrounds
25. Palm /~~eh Kennel S 40-50 West Plam January-Hay 5800 6075 6212 7450 8824 10199 11573 12934 Club Beach

26. Sour) gorida WSM 30-40 Palm Beach January" 470752 88000 92171 94257 113027 133883 154739 175595 196240 Fair Fairgrounds February

27. Speckled 30-40 Okeechobee Harch 5000 5237 5356 6422 7607 8792 9977 11150 fgch MSM Festival City

28. West Palm SSE 40-50 Mast Palm Year-Round 6000 6000 6000 6000 6000 6000 6000 6000 6000 huditorium fg~h Beach

29. liest Pal~ B~ach SSE 40-50 Hangonia Park Sepcember- 9000 9000 9000 9000 9000 9000 9000 9000 9000 Jai hlai Palm Beach County January

30. Mesc PalIa Beach SSE 40-50 West Palm 6800 7000 7000 7000 7000 7000 7000 7000 7000 Municipal Stadium (25) Beach
+ hctendance figures are confidential and not available for use in this report. First World Championship Tournament scheduled for 1982. SL2-ER-OL TABLE 2.1-6 Sheet 4 of 4 TRANSIENT POPULATION ATTENDANCE AT ATTRACTIONS AND EVEHTS 1978-2030 SOURCES OF INfORHATIOH (1) Chairman, Art-on-the"Green Festival, Fort Pierce, florida, Letter Dated November 17, 1978 (2) Executive Director, Jensen Beach Chamber of Commerce, Jensen Beach, Florida, Letter Dated November 17, 1978 (3) Haintenance Foreman, St Lucie County School Board, Ft Pierce, Florida, Letter Dated Hovember 28, 1978 (4) Director, Stuart/Hartin County Chamber of Commerce, Stuart, Florida, Letter Dated Hovember 22, 1978 (5) Supervisor of Special Facilities, St Lucie County Civic Center, Ft Pierce, Florida, Letter Dated November 17, 1978 (6) Executive Secretary, Sandy Shoes Festival (1979), Fort Pierce, Florida, Letter Dated November 27, 1978 (7) Office of Eastern Division Hanager, Los Angeles Dodgers Baseball Team, Dodgertoun Sport and Conference Center, Vero Beach, Florida, Letter Dated November 17, 1978 (8) Associate Chief of Security, Jai Alai of fort Pierce, Fort Pierce, Florida, Letter Dated Hovember 17, 1978 (9) fair Secretary, Hartin County Fair Association, Stuart, Florida, Letter Dated November 20, 1978 (10) Athletic Director, Hartin County Nigh School, Stuart, Florida, Letter Dated November 28, 1978 (11) Fair Secretary, St Lucis County Fair, Fort Pierce, Florida, Letter Dated November 20, 1978 (12) f'inance Officer, Indian River County Schools, Vero Beach, Florida, Letter Dated November 27, 1978 (13) Chairman, Fish Fry in Crant, Helbourne, Florida, Personal Communication, December 14, 1978 (14) Horse Complex, Palm Beach County Fairgroundsy West Palm Beach, Florida, Personal Communication, November 21, 1978 (15) Okeechobee Chamber of Commerce, Okeechobee, Florida, Letter Dated November 17, 1978 (16) Office of Public Relations, Lion County Safari, Royal Palm Beach, Florida, Letter Dated November 20, 1978 (17) Chairman, Offshore Sport Fishing, Tournament, Sebastian, Florida, Letter Dated December 13, 1978 (18) Project hanager, PGA Complex, Florida Realty Building Company, West Palm Beach, Florida,. Letter Dated December 11, 1978 (19) Office Nanager, Pshokee Chamber of Commerce, Pahokee, Florida, Letter Dated November 20, 1978 (20) Palm Beach Auto Auction, Palm Beach County Fairgrounds, West Palm Beach, Florida, Personal Communication, December ll, 1978 (21) South Florida Fair, Palm Beach County Fairgrounds, West Palm Beach, Florida, Personal Communications, November 21 snd 27, 1978 (22) Palm Beach Kennel Club - Greyhound Racing, West Palm Beach, florida, Letter Dated November 21, 1978 (23) West Palm Beach Auditorium, Meat Palm Beach, F)orida, Letter Dated November 22, 1978 (24) Office of public Relations, 'West palm Beach Jai Alai, Meet palm Beach, Florida, Letter'ated November 21, 1978 (25) Spring Training Coordinator, Atlanta Braves, Meat Palm Beach Municipal Stadium, West Palm Beach, Florida, Letter Dated Hovember 20, 1978 SL2-ER-OL TABLE 2.1-7 TRANSIENT POPULATION: HAJOR INDUSTRIAL EHPLOYERS AND COLLEGES 1978-2030 'e 1978 Ann<<l ar Total Peak Daxly Sector Location 0~ivv eet ~tle ~ t 3900 l 903 3990 2000 20I0 2020 2030 A. Ha or Ind<<strial Em lovers
l. Gr<<mman Aerospace (I) 8 10-20 Hartin County Airport, Stuart 731 700 700 700 700 700 700 700 700

2. Piper Aircraft NW 10-20 Vero Beach H<<nicipal Airport 2887 2000 2000 2000 2000 2000 2000 2000 2000 Indian River County

3. Pratt 6 Whitnev S 30-40 Ro<<te 770, South of Route 710 7261 6094 6094 6094 6094 6094 6094 6094 6094 Government Palm Beach County Prod9$ cts Division Total Peak Daily Enrollment Enrollment

4. Florida In@ jt2$ te of SSE 5-10 Jensen Beach Campus 900 1050 1200 1200 1200 1200 1200 1200 Technology Hartin County

5. Indian River NW 5-10 Fort Pierce Camp<>cie County 8 10-20 Stuart Campus, Hartin 1280 171 . 234 276 322 398 492 609 753 County WSW 30-40 Okeechobee Campus, Okeechobee 320 43 59 69 80 100 123 152 188 County HNW 20-30 Vero Beach Camp<<s, Indian 3200 428 585 691 806 997 1233 1526 1888 River Countv (1) Personal Comm9$ nication, Personnel Department, Gr$ 9mman Aerospace, November 30, 1978.
(2) Personal Comm9$ nication, Personnel Department, Piper Aircraft Corp, December 4, 1978. (3) Personal Comm<<nication, Employment Office, Pratt & Whitney Aircraft, November 30, 1978. (4) Personal Comml$ nication, Student Activities Office, Florida Institute of Technology, Jensen Beach Campus, November 27, 1978. (5) Personal Comm9$ nication, Office of the Vice President, Indian River Comm<<nity College, Fort Pierce Campus, November 28, 1978. SL2-ERR>L TABLE 2.1-8 TRANSIENT POPULATION: AVERAGE DAILY PASSENGERS ON HAJOR ROADS MITNIN 30 HILES OF ST LUCIE UNIT 2 1978-2030 Ni hwa s snd State Roads Mithin 10 Hiles of St Lucie Unit 2 Estimated Avera e Dail Number of Passen ers (2) Route Station Number 1978 1980 1983 1990 2000 2010 2020 2030 SR AIA St Lucie 114 2,802 2>935 3,134 3,599 4,259 4,926 5,590 6,248 (North Beach Causeway) SR 605 St Lucia 268 2,505 2,624 2,802 3,217 3,808 4,404 4,997 5,586 US 1 St Lucie 121 14,357 15 ~ 038 16>058 18>440 21 ~ 823 25 ~ 240 28>642 32>016 SR 607A St Lucie 199 6,525 6,834 7,298 8,381 9,918 11,471 13,017 14,551 SR 68 St Lucie 151 8,271 8,663 9,251 10,623 12,572 14,540 16,501 18,444 SR 611 St Lucie 274 2,172 2,275 2,429 2,790 3,301 3,81& 4,333 4,84>4 SR 70 St Lucie 106 5,910 6,190 6,610 7,591 8,983 10,390 11,790 13,179 I-91/ St Lucie Southbound 15, 151 15,869 16,946 19,460 23>030 26 ~ 635 30 226 33 ~ 787 Florida's Turnpike SR 709 St Lucie 279 990 1 037 1 ~ 107 1 272 I> 505 1 740 1 975 2 ~ 208 I-91/ St Lucie Northbound 25,541 26,752 28,568 32,805 38,822 44,901 50,954 56,956 Florida's Turnpike US 1 Hartin 113 20,922 21,911 23,399 26,862 31,778 36,767 41,731 46,647 (Roosevelt Bridge/Northbound) SR AIA Hartin 144 8,516 8,920 9,525 10,938 12,944 '14,971 16,989 18,991 Ni hwa s Mithin 30 Hiles of St Lucie Unit 2 I-95 Indian River Southbound 9,971 10 444 ll 153 ~ 12 ~ 807 15 ~ 156 17 ~ 529 19 892 22 ~ 235 I-91/ Okeechobee Southbound 15,151 15,869 16,946 19,460 23,030 26,635 30,226 33,787 Florida's Turnpike I-95/ Palm Beach Northbound 26,527 27,782 29,66& 34,059 40,292 46,618 52,911 59,144 Florida's Turnpike (1) State of Florida, Dept of Transportation, Bureau of Planning assigns code numbers to each station where average daily traffic (ADT) counts are taken in each county. (2) See Methodology, Section 2.1.3.8.2. SL2-ER-OL TABLE 2.1-9 TRANSIENT POPULATION: AVERAGE DAILY PASSENGERS BY RAIL AND AIR MITNIN 50 HILES OF ST LUCIE UNIT 2 1978-2030 ~Ca t Location 1978 1980 1983 1990 2000 2010 2020 2030
h. Rail Amtrak - S~~)oard Sebring - West Palm Beach 389( ) 195(3) 206 240 289 338 387 436 Coast Line B. Air

2. Mesc Palm Beach Palm Beach Meat Palm Beach 40878( ) 5,387 7,086 12,258 150163 18,068 20,973 23,878 International Airport (1) Peak daily capacity (that is, all seats available on all six trains on the line on one day) was 2,474 in 1978 (August).
Personal Communication, Route Analyst, Eastern Routes, Harketing Research, Amtrak, Mashington, DC, November 22, 1978. (2) See Hethodology, Section 2.1.3.8. (3) In Hay, 1979, Congress accepted a Department of Transportation plan to reduce service to Florida from three trains each dsy to one train. It is expected that ridership will be reduced to half the 1978 levels with this change in service. Sources'Personal Communication, Hanager - Eastern Routes, Harketing Research, Amtrak, Washington, DC, Hay 22, 1979-(4) Data include implsnements and deplanements. Personal Communication, Director of Planning, Palm Beach International Airport, Hest Palm Beach, Florida, November 30, 1978. SL2-ER-OL TABLE 2.1-10 TRANSIENT POPULATION: AVERAGE DAILY PASSENGERS ON MATERWAYS 'MITNIN 30 HILES OF ST LUCIE 2 1978-2030 ~Co nc Location 1978 1980 1983 1990 2000 2010 2020 2030 A. Materwa s Mithin 30 Hiles of St Lucie 2
l. Intracoastal Materway( 1) Jacksonville - Hiami via Indian River 1~490 1 ~ 561 1~667 1 ~ 914 2 ~ 267 2 ~ 620 2~973 3 ~ 323

2. Fort Pierce Harbor( St Lucie Fort Pierce 22 23 25 28 33 39 44 49

3. St Luc ie Canal( ) Hartin Lake Okeechobee/Port Hayaca - Stuart 108 113 121 139 164 190 216 241 B. Brid es Mithin 10 Hiles of St Lucie 2

4. Jensen Beach Bridge(3) Hartin Indian River at Jensen Beach 46 48 51 59 70 81 92 103

5. Roosevelt Bridge(4) Hartin St Lucie River in Stuart 89 93 100 114 135 157 178 198

6. St Luc ie Br idge ( Hartin St Lucie River, Stuart-Seawall's Point 62 65 69 80 94 109 124 138

7. Stuart Causeway Hartin Indian River, Sewall's Point - Nutchinson Island 60 63 67 77 91 106 120 134 (Indian River Bridge)
(1) Army Corps of Engineers, Materborne of the United States, Part Jacksonville District US Commerce 1, 1976 pp 135, 137 (2) Personal Communication, Lockmaster, St Lucie Lock & Dam, Stuart, Florida, September 14 and October 10, 1978 (3) Personal Communication, Bridgetender, Jensen Beach Bridge, Jensen Beach, Florida, September 14 and November 10, 1978 (4) Personal Communication, Engineering Department, Hartin County Department of Transportation, September 14, 1978 (5) Personal Communication, Bridgetender, St Lucie Bridge, Stuart, Florida, September 14, 1978 (6) Personal Communication, Bridgetender, Stuart Causeway, Sewall's Point, Florida, September 14, 1978 SL2-ER"OL TABLE 2.1-11 LOCATION BY ANNULAR SECTOR OF PARANETERS NEAREST TO ST. LUCIE UHIT 2 NOVEMBER 1978ia'b>c) CATEGORY N HNE NE EHE E ESE SE SSE S SSW SW 'MSM W MHW NM NHM hilk Cows 0 0 0 0 0 0 0 L L L L L 14.0/ L L L 260 hilk Coats 0 0 0 0 0 0 0 L L 5.95/ 2.2/ L L L L L 204 220 heat Animal 0 0 0 0 0 0 0 L L 5. I/ S.2/ 3.2/ 4.5/ L L 205 209 270 290 Gardens 0 0 0 0 0 0 0 L L 2.3/ 2.0/ 1.9/ 3.5/ 3.0/ L L 208 225 249 273 296 is>'go'Vegetable Residences 0 0 0 0 0 0 0 5.0/ 4.1 2.3/ 2.0/ 1.9/ 2.1/ 2.8/ 4.8/ 5.0/ 202 226 247 270 292 311 340
l. 0 ~ Ocean Areas

2. L ~ Land Areas: no numerical entry indicates that a ground survey of an established 22 I/2 degree radial sector showed no evidence of any activity.

3. '4.0/260 ~ 14.0 miles from the center of the reactor in the 260 direction, measured clockwise from north Source: a) Letter L-76-416 to 0 L Ziemann, Chief Operating Reactors Branch 02, Division of Operating Reactors, USNRC, Washington, DC, from R E Uhrig, Vice President of Florida Power & Light on December 7, 1976.
b) Letter FL0-1375, to L Tsakiris, Project Manager of Ebasco Services, from C S Kent, Project Nanager, Florida Power and Light, Narch 14, 1979. c) Florida Power & Light, St Lucie Unit I, Docket Ho 50-335, Annual Radiological Environmental Monitoring Report, 1978. SL2-ER-OL TABLE 2.1-12 Sheet 1 of 2 LAND USES AND LAND COVER llITNIN FIVE HILES OF ST LUCIE UNIT 2 Level I Land Use Classification Acreage Percent of Total Level II Land Use Acreage Level III Land Use Acreage Classification Percent of Total Classification Percent of Total 1 ~ URBAN OR BUILT UP LAND 3 ~ 541 7 0 11. Residential 2,300 4.6 ill. Single-family Resi- - 2,220 4.5 dances 112. Multiple-family 20'0 Residences 116. Transient Lodgings .1
12. Commercial and Services 28 122. Retail, Commercial 22 Services 123. Institutional Ser-vices

13. Industrial 14 ~
131. Light Industrial 14 *
14. Transportation, Communi- 964 2.0 141. Highway, Principal 210 .4 cations, and Utilities Road 142. Railroad 50 .1 143. St Lucie 1 & 2 300 .6 Facilities 144. Transmission Lines 386 .8 145. Utility Storage 18 *

17. Other Urban or Built-up 235 .5 171. Cemetery 10

Land 172. Undeveloped Land 37 173. Recreation Facilities 188

2. ACR ICULTURAL IAND 541 1. 1 21. Cropland and Pasture 449 .9 212. Citrus Groves 449 .9

22. Other Agricultural Land 92 .2 221. Nurseries 222. Old Field 83

4. FOREST/HARSH COVER 10,653 21.2 41. Coniferous Forest/ 7,910 15.6 410. Pine Flatwood Forest/ 5, 594 Freshwater Harsh Freshwater Harsh 411. Freshwater Harsh 2,316 4.6

42. Other Forested Metland 2,743 5.5 421. Hangrove 2, 743 5.5.
SL2-ER-OL TABLE 2.1-12 Sheet 2 of 2 Level 1 Land Use Acreage Level Il Land Use Acreage Level Ill Land Use Acreage Classification Percent of Total Classification Percent of Total Classification Percent of Total
5. SATKR 34,849 69.3 51. Freshuater 1,243 2.5 510. Streams and Canals 113 ~ 2 511. Lakes 1,130 2.3

52. Fresh/Salt Mater 10,656 21.2 520. Estuary 10,656 21.2

55. Salt Mater 22,950 45. 6 550. Open llarine Mater 22,950 45.6

7. BARREh LAhD 682 1.4 71. Natural Barren Land 97 .2 710. Beaches

74. Handmade Barren Land 585 1.2 740. Transitional Areas 390 .8 741 'xtractive 195 50,266 1GOX 50,266 100X 50,266 100X
+ The forest cover is to a great extent concentrated in a transitional area uhich is primarily marshy but includes relatively dry sites. In addition, the Florida land use/cover classification system considers mangroves as a rype of vetland - harduood forest. To account for these considerations, the USCS categories of Forest and Metlunds uere combined.
Less than .1X
SL2-ER-OL TABLE 2.1-13 TOTAL BEEF CATTLE AHD BEEF SLAUGHTER MITHIH 0-50 HILES OF SITE 3 ~Count Total No. of Head Total Sian hter/Yr k~lv (l> ) Brevard 2,250 675 231.5 Glades 3>000 $ 00 308.6 Highlands 1,680 504 172.8 Indian River 15,000 4,500 1,543.1 Hartin 35,000 10,500 3,600.7 Okeechobee 36,400 10,920 3,744.7 Oaceola* Palm beach 17,600 5,280 1,810.6 St. Lucie 26,000 7,800 2,674.8 136,930 41,079 14,086.8
Ho beef production assumed since that portion of county within 0-50 miles of site is wetland, according to USGS maps.
a) 1977 Florida and USDA official estimates from, 'Florida Agricultural Statistics-Livestock Summary 1977," Florida Crop and Livestock Reporting Service, 1222 Woodward St., Orlando, Florida 32803. b) Only those portions of county within 0-50 mile radius of site considered, excluding wetland areas. c) Estimated from county totals assuming equal distribution of cattle throughout county. SL2-ER-OL TABLE 2. 1-14 DAIRY HERDS AND MILK PRODUCTION WITHIN 50 MILES OF ST LUCIE UNIT 2 Heifers Heifers 1977 Annual Number of Over Under No. of Milk Production ~Count Dairies 500 lb 500 lb Milk Cows (1000 lb) Brevard 85 75 300 3,000 Highlands 145 140 720 7,600 Indian River 445 310 1,830 15,900 Martin 800 710 2,710 25,400 Okeechobee 20 7,260 6,440 22,300 226 >000 Palm Beach 430 590 4,140 33,900 St. Lucie 595 420 2,450 21,200. Total 41 9,760 8,685 34,450 333,000 (a) From "Dairy Summary 1977 - Florida Agricultural Statistics," Florida Crop and Livestock Reporting Service, 1222 Moodward Street, Orlando, Florida 32803. (b) Estimated from county totals for 0-50 mile radius, assuming equal distribution of dairies throughout county. SL2-ER-OL TABLE 2.1-15 MILK UTILIZATION FROM DAIRY HERDS-WITHIN 50 MILES OF ST. LUCIE UNIT 2
1. Average Annual Milk Production per Cow ~ 9,666 lbs ~ 4,385 kgs

2. Milk Fat (average) ~ 3.5X

3. 1977 Annual Milk Production ~ 330.0 x 10 6 lbs ~ 151.0 x 10 6 kgs

4. Milk Utilization 6
(a) Used on Farm ~ 3.1 x 10 lbs ~ 1.4 x 10 kgs 6
1) For milk, cream, butter 2.0 x 10 lbs ~ 0.9 x 10 kgs 6

2) Fed to calves ~ 1.1 x 10 lbs ~ 0.5 x 10 kgs (b) Milk Sold Directly to Consumers ~ 5.1 x 10 lbs ~ 2.3 x 10 kgs (c) Milk Sold to Plants for Manufacturing Dairy Products. ~ 324.8 x 10 lbs ~ 147.3 x 10 kgs

1) For frozen products-ice cream, ice milk, sherbert P
~ 7.6 x 10 gal
2) For cottage cheese -curd,
~ ~ 6 creamed 8.9 x 10 lbs 4.0 x 10 kgs
3) For skim milk and butter milk products. 23.2 x 10 lbs ~ 10.5 x 10 kgs

4) For whole milk products ~ 61.0 x 10 lbs ~ 27.7 x 10 kgs (a) Estimated 1977 data from "Florida Agricultural Statistics - Dairy Summary, 1977," prepared by Florida Crop and Livestock Reporting Service, 1222 Woodward Street, Orlando, Florida 32803 (July 1978)
(b) Estimated from county data. Only accounts for those portions of county within 0-50 mile radius, assuming equal distribution of dairy herds. SL2-ER-OL TABLE 2.1-16 EGG PRODUCTION WITHIN 50 MILES OF ST LUCIE UNIT 2 Number of La ers Number of E s/Da Brevard 4>500 2,925 ~ Glades 750 488 Highlands 750 488 Indian River 25,000 16,250 Martin 255000 16,250 Okeechobee 16,250 10,563 Palm Beach 11,950 7,768 St. Lucie 25,000 16,250 (a) 1977 data from "Poul.try Summary 1977 - Florida Agricultural Statistics", Florida Crop and Livestock Reporting Service, 1222 Woodward Street, Orlando, Florida 32803. (b) Accounts only for those portions of county within 50 miles of plant site; assumes equal distribution of layers throughout county. SL2 ER-OL TABLE 2.1 17 Sheet 1 of 2 FLORIDA COMMERCIAL VEGETABLES PRODUCTION IN 0-50 MILE RADIUS STUDY AREA Principal Production Acres Harvested ~Count ~Seoies Center 1976-77 1973-74 Brevard Tomatoes Fort Pierce 126 Watermelon 36 Glades Tomatoes Pahokee 60 101 Highlands Corn" (2) Potatoes (2) s Indian River Tomatoes Fort Pierce 700 Watermelon 200 Okeechobee Tomatoes Pahokee 273 754 Waterme ion 228 650 Martin Potatoes Stuart 7503 (2) Tomatoes (1) 500 Watermelon (1) 200 Palm Beach Beans Pompano 6,070 71816 Cabbage Pahokee (1) 404 Celery (1) 3,476 Corn (1) 16,280 Cucumbers 552 428 Eggplant 340 328 Escarole (2) 1,900 Lettuce (2) 2 $ 272 Peppers 1,020 880 Potatoes (1) 480 Radishes (2) 5,320 Spinach (2) 520 Squash 560 540 " Tomatoes 668 565 St Lucie Tomatoes Fort Pierce 745 875 Watermelon (1) 200 8132-ER-OL TABLE 2.1-17 Sheet 2 of 2 Principal Production Acres Harvested ~Count ~3eo ice Center 3976"77 1973-74 Other Counties (c) Snap Beans 1,270 1,190 Cabbage 28900 ',340 Ce lery (2) (2) Sweet Corn (2) (2) Cucumber 2,550 2,190 Eggplant 680 540 Green Pe~mrs 870 1,660 Potatoes 3,650 4,950 Squash 3,000 2,180 Strawberries 300 370 Tomatoes 870 1,165 Watermelon 4,000 800 (1) Included with other counties (2) Figures not available (3) Winter harvest only From "Vegetable Summary 1977 Florida Agricultural Statistics", Florida Crop and Livestock Reporting Service, Orlando, Florida 32803. (b) Estimated from county data. Accounts only for those portions of county within 0-50 miles of site. Assumes equal distribu-tion of vegetable crops within county. Counties throughout the state whose production was not large enough to warrant special statistics by individual county. SL2-ER-OL TABLE 2.1-18 FLORIDA COMMERCIAL VEGETABLE ACREAGE AN PRODUCTION - SOUTHEAST COUNTIES 1976 77 a) Acreage Yield Per SE Production State Produc-pro Planted Harvested Acre 1,000 Units tion 1,000 Units Snap Beans 34,550 24,600 125 3,073 3$ 680 Sweet Corn 17,600 9,500 210 1,995 11,990 Cucumbers 1$ 850 1>700 279 474 3,802 Eggplant 1,350 1,175 760 893 1,367 Green Peppers 3,750 2,650 478 15268 6,720 Potatoes (Winter) 7,900 7,700 184 1,434 1,602 Squash 5,600 5,300 155 822 1,893 Strawberries 100 100 1,200 120 2,127 Tomatoes 18,900 11,580 5,941 24,210 (a) From "Vegetable Summary 1977-Florida Agricultural Statistics", Reporting Service, 1222 Woodward Street, Orlando, Florida 32803 SL2-ER-OL TABLE 2.1-19 FLORIDA COHHERCIAL VEGETABLE PRODUCTION CROP YEAR 1976-77ia) Het Mc. Acreage Average Yield per Acre Production ~CC nsit Unit lb/Unit Planted Harvested ~k i 000 Units Beans Bushel 30 39,600 29,500 125 3,750 I, 701 3>680 Cabbage Crate 50 17,100 16,300 453 22,650 10,274 7,385 Celery Crate 60 10,700 10,100 578 34,680 15,731 5,833 Sueec Corn Crace 42 63,300 50,300 238 9,996 4,534 11,990 Cucumbers Bushel 48 16,100 15,000 253 12,144 5,509 3,802 Eggplant Bushel 33 2,250 1,950 701 23,133 10,493 1,367 Escarole Crate 25 6,900 6,000 513 12,825 5,817 F 080 Lettuce 100 11,700 9,500 151 15, 100 6,849 1,430 Peppers Bushel 25 21,100 16,800 400 10,000 4,536 6,720 Potatoes Sack 100 30,500 30,100 206 20>600 9,344 6,207 Radishes Carton 11.5 31>000 270300 291 3, 347 1,578 7,933 Squash Bushel 42 12,600 12>000 158 6,636 3>010 1,893 Scrauberries Flat 10.25 1,500 1,500 1,418 14,535 6,593 2,127 Toaatoes Carton 30 43,200 34,000 751 22>530 10,220 24,210 Matenne lens Cuc. 100 65,000 51,000 175 17,500 7,938 8,925 (s) Frcxa "Vegetable Sua>s>ary 1977 - Florida Agricultural Statistics", Florida Crop and Livestock Reporting Service, 1222 Mooduard Street, Orlando, 'Florida 31803 SL2-ER-OL TABLE 2'.1-20 Sheet 1 of 2 FLORIDA CITRUS ACREAGE AND PRODUCTION 1976-77 Est e Unit Prod. Harvest Mt, 1,000 Total ~Count Fzuit Unit lb Boxes ~Actee e Bzevard (b) 1 All Oranges Box 90 807 2,517 Ear ly- 6 Mids Box 90 507 1,351 Valencias Box 90 300 1,135 All Grapefruit Box 85 203 636 Seedy Box 85 9 53 Seedless Box 85 194 527 Specialty Fruit Box 90 39 201 All Citzus Box 1,049 3,354 Glades( ) All Oranges 1 Box 90 33 96 Early 6 Mids Box 90 24 59 Valencias Box 90 9 37 All Grapefruit Box 85 2 5 Seedy Box 85 0 0 Seedless Box 85 2 5 Specialty Fruit Box 90 1 12 All Citrus Box 36 113 1 Highlands All Oranges Box 90 265 847 Early 6 Mids Box 90 98 225 Valencias Box 90 166 603 All Grapefruit Box 85 71 143 Seedy Box 85 24 57 Seedless Box 85 46 79 Specialty Fruit Box 90 25 131 All Citrus Box 361 1,121 Indian River All Oranges Box 90 5,120 22,947 Early & Mids Box 90 2,937 10,972 Valencias Box 90 2,183 11,572 All Gzapef'zuit Box 85 8,537 30,477 Seedy Box 85 42 350 Seedless Box 85 8,495 28,182 Specialty Fruit Box 90 427 2,782 All Citrus Box 90 14,084 56,206 'Okeechobee (b) All Oranges Box 90 482 1,872 Early 6 Mids Box 90 284 864 Valencias Box 90 198 999 All Grapefruit Box 85 170 636 Seedy Box 85 1 3 Seedless Box 85 169 632 Specialty Fruit Box 90 31 198 All Citrus Box 683 370 SL2-ER-OL TABLE 2.1-20 Sheet 2 of 2 Est. Unit Prod. Harvest Wt, 1,000 Total ~Count Fruit Unit lb Boxes ~Acrea e Martin All Oranges Box 90 6,297 29,849 Early & Mids Box 90 3>078 11,678 Valencias Box 90 3,219 17,580 All Grapefruit Box 85 1,901 5,682 Seedy Box 85 15 213 Seedless Box 85 1,886 5,340 Specialty Fruit Box 90 288 4,733 All Citrus Box 8>486 40,264 Palm Beach (b) All Oranges 1 Box 90 1,080 4,126 Early & Mids Box 90 726 2,390 Valencias Box 90, 354 1,734 All Grapefruit Box 85 603 1,628 Seedy Box 85 15 119 Seedless Box 85 588 1,510 Specialty Fruit Box 90 229 1>912 All Citrus Box .1,912 7,669 St Lucie All Oranges 1 Box 90 8,984 36>619 Early & Mids Box 90 4,668 14>997 Valencias Box 90 4,316 21,009 All Grapefruit Box 85 9,306 30,050 Seedy Box 85 39 372 'eedless Box 85 9,267 27,746 Specialty Fruit Box 90 1,072 7,243 All Citrus Box 19,362 73,912 State Total All,Oranges 1 Box 90 186,800 628,567 Early & Mids Box 90 115,000 318,832 Valencias Box 90 71,800 298,236 All'rapefruit Box 85 51,500 137,909 Seedy Box 85 9,100 23,296 Seedless Box 85 42,400 107,944 Specialty Box 90 13,830 85,893 All Citrus Box 252,130 852,369
1) Includes unidentified variety acreage

2) Includes lemons, limes, tangelos and tangerines (a) From "Citrus Summary 1977 - Florida Agricultural Statistics",
Florida Crop and Livestock Reporting Service, 1222 Woodward Street, Orlando, Florida 32803 (b) Estimated from county citrus data for 0-50 mile radius assuming equal distribution of citrus throughout county. SL2-ER-OL TABLE 2.1-21 SUGARCANE PRODUCTION WITHIN 50 MILES OF ST LUCIE UNIT 2-Acres Harvested Yield Per Acre (tons) Production (tons) ~Count 1976 1977 1976 1977 1976 1977 Glades, 1,120 1,120 33.2 29.5 37,170 33,040 Martin 3,000 3,000 29.0 28.0 87,000 84,000 Palm Beach 137,000 104,000 32.4 29.8 3,378,000 3,093,000 State Total 286,000 285,000 32.6 29.8 9,324,000 8,493,000 (a) From "Field Crops Summary 1977 Florida Agricultural Statistics", Florida Crop and Livestock Reporting Service', 1222 Woodward Street, Orlando, Florida 32803. SL2 ER-OL TABLE 2.1-22 Sheet 1 of 5 FLORIDA MARINE LANDINGS: FOOD FISH, SHRI ND SHELLFISH MARINE LANDINGS BY COUNTY, 1976. Weight Weight ~Count Fish ~(k ) Shellfish, et al ~(k ) Brevard Amberj ack 6,804 Clams 22,928 Ange 1f ish 1,242 Crab, Blue (Hard) 715,338 Blue Runner 526 Crab, Blue (Soft) 107 Bluefish 70,760 Crab, Stone 1,378 Bonito 1,437 Lobster, Spiny 1,558 Catfish, Fresh>>Water 710 Oysters 11,185 Catfish, Sea 1,374 Scallops 193,460 Cigar fish 9 Shrimp 237,673 Cobia 642 Squid 1,275 Crevalle (Jacks) 3,206 Total Shellfish, Croaker 865 et al 1s184k902 Dolphin 3,081 Drum, Black 5,369 Drum, Red 10,293 Flounder 6,031 Goatfish 5,107 Grouper and Scamp 49,031 Grunts 1,569 Jewfish 6,752 King Mackerel 269,194 King Whiting 61,418 Menhaden 85,278 Mullet, Black 283,482 Mullet, Silver 57,654 Permit 1,090 Pigfish 1,393 Pompano 41,118 Sand Perch (Mojarra) 803 Scup 762 Sea Bass 2,356 Sea Trout 46,001 Sharks 1,179 Sheepshead 24,232 Snapper 49,198 Spanish Mackerel )95,972 Spot. 34,031 Swordfish 37,486 Tenpounder 159 Tile fish 9,091 Trigger Fish 1,402 Tripletail 406 Wahoo 405 Warsaw 3,797 Unclassified for Food 17,948 SL2 ER-OL TABLE 2.1-22 Sheet 2 of 5 Weight Weight ~Count Fish ~(h ) Shellfish, et al ~(h ) Unclassified for Miscel,laneous 29,778 Total Fish 1,430,449 India n River j Amber ack 321 Clams, Hard 2,922 Angelfish 101 Crab, Blue (Hard) 4,137 Blue Runner 1,165 Lobster, Spiny 258 Bluefish 36,743 Oysters 452 Bonito 306 Total Shellfish, Catfish, Sea '60 et al 7,769 Cobia 1,482 Creville (Jack) 981 Croaker 15 Dolphin 1,005 Drum, Black 464 Drum, Red 2,805 Flounder 162 Goatfish 86 Grouper and Scamp 16,487 Jewfish 1,083 King Mackerel 374,212 King Whiting 3,043 Menhaden 373,970 Mullet, Black 105,069 . Mullet, Silver 3,402 Permit 275 Pigfish 319 Pompano 49,539 Sea Bass ',082 Sea Trout 27,850 Sheepshead 607 Snapper 28,589 Spanish Mackerel 79,510 Spot 77,787 Tilefish 5,582 Trigger Fish 236 Tripletail 88 Wahoo 49 Unclassified for Food 13,416 Total fish 1,209, 890 Martin Amberj ack 2,215 Lobster, Spiny 885 Ange lfish 327 Total SheLlfish, 885 Blue Runner 14,206 et al Bluefish 237,057 Bonito 47 Catfish, Fresh"Water 503 Catfish, Sea 5,644 SL2-ER-OL TABLE 2.1-22 Sheet 3 of 5 Weight Weight ~Count Fish ~(k ) Shellfish, et al ~(k ) Martin Cigarfish 546 (Cont'd) Cobia 391 Crevalle (Jack) 15,742 Croaker 20,513 Dolphin 129 Drum, Black 15,965 Drum, Red 580 Eel 14 Flounder 665 Goatfish 35,648 Grouper and Scamp 2,597 Grunts 1,178 Herring, Thread 26,095 Hogfish 20 Jewfish 7,161 King Mackerel 43,413 King Whiting 10,783 Menhaden 7,636 Mullet, Black 102,281 Mullet, Silver 6,660 Permit 521 .Pigfish 290 Pompano 37,419 Sand Perch 47,342 Scup 10 Sea Bass 532 Sea Trout 7,549 Shark 1,393 Sheepshead 45,711 Snapper 5,948 Spanish Mackerel 1,44'1,118 Spanish Sardines: 7,27$ Spot 16,477 Swordfish 3,037 Tilapia (Nile Perch) 136 Tilefish 1,344 Trigger Fish 87 Tripletail 604 Warsaw 38 Unclassified for Food 12,699 Unclassified for Miscellaneous 51,165 Total Fish 2,238,715 Palm Beach Amberjack 1,464 Crab, Blue (Hard) 953 Blue Runner 2,300 Lobster, Spiny 16,986 Bluefish 50,612 Total Shellfish, Bonito 295 et al 17,939 SL2-ER-OL TABLE 2.1-22 Sheet 4 of 5 Weight Weight ~Count Fish ~(k ) Shellfish, et al ~(k ) Palm Beach Catfish, Fresh-Water 81 (Cont'd) Catfish, Sea 78 Cigarfish 23 Cobia 249 Crevalle (Jack) 199 Croakes 560 Dolphin 854 Drum, Black 10,229 Drum, Red 726 Flounder 6 Goatfish 1,037 Grouper and Scamp 3,074 Grunt 363 Hogfish Jewfish ll 35 King Mackerel 340,458 King Whiting 4,635 Mullet, Black 3,834 Mullet, Silver 1,316 Permit 106 Pigfish 11 Pompano 3,187 Sand Perch 4,458 Scup 20 Sea Bass 5 Sea Trout 477 Shark 81 Sheepshead 4,465 Snapper 23,792 Spanish Mackerel 933,340 Spot 2 337 Tilefish 507 Tripletail 24 Wahoo 434 Warsaw 34 Unclassified for Food 5,433 Unclassified for Miscellaneous 77 Total Fish 1,401,226 St Lucie j Amber ack 15,895 Crab, Blue (Hard) 1,633 Angelfish 489 Lobster, Spiny 3,110 Barracuda 998 Total Shellfish, Blue Runner 10,795 et al 4,743 Bluefish 125,705 Bonito 6,592 Cobia 2,294 Crevalle (Jack) 4,132 SL2-ER-OL TABLE 2.1-22 Sheet 5 of 5 Weight Weight ~Ceeea Fish ~(k > Shellfish, ea al ~(k ) St Lucie Croaker 1,067 (Cont'd) Dolphin 6,032 Drum, Black 4,534 Drum, Red 1,227 Flounder . 1,167 Goatfish 599 Grouper and Scamp 32,929 Grunts 52 Hogfish 12 Jewfish 2,642 King Mackerel 1,093,989 King Whiting 2,744 Menhaden 16,815 Mullet, Black 63,329 Mullet, Silver 18,629 Permit 1,220 Pigfish 336 Pompano 44,037 Sand Perch 3,843 Scup 341 Sea Bass 694 Sea Trout 13,866 .Shad 66 'Shark 72 Shee pshead 7 j 322 Snapper 24,859 Spanish Mackerel 1,636,766 Spot 31,125 Swordfish 31701 Tenpounder 48,932 Tilefish 770 Tripletail 420 Wahoo 937 Warsaw 1,111 Unclassified for Food 22,497 Unclassified for Mis eel lane ous 323 Total Fish 3,255,905 (a) From "Summary of Florida Commercial Marine Landings, 1976", Florida Department of Natural Resources, Division of Marine Resources, Tallahassee, Florida. SL2-E R-OL TABLE 2.1-23 COMMERCIAL MARINE LANDINGS OF COUNTIES WITHIN 0-50 MILE RADIUS (10 k ) ~Count 1976 1975 Percent Chan e Brevard Fish 11430 5 1,571.1 - 8.9 Shellfish 1, 184. 9 1,854.1 -36.1 Total 2,615.4 3,425.2 -23.6 Indian River Fish 1,209.9 1,155.5 + 4.7 Shellfish 7.8 27.7 -71.8 Total 1,217.7 1,183.2 + 2.9 St Lucie Fish 3,255.9 2,159.2 +50.8 Shellfish 4.7 7.2 -34. 7 Total 3,260.6 2,166.4 +50.5 Martin Fish 2,238.7 1,380.7 +62.1 Shellfish 0.9 1.3 -31.8 Total 2,239.6 1,382.0 +62.1 Palm Beach( Fish 1,401.2 873.2 +60.5 Shellfish 17.9 36.2 -50.5 Total 1,419.1 909.4 +56.0 Grand Total 10,752.4 9,066.2 +18.6 Fish 9,536.2 7,139.7 +33.6 She 1 1f ish 1,216.2 1,926.5 -36.9 (a) From "Summary of Florida Commercial Marine Landings, 1976", Florida Department of Natural Resources, Division of Marine Resources,'allahassee, Florida. SL2-ER-OL TABLE 2.1-24
SUMMARY

OF MARINE LANDINGS BY COUNTY 1976 Shellfish Food Fish Non-Food Fish (excluding Shrimp) Shrimp Total C~oun o Wei ht (k ) Wei ht (k ) Wei ht (k ) Wei ht (k )
Breve rd 1, 147, 852 282,597 947,229 237,673 2,615,351 Indian River 835,920 373,970 7,769 1,217;659.
Martin 221,863 16,853 885 239,601 Palm Beach 1,401,123 103 . 17,939 1,419,165 St Lucie 3,239,018 16,887 4,743 3,260,648 Total 6,845,776 690,410 978,565 237,673 8,752,424 (a) From "Summary of Florida Commercial Marine Landings, 1976", Florida Department of Natural Resources, Division of Marine Resources, Tallahassee, Florida.
SL2-ER-OL TABLE 2.1-25 J.W. CORBETT WILDLIFE MANAGEMENT AREA HUNTING DATA (a)
Species Number Taken Number Taken Common Name Se t 9, 1977 - Jan 7 1978 Jan 8 1978 Mar 26 1978 Deer -71 86 Dove 53 468 Duck 15 Hog 197 175 Quail 658 108569 Rabbit 82 Raccoon 13 Snipe 226 661 Squirrel 50 43 Turkey '3 (a) From data provided by B. Lusander, J.W. Corbett Wildlife Management District, January, 1979.
SL2-ERAL TABLE 2.1-26 RECREATIOHAL HATER USE HITHIH 50 MILES OF ST LUCIE UHIT 2 Average Daily per Capita Participation Rate -Ayers e Dail Recreational Saltwater Users within 50 miles of St Lucie Unit 2 Recreational
~tlcLL kk Re.id.nt.(') Tourists (2) 1978 1980 1983 1990 2000 2010 2020 2030 Beach Acti-vities (salt-water) .1095 .3264 66,666 73,159 80,879 94,703 110,017 122,940 = 135,478 149,325 Fishing
{saltwater) .0403 .0221 20,423 22 227 24~574 28 777 33,430 37,357 41, 172 45,374 Boating (saltwater)
Po~er Boating .0362 .0550 19,820 21,650 23,936 28,029 32,560 36,385 40,099 44,194 Sailing .0018 .0157 1,529 1>698 1,877 2,197 2,553 2,853 3,143 3,465 Surfing .0017 .0279 1,993 2,230 2,465 2,886 3,353 3,746 4,127 4,550 Population within 50 miles of St Lucie Unit 2 (see Section 2.1.2)
Resident 483,765 530,764 580,742 680,081 790,040 882,845 973,061 1,072,314 Peak Daily Tourists and Seasonal Visitors 41,953 47 927 52 965 61,993 72 026 80 485 88 631 97 758 Hotes:
(I) Assumes that daily usage of resident population is limited to weekends, May through October. Therefoie, thc annual per capita resident participation rate (e.g., 6.57 for beach activities) is divided by 60, the number of weekend days from May through October, to get the average daily per capita participation rate (e.g., 0.1095 for beach activi-ties). Region X rates used.
(2) Assumes that tourists stay 13 days. Annual per capita rates are therefore divided by 13. Region X rates used.
Source: Outdoor Recreation in Florida 1976. State of Florida Dept of Hatural Resources, Division of Recreation and Parks, Tallahassee, Florida, May, 1976.
1977 Florida Tourist Stud An Executive Summer , Florida Department of State, Division of Tourism, Tallahassee, Florida, 1977.
SL2-ER-OL TABLE 2.2-1 VEGETATIVE COMPOSITION OF FP&L PROPERTY Ve etation Cover T pe Acres Hectares Percent Mangrove Swamp 750 305 66 Coastal Beach and Dune 49 20 Australian Pine Utility-Developed Land St Lucie Unit 1 and 2 Facj3ities 248 99 22 Disturbed Field and Shrub 52 21 .5 Road and Roadside 24 10 Total 1132 459 100 Comprises part of St Lucie Units 1 and 2 fill/borrow area.
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RECREATION OPEN SPACE LAND USE PLAN HUTCHIHSOH ISLAND PLAN Ce ~ HOSPITALITYCOMMERCIAL FIGURE 2.1-11 TOVttCEt TNT PLANNINOIOKTtONOROVP,TAMPA,flOAtOA RU FORT PIEACG >PCS 0' I RLl 4 r I.E GELD ~Z wL LOW OENSITY RESIDENTIAL I O O AIUE MEOIUM OENSITY RESIOENTIAL GENERAL COMMERCIAL PORT r O Xl ~T HIGHWAYCOMMERCIAL ST. LUCIS ~O IL LIGHT INOUSTRIAL >gr +o l Q a ALEE AGRICUI.TURAL c~ eo III Ill x RcXIII C3+CI CONSERVATION OPEN SPACE IlI III III g <<~r + 'll > .,' ~ .bI-. ~i % 'I \ 'n n'\ ~ I 30 Ml $ 7445 \ <<L I ~ I 'Ei ~ ~ ~ INDIAN RIVER CO Q I 'KEECHOB E'O:.I.PI!cv- .,I:."",.' *, ~,, C 10MI ~ "<<hFORT PIERG p Np I' t ST LLICIE CO, r +ST I UNTIE np ~ I ~ I' ~ '..:I-.;.:-..;.: ~ .".i I,.".-,ST OR 1 LUCIE, ."y, N,uIIIT r HIGHLANDS gr l5 " '~'~~ ~ ~, ~ ~ ~ ~ 4' --I 'L ~:.. OKEEGIIIM EI ~.~. ...' ~ .\'f...".': .W . UART ... :::::.:.'i: MARTIN COI.-P:g -n 'X R 0 CO I P I I n m IN I: I ~ tI I h4 Thl 'im Il ~ gg W, " rsRorrrrrI ~ "SIRF,RRSllrr5%%51 0NBAorsrrrrrrrr RFkE9srswRrrrrrrr rladrrr8rrrrrrrr O rrr5rrrrrrrrrrll < gEE5855%55555SS)l SWK C' ~ ' ~ ~ I ~ I Unit 2 Oischarge Pipeline Unit Oischarge Pipeline 1 A 7gA A 7/C Intake Pipeline EA Ar Units 1 8 2 I Shoreline I Oischarge Canal Units 1 8 2 State Road AIA Blowdown Bldg. Seal Well Fuel Handling Bldg. ~ Parkin - Reactor Auxiliary Bldg. Q Reactor Bldg. Unit 2 Turbine Generator Bldg. Main 8 Slartu Transformers Unit 2 Intake Structure ~ X lntoke Canal Units 1 8 2 I Emergency x Coolmg Switch ard I x x x x x~x xl x x I x x x x x x~ x FLORIDA POWER 8 LIGHT COMPANY ST. LUCIE Pl ANT UNIT 2 GENERAL PLANT LAYOUT FIGURE 3.1-1 ATTACHMENT 2 ST. LUCIE UNIT 2 FINAL SAFETY ANALYSIS REPORT, SECTION 2.1.2 SL2-F SAR There are no industrial, commercial, institutional, recreational or resi-dential structu'res within the plant area. SR A1A traverses FP&L's property approximately 1,000 ft. east of the St Lucie Unit 2 Reactor Building. The 'exclusion area and low. population zones are shown on Figures 2.1-2 and 2.1-3. The radius nf the exclusion area is 0.97 miles from the St Lucie Unit 2 Reactor Building. The low. population zone includes that area within one mile nf the St Lucie Unit 2 reactor. 2.1.1.3 Boundaries For Establishin Effluent Release Limits The minimum boundary distance for establishing gaseous effluent release limits is that nnted on Figure 2.1-4 directly north of St Lucie Unit 2 Reactor Building. Also indicated on Figure 2.1-4 are other boundary line distances from plant liquid and gaseous release points. The restricted area as defined in 10CFR20 includes the fenced-in area. shnwn nn Figure 1.2-l,. 2.1 ~ 2 EXCLUSION AREA AUTHORXTY AND CONTROL 2.1. 2. I . ~AuthnrKt As indicated and authorized by Annex J, Appendix J-3 to the St Lucie Plant Emergency Plan, FP&L controls the use of all land and water areas inside the site boundary (property) lines. 2.1.2 ' Control of Activities Unrelated tn Plant 0 eration All activities conducted within the plant (restricted) areas during plant operation are related to the facility operation. The plant area is the fenced-off area surrounding St Lucie Units 1 and 2 as depicted on Figure 1.2-1. As indicated in and authorized by the St Lucie Plant Emergency Plan, formal arrangements are made to control the traffic and activities of the public on SR A1A which traverses FP&L's property east of the plant area, and nn the State and Federal waters and beach adjacent to the FP&L property, if necessary in the event of an emergency tn assure health and safety nf the public. Specific details are enumerated in the Plant Emergency Plan (see Section 13.3). 2.1.2.3 - Arran ements For Traffic Control Formal arrangements are made for traffic control in the event of an emergency as described in the St Lucie Plant Emergency Plan in Annex D. 2.1.2.4 Abandonment or Relocation of Roads There are no public roads subject to abandonment nr relocation as a result of construction of St Lucie Unit 2. 2.1-2 .JrI' c IR, . " ' " "il . ~ ' l',IIjtrdlLhj+vl g rvls I)s(+4jTrjilI+le jIIgTIIJj'j.i LLhr" r hill ~ l<,r i+~i'>>4 VM ~ ID@ vMIAsl 4, Vhth 044il orvv ~ <<MrMv( ~ JI4 cr4lk <<I gal ~ I<<I AONMVN+ MV 1 A M Sdwb 4 wr MVVVLVVMi M ~ 2'VALI L'0 r r IMMI~ ~ 4l ~ l MM ~ a ~e asv eva aoHF SSv T~:l 3/) LIQUID EFFLUENT RELEASE RUIN T QI LTfH CNSCHARCC CENTERLINC CLCVA TION I'4, 22'4 NORTH OF D:SEHAROC SCALRCLL CENTCRLIHC AHD SS' CAST OF ROAD CENTERLINE If' I OASEOUS CFFLUEHT RELCASC POINTS ~ il Ml t SEE FICURC 1.2< IV 'VII ivl~ F ~ V SC ~ 4IUI RIH A FLORIDA POWER d LIGHT COMPANY ST. LUCIE PLANT UNIT 2 SITE PLOT PLAN FIGURE 1.2-1, REF DWG 2098%458(REV 3t ATTACHMENT 3 ST. LUCIE UNIT 2 FINAL SAFETY ANALYSIS REPORT SECTION 2.3 SL2-FSAR 2.3 METEOROLOGY 2.3.1 REGIONAL CLIMATOLOGY 2.3.1.1 General Climate The prevailing climatology'f the St. Lucie site is dominated by the pre-sence of the -Azores"Bermuda high pressure system ~~~ulting in a subtropical marine type climate for the eastern Florida coast . This climate is featured by a long, warm summer with abundant rainfall followed by a mild, relatively dry winter. The high frequency of onshore winds and the proximity of. the warm waters of the Gulf Stream result in warm, humid conditions during most of the year. Temperatures in excess nf 90 F typically occur on about 45 days each year, but summer heat is tempered by sea breezes along the coast and by frequent afternoon or early evening thundershowers in all'reas. During the winter months, the area is occasionally subjected to an outbreak of cold continental air; however, the cold air mass usually moderates rapidly. Consequently, subfreezing temperatures rarely occur in the area. Rainfall is unevenly distributed during the year. In general, the heaviest rainfall occurs during the period of June through October, coincident with the hurricane and thunderstorm season. A distinct dry period exists from November through March. The monsoonal nature of the general circulation in the area and the proxi-mity of the site ot the ocean result in a high percentage of easterly com-ponent (on-shor~[ winds. Wind speeds are fairly high, averaging over 9 mph along the coast Annual average relative humidity is approximately 73 percent in the ay~a while the mean percentage of possible sunshine is about 65 percent The site area is periodically affected by the passage of tropical cyclones of various intensities; the months of September and October have the high-est frequency of occurrence. Tornadoes and waterspouts have been observed throughout the year in this part of Florida. Meteorological conditions conducive to high air pollution potential are infrequent in southeastern Florida. The warm waters of the adjacent Gulf Stream current, located a few miles offshore, inhibit the formation of strong persistent low-level inversions while instability during the day is aided by strong insolation. Along the immediate coastline and areas such as Hutchinson Island, well developed seabreeze conditions result in per-sistent, slightly stable, on-shore flow. 'I The terrain in the site area is essentially flat with elevations in the surrounding area ranging approximately from 20 to 30 ft MSL. The topo- ~ graphy should exert little or no influence on synoptic-scale atmospheric processes in the site area. Topographic cross-sections are.not incl'uded with this document due to the lack of significant terrain variation within 50 miles of the site. 2 3-1 SL2- FSAR 2.3.1.2 Re ional Meteorolo ical Conditions for 'Desi n and 0 crating Bases a) General Meteorological data are presented in this section for severe weather phenomena such as heavy rainfall, thunderstorms, lightning, hail, hurricanes, tornadoes and waterspouts, and high air pollution. Also presented are meteorological conditions used for design and operating basis considerations such as'design basis tornado parameters. The two U.ST National Weather Services stations which are nearest the plant site are West Palm Beach and Fort Pierce, Florida. West Palm Beach is approximately 38.5 miles SSE of the site and located on the coasts Fort Pierce is on the west bank of the Indian River approxi-mately 6.8 miles NW of the site. These sites have similar topo-graphy and location relative to the ocean and are considered rep-resentative of the regional meteorological conditions for the St. Lucie site. b) Precipitation The lower east coastal division of Florida following the NOAA group-ing scheme ( generally experiences an annual average rainfall exceed-ing 59 in. ~ . Measurable. precipi)g)ion falls on approximately 36 percent of the days of the year ~ Most of the heavy rainfall is associated with thunderstorms or passage of hurricanes'ta maximum t oersdvarainfall for time per j~js of five minutes through 24 hours are listed in Table 2.3-1 . The storm of April 17, 1942 set maximum rainfall records for all time. periods from one through 24 hours'he maximum point rainfall records for time periods less than one hour generally result to strong convective activity in the form of thunderstorms. Based on an extreme value (Gimbel) analysis of precipitation data, estimated maximum rainfalls for mean recurrence intervals of one to 100 years and for rainfa)) durations of oneWalf hour to one day are given in Table 2.3-2 ~ A comparison of Tables 2.3-1 and 2.3-2 shows that the 100-year estimated amounts were exceeded at at West Palm Beach for time periods of 2, 3, 6, 12,.and 24 hours, whereas the maximum observed one hour rainfall of 4.40 in. has an estimated mean recurrence interval of the order of 80 years. The Probable Maximum Precipitation (PMP) is derived using two basic principles - storm transposition and storm maximization. It is as-sumed that all storms which produced the heaviest rainfall in a mete-orologically homogeneous region containing the area under considera-tion could have passed over the area. The *actual conditions during the storms are then increased to the critical meteorological condi-. tions considered probable for the region. The critical meteorological conditions considered are based on an analysis of air mass properties (effective precipitable water, depth of inflow layer, temperatures, winds, etc.), synoptic situations prevailing during the recorded 2 ~ 3~2 SL2 FSAR storms in the region, topograp)jc8(eatures, season of occurrence and location of the areas involved In the site area, the PMP for a 10 squ~y~ mile area and a rainfall duration period of six hours is 32 in. ~ This is an average rainfall rate of the order six in. per hour. Such a rainfall rate wss observed for a period of oae hour at Hjgeah, Plorida near Miami (17 miles S.) during the hurricane of 1947 . A detailed survey of the September, 1950 hurricane indicated a precipitation amount of the order of 34 xn, feLL in a 24"hour period within the vicinity of Cedar Key. The peak 24-hour precipitation measured at Yankeetown during the ~arm (38.70 in.) is the record 24-hour rainfall for the nation ~ Additional information regarding the development of the PMP for the site is given in Subsection 2.4.F 1. The maximum point rainfall observed in the United States during a six-hour period is 32 j~), recorded on July 8, 1942 at Smethport, Pennsylvania ~ In cental Florida, rainfall of 13.6 and 16.0 in. occurring over a 10 square mile area during a six-hour period were ~)y~rved during October 1924 and September 1950, respect-ively . Table 2.3-3 summarizes estimated probable maximum precipitation for duration(g~riods of 6, 12, 24, 48, and 72 hours over a 10 square~ile area Measurable snow or )glen preoipitation during the winrer rime is unusual for Florida ~ been no measurable snow nor frozen precipitation ', In the immediate site gyes)there has therefore, the probability that the maximum winter precipitation, over a 48-hour period, be in the form of solid precipitation (other than hail) is extremely low. Thunderstorms Thunderstorms have been recorded during each month of the year. How-ever, more than 80 percent occur during the period from May t'hrnugh September; July and August experience the maximum number of thunder-storm days with 16 days during an average month.- On an annual average basis, there are 79 days during which thunderstorms are monthly and annual thunderstorm days as recorded at )~st'alm observed'verage Beach during the period 1943-1974 are listed in Table 2.3-4 Lightning The frequency of cloud'to~roun( jIjghtning flashes per thunderstorm day can be estimated as follows >E (0.1 + 0.35 sin ) (0.4 + 0.2) (1) Ls the number of flashes to earth per thunderstorm day per square kilometer and is the geographical Latitude. Monthly and an-nual est imates nf Lightning strikes are presented in Table 2.3-4 based on values of N and the thunderstorm data for West Palm Beach. The results indicate that the annual expectancy of Lightning strikes for a square kilometer area in the site vicinity is between four and 12. SL2-FSAR e) Hail In the period 1945-1953 the n~T(er of hailstorms recorded in all of Florida totaled only 37 cases . However, in the period 1955-1967, lid cases od ~yghce hailstorms (3/4 in. diameter or larger hail) were reported . On a state-wide basis, only 32 of these oc-currences (27.5 percent) had hail with diameters greater than 1.5 in. The average monthly and annual distributions of these hail-storms are given in Table 2.3-4. While the hail size distribution of the site area is not known, the one degree, latitude-longitude square in which the site is 'located has experienced an annual average of three hailstorms (3/4-in. or greater) as reported 'in the study above. However, the probability of hail at a specification is very small. The occurrence of hail is most likely during the months of March, April, andt May. ments~ Hurricanes Tropical cyclones are classified according to their stage of develop-Hurricanes are tropical cyclones with highest sustained wind speeds of 74 mph or higher, Tropical cyclones with sustained winds in the range of 39 to 73 mph are classified as tropical st~@~ and as tropical depressions when wind speeds're less than 39 mph During the period 1900-1963, the Florida Peninsula has been affected by 65 tropical cyclones. Of these, 25 were classified as hurricanes, l l7)~ The 33 as tropical storms and seven as tropical depressions~ ~ monthly and annual distribution of tropical cyclones affecting the Florida Peninsula is presented in Table 2.3-5. Roughly half the storms in each category passed close enough to the St. Lucie site to affect it with strong winds and/or heavy rainfall. Hurricanes have occurred most frequently in September and October in the sit e area. Hurricane paths affecting the site are generally toward the west-northwest with an average forward speed of about 12 mph. ln any given year, the ~)~nces of hurricane force winds affecting the site area are I in 15 . The worst hurricane in recent times in the site area occurred in August 1949. Winds at West Palm Beach reached 1lO mph with gusts to 125 mph before the anemometer was blown away. The highest(~~e~i nute wind speed,was estimated at 120 mph with gusts to 130 mph . The development of the meteorological parameters and the wind field of the probaable maximum hurricane. (PMH) are provided in Subsection 2.4.5.1. g) Tornadoes and Waterspouts Historically, tornadoes and waterspouts have been observed during all seasons in southeastern Florida; the greatest frequency of such events occurs during spring and summer. The number reported in a specific area is heavi ly biased by the population density and air-craft act ivity in the area. Since the West Palm Beach area is well populated and served by a major airport facility, more reports would be anticipated than had the area been situated in a rural setting.
2. 3-4
SL2-FSAR fi The average seasonal and annual frequency of tornadoes which have occurred in the state of Florida during the period from 1955-1967 are as follows (1>> . Winter 4.5 Summer 15.1 Annual 34,9 Spring 9.0 Autumn 6.3 In the one degree latitude'longitude souare in which the site is loca)~f)a totaL of 36 tornadoes were reported over the period 1955 1967 . The technique for determining the probability of a tornado striking a point in the one degree square in which the site is located yields a Level of 0.00094 per year (18); the recurrence interval is 1062 years. This technique is based. on the path width of tornadoes in the mid-west area. For the Florida region, tornado paths are narrower on the average. The total f~~gency for tornadoes in the site vicinity from an earlier data case is 14 for the period of 1953-1962, or a mean annual frequency of 1.4. Applying the same. technique for this data yields a probability of 0.00207 with a recurrence interval of 483 years, Two independent s)~Ji es have been made to determine the severity of Florida tornadoes ~ Both conclude that the severe 360 mph (Region I) tornadoes are not applicable to Florida, and that historical data does not substantiate speeds exceeding about 200 mph in Florida torna-does, The earlier study utilized all known Florida tornado data from 1887 to 1968, whereas the current study analyzed data for the period from 1950 to 1972. The current study went beyond the earlier, work in that it developed a Design Basis Tornado (DBT) for the Atlantic coast of the United States and the Atlantic coast of Florida. The results of the DBT analysis indicate that a Region III (240 mph) DBT is.appro' priate for the St. Lucie site However, the parameters pertinent to ~ the design and operation of a nuclear plant in this region are )ist-ed in Subsection 3.3.2. Waterspout reporting in the United States has been coordinated in a systematic manner since 1952 by the National Weather Service. A total of 190 watarspoots have bean reported from 1952 to 1973 along )00 mile zone of the Florida Atlantic Coast centered at St. Lucie ~ Of these, 178 were reported to have occurred within 25 miles of the shore. Remarks are rarely given about their size and direction of mo-tion because of their general. over-water trajectory. The monthly distribution of waterspouts occurring within 25 miles off-shore and along a 200 mile zone centered at St. Lucie for the period of record, 1952 to 1973 are given in Table 2.3-7. Of this pop-ulation, 82 occurred between May and October. Of the 178 waterspouts identified in Table 2.3-7, 11 were reported to land and their worst reported d'amage falls into the "weak to'igrate tornado" categ~H'estimated wind speeds of 72-112'ph), as defined in the F-scale . An in-depth analysis of the Lower Matecum e Key waterspout indicated a maximum estimated wind speed of 170 mph 22)
2. 3-5
SL2-FSAR It has been indicated that errors inherent in the damage assessment technique are about 15 to 20 ~gr~ent and that this estimate is prob-ably to the conservative side . This tangential speed when coupled with the translational speed of the waterspout, results in a maximum horizontal velocity of less than 200 mph, well below the NRC tornado design criteria. In order to compute the probability and recurrence interval of a waterspout at a point, estimates of waterspout diameter and path length are necessary. Since very little information was available, a conservative average waterspout width-path length of 200 ft. by four miles was assumed. Recurrence intervals were then computed for various offshore dis-tances along the 200,mile cg~stal zone. The method used is similar to the tornado evaluation The probability of a waterspout striking a given point is: Z T (2) ProbsbiliLy A Z Mean Area of a Waterspout T ~ Frequency of Waterspout (Annual) A ~ Area Examined The "recurrence interval (in years) is defined as: 1 Recurrence ~ (3) Probability The probability and recurrence intervals of waterspouts for various distances offshore are given in Table 2.3-6. h) . Air Pollution Potential Based nn a 35-year period of record from 1936-1970, the num)pg of stagnation days in the Eastern United States were tabulated There were approximately 155 days of atmospheric stagnation in the vicinity of the plant, of which 34 cases persisted four or more days. A study on the potential for urban air pollution throughout )$ g ) con-tiguous United States was made for the period from 1960-1964 This study indicated that the total number of forecast days of high air pollution potential in the site area was zero for this five-year periods Between August 1, 1960, and April 3, 1970, there were no high air pol-lution potential days a~g~~ding to data given in the State of Florida Air Implementation Plan . Air pollution potential criteria for meteorologjg~l' ggnditjog)that have the potential to develop into an episode were followed in the above assessment. r
2. 3>>6
SL2-FSAR Extreme Winds The distribution of extreme wind speeds is expressed in terms of a mean recurrence interval )~~ed on a mixed Fisher-Tippett Type II ex-treme value distribution . The mean recurrence intervals for "fastest~ile" wind speeds are shown in Table 2.3-8. These wind speeds are in reality a wind intensity in that the "fastest mile" is that wind speed associated with the passage of one mile of air. In general, the values are thought to represent an approximate one-minute wind speed; in reality, this is true only at 60 mph. Assum-ing that the fastest mile parameter represents a uniform data base, the'xtreme value analysis is performed. It can be seen from these data that the fastest mile wind speed of 120 mph has a recurrence terval of 100 years. Wind loadings for the site are discussed in Subsection 3.3 ', 2 ~ 3~7 SL2-FSAR 2.3.2 LOCAL METEOROLOGY The site characteristics described in this section are be~a) nn long term West Palm Beach, Florida National Weather Service records and short term onsite data collected from the St. Lucie meteorological tower between September 1, 1976 and August 31, 1978 (see Subsection 2.3.3 for collection program description). 2.3.2.1 Normal and Extreme Values of Meteorolo. ical Parameters 2.3.2,1.1 Winds Table 2.3-9 summarizes long term monthly and annual average wind data for West Palm Beach. In general, wind speeds are in excess of seven mph and the prevailing wind direction exhibits northerly components during the winter months shifting to southerly directions during the summer. The mean annual wind speed is 9.4 mph and the prevailing direction is from the east"southeast. Local winds of higher speed and short duration occur on occasion in connection with thunderstorms or the passage of cold fronts. The peak "fastest~ile" wind speed recorded between 1959 and 1977 was 86 mph in August 1964, Table 2.3-10 presents a summary of the lower level (32.8 ft) onsit'e winds recorded at the St Lucie meteorological tower.'he average annual wind ~ speed is 6.9 mph and the prevailing direction is from the southeast. The maximum hour averaged wind speed recorded during the two year period was 30.0 mph. Table 2.3-11 illustrates the mean diurnal variation of both the lower and the upper (190.0 ft) level winds. Offshore winds generally prevail during the night and early morning while on-shore winds are prevalent during the re-mainder of the day. Tables 2.3-12 to 2.3-18 provide annual lower level wind persistence d~)g for each of the stability classes described in Regulatory Guide 1.23 (RO) ) Tables 2.3-19 and 2.3-20 provided persistence data for all stable classes (Pasquill 088') and all classes combined (Pasquill All), respectively. In-valid wind speeds are presented as 99.99. In general, ~inds prevailing for 24"hours or more were from the east-southeast to the south-southeast. The joint frequencies of wind speed, direction and stability for upper and lower winds are found in Tables 2.3-21 to 2.3-36. 2.3.2.1.2 Temperature and Atmospheric Water Vapor Table 2.3-37 provides a summary of long term average temperatures and relative humidity and extreme temperatures at West Palm Beach. The mean daily maximum temperature during the warmest month, August, is 90.2 F; January, the coldest month has a mean daily minimum temperature of 55.9 F. The mean annual temperature is 74.5 F ~ The'iurnal range, the di fference between the mean daily maximum temperature (83.0 F) and the mean daily minimum temperature (66.0 F) is 17.0 F ~ The highest temperature on record between 1937 and 1977 is 101.0 F in July 1942; the coldest is 27.0 F in January 1977. The average annual relative humidity is 73.3 percent.
2. 3-8
'L2 FSAR At the St Lucie site the average temperature during the 2 year period was ~ 72.5 F and the diurnal range was 9.8 F. The mean daily maximum and minimum temperatures during the warmest (July) and coldest months (January) were 85.5 F and 51.3 F, respectively. The highest temperature recorded onsite was 99.8 F; the lowest was 28.4 F. Average monthly relative humidities exceeded 60 percent throughout the year. The average annual relative humidity was 71.6 percent; the mean annual dewpoint was 62.6 F. Tables 2.3"38 to 2.3-51 present a summary of the onsite data. 2.3.2.1.3 Preci pit at inn West Palm Beach has a mean annual precipitation of 62.06 inches. A maior portion nf the rainfall occurs between June and October in association with "local" showers and thunderstorms. Precipitation equal 'to or greater than 0.01 inches occurs on an average of ]31 days a year and most frequently during the rainy season. The greatest 24-hour precipitation on record between 1939 and j977 was 15.23 inches in April 1942. Snow rarely occurs in this region, although a trace was noted in January j977 Monthly and ~ annual precipitation totals and greatest 24-hour rainfall totals are sum-marized for West PaLm Beach in Table 2.3-52. Table 2 '-53 presents a summary of onsite precipitation data. The site averaged 3l.58 inches of precipitation annually with maximum monthly amounts in excess of 4 inches occurring during August and September. Rainfall fre-quency and duration are presented in Tables 2.3-54 to 2.3-66. Precipitation wind roses are presented monthly and for the total period in Tables 2.3-67 to 2.3-79. 2.3.2.1.4 Fog and Smog Table 2.3-80 presents heavy fog data for West Palm Beach.. On an average there are eight days a year when heavy fog occurs and these are mainly con-fined t o the months bet ween October and April. Although no onsite fog or smog data is available, the west Palm Beach data is representative for the site. 2,3.2,I ~ 5 Stability Studies by Holzworth indicate that for the eastern coast of Florida un-stable conditions (A,B,C) occur 16-25 percent of the time, neutral condi-tions (D) and stable cnndit iona (E,F,G) each occur 36>>45 percent of the time. Table 2.3-81 summarizes onsit e stability frequencies for the two-year period ~ Unstable conditions occurred 20 percent of the time, neutral conditions occurred 30 percent, of the time and stable occurred 50 percent of the time The site is, therefore, prone towards s'table conditions. Table 2.3-19 shows that there were two cases during the period when stable conditions existed for a period greater than 15 hours. 2.3-9 SL2" FSAR .2.3.2.2 Potential Influence of the Plant and Its Facilities on Local Meteorolo The site area and the surrounding five mile radius terrain is essentially flat with elevations not exceeding 25 feet ~ The higl!est elevation within a 50~lie radius is 75 feet and is located to the west~orthwest of the site ~ Between the northmorthwest and south-southeast sectors the Atlantic Ocean is the major feature. Topographic maps of the area within a radius of five and 50 miles are provided as Figures 2.3-1 and 2.3-2, respectively. Topo-graphic cross-sections were deemed inappropriate as the peak sector average slope to 50 miles was .03 percent (75 ft /264;000 ft ) ~ ~ ~ The presence and operation of the plant is not expected to exert a'odify-ing influence on the normal and extreme meteorological conditions in the area. r 2.3.2.3 Local Meteorological Conditions for Design and 0 crating Bases Local meteorological data have not been used for design and operating basis considerations orher than those conditions referred to in Subsections 2.3.4 and 2.3.5. 2.3.3 ONSITE METEOROLOGICAL MEASUREMENTS PROGRAM The onsite meteorological program was designed to provide a dispersion climatology for use in safety planning of radioactive effluent releases and as a means of determining the appropriately conservative meteorological parameters to be used in estimating the potential consequences of hypnthe- 't ical accidents. Analysis nf collected meteorological data permits an assessment of the diffusion parameters characteristic of the sit~~ The in-strument package which complies with Regulatory Guide 1.23, (RO) 30) is described in Subsections 2.3.3.2 through 2.3.3.4. The parameters which are monitored are wind speed, wind direction, temper-ature difference in height (delta-T), dewpoint, temperature, barometric, pressure and precipitation. The parameter, heights and number of sensors installed at the St. Lucie site are listed in Table 2.3-82. 2.3.3.1 Meteorolo ical Tower meteorological tower was erected at the St. Lucie site on Hutchinson Island in December 1970. A 199-ft framed tower is located on site ~ 2400 ft. north of the reactor complex. It is situated in an area of rela-tively flat terrain characterised by mangrove trees in the range of eight to l0 ft in height. Figure 2.3-3 illustrates the location of the meteoro- ~ logical tower relative to the rest of the site. 2.3 '.2 Instrumentation a) Wind Speed The wind speed sensors at the 32.8 ft. and the 190 ft. levels are Climatronics F460-WS wind speed transmitters. Each sensor consists of a sensitive three cup anemometer which drives a multi-holed light
2. 3- 10
SL2- FSAR chopper in the transmitter. The rotating light chopper produces an electrical signal output from a phototransistor and a light emitting diode source. The resulting signal is shaped into a square wave whose frequency is proportional to the wind speed. This square wave signal is then sent to the translator for conversion to engineering units, The specifications for the Climatronics Model 8F460-WS wind speed anemometer are as follows'. Accuracy + 0.15 mph or 1% whichever is greater Th resho ld 0.58 mph Range 0 to 100 mph Distance Constant. 5 feet maximum Temperature Operating Range WO F to +120 F b) Wind Direction Climatronics F460-WD wind direction transmitters are used to measure the wind direction at the upper and lower levels. Each wind direction sensor consists of a light weight counter-balanced vane connected to a precision low-torque potentiometer located in the transmitter. The position of the vane is sensed by the potentiometer and is sent to the translator as a dc voltage. The specifications of the Climatrnnics Model OF460>>WD wind direction sensor are as follows: Ac cur acy + 3 0 of azimuth Threshold 0 '8 mph 0 to 540 Range Distance Constant 3.7 feet maximum Damping Ratio 0.4 Temperature Operating Range -40 F to +120 F The signal conditioning equipment is the Climatronics Model 100078 analog translator. The output of the translator is 0-1.0 volt for 0-120 mph wind speed. Wind direction output is 0-1.0 volt for 0-540 c) 'ir Temperature Two Rosemount resistance temperature sensors Model 104 MB are used for the direct measurement of ambient temperature and delta temperature. The platinum resistance temperature sensor provides an extremely pre-dictable and repeatable resistive output with changes in temperature. The Rosemount temperature sensors are coupled with Rosemount Model 414L linear bridges to provide a millivolt output signal with an ac-curacy of + 0.17 F. Differential temperature is measured between the upper and lower temperature sensors (0-0.1 volt for 0-100 F) by using a differential'mplifier supplied with the control room e'quipment for temperature differential. The differential output range is +15 F. The heights of each temperature 'sensor are given in Table 2.3-82. 2.3-11 , SL2"FSAR 'he sensor consists of a precision, wire~ound resistance element, a protective enclosure, a mounting housing, and provisions for electri-cal connections. The specifications of the Model 104 >1B sensors are as follows: Accuracy +0.047 C g 32 F Response Time Y.5 seconds Response 'Time. of Probes 5.5 seconds Range o f Probes -100 to 500 F Resistance at 0 C (32 F) Approx 100 ohms (Dependent on Probe) Radiat ion Shield Under test radiation inten-si)y of 1.56 Gram calories/ cm min, radiation errors are less than 0.2 F. Aspiration Rate 10 ft/sec Operating Temp Range of Shield -40 F to 150 F Shield Finish Highly reflective Dupont Polar white epoxy d) Rain Gauge The precipitation sensor is a Belfort tipping bucket rain gauge. This type of sensor funnels rain into a small receptacle which tilts when it has received 0.01 inch of rain and another identical receptacle moves in place ready to receive the next 0.01 inch of rain. In the process of tipping, an electrical contact is closed momentarily. A translator card is connected to this electrical contact and counts the tips by adding. 0.01 volts (0.01 inches precipitation). After each 1 inch accumulation of precipitation the translator automatically re-sets the output to 0.0 volts, Belfort tipping bucket rain gauge (No. 595) Sensitivity 0.01 inches Range infinite Accuracy 2Z for rainfall rate of 1 ceil' in/hour or less 4X for rainfall rate of 3 in/hour 6X for rainfall rate of 6 in/hour e) Dewpoint Dewpoint (at the 34.65 foot level) is measured by a Foxboro Model 2711 AAG lithium chloride dew . The range of the sensor is 0 to 120 F; the accuracy is +0.5 F between 10 and 90% relative humidity. The linear output is recorded on' Bristol Model 550 dynamaster analog recorder.
2. 3-12
SL2- FSAR Barometric Pressure A Belfort microbarograph (USWB No. 355-31SW) is employed to provide a continuous strip chart record nf atmospheric pressure. It is calibra-ted to within .005 inches (.17 mbs) ~ 2.3.3.3 The meteorological data acquisition system for the St. Lucie site is designed accordance with the requirements listed in Regulatory Guide 1.23 (RO) jg ~ The data acquisition equipment is at the onsite meteoro-logical tower. The data output of the sensing equipment is routed to a local recording station located at the base of the meteorological tower. The six parameters were recorded on individual, single po'int analog recor-ders. The chart width is 4.8 in. for each parameter. The range for the wind speed is 0-120 mph. The chart range for wind direction is 540 to elimi-nate full scale wiping. The delta-T recorder has a + 15 F chart range. The temperature recorders are 0-120 F minimum. The dewpnint is 0-120 F. Chart speeds are 1.5 in. per hour. The following is a summary of the recorders provided in the local recording station at the base of the tower. Laboratory Data Control Model 2802 'also Navy I. D. RO-447/GMQ29 a) Wind Speed Recorders (2) 0-120 MPH Range b) Wind Direction Recorders (2) 0-540 Sweep Range c) Dewpoint 0-120 Range d) Delta-T Recorder + 15 F Range The telemetry system will be designed and described at a later point in time. 2,3.3.4 Data Reduction The meteorological data for the diffusion evaluation is presently recorded on strip charts located in the recording station at the base of the meteoro-logical tower. The data is reduced to mean hourly data and placed nn computer punch cards. This present data includes: a) Wind direction for the 32.8 and 190-foot levels of the meteoro-logical tower. b) Wind speed for the 32.8 and 190-foot levels. c) Vertical temperature lapse rates between the'10.3-foot and 32.8-foot levels and between 190.5-foot and 32.8-foot levels. d) Ambient temperature for the 34.7, 112.0 and 191 ' foot levels.
2. 3-13
SL2-FSAR e) Dew point temperature for the 34.7 and 110.3 foot levels ~ f) Precipitation at the surface'.3.3.5 Calibration and Maintenance a) Wind Direction/Wind Speed Translator System The translator cards supplying power to the wind direction and win'd speed sensors are capable of supplying a "zero" and "span" or "full scale" output using an internally calibrated voltage, precision resis-tance or crystal frequency oscillator. Values for the "as found" and "as 1'eft" test are documented for both "zero" and "span" modes at the remote site. This procedure documents any changes made during the calibration and readings indicated by the analog system. b) Wind Direction Sensor Calibration The bearings in the wind direction sensor are changed every year with replacement date and sensor serial number documented. The wind vane is pointed toward a known azimuth and the reading compared with expec-ted voltage and chart readings. Repeatability and proper 540 0 switching of the potentiometer is noted and documented. All values are checked for readings +5 of known azimuth points, Calibration is performed and documentation on the "as found" and "as left" condi-tions recorded for analog indicator at the remote site. c) Wind Speed Sensor Calibration Wind speed sensor bearings are replaced every six months with sensor serial number and replacement date properly documented.. The sensor is checked by inhibiting any movement of the cups and checking for expected voltage and analog outputs. Calibration is per-formed after noting the "as found" condition. Documentation of "as left" condition is made for the tower site recorders. d) Temperature System A variable precision resistance is substituted for each temperature probe. Factory calibration curves are compared with a five-point re-sistance test to verify temperature bridge linearity throughout the system operating range. Values recorded by the digital and analog systems are documented for the "as found" and "as left" condition for each point calibration. e) Delta Temperature System A variable millivolt source is substituted into the recorder and a five-point linearity check performed against known t'emperature points. The calibration is documented at each point with the "as found" and "as left" values recorded. A comparison is made with the remote and control room digital and analog recorders with any changes made during the calibration documented. 2.3-14 SL2-FSAR Dew Point Temperature System The dewprobe is disconnected and substituted with a variable mill.ivolt supply. Probe resistance values are simulated over a five-point line-arity range to compare with known expected results. Readings from the remote site analog recorder are documented in the "as found" and "as left" mode for the calibration procedure, g) Dewcell Calibration The old dewcell is replaced with a spare dewcell that has been cleaned and retreated with lithium chloride (LiC1). Wet and dry bulb readings are taken with a sling psychrometer to determine dew point and com-pared with the system dew point. Analog recorders in the remote site are compared with the sling psychrometer and values documented. h) Microbarograph System L The readings from the microbarograph are compared with the test barom-eter and recorded. A calibration is performed documenting the "as found" and "as left" condition.. The battery pack voltage is checked and replaced if below factory specifications of 2.9 volt dc, Rain Gage System The tipping bucket is activated several times with the correct value being verified on the analog recorder. Values are logged and documen-ted to indicate consistency in readings.
2. 3>> 15
SL2-FSAR 2.3.4 SHORT TERM (ACCIDENT) DIFFUSION ESTIMATES The objective of this subsection is to provide conservative estimates of atmospheric diffusion at both the site boundary and at the outer limits of the low population zone (LPZ) for appropriate time periods up to 30 days. The diffusion evaluations for the short-tean accidents are based on the assumption of a ground-level release (i.e., no reduction in ground concen-trations due to elevation of the plume). The data base used in the cal'cu>> lations is the same as was described in Subsection 2.3.2. 2.3.4.1 Diffusion Model for 0-2 Hours The analytical procedure for evaluating the 0-2 hour accident on a revision of the model described in Regulatory Guide 1.4 (R2) perjgf) i's based The changes reflect variations in atmospheric diffusion factors that occur as a function of wind direction and variable site boundary distance. Allow-ances are made for meandering plumes during light winds and stable atmos-pheric condi)jg~s. The new approach is described in Draft, Regulatory Guide 1.XXX (1978) The model is distance and 'direction-dependent. Variability of wind direc-tion frequency was considered in determining the relative concentration, X/Q, values. The hourly X/Q values were determined as described in the following manner. During neutral and stable conditions when the wind speed at the lower (10 meter) level is less than six meters per second (mps) the relative con-centration is computed as: (4) Q Ugp IP provided it is less than the greater value calculated from either X 1 (5) Q u (>~ ~z + cA) y or X 1 (6) y z where: X/Q is relative concentration of ground level (sec/m ) ~ ~ is 3.14159 is the hourly average wind speed at the 10 meter level above plant grade (m/sec). E ~ is the lateral plume spread (m) with meander and building wake effects (m) (a function of atmospheric stability, wind speed u and downwind distance from the release). For distances up to 800 meters, 2.3-16 SL2-FSAR ~ Ma . where(+>>s a function of atmospheric stability End wild speed (32) . For distances greater than 800 meters, y (M 1 ) 0 (g800 ) A ~ is the smallest vertical plane, cross-sectional area of the building from which the effluent is released (2726 m ) c ~ building shape factor (.5) ~ is the lateral plume spread (m) at a given distance and stability based on logarithmic fit of NRC curves in Reference (32). ~ is the vertical plume spread (m) at a given distance and stability based on logarithmic fit of NRC curves in Reference 32. During all other atmospheric stability and/or wind speed conditions, X/Q is the greater value calculated from Equations (5) and (6). Plume meander was accounted for by y~fjfying the lateral diffusion coeffi-cient ~ . The meander function (M) is evaluated as follows: a) For Pasquill stabilities A-C at all wind speeds or all stabilities when wind speed) 6 mps; M ~ 1 b) For wind speed (2 mps; Stab D M ~ 2 StabE;M~3 StabF;M~4 StabG;M~6 c) For 2 mps g wind speed ( 6 mps; M is evaluated by a logarithmic inter-polation from M value in b) above at 2 mps to M ~ 1 at 6 mps. An hourly observation is considered to be calm if the wind speed is less than the threshold of the wind instruments. For calm conditions a wind speed is assigned equal to the vane or anemometer starting speed, whichever is higher. A wind direction is assigned in proportion to the directional distribution of non-calm winds with speeds less than 1.5 meters per second. No substitution was made for missing or invalid data. The sector X/Q values at the exclusion boundary (.97 mile) and outer LPZ (1.0 mile) were determined for each sector. peg~ are defined as the X/Q value which is exceeded 0.5% of the total time . To extract this value, value, the hourly X/Q's are sorted according to sector and magnitude. A cumu-lative probability distribution of X/Q values can easily be constructed as: P(X/Q) ~ rank of X/ (7) X/Q population size P(X/Q) is the probability of being exceeded. For example the 10th largest value of a 100 value population has a probability of being exceeded of 10/100 or 10 percent. The highest of the 10 sector X/Q values is defined as the maximum sector X/Q value. 2.3-17 SL2-FSAR The overall 5 percent site X/Q values which are exceeded no more than five percent of the total time around the exclusion area boundary (.97 mile) and the outer'PZ (1.0 mile) were determined in a manner similar to the .5 per- 'cent sector X/Q values. All of the hourly. X/Q values were sorted accord-ing to magnitude (independent of the direction) and the five percent value chosen from the list. 2.3.4.2 Diffusion Model for 0-8 Hours The downwind centerline relative concentration of an effluent, continuously released from a point source at ground-)@el has been 'evaluated. The model used in the calculations is as follows X/Q ~ u( ~<< Z + cA) (8) where: X/Q ~ relative concentration (sec/m ) average hourly wind speed (m/sec) at the 10 meter level above plant grade ~y~z the horizontal and vertical dispersion coefficients (m), corresponding to the Pasquill st~)j)ities defined in Regulatory Guide 1.23 (RO) from measurements of the vertical temperature difference c empirical building shape factor 0.5 (dimensionless) A ~ minimum2cross sectional area of the Reactor Building (2726 m') Hourly average winds less than or equal to the starting speed of the anemom-eter or vane (0.36 mps) were considered calm. The calms were directionally assigned in proportion to the distribution of the lowest (non-calm) wind speed class by stability class. Eight hour running average relative concen-trations were calculated by wind at direction the exclusion area boundary and at the low population zone distances. 2.3.4.3 Diffusion Model for 8-24 Hours, 1-4 Da s, and 4-30 Da s For the postulated 16-hour, 72-hour, and 624-hour periods, the following equation, from Regulatory Guide 1.4 (R2) ~~~ident was used to calcu-late the relative concentrations by wind direction at 1.0-mile the low-population-zone distance: X/Q I n 2. 032 (9) n ~ X u.Dr 1 z ~ ~1 2.3-18 SL2-FSAR where: D ~ distance to point of analysis (m) n ~ running-average time of 16-hours, 72-hours and i 624"hours, from ~ 1 to n 2.3.4.4 Results of Short Term Diffusion Estimates Two hourly X/Q values were computed using the St. Lucie onsite data for September 1976 to August 1978. The sector X/Q values at the exclusion area boundary (EAB) (.97 mile) and the low-population zone (LPZ) (1.0 mile) were extracted from these X/Qs according to the method described'n Sub-section 2.3.4.1. The worst, and the worst 95th percentile X/Q values for each accident averaging period (8,16,72, and 624-hours) were determined from the rigorous analysis of all sequential meteorological combinations exhibited in the data base; the 50th percentile X/Q values for all five averaging periods and two boundary distances were computed as well. There are presented in Tables 2.3"83 to 2.3-100 for the data periods September 1976 to August 1977, September 1977 to August 1978, and September 1976 to August 1978. The maximum sector X/Q values for each averaging period, data period, and boundary distances were extracted and are presented in these tables, The five percent overall X/Q value was determined from the two hourly X/Q values (see Subsection 2.3.4.1) ~ The accident averaging period five percent overall X/Q's were determined from the cumulative frequency distribution of all non-zero X/Q's. The interpolation from the frequency distribution was performed for each data period and each boundary. The maximum sector X/Q's occur in the SE sector. For 1976-1977 the maximum X/Q at the LPZ and EAB was, 1.1E-04; for 1977-1978 the maximum X/Q at the LPZ and EAB were 8.5E"05 and. 8.7E-05, respectively; for the entire data period (1976-1978) the maximum sector X/Q value at the LPZ and EAB were 1.1E-04 and .1.2E-04, respectively. This-1 maximum X/Q corresponds with stability class F and windspeed of .9 m sec . A summary tabulation for the maximum of the sector X/Q values (two hours) and the worst 95th percentile X/Q values is given in Table 2.3-101. 2.3>>19 SL2-FSAR 2.3.5 LONG TERM (ROUTINE) DIFFUSION ESTIMATES The long term diffusion characteristics for the St. Lucie site were esti<< mate)3j~ accordance with the criteria set forth in Regulatory Guide 1.111, (Rl) . The analysis was performed using the onsite meteorological data for a two year period, September 1976 through August 1978 (see Subsection 2.3.2). Relative concentrations (X/Q) resulting from routine releases were calcu-lated using a mode(jc~)jon of the puff-advection model HESODIF developed by Start and Wendell ' A ground release was asssumed. The Start and Wendell dispersion coefficients we~p replaced with those consistent with other NRC evaluations from Gifford . Building wake was incorporated to allow for initial dispersion credit in the building cavity. These calcula-tions were made at distances of .5, 1.5, 2.5, 3.5, 4.5, 7.5, 15, 25, 35, and 45 miles. Undepleted relative concentrations (X/Q) were also computed using a straight line plume model. The ratios between the X/Q's from each model were determined and are characterized as the terrain/recir-ulation correc-tion factors. 2.3.5.1 Atmos heric Diffusion Models 2.3.5.1.1 Puff-Advection Model Spatial variability of stability, mixing height, wind speed, and wind direction facilitate that the effluent plume from a continuous point source be approximated by the release of a series of puffs. Each puff can be modified or advected independently according to the meteorological condi-tions of its immediate location. Total integrated concentrations at any sampling point can be calculated from the accumulated exposure due to individual puffs as they pass over the point. The instantaneous contribution of'n indivi)~~) puff to a sampling point's total integrated concentration, after Slade , for a ground release, is given by; X (x,y) exp 1 ( ) (10) ) 3/2(P2 2 (2 (y ~r 2 where: X (x,y) ~ The instantaneous ground level rela)ive concentration at coordinate (x,y), (seconds/meter ), ~z ~ the standard deviation of effluent in the vertical direction (meters), ~r ~ the standard deviation of effluent in the horizontal direction (meters), 2.3-20 SL2-FSAR r ~ the distance frcm the center of the puff to the coordinate (x,y) (meters) Using Equation (10) the total integrated concentrations are calculated as: TIC(x,y) ~ n X X J K. I. L E X "kl,y ill jal k~1 , 1~1 J L. where: TIC(x',y) ~ accumulated hourly relative concentration at grid point (x,y), (seconds/meter 3 ), n ~ number of sampling hours, J ~ the number of advection steps per hour, K. i ~ the number of puffs released up to hour i, L. the number of samples per advection step j, and j the instantaneous relative concentration coordinate Q (x,y) contributed from puff k,.during i, advection step j, .sampling step 1. This approximation with adequate sampling frequency will converge to the continuoy~<~oint source at any level of accuracy required (see Start and
Wendell, The diffusion of effluents is described by the distance and stability dependent values of ~ and o . Because the time history of a puff includes spatial and Temporal variations of meteorological parameters, the value of o and <r cannot be determined as a discrete function of stability and distance. These values are determined in a stepwise fashion according to the general form'.
0 + ha (12) where: the standard deviation before the advection step (meters), the incremental change during the advection step just completed (meters), and e ~ the updated standard deviation following the completed advection step (meters). Between sampling intervals, conditions remain constant. it is assumed that all meteorological Growth of the puff during this interval
2. 3-21
SL2-FSAR then is only a function of stability, total distance moved before the advection step, and distance increment moved during the advection step. 4o is specified by: 4r m s (IPAS, DIST + DIST) 'S (IPAS, DIST) (13) where: S (A1 B) 10 (a(A)+b (A) log (B)+c (A) (log (B) ) ) IPAS ~ the Pasquill stability class characteristic of the advection process, DIST ~ the total distance puff. has moved prior to advection step, DIST ~ the distance increment moved during the advection step, a,b,c ~ are coefficients dependent upon stability class, deter-. mined in a manner such the functions S (A,B) fits the curves given by Gifford t)g) In a method similar to that of Turner, (3&) ~z at any time and location is allowed to. increase via Equation (12) and Equation (13) until a value of 0.80 times the mixing height has been reached. At this point, the effluent is assumed to be uniformly mixed in the vertical direction. If previous values of crz already exceed this limit, they are held constant (i.e., 4<~ 0); they are not reduced in any manner b~~g~se a negative 4~ would imply negative diffusion (Start and Wendell, ). 2.3.5. 1. 2 Straight-Line Airflow Model The use of a ground-level release model in calculating the annual average atmospheric relative concentration (X/Q) values was determined by the meteorological data and the initial plant parameters. Depletion factors are c~gyted directly fran depletion curves as are the relative deposition rates . For long term, ground level relative concentrations, the plume is assumed to meander evenly over a 22.5 percent sector. The hourly relative concentration values are calculated at the sector defined by the wind direction using the equation: 2.032 X/Q (14) e uD z where: X/Q " relative ground level concentration (sec/m 3 ) vertical standard deviation of the plume (meters) u ~ average wind speed (m/sec.) D ~ distance from the source (meters) 2 ~ 3~ 22 SL2-FSAR However, with the wake turbulent effect considered, the equation is revised to: 2.032 (15) X/Q 2 2 + cV uD where.' ~ building shape factor v ~ vertical height of the highest adjacent building The wake factor () is 2 limited, close to the source, to a factor of twice p F 2 . So ~ xfq3 <<. a z 2 + cQ 2 the equation is: 2.032 (16) 3 a m D (i.e., X/Q is calculated to be the larger of Equations (15) and (16) ). The total integrated relative concentration at each sector and distance is then divided by the total number of hours in the data base. 2.3.5.1.3 Methods of Depletion and Deposition Calculation Depleted X/Q values were computed by applying Q~)depletion factors provided in Figure 2 of the Regulatory Guide 1.111 (Rl) curves to the calculat'ed X/Q values. Relative ground deposition rates were calculated using the equation'. D/Q ~ RDep / (2 sin (11.25) x ) where: 'I D/Q ~ Ground deposition rate RDep ~ 'Relative ground deposition rate x ~ Calculation distance 2.3.5.2 Terrain/Recirculation Correction Factors There is a distinct difference in theory between the PUFF model and the straight-line trajectory Gaussian diffusion model. A continuous release is approximated by dividing the plume into a sufficient number of plume elements to represent a continuous plume in the PUFF model. Each element can be modified or advected independently in accord with the meteorological conditions (wind direction and speed, and atmospheric stability) of its 2 '"23 SL2-FSAR immediate location. This would account for the temporal and spatial variations in the airflow in the region of the site. The straight-line trajectory Gaussian diffusion model assumes that a constant mean wind transports and diffuses plume effluents in the direction of airflow at the release point within the entire region of interest, i.e., the wind speed and atmospheric stability at the release point are assumed to determine the atmospheric dispersion characteristics in the direction of the meari wind at all distances. Spatial and temporal(g~iations in airflow in the region of coastal sites should be incorporated .. This is accomplished by the use of terrain/recirculation correction factors (TCF). I The terrain/recirculation correction factors (TCF) were determined as the ratio between the puff-advection estimate and the straight-line estimate in the form: X (x,y) (18) TCF( ~ ) (x,y) where TCF( ) ~ terrain/recirculation correction factor at the point (x,y) X -(x,y) Q the annual average relative concentration at point P (x,y) using a puff-advection modeling scheme s ~ the annual average relative concentration 'at point ~ J (x,y) using ~ a straight-line modeling scheme. ~ 2.'3.5.3 Results of Lon Term Diffusion Estimates Annual, average relative concentrations (X/Q) were calculated according to Equations (10) (PUFF model) and (14) (straight-line model) on 8760 valid meteorological observation between August 1977 and August 1978 from the Lucie site. Terrain/recirculation factors were determined for each 't. sector and distance according to the procedure outlined in Subsection 2.3.5 2. These correction factors are presented in Tables 2.3-102 and ~ 2.3-103. Annual averages were computed for the 16 cardinal directions for the Exclusion Area Boundary (EAB) 0.97 miles, the Low Population Zone (LPZ), ', 35.0, 1.0 miles, and the following distances: and 45.0 miles. .5, 1.5, 2.5, 3.5, 4.5, 7.5, 15 0, ~ '5 The diffusion calculations were made for each year of data (Sept. 1976 to Aug. 1977 and Sept. 1977 to Aug. 1978) and the entire two year data base using the straight-line model. Depleted X/Qs and deposition rates were also computed for the same points. The results of these calculations were = adjusted by the TCF values for each (x,y) point and are presented in Tables 2.3-104 to 2.3-115. The maximum annual average X/Q at the EAB was 1.6E"06. The maximum at the LPZ was 1.4E-06. 2.3-24 SL2-F SAR
REFERENCES:

SECTION 2.3 U.S. Dept. of Commerce, 1976, Climato ra h of the U.S. No. 20-Climate of Fort Pierce, Florida, NOAA, Environment Data Service. 2~ U.S. Dept. of Commerce, 1977, Local Climatolo ical Data - Annual Summary with Comparative Data, West Palm Beach, Florida, NOAA, Environmental Data Service. 3e U.S. Dept. of Commerce, 1968, Climatic Atlas of the United States, NOAA, Environmental Data Service. 4; U.S. Dept. of Commerce, 1977, Climatolo ical Data - Annual Summary-Florida, NOAA, Environmental Data Service. 5~ U.S. Dept. of Commerce, 1963, Weather Bureau Technical Paper No. 2 Maximum Recorded U.S. Point Rainfall.

6. Hershfield, D.M , 1961, Rainfall Fre uenc Atlas of the Unites States for Durations of from 30 Minutes to 24 Hours and Return Periods of from 1 to 100 Years, U.S. Dept. of Commerce, Weather Bureau Technical Paper No. 40.

7~ Schriener, 1978, Personal Communication, NOAA, Office of Hydrology regardi:ng Hydrometeorological Report No. 51.

8. Bruce, J.P. and Clark, R.Has 1966, Introduction to H drometeorolo Pergamon Press, New York.

9. V.S. Dept. of Commerce, 1959, Climatography fo the United States No.

60-8, Climate of the States - Florida, Weather Bureau.

10. U.S. Dept. of Commerce, 1977, Climatography of the United States, No. 60"8, Climate of Florida, NOAA, Environmental Data Service.

Linsley, Rap Kohler, Mep and Paulhus, Jas 1964, A lied H drolog McGraw-Hill.

12. U.S. Army Corps of Engineers, 1958, Storm Rainfall in the United States Depth, Area, Duration Data.

13. Marshall, J.L., 1973, Li htin Protection, John .Wiley & Sons, New York.

14. Flora, S.D., 1956, Hailstorms of the United States.

15. Pautz, M.E., 1969, Severe Local Storm Occurrences, 1955-1967, U.S.

Dept, of Commerce, ESSA, Technical Memorandum WBTM FCST 12.

16. Alaka, M.Aas 1968, Climatolo of Atlantic Tro ical Storms and Hurri-canes, U.S. Dept. of Doss'aerce, ESSA Technical Report WB-S.

2. 3>>25

SL2-FSAR

REFERENCES:

SECTION 2.3 (Contsd)

17. Cry, G.Was 1965, Tro ical C clones of the North Atlantic, U.S. Dept.

of Commerce, Weather Bureau Technical Paper No. 55.

18. Thorn, H.C.Sas 1963, Tornado Probabilities,'onthly Weather Reivew Vol. 91.

19. Florida Power 6 Light Coos November 1, 1974, Final Safet Anal sis Re ort, St. Lucie Unit 1, Appendices 2E and 2F.

20. U.S. Dept. of Commerce, 1952-1973, Storm Data, NOAA, Environmental Data Service.

21. Fujita, T.Tas 1971, Characterization of Hurricanes & Tornadoes b Area and Intensit , SMRP No. 92.

22. Golden, Jes 1971, Waters outs and Tornadoes over Southern Florida, Monthly Weather Review, V99n2.

23. GOlden, Jep PerSOnal COmmuniCatiOn.

24. Korshover, Jas 1971, Climatolo of Sta natin Antic clones East of the Rock Mountains in the United States for the Period 1936-1970, U.S. Dept. of Commerce, NOAA, Technical Memorandum ERL ARL-34.

25. Holzworth, G.Cap 1972, Mixin Hei hts, Wind S eeds and Potential for Urban Air Pollution Throu hout the Contiguous United States, U.S.

Environmental Protection Agency, Office of Air Programs, AP-101.

26. Florida Dept. of Pollution Control, 1972, State of Florida Air Im lementation Plan, Tallahassee, Florida.

27. Stackpole, J.Das 1967, The Air Pollution Potential Forecast Pro ram, U.S. Dpet. of Commerce, Weather Bureau, Technical Memorandum WBTM-NMC 43 1970, The National Air Pollution Potential Forecast

'8.

Gross, Ees

~pro ram, U.S. Dept. of Commerce, ESSA, Technical Memorandum, WBTM-MNC 47 ~

29. American National Standards Institute, 1972, Buildin Code Re uire-ments for Minimum Design Loads in Buildin s and Other Structures, ANSI A58.1-1972.

30. U.S. Nuclear Regulatory Commission, 1972, Re ulator Guide 1.23, 1972, Onsite Meteorological Programs. Directorate of Regulatory Standards

31. U.S. Nuclear Regulatory Commission, 1974, Re ulator Guide, 1.4.

Assumptions used for Evaluating Radiological Consequences of a Loss of Coolant Accident for Pressurized Water Reactions. Directorate of Regulatory Standards. 2,3-26
SL2-FSAR

REFERENCES:

SECTION 2.3 (Cont'd)'2. U.S. Nuclear Regulatory Commission, 1978, Draft Re ulator Guide I.XXX. Atmospheric Dispersion Models for Potential Accident Conse-quence Assessments at Nuclear Power Plants. Office of Standards Development.

33. U.S. Nuclear Regulatory Commission, 1977, Re ulator Guide 1.111.

Methods for Estimating Atmospheric Transport and Dispersion of Gaseous Effluents in Routine Release from Light-Water-Cooled Reactors. Office of Standards Development.

34. Start, G.E. and Wendell, L.L., 1974, Re ional Effluent Dis ersion Calculations Considerin S atial and Tem oral Meteorolo ical Varia-tions. U.S. Dept. of Commerce,, NOAA, Technical Memorandum ERL-ARL-44.

35. Dames & Moore, 1977, PUFF - A Com uterized Puff Advection Model, Los Angeles, CA.

36. Gifford, F.A., Jr., 1961, Use of Routine Meteorolo ical Observations for Estimatin Atmos heric Dis ersion. Nuclear Safety, V4.

37. Slade, D.H., Ed, 1968, Meteorology and Atomic Energy 1968. U.S.

Dept. of Commerce, ESSA, Air Resources Laboratories, Silver Spring, Md.

38. Turner, D.B., 1968, Workbook of'Atmos heric Dis ersion Estimates.

U.S. Department of Health, Education, and Welfare, Public Health Service, National Air Pollution Control Administration, Cincinnati, Ohio. 2 ~ 3>> 27
SL2-FSAR TABLE 2.3-1 KaXIMUM RECORDED POINT RAINFALL VEST PALM BEACH, FLORIDA MINUTES HOURS Time Period 10 15 60 I 2 3 6 12 24 Amount (in inches) ;0.74 0.90 1.17 4.40 -!8.35 8.77 9.90 15.16 15.23 Date 7/19/58 9/16/59 5/11/58 4/17/42 4/17/42 4/17/42 4/17/42 4/17/42 4/17/42 Period of Record 1953-1961 1941-1961 1939-1961

Reference:

U.S. Dept. of Commerce, 1963, Veather Bureau Technical Paper No. 2-Maximum Recorded U.S. Point Rainfall, Environmental Data Service.' 00
SL2-FSAR TABLE 2.3-2 ESTIMATED RAINFALL FRE UENCY FOR THE ST. LUCIE SITE inches) Return Period (Years) Time Interval 10 '5 50 100 30 minutes. 1.6 1.9 2.3 2.6 3.0 3.3 3.5 1 hour 2.1 2.4 3.0 3.3 3.7 4.1 4.6 2 hours 2.4 2.9 3.6 4.3 4.7 5.4 6.0 r 3 hours 2.7 3.3 4.1 4.8 5.5 6.1 6.8 6 hours 3.2 3.8 5.0 '.0 6.8 7.6 8.5 12 hours 3.7 45'0 71 8.1 9.4 10.5 24 hours 4.3 5,4, 7.1 8.5 9.9 12.5

Reference:

Hershfield, P.M., 1961, Rainfall Fre uenc Atlas of the United States for Durations of from 30 Minutes to 24 Hours and Return Periods of from 1 to 100 Years U.S. Dept. of Commerce, Weather Bureau Technical Paper No. 40.

2. 3-29

SL2-FSAR TABLE 2.3-3 ESTIMATED PROBABLE MAXIMUM PRECIPITATION FOR FLORIDA Duration (hours) Amount (inches) 32.0 38.7 24 47. 1 48

~

72 '5.7

Reference:

Schriener, Personal Communication NOAA Office of Hydrology about Hydrometeorological Report No 51 ~ (June 1978) ~ ~

2. 3-30

SL2-FSAR TABLE 2.3-4 AVERAGE MONTHLY AND ANNUAL THUNDERSTORM STATISTICS State of Florida West Palm Beach Estimated Average Number of Average Number of((a) Lightning Strikes Surface Hail Thunderstorm Per Based on . Month (1943-1974)

)ps Km West Palm Beach Data (2)

Occurrences(b)(3) (1955-1967) January 0.1 - 0.0 0.2'.1 February - 0.2 0.1 March O.l - 0.3 1.2 April 0.2 0.5 1.5 May 0.4 - 1.3 2.5 June

'l '0 I'L 13 0.7 2.0 1.8 July 16 0.8 2.5 1.2 August 16 0.8 - 2.5 0.2 September 0.6 1.7 0.3 October 0.3 - 0.8 0.2 November 0.1 - 0.2 0.1 December 0.1 - 0.2 0.0 Annual 79 4.2 -12.4 8.9 (a) Define as day on which thunder is heard at station.

(b) 3/4-inch diameter and larger.

Reference:

(1) U.S. Dept.'f'ommerce, 1977; Local" Cl'imatolo ical Data - Annual Summary with Comparative Data: West Palm Beach, Florida'. Environmental Data Service. (2) Marshall, J.L., 1973, Li htin Protection, John Wiley and Sons, New York. (3) Pautz, 1969, Severe Local Storm Occurrences, 1955-1967, U.S. Dept. of Commerce, ESSA, Technical Memorandum WBTM FCST 12. 2~3 3 l
SL2-FSAR TABLE 2.3-5 = MONTHLY DISTRIBUTION OF TROPICAL CYCL'ONES AFFECTING THE FLORIDA PENINSULA (1900 1963) Tropical Tropical 'e Month Hurricanes Stotas ressions Total January 0 0 0 0 February 0 0 March 0 0 0 it 0 April 0 0 0 0 May 0 0 June 2 6, July ,2 6 Augus t 14 Se p tember 10 16 October 17 November 0 December 0 0 Annual 25 33 65

Reference:

Cry, G.W., 1965, Tro ical C clones of the North Atlantic Ocean, U.S. Dept. of Commerce, Weather Bureau Technical Paper No. 55. 2 ~ 3 32
SL2-FSAR TABLE 2.3-6 CUMULATIVE FRE UENCY OF WATERSPOUTS OCCURRING WITHIN 100 MILES FROM ST. LUCIE FOR VARIOUS DISTANCES OFFSHORE AND THE PROBABILITY AND RECURRENCE INTERVALS BASED UPON STORM DATA RECORDS FROM 1952 TO 1973 Distance from Land (miles) 0-2 0-4 . 0-8 0-25 Frequency 17 41 52 Adjusted Frequencies By Apportioning 126 of the 27 58 140 178 Unknown Observations Area Examined (square miles) .400 800 1600 5000 Probability (10 ) 4.60 4. 94 5.97 ~ 2.40 Recurrence Interval (years) 2174 2024 1675 4167

Reference:

U.S. Dept. of Commerce, 1952-1973, Storm Data, NOAA, Environ-mental Data Service. 2~3 33
SL'2-F SAR

\

TABLE 2.3-7 a MONTHLY DISTRIBUTION OF WATERSPOUTS WITHIN 25 MILES OFFSHORE Booth Total 5 a a A 14 16 51 N 1 A - 19 30 0 17 N

.0 TOTAL 178

Reference:

U.S. Dept. of Commerce, 1952-1973, Storm Data, NOAA, Environmental Data Service. 2.3-34
SL2-F SAR TABLE 2.3-8 ONE MINUTE WIND SPEED RECURRENCE INTERVALS WEST PALM BEACH, FLORIDA Recurrence Interval Wind Speed (Years) (m h) 50 10 80 100 50 110 100 120

Reference:

Americaq National Standard, 1972, Building Code Requirements for Minimum Design Loads in Buildings and Other Structures, ANSI A58.1-1972. 2.3-35
SL2-FSAR TABLE 2.3-9 LONG TERM AVERAGE WIND SPEED AND PREVAILING DIRECTION AT WEST PALM BEACH, FLORIDA Averag'e Prevailingb Month S eed (m h) Direction 9.8 January'ebruary lg.3 SE March 10.7 SE April 10.9 May 9.6 ESE June 8.0 ESE July 7.5 ESE Augus t 7.6 ESE

'eptember 8.6 ENE Oc tober 10.0 ENE November 10.0 ENE December 9.9 NNW Annual 9.4 ESE a) Pe'riod of Record: 1942-1977 b) Period of Record: 1963-1977

Reference:

U.S. Dept. of Commerce, 1977, Local Climatological Data Annual Summary with Comparative Data: West Palm Beach, florida< NOAA, Environmental Data Service

2. 3-36

SLX-FSAR TABLE 2.3-10 AVERAGE MIND SPEED AND PREVAILING DIRECTION AT THE ST. LUCIE SITE Average Prevailing Month Direction January 8.1 February 7.6 March 7.2 SE Apr il 7.8 ESE May 6.7 ESE June 6.'3 SSE July 5.8 SSE August 6.5 ESE September 5.1 SE October 7.4 November 6.9 N December 7.8 Annual 6.9 SE Period of Record: September 1976 August 1978 2 ~ 3 37

, FSAR iLE 2>>3-12 0

FLORIOA PO((ER AND LIGHT Ca ~ ST ~ LUCIE UNIT 2 OATA PER(0(t (YR - JilLIAN GAY) - 76245 TO 78243 THHESHOLO OF ANEt(OHETEI) (HPH) ~ 58 ulNO DIRECTIOt( PERSISTENCE - PASOUILL SAN 1 SECTOR PERSISTENCE CONSECUTIVE HOURS SECTOR 3 4 5 6 7 8 9 10, ll 12 13 14 15 16 17 '8 19 20 21 22 23 24 >24 NNE 19 12 5 3 6 0 0 0 0 0 0 0 0 a a o NE 23 14 5 4 2 5 1 I 0 0 0 0 0 '00 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ENE 26 6 8 2 I 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E 19 3 5 2 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0. 0 0 0 0 0 EsE 16 15 3 6 0 1 3 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 sE 16 10 6 2 2. 2 0 0 0 0 0" 0 0 0 0 0 0 0 0 0 0 0 0 0 ssE 8 13 6 5 8 3 2 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SSM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S'I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 t(S l( 7 2 I 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 8 1 2 1 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lt t(tt 10 3 2 3 0 0 0 0 0 0= 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NII 7 2 5 3 I 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0, 0 0 NWH 9 5 3 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N 18 14 3 5 4 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AVERAGE 'WIND SPEEl) (H/SEC) CONSECUTIVE HOURS SECTOR 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 i24 N t(E NE 3 '3 3 '1 3.29 4.17 3 '3 3.29 3.37 3.84 3.53 '0 '7 5.20 3 0~ 3>>46 0~ 0~ 0 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 0~

~ 0~

0~ 0~ 0~ ( 3 '3 3 23 3 '6 2 86 2 '1 3 '5 6 '7 3 ~ 0~ 0~ Et>E 0~ 0 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0>> 0~ 0~ 3>>41 F 88 3 '4 3 '4 0>>

~

E 0~ 0~ 0~ 0~ 0~ 0~ 0>> 0~ 0>> 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 3 '4 3 '0 3 '4 ? 99

~

ESE 0~ 2>>75 F 17 3.03 0~ 0>> - n~ 0~ 0~ 0~ a. a. 0~ 0~ 0~ a. a. o. a. o. 20 4 la 3 '0

~

3.44 3.70 3>>58 0~ 0~ 0~ 0~ 0 0>> 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 4 nn 4 '6 4.4n 4.51 4>>81 5.26 4 '6 '4 4 ~ ~ SE'sc 4 0~ 0~ 0~ 0~ 0>> 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ S F 77 0 ~ 0 n~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0>> 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ ssu 0 ~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ Si( 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ a. o. t(SM 4 05 4 3.70 2.23

'7 5.92 0.

5 36 4 '9 0~ 0~ 0~ 0~ 4 58 0 ~ 3 80 0 ~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0>> 0~ 0~ 0~ 0~ 0~ 0~ 0~ Oi 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

'l ~

WN'Lt 3.58 3.48 F 46 4 60 0>> 0~ 0 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~' 0~ NI4 NNI4 3 '3 4 '0 3 '3 4 '5 4 4.la 4 '8 ll F 08 4.53 6~ 0~ 0 0~ 0 0>> 0

~

0~ 0~ 0~ 0~ 0 0~

~ 0~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0>> 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

~

0~ N 4.00 4 '0 ln 4 79 4>>43 n.

~ ~

5 27 5 '6

~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0>> 0~ TOTAI NO ~ (tf OOSERVAT Int(S 17520
SL2-FSAR Table 2.3-13 FLORIDA POWER AND LIGHT CO ST+ LUCIE UNIT 2 DATA PERIOD (YR - JULIAN DAY) 76245 TO 78243 THRESHOLD OF ANEHOHETER (HPH) 58 Mlt)O DIRECTION PERSISTENCE PASOUIL). <<8>> 1 SECTOR PERSISTENCE CONSECUTIVE HOURS SECTOR 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 >24 NNE 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NE 5 0 0 0 0 0 0 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ENE 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

. ESE 4 1 7 2 0 0 0 . 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I 0 0 0 0 0 0 0 SSE ~ 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .0 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SSM 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SM 1 '

0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MSM 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M

'MN'M I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NM NNM 1

1 9 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0, 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N 1 I C) AVERAGE MIND SPEED {H/SEC) CONSECUTIVE HOURS SECTOR 2 3 4 5 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 >24 0 0~ 0 0 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ NNE 4 ~ 40 0 ~ 0 0 0 Oa 0 ~ 0~ 0 ~ ~ ~ ~ ~ NE ENE 3 '6 2 91 0 ~ 0 ~ 0 0~

~ ~ 0 0 ~, ~ ~

0 0

~ ~ ~

0 0~

~ 0 0 ~ ~

0. 0~ n. 0~ 0. 0~ 0~ 0~ 0~ 0~ 0 0~

~ 0~

0~ 0 0~

~ 0 0 ~ ~

0~ 0~ 0 0'

~ 0~

0~ 0~ 0 ~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ E 3 ~ 13 0 ~ Oo 0 ~ ~ ~ 0~ 0~ 0~ Oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0 ~ 0~ 0~ 0~ ESE 3 ~ 35 3 AD )3 0 ~ 0 0 0 ~ SE 3 ~ 3.58 16 3 n.

'0 0 0. ~ 0 0 ~ ~ 0 0 ~ 0~

0 0 0

~ 0~

0. 0~ O. 0~ O. 0~ n. 0 0

~ ~

0~ 0~ 0~ 0~ 0~ 0~ Ot 0~ 0~ 0~ 0~ 0~ 0 0~

~ 0~

0~ 0 0

~ ~

0 0~

~ 0~

0~ 0~ 0~ SSE ~ ~ ~ 0 0 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ Oi 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 5 0 ~ Oe 0 0 ~ 0 ~ ~ ~ 0~ 0 0~ 0 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ SSM 4 13 0 ~ 0 0~ 0 ~ ~ ~

'2 8 '4 ~ ~

0~ 0~ 0~ 0~ 0~ 0~ 0~ SM 7 0 ~ 0 ~ 0~ 0. 0 ~ 0 ~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ MSM 0 ~ 0 ~ Oo 0 ~ 0 ~ 0~ 0~ 0 ~ 0~ 0~ -0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ Oi 0~ 0 ~ 0~ 0~ n. 0~ Oo 0~ 0 ~ 0~ 0~ 0 ~ 0 ~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ Oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ MNM 2oOI 0~ 0~ 0~ 0~ 0~ ~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ NM 2 ~ 01 0~ 0~ 0~ ~ 0~ 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ NNM 4 ~ 02 0 ~ 0~ 0~ 0~ 0 ~ 0~ 0~ ~ 0~ 0~ 0 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~. 0~ 0~ N 4 ~ 00 F 85 0~ 0 ~ 0~ 0 ~ 0~ 0~ 0 ~ ~ ~
SL2-FSAR TABLE 2+3-14 FI.ORIOA POMER ANO LIGHT Ca+ ST LUCIE uNlT 2 OATA PERIOO lYR - JULlAN OAY) 76245 TO 70243 THRESHOLO OF ANEHOHETER IHPHI 58 MIND 01RECTlON PERSISTENCE PASQUILL VCN 1 SECTOR PERSISTENCE CONSECUTIVE HOURS sEcTOR ~ 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 +24 NNE 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NE 4 1 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ENE 4 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E 5 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 EsE 8 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SE 4 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ssE 6 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S 0 1 0 0 0 0 0 .0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SSI4 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SM 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NSM 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 if 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 VO'M 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NQ 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NNV 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ' 0 0 0 N 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AVERAGE MIND SPEED {H/SEC) CONSECUTIVE HOURS SECTOR 2 3 4 5 '7 8 9 10 11 12 13 14 15 16 17 18 '9 20 21 22 23 24 i24 NNE o. e.se o. ao 0~ 0~ 0~ 0~ 0~ 0~ Oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ NE 3 '7 3 '8 0~ 0~ 0~ a. o. -0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ ENE 3 '1 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ . 0~ 0~ 0~ 00 0~ 0~ 0~ 0~ 0~ 0~ 3 '6

~

E 0~ oo 0 0~ Oo 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 2 '1 3 '5

~

ESE 0~ 0~ 0~ 0~ 0~ 0~ 0'o 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

'1 2 '8 ~

SE 3 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ SSE F 50 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~' 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ S 0~ 5 36 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ ~ 0~ a. o. 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0, SSM 0~ 3 l30 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ SM 4 ~ 25 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ WSV 4 ~ 36 0 ~ 0~ 0 ~ 0~ 0~ 0~ 0~ a. 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ V 3 ~ 58 0 ~ 0~ 0~ 0~ 0~ 0~ a. 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ oo 0~ 0~ MNW 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ oi 0~ 0~ 0~ NV NNM 0~ 3 '5 '72 4

'8 0~

0~ 0~ 0~

~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ Oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ Oi N Se27 F 80 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ TOTAL NO ~ Of OBSERVATlONS ~ 17520
J SL2-PS. TABLE 2 '"15 FLORIDA POMFR ANO LIGHT CO ST ~ LUCIE UNIT 2 DATA PERIOD (YR - JULIAt) OAY) - 76245 TO 78243 THRESHOLD OF ANEHONETER (tIPH) - F 58 MIND DIRECT ION PERSISTENCE PASQUILL IIOII 1 SECTOR PERSISTENCE CONSECUTIVE HOURS SECTOR 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 +24 0 0 NNE NE EIIE 13 22 49 19 6 8 4 4 9 0 2 0 0 1 I I I 1 0 0 o 0 0 1 0 0 o 0, 0 0

.0 0

0 0 0 0 0 I 0 ' 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 43 IS 3 2 0 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 F. eo 28 13 9 0 I 0 0 2 0 . 0 0 0 0 0 0 0 0 0 0 0 ESE 5 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SE 56 18 6 2 - 0 1 23 I 0 0 0 I 0 0 0 0 0 0 0 0 0 0 0 0 SSF. 52 7 2 0 0 ' 6 I 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 5 33 11 10 1 1 58 25 12 3 5 I 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S S'N 11 I I 0 0 0 0 0 0 0 0 0 0 0 0 0 S'N 48 9 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MSM 16 4 I o 0 0 0 0 0 0 0 0 0 0 0 19 2 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M 18 5 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0-MNM 8 4 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NM 35 14 1 0 34 13 9 9 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 Nt)N 1 1 1 N 18 9 6 3 3 0 I ' 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 AVERAGE MIND SPEED IH/SEC) COtISECUT IVE HOURS SECTOR 2 3 4 5 6 7" 8 10 ll 12 13 14 15 16 17 18 19 20 21 22 23 24 i24 2 '6

'7 4.34 3+94 0 ~ 3.58 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~

NNE NE 3 3 ~ 42 5.85 2.23 5 0~

'4 4 60 0~

0 0~ 0~ 0~ 0~ 0~ 0~ 0 0~ 0~ 5 '8 0~ 0~ 0~ 0~ 0~ oo 0~ 0 ~ 0~ 0~ ENE 3.70 3.56 3.59 3 3.22 3

'6 '8 '4n.

3 F 58 e.o7 lo 0 ~ 0 0

~ 5+ 31 0 ~

3 21 0 0~ 0 0~ 0~ 0 0~

~ 0~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0 ~ 0~ 0~ 0~ 0~ ESE E 3.14 3.27 3.55 3 '9

'951 3 '5 0~ 3 '8 2 '6 ~

0~ 0

~ ~ ~

2+93 0~

'4 3 '9 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

SE 3.05 2.74 3.13 3 F 04 3 '2 4 bio 2,58 2+iI 0~ 0~ 0~ 0~ 0 0 0~

~ 3 0~

0~ 0~ 0~ '0

. 0~ ~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 3.35 4.28 3.92 'o 5 '6 SSE ~ 4 0~ 5 14 5 14 6 ~ 35 0 ~ 0~ 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 9S 5 '2 3.97 4 '2 5 ~ 3.59 '2 4.11 3.90 3 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0 ~ 0~ 0~. 5 '0 3

'2 3 '6 5 53 SSM 3 '3 3.87 4.13 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~

SM 3 0 ~ oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ MSlt 2.59 4.73 4.25 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 2.95 79 2.35 Oo 0 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ N 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

?,46 3.61 3 ~ IFI 0~ 0~ 0 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~

M I IN NN 3. 22 3 3 42

'6 3,11 4 ll 2 53 3~77 3 '9 3.95 4 '2 3 '8 0 ~ 0 3 80 ~ 0 0 ~ 0~

3 '6 0~ 3 ~ 49 0~ 0~ 0~ 0~ 0 0~

~ 0~

0~ 0 0~

~ 0~

0~ 0 ~ 5,12 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ NNM tI 3.54 4 '8 4 '3 F 08 4+54 0 ~ 4 '4

~

0 ~ 0~ 0~ 4 '2 4 '1 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ TOTAL NO+ OF OBSERVATIONS 17520
SL2-FSAR TAULE 2 ~ 3-16 FLORIDA pO)tER aNO LIGHT ST ~ LUCIE Ot)IT 2 Oala PER IOI) IVR - JOLIAN OAT) - 76245 TO 78243 Tt)RFS))OLO OF attEHOHEIER (HPlt) - ~ 58 vlttD OIRECIIO~ I ERSlsTENCE - PasoulLL>>E>> SECTOR PERSISTFNCE COt ) SE CO I I VE HOUR S SEC IOR 3 4 5 6 7 8 9 10 ll 12 13 14 15 16 17 18 19 20 21 22 23 24 >24 NNE 23 10 5 4 3 0 2 I I 0 0 I 0 0 0 0 0 0 0 0 0 0 0 0 NF. 19 18 8 Q 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Et)E 39 I8 S 8 5 5 2 I 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 37 24 10 7 4 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 65 8 EsE SE 6? 38'922 37 15 6 12 3 6 5 5 1 4 I 0 1 I 1 I 1 1 I 0 I 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S5E 67 41 IB 9 5 I 3 3 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5 39 18 8 9 1 3 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 559 49 21 8 4 4 l 0 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 5)t 71 18 17 6 4 Q 1 2 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0

)ts)t .54 21 5 5 0 0 1 0 2 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 M 38 II 8 4 3 I 0 0 0 0' 0 0 0 0 0 0 0 0 0 0 0 0 0 8tl tt 60 8 9 3 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N)t NN)t 56 52 22 20 14 15 5

8 ll9 1 2 2 1 1 0 1 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 tt 30 15 8 6 3 1 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AvERaGE vltto spEED INrsEc) COt<SECtt I IVF. ))OILERS SECTOR 2 3 4 5 6 7 8 9 10 ll 12 13. 14 15 16 1'7 '8 19 20 21 22 23 24 i24 NttE NE 2it)6 2.8? 2o 77 2.66 3.24 4 12 3.32 3.65 3.65 0. Oo 3.63 4.22 5.99 0 ~ 4.20 1.68 0 ~ 0 4 '6 0~ 0 5 0

'3 0~

0~ 0~ 0~ 0~ 0~ 0~ Oi Oi 0~ 0~ Oi 0~ 0~ 0~ 0~ 0~ Oe 0~ 0~ 0~ 0~ 0 ENE E 3.13 3.32 3.10 5 ~ 14 4 3.44 4.00 2.75 2 ')4

'0 3.20 4.99 3.69 3 I ~ 72 0 ~ 0~ '8 0~

0~ 5.42 0 ~ 0~ 0

~ ~

0 Qo

~ ~ Qo 0~

Qo 0~ 0~ 0~ 0~ Oe Qi 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0 0~ 0~ ESE 2.72 2.90 64 3.?2 3 ~ t)8 2 ~ 41 3.69 4.27 4 ~ 43 4 ~ 51 3 ~ 17 3+06 3 93 0 ~ 0~ 0~ Oi 0~ 0 0~ 0~ 0~ 0~ 0~ sE SSE 2.29 2.32 2.57 2ob2 ? 70 2.83 2.4) ?.76 3.13 2.40 3.77 3.ul 3 I 92 3.11

'2 2 '2 0~

2.86 3.45 3+72 3 0 0~ 0

'6 2.97 3 0~ 0 '4 ~

0~ 0~ 234 0~ 0~ Oi 0~ Oi 0~ 0~

~

Oi 0~ 0~ Oo 0~ 0~ 0~ Oo 0~ 0~ 5 3.01 2.H6 3. )5 3. 5'1 2 09 2.91 n. Oo 0~ 0 0 0~ 0~ 0 0 Oi 0~ 0~ 0~ 0~ 0 0~ 0~ Ssv Stt 3.45 3.24 3 2.o9 2.38 2.80 3

'4 3 98 4 '7 'a F

4

'9 5 '4 4 '4 2+88 0

0 ~ 3 '0 0 ~ 0~ 4 ~ 78 0 ~ 0~ 0~

~

0~ 0~

~

0~ 0~ 0 0

~ 0~

Oi

~

0~ 0~

~

Oi 0~ 0~ 0~ 0 0~

~ 0~

0~ 0 0

~ 0~

0~

~

0~ 0~ 0~

~ ~ ~ 0~

Ws)t 2. IB ? 43 2+53 I 0~ 0 3.52 0~ I 34 0 ~ 2 ~ 31 0 ~ 0~ 0~ 0~ 0~ 0~ Oo 0~ 0~ 0~ Qi 2.02 2.1 I 2. 7t) 3 2.2l I-'94 2 '2 '6 '7 2.c)7 2.4t) 1.17 3

~

I.40 0 ~ 2.29 0 0~ Oo 0 0 ~ 0~ 0~ 0~ 0~ 0 0~

~ Oi 0~

Oe 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ Q~ 0~ 0~ Q~ 0~ MN'et 0 0~ 0~ 0~ 0~ 0~ 0~

)N Nttel 2.67 2.78 2 2 76 2-95 3.54 2 '9 '2 2 95 3.18 4.02 F 85 2 78 3.51 2.74 3 43 ~

0

~ ~

3.31 Oi

~

3 ~ 02 0 ~ 0~ 3 '9 0~ 0~ Qi 0~ Qa 0~ Oe 0~ 0~ Oi 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ N 2.92 2.79 3.62 4 '2 5.07 1.53 2 '1 0

~ ~ 0 ~ 0~

Q~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ TO'IAL ttO ~ OF OBSERVATIONS 4 17520
SL2-TABLE 2+~-17 FLORIDA PoltER AND LIGHT C00 ST ~ LUCIE UNIT 2 DATA PERIOD (YR - JULIAN DAY) 76245 TO 7B243 THRESHOI.D Of ANEMOMETER (MPH) F 58 It lt(D DIRECT ION PERSISTENCE PASOUILL ttFtt I SfCTOR PERSISTENCE CONSECUTIVE HOURS SFCTOR 2 3 4 5 6 7 B 9 10 ll 12 13 14 15 16 17 IB 19 20 21 22 23 24 +24 NNE 3 1 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 0 NE 1 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ENE 0 I .0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 0 0 0 0 0 0 0 0 0 E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0. 0 0 0 0 0 0 0 0 0 Esf 3 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SE 1 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SSE 7 3 0 0 0 0 0 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -0 S 6 1 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SSlt 6 3 I 1 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SIt 10 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ItSM 10 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M 3 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ItNIt 9 0 2 l 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NQ 13 1 2 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 0 0 0 Nt4It 12 6 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 LA I 4 0 0 0 0 0 0 0. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AVERAGE MIND SPEED IM/SEC) CONSECUTIVE HOURS SECTOR 2 3 4 5 6 7 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 +24 NNE 1 ~ 56 1.94 2.01 0 ~ 0~ 0 ~ 0~ 0~ Oo 0~ 0~ 0 0~ 0 ' 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ Nf 2+91 I 49 0 ~ 0~ 0~ 0~ 0~ Oo 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0 ~ ENE 0~ F 13 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0 ~ . 0~ 0~ 0~ 0~ 0~ 0~ E 0 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0 0~ 0~ 0 0~ 0~ ESf Sf

~

I ~ 79 2 2.91

'3 1.04 0~

0~ 0~ 0~

~

0~ 0~ 0~ 0~ Oo 0~ 0~ 0~ 0~ 0~ 0 0~

~ 0~

0 Oo 0 0~ 0~ 0 0~

~ Oo 0~ ~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

~

0~ 0~ 0~ 0~ 0~

~

0 ~ 0~ Oo 0~ 0~ 2 '3

~ ~

SSE 2 20 0~ 0~ 0~ 0~ 0~ 1 ~ B4 0 ~ 0~ 0 ~ 0~ , 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 2.11 3.13 34 n. 0 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 00 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 5SIt S SM 2 83 1 ~ 1.64 1+12 2 ~ 23 2.16 84 1 79 2.79 0 ~ 0~ 0 0~ 0~ 0~ 2 0

'3 ~ ~

0~ 0~ o. Oe n. 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 0

~ ~

0 0~

~ ~ 0~

0~ 0~ 0 ~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 0

~ ~

ItSM 54 1 ~ 49 0 ~ 0 ~ 0~ 0~ 0~ 0 ~ Oo a. o. 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ It I ~ 42 0 ~ 1+79 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ lgttit i+65 0 ~ 1 ~ 34 I 79 0 ~ 0 0~ Oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ '0 ~ 0~ Nlt NNIt I ~ 05 2+53 F 07 I ~ 87 F 01 2.57 n. 0~ 2 0

'1 0~

Oi

n. 0~

0. 0~ 0~ 0~ Oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~

~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

N F 01 0 ~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ . 0~ 0~ 0~ 0~ 0~ 0~ 0~

~ Oo 0~

TOTAL NO OF OBSERVATIONS

-e

SL' R TABLE 2 ' 18 FLOR I DA POWER AND L I GHT CO ~ ST. LUCIE UNIT 2 DATA PERIOD (YR - JULIAN DAY) 76245 TO 78243 THRESHOLD Of ANEHOHETER (HPH) F 58 WIND DIRECTION PERSISTENCE - PASOUILL ttGtt 1 SECTOR PERSISTENCE CONSECUTIVE HOURS SECTOR 2 3 4 5 6 7 8 9 10 ll 12 13 14 15 16 17 18 19 20 21 22 23 24 >24 t4NE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NE 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Et4E 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 -.0 C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ESE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SSC I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 S 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SSW 0 I 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SIN 2 1 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 WSW 6 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 WNW 1 1 I 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ttlt 13 2 2 I I 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NNW 3 0 0 n 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AVERAGE WIND SPEED (H/SEC) CONSECUTIVE HOURS SECTOR 3 4 . 5 6 7 . 8 9 ..10 ll 12 13 14 15 16 17 18 19 20 21 22 23 24 ~24 NNE 0~ 0~ 0 ai 0 0~ 0~ 0 0~ 0 NC 0~ 2 '3 0

~ ~ 0~ 0 ~ ~ 0 ~ 0~ 0 ~ ~ 0~

0 0 ~ 0

~ ~

0 0

~ ~

0 0~

~ 0~

aa-0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0 ~

,0 ~

0~ 0~ 0~ ENE ESC E 0~ 0~ 0~ 0 0 0

~ 'o0 0~ ~ 0~

a. 0 n. 0 ao

~

0. 0 0

~

0 0~ 0 0~ 0~ 0~ 0 0

~

0 0 ao

~

0~ 0 0~

~

0 0

~ ~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 0

~ 0~

ao 0 ai

~ ~ ~ 0~ ~ 0~ 0 ~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~

SE 0~ 0~ at 0 ~ 0 0 ~ 0~ 0 ~ 0~ 0 ~ 0~ 0~ 0 ~ ao 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0 ~ 0 ~ 0~ SSC 45 0 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ a. 0. 0~ ' 0~ 0~ F ~ 0 ~ 0 ~ ~ 0 ~ 0~ 0~ 0 ~ 0~ S 0 0~ 0. 0 0~ 0~ 0~ 0 0~

~ '9 ~ ~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0 0~ ,0 ~ 0 0~ 0~ 0~ 0~ ~ ~ ~ ~

SSW 0 ~ 99 1 90 0 ~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ SW 1.79 1.34 0. 0~ 0~ 0~ 0 ~ 0~ 0~ 0 ~ 0 ~ 0~ 0~ 0 ~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0~ 0 0~ 0~

'WSW I ~ 71 1 ~ 34 0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0 ~ 0 ~ 0~ -0 ~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~

Iol2 0. 0. 0~ 0~ 0~ 0~ 0~ 0~ a. n. 0~ 0~ 0~ 0~ 0 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~ WNW I 42 I 3499.99 1 43 0. I o 40 0 ~ 0~ 0 ~ 04 0~ 0~ 0 ai 0 ~ 0~ 0 0~ 0~ 0~ 0 0~ 0~ 0 ~ t)W 1 97 1 ~ 86 1 ~ 62 1 ~ 16 1 ~ 64 0 ' 99 99 0 ~ n. 0. n. 0~ ai 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ Nt4W 1.79 0. a. 1 ~ 25 2 16 0 ~ ~ 0~ 0~ 0~ 0 ~ 0~ Oo 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 00 t4 1.34 n. 0. 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ TOTAL NO OF OBSERVATIOt)S 17520
SL2. C"

~

TABLE 2 '-19 FLORIDA POWER AND LIGHT CO ST ~ LUCIE UNIT.Z DATA PERIOD IYR - JULIAth DAY) - 76245 TO 78243 THRESHOLD OF ANEMOHETER (HPH) - F 58 WIND DIRECTION PERSISTENCE - PASOUILL Nstt I SECTOR PERSISTENCE CONSECUI IVE Hot)RS SECTOR 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22, 23 24 F24 NNE 27 8 6 7 4 0 2 I 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 NE 21 18 8 6 0 5 l. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Et)E 42 20 5 8 6 5 2 1 0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 E 43 25 11 7 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ESE 67 37 22 14 9 5 6 1 2 I I I 0 0 0 0 0 0 0 0 0 0 0 SE 67 4n 30 5 12 5 5 0 I I 0 I 0 0 2 0 0 1 0 0 0 0 0 SSE 72 46 ~ 24 10 5 2 3 4 2 0 0 0 0 0 - 0 0 0 0 0 0 0 0 0 0 S 47 19 12 . 10 I 4 I 0 0 0 0 0 ' 0 0 0 0 0 0 0 0 0 0 SSV 60 22 13 7 5 2 I I 0 0 I 0 0 0 0 0 0 0 0 0 0 0 0 0 SV 84 23 17 5 7 1 I 2 I 0 0 0 0 0- 0 0 0 0 0 0. 0 0 0 0 MSM 67 29 6 6 0 0 0 2 0 1 0 0 0 0 0 0 0 0 0 0 0= 0 0 47 12 10 5 QNN Nit 75 70 l6 33 12 16 6 9 3 3 8 1 4 7 0 6 0 I 3 0 0 0 0, 0 0 0 0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NNV 64 26 20 10 12 2 1 0 1 0 0 2 0 0 0 0 , 0 0 0 0 0 0 0 N 35 18 7 6 4 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AVERAGE IlltlD SPEED IH/SEC) CONSECUTIVE HOURS SECTOR 2 3 4 5 6 7 8 9 10 ll 12 13 14 15 16 17 18 19 20 21 22 23 24 i24 NNE 2 '3 2 '8 2 72 2 bl 3 '5 '4 3 '368 22 5 '9 96. 0 4~ 0 0~ 5>>43 0 ~ 0~ 0>> 0~ 0~ 0~ NE ENE 2 '5 3.26 3.79 3>>II 2>>94 5 14 3.20 3 97 3 0 ~ 3 4

~ '8 '9 3 69 3 '8 1 0~ 0 ~ 4 ~ ~

5.42 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0. 0~ 0 ~ 0 0~

~ 0~

0~ 0~ 0~ 0~ 0~ 0~ 0~ ESE E 3 35 3 '6 90 2.65 2.86.2 '7 3 ? 75 3 26 2 '4 1.72 0 3 '4 F 05 3 '2 4 '7 0~ 0~ 0~ 4~ 4 '2 0~ 0~ 74 4 '1 F 17 0~ 0~ 0~ 0 0~ 0~ 3 06 3 ~ 93 0 ~ 0~ 0~ 0 0

~ ~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 00 0~ 0~ 0~ 0~ SE SSE 2 30 ? F 57 2 't) 2.27 2 34 2.56 3 ~ Ol

? ~ 83 2 '0 3 '9 01 3 82 F

2+40 2>>30 3>>ll 2 27 2 86 0 ~ 3 45 3 72 0 0~ 2.97 0~ 0~ 0 ~ 0~ 2>>70 0~ 0~ 0~ 0~ 0~ 3 '9 0~ 0~ 0 0>>

~ 0~

0~ 0~ 0~ 0~ 0 ~ 0~ 0~ 0~ 0>> 0~ 0 0~ 0>> 0~ 0~ 0~ 0~ S 2 '6 23.ll 3.25

't) 07 41 2.09 3 3 3.42 2.8n 3.98 3.98 3. 13 3.6199.99 ~

2 ~ 48 0 ~ F 88 0 ~

0. 0

~ ~

F 09 0>> 0~ 0~ 0~ 0~ 0

~ ~ 0~ 0~ 0~ 0 ~ 0~ 0~

0~ 0~ 0 0~ 0~ 0>> 2 48 F 27 2 77 I 63 3 '9 SSW 0 0~ 0~ 0 0~ 0~ 0 0~ 0~ S'N MSM F 08 2 '7 2..23 61 I

~

0 F 07 4 64 0 3.52 3.90 0 4 '834 0 0

~ ~ 0~

2 '1 0~ 0~ 0~ 0~ 0~ 0~ 0~

~

0 0~ 0 0~ 0~ 0

~ ~ 0~ 0 ~

0~ 0~ 0~ 0~

~ ~ ~ ~ 0~ 0~ 0~ 0~ 0~ 0~ 0 ~ 0~ 0~

I 87 F 04 2.56 ? 81 2.48 1.40 0. 0>> 0~ 0 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 68 2 '6 I 68 0~ 0 0 MtN 14 Nll F 08

~ ?.54 2,62 2 '1 3 '8 1 ~ ~ 3 '0 I ~ 77 2>>29 2 2>>99 8 ~ 34 2 63 '3 0~ 0~ ~

0~ 0~ 0~ 0~ 0~ 0~ 0~

~

0~ 0~ 0~ 0~ 0~

~

0~ 0~ 0~ 0~ F 02 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ NNM N 2 58 ? 67 3.3? ? 62 3 05 2.73 2.65 3.64 4.01 4.82 1.53 2.91 3 51 2 12 n. 0~ F 31 3 0~ 0~

'3 0~

0~ 0 0~

~ 2 0~ '4 0~

0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0~ 0 0~

~

0~ TOTAL NO ~ OBSERVATIONS +zo
( SI.2-FSAR YAULE 2.3-20 t'I,tltttlta Inwftt at)I) LIEUII co. SI I IIC It IINI1 2 I)AIA I' lt lt)0 I Vlt - .IIII. I AN l)AY) - 7624S fo 7t)243 Ittt<ESIII)I.A nt attt'IIOIIEIEI<<ttt>>II - .50 WIN)) I)lttEC1ION I'tIISISltNCE' f'ASONILL ALL I StCIOII I'fl3SlbTENCE CnttSEI'III lvt IIAIIII'5 bt Clots 3 6 1 8 9 10 II 12 13 14 15 L6 17 18 19 20 21 22 23 24 i 24 NtIt b2 I I 20 l2 I 7 4 3 2 2 ? 0 .o I 0 0 0 0 0 0 0 D 0 NE Sn 24 16 1 I) 3 2 3 I I 2. I 0 1 a o 0 0 0 0 tttE E Ua) a)3 4 50 I 22 20 ln ll 16 9 5 7 2 4 3 I I 3 0 0 0 0 0 I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 I 0 0 tsE ln2 52 40 34 24 4 7 5 8 2 . 2 2 0 0 1 1 1 2 0 SV lln t2 40 16 2L 11 ll 5 2 2 I 0 3 0 1' 0 0 0 2 2 bSE 75 52 23 16 13 lo 7 6 I o 2 0 0 a 2 0 0 0 0 0 0 I b I t) 29 I a) IS 9 3 2 3 0 0 0 0 0 0 0 0 0 0 0 a bSw I lb 52 20 22 lo 6 3 S 2 0 o a o 0 0 0 D 0 0 0 0 0 0 SM )u 3') 33 17 12 7 2 4 3 0 2 0 0 a I o 0 0 0 0 0 0 0 ItbW I)7

'l I 13 ll o 0 0 2 I

0 0 0 0 0 1 0 0 0

, 0 0

0 0 o 0 a 0 0 0 w 21 20 5 2 3 I n ~ 0 o 1 o 0 0 0 wllw la 1 28 20 8 8 4 2 4 I 0 0 0 0 o 0 0 0 0 0 a o 0 0 0 I4W ln5 40 29 16 Il 2 3 2 I I ' I 0 0 0 I 0 D 0 0 0 0 IIIIW I'J 46 20 2l LD 5 4 3 0 3 2 I D 0 1 1 0 0 0 0 0 II bo 35 21 14 0 IJ 0 2 3 5 3 I 1 2 0 1 0 0 1 o 1 o 0 Avt'ltat t ulNI) SI t'EA IH/SE CI CIINSI CIII I VI IIOIIIIS StClOll 'S ta 7 IO II 12 13 14 15 16 17 18 19 20 21 22 23 24 i24 I'lIt I ~ II 3. I 8 2 'J9 3. 31 ~ 3 ~ 06 3 60 3

'S '0 3I b 34 2. bb 3.02 4 ~ 21 ~ 9! 2.01 4.33 0~

S-ll 0~

'2 6 79 Or 0~ a. 0~ 0~ 0~ 0~ 0~

5 '2=0 Or Itt 2.02 2.05 3.41 3. 34 4 ~ 02 3 2.b4 i! 01 4.03 4 6 0~ 0~ 5 ~ 71 0 0~ 0~ 0~ 0~ ~ Et)E ~ 'I. Ul 2.93 I 4 I I I. 73 3 f)4 3 '2 4 90 Arnl 3. I') 5 '7 4 '2 S. I 2 U ~ 0~ Or 1.48 0~ 0~ D~ Or 0~ 0~ 0 ~ 5r12 0 ~ t I- I') 3 Il I.'l) 2.nd 'I.S3 3 ~ )7 3 04 3.05 3.')2 :I ~ 22 2.71 0~ 0~ Or 0~ 0~ 0~ o. a.

'0 3 '8 0~ 0~ 0~ 'I l5 3 64 3 '9 D

LSI: 2. Iaa 2.81 2.07 3 ~ lo 2 bil 2.'Jll 3.26 3 ~ t4 3 '2 3.O6 3 2I 0~ 0~ 5 ~ 13 4 3 ~ 62 0~ 3014 ll l3 2 '2

~

a' F 04 2. I'J 3. t)6 10 3 ~ 46 2.t):I 2.') l 3~ 3 3S 3.10 a.

~

3~ 75 2.91 3.o5 0~ 1-39 2 'S 0~ 0~ a. 439313 Sbt' a!. 60 2. t>ta I II 3.26 3.25 3. I I 3.41 32 3r 08 5.12 a. 3 6S 3 l9 0 0~ 0~ 3 80 0 ~ 0 0~ 0 a. os 3 92

'0 2 '9 ~ ~

3. n'I 'I. I n 3.23 3. Sil 2r95 S.OU 4.SI 4.rS 24 4.10 a. 4 0 ~ 0~ n~ 0 0 ~ 0 ~ 0~ 0~ 0 ~ 0 0~

bbW I. <".5 l.4 I I.UO I. 0') 3.')6 3r')2 3.46 4.06 3.20 n. 4,'IS 0 ~ 0~ 0 ~ 0~ Or 0 ~ a. 0~ 0~ 0~ 0~ 0~ 0 Sw i.'. Ud ?.Un lr 3'I 'I. l'l')3 3.46 3 2') 3 S2 3 'U 4-31 Or a J IJ Ur 0 ~ S. 0 I Or S.n2 0~ 0 oi 0~ 0~ 0~ 0 0~ ia I'I i! 02 I.ol 2. 3 30 0 ~ o. I ~ a)9 4.14 a. I 25 0 0~ 0~ Or 0 3 ~ 30 0 ~ Or Or 0~ 0~ 0~ 0~

'WbW 'w a

2. I l 2.20 3. 2') 2-41 2 12 2 I'5 2bl a. 3.93 o ~

3.26 0 S.7a 0 ~ 3 '2 Or 0~ a. 0~ 0~ 0 ~ 0 a.

~ 0 0~ 0~ n~ 0~

8 2b 2. It) 2. ln 2 Un 2 ~ I)3 2 'JEa F 77 n~ 0~ 0~ 0 Or 0 0~ 0~ 0~ 0~

I 'J:I 2 '9 3 99 wllw 0 0 Ilu I II I W i!

~

UO

)t

2. 'Jb ajaJ I. In 3.40 IS 3 29 2 3 30

'6 3.19 2 'IU i.' 56 3 07 3 ~ 40 3.5'3 3.SD 4.13 0 ~ 4r67 3 '2 3 '9 3.9n 2 62 Or 0~ 0~

0~ 0~ 4 '7 5 90 0 5.06 3 '7 0 0~ 0~ 0~ 0~ 0~ o. 0~ a. 0~ II 2.'J6 .I ~ OO 3.t,) 3 Io 4 01 4.22 3.67 5. 34 4 ~ 3l 4 29 4 '1 4.47 4.5o 4 96 0 ~ 6.0S 4 92 0~ 0~ 4 ~ 98 0~ 4.76 0 0~

~ ~~ ~ ~~ a ~ ~ a ~ ~ ~ a ~ ~ a ~a ~~

SL2-FSAR TABLE 2 '-21 JOINT wINO FREOUENCY OISTRIBUTION BY STABILITY CLASS oata pERIooi sfpTENUER 1, 1976 - aUGUST 31, 1978 TaBILITV CLasS: PASnuILL a ST LUCIE UNIT 2 ATA souRcfi 5A 0 E on-slTE HUTCHINSON IS( ANOe FLORIOA wINO SENSOR HEIGHT! 10 ~ 00 HETERS FLORIOA POWER AND LIGHT COo wINO SECTOR 0 ~ 0-1.5 I ~ 5-F 0 3 '-5 WINO SPfEO CATfGORIESIHETERS PER SECONOl

~ 0 5 '-7 ' 7os-lo 0 ~10 ~ 0 TOTAL HEAN SPEED NNE F

2 10 1 ~ 21 17 6 '6 135

.246 0

0 F 00 0 0 F 00 8 '9 177 3 '6 ol l4 3 '7

~ ~ 82 F 10 0 F 00 0 F 00 F 08 NE 2.h4 7 ')

150 k.) 8:IIS 0 0 II:3II I I.6II 3i43 ENE F

~

3 15 02 56 2 ~ 84

~ 34 103 5 23 63 F 08 o.no 0

0 F 00 0 F 0 0 F 00 00 8 '9 17S 1~07 0 36 88 2 0 0 126 3 ~ 36 0 F 00 1 ~8'I 4 ~ 47 0F 00 0 ~ 00 6 ~ 40 0 F 00 ~ 22 ~ p4 :o' 0 00 F 0 ~ 00 17 ESE 68 127 0 0 203 3028

.0( 3 ~ 45 6+45 +36 0 F 00 0 F 00 10.31 ol SE ~ .o< ~ 4?

36 I ~ 83 7 '7 78 149

~ 04 F

3 15 0 ~ 00 0 0 F 00 0 F 00 0 0 ~ nn 1 +24 189 F 60 3 '5

~ 22 ~ 91 ~ 02 0 F 00 0 F 00 la ls Ssf 9 164 55 0 230 4+44 .0< ~ 46 8 33 2.79 .nk 0 ~ 00 II 68 ~

ol ~ ol 0

~ ~

n 00

~ 05 F 05 1

1 ~

~

00 ll 56

~ 34 +36 7 0 0 ~ 00 0 F 00 0.00 n ~

19 96 4 '4 D.n~ ~ 0I F 07 ~ 04 0+00 0.00 ~ 12 SSW 0 0 0 0 2 2000 F 05 0 F 00 0 F 00 o.no 0 ~ 00 ~ ln

~ 01 F 01 0 ~ nn 0 F 00 0 F 00 0 00 F F 01 Sw 0 6 0 0 3 ~ 73 0 F 00 ~ 15 ~ 30 .01 0 F 00 0 ~ on o.on ~ 0? .n4 ~

0I 0 00 0 F 00 ~ 06 wSv 0 8 27 0 0 46 4+36 o.on ~ 41 1 37 ebb 0 00 0 F 00 2 o.'14 ips ~ lb 0 F 00 0 0 F 00 12 ?5 1 ~ 27 F 07 0 F 00 o.nn 0 0 F 00 0 0 ~ 00 2

~ 28 '448 4 '4 0 F 00

6) ~ 15 0 F 00 0 F 00 ~ 29 WNW ?0 36 8 0 0 65 3 53 02 1 ~ 83 ~ 41 0 F 00 0 F 00 3 .30

.0( 4 2? 05 0 F 00 0 F 00 ~ 40 A )2 6I ~ ~ 25 F 03 1 ~ ~

0? 2 3 40

~ 41 I~ I 23 ~ 4 o.on 0

0 F 00 o.no 0 ~ 0 00 5 '470 115

~

3+93

'6 5 '4 NNW 2 6 72 0 0 109 3+98 A )0 ~

8) 3 ~ vb 0 F 00 0 F 00

~ 44 'H 0 F 00 0 00 ~ 67 o.on 0 ~ 00 ~ ~

a 12 9 6 7 '6 143

+87 3 '038 ~

o.no 0 0 F 00 0 0 F 00 0 F 00 22S 1),43 4+41 CALH n 0 CALH 0 F 00 0 F 00 0 F 00 0 00 TOTAL 20 I ~ 02 F 12 19 '0 384 2+34 1303 bboIB I.96 13 '6 261 lob9

;nk ~ 01 0

0 F 00 0 F 00 1969

'2 100 F 00 12 3081 KEY XXX NURSER OF OCCURRENCf5 XXX PERCENT OCCURRENCE,s THIS CLASS XXX PERCENT OCCURRENCES ALL CLASSES e

L2-rsAR TABLE 2<<3"22 JOINT WINO FREOUENCY DISTRIBUTION BY STABILITY CLASS Dala PERIOOs SEPTEHBER I, 1976 - aUGUST 31. 1978 STABILITY CLASS PASOUILL 8 ST ~ LUCIE UNIT 2 DATA SOURCES l)N-SITE HUTCHINSON ISLAND~ FLORIDA MIND SENSOR HEIGHTt lo.on HETERS FLoR10a PDMER AND LIGHT co WIND SECTOR 0 ~ O-l<<5 MIND SPEED CATEGORIFSIHETERS PER SECOND) 1.5-3 ' 3 '-5 ~ 0 5 '-7 ' 7 '"10 ~ 0 >In ~ 0 TOTaL HEAN SPEED NNE 0 ~ 00 0 F 00 0 2 '30914 F 3 '82515 ~ 64

0(

4 o.no 0 F 0 00 o.on 0 0 00 F 85

~

43 26 3<<41 3 '6 NE 2 ?5 ?3 0 0 55 3<<29

~ 32 3 ~ cln ;An o.no 0 F 00 8 ~ I6 Ol ENE ~

0 F 00 0 4 15

'83n 4 '7 14 29 ~ ~

03 2 0 ~ 00 n 0 F 00 o.no 0 9~

~ 34 6

7 3 '6 0 00 ~ 18 .)8 3( 3:()3 0 F 00 I F 16 3 98 4 F 78 o.on 0 0 ~ On 0 F 00 0 0 F 00 o.no 8 '234 3<<03 ESE.

~

0) ~

4 '6 JS ~ 8 '0 4 18 0 ~ On 1 0 0

~

83 3<<19 SE 0 F 00 0 F 00 0

~ li ~ 33 4A ~

F 16 01 2 0 nn 0 F 00 0 0 ~ no 0 F 00 0 13 ~ 22

~ 51 68 3<<46 0<<00 2.)7 '7 ~ 64 32 0 F 00 0 F 00 10<<83 SSE 0 F 00 0 ~ ll ~ 6 ~ 29 38 ~ ~ Ol A

0 F 00 0 0 F 00 0

~ 42 52 3<<99 0 F 00 ~ 96 6.n5 1 ~ 27 0 F 00 0 ~ no 8 28 o.on ~ 04 ~ 21 F 05 0 00 0 F 00 ~ 32 0 1 6 2 0 0 9 4<<08 0 F 00 ~ 16 ~ 96 ~ 32 0 F 00 0 F 00 1 ~ 43 .nl SSW 0 F 00 0

0 F 00 32 7

~ 04 ll 7 an) 0 F 00 0

0 F 00 0 F o.on 00 0 F 05 I.H 3 '2 0F 00

~ ~ nl 3

1

.n4 5 ~

F 32 01 3 0 'n2 0 F 00 0 F 07 4 ~ 35

~ 48 ~ 02 .An .03 ~ <<48 ~ 02 ~

F 32 01 0 F 00 0F 00 2.B

~ 09 0 2 2 4 F 80 WSM 0 F 00 0 F 00 ~ 32 ~ 32 Ol ~ 64 ~ 02 0F 0

00 0 F 00 3 ' 19 4

.ng ~

3 0 0 3<<21

~ 64 ~ Bn ~ 64 ~ 48 0 F 00 0 ~ no WNM ~ 02 ~

1 ~ 03 4'1

~

1 ~ 07 11

~

o.on 02 0 0 ~ 00 0 0 F 00 0 F 00 o.no 0 2~ 2 '4 2 '6

~ Ol .05 .n4 0 F 00 0 F 00 o.no ~ )0 NM 7 0 0 ~ 64 I ~ Ij )9 0 F 00 0 F 00 3.5o ~ 02 06 0 F 00 0 F 00 ~ 13 3<<43 NNM I ~ 43 9

3 '413 21

~ 32 .01 ?

0 00 0 0 ~ 0 00 5<<?5 3-'1

~ 01 0

0 F 00 F 1 ~ 05 43

~

7 0~ 44 2 '90915 0 F 00

~ 16 1

0 F 00 0 0 F 00

~

10<<99 20 4 '1 0 F 00 F 05 ~ ~ Ol 0 F 00 <<42 CALH n 0 CALH 0 ~ 00 0<<00 0 F 00 0 F 00 TOTAL 2.4 193 362 I ~ 64 '857 7 0 628 3 '1 F 09 30 ~ 7'1 I <<IA 5 2 ~ 21 8

32

1. 11

n4 0 F 00 0 F 00 3 '3 100 F 00 KEY XXX NUHBFR OF OCCURRENCES XXX PERCENT OCCURRENCES THIS CLASS XXX PERCENT OCCURRENCES ALL CLASSES

SL2-FSAR TABLE 2+3"23 JOINT WINO FREOUENCY DISTRIBUTION BY STaBILITY CLaSS DATA PER100l SEPTEMBER It 1976 - AUGUST 31 1 1978 STABILITY CLASS PASOUILL C ST LUCIE UNIT 2 uaTA sOUMCE: bN-SITE HUTCHINSON ISLANDe FLORIDA WIND SENSOR HElGHT: 10 ~ 00 METERS FI.ORIOA POMER AND LIGHT COo WIND SECTOR 0 ~ O-l 5 ITS-3 ' 3 '-5 WIND SPEED CATEGORIESlHETERS PER SECOND) 0 an-7 ' 7 5-10 0 >Io.o TOTaL MEAN SPEED NNE 0 3 4 0 0 4 ~ 15 o.on ~ 46 ~ 61 0 F 00 0 F 00 o.on on2 ~ 07 ~

0) O.OO 0 F 00 NE 3 '7l?

?n 2 ~ '9) I ~ 07 ~ 04 o.no o.on 0

0 F 00 0 F 00 0

'at56 3%38 46 ~ 02 3

3 '722l3

~

3 '92616 +77

~ 03 5

o.no 0 F 00 0 O.no 0 F 00 0 8 '9

~ 34 3 41 3 '8 1 ?4 42 ? 0 0 69 3~28 15 6~44 ~

3I o.no 0 ~ no in+58 Ol ~ 26 ESE

~ ~ 46 3 ~

4+ho 15 43 7 49

'230 0 ~ nn o.on 0

0 F 00 0 F 00 0

~ 42 96 14 ~ 72 3 '4 ~ 02 ~ 26 0 00 00 F 59 SE 4 17 ~

40 .0( F 0 0 F 0 62 3 0 23

~

6[ 2 61 6~ l3 0 F 00 0 F 00 9 5)

'10 ~ 24 ol SSE 15 1

2o30. l5 6 '544

~ ~ 92 6

0 F 00 0 '0000 0 00 0 F

'0000 10 12 66 3 '3 ~ Ol F 09 ~ 27 ~ 04 0 0 F ~ 40 2

o.no 0 ~ on 0

~ 07 ~ ~

77 03 5 0 ~ no 0 F 00 0 0 '0 0 arm 0 2 '618 4+13 SSM OI 7 3 0 0 3+37 l.n7 ~ 61 ~ 46 0 ~ nn 0 F 00 2 30 F 01 :n4 ~ 02 ~ 02 0 F 00 0 F 00 ~ 09 5'M ln 8 4 0 0 Z3 3+55

.Ik b3 06 1 ~ ?3 ~ 61 0 ~ 00 0 ~ nn 3+53 F F 05 ~ 02 0 F 00 0 F 00 F 14 ln WSM I ~ 53 06 I ~ 07 .n4 7 ~ 46 ~ 02 3

0 F 00 0 F 00 0 0 '0000 3 '221 3 ~ 43 Oooo 0

~

I ~ 3R 9 Ien7 7 0 F 00 0

~ Ib 0 F 0 ~ no 0

2.L 3 '5 o.on :n5 :n4 0 00 ol nano 3 '5

~ ~ 1

'MNM 0 4 7 0 0 0 0 F 00 bl I ~ 07 0 F 00 0 F 00 0 F 00 0 F 00 02 0 F 00 0 F 00 0 F 00 .n7 NW 2 '516ln ~

~

2 31 01 0 F 00 0 ~ 00 n 0 F 00 0 F 0 00 4 '03018

~

3 ~ 09 NNW

~

F Ib 01 l Ie07

~ 04 7

3 '9?616

~ ~

ool 2 31 o.on 0 F 00 0 o.no 0 F 00 0

~

36 5 ~ 52 22 3066 ln 4n

~ .nl ls 1

I ~ 53

~ 06 A )3 ~

10 I ~ 53 06 :oI 2 0 F 00 0 F 00 0 9 '66338

~

4+22 CALH 3 3 CALH

~ 46 ~ 46 F02 F 02 TOTAL 3 '815 F

24 33 '8 217 I 33

~

S4 2 35

'6 3

8.44

~

55 34

~ ~

3 4b 02 0 F 0 00 F 0 00 3 652

'8 100 F 00 3+46 KEY XXX NUMBER OF OCCURRFNCES XXX PERCEtlZ OCCURRENCES THI 5 CLaSS XXX PERCENT OCCURRPlCES ALL CLassks a a -

0
( SI,2-FSAR TABLE .2+3-24 JOINT WINO FREOUENCY OISTRIUUTION BY STABILITY CLASS DATA PERIOOS SEPTEHBER I ~ 1976 - AUGUSt 31 '978

$ TABILITY CLASS< PASOU]LL 0 ST. l UCIE UNIT 2 uATA SOUkCE! ON-SITE )<UTCH] NSON I SLANO ~ FLORIOA lllNO SENSOR HEIGHT: lo ~ 00 HETERS FLOk]OA POWER AND LIGHT COo WINO WINO SPEfn CATEGORIFSIHETERS PER SECOriOI SECTOR 0~ 0-].5 ]+5-3 ' 3 '"5 0 5 '-7 5 7~5-]0 ~ 0 i]0.0 TOTAL HEAN SPEEO NNE 15 41 56 ]6 0 0 ]34 3 ~ 34 o3] ,91 1+16 ~ 33 0 00 0 00 .2+ 71 09 .29 ~ 34 F 10 0 F 00 0 F 00 ~ 82 NE 8 89 II 05 ].0 .49 ] I34 ~

54

].ns 31 o.no 00 0

0.00 0 2?9 F 75 0 F 0 F 00 1 40 ENE l&7 51 0 0 3 AD &0 A+45 1 ~ (lb 0 ~ 00 0 F 00 6 ~ 8)

.0( 0 00 9 123 54 3 '7 ~ 5& o.no F

0 0 00 0 F 00 0 2 ~ ll 6 '5 3? $ 3 '8 F 05 -75 1+03 l6 o.'on 0 F 00 F 00 19 216 ESE

~ 39 ]2 4,46 32 4 '5 230 I 40 ~ $5 b2 o.no 0 F 00 0

0 ~ 00 0

]0 2 '9 ~

490

]2 3 AD ]2 SE AD ~ (8 1

4.05

~

I ')6 I5 o.no 0 0 ~ O.OO 00 0 2 '4 I- I I 1.? 0 :oL 3 '8 O.OO 0 F 00 SSE

.009 2 '8 1.30 ~79 4 '3 279 1.40 .17 0 F 00 0

o.oo 0 7 3I37

~ ')9 3 '5 ~ ~ )8 0 F 00 0 F 00 2 1&

12 SS

'I& ]96 6 0 355 25 1 ~ 4.05 ]o(6 ~ 12 o.no 7 ~ 33 07 20 3 '6 5?. 1 ~ 04 0 00 2 I7.

l? ]49 SSW 07 3+06 90 5 '7 255 56 1 43 69

~ 47 o4]

20

~ 02 I 505 ]0 ~ 43 3.08 3 '3 F AD ]2 ~ Ol ]50 59 9 0 3&1 2! 7I 3 ~ 10 ]+22 AD ]9 0 F 00 7 58 .80 ~ 92 ~ 36 F 05 0 F 00 2 24 MSW 10 &l 53 7 I 0 138 2098 ~ 21 1.3h 1 ~ 09 ~ 14 ~ 02 0 F 00 F 85 F 06 41 ~ 3? F 01 o.nn ~ H4 18 73 'I 9 0 0 2+74 ~ 37 5] AU] o.nn 0 F 00 ~ 11 ~ 4b ~ 24 0 F 00 0 F 00 .86 WNW 23 61 45 4 ~

F 48 14

]+2& ~ 3I ~ ~

93 27

~ ~

os 02 0 F 00 0 F 00 0 0 F 00 0 F 00 0 2 '5 133 2+69 NW 2!L2 F 87 139

.009 0 ~ 00 0 0 zN 3o]3 ll .85 o.oo 0 F 0 F 00 00 6~

245 NNW

~

77 59 206 4 ~ 25 F

.nk 0 00 0 320 6 ~ 61 3 '3 ~ 06 8 ~ 41 46 1 ?6 26 '204 0000 1 258 95 AD F ]7 05 ~ 95 ~ 2S 3+&3 17c ]+07 ~ ~

54 16

~

F 01 O.no 0 F 00 0 5 1.58

'3 3~85 CALH ]4 ]4 CALH ~ 29 ~ 29 ~ 09 ~ o9 TOTAL 5 '3 258 ]+58 34 '8 1684 ]Oi28 49 2394 '4 ]4 ~ 62 9

466

'2 2 85 F ~

39 81 24 4842 100 F 00 29.51 3i4] KEY XXX NUHBFR OF OCCURRFNCES XXX PERCE.NT OCCURRENCES THIS CLASS XXX PFRCENT OCCURRENCES ALL CLASSES
8L2-FSAR TABLE 2+3 25 JOINT WINO FREOI)ENCY DATA PERIODt IND SEPTEHBER I TABILITY CLASSt PASOUILL b ATA SOURCE i tS)N-S]TE M]ND SENSOR HEIGHTt E'T DISTRIBUTION BY ST481L I TY CLASS 1976 - AUGUST 31 ~ 1978 10 F 00 HETERS WINO SPEFO CATEGORIES (HETERS PER SECONOl I UCIE UNIT 2 HUTCAINSON ISLANDq FLORIDA FLORIDA POWER AND LIGHT CO. HEAN W SECTOR 0~ o-l 5 ]oS-3 ' 3 o-b. 0 Soo-7 ~ 5 7 '-10 ~ 0 %]0 ~ 0 TOTAL SPEED NNE

.23 38 51 1 98 33 1 ~

88 19

!i4 ~

30 41 ~04

..n2 3

o.no 0 3 '8Sl 257 3 AD ]6

.54 4Q ~ 60 9g ~

ln?

].aH F 18 44 n 0 F 00 0

I'.!lf 3 '4

~ ?4 58 62 ~

6) 3:QO 8:Qo 34 ]69 87 0 0 409 3+6]

~ 46 ~ 21 ]I~( 2.29 03- ]~ )8 0 F 00 Oooo o.nn 0 00 5 S4 2.50 5? 136 1

161 '40 Q. 0 395 30]2

~ 70 ]+84 2~26 ~ 54 0 F 00 o.on 5.35 ~ 32 .83 l,n? ~ 24 0 F 00 0 F 00 4) 2+9]

ESE

]if] 82 313 4 ~ 7.4 3 '8 272 35 ~ 47 0 0 F 00 0 '9 9+52 138 1 i9]

4n2

'4 I ~ 66 3nn ~ 21 2 'o00 0 F 00 0

4 852 2o65 1 i87

.84 5

2.45 F 06 1.83 F 07 6 0 F 0 F 00 0 F 00 0 F 00

][ ~~ 54 20 SSE l.?7 94 57 5 '4 38o 176 2 ~ 3th 1.'nr o

F 07 I

',i 0 F 0 00 F

00 0 0 ~ nn 0 F 00 0 8'.9i 4i04 2+5] 42 ]96 443 3 ~ ol

'5 2 '4 173 2 57 2 ~ 39 ~ 03 ~ 0 F 00 ~ 76 ]i20 06 ~ 18 an) 0) 2ir)

]8 164 ]63 3+35 SSW

~ 51 ~ 23 2 ~ 22 ].on 2 '1 l.'nn ~

31 42 19 AD F

]8 08 .n4 ~ 02 5.>8 2 52 SW 77 25n 161 3') 3 0 530 2.87 I ~ 04 3 ~ '3') 2~]8 ~ 53 ~ 04 0 ~ 00 F 18 .47 ] 51 ~ 9lt ~ 24 ~ 02 0 ~ 00 3.74 ]00 204 es 394 2.28 WSW 1 ~ .35 <<61 2.76 1-25 I e15 + 52 F 07 ~ 03 5

0 F 00 0 F 00 0 0 F 00 0 00 F 0 5 2

'341 ]14 143 44 0 314 2+]4 ]+54 ],')4 .6n ~ Q Q ~ QQ 4 ~ 25 70 .87 ~ 27 ~ 07 ~ 0 0 F 00 1.92 ]n2 166 348 2 ~ 22 ~

1 38

~ 67 2 'S I 01 ~

7S 02 46 F 07

03 S

0 F 00 0 F 00 0 o.no 0 F 00 0 4 '1 2 12 NW 73 4S 248 3 ~ 36 1.51 2 '3 194 1 ~ 18 9 0 F 00 0 F 00 0 o.no 0 F 00 0 3 524 7.n9

'0 2072 NNW 48 203 2QS 19 0 0 475 2+97 ~ 65 2 2a78 ~ ?6 0 00 0 F 00 6.43 ~ 29 o.on 2+90 '3 75'~24 25 o It2 0 F 00 N 64 F 87 ~ 39 1 ~

102

~ 38 62 1

124

~

68 76 ~ 46 2] 0 F 00 0 F 00 0 0 F 00 0 F 00 0 4 '9 324

] ~ 98 3

CALH 64 64 CALH F 87 ~ 87

~ ]9 39 TOTAI 1200 3219 2498 447 23 4 7386 2oa]

16 'S 7 ~ 33

,43 >8 ]9 h6 33,87, 15 25 5 ~ ')H 2 70 ~ ~

31 14 F

~

05 02 100 F 00 45+]0 KEY XXX NIIHBER Of OCCURRE.'tCES XXX VER CENT OCCUlNENCES Ttl]S CLAS".i XXX PER CENT OCCURRENCES ALL CLASSES a a -
SL2-FSAR TABLE 2 ' 26 JOINT Mltto FREOIIENCY OISTRIUUT ION BY STABILII'Y CLASS DATA PERIOOt SEPTEMBER I ~ 1976 - AUGUST 310 1978 STABILI TY CLASS ~ PASOUILL DATA SoitRCE: ON-SITE f STo L(ICIE UNIT 2 HltTCHINSOtt ISLAND~ FLORIDA KIND SENSOR ttEIGHT0 lo ~ 00 HETERS FLORIDA POKER AND LIGHT CO K IND SECTOR 0 ~ o-1 ~5 105-3 ' 3 '"5 ' 5 '-7 VINO SPEED CATEGORIES(HETERS PER SECOND)

~5 705-1000 i I 0.0. TOTAL HEAN SPEED NNE 2 '509 14 3.o) ~ 13 ~ ~

2 29 01 0 00 0 F 00 0 0 0 F 00 0 F 00 0 F 00 0 F 00 0 5 43 37

~ 23 .1 ~ 79 5 9 0 0 0 1081 ~ 73 1 ~ 32 o.no 0 F 00 0 F 00 2.1o o.on 09 ENE ~ 03 F 88 6

005 4 59 7 0 F 00 0 0 0 F 00 0 F

'91710 2 '2 ~ 04 5

an( 1 ~ 33 3 3 tt 8:0II 8:IC3 2

~

14 2039

~ 73 F 73 ~ 44 0 F 00 0 F 00 F 05 ~ 03 :n3 F 02 o.no 0 F 00 F 09 8 ln 0 0 0 0 1057 I ~ l7 1,47 0 F 00 0 F 00 o.no 0 ~ 00 05 06 0 F 00 o'.oa 0

0 F 00 0 0 F 00 0

~ ll 1 ~ 70 ~ 73 0 F 00 0 F 00 0 ~ on 2.1S F 06 .n3 0 F 00 0 F 00 0 F 00 ~ lo SSE 34 2 n 0 0 47 1 ~ 9S 101) 4 ~ 99 ~ 29 , o.no o..no 0 ~ 00 F 89 ?I ~

0) 0 00 F 0 F 00 o.no ~ 29 I 24 0 0 0 42 2 01 106) 3 ~ 5?. 1 ~ 03 0 F 00 o.an 0 ~ nn

~ l5 ~ 04 o.no 0F 00 0 F 00 A )6 SSK 38 l3 0 0 0 72 2019 3.oII S0 57 I ~ 9l 0 F 00 0 F 00 0 F 00 10 ~ 56 ~ 13 ~ ?3 .08 0000 o.on 0 F 00 44 SK 17 32 5 0 0. 0 54 1093 2 49 4 ~ 69 ~ 73 0 F 00 0 ~ 00 0 F 00 7092 ~ 20 ~ 03 0 F 00 0 ~ on 0 F 00 ~ 33 ~ /0 48 KSK 4 ~ 40 2.W ~ lo n

0 ~ on 0 F 00 0 0 F 00 0 F 00 0 ~ 00 0 00 0 7 '4

~ 29 1053 2n n 0 0 0 39 1051 2 ~ 9'3 0 F 00 0 ~ 00 0000 0 F 00 5072 ~ 0)2 0 ~ on 0 F 00 o.on 0 F 00 F 24

'KNK 5 '822(2

~

4.60

~ 20 ~

2 29 0 00 0 F 00 0 0 0 F 00

.0 F 00 0 F 00 o.on'0 0

10.26 70

~ 43 1057 2 '5 14 64 0 0 79 1096 9 38 0 F 00 0 ~ 00 0 F 00 1 1 ~ 58 F 09 ~ 39 0 F 00 0 F 00 0 F 00 ~ 48 NNK 17 52 l 0 0 74 2006 2 706? 59 ~ 15 0 F 00 0 F 00 10.85 2

ln

'50914 F ~ 32 1017 8

F 05

~ 0?

4 F 59

~ 02 ~ nl 0 ~ un 0 F 00 0

0 F 00 0 0 F 00 0 F 00 0 F 00 o.no 0 F 00 0 3 'l

~ ~

45 2b I6 77 2 '5 CALH 14 CALH F 05 O9 F 09 682 1084 TOTAL 3ho9( 1 54 54 '9 375 2 ~ ?.9 5? 7 ~ 62

~ 32 ~ ~

44 02 3 0 0 F 00 0 F 00

.0 ~ 00 0 F 00 0

100 F 00 4 ~ 16 KEY XXX NtJHB)R OF OCCU)REtICES XXX PORC NT OCCURR NCKS THIS CLASS XXX PERCENT OCCURRENCES ALL CLASSt'.5
SL2-FSAR TABLE 2 ' 27 JOINT KINO FREQUENCY OISTRIBUTION UY STABILITY CLASS DATA PERIOD: SEPTEHBER I ~ 1976 - AUGUST 3l ~ 1978 STABILITY CLASS: PASOUILL G ST. LUCIE UNIT 2 OATA SouuCE: ON-SITE HUTCHINSON ISLANDy FLORIOA MINO SENSOR HEIGHT! 10 ~ 00 HETERS FLORIOA POKER ANO l.lGHT Cao KINO SECTOR 0 ~ Q-I ~ 5 I+5-3 ' 3 '-5 0 5 '-7 ' KINO SPEEO CATEGORIES(HETERS PER SECONO) 7+5-10 ~ 0 %10 0 TOTAL HEAN SPEED NNE 92 2 0 0 F 00 0 0 F 00 Qeoa 0 0 00 0 0 0 ~ 00 ~ 2 92 lola

~ ol 0 F 00 0 F 00 0 ~ an 0 F 00 0 F 00 ~ ol NE 0 4 n 0 0 4 2+35 F 00 1 83 Q.nn o.nn II.o3 o.no 1 ~ 83 3 ~ 02 0 F 00 0 F 00 0 F 00 F 02 ENE 0 0 0 0 0 0 0 0 F 00 0 00 0 F 00 0 ~ 00 0 ~ 00 o.ao 0 F 00 0 F 00 0 F 00 0 F 00 0 ~ Qn 0 F 00 o.'oa a.oo o.ao 0 0 n 0 0 1 I ~ 80 0 F 00 .4L o.on 0 ~ no o.on 0 F 00 .46 o.on ~ 01 o.on o.on 0 F 00 0 F 00 ~ 01 ESE n 0 0 0 a 0 0 0 F 00 0 ~ 00 0 F 00 0 F 00 0 F 00 0 F 00 0 ~ 00 0 F 00 0 ~ aa 0 F 00 0 F 00 0 F 00 0 ~ Go 0 F 00 0 F 00 0 0 0 0 0 0 0 0 F 00 0 00 0 00 0 ~ on 0,00 o.no 0 ~ nn 0 F 00 '3 F

0 F 00 0 F 00 o.no 0 F 00 0 F 00 0 F 00 0 F 00 SSE 2 0 0 0 0 F 87 o.aa a.ao 0,00 a.oo 1 38 9I ~

0) 0 F 00 0 F 00 0 F 00 0 F 00 ~ 02 0 0 0 0 3 I ~ 63 46 92 o.on 0 00 o.na 0 ~ nn 1 ~ 38

~ Ol an) o.on 0 F 00 0 F 00 0~00 ~ 02 SSM 2.29 ~ 03 5

2 '504

~ ~ ol 0.00 0 F 00 n

0 Go 0 Qn 0 0 0 F 00 0 F 00 S.ko

~ 07 1067 2 '9 5'K a 0 Q 0 1 ~ 44 5.oi o.on o.on 0 F 00 0 F 00 7.34 ~ 07 ~ 03 0 F 00 0 F 00 0 F 00 0 F 00 ~ lo l4 9 0 0 0 0 1+56 6+42 l3 0 00 0 F 00 o.'on 0 ~ 00 n.oo low'b3 ~ 09 .08 o.on 0 F 00 0 F 00 ~ l4 0 0 0 0 22 1 ~ 36 7.kt 2.29 0 ~ on o.no 0 00 0 F 00 1 o.n9 )0 on3 0 F 00 '

0 F 00 0 00 oman 13 15 '0 5 'n lJNK 12 0 0 0 46 I +40 0 F 00 0 F 00 0 F 00 0 F 00 21 ~ I0

~

2[ ~ 07 0 ~ an 0400 a.ao o.oa ~ 28 44 NK 8.16

~ ll 20 18 ~ 27 :nl 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 F 0

00 0 F 00 28 '063

~ 38 1 ~ 76 NN'N 2 '5046 ~

3 6 '(14 n o.no o'.on 0 n 0 F 00 0 F 00 0 0 0 0 ~ 00 0 ~ 00 0 0 0 F 00 0 F 00 0 20 9 ~ I7

'. 3 1 ~ 75 17 I ~ 38 o.on o.on 0.00 0 F 00 0 F 00 38 ~ 02 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 ~ 02 CALH 0 0 CALH 0+00 0000 Q.on 0 00 ln3 TOTAL 113 SI ~ 83 ~ 69 47 '563 ~ ~ ~

2 92 ol 0 na 0 F 00 0 0 0 F 00 0 F 00 0 0 F 00 0+00 218 100 F 00 1 33 1 +58 KEY XXX NUH BER OF OCCURRENCES XXX PER CENT OCCljRREthCES THIS CLASS xxx pER CENT OCCURRENCES at i Ci aCCFS~ a a
SL2-FSAR 0 TABLE 2 ' 28 JOINT MINO FREOUENCV OISTRIBUTtol< OATA PERIOD ~ SEPTEMBER I ~ 1976 -'UGUST 31 ~ 1978 ALQ MINOS ST LUCIE UNIT 2 OAIA SOURCES ON-SITE HUTCHINSON ISLANOo FLORIOA

'NIND SENSOR HEIGHT0 10 ~ 00 HETERS FLORIOA POMER AND LIGHT C00 MINO MINO SPEEO CATEGORIES(METERS PER SECONOl MEAN SECTOR 0 ~ 0-1 ~5 ITS-F 0 3 '-500 5 ~ 0-705 7 '-10 F 0 ~10.0 TOTAL SPEEO NHE ~

71 43 1 '5 206 1 318 92 3 02 0 0 F 00 4 '5 669 3 0 32 NE 67 297 385 0 0 867 3 ~ 43

.36 1.77 2.33 /7 0 F 00 0 F 00 5.25 60 5o5 ENE ~ 36 2 '2 334 3006 158 ~ 96 0

0 F 00 0 0 F 00 1057 6040 3051 E 69 355 Slo 76 0 0 10I0 3025

~ 42 2015 3009 ~ 46 0 F 00 00OO 115 684 744 72 3004 $ 6)6 ESE 0 ~ lo 4 ~ 14 4050 ~ 44 .OI 0 F 00 SE i'll 183 3 '9 660 4 '3 .f7 0

0 F 00 0 0 F 00 V3) 2 '8 SSE'29 ~ 788 579 3050 3 '7 656

~

93 56 .oI 0 0 F 00 II458 3010 5 72 310 407 99 8 897 3036

~ 44 1 ~ 88 2046 ~ 60 05 .oI 5043 SS'N 84 372 446 105 4 )04) 3048 F 51 2025 2070 ~ 64 F 30 ~ 02 Sil 129 440 336 106 0 1025 3010 .78 2.66 2.03 ~ 64 .)8 0 F 00 6020 MSM 155 320 186 5 0 .695 2059 ~ 94 I ~ 94 I ~ 13 ~ f8 ~ 03 0 F 00 . 4021 N ]74 267 119 37 2 0 599 2043 I ~ 05 1 ~ 62 072 ~ 22 ~ 01 0 F 00 3063

'MNll 1 203 23 1 '4 304 172 1 04 .Io 0 0 ~ 00 0 0 F 00 4 696

'1 2 '4 NM 143 5 le 424 50 0 0 1135 2085 ~ Bl F 14 2057 ~ 30 0 F 00 0 F 00 6 87 NNil 85 3'l9 53'5 70 0 )070 3022 ~ 51 2 29 3 ~ 24 ~ 42 .oI 0 F 00 148 5 0 969 3069 .8 I!17 3'2I ~ 90 ~ 03 0 F 00 5086 CALM 9S CALM ~ 57 .s)

TOTAL 11 1920 62 6214 3l 61 7023 42 51 7 '9 128'7 73 44 ~ 5 03 I)0 F 00 3010 NUMBER OF VALID OBSERVATIONS 16522 94 '0 PCS NiFHBER OF tNVA( IO OBSERVATIONS 998 5070 PCTo TOTAL NUHBtR OF OBSERVATIONS 17520 100 F 00 PCS KFY XXX NUMBER OF OCCURRENCES XXX PERCENT OCCURRENCES
SL2-FSAR TA8LE 2 '-29 nlNT wtt)0 b ATA PERIOO) FRE))UE Nrv oISTRI))uzloN HY sTault

- ltY cLAss SEVTF;MUER 1 e 1976 Al)GUST 31e 19/8 STaHILI Tv CLAss: pnsBUILL a ST ~ LJJCIE UNIT 2 OATA Snl)RCE: nN-S I TE HUTCHINSON ISLANO ~ FLORlOA W INJ) SEJ )SOP H EIGHT: 57.91 DIETERS f).o)JIOa PowER ANO LIGHT Co.

wiNO wlND SPEEn CATE'GO)tlfs )METERS J'ER SEcotlo) MEAN SECTOR 0~0 I~5 1 ~5 3 ' 3 AU 5 ~ 0 5 ' I+5 7 ' 10 ~ 0 >10 0 TOTaL SPEED NNE

.OS '~ 01 1 ~ 46 05 9

3 '967 48 F 15 82

~ 49 1.77 35 +15 ~ 02 3

9 '6 197 1-18 5 ~ 78 NE I in> 52

~ ?f b 188 5 27 o.nn ~ 35 5 ~ 11 2.63 1 ~ 30 F 50 0 F 00 .n4 .cn .:)1 ENE n.oo 0 ~ 46 4.)n Jll 2 83 56 ~ 66 3

F 04 I ~ )2 8!59 5 '2 0 00 ~ ns ~ 4)l +33 .n8 '2 1+02

~ OS

nl 1

OA 3 '9Ii

,~?

4 84

~ 48 t)0 ebb 13 ~ l)H F 10 ul 9+lb Inl I I)d F 19 ESE =0 I3 74 2b 2 1!9 5.61 0 ~ nn 20 3oc") 3. I4 1 ~ 31 bio F 05 n.on ~ n2 ~ 44 ~ l) 4 ~ 16 ~

OI l. 0 I '2 o 15

'~ 02 3 ~ )5 .n? '1 2 '35 I) ~ 35 4 ~ IS F 56 1 ~

i?5

?6 0.00 it)3 9 ~ 25 5

ssE n.nn ~ t)b l 87 4 ~ 40 6!)3

)5 0 F 00 12 1 ~ 09 244 '4 7 '2 0~00 .nl sod ~ 52 ~ 72 ~ 13 F 46 n 0 2 1 1 1 5 6+62 o.nn o.nn ~ 1 t) F 05 ~ O'5 .ns ~ i?5 SSW 0 F 00 0

0 F 00 0

.ni ~ Ul ~ Ol o OII ~ 03 1 0 2 4 ~ 25 o.nn 0 ~ Un o05 .nb 0.00 0.00 F 10 o.'on 0 nn ni onl Sw 0 F 00 I) an>

I

-)5

l

~ Ub l

0 no F 10 2 0 F 00 0 F 00 0

~ ~

Ol 35 I 4 '9 0 ~ on F 01 02 .Oi tol 7 '3 04 HSw 0 F 00 n u.nn 0

~ i.'5 Il ~ dh 13 ~ 66 0 F 00 ~ 10 2

1

~

37

~ 87 o.on DUO ~ 03 7 '4 ~ 10 F 08 01 ~ 22 0 ~ on o'on n

0 arm 0 F 09 n

.>I 10 ~ Ob 1

20 Ul

~ )2 and ~ ~

30 04 6 2 '3.in

~

50 1'I 3l 78 6.28 3 '4 17 6

~ ln ~ 25 F)6 1+57 ~ 86 30 ~ 01 03 ~ ln ~ )9 F 04 47 ln 47 43 ~ )0 .in2 6 '7 NW 0 126 5 35 ~ SI 2 ~ .)d F 17 I ~ 21 0 F 00 .ni 06 ~ 28 F 26 ~ 14 0 F 00 IS Nt)W 0 F 00 0 ~ 0) 72 2 '?47 I ~ 52 3n 15 '3 ~

98 4 ~ ')5 6 '1 0 '~ On 1 1 ~

.nl4 ~ 25 ~ 5')

7 '4

~ 3 'I 8 ~ 18 ~ 07 9 96 16 233 O.no .?n 1 ')7 3 ~ 94 4 ~ J)5 ~

8) 1 1 ~ 7))

0 ~ on ~ 02 23 ~ 47 F 57 1 ~ 39 CALH 0 0 CALH o.on 0,00 o.on 0.00 TOTAL

.46 9 '4b8ql 3o.4611 7!i9 '9<<779 197)) 6 '3 05 3 ~ 3.bs 4 '3 36 F 37 2 '0 3 ~

100 F 08 11.81 KEY xxx HUH) E)t Ol t)Cr)J) HENCLS xxx pERcENT ))cc)JR)t);Net.s THIs cLass xxx pF:RcENT occl)RRF;NcEs ALL cLAssEs 0
0, SL2-PSAR TA8LE 2o3>>30 OINT 'gINO FREOUENCY OlSfRIHUTIl)N'OY Sf AulLITY CLASS AtA Ptllloot sEPTEs8ER l 197& Auousf 31 f978 - STABILITY cLAss! PAsnuILL 8 ST ~ LUCIE UNIT .2 DATA snuROEl ON-slfE HUTCHINSON ISLANOy FLORIOA VINO SENSOk HEIGHT: 5/ ~ 91 HETEHS FLORIOA POSER ANi) LIGHT CO M IND SPt ti) CAftGORIFSlHETERS PER SECONO) 'JUNO St.CTOR aoa-1 ~ 5 lo5-3 ' 3 '-5 ~0 5 ~ 0-7 ' 7 '-10 ~0 >loon TOTAl. HEAN SPEED NNE NE n<<na o.nn 0 n

~ 32 .nl8 7

3 'l24

~ 4 7 ~ &3 ~ 02 4

5

~ 06 7

0 F 00 0 F 00 0 2 6 '540

~ 24 39 'o42 4o94 0 F 00 '0 ~ 00 l o?7 OS 2 ~ 70 ~ lo ~ 79 ~ 03 loll F 04 ~ 32 oal 6o)9 ~ 23 ENE 0 10 ?4 ) I- 2 56 4 F 84 O.nn 1 ~ 59 3~ I rl lofS 4') ~ 32 8o89 0 F 00 F 06 ~ )4 F 07 . F 05 ln ~ OJ ~

3)

~ )L ~ nl lo59 ~ 06 5 '737 ~ ??

3 dl

?4 ~ 14 Iob9 (0

nb

~

b) 13 '5

~ 51 5o14 ESE o.nn 0 .? 3A, 18 1 70 5o40 F 32 c 03 olb 1 1o 1 1 ~ ?3 F 07 ~ 42 0 ~ On ~

0$ o

)) ~

OI n.on 0

~ 32 5 '4:l3 4 '4 ~ 95 6

11 ~ 11 70 So 37 SSE 0 ~ On o.no 0

~ 0 ~ 4l ~ 20 7. ~ 04 2.4 0I ~ 42 50 7 ~ 94 6 '9 0 '~ an ~ 02 F 13 3 ~ ll0 ~ ) ~ 30 7 4o41 loll ~

1 n.on ~ 48 o 16 o48 0000 0 ~ On o.'nn 02 oo( ~ 02 0 F 00 0 F 00 ~ 04 SS4 0 0 4 0 0 9 4o98 0 F 00 o.no o79 ~ b3 0 F 00 0 F 00 1 ~ 43 0 F 00 0 F 00 o03 F 02 o.ao 0 F 00 oo5 SM 0 2 5 )5 6005 o.on ~ 4ol o32 ~ 79 ~ 63 2o 38 0 F 00 ~ 02 oal F 03 ~ 02 ~ 09 4 2 5 7051 16 ~ &3 ~ 32 ~ !9 o&3 2.)t 0

~ 32 F 07 o 32 2 ~

0) I ~ )I

~ 03 ~ 32 2 ~ 02 ~

I ~

~

2.)8 0 5 '9

~ ol ~ ol It& F 09 0 ~

0) b 4 3 1 2 O.nn I )I

~ ~ 9S ~ &3 ~ 48 ~ 14 3~3 0 F 00 F 04 ~ 0$ ~ 02 NW 9 10 5 3 ~

0) 18 4 ~ 16

~ l6 ~ Ol I~ 4'1 F 05 1.4 o06 .79 ~ 03 .4a F 02 0 F 00 0 F 00 4 ~ 44 ~ 17 NNH n 3 17. 15 8 0 3l) F 80 0 F 00 ~ 48 1 ~ 90 2.38 1 ~ 27 o.no bo03 0 F 00 ~ 02 af F 09 <<GS 0.00 o23'9 N

o.no o.nn n

~ 63 ~ 02 4

2 ~ i?7 NOH

. 23 3.&5 ~ 14 '3 '720 1 2$ ~ ~ Ob 8

10 '54l

~

7o12 CALH 0 0 CALN o.no o.ao o.on 0 F 00 T0TAL

~ 63 ~ 02 10 95~

69

.4l 37 1 'b 23&

o41 116 18 ~ 4)

~6 F 13 26 ~ 16 630 100 F 00 3i76 5o59 KEY xxx NO~HER of DCCuilRENCES xxx PFRcFNT occuRRENct:s THls cLAss XXX PERCENT OCCURRENCES ALL CLASSES

SI.2-FSAR TABLE 2 ~ 3 31 JOINT WINO FREOUENCY DISTRIBUTION I]Y STABILITY CLASS DATA PERIOD: SEPTEHBER le ]976 - AUGUST 3] ~ 19/8 TABILITY CLASS: PASnU]LL C ST LUCIE UNIT 2 b ATA SOIIRCE! ON-5 I TE HUTCHINSON ISLANO ~ FLORIDA MIND SENSOR HEIGHT: 57 ~ 91 HE,TERS FLORIOA POMPEII AND'I.IGHT COo il I NO MIND SPEED CATEGOR]tS(HETERS PFR SECOND) HEAN SECTOR 0~0 I ~5 1 ~ 5 3~0 3~0 5~0 Sea 7 ~ 5 7 '-10 ~ 0 >]0 ~ 0 TOTAL SPEEO NNE 0 4 / 6 5 4 2& 6o 69 0 ~ 00 ~ 60 1 06 .90 ~ 7b ~ 60 3i92 0 00 ~ 02 ~ 04 ~ 04 F 03 ~ 02 ~ 16 F 4 5.87

~ 1$ e90 ]eU le36 I.OL ~

6) S.H

.01 ~ 04 ~ 07 F 05 :n4 ~ 23 0 6 18 7 5 llew45 Sino 0 ~ On ~ 90 2~ 7 1 ] e36 1 oa6 ~ 75 6 79 E

0 F 00

.15 I ~ 04 1.81 12 5.28 ~ 11 35 F 05 4.n7 27 ~ 04 le96 13 ~ 03 ~ 30 2

13o57

~ 27 90 5 '2

nl ~ Ol ~ 21 ~ 16 :o8 ~ Ol ~ 54

]4 5 33 3 '7 ESE 43 23 2'

0 10 0 F 00 0 00

] AS]06 6 49 ~ 26 ~ .01 ~ 54 F F J4 77 5038 4 '8 0 0 0 F 00 .eo 4.e( 1 ~ 3b 05 0 F 00 oiao 61 46 0 00 ~ 02 ~ )9 ~ 20 ~ ~

SSE o.on n.nn n

~ 45 3 ]ebJ 0

Se13 34

~ 20 1 11 06 0 F 00 0 F 00 0

8 '0 57

~ 34 6 AD ]2 ~ 0? ~ F 5o52 0 2 7 9 3 0 0 ~ an ~ 30 1.06 1 ~ 3b ~ 45 0 00 3 a.oo O'J ~ 04 ~ 05 ~ 02 0 F 00 5 5 I/ 0 3 2 3 0 F 88 0 ~ 00 F 60 ~ 45 ~ 30 ~ 4S 0.00 1 ~ 81 SI/

o.on 0

~ Og ~ 02 6

F 01 F 02 4) 0 F 00 0 ~ '00 0 2.0

~ 07 4 '8 'W5H 0 ~ an 0 ~ On n ~ ~

7J 03

? ~

e04 90 5

~ 75 ~ 03 7 ~ 02 5

0 F 00 ~ ll 20' 6 '3 0 ~ on ~ 30 ~ 75 0& ~ 75 02 0 F 00 o03 ~ 04 o03 ~ 12

~

0( 9 I 0 F 10 AD 1

]5 ~5 3& aha ~ ]S 0 F 00 2.0 MNI/

F 01 2 F 02 3 F 05

'1 F 02 4

F 01 0 F 00 0

~ ]) So49 .30 ~ 45 ~ 45. .&n ~ 75 0 F 00 2o56 ~ ~

0) 30 F 02

~ 75 1 obl n2 ln ~ ]e>]

02 Ja

~ 03 ~ 30 2

oooo 0 F 00 0 4 ala

'729 4 '3 NNI/

o.an 01 0

~ 0'1 ]s 1 ~ ne 12 8]

F 06 2 ~ A7 9

~

0) o.on

]S ~

6 79 17 45 6 '9 0 F 00

~ ~ ol .2 .07 ]n ll F 07 22 ~

e0$ ~ 27 58 7ee4 N o.on 0 F 00 n

~ 30 01 1.51 ~ 06 ~ 2,26 15 09 3 '?

AD ]3 1 ~ 36

~ 05 8 ~ 75 e35 0 0 CALH CALH o.no o.nn TOTAL n'.on 7 /7o 2i.'0 2/6 32os8 171 ] II~ 2b 4.n7 0 F 00 100.00 663 5 '2 1.06 ] 0 ~ II/i Q3 ~ )A1 3.96 ~ 04 ~ 43 1 ~ le29 ~ 72 F 16 KEY XXX NUHBFR OF OCCURIIENCES . 'XXX PERCENT'CCUIIIIENCtS TH]5 CLASS <<<<<<nrnrcest nr ran>nI. oirvc e} I rJ Accc>>

a a
2-FSAR TABLE 2 '-32 JOINT I}IN0 fREOIJEVCY DISTRlUIJT ION dY STA81LI )Y CLASS bATA PERI OOJ SEPTEHUER Ir 1976 AUGUST 31r I 978 STAB I). I TY cLAss I I Asnl}ILL I) ST. LIJCIE UNIT 2 DATA SOIIRCE I ON-S I IE MIND SENSOR HEIGHT: 57 91 HETEttS f HUTCJJINSON ISLANDS LOR IOA FLORIOa POIJF)I AND L1GHI CO. MIND MIND SPEFIJ CAIEGO)tIES IHETERS PER SECOND) HEAN SECTOR 0~0 I 5 I~5 an 3 ' 5~0 5 ' 7 ' 7 5-10 ~ 0 >IQ ~ 0 IOTAI SPEEQ

)9 48 145 6r08 NNE .nh 3 ~ 38 ~ 9h ~ .3) 62 ?r5 50 .)8 2 '1A7 ~ 0? ~ 11 34 ~ i!9 43 F 19 sn ~ )5 ~

If 235 6r72

. .Ok ~ nl hn ~ 20 ~ tt h ?6 iran 30 I . 5~8 i!7 ~ 56 17 4

Iohn ll ENE

'?04

h9 5

~

28 ll F 56 I.hn

~

tin 4 t) 104 2rn9

~ 62 l.n8 ~

Sh 32

~

l6 l2 6 '6 307 6r35 Inh l?8

~

2'

~ r9n 45 ~ 71 2o I -I nl 2 '7 r76 82 I ~ 64 ~ 49 S26 391 F 84 2-. 33 6rOS ESE ~

0( 3) 27.5 I I3 85

~ )7 539 5 ~ 61 hrSI 3rhl 10.81 ~ Oh F 07 F ~

62 19 I 34 I 03 1 ~ 70

~ Sl F 44 13 3 '2 SE ~ ~

la 03 S

~ ~

li

.J6 21 ~

3 ~ tl9 I ~ )o J 4 1gh 2.89

. JJ6 1.?n ado 60 .a6 F 02 3

JJ 442 2 hh w tltl 5 ~ 16 SSE 4 )6 10t) 1th ')3 ba 3S6 Sr72 BOA ~ 3? 2 ~ )3 3~ I ~ 20 F 08 F 14

~ 07 ~ la ~ 63 ~ 99 ~ 36 ~ 02 2r 13 5 31 ISl Sh l) 404 F 50 .~n t h) 3 II( 3. Ul I ~ )2 ~ l6 8 10 ~ 1'i ~ 90 ~ 9J ~ dl F 05 2 ~

4I sl 24) SSIJ

~ .ns lh 8

I ~ 02 3n 4 '344 999 59

~i 41 l2 ~ i.'4 ~

11 22 Ul 9.as 2 ~ P9 F 81 SIJ Ih 7

~

I.J)$ I ~ I ln 3 ~ 5.) I ~ tt9 33 66

~

ll 7 '6 372 4 ~ 87

~

F 04 ~ 30 l.ns Sh F

.?.0 2) 2 22 3 33 43 )9 6 I 5? 5r06 .06 ~ Clh ~ 96 ~ 86 ~ 38 F 12 F 05 ~ 0?7' l4 ~ ?0 2n ~ 40 I ~ ?9 5tl Ii! ~ 26 3l ~ 66 ~ )I 40 F 04 .Ia 9

2

~ 91 ')lhl IhS 5 '5 ~ 04 ~ )2 ~ i') ~ 17 F 05 MNV tit) 32 24 4 4.77 ~ lb ebb 64 48 F 08 3. 35 OS .?n 39 19 ~ 14 ~ 07 1 Oa NIJ ~

lh 7 hi? dt!

~

lan lnl

'5 .74 .37 ala S

5 298

'A 5r17 ~ ~ 2 ~ Ol 2 7!i rhn ~ h4 72 03 I 78 .Oh ~ 07 I ~ ~

ll lh

'i9 I ~ J I) 2!ki ~

83 I ~ t)6 F 2J 5

~ '4 296 6r66 .nl Ia >5 69 .50 13 I ~ 77 On ~

ll ~ h)

. tt6 ~

I.c n la lah F 09

~

46

~ 92 5 '6 277 7r53 ~ ~ 07 ~

2( ~ 76 ~ 42 ~ b2 r2( 1 ~ 65 CALH 9 9 CALH

~ 18 ~ 18 -05 TOTAL F 05 49JJ 9.9'}

1747, 3hr94 1542 3nri3 17 2~ 52~?i 4986 100 F 00 5 '7

~ 48 2.9l In.ha 9 21 5 ~ 15 1 ~ 56 29 77 KEY XXX HIJMBEJ} Of J)CCUI})tt'NCFS XXX PERCEN T UCCIJRIJE+Ct.S TII IS CLaSS XXX PERCEN T OCCUI)RENCES ALL CLASSES

SL2-FSAR TABLE 2 ' OINt w)NO FHEOI(ENCY 0[St()It)ut )ON UY Sta))ILITY CLASS b Ata PERIOD( sEpTE)s)(E)t I, 1976 - AUGusT 31. 1978 stat) IL I TY CLASS) PAS(tt)ILL E ST ~ Lt)CIE UNI T 2 DATA SOUHCI: ) t)N-SI TE NUTC)tlNSON ISLaND, Fi ORIDA WIND SENSOR t(EIG)(t 4 5/.9) NFTEHS FLORIDA POHEH AND LI6)(T CO w) t(n IND SP)'EO CATEGO!(IE5 (RE TERS PER SECONI)) HEAt4 SECTOR 0 ~ 0-1.5 Ie5-3 0 AU-S 0 an-7 5 7 b"In+0 iln 0 TOTAL SPEED ~ NNE

~

3 7 ~ 64 69 92 64

~ ))5 hn ~ st 0 42 ~ 56 296 3 93 6 '1 o 2'J n

0ts ~ 41 ~ 36 I ~ 77

?

6 .nn

!)n ~ 13 3)s 6'i ~ clh c~0 ~ hb ~

2)

.)6 254 3.31 5 '7 ~ 07 2/ ~ .3:l 3a) ~ .In i lh I ~ '.) 2 7 51 lun 104 36 3'jb 6o40 09 ~ 04 p h't ~ .') I ~ 'I(! ~ .)4

l. arm

3) I~ 3)I

~ 62 ~ 4() ?I

4. /3 2.13 E )i ii) I) I in/ 148 72 590 6 ~ 56

.nV ~ 0'I ~ 76 I-bl 2.4)s 96 ~ un 7on3 ~ 34 ) /2 1.-12 ~ is ll .43 '5 ESE ~

I?

)6 n7 I.n) 77 46 3 ~

1.!i I In 4

.silO ~ (I'J I . ()4 2 '6 I ln 02 ~

55

'l3 33 I) /5 11 o/) I 5.22 5

SE

~

Il lb I~

~ >acth 3 ~ >il) 2s?

3 ~ )4 I 4'i

~ )301 5.47 ~ .n7 11 I ou).'I ~ .) I 10 ~ 63 SSE I? ~ ')n I ~

2)'> 71 I.sn ti ~ 14 4. I() 2)S 5 b I?

~ Ih 07 ~ 7'I .)5 ).

I s)

)) ? ~

1.?lt

>s') .!)4 3tt ~ Ul 7 ~ c) ay 5 AD )3 ~

7.') 3 I

~

69 F 64

~

I ') I )44 I- )tb tl

~ ~ 37 ~ ~

03 04 3 3 ~ 42 abn 4 '9

~ 15 s)4 .02 ~

I 0 SS)4 14 19 112 I ~ 49 I I!)4 F 44

~

103 31

~ ~ ) 7 i'.4 )2 b,05 456 4 '3 o nst 61 I ln ~ hl ~ ~ 14 ~ )I 2 12 Sw 2n t)9 194 ) (t!I 4? 464 F 55 F27 I ~ I t) 2.57 1-43 o!ih ~ IS ha lh I? 1I I I!! ~ na .2) nl 2. 17 wSw ~ ~ )7 23 ~ ~

I ~ ()9 ti?

~

I 2 e (I?

)2 94 I ~ )'.) ~

2/ 36 alt I I J)3 4 95 4 '6 ln 4 ) tl ~ ah 2.?3 F 4 '2

~ ~ ~ ~ ~ ~ 16 ~

0$ 6? I (in Ist

~ 31 I ~ 4') 1.04 3)) )g 31)

I 'i

~ ~

7'I ~ 3 63

~ ha I lh 47 109 -j ng 5

1. ((6 3'6 4 '7

~ 36 ~ t)4 I 4b ~ 35 ~ 07 4 ' 9 ~ )6 ~ .) Il ~ (!'4 ~ (!5 ~ 16 ~ 03 2,07 NW )6 )s? I'tn I tiji hn I 53/ 93 21 I.n'I 2 ~ '.) 2 2 '.>0 .fsn (t I 7 13 4 ~ .jn 4) I ~ 13 .36 ~

3 i.'I

~ 17 ~ .bn ln I II d4 I

3.15 12 i.'37 1,?h 95 4()2 6 ~ 40 6 '3

. Of'. )'t hl) 1.4). s'i7 :n9 2 ~ tin 6 '7 ~ ~ .nh ll I (s ~ ~ ?2 .(7 49 .t(8 a39 66 1-15 !)7 ~ b2 I ~ 27 ~

9f b7

~ ~

2)I 37 17 3c'4 4 ~ 30

).93 CALN 37 37 CALH ~ 4') ??

TOTAL

~

276 h6 1055 14.nn 234'i I 'I 2339

'9 1167 6) s 22 7534 5 '8 3

I.bS 6. )n 31 14 ~ 00 31 13 F 97 05 15 6 '7 F BIO 100 F 00 44 ~ 9() KEY XXX Nt)M()ER OF OCC(/HHLNCES xxx pE HcEslT ore()HH),'Nct 5 It(Is cl.a. 6 XXK PEHCENt OCC))HHENCES ALL CLASSES
SL2-PSAR TABLE 2 ' 34 JOINT WliVO FAEOUENCY OIS)H]oUT]otl IIY S'(ABILITY CLASS DATA PFR I OO I SEPTEt<BEA I ~ I 916 AU(sUST 31 y ] 978 TAB ILI TY CLASS: PASOUILL F ST LUCIE UN]T 2 b ATA Sottr CF: or<-Sl TE H(ITCt)INSON ISLAND+ FLORIDA WIND SENS()tt HE IGt(T: 57.9] Mf TEt(S FLU(< IUA POWE)I AND LIGHT CO WIIID wINO SPEED CATEGOH]f.S(IRETEHS I'EA SECOND) HEAN SECTOR Oso-l.5 I b-3.(t 3 '-boo 5 ~ 0-7 ' '1 5-10

~ 0 >]0.0 TOTAL SPEED NNE ~ )4 I ~ Ssst l

2 3st

]7 ~

6 t$ 4 0 arm n 0 F 00 0 3) 4 ~ 35 3 '3

]0 0.00 4 '3 F 01 ~ 04 ~ ~ 0< O.nn F 19 NE o.nn n 3 s) 4 .2 0

47. ]+26 56 i.'8 0 F 00 F 52 Et<E 0 ~ nn

~ ~ 02 .n5 1.

F

~ 07 3 ~

F 01 6 0 F 00 0 ll 23 F 81 AD %6 ~4? ~ ') st ~ 42 ~ 8ss 0~On 3 23

n? :07 :n>> ~ 02 ~ 0>> n.nn . I>>

n 4 I 1 7. 11 Se]3 0 nn 's6 ~ 4i.' ~ 14 ~ 14 ~ ? I) ] F 54 n.on :n? 0 i'. ~ Ul ~ nl F 01 .01 ESE 7 s3 7 3 I I ]9 26

~ i? (I 7<) 98 42 ~ ]4 2ors6 nl ~

n)

~ ~

Il '7 SE SSE

~

0 00 F o.no n 7 17 I ~f 8 nl 1 I

~ ~

0'3 t) s?

~ <Its i'i'.

2. an?

.09 15s In ?4 o.nn O.on 01 0

0 o.nn OI 0 F 00 s) 0 5 '] 40 AD 55

?4 4

4 '6 F 28 .s)n 3 0'I 3 $ 1 0 F 00 o.nn 7 7) nl :n4 '.I I '1 0.00 0 00

~ 70 )I

nl 2e.3s)

I lo 40

nh

~ .nl )4 1

n.oo 0 6 '7 3i82 SSW F 03

~ 84 F 66 ] s) ~ ln <.07 ?9 3

ch 65 0 ~ <)0 n 0 F 00 0 no 0 o 1] 22 s'.6 80 4 '3

n4 ~ ll ~ )1 16 (I on

~

o.no ~ 4 <3 58 4.')35I F 81 SW ss 11 0 0

~ 5<s I 12 ] ~ q4 o.on 0 F 00 8 13 ~ 0? .05 21 F 07 n.oo n.on ~ 35

'WSW 7 7 ?5 In I n 45 4~]6

~ 2H 3~51 I 40 ~ ~ 14 0 ~ on 6 3) 0.00 ~ 0) ~ 78 ?

a (l4 2~ n 15

~ 06 a47 3

F 01 0 ~ n(I n o.oo 0 4~49 32 3 '4 Ol ~ U7 . o') .07 0 F 00 0 F 00 ~ 19 WIIW 3 lb 29 7 n 0 3 5]

~ <s? 2. In ss s) 1 i '9tt o.no 0 00 7 ~ !i7 NW ~ ~

07 56 4 09 14 s)6 3

~ I i'3 I

2~

~ 04 17 $8 o.nn '.2 F 28 O.on 0 F 00 0

8.42 32 60 4 '9 4 '9

n2 .ne 14 10 F 01 0 00 . )6 NNW 7 p i) 3? .) 0 14

~ 47 i<)8 4.ul 4 ~ ss9 ~ 4i.' 0 F 00 10 ~ 38 07 F 04 o]1 ~ 19 02 0 F 00 ~ 44 4 i) 30 ?n 1 0 64 4028 ~ 55 I ?h ~ 4 21 2~ Il ~ 14 0 00 8 ~ i)8 .]tt ~

n? F 05 F 12 ~ ol 0 F 00 ~ 38 CALH 5 CALH

.70 ~ 70 F 03 ~ 03 TOTAL 47 14'3 310 I s)2 3 713 4 ~ 12 6.59 ~ 2)$

20 ~ nh

~ <$ 5 43 ~ 4tt

1. s)5 26 93 1 15 2.8~ 11

~ ~

42 02 4 '6 100 F 00 xxx NUHHFR 0F OCCIIHHENCES XXX PERCENT ()CCUstALsVCtS Trt]S CLASS XXX PEACI.NT OCCUtttttttct.S ALL CLASSES
I

..).2-FSAR TASLE 2o3 35 JOINT MIND FRED(iENCY DISfRIUUtlON HY STAUILltY CLASS DATA PERIOD( SEPtE'IUEH I o 1976 " AUG)UST 31 O 1978 TAOILITY CLASS) PASOUILL 8 St. LIPCIE U~IT 2 Ata Soi(RCE: ON-Sl fE HUTCH NSON ISLANDq FLORIDA lllND SENSOR HEIGHT) b7 ~ 91 HETERS FLORIDA PO~EH aND LIGHT CO.

W IND BLIND SPEEi) CATEGU((IES(((ETERS PER SECOND) HEAN SECTOR an lo5 1 ~ 5 ') ~ 0 3oo 'boo 5 ' 7 ' 7 b 10 ' +10 0 TOTAL SPEED NNE ? 2.0~ 4.ln lo 0 F 00 n 0 ~ Uo 0 o.no 0 6 '71710 2 '3

.n .n3 ~ Ot) 0 F 00 n.'oo O.oo NE .n o4 ~ nl . ~ 4 OI 0 00 0 F 00 n

0 ~ no Oooo n o.on 0 F 00 n 1 '3023

~

2 ~ 07 ENE 0 il .3 7.57 o.oo n.nn o.nn O.nn U o.nn o.oo

~

nl 4l I

1

~

23 Ug 0 F 00 0 F 00 0 1 '402 F E I 0 n n 0 2 1 55

~ 41 ~ 4 U~ nn o.nn 0.'n 0 ~ no o.no ~ U2 ~ OI ~ ll o.on Uolio 0 F 00 ~ OI ESE ? I 0 0 2.47 F 02 1 ~ c'l ~ 4l ~ 4 0 ~ Uo o.no 2 H7 .nl .n2 Ol SE n.nn n ~ 4 o.on n ~

0 F 00 (I 0 0 00 0 F 00 0 0 F 00 0 0 F 00

~ ~

04 4 2 '0 o.nn F 01 n.oo ' 0 ~ Un 0 00 0 00 0 SSE o.nn n AH?

?

3.49 9 o.nn F 0 F 00 0 F 0 ~ nn 0

~

3 'S 0 F 00 ool o(o l,h4 3.4~

~ US 9

0 ~ Un 1 0 ~ OU O.OU 0 O.UO o.no n e.

~ 0 5

3 '5 SS((

~ 0 an?

7

nS :,)I o.no o.on ~ 09 2 0 F 05 I ~ 23 2 ~ I(7 I . ()4 ~ H2 ~ 4 0 F 00 02 an? .n S((

1 ~ 44 4 4.5

~ (I t) 2 ~ ((7 ~

o4 I) 82 0 00 0 F 00 U loon@

~ )0 3 '3 n2 :ni ~ 04 .n ~ ~ ol "0 O.on ~ Ib Its(t ) 0 30 3o49 ~ 4 3 ~ t)9 I ~ 44 0 ~ UU o.nn 12 ~ 30 .n .In)I ~ ng U.nO o.no ~ 4 ~ OS I Il 4 ~ I (I 3 2H 1 ~ 64 0 F 00 0

0 ~ no 0

~

9 ~ 43 IH 23 3 '7 0 ~ og F 05 F 02 0 F 00 0 F 00 F 14 ((NM 4 n 0 0 d 3ol4

~ 4 1 o?.I I ~ t)4 n.on 0 ~ On 0 F 00 3 ~ 2H 0 an? :nz 0 ~ i)0 0 OU o.on F 05 N(t I (I 7 0 U 0 2o77 o4 4. In )I 1 O.no 0 F 00 0 F 00 7.1H N()It ~ 0 n ~ (I )

4 'Ij

~ (14 U.nn ,n.'oo 0

0 F 00 0

~ ll 29 4 'S o.nn o.on an?

F 15 F 09

..}o o04 0 F 00 0 F 00 0 F 00 0 F 00 11 ~ ~ 4 AH?

2 9 ~ 4I

?3 2 ~ H7 7

0 F 00 0 Oooo 0

~

13 F 52 7 3 4 '8

~ 0 ~ ii I ~ 14 ~ l(4 0 ~ no 0 F 00 ~ 20 CALH n 0 CALH o.nn 0 ~ no o.nn 0 00 TOTAL 7)) 114 6 0 244 3o52 ~ ll 30.33 ~ )) 4 46. ~

4 6H 12 ~ )0

~ 19 2 ~ 4t) ~ 04 0 F 00 0 F 00 looooo 46 1 ~

HEY XXX N(IHUE(t Of nCCURRE((CES XXX PFRCENT OCCURRENCES THIS CLASS xxx f ERcEht occuRRENcl'.s A cLassEs
TAOLE 2o3-36 JOINT WINO FREO<<ENCY DISTR IUUT ION - DATA PERIOD: SEPTEMOER I ~ 1976 AUGUST 31 1978 al.l. wlNOS ST LUCIE UNIT 2 naia SO)lkCE: ON-Sl Tt . H)/TC)lINSON ISLAND~ FLORIDA

'HIND SENSOR HEIGHT) b7<91 f<L'TERS FLORIDA POWER ANO LIG))T CD ~

W I BIO WIND Sl EEl) CATEGO)lit 5 lMETERS PER SECOND) MEAN SECTOR 0 ~ 0-1 ~ 5 I ~ 5-3.0 3<0-5 ~ 0 5 ~ 0-7 5 7 ~ 5-10 ~ 0 plo ~ 0 TOTAL SPEED NNE 20 94 742 193 136 68 753 5 ~ 88

~ 17 o56 1 43 I o 14 ~ 80 40 4.45 )6 F 09 Inb ~ 63 73/

1.40 I ~ 09 167

.'t9 67 ~ 40 4 '0 778 5 '4 2/3 )96 969 ENE 16 F 09 I))8 t)4 1 61 Z06 1 ~ 69 1 ~ lb 90 ~ S3 5 '3 6 F 04 449 292 1307 6 F 07 ~ I I <) 2 '2 375 2ob6 1 73 0 ~ 1/

bol 1796 5 72 ESE

~

19 ll ~ /9 6bo 3 ~ <)4 3 '5 310 1 ~ 83 02

~ 49 10 '2 19 ll 14) ~ d> 3 ee) '8 S<<n 3 43 2Sl 1.40 27 F 16 )643 5 '9 SSE 18 <l I 3'l 0 5SA 274 II:)54 So82 F 11 ~ 54 2 ~ 31 3.?5 1 ~ 62 36 ~ 2l ~ /3 3)l I 2~7 )

373 1 ~

'9 l 90 ~ 53 ~ 0) 966 5 ~ '/1 4 '4 478 69 1046 4 F 58 SSW AD 33 ?0 196 1 ~ 16 2 '3 240 1-42 .41 ~

30 18 6 1'9 SW .36

~ i'1 III 1 ~ 01 4Z7 2.53 ?ZS .

1 ~ 33 0/ Sl ~ 23 14 5 969

'3 4.61 WS)/ 24 1.1<< 256 179 70 4 ~ 74 ~ 14 ~ l)2 1 ~ 51 F 06 41 .)8 4'.o) ~

37 22 1

~

lo 65 15n o09 ~ 66 39 ~

?5 15 3 '4 5<)9 4 '8 WNW 44 1)) 0 241 107 75 16 693 4 '4 AD ?6 ~ /7 1 43 1 ~ 11 44 ~ 09 4 bio NW 33 173 307 37:) I t.0 6 )Ioo 4 '3 ~ 20 1 ~ 02 2 ~ <"I 2 ~ i.' ~ Ib ~ 04 066 6ol4 NN)t .43 /2 l.2)438 1.37 ~

40 24 [

~

19 ll ~ 69 41 2?S 1 ~ 33 300 1 ~ /7 339 2 ~ 01 ~ lo7 63 6 '6 1059 6 '8 CALM 53 53 CALM

~ 31 o31 TOTAL 2

4SI

'7 ll2on~05 5630 33.30 5292 31.30 16 '5 2782 4 '2 748 16907 100 F 00 5 ~ 49 f)))H))FR 0F vaLlo 00sE)tvaT IUNS 1690/ 96 So PCTo NUNl)Ek OF I Nva) I 0 0<<SE)I va T I ONS 613 F 50 PC)A TOTAL NUMBE R Of 005tH)/AT I ONS I 7520 100 F 00 PCT ht Y XXX llllN<<tk 0) ()CC<lkktl)CES

TABLE 2.3-37 LONG-T~R~3 ANGE M'D EXTREME T" tiP~~TURES Ai&) AVERAGE RELATIV~ EPifXDZT AT NEST ?ALi4 BEACH,, FLORIDA o a Average Averages ( F) Extreme (o )b Relative nnntt Dailv trav Dailv Min Mean Hie teat Loveat Humiditv 5 January 75.0 55.9 65 5 89 27 73.5 Pebr'uary 76.0 56.2 66.1 90 34 71. 0 March 79.3 60.2 69.'8 94 69.5 April 82.9 64.9 73.9 99 66.5 May 86.1 68.9 77.5 96 70.0 June 88.3 72. 7 80.5 98 62 77.3 July 89.6 74.1 81. 9 101 66 77.0 August 90.2 74.4 82. 3 98 76.8 September 88.3 74.7 81.5 66 78.5 October 84.3 70.1 77.5 93 46 74.5 November 79.5 62.5 71.0 72. 3 December 76.1 57.4 56.8 90 30 71. 8 Annual 83.0 66.0 74.5 101 27 73.3 a) period of record: 1941-1970 b) period of =ecord: 1937-1977 Refer nce: U.S. Dept. of Commerce, 1977, Local Climatological Data Annual Surtmary with Comparative Data: Hest Palm Beach, Elorida, NOAA, Environmenta Data Service. 2,3 54
SL2-PSAR TABZZ 2'-38 AVc UQ- A?Kl W~~~ ~~~~d~g AND AV=~~i

"MED A ~" ST+ MCIZ SIT Avocage Ave@age Exarne (~) 'ala "ive

~ne Dail@ Mm Daflv Min Elahest IclVSS t Humid' 0 January 65 1 51 3 80 1 28.4 65 1 Pehruarp 66 9 53 4 60.3 82,0 37 ~ 6 69.6 iWcch 74.3 64 ' 69.3 88 9 47.8 72 2 Apt U. 76.6 67.8 72 3 90.5 57.7 67.4 80+? 72%7 76 5 86.0 61.5 73 02 June 84.2 76.3 80 2 90 ' 7L 8 77.6 85 5 81 3 89 8 7L 4 78.2 AQQQS ~ 84 9 77.7 81 3 90.0 72-5 75.2. Sepembe" &4 2 75 9 &0 1 89.6 70.5 74 8 Cc "beg 79 7 70.5 75.2 88.2 57. 0 6 I.5 Hevenheg 75 ' 65.3 70 3 99.9 50.0 70 7 Qecmbeg 71.4 59.2 65.3 82.8 41.9 68.3

77. 4 67. 6 72 5 99.& 71 6 pea"'cd cf retard: Sept~~'"e~ B75 ~ August 1978 2,3-65

SL2-FSAR TABLE 2e3-39 STATISTICS ANO DIURNAL VARIATION OF'ETEOROLOGICAL PARAMETERS OATA PERIOD: SEPTEMBER 1976 ANO 1977 DATA SOURCE < ON-SITE ST ~ LUCIE U NI T 2 HUTCHINSON ISLANOi FLORIDA FI OR IDA POWER ANO LIGHT CO ~ METEOROLOGICAL PARAMETERS (HEIGHTS IN METERS) REL ORY OEW ORY HUMID BULB POINT BULB

}0o56 10 ~ 56 10 ~ 56 58 '9 HOUR PCT OEG C OEG C OEG C 78.4 25.9 21.9 25+9 2 79 ' 25 ' 21 ' 25 ~ 7 3 80 ' 25 ' 22 ' 25 '

4 80 ' 25 ' 2' 25 ' 5 8)o} 25m} 2}eb 25 ' 6 81.7 25 ' 21 6 25 ' 7 81 5 25+} 21 ' 25 ' 8 77,0 26 ~ 2. 21.9 26 ' 9 72 ' 27oz 21 ' 26 ' 10 69 ' 27 ' 21 ~ 8 27 ' ll 67 ' 28 } 2}+8 27 ' 12 66 ' 28 ' 21 ' 27 ' 13 67 ' 28 ' 21 ' 27 ' 14 67eb 28.4 22 ~ 0 27 ~ 7

}5 68 ' 2' 22 ' 27 '

16 70.4 27 ' 21.9 27 F 1

)7 72.1 27.4 22 ' 26 ' )8 73 ' 27+0 21.9 26 ' )9 75 ' 26 ' 21 ~ 8 25 75 ' 26 ' 21.8 21 76 ' zbo} 2)o8 -

Z6 ~ 2 22 77+0 26 ' 21+8 26 ~ 2 23 76.8 26.0 Zl ~ 7 25+} 24 77 ~ 7 Zb ~ 0 2}.8 2' ABSOLUTE (AX }on.o 32 ' 24 F 4 3) ~ Z AvG QA ILv <Ax 85 ' 29'.0 22 ~ 8 29 ' ME AN CLI'4IATIC 74 ~ 8 74 ~ 3 26 '7 2) ~ 8 26 '

. IEA<V 26 2} ~ 7 Zbe5 A VG DA I> Y ~ }<V 63 F 1 24e4 25 ~: 24mb ABSOLUTE 38 ~ a .Zj ~ 4 Z}~(

STAXDARO OEV (j ~ d } <2 } <5 VALID OBS )347 )350 1353 }352 j7 INVALID OBS TOTAL OBS QAra RECOVERY

} 440 93 93 95 ),440 93 ad } 4~()

94 ~ 0

}'0 93 '

2:3-66
SL2-FSAR TABLE 2.3-40 STAT IST ICS ANO DIURNAL VAR I AT IQN QF METEOROLOGICAL PARAMETERS DATA PERIOD: OCTOBER 1976 ANO 1977 O DATA SOURCE: ON-SITE ST ~ HUTCH LUCIE UNIT 2 IiVSQN I SLAND e FLORIDA, FLORIDA POWER .AND LIGHT CQ. METEOROLOGICAL PARAMETERS (HEIGHTS IN METERS) REL DRY OE'A DRY HUMID BULB POINT But B 1O.Se lo.Se 10 56 58 '9 HOUR PCT OEG C QEG C OEG C 1 71e2 23 ~ 3 17 ~ 8 23 F 6 2 72 ~ 2 23 ~ 1 17 ~ 8 Z3 ~ 4 3 73 ' 22 ' 17m 8 23 ~ 2 4 74 ' 22o7 17 ' 23 ' 5 74 ~ 7 22 os 17 ~ 7 22 ~ 8 e 76 ' 22 ' 17 ' 22.5 7 75 ' 22 ' 17 ' 22 5 8 71 ' 22 ' 17 F 4 Z2 ~ 8 9 68 0 24 0 17 ' 23 F 6 10 64 ' 24 ' 17 F 6 24@3 11 61 ' 25 as 17 ' 25 ' 12 60 ' 25 ' 17 ' 25 ' 13 .6) ~ 2 25 ' 17 ' 25 ' 1'4 coal Zeal 17 F 7 Zs ~ 3 15 60 1 26.1 17 ' 25 ' 16 6O.4 25.7 17.4 25.1 17 6Z ~ 0 25 ' 17 ' 24 ' 18 64 as 24 ' 17 5 24 ' 19 66 ' 24 ' 17 ' 24 ' 20 66 ' 24 ' 17 ' 24 ' Zi 67 4 24 ' 17 F 6 24 ' 22 68 5 23 ~ 8 17 ~ 7 24 ~ 0 23 69 ' 23 ' 17 8 23 ' 24, 70 ' 23 ' 17 ' 23ob ABSQLU TE MAX 98 ' 31 ' 25 0 37 ' AVG OA ILY HAX 79 ~ 9 Z5 ~ 5 19 ~ 3 25 1 MEAN CLIMATIC ~EAN 5715 67 ~ 3 24+i 24 ' lee 17 ' 24 23 A~/G QA I> Y

>BSQLUT= '41N N IN 5' 35.9 Zl ~ 4 13 ' 15 ~ 3 21 '

13.8 STANDARD OEV 12 ~ 3 2 ' F 5 2' VAL IO OBS 1375 1376 137' 1376 INVALID QBS TOTAL QBS ll2 1488 112 1488 14&8 LZ 112 1488

'DATA RECOVERY 92 as 92 as 92 ~ 5 92 ~ 5 2.3-67

SL2-FSAR TABLF..2 ~ 3 41 STATISTICS AND DIURNAL VARIATION OF METEOROLOGICAL PARAMETERS DATA PERIOD: NOVEMBER 1976 AND 1977 DATA SOURCE: ON-S I TE. ST ~ LUC IE UNIT 2 HUTCHINSON I SLAND i FLORIDA FLORIDA POWER AND L IUH7 C9 ~ METEOROLOGICAL PARAMETERS (HE IGHTS IN METERS) REL DRY DEH DRY HUMID BULB POINT BULB 10 '6 10 ~ 56 10 F 56 58 '9 HOUR PCT DEG C DEG C DEG C 73 ' 20 ' 15 ~ 5 20 ' 74 F 1 20 ' 15 ~ 5 20 ' 74 ' 20 ' 15 ~ 3 20 ' 74 ' 19 ~ 9 15 F 1 2003 75 ~ 2 )9tb 15 ~ 0 20 ~ 0 6, 75 ' 19 ~ 4 14 ~ 9 19 ~ 9 76 ' 19 ~ 3 )4 ' 19 ~ 8 75 ' 19 ' )5o) )9o9 73.4 20-5 15.5 20.3 10 70 ~ 5 2)o9 15 ' 2) 6 ~ 67 ~ 3 22o8 )6 ~ ) 22 ' 12 66 ~ 6 23 ' 16 ~ 3 22 ' 13 65 ~ 8 23 ' 16 ~ 6 22 ' 64ob 23 ~ 5 )6 ~ 1 22+9

)5 64 ' 23.5 )6 ' 23 '

16 54 ~ 4 23 ' 16 ~ 2 23 F 0 17 6 e4 22.9 )So9 22e7 68.2 22.1 15 ~ 8 22.2 19 69 ' 2)o8 )So8 22 ' 20 70 ' Zl 5 F 15 ~ 9 21 ' 21 7) ~ 2 2),u )5 ' 21 '7 22 70.8 2).3 15.7 21.6 72.0 21.2 15 ~ 8 21 ' 72 ' 20o7 )F 6 21.1 ABSOLUTE 44X DAILY 100.0 82+3 37 24 '

~ 7 37 i'2 37 '

AVG MAX )deo 23o7 MEAN 70 ' Z)e4 15 ~ 7 21 ' CL)MATIC <EAN 70 ' 2)o3 15.6 2) 3 ~ >VG 04)LY <IN 57.9 ).'3 e5 )3 ' )8 ' ABSOLuTE ~l.'i 28 ' )0 ~ 0 ~ 0 9 ' STANDARD DEV )3 ~ ) 3 ' 3' VALID Ois 138u ) 393 )3)4 1393 )i]VALID OBS 47 <<6 47 TOTAL OPS 1440 luuo ')c 40 1440 DATA RECOVERY 96 ' Qe). 7 96' 96 ~ 7 1A
SL2-CESAR TABLE 2 '-42 STAT'ISTICS ANO DIURNAL VARIATION OF METEOROLOGICAL PARAMETERS DATA PFR IOO: DECEMBER 197b ANU ) 977 O DATA SOURCK: ON-SITE ST ~ LUCIE UNIT 2 HUTCH IiVSON ISLAND FLOR IOA FLORIDA POWER AND LIGHT CO. HETKOROLOG ICAL PARAMETERS (HEIGHTS IN 4IETERS) REL ORY OK'4 ORY HUMID 8UL8 POINT BUL8 10 '6 10 '6 10 '6 58 '9 HOUR PCT OKG C DKG C OKG C 71 ' 17 F 4 12oj 17 ' 71 d 17.3 12.1 17 7 72 ' 17oj 12 ' 17 F 6 73 ' 17 ' 12 ' 17 F 6 73.2 17oO 12 ' 17.5 73 ' 16 ' 12eO 17 ' 74 ' 16 F 7 12 ' 17 ' 7'0 74 ' 16 ~ 8 12 ' 17 ' 71 ' 17 F 6 12 ' 17 '9 68 ' 1'9 ' 12 ' 18 ' 11 65 ' 19 ' 13 ' 19' 5 12 63 ad 20 ' 13 ' 20 ' 13 62.1 20 ' 13.2 20 ' 14 51 ' 21 ' 13 ' 20.5 15 60 ' 20 ' 12 ' 20 ' 16 61 ' 20ob 12.9 20 ' 17 53 1 20 F 1 12 ' 19 F 9 18 65 ~ 4 19 ' 12.4 1'9 ~ 5 19 56 ~ 9 id' 12.3 19 ' 20 67 ' 18 ' 12.3 18 ' 21 68 ~ 8 18.2 12.3 18 ' 22 69 ~ 2 18 1 12e3 18 ' 23 70 1 18 ' 12 ~ 3 jd ~ 5 24 71 ~ 2 17.7 12.3 18.2 ARSOI UTK 4/AX 97.5 28 ~ 2 22 ~ 2 28oj AVG DAI! Y ~AX 80 ~ 2 21 ' 15.4 21+6 qKAN 68 ~ 3 18 ' 12 ' 18.8 Cl IWATIC <KAN bd ~ 3 13 ' 12a2 18o5 ILY + liV ' 15.5 e AVG OA 9 ABSOLUTE IIV 34 F 1 3 ' 5 ' STANDARD OKV 14 ' 4~7 bej F 6 VALID OSS 1464 1467 1 464 1467 INVALID OBS 24 21 21 OBS j 4dd 14od 9'

'OTAl DATA RECOVERY 98eb 98 ~ 4 98 F 6 2.3-69

SL2-PSAR TABLE 2 ' 43 STAT I ST ICS AND DIURNAL VAR IAT ION OF METEOROLOGICAL PARAMETERS DATA PERIOD: JANUARY 1977 ANO 1978 DATA SOURCE: ON-SITE ST ~ LUCIE UNIT 2 HUTCHINSON ISLAND e FLOR IDA FLOR I DA PO'WER AND L I GH T CO ~ METEOROLOGICAL PARAMETERS (HEIGHTS IN METERS) REL DRY DEw DRY HUMID BULB POINT BULB

)o.se )o.se ]o.se sa.49 HOUR PCT DEG C DEG C DEG C ) 70 4 13 ~ 5 8 1 14 ~ 1 2 71 F 6 13 ~ 0 8~0 13 ~ 6 3 7]o9 12 ~ 8 7 ' 13 ~ 4 72 ' ]2+7 7 ' 13 '

72 ' ]2+5 7' ,1?e9 72 ' )2 ' 7' 12 ' 72 ' 12 ~ 3 7 ' 12 ~ 8 71 F 6 12.3 7' 12 ~ 8 9 68 ' 13 ~ 3 7 ' 13 ~ 4 10 63 ' 14 ~ 7 7' 14.2 ll 60 ~ 9 15 ~ 9 8 ' 15 ~ 3 12 59+0 16 ~ 7 8 ' 16 ~ 0 13 57 ' 17 ~ 2 8.6 lsd'

]e.s ]4 56 F 1 17 ' 8+4 16 ~ 7 )5 56+6 )7eb 8~6 )6 ~ 9 16 56 ' ]7 ~ 4 as ]6 9 17 57 ' 17 ' 8 ~4 16 ~ 7 18 59.2 16.4 a~3 )eo4 )9 5].o 1S.a ]6 ~ )

20 21 22 62 ' 65.4 67m)

)F 4 )4,g ]> ~ 2 a.o 8~2 8 '

15 ~ 7 14 0 F 7 23 67.8 14 ~ 0 8~0 14 ~ 4 24 69.9 ]3 ~ 5 ad ]F 0 ABSOLUTE ~AX 100 ' 26 ~ 7 20 0 26 ~ 4 AVG DAILY MAX 80 ' 18 ~ 4 ])ob

~ )8 ~ 0 if'N 55 '1 )4 ~ 7 8 0 l4 8 CLIMATIC MEAN 56' )as N ~ ~ 2 ]4 ~ ~ 5 AVG DA I/Y 4 IN 5) ~ 9 )0 ' ~ 8 ]) ~ 1 AGSOLUTc <IN 5 ~ 0 2 ' 0~3 -)e9 STANDARD DEV ]4 i 7, 5~6 Q ~ 7 '3 ~ 7 VALID OBS ] 443 ]449 ]443 ]434 INiVALID OBS 45 45 TOTAL OBS 1488 1488 ]488 )488 DATA RECOVERY 97 ~ 0 47o4 97o0 96 '

S I.2>>FSAR TAOLE 2+3-44 TATISTICS ANO OIIIIIIIAL VAIIIATION Of HFTEOROLOGICAL PAMAHETERS Ata PitIIOOI FEBRUARY 1911 ANU 1978 OATA SOURCE: Ot~-SITE ST ~ L I ICIE Uttt I 2 HIII Ctt I NSUtt I SI.ANO ~ FLORIDA FLORIDA POIIER ANU LIGHT COo HETEOROLOGICAL I altaHEIERS IHEIGHTS IN HETERSI IIEL OHY OEIt ORY HUHIO IIUL8 POINT UULO 10 '6 10.56 10.56 Se.cv HOUR PCT OEG C OEG C UEG C I 75 4 Ic+5 IO ~ 1 IS.O 2 75 ' Ic ~ 3 9 ' lc ~ 8 3 76 ' 14 F 1 9~9 14 ~ 5 76 ' 13+9 9.7 14.3 71 ~ 6 13+ 7 9 ' Ic ~ 1 7' 13 ' 9 ' 13 ~ 9 78 ' 13 4 9.1 13 ~ 8 77 ' 13 7 9~8 Ic ~ 0 9 73 ~ 2 14 ~ 7 9 ' 14.5 10 67 F 4 16 ~ 2 10 ' Is+7 ll 64 ~ 1 17 ~ 3 10 2 16+ 7 12 62 ' 17+9 10 ~ 3 17%2 13 61 ~ 0 18 ~ 4 10.5 17 7 14 61 ~ I 18.4 10 ' 17 ~ 7 15 60 ~ 7 18 ~ 6 10 ' 17.8 16 61.2 18 ~ 6 10 7 17+8 17 62 ' 18 ~ 2 10 ~ 6 17 ~ 6 18 64 ' 17 ~ 4 10 ~ 4 17 ' 19 66 ~ 3 16 ' IO ~ 1 16 ~ 8 20 67 ~ 7 16 ' 10 ' 16 ' 21 69.6 lan 10 ~ 3 16 ~ 3 22 69+9 Is+ 8 10.2 lt ~ I 23 70 ~ 8 15 ' 10 ' 15 ' 24 73~3 14 9 10 1 15 4 AIISOLUIE HAX lnn.n 27,8 ?1 ~ I 9 AVID OAILY HAX 85+0 19 ~ 4 13.0 19 ~ 0 Ht.alt 69 ' '.i ~ 9 ln.g IS+9 CLIHAIIC HEAN 69 ' ) 15 7

-66 ' 7 Avtt Oa II.Y .HIN 53 ' If 9 ~ 12 ~ 3 AUSULUIE HIN 23 ' 3.1 StaNOaRO OEV IS ~ 1 4ob 5' 4 '

VaLIO OOS 1340 134) 1340 134( INVALID OBS 4 4 TOtAL AAS )344 ).I44 1344 )344 OAIA RECOVERY 99 F 7
SL2-FSAR TABLE 2e3 45 STATISTICS ANO DIURNAL VARIATION OF METEOROLOGICAL PARAMETERS DATA PER IOO ~ MARCH 1977 ANO 1978 DATA SOURCE: ON S ITE ST ~ LUC I E UNIT 2 HUTCH INSON I SLANO e FLORIDA POWER ANO fLOR IOA LIGHT CO ~ METEOROLOGICAL PARAMETERS (HEIGHTS IN METERS) HEL ORv OEw ORv HUM I 0 BULB PO INT BULB 10 '6 10 '6 10 '6 58 '9 HOUR PCT DEG C OEG C OEG C 1 7be0 19 ' 15 3 19 ' 76e9 19 ' 15 ~ 2 19 ' 78 ' 19 ' 15 ' 19e3 79 ' 18 ' 15 ' 19 1 79 F 6 18 ' 15 1 19 ~ 0 79 ' 18 ' 15 ' 18.9 79 ~ 0 18 ' 14 ' 18 ' 77 e4 19 ' )5 ~ 0 19 F 1 72e7 20 ' 15 ~ 1 19 ' 10 67e7 Zle3- 15 F 1 ZO ~ 7 ll 64 ~ 7 22 ' 15el 21 ' 12 13 63 65 '

' 22 22 ' ' 15 15 ' ' 21 21.8 ' .0 14 64 ' 22 ' 15 F 6 21e7 15 64 ' 22e9 15 ' 21 '

16 64 ' 22e7 15 ~ 7 21 ' 17 66 ' 22 ' 15 ' 21 ' 18 69el 21 ' 15 ~ 6 21 ~ 1 19 72 ' 20 ' 15 ' 20 ' 20 73 F 1 20 ' 15 F 6 20 ' 21 73 ' 20 ' 15 ' 20 ' 22 74 20 ' 15 ~ 6 20 ' 23 74 ' 20 ' 15 ' 20 ' 75e2 20 ' 15 ~ 5 20 ' ABSOLUTE MAX 98 ' 31 F 6 30 30 ~ 7 84 ' '0

~

A VG OA ILY MAX 23 17 22 '

' 15 ' 20 ' 'O MEAN 72 7 CL I '4A T I C HE AN 71 ' ~

ZV ~ 7 15,4 20 ~ 4 AVG OAI/Y ~IN 59 F 1 17.9 13 ~ 3 18. 0 ABSOLUTc, MIN 4>> ~ 1 8 ' 2 ' 7e8 STANDARD DEV ,12 ' 3 ~ 7 4)4 3.6 VALID OBS 1 46.7 1467 1471 1467 I%VALID OBS Zl 21 17 21 TOTAL OBS 1488 1488 1488 1488 DATA RECOVERY 98eb 98 ~ 6 98e9 98.6 2.~2
SL2-PSAR TABLE 2 ' 46 STATISTICS ANO DIURNAL VARIATION OF MKTKOROLOGICAL PARAMETERS OATA PERIOD: APRIL 1977 ANO 1978 DATA SOURCE: ON-SITE ST ~ L CIK U NIT 2 HUTCHfNSON TSLANOi FLONTOA FLORIDA POWER ANO LIGHT CO ~ MKTKOROI OG ICAL PARAMKTKRS (HEIGHTS IN MKTERS) RKL HUMID ORY BULB OKV POINT

'RY BULB 10 ~ 56 ]Oe56 1'6 58 49 HOUR PCT OKG C OKG C OKG C 71 2 2]+5 16 ~ 0 21.5 72 ' 2]oZ 15 ~ 9 21 '

72 ~ 2 20 ~ 9 15 ~ 7 20 ~ 9 72 ~ 8 20 ' 15 ~ 6 20 ' 73' ] 20 F 6 15 ~ 5 20 ' 73 ' 20N5 15 ~ 6 20mb 73 ' 2]o0 16 ~ 0 21 ' 69 ' 22 ' 16 ~ 2 21 ' 65 ' 23.1 16 F 1 22 ~ 2 10 62s5 Z3 F 7 16 ' 22 ' ll 6]o] 24 ' 16 1 Z2 ~ 9 12 60 ' 24 ' )6 ' 23+] 13 60 ' 24 ' 16 ~ 2 22 ' 60 F 6 Z4 ~ 5 16 ~ 4 23 ' 15 6]+6 24 ' 16 ~ 5 23 ~ 0 16 62 ~ 3 24+] 16 ' 23 '

]7 64 ' 23 F 7 ]bo5 22 '

18 65 ' 23 ~ 2 16 ~ 5 22 '

]9 68+2 ZZ+5 16 ' 22.3 20 69 ' 22 ~ 2 16 ~ 3 22 '

21 69 ' 22e3 16 ' 22o3 22 69 ' 22 3 16 3 22 ' 23 69.2 22+0 16 1 22.0 24 21.8 ]F 0 21.8 ABSOLUTE .lAX 93 8 32 ~ 5 2] 7 30 eb AVG OA ILY '4IAX 79 ' 24,8

~

17 ~ e 23 ' e? ~ 22.5 ]6+] 22 ' CL ]>AT IC >KAN .?

'?

22A4 15 ~ 8 2] ~ 9 AVG QA ILY MIN ]9,9 ]4+i 20'1 ABSOLUTE M]N )4 ' a.? )4 ' STANOARO QKV 1] 3

~ 2 ' 3 ' 2A0 VAL]O 085 ]409 14]0 1409 ]271 t "lVAI IO 085 3] 30 31 ]69 TOTAL 085 14AAQ 1440 ]440 )<<0 OATA RECOVERY 97 ~ 8 97 ' 97 ~ 8 88.3 2.3-73

SL2-FSAR TABLE 2 ' 47 STATISTICS ANO OIURNAL VARIATION OF METEOROLOGICAL PARAMETERS DATA PERIOD: MAY 1977 AND 1978 OAT A SOURCE: ON-SITE ST ~ L CIE U NIT 2 HUTCH)NSON ISLANOO FLONIOA FLORIDA POWER AND LIGHT C8 ~ METEOROLOGICAL PARAMETERS (HEIGHTS IN METERS) REL ORY OEW ORY HUMID BULB PO INT BULB 10 ~ 56 10 ~ 56 10 ~ 56 58 ~ 49 HOUR PCT OEG C OEG C OEG C 1 75 ' 23 ' 19.3 Z3 ~ 8 2 7bo4 23 ~ 7 19 ' 23 F 6 3 77 ' 23o5 19 ' 23 ' 78 ' 23 ' 19 ' 23 ~ 3 5 79 ' 23 ' 19 ' 23 ' 6 80 F 1 23 ' 19o4 23 F 1 7 78 ' 23 F 6 19 ' 23 ' 8 75 ' 24 ' 19 ' 24 ' 9 71 ' 25 ' 19 ' 24 ' 10 68 ' 25 ' 19 ' 25 ' 11 67 ' 26 ' 19 ' 25 ' 12 68 4 26 1 19 ' 25 ' 13 68 1 26 ' 19 ' 25 ' 14 68.4 26.1 19.8 25.1 15 69 ' 25 ' 19 ' 25o 1 16 70 ' 25 ' 19 ' 25 ' 17 70.4 25 ' 19 ' 25 ' 18 70 ' 25 ' 19 ' 24 ' 19 71 4 25 ' 19 ' ?4 ' 20 72 ' 24 ' 1953 24 F 6 21 73.7 24.5 19.5 24.4 22 74 ' 24 ' 19 ' 24 ' 23 75 ' 24 ' 19 F 6 24 1 24 75.9 2450 19 ' 24 ' ABSOLUTE MAX 98 ~ l 30 ~ 0 23 ' 29 ' AVG DA[l Y MAX 8451 26e8 21 ' 26 ~ 1 MEAN 73 ' 24 ' 19.5 24 ' CL IMAT I C MEAN 73 5 24 ' 19.5 24 F 4 AvG OA tLY <IN 63 ' 22 F 6 1850 22 F 6 ABSOLUTE M[N 27 ' }6 ~ 4 5 ~ lb' STANDARD OEV 12.2 1.8 1 ~ 7 VALID OBS INVALID OBS 74 I'5 1414 7w 14lb 72 TOTAL OBS 1~88 1488 l<c38 l488 DATA RECOVERY 95 ~ 0 95.2 95.0 95 2 2.3-74
SL2-FSAR TABLE Z ~ 3 48 STATISTICS ANO OIURNAI VARIATION OF METKOROLOGICAL PARAMETKRS OATA PERIOD: JUNE 1977 ANO 1978 OATA SOURCE o QN-S ITE ST ~ LUC IE UNI T 2 HUTCH INSON I SLANO FLOR IOA FLORIOA POWER ANO LIGHT CO ~ METEOROLOGICAL PARAMETERS (HEIGHTS IN METERS) REL ORY OEW ORY HUM IO BULB PO INT BULB 10 F 56 10 '6 10 '6 58 '9 HOUR PCT OEG C OEG C OEG C 8le 1 25 ' 22 ' 25 6 82 ' 25 ' 22 ' 25 ' 83 ~ 0 25 ' 22 ~ 2 25e2 83eb 25 ' 22 ~ 2 25 F 1 84 ' 25 F 1 22 ~ 2 25 ' 84ea 25 ' 22 ~ 3 25 F 1 8Z ~ 8 25 ' 22 ' 25 ' 8 78 F 6 26 ' 22 ' 26 ' 9 75 F 1 27 ' 22e 7 27 F 1 10 72 ' 28 ' 22 F 6 27 ' ll 7leb 28 ' 22 ' 27 ~ 8 12 7Z ~ Z 28 ' 22 ~ 9 27e7 13 72 ' 28 ' 23 ' 27 ' 14 71 ' 2' 23 ' 27e7 15 72 ' 28 ' ZZe9 Z7 F 6 16 73 ' 27 ' 22e9 27 ' 17 75 ' 27 ' 22 ~ 8 27 ' la 75 ' 27 ' 22e6 26 ' 19 76 ' 26 ' 22 ' 26 ' 20 76.8 26eb 22 ' 26 F 4 21 77 ' 26 ' 22 ~ 3 26 ' 22 7' 26 ' 22 ~ 3 26 ~ 0 23 79 ' 26 F 1 22 ' 26 ' 24 80 ' 25 ' 22 ~ 4 25 ~ 8 ABSOLUTE MAX 98e2 32 ~ 6 26 ' 33 ' AVG OAILY !WAX 87 ' 29 ' 23'.a 28 F 6 MEAN CLIMATIC MEAN 77 F 6 77 ' 2' ' 25 22.5 22 ' 25 ' 26 ' AVG OA ILY MIN

>IN 67 ' 24.6 21 ~ 2 17 '

24e5 ABSOLUTE 42e5 22 F 1 22 F 1 STANOARO OKV 1.8 1 ~ 4 VALIO OBS 1333 1333 1334 1333 154 INVALIO OBS TQTAI OBS OA TA RECOVERY 155 14aa adeb

)'a 155 14aa a'9 ~ 7 155 14aa 89 6 F

2.3-75
SL2-FSAR TABLE 2 ' 49 STATISTICS DATA PERIOD: ANO DATA SOURCE: DIURNAL VARIATION OF METEOROLOGICAL PARAMETERS JULY 1977 ANO 1978 ON S I TE ST. LUCIE U NIT 2 0 HUTCHINSON ISLANOe FLORIDA FLORIDA POWKR ANO LIGHT CO ~ MKTEOROLOG I CAL PARAMETERS (HEIGHTS IN METERS) REL ORY OEw ORY HlJM I O BULB POINT BULB 10.56 10.56 10 '6 58 '9 HOlJR PCT OEG C OEG C OEG C 83 1 26 F 4 23 ~ 3 26 ~ 3 83 ' 26 ' 23 ~ 3 26 ' 83 ' 26 ' 23 ~ 3 26 ' 84 ' 26 ' 23 ~ 3 26 ' 84 ' Z6 ~ 0 23 ~ 3 26 ' 84 ' 26 F 1 23 ' 25 F 1 82.8 25.6 23 ' 26 ' 78 ' 27 ' 23 F 7 27 ' 9 75 ' 28 ' 23 ~ 7 28 ~ 2 10 72 ' 28 ' 23 F 6 28 ' 11 71ob 28 ' 23 F 4 28ob 12 72 ' 28 ' 23 ' 28 ' 13 71 ' 29 F 1 23 F 6 28 ' 14 71 ' 29 2 23 ~ 7 28 ' 15 72.3 28.9 23 F 6 28 ' 15 73ob 28 ' 23 6 28 ~ 3 17 74 ' 28 ' 23 ' 28 ' 75 ' 28 ' 23+5 27 ' 19 77 ' 27 F 6 23 ' 27 ' 20 78 F 7 27 ' 23 ~ 2 27 ' 79 ' 27 ~ 0 23 ~ 2 26 ' 22 80 F 6 26 ' 23 ~ 3 26 ~ 7 23 82 ' 25 ' 23 ~ 4, Zbob 82.8 25.5 23 ' 25 ' ABSOLUTE "dX 100 o0 32 ~ 1

' 26 31 '

>VG DAILY MAX 89.0 29 24 29 ' MFAN 78+i 27~b 23 ' 27 ' CLIMATIC ~KAN 78 ~ 3 27 ~ 4 23 ' 27 ' AVG DA tl Y 57+3 25 ' 22 ' 25 ~ 1 SOLUT= utN 55' 21.9 20 ' 22 ~ 2 STANDARD 3KV 7 ~ 7 1.7 1 ' 1 ~ 5 V~LID OHS 1 4' tw<7 1465 1467 tuVALIO 085 23 21 23 21 TOTAL 08S 1<ed 1~8'8 1488 148b DATA RECOVER PV 't 8 ~ Q F 6 98 ~ 2 98 ~ b 2.3-76
SL2-PSAR TABLE 2 ' 50 STATISTICS aNO DIURNAL VARIATION OF MKTKOROLOGICAL PARAMKTKRS OATa PKRIOO: AUGUST 1977 ANO 1978 OATA SOURCE: ON-SITK ST ~ L CIE U NIT 2 HUTCHKVSON ISLAND ~ FLORIDA FLORIOA PO'AKR ANO l IGHT CO ~ MKTKOROLOG ICAL PARAMKTKRS (HEIGHTS IN METERS) RKL ORY OEv ORY HUM I Q BULB POINT BULB 10 F 56 10 F 56 10 '6 58.49 HOUR PCT QEG C OEG C OEG C 78 ' 26 ' 22 ~ 6 26 F 6 79 ' 26 ' 22 ' 26 '

.3 79 ' 26 ' 22 ' 26 '

80 ~ 0 26 ' 22 ' 26 ' 80 ' 26 F 1 22 ' 26 ' 8' 26 F 1 22 ' 26 ' 79Rb 25 ~ 4 22 ' 26R5 76 ~ 1 27 ~ 3 22 ~ 8 27 ~ 0 72 ' 28 ' 22 F 7 27 ' 10 70 ' 28 ' 22 ' 27 ' 6' 28 F 6 22 ' 28 ' 12 6' 28 F 6 22 ' 27 ' 13 69 ~ 8 28 ~ 7 22 ~ 8 27 ~ 9 14 69 ' 28 ~ 9 22 ' 28 F 1 15 70 ~ 1 28 ' 22 F 9 28 F 1 70 ' 28 ' 22 ' 28 ' 17 71 ' 28.4 22.9 27 ' 73 ~ 3 27 ~ 8 22 ~ 6 27 e4 19 74 ~ 8 Z7 ~ 3 22 ~ 5 27 ~ 2 76 ' 26 ' 22 ' 27 ' 21 76 ' 26 ' 22 ' 27 ' 22 77 ' 26 ' 22 ' 27 ' 23 77 4 26 ad 22 ' 26 ' 79 1 25 ~ 7 22 F 6 26 8 a8SOLUTK Max IOn.O 32 ~ 2 25 ~ 6 31.4 avG Oa ILY Max 94 ~ 3 29 ~ 4 23 F 6 28 ~ 5 uK gg 75 ' 27 ' ZZ ~ 6 27 ' Cl IMn TIC F FAN 75 ' 27 ~ 4 22 ~ 5 27 ' avG Oa Il g 'LIIQ a& ~ I 25.4 21 eS 25 ~ 6 4+SOLUTE +5 ~ b 2ZA5 18 ~ 3 22 ~ 8 STANOaRG OKV 3 ~ 2 1 ~ 5 lou 1 .'2 VaLIO OelS 1407 140 7 14$ 7 1407 INvaL IO OHS dl vl el dl ~)TaL )85 14dd 14dd <<88 lund a PKCOvK~Y 9uob 9ueb 94 ' 9u,b 3-77
SLZ-FSAR

-51 STATISTICS OATA PERIOO:

OATA SOURCE: ANO OIURNAL VARIATION OF METKOROLOGI CAL PARAMETERS SKPTEMBER )o ON S ITK 1976 - AUGUST 3)> 1978 ST ~ LUC IK UN I T 2 HUTCH INSON I SLANO e FLOR IOA 0 FLORIOA POWER ANO LIGHT CO ~ lory MKTEOROLOG I CAL PARAMETKRS (HE IGHT5 IN METERS) REL ORY OEW ORY HUMIO BULB POINT BULB 10 ~ 56 10 ~ 56 56 58 '9 HOUR PCT OKG C OEG C OEG C 1 75 ' 2' 17 ~ 0 21 ~ 7 2, 76+2 2) ~ 3 16 ~ 9 21 ' 3 76 ' 2) ~ ) )6'o9 Zl ~ 3 77 ' 20 ' 16 ~ 8 2) ~ 2 77 ' 20 ' 16 ~ 8 2) ~ 0 78+4 20 ' 16 ' 2) ~ 0 77 75 71

1 20 Z2 ~ 4 )be9 17 ~

17 ~ 0 0

2) ~ 1 21 F 6 22 ~ 2 10 68 ' 23 ~ 3 17. ~ 1 22 ~ 9

~ ll 66 ' 23 ' 17 ~ 2 23+4 12 65 ' 24 ' 17 ~ 3 23+6 13 65 ' 24i4 17 o4 23+6 14 64 ' 24 ' 17 ' 23 '

15 65 ' 24 ' )7+4 23+7 16 65 ' 24 ' )7+4 23 F 6

)7 66 ' 23 ' 17 ~ 3 23 '

18 68 ' 23 ' 17 ~ 2 23 ' 19 70 ' 22 ' )7 ' 22 ' 20 71 oS 22o5 )7o) 22 F 6 Zl 72 ' 22 ' 17 F 1 22 ' 22 73 ' 22 ~ 2 )7 ' 22 ' 23 73 ' 22 ' 17.) 22 ' 24, 74 ' 21 ' 17 ~ 0 21+9 ABSOLUT'E MAX lon.o 37 ' 37 ~ 2 37 ' AVG QAII Y 83+5 Z5o2 19 ~ 0 24 ' MAX'EAN 71+6 22oS )7 ) ~ 22 ' CLIMATIC MEAN 7) ~ 6 22 ' )7 ' 22 ' AvG OAILY wlN 59 ' )9 ' 15 ~ 0 20 ' ABSOLUTE uIN 23 2 -2 ' 8 ' )~9 STANOARO OEv 12.5 5,g 6~3 5~3 VALID OBS )bdo) )6828 16812 ) 6676 INvALIO oeS 7)9 692 708 844 TOTAL OBS )7520 17520 17520 7520 OATA RECOVERY 95 ~ 9 96 ' 96 ' 95 ' 2,3-78
SL2-FSAR " TABLE 2.3-52 PRECIPITATION DATA AT WEST PAL'4 BEACH'LORIDA Gr latest Manm Mean Total (inches) 24-Hour (inches) January 2.60 6 '6 February 2 60 4 '0 March 3 32 4 88 .April 3+51 15. 23 May 5 ~ 17 7.04 June 8 '4 9.21 July 6.52 5.83 August 6.91 5.89 September 9.85 8.71 October 8.75 F 58 November 2.48 5.52 December 2. 21 5.26 Annual 62.06 15. 23 a) period of record: 1941-1970 b) period of record: 1939-1977

Reference:

U.S. Dept. of Commerce, 1977, Local Climatological Data-Annual Summary with Comparative Data: West Palm Beach, Flor'da, NOAA, Environmental Data Service. 2.3-79
SL2-FSAR TABLE 2.3-53 PRECIPITATION DATA AT THE ST. LUCIE SITE Month Mean Total (inches) January 2 65 February l. 00 March 1.74 April 2 77 May 2.07 June 1.37 July 3 27 August 4. 19 September 4.11 October 2.78 November 2.78 December 2.93 Annual 31.58 period of record: September 1976 - August 1978 2.3-80

'L2-FSAR TABLE 2 '-54 FREO(JEtJCY DISTR IBUT ION OF I'l(ECIPI TAT ION DATA PERIOD: SEPTEWIER 1976 AIJD 1977 DaTa souRcEI oN-slTE ST. LUCIE uNIT 2 HUTCHINS(ltJ I Sl AIJD ~ FLORI DA FLORIDA POWER AtID LIGHT CO ~

PRECIP I TAT ION FREOIJEiJCY FIIEOUENCY FREo(JENcv FREOUENCY FREOUENCY FREDUENcv CLASS DISTR IBIJT ION OF DI.JTRIOUT ION OF DISTRIBUTIOIJ OF DISTRIBUTION OF DISTR I(JUT ION OF DISTRIBUIIOtt OF itJTL RVAL PREc IP I Ta I 10N PJICC IP I TAT ION PRECIP I TAT ION PREC IP I TAI ION PREC IP ITATI ON PRECIP I TAT ION ( ltJCHE5) I HO(JII 2 HOUR 3 HOUII 6 HOUII 12 HOUR 24 HOUR I OUIJA IOII DURATION DURAI IDN DURATION DURATION DURATION t)0% PCT. NO. PCT NO PCT. NO PCT ~ NO ~ PCT% NO ~ PCT

~ 0 TO ~ 1 21 52 50 2 16 67 0 000 0 F 00 0 0 F 00 0 0 F 00

25. 0II 20.00

~ ~

I ( TO 10

~ ~

f 2 4 8 20 00 3 2 2 Ib,bl 20 '0 20.00 0 F 00 I:tlj 0 0 0 0 00 0 F 00 0 F 00 0 0 0 0 F 00

,0 F 00 0 F 00

4 Tn .5 2.50 0 o.no 0 F 00 0 0 F 00 0 0 F 00 5 10 6 3 7.5O 0 0.00 0 0 F 00 0 0 F 00 0 0%00

~ 6 10 ~ 7 1 2 50 0 0 F 00 o o.on 0 00 0 0 F 00 0 0%00 .7 10 ~ 8 0 0.00 2 lb.67 0 0 00 0 00 0 0 00 0 o.'no o.'no F F F ~ 8 10 ~ 9 0 0 00 n o.no o 0.00 0 0 F 00 0 0 F 00 .9 tO .0 0 0.00 0 n.oo I 20%00 0 F 00 0 0 F 00 0 0%00

n ro I 0 o.no 0 o.on 0 0 F 00 0 00 0 00 0 00 I: 2I

~ 10 ~

0 0.00 0 0.00 o o.nn F 0%00 0 0 F 0%00 0 0 0 F 00 I 1() ~ 3 0 O.nn 0 0 F 00 0 0 ~ 00 0 F 00 0 o.'on 0 0 F 00

~ li 0 n.oo 0 o'.no o n.no 0 F 00 0 0 F 00 0 0 F 00 0 0 00 F 0 o.no 0 0 F 00 0 ~ (in 0 0 F 00 0 0 F 00 ~ 6 0 n.on 0 0 F 00 0 0 F 00 n'.oo 0 0 00 0 0 F 00 ~ 7 0 0 F 00 0 0 F 00 0 0 00 0 F 00 0 0 F 00 0 0%00 0 o.nn ~

0 0.OO 0 0 F 00 0%00 0 0 00 0 0.00 I 2%50 0 0 F 00 0 0 F 00 0%00 0 0 00 0 0 00 o.'on F 0 0 F 00 0 0 00 o 0%00 0 0 F 00 0 0 00 2.'0 In 2~2 0 0 F 00 n o.no 0 0 F 00 0 F 00 0 0 F 00 0 0 F 00 2' 10 2.4 0 0 F 00 0 n.oo 0 0 F 00 0.00 0 n.oo 0 0 ~ 00 2 ~ 4 1() 2 6 0 0 F 00 I 8 ~ 33 I 2o.on 0 F 00 0 0 F 00 0 0%00 to 2.8 0 0.00 0 0.00 0 0 00 0.00 0 0 00 0 0 00 i' 8 10 3 0 0 F 00 0 0 F 00 0 F 0.00 0 00 0 0 F 00 0 0 F F 00 3'.n ro 3 0 o.on 0 0 00 0 0 F 00 0 F 00 0 0 00 0 0 F 00 3 ' 10 3 ' 0 o.nn 0 0 F 00 0 0 ~ nn 0 F 00 0 0 F F 00 0 0 ~ 00 3 4 1() 3.6 0 0 nn 0 0 00 0 0 F 00 0 F 00 0 0 F 00 0 0 F 00 3 6 10 3.8 4.'n 0 0 00 0 o.on 0 0,00 0 F 00 0 0 F 00 0 0 F 00 3,8 4.'0 1() 0 0 F 00 0 0 F 00 0 0 ~ nn o.oo 0 0 00 0 0 F 00 o .'nrt F to 4 i3 0 0 F 00 0 0 0 F 00 0 F 00 0 0 F 00 0 0%00 4.5 5.'n to 10 5 0 0 0 ~ 0(J 0 0 F 00 o o.on o.'on 0 0 F 00 0 0 F 00 5.5 6.'n 0 0 F 00 0 o.'no 0 0 F 00 0 F 00 0 O'.Oo 0 0 F 00 5 ~ 5 10 0 0 F 00 0 o.no o o'.on 0 F 00 0 0 F 00 0 0F 00 6 ~ 0 10 6.5 0 n.oo 0 0 F 00 0 0 00 o.'oo 0 0 00 0 0F 00 6 ' 10 7.n 0 o.'nn 0 0 F 00 0 0 00 o.'no 0 0 00 0 0 F 00 7 0 7'

~ 10 7 '

8 0 0 0 F 00 0 0 F 00 O O.OO 0 F 00 0 0 00 0 0 F 00 TO 0 0 F 00 0 0 F 00 0 0 F 00 0 00 0 0 00 0 0 F 00 9' F 8 0 ~ 10 o'.n 0 o.on 0 0 F 00 o o.'no 0 F 00 0 0 F 00 0 0 F 00 9 ~ 0 10 0 0 F 00 0 o.on n o'.oo 0 F 00 0 0 F 00 0 oino O.O Tn l.'o To GT 1%0 2 ' 2 0 0 0. 0 0 0F

'000 0 F 00 0 0

0 0 F 00 0.00 0 F 00 0 0 0 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 0 00 0 0 0 0 F 00 0 F 00 0 F 00 0 0 0 0 F 00 0 F 00 0 F 00 TOTAL 40 100 00 12 100 F 00 5 100 ~ 00 0 F 00 0 0 F 00 0 0 F 00 HAXIHUH AHA 1.86 2%43 2%51 0 F 00 0 F 00 0 F 00 TOTAL PRECIPITATION FOR DATA PERIOD 8%22 INCHES OBSERVATIONS MITH NO PRECIPITATION 085(Rvallo)ts )IIJH pREclpllalloN NO. 1400 40 97 '2 PCT

'8 VALID OBSERVATIONS INVALID NO 1445 PCT 100 ~ ob 0 00 Tllrh) iihi t() nfl< l>iihr tnt ~ <

GE 0 %01 INCH 1/hn 2 snn'nn Tnrhi - nniOOSERvATIONS viJiihr tnhic -') ann0 s nn nn
TABLE 2 '-55 FREOuENCY OISTRlBUTlow OF PftECIPITATION DATA PERIOD: OCTOHEH 1976 Af40 1977 ISLANDED DATA SOURCE) OW-SITE ST LUCIE UNIT 2 HUTCHINSON FLORI DA FLORIDA POWER At)D LIGHT CO. PRE C IP I T a T ION FREouENcY FREOt)ENCY FREouEwcY FREQUENCY FREQUENCY FREOUENCY CLASS INTERVAL DISTHI)H)T ION OF PREC IP I TAT ION DISTR I BUT tow 0F PRECI) ITATION D I S TH I I) I) PREC I Int) IP I TA't ION OF DISTRIBUTION OF PREC I P I TA I'ON DlstHIBUTIow PRECI) ITATION oj DlsTHIButlow PRECIPITATION 0F I It)CHES) I Hnt)R 2 HOUR 3 Knt)R 6 HnuR 12 HDUR 24 HOUR DuHAT low Dl)HAT I 0tf DURAT lntf OURAT ION OURATIOtf DuRATlow Nn~, pet~ NO( 26'.(> No) PC/) NO PCT NO ~ PCTy 0.00 NO) PCTo oo TO

~ 1 ~ 2 TO fn ."2 3

I 4 3 7 ~ A+45 27 6 31 58F S.26 3 o 33 '3 Q.oo 0 0 F 00 50 F 00 0 F 00 0 0 0 0 00 0 F 00 0 0 0 F 00 0 F 00 0.00

~ 3 In .'5 0 0 F 00 10 53 0 0 F 00 0 0 ~ no n o.'oo 0 0 ~ 00 fn 5.45 5.26 n.'Qo 0,00 22 '2 ~ 4 3 o 0 0 00 0 0 F 00 0 .5 ft) ~ 6 I I .t)2 2 10.53 2 0 0 F 00 0 0 F 00 D 0 F 00 ~ 6 TO ~ 7 1 1.0? 2 ln 53 n o.'oo 0 0 F 00 0 0 F 00 0 0.00 ~ 7 fn t) 0 0 ~ on 0 F 00 2 2?.22 0 DODD 0 0 F 00 0 0.00 ~ A fn ~ 9 0 0 F 00 0 Q.nn 0 0 F 00 0 0 F 00 0 0 F 00 0 0.00 fn .0 o n.'ou 0 0 F 00 0 0 00 50 F 00 0 0 00 0 0.00 ~ 0 fn 0 0 ~ DQ o'.on 0 o'.no 0 noon 'on 0 0 ~ DD 0 00 0 0 00 ) fn o 0 0 ~ Qo o o. 0 0 F 00 0 0.00 ~ 2 fn ~ 3 o o.no 0 0 00 0 0 ~ no 0 0 00 0 0 F 00 0 0 F 00 ~ 3 fn ~ 4 0 0 00 0 0.00 0 0 F 00 0 0 F 00 0 0 F 00 0 O'.nO ~ 4 Tn .5 0 0.00 0 0 F 00 0 0 ~ nn 0 0 F 00 0 0 ~ QD 0 0 ~ 00 I ~ 6 0 000 0 0 F 00 o o.no 0 0 F 00 0 0.00 0 0.00 ~ 6 tn 7 0 0+QQ 0 0 ~ Qn 0 0 F 00 0 o.no D 0 F 00 o o.'ao ~ ~ ~9 7

A

)n fn ~ A .9 0

o o 0

'.on . n.oo 0 ~ Qn 0

0 0 0 00 0 00 0 F 00 0 0 o 0 F 00 0 ~ 00 o'. on 0 D 0 0 F 00 0 ~ 00 o.no 0 0 0 0 F 00 0 F 0.00 00 0 0 F 00 0 F 00 2' tn 2.2 0 oi00 0 0.00 0 0 F 00 0 0 ~ 00 0 0 00 F 0 0 F 00 2.2 10 ?.4 0 0 ~ (la 0 o.nn 0 0 F 00 0 0 00 0 0,00 0 0 ~ QQ 4 fn 2.6 0 0 F 00 0 0 F 00 0 0.00 0 0 00 0 0 F 00 0 0 F 00 2' fn ?.)1 0 0 F 00 0 0 F 00 0 0 ~ QQ 0 0 ~ 00 0 0 00 0 0 ~ QQ

2. I) ft) 3.0 o o.no 0 0 F 00 o o.'no 0 o.no -0 0 ~ 00 0 0.00 3.0 fn 3.2 0 0 F 00 0 n.oa 0 0 F 00 0 0.00 0 0 F 00 D Q,DQ 3.? 10 3.'6 3' 0 0 ~ nn n 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00

'I ~ 4 TO 0, 0 00 0 0 F 00 0 0 ~ QQ 0 0 ~ no 0 0 F 00 0 0,00 3+6 fn 3 t) ~ 0 Qooa n 0 00 0 0.00 0 0 F 00 0 000 0 '.0000 0 Dn 3 ~ t) fn 4.n 0 0 F 00 0'.r 0 0 F 00 0 0.00 D Dorm o o.no 0 4~0 fn 4 ' o n 0 0'.no 0 oooo o'.on 0 0 F 00 0 0 F 00 0 0 F fo AKING S.n 0 D t)0 0 0 F 00 0 0 0 F 00 0 0 F 00 o a'.oo 5.0 fn 5' o n.oo 0 0 F 00 0 0+00 0 0 F 00 0 0.00 0 0 ~ 00 5.5 Tn 6.'n o o.on a 0.00 0 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 an 6.5 Tn I()

6 7~0 0 0 0 f)0 0 ~ 1)0 0 0 o.no 0 ~ nn 0 0 0 F 00 0 00 0 0 0 F 00 0 F 00 0 0 oman 0 00 0 F 00 an fn 7.5 A'. o 0 0 QO 0 F 00 0 0.00 0 0 F 00 0 0~00 0 D DO 7.5 tn O O.nn 0 0 F 00 0 Dion 0 0 F 00 0 0 F 00 0 0,00 8 0~ fn 9~0 o n.'Qo o'. on 0 0 F 00 0 000 0 0 F 00 D 0 00 F 0 0 F 00 9.0 tn 0.'O o 0 0~00 o o.oa 0 0 F 00 0 0 00 F 0 0 ~ Oo Io.o fn I ~ 0 0 oono 0 0 ~ 00 0 0~00 0 0 F 00 0 0 F 00 0 000 11 ~ 0 Tn 2.o 0 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 GT 2.0 0 0 ~ 00 D ADD D 0 F 00 0 0 ~ OD 0 0 F 00 0 0 F 00 TOTAL 55 1D'0 F 00 19 100 00 9 100 ~ 00 100 F 00 0 0 ~ 00 0 0 F 00 HAXIHUH 61 ~ 70 ~ 74 ~ 93 0 F 00 0 ~ 00 TOTAL PftfcIPITAT IDN F0R DATA PEH IOD 5 55 INCHES OBSEHVAT Inws )tl TH NO PRECIPI TATION OBSFRVATlnwS MITH. PRECIPITATION GE 0 ~ ol INCH NO 1433 55 PCT

'0 3 '0 96 ~

VALID OBSERVATIONS INVALID OBSERVATIONS NO ~ 1488 0 PCT Ioo.oh 0 F 00 TOTAL VALID OBSE RVAT IONS 1488 100 ~ DD TOTAL OBSEHVAT IONS 1488 100 ~ DD a

-PSAR TABLE 2 '-56 FRfnlJENCY DISTIJIBUT lntl OF PRECIPITaTION f)ala PERIOD) NOVEtlBElt 197l AND 1977 DATA SOURCE) OI4-SITE ST ~ LIIC IE UNIT 2 HUTCHItJSON ISLAND~ FLORIDA FLORIDa POWER awD LIGHT CO.

PREC IP I TAT ION FRED<st. tlCY FREolJENCY FREOUENCY FREOlJENCY FREOUEwCY FRED) JENCY CLasS DtSTRIUJJTIOrl OF Dl STR I BlJT ION OF DISTRI))IJT ION OF DISTR)BI)Trow OF DISTRIBUTION OF DISTIIIBUT ION OF I N T El I V 4L PJIKC IP I Za I ION PRE C IP I TAT ION PRECISE ITAIION PRECIPITATION PREC IP I TAT ION PREC IP I TAI ION llNCHES) I HOJ)lt 2 HOUR 3 HOUR 6 HOUR 12 H OUR 24 HOUII 0uc> a I I ow DURATION DURATIOtJ DURAT 1otl DURAT ION DUR AT IOtl NO ~ I'CT NO. Pcr NO ~ PCT NO PCS NO ~ PCT% tlo ~ PCT.

.n rn rn ) 35 6

71.43 12 ~ 24 ll so.on 18 )8 3 2 30.00 2o.'no 0 I 0 00 2S F 00 0 0 F 00 0 F 00 0000 6 ~ J2 2 V.n J 0 n.oo

~ 3 ron .4 2~ 4 =10 ~ JI0 0 0,00 ~ 4 ro .5 4 ~ 08 4.55 0 0,00 0 0.00 0 F 00 .5 rc) 6 0 F 00 0 0 F 00 0 0.00 1 25.00 0 0%00 ~ 6 IO .7 0 F 00 1 4.55 Io 00 0 o.on 0 0.00 0 F 00 ~ 7 IO .8 F 04 0 0 F 00 0 .0 ~ no 0 0 F 00 o.on ro 0 00 0 F 00 00 %8 .9 Io .n rn ~

0

)

0 0

? ~ 04 o.'n o.on 0

n I 4 '5 0%00 0 F 00 0 o o 0%00 o.'on n'. on 0 0 0" o.on 0.00 0 0 0 0 F 00 0 00 0 F 0%00 0 F 00 rl) ? 0 0 F 00 o,nQ -0 0 ~ 00 0 n.no 0' 0 F 00 0 F 00 Il) ~ 3 0 0 F 00 I 10 ~ nn 0 F 00 0 F 00 0 F 00

~ 3 II) 4 0 o.nn 0%00 0 ~ 00 0 ~ on 0 0 F 00 0.00 ~ 4 I') .5 0 0 nn 0 0 F 00 lo.no n.'no 0 O.On 0 F 00 .5 TO .6 0 o.on 0 0 F 00 0 0 F 00 25 F 00 0 0 F 00 0 o'.on .6 TO .7 0 0 F 00 0 o.on o o.on 0 0 F 00 0 n'. oo 0 0%00 .7 rn I.e9 0 n.oo o.'on 0 0 00 o o.no 0 0 F 00 0 0 F 00 0 00 0 0 F 00 0 F 00 ~ Jl f l) I 0 0 O.on 0 0 F 00 0 0 00 0 0 ~ 9 ro 2.0 0 0 ~ nn 0 0 00 o o'. on 1 25 F 00 0 0%00 0 0 F 00 ? 0 fl) ~ 2.2 0 0 ~ 00 0 0 F 00 0 0%00 0 0 F 00 I 100 F 00 0 0 F 00 ? ~ 2 ro 2.4 0 0 F 00 n 0 F 00 o o.'no 0 0.00 0 0 F 00 0 0%00 2 4 ro 2 ' 0 0.00 0 0.00 0 0 F 00 0 0 F 00 0 o.'oo 0 0 F 00 2.6 rn 2.'0 0 o.'nn 0 o.nn o o.no 0 o.'no 0 0 F 00 0 0 F 00

2. s) ) l) 3.0 0 n.on 0 0 F 00 o o.'no 0 0 ~ 00 0 0 F 00 0 0 F 00 3' ro 3.2 0 0 00 0 o'. no 0 000 0 o.'on 0 0.00 0 0 F 00

'3 2 ro ~ 3 ' 0 0 ~ 00 n 0%00 0 0 ~ 00 0 0 F 00 0 0 F 00 0 o.no F 4 ro 3 6 0 0 F 00 0 0 F 00 0 0 ~ nn 0 0 F 00 0 0 F 00 0 0 F 00 3.6 ri) 3 ~'nsl 0 o.nn 0 o.'nn 0 0%00 0 0 F 00 0 0%00 0 0 F 00 3,A rn 4. 0 0.00 n 0 F 00 0 0.00 0 o.'oo 0 0 F 00 0 Ci% 00 4.0 10 4.5 0 0 F 00 0 0 ~ On 0 0 F 00 0 0%00 0 0 F 00 0 0F 00 4 ro 5.0 0 0 F 00 0 0.'oo 0 0%00 0 0 F 00 0 0 F 00 0 0 00 5.0 ro 5;5 0 o.'on 0 0 F 00 o o'.on 0 0 00 0 0 ~ 00. 0 0 F 00 5 5 TO 6 0 0 0 F 00 0 o'.no 0 0 ~ on 0 0 00 0 0 F 00 0 o.no 6.0 ro 6 5 0 n.on 0 0 ~ Qn o o.nn o.'on 0 0 00 0 0 00 0 0 F 00 6.5 ro 7.0 0 U ~ nn 0 C.nl o 0 o.no 0 0 F 00 0 0 F 00 7 ~ 0 li) 1.5 U.oo 0.00 0 F 00 0 F 00 0 F 00 0 0 F 00 7'5 ro 8 ~ 0 TO AD 9 0 0

0 0 0 0 00 n.oo 0 0 0 0 '0 0 F 00 0 0 0 0 F 00 0 F 00 0 G 0 0.00 0 F 00 0 0 0 0 F 00 0 00 0 0 0 F 00 0 F 00 9.n TO 0~0 0 0%00 0 0 F 00 o o.'oo 0 '0% 00 0 0 F 00 0 0 00 0 F 00 0 F 00 00 0 0 F 00 0 0 F 00 10 ~ 0 To 11%0 ro GT I~0 an 20 0 0 0 0 'o 0 00 0 F 00 0 0 0 0 F 00 0%00 0 0 0 0 F 00 0 F 00 0 0 0 0 F 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 0 0 F 00 0 F 00 ToraL lno.oo 22 100 F 00 10 100 ~ 00 100 F 00 I 100 F 00 0 0 F 00 II AX I HI JH A)41 ~ F 85 1%24 I ~ 42 1%98 2%12 0 F 00 TQTAL pREclpITATIDN FQR DaTa pERIDD 5.56 INCHES N0% PCT NO ~ VALID OBSERVATIONS 1440 Ioo'.2I( OOSERVAT IO>IS WITH NO PIIECIPITAT ION OASERVaf lotlS WITH Pf)EC IPI TAT ION GE 0 ~ ol INCH Tnrat. va~ ID oosERvarto>>s-1391 49 l440 3 '0 96 60 100 00 F INVALID OBSERVATIONS. TOTAL OOSERVATIONS 1440 0 0 F 00 100 F 00

-FSAR TA8LF. 2 '-57 FRfdttftict dIsrRIBltr lot) 0F PREcIPITArloN DATA PERIOD) DECENDER 1976 AND 1977 DaTa SOURCE'N-SITE 'k .. L'ti'C 1'E, 'u'tal.'t. 2, a)cHI)J"))IJ. JI.JN))'LORY))J I

(Rf'CIP1rar C).4SS tON FREU(tf NC) DlsrwluiirlnN OF FREO(AGENCY Dl~rltltturlotl dk FR'toi)ENCV DlsrR Iuttlk)t) .dF

...,, 'FREO't'if'NCY .

ol s TR(0(t I) 0Y(.

,, , f WEOtlFACV ',OV 57(ti8()T'16A,'6F It'tent'dOENL1... ,DlsrRIBUTlott oF I)JIERVAL PRECII ITAIIOtt t P(t C l)J I TA I lute ION PRECI ITA110t< &'RECIPITAI PREC IP1 TA I'ION PREC IPI TAI ION

( It)CtlES) t(0(JR 2 HO(IR 3 Hot)R HO(IR, 2. )(6()R i?4 HOUR, t)i)Ra T IOti nu(tar ION Dt)RAT IO(1 . Ot(RATIO(( 'RATIO(tt

~

()ORAT IOtt

'N'b VI).

NO ~ PCT. Nfj t(o PCI P(,F) I I) 54 79.4) 8:oo lo 7 10.2

'.0 0 F 00 4,41 ~

14 j I() 10 :5 3 2 0 2 '4 0'. on 4 ~ 3b 8;70 0'.Oq

~ ;00 0 Oinn 0 F 00 5 0 0.00 0.(in .0 ~ 00 0!00 16 0 0 F 00 J) 0 i ~ 0!oo o.on ;7 0 0.00 0 o.nn .0 0 F 00 8 1() 3 I 1.41 .on ;,0 0 ann '9 ~

0 O.no '0 0 0 eon 0 F 00 I 1.47 woo 0 n.no coo 2 l) 0 0 00 4 3 1

\0 0 0.00 !on ;0 .on ~

4 1() 0 0 F 00 .nn ;00 F 00

~

6 0 o.'nn oo no .0 00 5 1() ~

.0 F 00 5 1l 7 0 0 ~ nn 6 ~ 0(I :no 0 i OI) ~ .7 ll ~

ojt 0 n,l)0 ~ LI0 .0 0

.t) 0 o. Jin ~ 0 0 0 0 OJ) ~ 00 (I ~ J ~ J 0 00 0 on 2.2 0

0 n.no 0; lIJ .ot 2.4 0 ?.7J 0 0 OJ) 0 ~ I ( .0 00 2.5 0 P.s 0 0 00 ~ o(I F too an 3.n I) 0'.n I~ ? 0 0 o.on 0 F 00 0;(9 01() l ~ on ;on

' () )~4 0 O.OO oo :0 )00 3

0 3 6 0 n.no .Oo :n )0 .on 0 3 ~ (l 0 O. (Ilt ~ 00 :n II 4 ~ t) 0 0.00 0 ~ (I ) l't9 I) 0 4 ~ 'j

!i ~ 0 0

0 0 ~ on 0 (Jn (l. n(I ~

~

i) (0 9(

'l ,'on 5.0 J) 5~5 0 O.rin 5.5 0 6~0 0 0, ol) 0 Io 6 0 tl a(el.

6.5 0 o,nn ) ~ 0( )OI ' tng 6 ~5 () 7.0 0 0.00 o . ll() 1(l II no 7 ' tl 7.S 0 o.on 0 ~ Oit .Otl 7.5 () () ~ 0 0 O.on 0 0 ~ o(l ~ 00 )00 n~0 I) 9. I) 0 0 nil 0 0 ~ 0 l) 0 ::Ito io 9.n Gn ~ 0

)nao () I' 2.'n 0

n 0 0 G ~ 00 0 F 00 Oi(I))

;0 10 b't'.

O T 2sn 0 norm 40 T()1 AL 68 100 F 00 23 1oo.oo 15 1oo.oo t00 ~ Od 4 '"8;tN 0'o I ~ Io ).95 Oodn 0'.do tlax It(utt i+05 1 ~ 09 TOTAL PRECIV ITATIDN f'0R DaTa vfalot) F 85 1NCHES tt(5'r PC)(r oosFRvar loss WITH No pRfclplrATIQN 0()SFRVAt lot)S J(1 TH ltktCIPITATION GE 0 ~ Ol INCH NO ~ Lff20 68 95 '5 Pere ff ~ 57 VALIO MSE(t'(/fT IWiSJ t(v4L I(7 ot(sERV47 foNs. L)488 , I'OO;OOJ

, 0 ~

1488 Looooo 68SLRVAT1ONS LJ48$ 0'14L 0'0'ondon' TOTaL VALID Ot)SE ()var lotiS a
SLc <<SAR TABLE 2 3-58 FREouENCY olsTRIBUTION of IRECIplTATION DATA PERIODS JANUARY 1977 ANO 1978 DATA SOURCEI ON-SITE sT. LUCIE uNIT 2 HUTCHItISON ISLAND~ FLORI DA FLORIDA POMER AND LIGHT CO ~ PREC IP I TAT ION FREOI)ENCY FREQUENCY IREQUENcY FREQUENCY FREOUENCY FREQUENCY CI. ASS DISTR Ir)ur I ort Of DISTR I BUT Intr OF DISTRIBUTION OF DISTRIBUTION OF DISTRIBUTION OF DISTR I BUT lott OF INth)IVAL PREC IP I TAT ION PREC IP I T A I I ort PREC IP I TAT ION PREC IP I TAT ION PREC IP I TAT ION PRECII'ITAt ION I I tICHE S) I HQIIR 2 HOUR 3 HOUR 6 HOUR 12 HOUR 24 HOUR Drr)IAT low OUIIAT I ON DURATION DURATION DURATION DURAT Iotl No ~ PCT No. No. PCT NO ~ PCS NO PCT ~ NO ~ PCT

.0 ro I 46 79 ~ 31 11 52.)8 3 30 00 0 00 0 0 F 00 0 0 F 00 i<< ~ ~

I)<<79 5 f3 8) ~ 4 40 F 00 0 F 00 0 0 F 00 0 0 F 00 I ( 4 o.no 3

~

0 F 00 2o.'o3 100 ~ QO 0 0 F 00 0 ~ 03

~ 0 0 ~ Qo 0 0 F 00 Im 10 ~ ~

4

5 In 6 10

<<5 ~ ~

6 7 1 0 0 1 '2 F 00 0 ~ Qn 0 0 I 0 F 00 4 '6 0 00 0 0 0 F 00 0 F 00 o.oo 0 F 00 0 F 00 0 F 00 0 0 0 0 F 00 0 F 00 0 F 00 0 0 0 F 00 0 ~ 03)

~ 7 I'0 ~ A 0 0 F 00 0 Q.on 0 0 F 00 0 F 00 0 0 F 00 0 000 .8 10 ~ 9 0 0 F 00 0 0.00 0 0 F 00 0 F 00 0 0 F 00 0 0 F 00 ~ 9 10 ~ 0 0 0 F 00 0 F 00 0 0 F 00 0.00 0 0 F 00 0 0 F 00

o tn 0 0 F 00 0 0 F 00 00 0 F 00 0 F 00 M :l ro

~

f

~ 3 0

n 0 00 0 F 00 n 0 0 F 00 00 0 0 0 F 0 00 F 0 F 00 0.00 0 00 0 0 0 F 00 0 0 0 F 00 0 F 00 0 F 0 0 0 F 00 0 0 F 00 In ~4 0 ~.nn 0 0 F 00 0 0 F 00 0 F 00 0 0 00 0 0 F 00 4J ~ 4 10 <<5 1 0 0<<00 0 0 F 00 0<<00 0 0 F 00 0 0.00 I 00

~ 5 1n ~6 0 0 ~ Qo 1 4 ~ 'l6 0 0 F 00 0 F 00 0 0 00 0 0 F 00 LA ~ 6 10 ~ 7 0 n.oo 0 0.00 0 0 F 00 0 00 0 F 00 0 0 F 00 ~ 7 10 <<8 10 << 0 0 F 00 nn 0 0 00 0 0.00 0 F 00 0 F 00 0 000 ~ 9 2 ~ 0 10 In j2? 0 0

0 ~ 0.00 0 F 00 0 0 0 F 00 0 F 0 00 00 0 0 I 0 F 0 00 10 00 00 0 00 0 F 00 0 F 00 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 0 F 0 0 F 00 0 0 F 00 7%2 IO 2 4 0 o.no 0 0 F 00 0 0 F 00 0 F 00 0 0,00 0 0 F 00 2 ~ 4 10 2~6 0 0 F 00 0 0 F 00 0 o.no 0 00 0 0 F 00 0. 0 ~ 00 2 ~ 6 10 7 ~ tr 0 0 00 0 F 00 0 F 00 0 F 00 I) ~ 00 0 0 ~ Qo 0 0 2 ~ 8 10 3.0 0 o'.Qn 0 0 F 00 0 0.00 0.00 0 0 F 00 0 <<00 0 ln 3 2 0 0-00 0 0 00 0 0 F 00 0,00 0 0,00 0 0<<00

'1.2 rn 3 ' 0 0 F 00 0 0 F 00 0 0 F 00 0 F 00 0 0 F 00 0 F 00 3 6 rn 4.5 In F 6 3.8 10 4 '

0 fn 4 10 3' 5 0 0 0 0 0 0.00 0.00 o.on 0 00 F o.nn 0 0 0 0 0 F 00 o.no 0 F 00 0 F 00 0 0 0 0 0 F 00 0 F 00 o.'on Q 00 0 F 00 0 F 00 o.'Qo 0 F 00 0 0 0 0 0 F 00 0 F 00 0 F 00 0 F 00 0 0 0 't 0 F 00 0%00 0 F 00 0 F 00 5.0 5 ~ 5 10 To 5,5

~

6'.n 0 0 n.oo o'. 0 0 0'0 0 0 0 F 00 0 F 00 0<<00 0 0 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 nn 0 0 F 00 0 0 F 00 0 00 0 0 F 00 0 0 F 00

10 10 as F

6 0 0 F 00 0 0.00 0 o'.no 0 F 00 0 0 F 00 6 'I.o 0 0 00 0 0.00 0 0 F 00 0 00 0 0 F 00 o'.oo 7<<0 ln I 5 0 0 F 00 0 0 00 0 0 F 00 0 F 00 0 0 F 00 0 0 F 00 7'

~

10 8 ' F 0 0.00 0 0 F 00 0 o.no 0 F 00 0 0 F 00 0 0 F 00 8<<0 In 9<<0 0 0.00 0 0 F 00 0 0 F 00 0 00 0 0 F 00 0 0 F 00 9,0 Io 0 ~ 0 n 0 F 00 0 0 F 00 0 0 F 00 0 F 00 0 o.no 0 0 F 00 10<<0 ro 1<<0 0 0 F 00 0 0 F 00 0 0 F 00 0 F 00 0 0 F 00 0 0 F 00 11 ~ 0 0 2.0 0 o.on 0 0 F 00 0 0 F 00 0 F 00 I) %00

$r 2 ' 0 0 F 00 0 0 F 00 0 0 F 00 I)%00 0%00 TorAL SU 100 F 00 21 100 F 00 10 100 F 00 100 F 00 0 0 F 00 0 0 ~ 00 HAxt)IUH ANTE 1 ~ 41 1 '6 2 '6 ~ 25 0 F 00 0 F 00 TOTAL PRECIPITATION FOR DATA PERIOD 5%30 INCHES No PCT ~ NO PCT OBSERVATIONS IIITH No PRECIPITATION 1424 96 ~ )00% VALID OBSERVATIONS l48 99.95 OBSERVAtlnr)S ~1TH Pi)ECIPITATIDN GE 0 .01 INCH 58 3~ 0 INVALID OBSERVATIONS ~ 07 T')TAL VALID OBSERVATIONS 1487 100 ~ OO TOTAL OBSERVATIONS 148 100 F 00

TABLE 2 ~ 3-59 FREAUENCY DISTRIBUTION Of PRECIPITATION DA'IA PERIOD) FEI)RrraRY 1977 AND 1978 nata souRcE) DN-sltE ST. Lr)CIE uNIT 2 HUTCHlr)SON ISLAND. FLORIDA FLORIDA POvER AND L IGHT CO~ PRECIP I TAT ION Cr aSS fOISTRIRtrtlorr Rt Or)EI!cY HO()R OF FRE Out ICY 01$ TRIrrr)t lot) 0F

) REOUENCY DIQTRIBI)TIOtr 0 FRED)JENCY Dl(t TRI HUT ION OF FREOUENCY Distr)IAUTIDN QF FREOUENCY DISTRIBUTION OF INTfrrVAL PREC IP I TA I ION PRt C t P I TAt lOrs PRf,CIPITAIIOrr Pkr.c I PI TAT Ir)N PREC )PI TAT 10)J PREClP I TA I IOtl l lrrCHES) l 2 trOUR 3 HOUR 6 HOUR 12 HOUR HOUR Du RATIO)) DURATION DuRatlotr DURATIOtr Du RAT I01) DURATIOtr NO) 8")'.I) NO. VC/) NO( PCT) NO) PCT( NOII NO( PCT3 0 10 ~ l '0 6.5) 29 F 4) 33.33 o.no ~ ~ )

2 TO 10 3 Tr)

~

2 3 2 0 3 0.00 5 0 1 lJ ~ 00 S.t)8 2 22 F 22 I) )I

~ 33 '3 33<<33 0

I 0 F 00 100 F 00 0 0 0 0 F 00 o.on 0 F 00

~ 4 10 .5 0 o.on 0 0 ~ AO 0 0 F 00 0 00 0 O'. AO 0 0 ~ no .S 1r) 6 0 0.00 0 000 o n.'no 0 F 00 0 0 F 00 0 0 ~ 00 ~ h Tr) ~ 7 0 o.on o o.no 0 0 ~ 00 o.on 0 0 F 00 0 0 F 00 ~ 7 rr) ~ A 0 0 F o'.on 00 0 0 F 00 o o.'na 0 F 00 0 0.00 0 0 F 00 ~ <<) 10 ~ 9 0 0 0 F 00 o o.no 0 F 00 0 Oooo 0 0 00 .9 10 ~ 0 0 0 ~ t)0 0 0 F 00 o o.on 0 F 00 0 D.no 0 0 F 00 ~ 0 10 ~ 1 0 0 00 0 0 F 00 0 0.00 0 F 00 0 0 F 00 0 0 F 00 ~ ) 10 2 0 n.ao o o'.no 0 0 ~ On 0 F 00 0 0 ~ 00 0 o.no ~ 2 10 ~ 3 0 0 ~ DD D 0 no D 0 ~ on 0+00 0 0 ~ 00 0 0 F 00 ~ 3 rr) ~ t 0 o.nn 0 0 F 00 0 0 F 00 0 ~ 00 0 0 F 00 0 0<<00 4 rn .5 0 0.00 0 0 F 00 0 0.00 0 ~ 00 0 0 ~ 00 0 0 00 n.'no ~ F ro .6 0 o.no o 0 I( ~ 00 0 F 00 0 0 F 00 0 0 F 00 .6 10 ~ 7 0 o.nn 0 0 F 00 0 0 '00 o.'no 0 0 F 00 0 0 ~ An .7 I t) .8 0 0 00 F O O.OD o o.on 0 F 00 0 0F 00 0 o.on 9 n o.nn n o.on 0 0 F 00 0 F 00 0 0F 00 0 n. ()0 IO J ~ n 0 0,'nn 0 0~00 0 0<<00 0+00 0 0.00 0 0 F 00 10 ? 2 0 0 nn o o.no 0 0 F 00 0.00 0 0 F 00 0 0 F 00 ? ~ 2 1() ?,4 0 D.r!n o n.nn o o'.on 0 F 00 0 0 ~ no 0 0+00 2~4 10 2 6 ~ 0 0 00 0 0.00 o o.no 0 ~ 00 0 ~ Do 0 0 ~ nn 2,6 ro ?.0 0 D An 0 0.00 n o.'nn 0 F 00 0 0 F 00 0 0.00 ?on lr) 3. 0 0 0 F 00 0 0.00 0 0.00 0 F 00 0 0.00 0 0 F 00 3.0 10 3' 0 D.on o D.no o o.no 0 F 00 0 0 F 00 0 0 ~ 00 F 2 )0 3.4 0 o.no 0 G ~ An o o.'on 0+00 n 0 F 00 0 o.on 3' to 3 f<< 0 0 F 00 0 0.00 0 I(. 00 0.00 0 0 nn 0 0 ~ 00 3.6 I I) 3- r) 0 D.nn o o.no n e'. oo o. 0(o 0 0 F 00 0 o:on 3.0 ro 4.A 0 A.no o o.'no o o.na o.on 0 0,00 0 0<<QD 4 ' rn 0 0'.nn n o.'oo o 0.'An 0+00 0 0 F 00 0 0(00 t ~ 5 tt) S.A 0 n.no o n.'oo o o.'nn 0 F 00 a 0+00 0 0 F 00 <<.0 lr) 5-5 o.on n.on t<< ~ A )0 10 6.0 t(.5 0

n 0 0 ~ no o'.on 0.'At> o 0 0

'.00 0 00 ~

o 0 0 0.00 0 r)A 0 F 0 DD 00 0 F 00 0 0 0 0 F 00 0 F 00 0 F 00 0 0 0 0 F 00 0 ~ ()0 0<<00 6.5 rt) 7 0 0 r,'.An o r('.An 0 0 ~ ni) 0 ~ on 0 0 F 00 0 O.AO 7'n rr)

~

7.(<< 0 u.nn o o.no 0 A ~ DD 0 ~ 00 0 0 F 00 0 0 F 00 7.S ro 8.n 0 A.no 0 n.oo 0 0 F 00 o.'on 0 0 F 00 0 0 F 00 rt . r) 9.'A ro rn an ln.o n 0 00 r<<00 0 0 o.nn 0 ~ an o o'.nn 0.00 0 ~ An 0 ~ 00 0 0 F 00 0 00 0 0 F 00 0 F 00 0 0 0 In.o ln ).O 0 0 Da o O.no 0 0 F 00 0~00 0 0 F 00 0 0 F 00 ll.n Gt 10 7 0

)2.n 0

0 0 F 00 0 F 00 0 o 0 F 00 o.'no o 0 o.'on 0 F 00 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 0 0 F 00 0 F 00 10)rL 46 )oo.nu 17 100 ~ 00 9 100 ~ 00 100 F 00 1 loa.oo 0 0 F 00 Ha(r)HU(". Avl. ~ ?e ~ 34 ~ 38 ~ 39 ~ 38 0 ~ 00 IOIAL r'REClr ITaTIOtt FOR r)ata PERIOD 2 '00 INCHES NO PCT. NO ~ PCS f)r(5t'.(fva 1 tot). )flit( Ito )<<<<rect('I rat totJ vaL Io ot) <<tRvAT Iotrs 1343 99,93 ()t>=.fr var lrrrs ttl)tr Tnt'n).'AL r<<rtr.'clpl lat lON GL to 0!)Sf RVAT IOUS 0 ~ 01 Itrctl 1297 1343 46 3 '3 96 F 57 100 00 INVALlO f!()SERVAI IONS TOTAL OOS!:RVAT IONS 1344 100 F 00

a7

; RAR TABLE 2 '-60 PERIOD(

FREO(rENCY DIST((I(3(rf ION OF PRECIPITATION DATA Har)CH I 977 AND 1978 DATA SOURCEi nh-Sl'TE ST LUCIE UNIT 2 HU'fCHINSOtt I SLAtiOR FLORIDA FLORIDA POWER At(D LIGHT CO ~ PRECIPITATION FREOI(ENCY FREOUFNCY FHEOUENCY FHEOUENCY FREOUENCY FREOUENCY CLASS DISTHIU()TION OF DISTR II)((T ION OF DISTR If((rf intr OF Df ST(t I BUT Int) OF DISTR It)UT ION OF DISTklOUl intr OF It( TERVAL PREC IP I TAT ION PkEC IP I TAT ION PHECIPITAf ION PRECIPITATION PHFC IP I TAT intr PRECIPITATION ( It)CHES) Hnl)H 2 HOU(t 3 HOUR 6 HOUR 12 HOUR 24 HOUR Dur)AZ I nrc Dl(HATI ON DURATION DUH a T lOrs DURATION DURATION t(D PC T ~ Nn. VCT ~ NO PCT NO ~ PCT NO PCl a NO. PCS

.n fn 17 62.96 5 5(r 00 0 0 00 0 0 F 00 0 0 00 0 0 F 00 ln 0 F 00 I 33..33 0 0 F 00 0 0 F 00 ~

f fn

~

f I 0, i)n 0 0'~no o.no 0 n.oo 0

~ ~

3 4

.5 fn fn ~ ~

4 5 6 3i70 0~00 0 F 00 2o.'no 0 0 0 0 F 00 0 ~ 00 0 0 0 0 0 0F

'ono00 0 0

0 0 F 00

~ 6 ln .7 o'.un 0 0 00 0 0 F 00 0 0 F 00 7 fn ~ 8 o.nu Io oo 0 F 00 .0 0 F 00 0 0 F 00 0 0 F 00

8 fn .9 0 arm 0 F 00 0 o.on 0 0 F 00 0 O'.OO 0 0 F 00

,9 fn io 0 F 00 0 ion ~ 0 fn ~ 2 I 0 'n 0 no

n. (jn 0 00 o.nn 0 nn 0 0 no

33. 3.3 33.33 0 0 F 00 0 F 00 100 F 00 0

0 0 OR00 0 F 00 0 0 0 0 F 00 0 F 00

3 fo ~ 3 0 F 00 n'. nn 0 F 00 0 F 00 0,00 0 0~00 0 0 F 00

~3 fn ~ 4 0 F 00 0+00 0 0 F 00 0 0 00 0 0 F 00 fn ,5 0 F 00 o.'no 0 0 ~ no 0~00 0, 0 ~ 00 0 0,00

5 fn 6 o.on 0 F 00 0 0 F 00 0 0 F 00 0 0 ~ 00 0 0 F 00 o.'nn

~

6 fn ~ 7 0 ~ no 0 0 F 00

'00 o.'no 0 0 F 00 0 oion .7 fr) ~ r) 0.00 0 F 00 0 o.no 0 ~ no 0 0+00 0 0 F 00 ah (0 ~ 9 0.00 0~00 0 0 F 00 0 0. (io 0 0 F 00 0 0 F 00 ~ 9 fn .0 0 F 00 0 ~ no 0 0 F 00 0 0 ~ 00 0 0 F 00 0 0 F 00 2.0 fn ?.2 n.on 0.00 0 0 F 00 0 0 00 0 0 F 00 0 0 F 00 2.2 2.4 0 ~ nn 0.00 0 0 F 00 0 0 F 00 0 0 00 0 0 F 00 o.'nn 2' fn 2.6 0 F 00 0 F 00 0 0.00 0 0 00 0 0 F 00 o 2.6 fn 2.8 0.00 0.00 0 0 F 00 0 0 F 00 0 0 F 00 0 oioo 2 rr 'l,a fn ~ fn 3.0 0 00 O.i)n 0 0 F 00 0 0 F 00 0 0 F 00 0 0 ~ Oo l.24 n. (rn 0 ~ nn 0 0 F 00 0 0.00 n 0 F 00 0 0 ~ 00 o.'on

(.2 .(0 o.nn o'.no o.nn 0 0 F 00 0 0 F 00 0 0 F 00 o F 4 fn 3.6 o.nn 0 0.00 0 0 00 0 0 F 00 0 0 F 00 l.h fn 3' 0.00 n.oo 0 0 ~ on 0 n.oo 0 0 F 00 0 0 F 00 3 rf fil

~ 4:n o.no n.no 0 0 inn 0 0 00 0 oioo 0 000 4:n'5 fr) 4.5 0.00 (I 00 0 0 ~ Gn 0 0 00 0 0 F 00 0 0 F 00 4~ ln 5 0 ~ 0 ~ oi0 0 F 00 0 0 00 0 0 ~ 00 0 0 F 00 0.00 0 0 ion 5.0 fn 5.5 0 ~ no o.no 0 0 00 0 0 F 00 0 0 nano 55 6.n fn )0 6' h,5 0 arm 0 F 00 0 F 00 o.no 0

0 0.00 0 F 00 0 0 0 F 00 0~00 0 0 0 F 00 0 F 00 0 0 ' Oion

~ Oo 6.5 fn 7' o.'on o.no 0 0 F 00 0 o.no 0 0 00 0 0 F 00 o.'on F

7' fn 7.5 0 arm 0 F 00 0 0 F 00 0 0 0~00 0 0 F 00 7,5 fn R.n 0.00 0 ~ no 0 0.00 0 0 00 0 0 F 00 0 0 00 () ~ 9~0 0'nfn V.n n'.n 0 0

~ ~

on nn 0 F 00 0 F 00 0 0 0 0

~ no F 00 0

0 F 0 00 0 F 00

0 0

0.00 0 F 00 0 0 F 0 F 00 0 F 00 In.o fn ) ~ 0 n.oo 0 ~ no 0 0 F 00 0 0 F 00 0 0 F 0400 00 0 0 F 00 0 F 00 11.0 10 2.0 o.no 0 F 00 n 0 00 0 0 F 00 0 0 GT 12in 0 F 00 0+00 0 0 00 0 0 F 00 0 0 F 00 0 0 F 00 TOTAL 27 )no.oo 10 100 F 00 3 100 ~ 00 100 F 00 0 0 F 00 0 0 F 00 Ha x I rhllN AHI ~ ~ 56 ~ 77 I~ 1'1 I ~ 13 0 F 00 0 00 Tnf AL Pkf elf'I TAT IDN FOH DATA vfRIDD 3 48 INCHES NO ~ PCT Nn PCT ~ onsf rr va 7 lnrrs V I TH Nn pkf c I p I la T ION 1461 98il9 VALID ODSEHVATIONS 1488 100 F 00 OrsSERvafln~(S ufft( Pr(ECIPllaTION GE 0 F 01 INCH 27 INVALID 0(3SERVAT IONS 0 0 F 00 TnrAL va(. ID n(fsfrtvaTIDNs 14(r 8 IOO.'OI) TOTAL OBSERVATIONS 1488 100 F 00
SL2-FSAR

)AOtE 2.3-41 Focn<>><ICY iilglnlo<>> loii iic ) IIECIPIraIIAN I<a Ta Pt 0 li)l)I AP)t li. I i77 a)in l9)8 OA I A SO<ii<Ct I Iiti-5I )E ST. uiCIE UNIT 2 jlUJCN(NSOII SLAI)0 ~ F)OR IOA J

I i<c c I p I I a I I oti Fiit Aiit NCY Flit'OUE'NC I t F Il OUEt)CY FRED))ENCY CI A45 I) ISIR)ll<t<EC TP TTA I Tot)

I) I 5TII)III)I Iatl OF I) tSTRIIIIU/ Otf f Of gS/Rf II+II}[OW 0> IN I EI) v AI PilE C IP I TA I TON I It<<<:>c 6 I I << ii<<1 2 Iioort 3 tin<In 4 HOIIR 12 hOUR 4 IIAUR Uoi>a T li)N I)))<i A I I Oil OU<lAT ION - OURAT TON OUI)AT ION URAT!ON I<A I'C I . Nii) (CJ ) tin PC NO NOI} PC NO( PC

~ 0 O.L I} a. Lh a'.oo n l ii ~ II<I 20 0 0,0 o

0 000 0 0 ao 0 0~ 0 n 0 .4 n.oo 20 AD 0 000 a o.ao

~ 1 n .5 n o.nn n.na o.a D.o 0 000 I:al 0 0'.ao .5 n o a I) ~ 00 6 tl 7 3 2).2$ n 0.0 NI:ao a.'oo 0 0 ~ 0 .7 n .n o. o v.nv a D.oo 0 00 0 n.nn ~ ) n o.nn 0 D.n 0. 0 o.oa 0 F 00 ~ <) .n o ri.ao 0 D.nn 2 40 00 o,no a.oo

a o D.on n o.na a D.oa a.'no 0 F 00 o n.no D 0 00 a.oo 0.'aa 0~ 0 o'.Da

>3 0 n.oa ~).N 0 0.00 ~ 4 n . a.an 0 o.nn 0 D.na a. on 0 00 4 .5 n o.oa o D.nn 0 a.no 0 00 0 00 0.na 00 ~ .f. 0 o.nn n 0 0 F 00 0 00 0 ~ nn 0.'oo I> .7 o n.nn o o. 0 000 0 00 0 00 0 F 00 .n 0 0.00 0 0.00 0~00 0 F 00 0 o'.ao ~ <) n n.nn n o.'an 0 00 .') .0 n D.nn a o.'na (0.00 o.no

n n 2.2 o n.nn o n.on a o.ao 0 00 0 0+00

?.2 0 2 ~4 0 D.an 0 n.'nn o o.aa 2.4 0 7..6 n a.nn 0 n.no o D.oa 0.'aa 2.6 0 >!.8 n n.nn a 0.'na 0 'a.oo o.'oa

2. tl 3'.n o i: n

'1.2 o a.nn n.no o n.no a'.na a o.aa n.'no 0 00 0 ~ 00 0 a'.oo a,oo 0 000 0 a n a 1.2 0 1 ~ 4 n n.nn 0 D.no 0 0 F 00 o.'oa 0 0 00 0 0 F 00 1.4 0 1.6 n n.aa o .

D.an D 0 F 00 0 00 0 ODD 0 0 F 00 I. f> 0 l.d a n.nn n o.'on n a.'00 o.no 0 0 F 00 '0a 0.'oo

1. I) o 4.n a D.nn o o.na, o o.nn a'. oo 0 0.00 . 0.'oa 4.'n I0 4.5 0 0 nil n a.aa' 0 o.'ao 0>00 a o.oo o a.ao o 5.'n o o.nn D.no 0 0.00 0'.no s.'n n 5.5 a n.no o O.no o D.no 0 F 00 o 00 5.5 0 f>.n 0 n.no 0 0.00 n o.oo 0 F 00 n o.'oa f>. 0 0 6.5 n o.an n o.no a o.no o.'on 0 000 t.5 i) 7.n

).5 a n.oo n.na o o.no 0'.ao a o.oo o.ao 0 ~ Dn 0 0 F 00 0 F 00 0 0 ~ 00 000 7.n n n a 0+00 o.'ao 0

a.'oo 0

).5 I) D.n n D.nn n- o.oo 0 0 F 00 o.'nn 0,00 o

Dan 0 0+00 o.oo D.n 0 ).n a n.un n o.nn o n.'oo 0 a

).n o n.n o n.na n a.on o o'.nn 0 F 00 0>00 ~n'.0 II" }.0 o I) '.nn n o.'nn a 0 F 00 o 3:oo 0 F 00 0 r..n n o.no 0 0 ~ an o a.oa a.'00 II ~ 00 0 O.DO I i.n a n.no 0 0 F 00 0 0.00 0 00 0 0 F 00 I <> I Ai I I) I) ~ I) >><>III A<< I, I i83 I ~ 83 2~03 0 F 00 0 F 00 i>iI<'..t wva I I <I<<'> <<>)MALln onsERyAy InNS o.'oo 0>> .I I<va I I i)<)S u I I I I I'It t I I I' I a I I 0ENCY FREOUENCY FREouENCY FREOl)ENCY FREOUENCY CLASS OlqTttrttuf rntt Of OISTRINUTlatt OF OISTRIOUT ION OF DIST)tIBt)TION OF DISTR I))UT ION OF DISTRIBUTION Of INTf kvAL PktclF'ITATION PttECIPITAI Intt PRECIP I TAT ION PRECIPITAI ION PREC I P I TAT ION PRECIP ITAT ION.

I INCHES) Hnuk 2 HOUR 3 HOUR 6 HOUR 12 HOUR 24 HOUR OUR AT ION UURATIUtt OuRAT ION OURAT Iott OURAT ION QURAT IOtt NO~ PCT. Noi VCI. NO. Pcf NO PCT NO PCT NO ~ Pc TO I 14 s6-on 3 30 00 0 0 F 00 D 0 F 00 0 0,00 0 F 00 10 00 G.DG 50 F 00 0 0 F 00 0 0 00 0 000 o.no n 0. DII 0 0 0 0 F 00

~ 4 0,00 n'. no 0

0 0 00 0 0 '.'oa

. 3:oo 0 0 0 F 00 .0+00 ~ 5 IO .6 2 it ~ 00 4 F 00 0 oooo n 0 F 00 0 0 00 ~ 6 10 ~ 7 0 0 F 00 D.na 0.00 0 0 F 00 0 o.on 0 0 ~ 00 ~ 7 10 ~ 8 0 D.nn D~ on D ~ Da D o.on 0 0 00 o.'oo ~ 8 10 ~ 9 0 0 00 ~ 0 ~ no 50 F 00 0 0 F 00 0 0 F 00 i) 10 .n 0 o.on 0 F 00 0 00 D o.no 0 0 F 00 0 0 F 00 TO ~ I 0 D.nn o.'nn G 0 F 00 0 0400 0 0 F 00 0 0 F 00 I:II 10 ~ 2 0 0 F 00 o.no 0" 0 0 00 0 0 F 00 0 0 00 0 0 F 00 4J 1 ~ ? 1 t) a3 0 n.oo 0 ~ no 0 00 0 0.00 0 oooo 0 0 Da I ~ 3 10 ~ 4 0 0~00 0.00 0 0 F 00 0 0 00 0 oino 0 0 F 00 o'.ao CO ~ 4 fu .5 0 I) ~ 00 n.no D o.nn 0~00 0 0 ~ 00 o .S 1l) ~ 6 0 0 ~ tin 0 00 0 0.00 0 0 00 0 0 00 0 0 F 00 ~ 6 10 I .7 0 o.on 0 00 0. 0 F 00 0 o.on 0 0.00 0 0 F 00 n.'on F ~ 7 TO .fs 0 0.'no 0 0 F 00 0 0 F 00 0 a.oo 0 0 F 00 ~ 8 Tn ~ 9 0 0 (la ~ 0 ~ 00 0 o.no 0 a'.on 0 a.'oo 0 0 ~ 00 ~ 9 ~ 0 0 o.on 0 ~ 00 0 0 F 00 0 0 F 00 0 0.00 0 0 F 00 2.0 10 2 2~ 0 0 F 00 n'. no 0 o'.nn 0 0 F 00 0 0 F 00 0 000 2~? 10 24 ?.6 0 0 F 00 0 ~ no o'.nn 0 0 DD 0 o.no 0 0 F 00 0 000 4 10 0 o.on. 0 o.no 0 0.00 0 a.oo 0 0 F 00 2 ~ 6 10 2.8 0 0 F 00 o.no 0 0 00 0 0 F 00 0 0 F 00 0 0iao ?..8 fl) 3.0 0 0 F 00 n.'oo 0 oioo 0 o.'an 0 0 00 o o.ao 3., 0 10 3 2 0 Din~i 0 F 00 0 o'.no n 0 00 0 a,na 0 0 ~ Ga 3.'2 'I fO 3 ' 0 0 00 F 0 ~ nn 0 0 F 00 0 o.oa 0 0 00 0 0 ~ i)0 4 1ll 0 o.nn n.no 0 0 F 00 0 0 F 00 0 0 ~ OG 0 0 F 00 n.'oo ~

1.6 10 3.i) 0 0 F 00 o.'no 0 0 0.00 0 a'.no o o'.no 3.8 n'.Do o.no 4' 4.5 1 10 ro

~ ) 4 ~0 4.5 S.n 0

0 0 0 0 'a00 F o.'nn o.no o.'ao 0 0 0 0 00 0 F 00 0 <)0 0 0 a 0 F 00 0 F 00 Dion 0 0 0 0 F 00 0 F 00 0 F 00 o 0 0 oiaa oiaa S.n 10 5 ~ 5 0 o.on o.on 0 0+00 0 o'.oa 0 0 00 0 0 F 00 5.5 )0 6-0 0 0 ~ nn 0 ~ no 0 0 F 00 0 o.'no 0 0 Do 0 0 F 00 6.0 Tll 6.5 0 0 ~ no n.'no 0 0 00 0 o.'ao 0 0 F 00 0 0 F 00 6.5 To 1.0 0 o.no D.on 0 0 F 00 0 o.on 0 0 F 00 0 0.00 7.n fo 7 5 ~ 0 0 F 00 o.nn 0 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 7~5 10 A.tt 0 oiaG D.no 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 8.0 fO 9.0 0 ' 0 00 u.ao 0 o.'no 0 0.00 0 0 00 0 0 F 00 9.0 10 0 0 0 0 F 00 0 F 00 0 0,00 0 o.oa 0 0 00 0 0 F 00 ln.o 10 I 0 0 00 0 00 0 0 00 0 0 F 00 0 0 ~ 00 0 0 ~ DD ll 0 10 6T

? 0 2 ' 0 0

o.no 0 F 00 0 F o.no F 00 0 0 0 ~ 00 0 ~ 00 0 D 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 0 0~00 0 F 00 TOTAL 25 I DD Do 10 100 F 00 2 100 F 00 0 F 00 0 0 F 00 0 0 F 00 Nn X I t<!) IO AN f 57 ~ )to 0 F 00 0 F 00 0 F 00 TOf AL VRECIVITATIOtd FOR DATA PERIOO 4 ~ I3 INCHES Nn. PCT. NO PCT ot! sl Rvn I Inks WITH lln PltECIPl fATION 1462 98.32 VALIO OGSERVATlONS 148 99 ~ 93 nosf itvn1 1nllS <<rrll l ftfrrVirnfro>> riE o.ol INVALID OBSERVATIONS ~07 INCH 2s tnrI 68 nn I 0 I AL OU 5E tIVAT I ON S 1488 100.00
SI 1AR TABLE 2 '-63 FREOUENCY OISTRIBUT Iutl OF VHECIP I TA1'ION DATA PFR IODJ JUNE 1977 Allo 1978 DATA SOURCE) ON-SITE ST LUCIE UtJIT 2 HUTCHINSOtJ tSLANO ~ FLORIDA FLORIDA PO)tt;H AtJD LIGHT CO~ P+Ec I VI TAT ION FHEnUFNCr FREOUEt<CY FREQUENCY FREOJJENCY FREOUENCY 4L>>SS DISTR IIJIJI lull OF 0 I S Tlt I or 1 T I ON OF DISTR IBUI IotJ OF DISTHIB(JT ION OF DISTJJIBUIION OF DISTRIBUTION OF ltJTERvaf. PREC IP I TAI I otl PREC II I TAT ION PHECIPI TAT ION PRECIPITATION PHEC IP I TAT ION PRECIP I TAT Iott (INCHES) 1 HOJJH 2 HO(JH 3 HOUR 6 HOUR 12 HOUR 24 HOUR DUJJAT ION DUuATION DURATION DURATION DURATION DU RATION 0 TO TO il2 NO)

'7 6n! It ?S.nn NO.

4 2 NO) so'.3S 0 F 00 NO) PCT( 0 F 00 NO( PCT 0 F 00 NO) PCT)

~ 1 ~ 0 0 0 0 F 00 0 0 F 00 ~ ? fo ~ 3 3 10 7) ? 0 0~00 0 a.oo 0 0 F 00 0 0 F 00 ~ 3 lu 4 I ? illa 8 2 50~00 0 0 00 0 0 00 0 0 F 00 ~ 4 fo ~ 5 0 0 F 00 1 9;09 0 0 F 00 0 0 F 00 0 0 00 0 0 F 00 ~ S fO 6 0 0 ~ 00 0 0 F 00 0 0.00 0 0 00 0 oooo 0 0 F 00 ~ 6 )0 ~ 7 0 n.'no 0 0 F 00 0 0 F 00 0 o.no- 0 0 0000'REOUENCY 0 0 F 00 ~ 7 10 8 0 n.'on 0 o.'na 0 0 F 00 0 n.'oo 0 0 ~ 00 0 0.00 ~ 8 10 ~ 9 0 o'.on 0 0+00 0 0 F 00 0 0 F 00 0 0 F 00 0 0 F 00 9 fo ~ 0 0 o.'nn 0 o.'nn 0 0~00 0 0 F 00 0 0.00 0 0.00 ~ 0 fO I 0 0 ~ no 0 -0 ~ ao 0 0 F 00 0 o.'no 0 0 F 00 0 0 F 00 10 )I 2 0 0 nn 0 0 ~ 00 0 0 00 o.on ~ ~ 0 0 0 F 00 0 0 F 00 1O 3 0 o.nu 0 o.nn 0 0 F 00 0 0+00 0 0 00 0 0 F 00 ~ 1 10 ~ 4 =0 o.nu n o.ou 0 0 F 00 0 o'.no 0 0 F 00 0 0 F 00 ~ a fn 'i lr) .5 0 0 00 0 o.no 0 0 F 00 0 0 F 00 0 0.00 0 0.00 o.'on a.'oo = ~ 6 0 0 ~ Gn 0 0 0 ~ un 0 0 0 F 00 0 0 F 00 ~ 6 1O ~ 7 0 0.1>n 0 o.'un 0 o.ro . 0 0 F 00 0 0.00 0 0 F 00 .7 fn .8 0 o.no 0 0.'no n 0 F 00 0 .0.00 0 0 00 0 oion .8 10 .9 ~ 9 0 0.00 0 0.'nu 0 0.00 0 0 F 00 0 F

o'.no 0 0 ~ 00 on 0 o.nn 0 0 nn 0 0.00 0 0.00 0,00 o.'on

~ 0 10 iO 2 ' 0 O.ou o.'on 0 ~

o.'no 0 o'.ao 0 0 F 00 0 0 0 00 0 0 0 F 00

?~2 i? 4 ~ 0 0 0.00 0 0 F 00 0 0 00 0 0 F 00 0 o.no ?~4 fo 2~6 0 n.'on 0 0 00 0 0.00 0 0 00 n.'oo 0 0 F 00 2~r late fO 2~8 0 o.'no 0 o. 'nn ~

0 0 F 00 0 o.no 0 0 0 F 00 0 0 F 00

2. JJ )n 3.0 0 0.00 0 0'. nn 0 0 ~ an n 0.00 0 0 ~ un 00 3'

0 0 3 ' TO 3.4 0 o.un 0 u.nu 0 o.nn 0 0 F 00 0 0 F 00 0 F nona 3 ~ 2 10 0 rt ~ on 0 (I ~ 00 0 o.'on 0 0.00 0 0 00 0 0 F 00

') ~ 4 fn 0 eau 0 0 i)0 0 0.00 0 0 F 00 0 0 ~ nn 0 0 F 00 F 6 fO 3 8 0 n.'on n 0 F 00 0 o.no 0 o.oa 0 0 F 00 0 0 F 00 3 8 1O 4 0 0 0 ~ ou 0 o.no 0 0 F 00 0 o'. no 0 00 0 ~ 00 an 4.3 10 4,b S.'0 0 0 00 tl 0 nu 0 F 00 0 0 F 00 0

0 0.00 0 0 0000 . 1 O 0 o.on 0 ~ 0.00 0 o.on 0 0.00 0 0 F 00 0 0 F 00 5.0 fu S.s 0 o ~ uo 0 0.00 0 0,00 0 0 00 0 0.00 0 0 F 00 5.5 fO 6.0 0 0 ~ uu 0 0 ~ nn 0 0~00 0 0 00 0 0.00 0 o.no 6.n I 1) ri7.'n'i ~ 0 n.'nn 0 n.'no 0 0 na 0 0 F 00 0 0 00 0 0 F 00 has fn n n.nu n o.no 0 o.on 0 0 F 00 0 F 0 F 00 0 0 F 00 7.0 IO 7.5 0 F 00 0 F 00 7.5 fu I 0 o.on 0 0 0 ~ Qn 0 0 0 F 00 0 0 F 00 0 8'

~ 0 n.nu 0 tl ~ no 0 o.'on 0 0.00 0 0 F 00 0 0 F 00 10 9 0 ~ 0 u.rtn 0 u,nu 0 o.nn 0 ~ 0 F 00 0 0 F 00 0 0 F 00 9,0 fo ln.o n o. (Ju 0 n,nu 0 o.'no 0 0 F 00 0 0 F 00 0 0 00 0 fo 11.'n o.'no o'.no F 0 0 ~ on 0 0 0 0 F 00 0 0 F 00 0 o.no 11 0 fo 12.o ~ 0 rj.'oo 0 0 F 00 0 0 F 00 0 0 F 00 0 o.no 0 0 F 00 Ci( 12.0 0 0 F 00 0 0 F 00 0 0 F 00 0 0 00 0 0 0 0 F 00 TOTAL 2rt I on. 00 II I oo. Cju 100 ~ 00 0000 0 0 F 00 0 0 F 00 HaxlHUM aMf ~ 3 it ~ 41 ~ 37 0 F 00 0 F 00 0 F 00 TnfaL PRECIPITATION FOR oafa VEHIOI) 2 73 INCHES NO PCT -NO ~ PCT OffSERVa T lurtS Wl ftt rti3 1 HFCIV I Ta TION 1460 98.12 VALID OBSERVATIO)JS 1488 100 F 00 ~

olisFHvaf lotls vlTtt plrEclpl TAT IQN GE 0 ~ ol ItJCH i?8 I ~ 88 INVALID Ot)SERVATIONS 0 '0 00 TniaL V 1 Or)SI,(<Var IONS 14JJJJ 100 F 00 L OBSEHVATIONS 14 Iooeoo
s s:+ss Taf)LE 2 '"64 FttEnr)FrsCY OISTRIRUT IOrr Of Pt)ECIV I TAT'ION DATA PERIOD: Jt)LY l917 at)f) 1978 OaTa SOURCE) ow-SITE ST Li)CIE 'Lrt) I T HU1CHINSntt I SLAttn ~ FLORIDA FLORIDa PnstEft atro LIGHT Co. PVEC IP I TAT lort Ff)EOUENCV Ff)EnuEt)CV FREOUENcv FREOUENCY FREOr)ENCY FREOUENCY CLASS DISTRI)tstilnrt OF DISTRII)UI ION OF DISTR l ftt)T ION OF DISTR!I)UTIott OF DIST)tIHUTION OF D!STRInuTIOrf OF. INTERVAL P)tEC IP I TA t ION PHEC IP I TAT ION VRECI)'I TAT ION PREC !PI TAT Iotf PRECIP I TAT loll PREC IPI TAI ION I I Nc) tF. 5) I HOIIR 2 Hnr)R 3 ftOUR 6 HOUR 12 HOUR 24 HOUR Oi)RATION DUtt A 7 I ON DURATION DURATION DURATION DUR AT Iota No ~ PCf No. PCT No f'Cr ~ No. PCT No. PCT ~ No( PCT ~ Tn ~ I 26 63.41 5 35.71 0 0 00 0 F 00 0 0 F 00 o.on n .2 6 14.63 0 0 F 00 0 F 00 0 0 F 00 0 ~ 00 rn rn

~ 3 4 ~ tt sr ? ~ 44 sl:P 25.00 0 ~ ou o,etc t,oo 0 F 00 0 F 00 ~ 4 fn ~ 5 7 32 0 0+ lsn 0.00 0 F 00 0.00 ~ 5 fn ~ 6 0 u.nn 0 o.no 0 0 Gn 0 F 00 0 F 00 0 00 6 fo 7 2 4 urr 2 14 ~ ?9 n G.oo 0.00 0 0 F 00 0 F 00 0.'uu ~ ~ ~

7 rn .8 0 n n.no 25+00 0 00 0 G 00 o.on

~ '5o.no 1 F ~ f) 10 ~ 9 0 0.00 I 7 14 o o'.no 0 00 0 . 0 00 0 0 F 00 ~ 9 1() ~ 0 0 n.nn 0 n.on I 00 o.no 0 0 F 00 0 o.on 0 I 44 n 0 00 n 0 F 00 0 0 00 0 o.no il2 ~ ~

fn in ~ 3 0 0

~

0 00 u.un 0

~

7.14 o.'no o I o.nn 25.00 0,00 0 F 00 0 0 0 F 00 0 F 00 0 0 o'. no o.on

~ 3 fn ~ 4 0 0.00 0 oeGO o o.'no o.on 0 0.'no 0 Oooo ~ rs in .5 0 o.nn n.'nn n 0 F o.'nn 00 0 norm o.'on 0 0,00 0 0 F 00 o.'on fn ~ 6 0 0 0 0 F 00 0 F 00 0 0.00 0 its f{) ~ 7 0 0 Gn 0 0.'no 0 0.00 o.no 0 0.00 0 0 F 00 ~ 7 in .f) 0 o.no 0 G.nn 0 0 F 00 O.OO 0 0 F 00 0 0 F 00 ft in ~ 9 0 rs. Gn t) G.no o G.on G.ilo 0 O.'On 0 0.00 s) .n 0 rs.no n o.'nn 0 000 0 0 (rn 0 F 00 0 0 00 ~ 0 In 2 ? ~ 0 0 F 00 0 0 F 00 o o.nn 0 n.oo 0 0 F 00 0 0 F 00 ?.? in ?.4 0 o.nu 0 0 nu 0 0 F 00 0 o.'on 0 0 F 00 0 F 00 ? 4 rn 2' 0 n. (sn 0 is ~ un 0 0 F 00 0 0 F 00 0 0 F 00 o'. nn ? rn ?'.8 0 not)n n G.nn o o.on 0 G.no 0 o.'on 0 F 00 2.8 3.'n fr) irr .)'.n 0 o'.isn 0 0 ~ nn o o.no 0 O.ou 0 o.'on 0,00 3~2 0 n'.:sn 0 0 ~ nn o n.oo 0 0 ~ 00 n 0 ~ 00 norm 3 ' it) 3~4 n 0.00 0 n.nu 0'. no 0 0 00 0 0 F 00 0 0 00 o.on F 4 'tr) 3.6 0 Ootrn 0 0 0 ~ 00 0 0 F 00 0 0.00 0 F 00 3' fr) 3 ~ 8 0 o'. Gn 0 n.no o o.'no 0. 0.00 0 0 00 0 ~ Gs0 an is) 4~0 0 0 ~ on 0 o.'no 0 0 F 00 0 0 00 0 0.00 o,on an 4'

fs) rn r 5 S.r) 0 0 n.nu ir un 0 n 0 ~ nn o'.no o u o.no 0'.no 0 0 0 ~ 00 0 ~ 00 0 0 o.on 0 ~ Gn Oooo 0 F 00 5 ' rt) 0 0.00 0 o.on o o.'no 0 0 F 00 o.'on 0 0 F 60 0 F 00 5.5 fsl 6.0 0 o.nn 0 o.no n o.oo 0 0 0 F 00 o'.On f,n 6 5 in

~

in h.b an 0 0

0. fsn o.no n

0 o.on o.'no o o o.'no n.oo 0 0 0 00 o'.no 0 0 0 00 0 F 00 0.00 n.oo 7.O io 7.5 0 n. ssn n 0 ~ 00 u.'no o o.no 0 o,no 0 0 00 0 00 7.5 fn e'.n fn ft.o 0 G.nu n n G.oo 0 0.00 0 0 F 00 0 ~ 00 9.0 n'. 0 G.nn 0 0 Ou n o.on 0 o.nn 0 O.'GO 0 F 00

9. i) in 0 0 ~ Gn 0 G.nn o o.on 0 0 00 0 0 F 00 0 F 00 ln 0 ro ll.'o0 0 n.on 0 G.nu 0 0'.on 0 F

0 F 00 0 0+00 Oooo ll ~

~ 0 in 2.n rsf 1?.u 0

0 0 F 00 0 F 00 0 0 O.nn o.no n 0 o.oo 000 0 0 0 F 00 0 F 00 0 0 0 00 Oeno 0 F 00 0 F 00 T() f aL lno.uu lr loo.no 4 100 00 0 F 00 0 0 F 00 0 0 F 00 Hhx IHr)H aMI I ~ OI I ~ 24 0~00 0 F 00 0 F 00 fntaL Pf<ECI)sITATION Fort f)t Ta PE)rlOD 6.54 !NCHES tro. PCT, NO ~ PCS nl)SF:rVATIOrt& )Sf))l stn PRf.CIPITATInrk 1447 97.24 vAL ID oOsEflvAT IONS 1488 IOG F 00 ()stsf stva f Is)sts )rf f)t VREclvllaf loth GE 0 ~ Ol INCti 41 2. 76 INVALID Ot)SERVATIONS 0 0 F 00 rnrat. vai. Io nt)sERvaf IONS 14tttt 100 F 00 TOTAL OOSLIIVATIONS 1488 Ion+00
TAOLE 2 '-65 F JJEOUEJJC V n I 5TR I I)U T I O(4 Of PREC IP I TA T ION OATA PER IOO: AUGUST 1977 AN(J 1978 OAl'A SOURCE) OW-SITE St LUCIE UNIT 2 HUTCHI J(SO() ISLA('JO ~ FLORIOA FLORIOA Po)(EH ANO LIGHT CO PREC IP I TAT IO(4 FREr)IJE:rcv FREOIJENCY . FkEOIJENCY fREOUEWCV FREOUENCY. FREOUENCY Cl,ASS OIST(el)i(lt lo(J OF DIFJTJ>IHI>t in(4 OF ()IST(clHUtloW OF OISTRIHUTIO(4 Pf DISTRIHUTIOW OF DISTRIBUTION OF INTL>eVAL PRECIPITAtlocl Pret CII'I TAT ION PREC II'ITAI ION PRECIPITATION PRECIPITATION PREC IP I TA I I O)4 l INC>IES) I HOI JR 2 Hnl)B 3 HO(JR 6 HOUR 12 HOUR 24 HOUR l>I>kAT ION oIJ(eAT10)4 UukAT ION OURAT Iow OURATION DURATION l NO. 49 7".".34 No ~ NO PCt. No. PCT No PCT No. PCT.

~ 0 To to ~

2 8 12. I? 9

?

5(>. 15 12.50 0 0 00 2b.oo 0 0 F 00 0 F 00

0. o.no 0 0 F 00

~ 1 1 0 0 0 F 00 0 0 F 00 ~ ? t I) ~ 3 4 F>. 06 l I 25.00 0 0 F 00 0 a.oo 0 0 F 00 ~ 3 tn ~ 4 I 1.52 l h ~ 25 0 0 F 00 0 a.'oo 0 0,00 0 0 F 00 tl) 5 F 03 6

to rn .7 2 0 0 0 (10 0 F 00 n 1 6 '5ao 0 F 00 0 I 0 F 00 25.00 0 F 00 0 0 .0 ~ 00 0 F 00 0 0 0 F 00 0.00 0 0 0 F 00 0 F 00

.I ~

lo 10

.cs 9

0 0 F 00

n. r>n n

0 0 n.nn 0 0 0 F 00 0 0 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 0 0>on 0 F 00

~ L! 0 0 Q.au 0 0 F 00 0 o.no 0 0.00 0 0 F 00 9 to .0 0 n.un 0 0.00 0 0 00 0 0.00 0 0.00 0 o.on .n ~ I 0 A.nn 0 0 F 00 0 0 00 0 0 F 00 0 0.00 0 0 F 00 ~ I ~ ? 0 n.oa 0 0 C>Q 0 0 F 00 0 0 F 00 0 0 F 00 0 F 00 .? 0 0 ~ c)n n O.AA 0 o'. nn 0 0 00 0 0 F 00 0 F 00 ~ l lo ~ 4 I I ~ 5?.

o.'ci 0 0 F 00 0 n 00 0 0 F 00 0 o.no 0>00

~ 4 .5 ln (O I ~ .6 > 0 l 6 ~ 25 l 25.00 0 0 F 00 0 0 00 0 0 00 F

0 0 (IO 0 0.00 0 0 F 00 0 0 F 00 0 0 00 0 0 F 00

>6 )0 I .7 0 n.uo 0 A.AO 0 0 F 00 0 o.'no 0 0 00 0 0.00 .7 'l 0 ~ o 0 A. Ica 0 0 ~ QU 0 0 Aa a 0 ~ Qo 0 0 F 00 0 0 ~ no ~ c> lo 9 0 0. (>A 0 o.nn 0 0 ~ Ao 0 o.'on 0 o.'no 0 0 F 00 ,9 J .0 0 0 ~ (> 0 n 0 ~ (>0 0 0 ~ 00 0 0 00 0 0 00 0 0.00

n I 0 2.? I 1.52 l I>. 25 0 0 00 0 0 F 00 0 0 F

00 0 0 00

? ?~ )0 2 4 ~ 0 0 on 0 A.()n 0 n.uo 0 o'.no 0 duo 0 o.'no F ? 4 lfl 2 ' ~ 0 o.on 0 U.no 0 0 F 00 0 0 ~ nn 0 0.00 0 o'.no 2 f lo ~ ?,(s 0 (>. QU 0 o.'no 0 F 00 0 a.'no 0 0.00 0 00 ln I.'n n n'.no 0 n.r>o 0 0 ~ Un 0 0 C>0 0 0 F 00 0 0 F 0 00 3>A IO '3.2 0 A.no n 1).nc) 0 0 QO 0 o.nn 0 n'. oo 0 o.on 3~ ? l i) .'l. 4 0 O.AO n o.'oa 0 o.no 0 0 00 0 0.00 0 0 F 00 3~4 ln 0 0 ~ AO 0 A.no 0 0 F 00 0 F

0 F 00 0 0.00 0 o.na Iah >) 3. 0 3.8 tn 4.n 1 0 u.nn 0 A.nn 0 o.'on 0 0 F 00 0 0>00 0 0 F 00 4.0 tc) 0 U.AU 0 u. OI> 0 0 F 00 n.'( 0 0.'un 0 0.00 0 o.an n n.r>n 0 U.no 0 u 0 0 C>o 0 0 F 00 0 o.on 4>5 ln 5 0 ~ 0 A ~ Ac) 0 n.on 0 0.'r>0 0

~

0.'nO 0 0 00 0 0>00 S.n tn 0 u.'nn 0 O. 'C>O 0 0 F 00 0 0 00 0 F 0.00 0 o.'on 5.5 lr) f>.n 0 0 ~ uc) n n.'An 0 0.00 0 0.00 0 0 F 00 0 ,0 ~ 00 6 0 ln 6.5

~ 0 C>. GO 0 A.no 0 0 ~ no 0 n.on 0 0.00 0 0 F 00 6 "> li) 7.1) ~ 0 n.no 0 0 ~ ac) 0 0 00. 0 0 F 00 0 0 F 00 0 0.00 7.'n lo 7.5 0 A.uo 0 0 ~ ri0 0 Q.QQ 0 0 F 00 0 0 F 00 0 0 F 00 7.5 ln cS.O 0 0 ~ 00 0 0 ~ nn 0 0 F 00 0 o.un 0 0 F 00 0 0 F 00 (3 0 ~ 1 0 'J. 0 0 0 ~ Ao U o.'An 0 0 0>3 0 0 F 00 0 0 00 0 0 F 00 9:n to Q.o 0 o.no 0 o.'no 0 0.00 0 0 F 00 0 0,00 0 O,GQ n.'o tn l.a 0 0.00 0 n'.Ao 0 0 F 00 0 0 F 00 0 0.00 0 F 00 I l. o tn 2.0 1 0 0 A.AQ 0 0 ~ 00 0 0 F 00 0 0 F 00 0 0 00 0 0 00 2'

F F Gt 0 0>UO 0 0 00 0 0 00 0 0 F 00 0 0 00 0 0 F 00 TOTAL 6r lnu.uO 16 loo.r)o 100 F 00 0 F 00 0 0 F 00 0 0 F 00 Jch>I lc'Icrcl A>1 ( ~ 2.07 2~ Ib I 43

~ Oeoa 0 F 00 0 F 00 TOIAL PJCFCIPI TAT low Fok OAta l Lkloo 8 '7 INCHES N() PCT (40~ PCT A H>CRVAtlnc)S I.ITH r)n PRECIPI thtlOW 123l '94 ~ 9 l VALIO OHSERVATIOWS 1297 87.16 0(J'I(eYAI IGJJS 'Al tll P>>EC lPI TAT ION GE 66 t(>CA( YAI OHSE(eYAT In(IS 0 Ol I New l297 5 09 100 F 00 INvALIO 0>JSERvAT IONS T OOSEcevAT I OWS l48~

191 12 84 00 ~ 00
SL AR TABLE 2.3-66 FREOUENCY DISTRIBUTION OF PAECIPITAT ION DAfA PERIOD) SEPTEMBER 1 ~ 1976 AUGUST 31 ~ 1978 DATA SOURCE SOURCE: ON-SITE St+ LUCIE UNIT 2 HUTCHltlSOtl I SLAtlD ~ FLORIDA FLORIO* f'()WEit ANU LIGHT CO ~ I PRE C IP I AT ION F REOUI'.NC Y DISTAIBUT10)l OF FkEUUFNCY DISTklllUTIUN OF FAEGUENCY DI5 IA I But IOtl Or FREQUENCY DISTAIUUIIOth OF FAEOUE NCY DISTAIUUTIOM OF FREQUENCY DISfklBUIION OF CLASS INTFAVAL PRECIPI TAT lotl PRE CIPITAI ION Pkt.C IP I In I I ut) PREC IP I TA I lDN PREC IP I TA I ION PAEC IP I TA1 ION ( INCHES) 1 HOUR ? HOUR 3 HOUR 6 HOUR 12 HOUR 24 HOUR DURATIOtl Dt)AATJOts DUAATIow DURATloll DURAT ION DURATIOt4 Pcf, NI). PCf ~ PC~ NO ~ PCT ~ NO PC1 ~ ND( PCI ~

~ 0 TO I Nf( 70.eb 44 F 09 NO< 0.00 0 0 F 00 0 F 00 ~ 1 TO ~ 2 67 12 'b2 36 19. 35 21 26 25 23.53 0 0 F 00 0 0 F 00 e.54 9.14 .7.5o 17~65 0.00 0 F 00 ~2 10 .3 TO ~ ~

3 4 35 2 '9 17= 13 6.99

'9 e

9 11 ~ ?5 17,e5 o.'on 0 1 50 F 00 0 F 00 0 0 0 F 00 00

~ 4 .5 oe 10 TO TO +5 ~ 6 ~ 7 Is F 00 I.BI ~ 93 5

Il7 2 3 '6 5,9) 0 3 . 3 0

'5 ~ 00 lode 5 ~ 88 o.'on 0

0 0 0 00 0 F 00 0 0 0 0 oeCO 0 F 00

~ 7 TO .8 5 6 F 25 0 F 00 0 0 F 00 0 0 F 00 ,8 I() ~ 9 F 37 54 I ~ 25 0 F 00 0 0,00 0 0 F 00 ~ 9 10 ~ 0 o.no 4 beoo 5 F 88 0 0 00 0 0 F 00 0 F 00 ~ 0 TO ~ 2 F 37 F 54 2 /SO 0 F 00 0 0 F 00 0 10 J 0 0 F 00 .54 F 88 0 0 F 00 0 0 F 00 ? 10 ~ 3 .IO ~ 3 4

0 0 00 19 I. 0)) 0 F 00 2 0 F 50 0.00 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 0 0 F 00 0 00

~ 4 10 .5 .19 ~ 54 2 2e50 0 00 0 0.00 0 0 F 00 ~ 5 TO ~ 6 0 0 F 00 F 54 0 0 F 00 5 ~ 08 0 0 F 00 0 0 F 00 ~ 6 To ~ I 0 0 F 00 0 F 00 0 0 F 00 0 F 00 0 0 F 00 0 0 F 00 or TO .8 0 0 F 00 0 F 00 0 F 00 0 F 00 0 0 F 00 0 0 F 00 8 TO ~ 9 1 o l9 0 F 00 F 25 0 0.00 0 0 F 00 o.'no ~ 9 10 ~ 0 0 o.'no 0 F 00 F 00 0 0 ~ Uo 0 oO TO 2 2 1 ~ 19 ~ '54 ~ ?5 1 50.00 0 0 l)0 ? ~ ? IO 2-4 0 0 F 00 0 ~ 00 0 ~ ()g 0 0 F 00 0 0 F 00 2 '

2.'e Io 10 2 6 2.8 0 0 0 0 F 00 F 00

~ 54 0'. 0O 1 ~ ?'b 0 ~ 00 0 F 00 0 F 00 0

0 0 F 00 0 F 00 0 0 0 F 00 0 F 00 2+8 10 F 0 0 0 F 00 o.'00 0 F 00 0.00 0 0 00 0 0 F 00 3 0 10 3 ~ ? IO 3 ' 3.4 0 0 0 0 00 00 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 0 0 0 F 00 0.00 0 0 0 F 00 0 F 00 3.6 00 o'.no oooo 0 F 00 0 0' 00 0 0 F 00 3 4 I l) 0 0 F 3 ~ 6 10 3.b 0 0 F 00 0 ~ l)0 0 F 00 0 F 00 0 0 00 0 0 F 00 3 8 10 4 0 0 F 00 o.on 0 F 00 0 F 00 0 0 F 00 0 0 F 00 4 0 IO 4 ~ 5 TO 4 ' 0 0 F 00 o.no 0 F 00 0 F 00 0 F 00 0 F 00 0 00 0 F 00 0 0 0.00 0 00 0 0 0 F 00 0 F 00 0 F 5.0 IO 5~5 0 0.00 0 F 00 0 F 00 0 F 00 0 0 00 F 0 0 F 00 5 5 10 6~0 0 0 F 00 0,00 0 F 00 0 F 00 0 0 00 0 0 F 00 beo 10 6+5 0 0 00 o.'no 0000 0 00 0 0 F 00 0 0 F 00 6 ~ 5 10

' 10 7 '

ro5 0 0 F 00 0 F 00 0F 0 00 00 0 F 00 0 F 00 0 F 00 0 F 00 0 0 0 F 00 0 F 00 0 0 0 00 0 ~ 00 7 0 7.5 IO F 0 0 0 00 0F 00 0 F 00 0 F 00 0 0 F 00 0 0 F 00 F 0 IO F 0 0 0' 00 0F 00 0.00 0 F 00 0 0.00 0 0 F 00 9:0 IO 0~0 0 0.00 0 F 00 0 F 00 0 F 00 0 0 00 0 o.on 10 F 0 IO I~0 0 0 ~ 00 0 F 00 0 F 00 0 F 00 0 0~ 00 0 0 F 00 11,0 10 ?oO 0 0+00 0 F 00 0 F 00 0 F 00 0 0 F 00 0 0 F 00 Gt 2' 0 0~00 0 F 00 0 F 00 0 F 00 0 0 F 00 0 0 F 00 TotAL 535 100 F 00 186 100 F 00 80 100 F 00 17 100 '0 2 100 F 00 0 0 F 00 HA)(IHUM ANTE 2.07 2 ~ 43 2+51 2 '3 2+12 0 F 00 TOTAL PRECIPITATION FOA DATA PERIOD 63 ~ 16 INCHES NO+ PCT OBSERVATIONS WIT)l NO PRFCIPI TAT ION OBSERVATIONS WITH f'AECIPITATION GE 0 ~ 01 TOTAL VALI 0 OU SEA VAT I ON 5 INCH NO 1679t S35 17326 PCT 96.9) 100 ~ 00 VALID OBSERVATIONS INVALID Oi)SERVATIONS TOIAL OBSERVATIONS

'94 17326 )7520 98 F 84 Idyll 100%00

TABLE 2 '-67 JOINT wIND FREQI)ENcY I) I s)'R I))UT IDN oatA ptRIDD) sEpTE)48844 1976 AND 1977 P)4ECIPI TAT ION Wl)44) HOSt ST L))CIE UNIT 2 DaTa 504)RCE t ON-SITE HUICHINSON ISLAND~ FLORIDA WIND SENSOR HEIG)4T: 10 ~ 00 HETE)46 FL4))41OA POWE)4 AND LIGHT Coo wIND SPt'.EO CATEGORlt S(HEI'ERS PtR SECOND) WINO SECTOR 0 ~ 0"I 5 I ~ 5- I 0 3 0-5.0 5 '-7 5 I 5-10 ~ 0 >loan TOTAL HEAN SPEED NNE 0 0 0 0 0 0 0 0 F 00 0 F 00 0 00 0 F 00 0 F 00 o.no 0 00 0 F 00 0 0 n 0 0 0 0 0 F 00 0 F 00 0 ~ no 0 F 00 0 00 0 F 00 0 F 00 0 F 00 ENE 0 0 F 00 2 '4 1 2.94 I 0 ~ Uo 0 0 0 ~ OU 0 00 n 5 F 83 2 '5 0 0 2 0 0 0 2 4 F 50 0 F 00 O.nn So88 O.no 0 F 00 0 ~ no F 88

'0 ESE 2 '4I 2 '4I 2i94 I

0 F 00 0 0 F 00 0 F 00 0 8 '2 3 2+37 SE 0 F 00 0 5+88 2 0 ~ OU 0 0 0 F 00 0 F 00 0 8 '23 2 '3

.n 4 '5 17 '5 SSE n 3 ) 0 ~0 6 0 ~ OU 0 F 00 8.82 8 82 O.UO 0 00 17 '5 0 0 2 n 0 6 3+30 t4. on II ~ 76 o.on 5.88 0 F 00 O.OO SSW 2 '4I 2..$ o.oo 0 0 0 F 00 0 F 00 0

8.8) 2 '3 SM n 0 n n 0 0 0 4 F 00 0 F 00 0 F 00 o.on o.on 0000 0 F 00 0 F 00 WS'W 0 n n n U 0 0 0 F 00 0 F 00 o.oo U.nn o.on 0 F 00 0 F 00 0 F 00 0 F 00 0 2 '4I U~ n nn 0 ~ OU 0 0 0 F 00 0 0 ~ 00. 2 '4I 2 70 4 I o 10 W)4W 11 ~ 76 0 ~ 00 n o.nn n O.UO 0 0 0 ~ no 0 F 00 0 11 '64 NW 2+94 u 0 0 0 2 I ~ 80 2 94 0 F 00 O.no O.UO 0 F 00 5.84) NNW 0 ~ no 0 n.nn 0 n.on 0 o.no 0 0 F 00 0 2 '4I ~ 90 r n I 0 0 0 0 I 2e'70 0.00 2. )4 u.nn n.on o.on 0 00 2+94 CALH 0 0 CALH o.on 0 F 00 TOTAL 23 '38 35.29 12 2h 47 14 '15 0 0 F 00 0 00 0 100 F 00 34 2 '5 N))HOER DF vaLID 0!)sFRvatlnus wt tH PREcIPItatloN 34 2 '6 N))MBFR t)F VAL IO OBSFRVAI 104)S wl t)IUI)T PRtCIPI IAT ION II)h N))HRt)4 'Of'NVALIO Oi'SE)4VAT I ONS 7'0

?0 14 ~

PCT PCT PCS

~

tntAL t)i)HI)F)4 OF OOS(t)VAT 14)NS 100,00 PCS 6 '3 1440 TOTAL AHOU)4T OF PRECIPITATION FOR DATA PERIOD INCHES KEY XXX N))HOER OF 4)CCU)4)<E)4Cf:S XXX Pf:)4Ci;NT OCC))RI<ENCES a
J. SAR TABLE 2+3"68 JDINT MIND FREOUENCY DISTRIIJJJT ION Data PERIOD: OCTO))EH 1976 aNO 1977 PHECIP I TAT ION WIND f>OSE S I~ LUC IE IJNI T 2 DATA SOJJJICE J ON-SITE tJJJTCJJINSON ISLAND~ FLORIDA WINO SEtlSOR JIEIGJJT) 10 ~ 00 NETEHS FLOHIOA POMEtI AND LIGHT CO ~ WINO 'WINO SPEED CATEGOHIESIJJETEHS PEH SECOND) NEAN

~

SECTOR 0 1 I~5 3 3 ' 5 5 ' 7 ' 7eb-10 0 ilo ~ 0 SPEED NNE 0 ~ on 0 4.17

?

JI ~ 33 4 4 ~ 1I 2 0 0 F 00 0 F 00 0 16 '78 F 07 0 F 00 0 Oooo 0 2 ~ ndk 4 ') n 0 F 00 0 F 00 0 6 '3 5 '0 ENE 0 ~ 00 0 0 ~ on 0 6 '3 20 83 10 0 0 F 00 0 F 00 0 27.t83 5 ~ 47 4s99 0 F 00 0 0 F 00 0 8 '3 4 8 '34 0 0 ~ no 0 F 00 0 le.e7 8 ESE 0 F 00 0 0 F 00 0 8 '3 4 0 F 00 0 0

-0 ~ 00 0 F 00 0

8 '3 3 '2 SE 0 I 0 0 0 3 '5 0 ~ on 2.0> 2+08 0 F 00 0 F 00 0 F 00 SSE 0 00 0 4+1't 7 2.03 0 F 00 0 0 0 F 00 0 F 00 0 6 '53 2e67 0 ~ on 0 2.0JI o.oo n o.nn 0 o.nn 0 0 ~ 00 0 2 ~ 08 I 2 '0 SSW 0 0 n 0 0 0 0 0 F 00 0 F 00 0 F 00 O.on 0 F 00 0 F 00 0 F 00 0 F 00 SW 0 0 0 0 0 0 0 0 F 00 0 F 00 0 ~ nn 0 F 00 0 F 00 0 F 00 0 F 00 0 ~ 00 WS'M o.oo 0 2.n8 o.on n o.oo 0 0 0 F 00 0 F 00 0 2 ~ 08 I 2 '0 n 0 0 0 0 0 0 0 F 00 0 F 00 0 F 00 0 ~ no 0 F 00 0 F 00 0 ~ 00 0 F 00 MNW 0 F 00 0 0 ~ 0 on 2.n8 1 o.nn 0 0 0 F 00 0 F 00 0 F 08 1 3 'n NW 0 0 0 0 0 0 0 0 F 00 0 ~ no 0 F 00 o.no o.no 0 F 00 0 F 00 0 F 00 NNM o.on 0 8 '3 4 0 F 00 0 0 F 00 0 0 0 F 00 0 F 00 0 8i33 4 2435 0 0 0 0 JJ 0 0 0 F 00 0+00 0.00 0 ~ no 0.00 0 F 00 0F 00 0 F 00 CALJI 0 ~ 0 CALH 0 F 00 0 F 00 0.00 0 22.92 11 39.58 19 37.50 I JJ 0 0 F 00 0 F 00 0 100%00 48 4 '5 NlloofR of VALII) ol)sEJJVatlnt~S MITT) PHECIPITatlow 48 3 ~ 23 PCS tllJNI)l:H OF VALII) 03SEHVAt IotlS Ml IJJJ)IJ f PJIEC IP I TAT ION 1364 tlllwllL'H Of IJ~VAI.IO OUSERVAT IUNS 76 9/ie7 11 PCI PCT

~ ~

TOTAL tn)NBEJI OF oasE)tvatloNS 1488 100 ~ 00 PCS totAL AJIOUNT OF PRECIPITATION FOH DATA PERIOD 4 ~ 94 INCJIF S Kl:.Y XXX Nllt)JJFJI Of OCCJJJ(JCtJJCES
TABLE 2+3-69 JOINT WIND FHE()(IENCY OISTRIBUT ION DATA PERIOD( NOVEt(dER 1976 AN() 1977 PRECIPITATION Wlt(D ROSE 51 LUCIE UNIT 2 DATA SOURCE( ON-SITE t(UICHINSDN ISLAND FLORIDA WIND SENSOR t(EIGHT: 10 F 00 HETERS FLORIDA POWER AND LIGHT CO. w It(D SECTOR 0 '-1 WIND5 SPEED 1 5-3 0 AU-S.Q 5 '-7 ' CATEGOHIES(HETERS PER SECOND) 7+5 10 ' >10 ~ 0 TOTAL HEAN SPEED NNE a.oo 0 o.no 0 2.n4 I o.oo 0 0 0 F 00 0 00 0 F 04 I 4 '0 NE 0 0 0 3 4 '3 o.on 2.0L 2.0L 2.0L 0 ~ QU 0 F 00 6 12 4 '7 ENE 0000 0 0 ~ n 00 8 ~ 16 2 4 ~ 08 0 0 F 00 0 F 00 a 12 '46 16 '3 E n n 2 e 0 0 8 5 54 0 F 00 0 F 00 F 08 12+24 0 F 00 0 F 00 0+00 0 0 0 F 00 2 '4 1 3 6 ~ 12 0 0 F 00 0+00 0 8~ 4 Ib 5+37 SE 0 0 F 00 16 '38 0 0 ~ 00 0 0 F 00 0 0 F 00 0000 0 lb+33 8 2+29 SSE 0 0 F 00 F 08 2 2 '4I 0 0 F 00 0 0 F 00 0 F 00 n be 12 3 3+00 12 '4 e F 85 S 0 0 ~ on F 08 2 F 08 2 0+00 0 0 F 00 0 20 '110 SSw 0 n n 0 0 0 0 0 F 00 0~00 0 F 00 0 F 00 Oooo 0 F 00 0 F 00 Q ~ QQ Sw n n 0 n 0 ~ 90 F 04 0 ~ 00 Quinn 0 F 00 o.oa 0 F 00 2.03 wsw 0 0 U 0 0 0 0 0 F 00 0 iaa 0 00 o.no a.oo 0 F 00 0 F 00 0+00 0 0 0 0 0 U 0 0 F 00 0 ~ Qn 0 ~ nn Q.on 0 ~ Uo 0 F 00 0+00 0 ~ 00 WNW I 2 ~ 04 o.nn 0 0 0 F 00 0 F 0 00 0 F 0 00 0 F 00 0 2 '4 1 1 '0 NW a a 0 n n 0 0 0 F 00 0 F 00 o.nn U ~ Qn 0 F 00 0 F 00 0 F 00 0 F 00 Q.nn 0 2.nk 2.n4 I o.nn 0 0 00 0 0 F 00 0 F 08 2 2 '0 2 0 n n 0 0 ? I ~ 10 4 ~ QB u.na 0 F 00 0F 00 0 QI) 0 F 00 4 ~ 08 CALH 0 0 CALH 0 ~ on 0F 00 TOTAL Bale 28 87 14 )7 34 ~ 69 14 78 ~ 57 0 0 F 00 o.nn 0 100 F 00 49 3 '2 Nl)t((IER nF VAL Io oBSF((vnl lnN>> w I I(( (ii(FCIP I TAT IDN 3 ~ 40 PCS t(()(8EH GF VALID 08sEHyAItnws ('T((o()T pwtclpiTATION 13'$4 92.e4 PCT ~ t(((ddER OF It(VAI.ID OI)SLRVAT IOt(S 57 3 ~ 96 PCT ~ TOTAI NUHBEH OF OBSERVATIONS 1440 IQQ F 00 PCS TOTAL AHOUt(T OF PHtCIPI TAT ION FOH DATA PERIOD 5,5b INCHES KEY XXX NI)MI(EH OF ()CCU((HE(ACES XXX PEHCENT OCCURHCNCh.S
S PAR TABLE 2 '"70 JOINT WIND FREOUENCY D IS)'R lr)Uf ION OAfA PERIOD) DECEMBER 1976 ANO 1977 PAECIPITAT ION HIND RASE ST ~ LUC I E UN I I 2 DATA SOURCE) ON-SlfE Hr)TCHIt4SON ISLAND ~ FLORIDA WINO SENSOR HEIGHT: 10 F 00 METERS FLORIDA POWER ANO LIGHT CO ~

'W I NO WIND SPEED CATEGO)rIES(HET).RS f ER SECOND) MEAN SECTOR 0 ~ 01 ~5 I~ 53 ~ 0 3~ 050 5~ 07 ~ 5 7 '-10 F 0 ilo ~ 0 TOTAL SPEED NNE 0 0 n 0 0 0 0 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 0 ~ Uo 0 F 00 0 F 00 NE 0 0 0 - 0 n 0 0 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 0 F 00 ENE 0 ~ nn n

0 ~ nn n 5 'r)3 3 '22 0 ~ 00 0 0000 0 F 80 5 5 '2 0 n 2 0 0 3 5010 0 ~ nn 0 ~ no 1.9L 3.92 0 F 00 0 ~ 00 5 ~ BU ESE 0 F 00 0 0 F 00 0 3 '22 0 ~ no 0 0 ~ 00 0 0 ~ 00

-0 3+92 2 4 '0 13 '3 '98 SE 0 7 0 0 0 F 85 1 9k 0 ~ 00 0 00 0 F 00 04 00 15 SSE 0 3 '2 n I 0 0 2 4+25 0 F 00 1 9L o.on I ~ 96 0 F 00 0 00 1 3 0 0 0 5 F 12 ).9L I ~ 96 5 ~ 8)) 0000 0 ~ 00 0 F 00 9.80 SSW o.on n

3 '22 I 96 I 0+00 0 0.08 0 F 00 0 S 88 3 2.67 SW 0 F 00 0

5. Br) 3 3 '22 0 F 00 0

0 ~ 00 0 11 ~ 76 6 4 ~ 33 WSW 0 ) 0 0 0 0 1.80 0 F 00 I ~ 96 O.nn 0 ~ nn 0 F 00 0 F 00 3 I U 0 0 S 2056 5 ~ 88 1 ~ 96 0 F 00 o.on 0 F 00 9+80 WNW I 96 1 0 00 0 1+96 1 0 00 0 0 ~ 00 0 oooo 0 3 '22 2 'S NW 0 3 0 0 0 2 ~ 35 0400 5 ~ 88 I +9' O.nn u.no 0 F 00 7 ~ 84 1 9L 3 '2 0 ~ nn 0 0 F 00 0 0 F 00 0 F 84 4 F 00 0 F 00 n I ~ 96 1 n.oo 0 0F 00 0 0 F 00 0 0 F 00 0 I ~ 96 1 2 '0 CALH 0 0 CALM 0 ~ on 0 F 00 TOtAL 7 )2 24 8 0 0 5 3+56 13.73 23.5 ) 47.n6 lb.69 0 ~ 00 0 F 00 Ioo.o) trl)HBFR oF vaLID oosrwvatlnws HITH PREclpITATIotr 3.43 Nl)ljr!)IR OF VAL}l) nl)SF)tvht IOTAS WI fHOUT PHFCIPI fat ION 12351 t)2 86 PCS PCT ~ Nl)H!lEA OF INVALID r)r)SIRVAT IONS '04}}

ML17266A362

Text

Dear Nr. Eisenhut:

SUMMARY

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