ML19351D860
| ML19351D860 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie  |
| Issue date: | 11/14/1980 |
| From: | FLORIDA POWER & LIGHT CO. |
| To: | |
| Shared Package | |
| ML17266A363 | List: |
| References | |
| NUDOCS 8011200258 | |
| Download: ML19351D860 (650) | |
Text
{{#Wiki_filter:__ _ i O l i ATTACHMENT 2 9, l Re: St. Lucie Unit 1 l Docket No. 50-335 Stretch Power _ i O i 4 i TECHNICAL SPECIFICATION CHANGES i O I
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O O O O O TABLE 1 St. Lucie Unit 1 - Stretch Power . Technical Specification and Bases Changes 1 h Specification Change Remarks 1-1 1.3 Change rated thermal power .l from 2560 Nt to 2700 Nt.
- )
2-2 Figure 2.1-1 Replace this figure with a The Thennal Limit Lines have been changed to revised figure. reflect 2700 Nt 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 Asynunetric 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 Figu.c 2.2-2 Replace this figure with a The LPD LSSS is being changed to reflect operation revised figure. at 2700 Hwt with higher radial peaking factors. These limits were generated using a fuel centerline melt limit of 21.7 kw/f t. 2-8 Figure 2.2-3 Replace this figure with a The TM/LP LSSS is being changed to reflect opera-revised figure. Lion at 2700 At with higher radial peaking factors. 11-14-80
TABLE 1 (continued) Page Speci fica tion Change Remarks 2-9 Figure 2.2-4 Replace this figure with a The TM/LP LSSS is being changed to reflect opera-revised figure, tion at 2700 Mwt with higher radial peaking factors. B2-1,82-3 B2.1,82.2 Change the "W-3 DNB correlation" The DNB correlation used in the Cycle 4 analysis B2-5,B2-7 to "CE-1 DNB correlation", and is the CE-1 correlation and the minimum DNBR has changa the minin.uin Ufdik value been reduced to 1.23. I frora 1.30 to 1.23. 82-4 B2.2.1 Editorial change for clarifi-cation. 82-5 B2.2.1 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. 82-7,02-8 B2.2.1 Add a function description for the asynnietric steam generator transient protective trip. 82-7 82.2.1 Revi'se the TM/LP Trip descrip- The TM/LP Trip description has been mvised to f tion. reflect the change in methodology (n.7 COSM0/W-3 to statistical TORC /CE-1 and the CEAL aca tegcri-zation. 3/4 1-1 3/4.1.1.1 Change the Shutdown Margin The shutdown margin has been increased to yield ' for T-avg >200 F from acceptable consequences from a Steam Line Break 3.3%Ak/k to 4.3fAk/k. event due to the moienegative MTC allowed in Cycle 4. 11-14-80 9 O O O _ O
O O O O O l l TABLE 1 (continued) Page Specification Change Remarks 3/4 1-3 3/4.1.1.2 Change the Shutdown Margin The shutdown margin has been increased to lengthen for T-a.g below 200 F from the operator action time required in a boron dilu-1.0%Ak/k to 2.0%ar/k. tion event. 3/4 1-5 3.1.1.4 Change the MTC limit to The most n' egative MTC permitted for Cycle 4 "less negative fhan has been made more negative for longer cycle
-2.5X10- ak/k/ F." lengths.
3/4 1-10 3.1.2.2 Change the Shtudown Margin The required shutdown margin has o'een increased equivalent at 200 F to at to be consistent with Specification 3/4.1.1.2. least 2%ak/k. .,i 3.1.2.8 Change the Shutdown Margin The required shutdown margin has been increased j 3/4 1-18 to be consistent with Specification 3/4.1.1.2. equivalent to at least 2%Ak/k i at 200 F. I
! 3/4 1-30 Figure 3.1-2 Replace this figure with a The PDit is being changed to be consistent with revised figure. the new LPD and TM/LP LSSS.
, -3/4 2-3 Figure 3.2-1 Change the allowable peak Increase the allowable peak linear heat rate to
- linear heat rate from 14.68 15.0 kw/f t to be consistent with the ECCS analysis
- kw/ft to 15.0 kw/f t. value.
l i e 11-14-80 i
TABLE 1 (continued) Page Speci fica tion Change Renarks 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/"t 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 .i revised figure. have been increased due to the higher enrichnent i fuel and uncertainty in the power distributions of future cycles. 3/4 2-6 3.2.2 Changethgmaximumcalcu- The curves of Fr T and FxyT vs. power are being lated Fxy from 1.627 to 1.70. changed to reflect oparation at 2700 Mat with higher radial peaking factors, new LPD LSSS, new TM/LP LSSS, new DNB LCO, and new LilR 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 Ciiange 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 orc.ui.lon revised figure. at 2700 Mwt with a 549 F inlet temperature and higher radial peaking factors. 3/4 3-2 Table 3.3-1 Add " steam generator pressure The asynnetric steam generator pressure trip has dif ference-high" description been added to the Table. to Table. 11-14-80 0 - 0 0 0 0 --
O O o o o TABLE I (continued) . Page Specification Change _ Remarks Table 3.3-1 Change the " steam generator The " steam generator pressure-low" trip bypass has 3/4 3-4 pressure-low" trip bypass from been increased to be consistent with the new trip 585 psig to 685 psia. value. i Table 3.3-2 Add " steam generator pressure The asymmetric steam generator pressure trip 3/4 3-6 difference-high" response time. has been added to the Table. Table 4.3-1 Add " steam generator pressure The asymmetric steam generator pressure trip . 3/4 3-7 has been added to the Table. difference-high" surveillance, 3/4 3-12 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. 3 the Main 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 wi th the reactor trip setpoint. Hain Steam Line Isolation l function to 600 psia. 3.4.1 Replace the entire page. The shutdown margin requirement has been increased 3/44-1 to yield acceptable consequences for a Steam Line Break event during one-loop operation due to the more negative MTC permitted during Cycle 4. Modes 4 and 5 shutdown margin has been increased to 4.3%Ak/k. a I 11-14-80
TABLE I (continued) Page Speci fica tion Change Remarks 83/4 1-1 83/4.1.1.1 Change minimum Shutdown Margin The shutdown margins in t' t Bases have been B3/4.1.1.2 from 3.3%Ak/k to 4.3%ak/k, and increased to be consister) dith Spec'ifications from 1.0%ak/k to 2.0%Ak/k. 3.1.1.1 and 3.1.1.2. B3/4 1-1 D1/4.1.1.4 Change MTC to -2.5X10'4 ak/k/ Of . The most negative MTC permitted has .been changed in the Bases to be consistent the Specification 3.1.1.4. B3/4 1-2 83/4.1.1.4 Change shutdown margin to The shutdown margin has been increased in the 2.0%Ak/k af ter 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 Dt0R to 1.23. The minimum DNBR has been decreased to be i consistent with Specification 82.1. 83/4 4-1 B3/4.4.1 Change mirimum DNBR to 1.23. Spine remarks as for preceding entry. 83/4 7-1 B3/4.7.1.1 Steam flows are revised to B3/4 7-2 reflect '2700 Mwt. 11-14-80 e -- O-- 9 9 8
O 1.0 DEFINITIONS .. DEFINED TERMS 1.1 The DEF.INED TERMS of this section appear in capitalized type and are applicable throughout these Technical Specifications. THERMAL POWER f) 1.2 THERMAL POWER shall be the total reactor core heat transfer rate to the v 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 spe :ified in Table 1.1. art.ON 1.5 ACTION shall be those additional requirements specified as corr.lary
,! 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, electric power, cooling or seal water, lubrication or other auxiliary equipment that are required for the system, w subsystem, train, component or device to perfonn 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.l.9. O b ST. LUCIE - UNIT 1 1-1 11-14-80
600. e g 580. --- UNACCEPTABLE OPERATION H ,
- REACTOR OPERATION LIMITED TO LESS
' TilAN 500 F BY ACTUATION OF Tile MCCMABLE .
MAIN STEAM LINE SAFETY VALVES. OPERATION y 560.. VESSEL FLOW LESS MEASUREMENT l a UNCERTAINTIES - 370,000 CPM l
- 4 i
FOR PRE-CLAD COLLAPSE l 6 W l #o OPERATION ONLY p"o
' g LIMITS CONTAIN NO ALLOWANCE O o
h FOR INSTRUMEffl' ERROR OR FLUCTUATIONS ! b N E4 VALID FOR AXIAL SilAPES AND l b o 520 . INTEGRATED ROD RADIAL PEAKING les N FACTORS LESS TIIAN OR EQUAL TO 3 Til0SE ON FIGURE B 2.1-1
.ll*om l
8 g500 . kC ACCEPTAb!.E 4 OPERATION lh h My N g, $ E
% a ia 480 l $o lr<
lh r* b IE! r C 460 - L 0 0.20 0.40 0.60 0.80 1.00 1.20 1.40 1.60
? 1.80 2.00 8 FRACTION OF RATED TilERMAL POWER Fi. jure 2.1-1 REACTOR CORE TilERMAL MARCIN SAFETY LIMIT - FOUR REACTOR COOLING PUMPS OPERATING e -
G G G G
.____ __ _ _ _ _ - . _ . - _ _ . ~_ - -
O O O O O TABLE 2.2-1 m R_EACTOR PROTECTIVE INSTRlTMENTATITN TRIP SET POINT LIMITS
?
,_ FUNCTIONAL UNIT TRIP SET POINT ALLOWAB'E L VALUES E
;;; 1. Manual Reactor Trip Not Applicable Not Applicable h 2. Power Level - : ;h (1) i'i H
7' " Four Reactor Coolant Pumps ~< 9.61% above THERMAL POWER, < 9.61% above THERMAL POWER, Operating 1th 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 -< 107.0% of RATED THERMAL POWER THERMAL POWYR.
- 3. Reactor Coolant. Flow -
Low (1) m Four Reactor Coolant Pumps > 95% of design reactor coolant 195% of design reactor coolant i Operating Tlow with 4 pumps operating
- flow with 4 pumps operating *
- 4. Pressurizer Pressure-High f 2400 psia f 2400 psia
- 5. Containment Pressure-High f 3.3 psig < 3.3 psig
- 6. Steam Generator Pressure - > 600 psia 1 600 psia low (2) -
- 7. Steam Generator Water Level- 137.0% Water Levei .- each 137.0% Water Level - each steam Low ste5m generator generator
- 8. Local Power Density - High Trip setpcint adjusted to not Trip setpoint adjusted to not
=' (3) exceed the limit lines of exgeed the limit lines of
,. Figures 2.2-1 and 2.2-2 Figures 2.2-1 and 2.2-2.
~-
- Design reactor cooTant flow with 4 pumps operating is 370,000 gpm.
TABLE 2.2-1(CONTINUED) REACTOR PROTECTIVE INSTRUMENTATION TRIP S2T/0!NT LIMITS ,A FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES E 9. Thermal Margin / Low h Pressure (1) $ Four Reactor Coolant Pumps Trip setpoint adjusted to not Trip setpoint adjusted to not -4 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 i 135 psid i 135 psid Difference-liigh (1) (Logic in TM/LP)
- 10. Loss of Turbine--Ilydraulic > 800 psig > 800 psig Fluid Pressure - Low (3) m 11. Rate of Change of Power - < 2.49 decades per minutes f 2.49 decades per minuts in liigh (4)
TABLE NOTATION (1) Trio may be bypassed below 1% of RATED TilERMAL POWER; bypass shall be automatically renoved when TilERMAL POWER is > 1% of RATED TilERMAL POWLR. (2) Trip may be manually bypassed below 685 psia; bypass shall be automatically renoved at or above 685 psia. (3) Trip may be bypassed below 15% of RATED THERMAL POWER; bypass shall be automatically renoved when TilERMAL POWER is )_15% of RATED TilERMAL POWER. g (4) Trip may be bypassed below 10-4% and above 15% of RATED TilERMAL POWER. s e G O G . 9
I i O . l l i t i 1,4 - 'i i
- 1. 2<
UNACCEPTABLE (0.0, 1.17) UNACCEPTABLE OPERATION OPERATION O i 1.0 . ( .145, 1.0) (0.2, 1.0) i
- 0. 8..
QR2 (-0.4, 0.70) (0.4,0.70) l 0. 6-- i ACCEPTABLE OPERATION
- 0. 4 -
0.2- - 0.0
-0.6 -0.4 -0.2 0.0 0.2 0.4 0.6 i AXIAL SHAPE INDEX, Y1 FIGURE 2.2-2 l
Local Power Density-High Trip Setpoint Part 2(QR Versus Y 1) l 2 I 1 l ST. LUCIE - UNIT 1 2-7 11-14-80 l O
\
~ i
1.5 .Al FUNCTION PVAR = 2061
- Al - QR1 + 15.85 TIN - 8950 1.4 -
1.3 - 0
- 1. 2 '
l.1 - 0 1.0 .
-0.6 -0.5 -0.4 -0.3 -0.2 -0.1 0.0 j 0.1 0.2 0.3 0.4 0.5 0.6 AXIAL SHAPE INDEX, Y1 FICURE 2.2-3 Thermal Margin / Low Pressure Trip Setpoint I
\ - ST. LUCIE - UNIT 1 2-8 11-14-80
O ! PVAR = 2061 Al - QR1 + 15,85 TIN - 8950 QR1 FUNCTION-O 1.0 (.972,.972) ( . 781, . 86. O.8 ' QR y 0.6 0.4< 0.2-O o 0 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 i Part 2 (Fraction of RATED THERMAL POWER Versus QR1) l O ST. LUCIE - UNIT 1 2-9 11-14-80
l l 2.1 SAFETY LIMITS BASES 2.1.1 REACTOR CORR The restrictions of this safety limit prevent overheating of the fuel cladding and possible cladding perforation which would result in the release of fission preducts 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 co:fficient. DNB is not a directly measurable parameter during operation and th:refore THERMAL POWER and Reactor Coolant Temperature and Pressure have been rolated to DNB through the CE-l correlation. The CE-1 DNB correlation has be:n developed to predict the DNB flux and the location of DNB for axially l unifom and non-unifom 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 DUBR during steady state operation, normal operational transients, and anticipated transients is limited to 1.23. This 44 l value corresponds to a 95 percent prcbability at a 95 percent confidence level that DNB will not occur and is cho:en 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 Reactor 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 l 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 deshed 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. l ST. tuCre - cNiT 1 B 2-1 n-14-80 g i
--e=-e--
- m
D SAFETY LIMITS (O BASES The conditions for the Thennal 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 prevent any anticipated combination of transient conditions for reactor coolant system temperature, pressure, and thennal power level that would result in a DNBR of less than 1.23 and preclude the existence l of flow instabilities. (v] 2.1.2 REACTOR COOLANT SYSTEM PRESSURE The restriction 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 reactor 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 110% (2750 psia) of design pressure. The Reactor j Coolant System piping, valves and fittings, are designed to ANSI B 31.7, Class (D I which pennits a maximum transient pressure of 110% (2750 psia) of conponent 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 hydrotested at 3125 psia to demonstrate integrity prior to initial operation.
,a i :
V l /"; ST. LUCIE - UNIT 1 B 2-3 11-14-80 1\ ) s .- l
2.2 LIMITING _ SAFETY, SYSTEM SETTINGS, BASES 2.2.1 REACTOR TRIP SETP0INTS 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 Trip The Manual Reactor Trip is a redundant channel to the automatic protective instrumentation channels and provides manual reactor trip capability. Power Level-High 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 Thennal 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 trip 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 15% of RATED THERMAL POWER. Adding to this maximum value the possible variation in trip point due to ::alibration and instrument errors, the maximum actual THERMAL POWER level at which a trip would be actuated is 112% 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 prevent DNB in the event of a sudden significant decrease in reactor coolant flow. Provisions have been made in the reactor protective system to pennit operation of the reactor at reduced power if one or two ST. LUCIE - UNIT 1 B 2-4 11-14-80 9
~.
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 Values 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 nomal operation and l expected transients. For reactor operation with only two or three reactor coolant pumps operating, the Reactor Coolant Flow-Low trip setpoints, the O v Power Level-High trip setpoints, and the Thermal Margia/ 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 setroints during two and three pump operation prevents the minimum value of DNBR from going below 1.23 during nomal operational transients and l anticipated transients when:only two or three reactor coolant pumps are operating. Pressurizer Pressure- Hip 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 i. 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 pressurizer code safety valves and its concurrent operation with the power-operated relief valves avoids the undesirable operation of the cressurizer code safety valves. Containment Pressure- High The Containment Pressure-High trip provides assurance that a reactor trip in initiated concurrently with a safety injection. Steam Generato_r_P_res_sure - Low The Steam Generator Pressure-Low trip provides protection against an excessive rate of heat extraction from the steam generators and subsequent O v cooldown of the reactor coolant. The setting of 600 psia is sufficiently below the full-load operating point of 800 psig so as not l l (J ST. lac 1E . oH11 1 e 2.s 11 14 80 l t
O ' LIMITING SAFETY _ SYST_EM_ SETTINGS BASES Themal Margin / Low P_ressure The Thermal Margin / Low Pressure trip is provided to prevent operation when the DNBR is less than 1.23. l The trip is initiated whenever the reactor coolant system pressure signal drops below either 1887 psia or a computed value as described below, whichever l is higher. The computed value is a function of the higher of AT power or n;utron power, reactor inlet temperature, the number of reactor coolant pumps operating and the AXIAL SHAPE INDEX. 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 sssociated with providing effective temination of the occurrence that exhibits the most rapid decrease in margin to the DNBR 1imit. Asymmetric Steam Generator Transient Protective Trio Function (ASGTPTF) 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 dicount 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 0
i (3 v ' LIMITING _SM ETY SYSTEM SET _ TINGS BASES Loss of Turbine A Loss of Turbine trip causes a direct reactor trip when operating above 15% of RATED THERMAL POWER. 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 Chan_qe_af _P_o_we_r-jii_gh The Rate of Change of Power-High trip is provided to protect the core during startu'p operations and its use serves as a backup to the administrative 1y enforced startLp rate limit. Its trip setpoint does not correspond to a Safety Limit and no credit was taken in the accident analyses O for operation of this trip. Its functional capability at the specified trip setting is required to enhance the overall relis aility of the Reactor Protection System. O ST. LUCIE - UNIT 1 B 2-8 11-14-80
~
l l 1 3/4.1 REACTIVITY CONTROL SYSTEMS 3/4.1.1 B0 RATION CONTROL SHUTDOWN MARGIN - TAVG >200 F LIMITING CONDITION FOR OPERATION 3.1.1.1 The SHUTDOWN MARGIN shall bel 4.3% Ak/k. APPLICABLITY: MODES 1, 2, 3, and 4. .cTION: With the SHUTDOWN MARGIN < i.3% A k/k, immediately initiate and continue boration at > 40 gpm of 1720 ppm boron or equivalent until the required SHUTDOWN MARGIN is restored. SURVEILLANCE REQUIREMENTS 4.1.1.1.1 The SHUTDOWN MARGIN shall be detennined to be > 4.3% A k/k: l
- a. Within one hour after detection of an inoperable CEA(s) and at least once per 12 hours 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 hours 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. Pr or to initial operation above 5% RATED THERMAL POWER af ter each fuel loadirig. by consideration of the factors of e below, with the CEA groups at the Power Dependent Insertion Limits of Specification 3.1.3.6.
o See Special Test Exception J.10.1. O With Keffl 1. 0.
- With Keff < l.0 ST. LUCIE - UNIT 1 3/4 1-1 11-14-80
d r
'N .
REACTIVITY CONTROL SYSTEMS SHUTDOWN MARGIN - Tavg;[2.0% ak/k. LIMITING CONDITION FOR OPERATION 3.1.1.2 The SHUTDOWN MARGIN shall be 2; 2.0% ak/k. APPLICABILITY: MODE 5. With the SHUTDOWN MARGIN < 2.0% ak/k, in. mediately initiate and continue
. boration at > 40 gpm of 1720 ppm boron or equivalent until the required SHUTD0WN MARGIN is restored.
SURVEILLANCE REQUIREMENTS 4.1.1.2 The SHUTDOWN MARGIN shall be detennined to be JL 2.0% ak/k:
- a. Within one hour afer detection of an inoperable CEA(s) and at least once per 12 hours 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 hours by consideration of the following factors:
- 1. Reactor coolant system boron concentration,
- 2. CEA pusition,
- 3. Reactor coolant system average temperature, .
f)
\_ - 4. Fuel burnup based on gross thermal energy generation,
- 5. Xenon concentration, and
- 6. Samarium concentration.
L ST. LUCIE - UNIT 1 3/4 1-3 11-14-80 [) A -
REACTIV_ITY 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 10-4 Ak/k/ F whenever THERMAL POWER is
< 70% of RATED THERMAL POWER,
- b. Less positive than 0.2 x 10-4 a k/k/ F whenever THERMAL POWER is > 70% of RATED THERMAL POWER, and
- c. Less negative than -2.5 x 10-4 Ak/k/ F at RATED THERMAL POWER.
APPLIC ABILITY: MODES 1 and 2*# ACTION: With the coderator temperature coefficient outside any one of the above O limits, be in H0T STANDBY within 6 hours. SURVEILLANCE REQUIREMENTS 4.1.1.4.1 TheMTc MTC shall be detennined to-be within its limits by confirmatory measurements. measured values shall be extrapolated and/or compensated to permit direct comparison with the above limits. CWith Keff > 1.0.
- See Special Test Exception 3.10.2 1
ST. LUCIE - UNIT 1 3/4 1-5 11-14-80 l l
(v REACTIVIlT gNTROL. SYSTEMS FLOW PATHS - OPERATING LIMITING CONDITION FOR OPERATION S.1.2.2 At least two of the following three baron 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 charging 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 flow paths to the Reactor Coolant System to OPERABLE status within 72 hours or make the Os reactor subcritical within the next 2 hours and borate to a SHUTDOWN MARGIN equivalent to at least 2% ak/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 hours. SURVEILLANCE REQUIREMENTS 3 _ _ _ _ _ 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 1 3/4 1-10 11-14-80 i
~
REACTIVITY CONTROL SYSTEMS B0 RATED 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 Figuia 3.1-1, and
- b. The refueling water tank with:
1- A minimum contained volume of 401,800 gallons of water, 2- A minimum baron concentration of 1720 ppm, 3- A minimum solution temperature 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 hours or make the reactor subcritical within the next 2 hours and borate to a SHUTOOWN MARGIN equivalent to at least 2% Ak/k at 200 F; restore at least two borated water sources to l OPERABLE status wihin the next 7 days or be in COLD SHUTDOWN within the next 30 hours. SURVEILLANCE REQUIERMENTS 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 baron concent.ation in each water source.
ST. LUCIE - UNIT 1 3/4 1-18 11-14-80
O O O O O l l l 1.00 (14. 1.Oi U
- I g g 0.90 < g E N l 2 0.80 g
@ l 82, .70)
H 0.70 H s(68,.75)
- E I '
z g 0.60 < l O.50 POWER DEPENDENT INSERTION LIMIT LONG TERM l STEADY STATE g 0.40 INSERTION U l LIMIT u
! 3110RT TERM N N 1 STEADY STATE 0.20 I-- - - - - -
r 6 0.10 0 i GROUPS a a7a e a i a i 5 a e a a a a 3 a a 1 0 2? 55 82 109 137 0 27 55 82 109 137 0 27 55 82 109 137 e i a 6 a a a a a 4 a a n 0 27 55 82 109 137 0 27 55 82 109 137 C CEA INSERTION (INCllES)
$ Figure 3.1-2 CEA Insertion Limits vs TilERMAL POWER with 4 Reactor Coolant Pumps Operating
I I l l O'. 1 C 16.0 - UNACCEPTABLE OPERATION
'E b 2 5o s .
g db
- 15.0 15.0 e x 8
d+ b4 MU ACCEPTABLE OPERATION d+
"' a 14.0 -
U$
%b 8
d 13.0 BOL EOL CYCLE LIFE FIGURE 3.2-1 Allowable Peak Linear Heat Rate vs Burnup 9 l l O ST. LUCIE - UNIT 1 3/4 2-3 11-14-80 l l 1 I
~
l.2 .. 1.1 - id
> 1.0 .
$ REGION OF e UNACCEPTABLE g OPERATION O w w 0.9 Zij s
}< 0.8 -
(-0.05, 0.82) (0.15, 0.82) REGION OF E UNACCEPTABLE I OPERATION w 0.7 - o 5 O U
@ 0.6 A
(-0.3,0.58). REGION OF ACCEPTABLE OPERATION (0.3, 0.58) 0.5 < 0.4 w y F W w w
-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 l
l l l
. 1
1.10 , , , g i i g i I 1.08 - y134.7,1.p71_
- 106.5,1.063 f ' 118.6,1.067 a: -
$1.06 -
y
- 90.5, 1.057
'i
-
- 74.4, 1.050 -
Q 62.3, 1.045 w -
'f: g1.04
{ 5 46.2, 1.035 30.2, 1.025 1.02 -
*18.1, 1.017
- 2.0, 1.004 1.00 t t i I e I I t 0 14 28 42 56 70 84 98 112 125 140 DISTANCE FROM BOTTOM OF CORE, INCllES E
FICURE 4.2-1 h AUGMENTATION FACTORS vs DISTANCE FROM BOTTOM OF CORE O O O O O
. - - __ - ~_ -._
1 POWER DISTRIBUTION LIMITS TOTAL PLANAR RADIAL PEAKING FACTOR - FT xy i - LIMITING CONDITION FOR OPERATION 3.2.2 The calculathvalue F,T, defined as T F , = F (1+T q ), shall be limited
; to i 1. 70.
APPLICABILIT_Y1 MODE 1*. g ACTION: With FT >1.70, within 6 hours either: ' *1 ;
- a. Reducg THERMAL POWER to bring the cambination of THERMAL POWER to within the limits of Figure 3.2-3 and withdraw the and full F' le5gth CEAs to or beyond the Long Tenn Steady State 1 Insertion Limits of Specification 3.1.3.6, or I
i b. Be in HOT STAND 8Y. 1 i SURVEILLANCE REQUIREMENTS 4.2.2.1 The provisions of Specifications 4.0.4 are not applicable. 4.2.2.2 T T F, shall be calculated by the expression F , (1+T when in non-LOAD FOLLOW OPERATION and by the expression Fh = 1.03 i Fxy (1+T )qwhen in LOAD FOLLOW OPERATION. F shall be
- determined to be within its limit at the following intervals
! a. Prior to operation above 70 percent of RATED THERMAL POWER f after each fuel loading, i b. At least once per 31 days of accumulated operation in MODE 1, and l
- c. Within four hours if the AZIMUTHAL POWER TILT (T q ) is !
}
> 0.03. j !
t
- See Special Test Exception 3.10.2.
ST. LUICIE - UNIT 1 3/4 2-6 11-14-80 i 1 I ' l .__._. ,-1
d r* E! N
' 1.1 E
4 cx: 1.0
. , 1.0) UNACCEPTABLE OPERATION REGION 1
M H O ~ (1.78,0.9) s N 5 8
~ z i S 0.8 -
ACCEPTABLE OPERATION REGION N h 0.7 s
- s o.6 . . . . . . .
r. T 1.70 1.71 1.72 1.73 1.74 1.75 1.76 1.77 1.78 E Measured F7 , F T T 4 o FIGURE 3.2-8 AllowableCombinationsOfThermalPowerAndF$,F xy O O O O _ O
POWER DISTRIBUTION LIMITS
,- s ,OTAL INTEGRATED RADIAL PEAKING FACTOR - FT r
(
'\_ f
)
LIMITING CONDIYION FOR OPERATION __ 3.2.3 The calculated value of TF , defined as pFT,y , (1+T ), shall be q 1imited to 11.70. APPLICABILITY: MODE 1*. (~'i, ACTION:
'w) With FT > 1.70, within 6 hours either:
- a. Be in at least HOT STANDBY, or
- b. Reducg THERMAL POWER to bring the combination of THERMAL POWER and F' to within the limits of Figure 3.2-3 and withdraw the full length CEAs to or beyond the Long Tem Steady State Insertion Limits of Specification 3.1.3.6. The THERMAL POWER limit detemined 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 detemined by Figure 3.2-3) and subsequent L/ operation shall be maintained within the reduced accceptable operation of Figure 3.2-4. SURVEILLANCE REQUIREMENTS 4.2.3.1 The provisions of Specification 4.0.4 are not applicable. 4.2.3.7 FT p shall be calculated by the axpression FT=F p (1+T ) when in non-LOAD FOLLOW OPERATION and by the expression p FT = 1.02 F (1+T ) when in LOAD F0LLOW OPERATION. FT shall be detemined to be within kJ 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 q(T ) is > 0.03.
*See Special Test Exception 3.10.2.
(, 'N ST. LUCIE - UNIT 1 3/4 2-9 11-14-80
l 1
)
O Tndt.E 3.2d DNB MARGIN LIMITS Four Reactor Coolant Pumps Parameter Operating Cold leg Temperature < 549*F Pressurizer Pressure > 2225 psia
- Reactor Coolant Flow Rate > 370,000 gpm AXIAL SHAPE INDEX Figure 3.2-4 o Limit not applicable during either a THERMAL POWER ramp increase in excess of 5% of RATED THERMAL POWER or a THERMAL POWER step increase of greater than 10% of RATED THERMAL . WER.
O 1 ST. LUCIE - UNIT 1 3/4 2-14 11-14-80 01
1.1 O 1.0 . (-0.08,1.00) (0.15, 1.00) UNACCEPTABLE UNACCEPTABLE OPERATION OPERATION REGION REGION g 0.9 . 5 ' 2 a 0.8 - 5 g ACCEPTABLE i s OPERATION
$ 0.7 (-0.3, 0.70) REGION (0.3, 0.70) 8 s:
U g 0.6 . a. 1 0.5 - 0.4
~
-0.4 -0.4 -0.2 d.0 0 .'2 0.4 0.6 PERIPHERAL AXIAL SHAPE INDEX (Y1 )
FIGURE 3.2-4 AXIAL SHAPE INDEX Operating Limits With 4 Reactor Coolant Pumps Operating i ST. LUCIE - UNIT 1 3/4 2-15 11-14-80 0
. ')
h
, - - - _ , -- , --- ---w- - - ~ -
,U TABLE 3.3d E < TACTOR PROTECTIVE INSTRUMENTATION m
c MINIMUM 5 H TOTAL NO. CHANNELS CHANNELS APPLICABLE FUNCTIONAL UNIT OF CHANNELS TO TRIP
- OPERABLE MODES ACTION
- 1. Manual Reactor Trip 2 1 2 1, 2 and
- 1
- 2. Power Level - High 4 1, 2 2(a) 3(f) 2#
- 3. Reactor Coolant F :ow - Low 4/SG 2(a)/SG 3/SG 1, 2 (e) 21
- 4. Pressurizer Pressure - High 4 2 3 1, 2 2#
w 5. Containment Pressure - liigh 4 2 3 1, 2 2 2# w 6. Steam Generator Pressure - Low 4/SG 2(b)/SG 3/SG 1, 2 2#
- 7. Steam Generator Water Level - Low 4/SG 2/SG 3/SG 1, 2 2#
- 8. Local Power Density - High 4 2(c) 3 1 2#
- 9. Thermal Margin / Low Pressure 4 2(a) 3 1, 2 (e) 2#
9a.Stean Generator Pressure Difference
-High 4 2(a) 3 1, 2 (e) 2# = 10. Loss of Turbine- -Ilydraulic Fluid Pressure - Low 4 2(c)' 3 $ 1 2#
e _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ e 9 9 9 _ _ _ . _ _ _ _
l 1 l i O TABLE 3.3-1 (CONTIWUED) - 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 1% of RATED THERMAL POWER, bypass shall be automatically removed when THERMAL POWER is 11% 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 15% of RATED THERMAL POWER; bypass shall be automatically removed when THERMAL POWER IS 115% of RATED THERMAL POWER. (d) Trip may be bypassed below 10-4% and above 15% of RATED THERMAL P bypass shall be automatically removed when THERMAL power is%>or10~gWER; < 15% cf RATED THERMAL POWER. 4 (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. A_CTION 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 hours or be in HOT STANDBY within the next 6 hours and/or open the protective system trip breakers. c, ACTION 2 - With the number of OPERABLE channels one less than the l] 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 i,ithin 1 hour. For the purposes of testing and maintenance, the inoperable channel may be bypassed for up co 48 hours from time of initial loss of OPERABILI;Y, however, the inoperable channel shall then be e'cher restored to OPERABLE status or placed in the cripped condition.
ST. LUCIE - UNIT 1 3/4 3-4 11-14-80
~.
"I TABLE 3.3-2 5 REACTOR PROTECTIVE INSTRUtENTATION RESPONSE TIMES [ FUNCTIONAL UNIT RESPONSE TIME 5 H 1. Manual Rr,ctor Trip Not Applicable
- 2. Power Level - liigh < 0.40 seconds *f and < 8.0 seconds ##
- 3. Reactor Coolant Flow - Low f 0.65 seconds
- 4. Pressurizer Pressure - High I 0.90 seconds
- 5. Containment Pressure - liigh 1 1.40 seconds
- 6. Steam Generator Pressure - Low f 0.90 seconds
- 7. Steam Generator Water Level - Low f 0.90 seconds g 8. Local Power Density - High < 0.40 seconds *# and < 8.0 seconds ##
w 9. Thennal Margin / Low Pressure < 0.90 seconds *# and < 8.0 secondsff 9a. Steam Generator Pressure Difference - liigh 1 0.90 seconds l
- 10. Loss of Turbine- -Hydraulic Fluid Pressure - Low Not Applicable
- 11. Wide Range Logarithmic Neutron Flux Monitor Not Applicable Neutroa detectors are exempt from response time testing. Response time shall be measured from detector output or input of first electronic component in channel.
C k # Response time does not include contribution of RTDs. b
## RTD resporse ; ime only. This value is equivalent to the time interval required for the RTDs output to achieve 63.2% of its total change when subjected to a step change in RTD temperature.
O O O 'O _ O
TABLE 4.3-1 REACTOR PROTECTIVE INSTRUMENTATION SURVEILLANCE REQUIREMENTS w (
. CHANNEL MODES IN WHICH r- CllANNEL CHANNEL FUNCTIONAL SURVEILLANCE o FUNC_TIONAL, UNIT CHECK CALIBRATION TEST REQUIRED g 1. Manual Reactor Trip N. A. N. A. S/U(1) N.A.
- 2. Power Level - High
- a. Nuclear Power S D(2),M(3),Q(5) M 1, 2 B. A T Power S D(4),Q M 1
- 3. Reactor Coolant Flow - Low 'S R M 1, 2
- 4. Pressurizer Pressure - liigh S R M 1, 2
- 5. Containnent Pressure - High S R M 1, 2
$ 6. Steam Generator Pressure - Low S R M 1, 2 w
a 7. Steam Generator Water Level - Low S R M 1, 2
- 8. Local Power Density - liigh S R M 1
- 9. Thermal Margin / Low Pressure S R M 1, 2 9a. Steam Generator Pressure Difference - liigh S R .. M 1, 2
- 10. Loss of Turbine--Hydraulic Fluid Pressure - Low r.. A . N.A. S/U(1) N.A.
1
~ 11. Wide Range Logarithmic Neutron y Flux Monitor S N.A. S/U(1) 1, 2, 3, 4, 5 and
- g 12. Reactor Protection System Logic N.A. N. A. M and S/U(1) 1, 2 and
- I 13. Reactor Trip Breakers N.A. N.A. M 1, 2 and * ,
DBLE3.3.-3(CONTINUED) TABLE NOTATION , (a) Trip function may be bypassed in this MODE when pressurizer pressure is
<l725 psia; bypass shall be automatically removed when pressurizer pressure is > 1725 psia.
(b) An SIAS signal is first necer vy to enable CSAS logic. (c) Trip function may be bypassed , 'iis MODE below 685 psia; bypass shall be automatically removed at or above 685 psia.
- The provisions of Specification 3.0.4are not applicaole.
- ACTION STATEMENTS ACTION 8 - With the number of OPERABLE channels one less than the Total Number of Chann'els, restore the inoperable channel to OPERABLE status within 48 hours or be in at least H0T STANDBY within the next 6 hours and in COLD SHUTDOWN within the following 30 hours.
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 hour. For the purposes of testing and maintenance, the inoperable channel may be bypassed for up to 48 hours 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 channal may be bypassed for up to 48 hours while perfonning tests and maintenance on that channel provided the other inoperable channel is placed in the tripped condition.
ST. LUCIE - UNIT 1 3/4 3-12 11-14-80 1
, O O O O O , t
- m TABLE 3.3-4
- Y ENGINEERED SAFETY FEATURE ACTUATION SYSTEM INSTRUMENTATION TRIP VALUES h ~ FUNCTIONAL UNIT TRIP SETPOINT ALLOWABLE VALUES
- 1. SAFETY INJECTION (SIAS)
- a. Manual (Trip Buttons) Not Applicable Not Applicable
- b. Containment Pressure - High 1 5 psig I 5 psig
- c. Pressurizer Pressure - Low > 1600 psia J_ 1600 psia
- 2. CONTAINMENT SPRAY (CSAS) ;
- a. Manual (Trip Buttons) Not A,iplicable Not Applicable
- b. Containment Pressure -- liigh - High 1 10 psig i 10 psig g 3. CONTAINMENT ISOLATION (CIS) 1 w a. Manual (Trip Buttons) Not Applicable iot Applicable i b. Containment Pressure - liigh I 5 psig n 5 psig
- c. Containment Radiation - liigh < 10 R/hr C 10 R/hr r
i 4. MAIN STEAM LINE ISOLATION (MSIS) l
- a. Manual (Trip Buttons) Not Applicable Not Applicable N Steam Generator Pressure - Low g 600 psia J_ 600 psia l
- 5. CONTAINMENT SUMP RECIRCULATION (RAS)
- a. Manual RAS (Trip Buttons) Not Applicable Not Applicable
= b. Refueling Water Tank - Low 48 inches above 48 inches above
,L tank, bottom tank bottom
?
i 8 1
3/4.4 REACTOR COOLANT SYSTEM REACTOR COOLANT LOOPS LIMITING CONDITION FOR OPERATION 's . 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 h STANDBY within 6 hours. MODE 3 Op ration may proct.ad 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 reactc 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% a 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 REQUIREMENTS 4.4.1 Tne Flow Dependent Selectcr Switch shall be detennined to be in the 4 pump position within 15 minutes prior to making the reactor critical ,.nd at 1ast once per 12 hours thereafter.
# All reactor coolant pumps and shutdown cooling pumps may be de-energized for up to 1 hour, 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 [v] BASES _ 3/4. 1 .1 B0 RATION CONTROL 3/4. 1 .1. I and 3/4_1_._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
[V 1 subcritical to preclude inadvertent criticality in the shutdown condition. IndiDOWN MARGIN requirements vary throughout core life as a function of fuel depletion, RCS boron concentration, and RCS T a The most restrictive condition occurs at E0L, with T at no load operaNn.g temperature, and is associated with a postulated sten line break accident and resulting uncontrolled RCS cooldown. In the analysis of this accident a minimum SHUTDOWN MARGIN of 4.3% Ak/k is required to control the rea tivity 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 T av < 200 F, the reactivity transients resulting from o any postulated accident arS iiinimal and a 2% Ak/k shutdown margin provides l V adequate protection. 3/4. 1. 1. 3_ BOR,0_N DILUTION AND ADDITION A minimum flow rate of at least 2000 GPM provides adequate mixing, prevents stratification and ensures that reactivity changes will be gradual during baron 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) V The limiting values assumed fog the MTC used in the accident and transient analyses were + 0.5 x ak/k/*F for THERMAL POWER levels < 70% of RATEDTHERMALPOWER,+0.2x10-}0-Ak/k/ F for THERMAL POWER levels > 70% of RATED THERMAL POWER and - 2.5 x 10-4 ok/k/ F at RATED THERMAL POWER. Therefore, these limiting values are included in this specification. Detennination of MTC at the specified conditions ensures that the maximum positive and/or negative values of the MTC will not exceed the limiting val ues. / \ b ST. LUCIE - UNIT 1 B 3/4 1-1 11-14-80
REACTIVITY CONTROL SYSTEMS BASES h 3/4.1.1.5 MINIMUM TEMPERATURE FOR CRITICALITY The MTC is expected to be slightly negative at operating conditions. H: wever, 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 T avg is significantly belnw the nonnal operating temperature. 3/4 1. 2 B0 RATION SYSTEMS The boron injection system ensures that negative reactivity control is available during each mode of facility operation. The components required to perfonn separatethis flow function paths 4include 1) borated water sources, 2) charging pumps, 3) and 6) an emergency, pow)er supply from OPERABLE diesel generators. boric a With the RCS average temperature above 200 F, a minimum of two separate and redmdant 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 companent 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 2.0% Ak/k after xenon decay and cooldown to 200*F. The maximum boration capability requirement occurs at l E0L from full power equilibrium xenon conditiens and requires 7,925 gallons of 8.0% boric acid solution from the boric acid tdnks or 13,700 gallons of 1720 ppm barated 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 CS to the desired level. The specified quantity of borated water is consistent with the ECCS requirements 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 1 B 3/4 1-2 11-14-80 , 9 h
POWER DISTRIBUTION LIMITS B. 'S used in the analysis establishing the DNB Margin LCO, and Thennal Margin / Low Pressure LSSS setpoints remain vaJid dping opergn g ag gous allowable bikaOS0n $haEion*by*conkikue#undeE the 3dditional 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, Thennal Margin / Low Pressure and Local Power Density - High LCOs and LSSS p setpoints remain valid. An AZIMUTHAL POWER TILT > 0.10 is not expected and if V 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 ,pxy (1 +T q) and xy F r *Ir (1+T q) is the measured tilt. T T The surveillance requirements for verifying that F xy, p r and Tq are T T within their limits provide assurance that the actual values of F xy, p r and Tq do not exceed the assumed values. Verifying F xy T and d p ah ead fuel loading prior to exceeding 75% 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 ma.intained 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 hour 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 hour basis. ST. LUCIE - UNIT 1 B 3/4'2-2 11-14-80 O
3/4.4 _ REACTOR.C.00LANT SYSTEM BASES 3/4.4.1 RbCTORC0bbNTLOOPS 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. l 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 l channel flow stability within the core ar.d 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 MODES 2 and 3; however, single failure considerations require plant cooldown if component repairs and/or corrective actions cannot be made within tne allowable out-of-service time. 3/4.4.2 and 3/4.4.3 SAFETY VALVES The pressurizer code safety valves operate to prevent the RCS from being O pressurized above its Safegy 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 conditic1 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 suf#icient 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 t Jrbine) 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
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l 3/4.7 PLANT _ SYSTEMS BASES 3/4.7.1 TURBINE CYCLE 3/4.7.1.1 SAlfTY VALVES The OPERABILITY of the main steam line code safety valves ensures that the secondary systr. pressure will be limited to within 110% of its design pressure during the most severe anticipated system operational transient. The i maximum relieving capacity is associated with a turbine trip from 100% RATED j p) 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 II. The to al relieving capacity for all 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 channel:. The reactor trip setpoint reductions are derived on the following basis: l For two loop operation SP = (X) - (Y) (V) x (106.5) where: SP = reduced reactor trip setpoint in percent of RATED THERMAL POWER V = maximum number of inoperable safety valves per steam line 1 ST. LUCIE - UNIT 1 B 3/4 7-1 11-14-80 'O l
~
PLANT SYSTE,M5 O BASES 106.5 = Power Level - High Trip Setpoint for two loop operation X = Total relieving capacity of all sagety valves per steam line in lbs/ hour (6.1 h : 10 l bs/hr. ) Y = Maximum relieving cagacity of any one safety valve in lbs/ hour (7.740 x 10 l bs/hr. ) [ 3/4.7.1.2 AUXILIARY FEEDWATER PUMPS The OPERABILITY of th'e auxiliary feedwater pumps ensures that the Reactor Coolant Systen 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 provida 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 The OPERABILITY of the condensate storage tank with the minimum water volume ensures that sufficient water is available for cooldown of the Reactor Coolant power. System to less than 325*F in the event of a total loss of off-site The minimum water volume is sufficient to maintain the RCS at HOT STANDBY conditions for 9 hours 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. G These values are consistent with the assumptions used in the accident T analyses. ST LUCIE UNIT 1 B 3/4 7-2 11-14-80
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f l i i ATTACHMENT 3 l l Re: St. Lucie Unit 1 i l i Docket No. 50-335 Stretch Power i l i SAFETY EVALUATION l J 1 i i
1 J .i i ,
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- l s.
l Oesign and Safety Report , t
- for j St. Lucie Unit 1 Cycle 4 at 2700 MWt g
i. l l i l 4 1 . I i l O . G l 1 j i i 1 1 I O I v f 4
i iOe Table of Contents j Section Description 1 Introduction and Susmary i 2 Operating History of the Reference Cycle ! 3 General Description I
- 4 Fuel Design 5 Nuclear Design 6 Thennal-Hydraulic Design Gefs s S e e 1 6) 7 Transient Analysis
- (Ref. Section 7) i 8 ECCS Analysis (Ref. Section 8) 9 Reactor Protection System
- Asycnetric Steam ,
Generator Transient Protection System i ] O . i
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- - . ,. . _ , - - _ - - .-. Y.- . . . , . - , _ , . - . - , . - , , . -.. ., , _ . - . . . - - , . .
1
- 1. INTRODUCTION AND SU?HARY This report provides an evaluation' of the design and performance for the j
operation of St. Lucie-1 during its fourth fuel c'ycle at a full power, stretch rating of 2700 MWt; Cycles 1, 2 and 3 were at a full power rating of 2560 MWt. Other cha'nges evaluated are an increase in the full power inlet temperature to 549 F and the addition of an asymetric steam generator trip function. The core will consist of presently operating Batch C, O and E assembifes together with fresh Batch F assembifes. h System requirements have created a need for flexibility in the Cycle 3 burnup length ranging from 7250 to 8250 MWO/T. The Cycle 4 Icading pattern described in this report has been designed to acccc=cdate this range of shutdown points. In performing analyses of postulated accidents, determining limiting safety system settings and establishing limiting conditions for operations, value. of key parameters were chosen to assure that expected conditions are enveloped within the above Cycle 3 burnup range. ~ The sleeving of CM guide tubes caused by waar of the CEA fingers follows the same procedure as reported in Reference 1. For Cycle 4 operatio ', only sleeved assemblies will be placed under CEAs and all 38 Batch F assembifes will be sleeved. The evaluations of the reload core :haracteristics have been exanined with respect to the safety analyses describing Cycle 3 (Reference 2) hereafter referred to as the reference cycle. In all cases, it has been concluded that the revised analyses at 2700 MWt presented in this reporc concinue to show acceptable results. Where dictated by variations from the reference cycle, proposed modifications to the plant Technical Specifications are provided and are justified by the. analyses reported herein. O'
s - . I, g) r a b ./ - ' ( 2.0 OPERATING HISTORY OF THE REFERENCE CYCLE __ _ _ _ _ _ _ _ . __ Cycle 3 is the designated reference cycle for this report. St. Lucie Unit 1 operated during its third fuel cycle utilizing Batch B, C, D, and E fuel assemblies at er near a licensed core power level of 2560 MWt. Cycle 3 terminated on March 15, 1980 at 8:42 pm with a burnup of 6050.91 EFPH or 7730 MWD /T. The termination was within the range of burnups between 7250 and 8250 MWD /T anticipated for Cycle 3.
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- 3. GENERAL DESCRIPTION .
The* Cycle 4 core will consist of thei rumbers and types of assemblies from the various fuel batches as described in Table The ~3-1. primary i change to the core for Cyclo '4 is the' removal of the remaining 21 Satch B assemblies and 67 of the 68 Batch C assemblies. These assemblics l will be replaced by 40 Batch F (3.65 w/o enrichment) and 48 Batch F- (3.03 w "enrfctment) assemblies. The 48 Icw enrichment 8aten F* assemblies 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 in the reference cycle. The fuel management pattern developed for Cycle 4 allows for flexibility in Cycle 3 burnup length between 7250 and 8250 P10/T. The loarting pattern is shown in Figure 3-1. The Cycle 4 core loading sattern is 90 degrees rotationally sy.. metric. That is, if one cuadrant of the core were rotated 90 degrees into its neighborind cuadrant, each assembly wculd overlay a similar assembly. This similarity includes batch tyne, number of fuel rods, initial enrichment and beginning of cycle burnup distribution. Figure 3-2 shows the beginning of Cycle 4 assembly burnup distribution for a Cycle 3 burnup length of 7750 W.10/T. The initial enrichment of each assembly is also shown. O O
O O O O O \ ( p Table u-1 G St. Lucie Unit 1 Cycle 4 Core Loading ' 1:eginning of Cycle 4 - Batch Average Burnuti Initial NDU tiumber Initial-Shim - Total Assen:bly ilumber of Enricimient Desient, t ion (f0C 3 a of Loading Total Fuel Assemblies w/o U-235 77501510/T) Shims _ w/o D 4C Shims Rods C 2.82 1 24,800 0 --- 0 176 D 40 3.03 15,700 0 t 0 7,040 D* 20 2.73 - 17,700 0 --- 0 3,520 E 40 3.03 E* 6300 O a-. 0 . 7,040 28 2.73 0 9100 --- 0 4,928 f 40 3.65 0 0 --- 0 7,040 FC 4i1 3,03 0 12 3.03 576 7,872 217 . 576 37,616 t B _- _____ - __ e - _ ___________ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _
O F F F F F* E* D F E E* E E F* F F* D* F* D F* D* F E D* E D E D* E* F; E* F* D F* D F* D F* E D E D E D E* F E* E F* D* F* D i F* Ea F D F* D* E* D E* E* C h st. tucie F.igu re O Nuc! car Power Station CYCLE - 4 LOADING PA1itRN untno.1 3-1 1
iO XXXX BOC 4-BURNUP (MWD /T) Y.YY INITIAL ENRICHMENT, WT % 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 l - 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 2.73 3.03 3.03 3,03 2. 73 '. 2.73
- O
! 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 I 3.65 8,700 7,300 0.0 17,100 0.0 15,900 0.0 9,800 2.73 3.03 3.03 2.73 3.03 3.03 3.03 2.73 0.0 3.65
- 15,900 0. 0 18,300 9,800 15,800 9,700 9,800 24,8C0 L 3.03 3.03 2.73 2.73 3.03 2.73 2.73 2.82 f
i st. tuci. CYCLE 4 - ASSEMBLY AVERAGE BURNUP AND Figure j
""cfl ;[8t'd " 3 INITIAL ENRICHMENT JISTRIBUTION 3-2
4.0 FUEL DESIGH ~ '--- 1 1 4.1 Mechanical Oesign The fuel assembly ccmplement for Cycle 4 is gf'ven in Table 3-1. ' The mechanical design of the reload fuel assemblies, Batch F,is identi. cal to St. Lucie-1 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 g 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 a duration. Predicted times to cladding collapse fo' r the fuel batches that will be irradiated during Cycle 4 are given in Taole 4-1. - The. analyses utilized the CEPAN ccmputer code (Reference 3) and included as input censervative values of internal pressure, cladding dimensions, cladding tenperature and neutron flux. Table 4-1 Claddina Cc11aose information Calculated End of Cycle 4 Batch Predicted Time Goeration (EFPH) C to Collaese (EFPH) 33,608 0
>40,000 24,002 32,600 E
17,628 F 27,800 11,193
>27,000
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_,. , * $Df} h I 4.2 - Hardware Modifications to Niiigate Cuide Tuoe Wear l a" All Batch C, E, and F fuel assemblies installed in.CEA locations for Cycle 4 have stainless steel sleeves inctalled in the rJuide tubes in order to mitigata i tube wesr.
'A detailed discussion of the design of the sleeves and its effects on i
reactor operation is contained in Reference 4. 4.3 Thermal Design' 4 I Using tne FATE 5 mod..t (Reference 5). the thermal performance of the various
. types of fuel assemblies has been evaluated with respect to tneir Cycles 1
!' 2, and 3 burnups, procosed burnups curing Cycle 4, their respective fuel geometries, and expected flux levels during Cycle 4 The Batch E fuel has been deternined to be the limiting fuel batch with resoect to storec energy. Burnuo cacendent fuel performance calculations were used in ECCS fuel performance calculations performed in Section 3, ECCS Analysis. o L L 1.4 . Chemical Cesian The metallurgical requirements of tne fuel cladding and the fuel assembly structural members for the Batch F fuel have r.ot been changed from the original Cycles 1, 2, and 3 designs. The re fo re , the chem.ical or metallurgical performance of the Batch E fuel will be unchanged from that of the original core fuel and discussions i in tne FSAR, Reference 6, are still valid. ] a.5 Onerating Experience Fuel assamolies incorpora ting the same design features as tne St. Lucie Unit 1, Gat:h F fuel assemblies have had coeratinq 1 exceriences at Calvert Cliffs 1 and 2. Fort Calhoun 1, Millstone II and previous reload cycles for 5t. Lucie-1. The operating experience has i
) (v. -been successful with the imolecentation of stainless steel sleeves to l mitigate the CEA guide tube wear problem as discussed in Section a s2s
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D a Aw 5.0 NUC!. EAR DESIGN . 5.1 Physics Characteristics - 5.1.1 Full Management The Cycle 4 fuel management employs a mixed central region as describ in Section 3, Figure 3-1. The fresh Satch F is comprised of two sets of assemblies, each having a unique enrichment in order to minimize radial power peaking. There are 40 assemblies wi:h an enrichment of 3.55 wt". andassemoly. per 48 assemblies with an enrichment of 3.03 wt". U-235 and 12 poison s With this leading, the Cycle 4 burnup capacity for full gewer operation is expected to be between 14,300 MWD /T and 14,9CIMWO/T, depending on the final Cycle 3 termination point. The Cycle 4 core characteristics have been examined for Cycle 3 terminations between ~ 7250 and 3250 MWO/T and limiting values established The for :ne safety analyses. tion leading pa::ern (see Saction 3) is applicable to any Cycle 3 termina point between :ne stated extremes. physics enaracteristics including reactivity coefficients for Cycle 4 are listed in Table 5-1 along with the corresconding values frem :he reference cycle, please note that the values of parame ers actually employed in safety analyses are different than those disolayed in Table 5-1 ano are typically chosen to conservatively ecound predict d values wi:n ace:mmodation for appropriate uncertainties and allowances . Table 5-2 presents a summary of CEA shutdown worths allcwances for Cycle a y and reac:ivi: with a c:mparison to reference cycle data. Ta le 5-2 generally characteri:es the cnanges in reactivity tnat occur trip during a from full power with a corresponcing change in coreo the power state. parame:ers zero t [t is not intanced to recresen; any par-icular mli iti ng A00 or accident, althougn the quantity shewn as
- Required Shutdcwn resents :.u Margin" numerical value of the worth whicn is applied to the hot line break accident.
- ero po wer steam For the analysis of any specific accident or ACC ,
conservative or "most limiting" values are used. The power dependent
' insertion limit (F3IL) curve for Cycle 4 is shown in Figure 5-1 The CEA group identification remains the same as in the reference cycle. Tabl e 5-3 shows the reactivity worths of various CEA groups calculateo at full bp-power conditions for Cycle 4 and the reference. cycle.
5.1. 2 Power Distribution Figt.res 5-2 through 5-4 illustrate the all rods out (ARO) planar radial power distributions at BOC 4, MCC 4 and EOC 4 that are characteri: tic 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 ccre length between about 20 and 80 percent of the fuel height. The higner burnup end of the Cycle 3 shutdswn window tends to increase the power peaking in this central region of the core, p Figure 5-5 illustrates the clanar radial cower distribution within the O b.. upper 15 to 20 percent.of the core produced with the insertion of the first CEA regulating group, Bank 7. This power distribution, calculated at 500 %0/T ,is casea upon ene low ournup end of the Cycle 3 shutdown window, providi;.g an illustration of maximum power peaking exoected for this configuration. Higher burnup Cycle 3 shutdown points tend to reduce power peaking in this upper region of the core with Bank 7 inserted. It is a characteristic of both ARO and Bank 7 inserted conditions that the Cycle 4 peaks are highest near BOC. ON The r,adial power distributions described in this section are calculated i data without uncertainties or other allowances. However, single rod power peaking values do include the increased peaking that is characteristic of fuel rods adjoining the water holes in the fuel assembly lattice. For both ONB and kw/ft safety and setooint analyses in either redded or unrodded configurations, the power peaking values actually used are higher than those expected to occur at any time during , p - 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 O conditions for operation"of the axial shape index (ASI). Within these ASI limits, the necessary DilBR acd kw/ft margins are maintained for a wide range of possible axial shapes. The maxicum three-dimensional or total peaking factor anticipated in Cycle 4 during normal base load, all rods out operation at full power is 1.55.not including uncertainty allowances and augmentation factors. O 5.1.3 Safety Related Data ' 5.1.3.1 E,jected CEA The maximum reactivity werths and planar radial power peaks associated with 2 ejected CEA event are shown in Table 5-4 for Cycle 4 and the referine.e cycle. The Cvele 4 values encompass the worst conditions anticicated durine Cycle 4 and are safety ar= lysis values, which are ! O corservative wi:n rescect to :ae ^ctu>t => cu aced v ues- O 5.1.3.2 Oropped CEA ' The limiting parameters of dropped CEA reactivity wceth and maximum increase in radial peaking factor are shown in Table 5-5 for Cycle 4 and the reference evcl e. 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 O Scran reactivities are calculated using the space-time kinetics code FIESTA described in Reference 13.
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( 5.1.4 Augmentation Factors Augmentation factors have been cal'culated for the Cycle 4 core using the calculational model described in Reference 5. The input information required for the calculation of augmentation factors that is specific to the core under consideration includes () the fuel densification characteristics, the radial pin power distr 1bution and the single gap peaking factors. Augmenta tion factors for the Cycle.4 core have been conservatively calculated by combining for input the largest single gap peaking factors with the most conservative (flattest) radial pin power distribu-tion. The calculations yield non-collapsed clad augmentation factor, showing a maximum value of 1.048 at the top of the core . The calculated values were increased to create conservative aug tion factors to be used in the i'n-core monitoring system The O C; augmentation factors used for Cycle 4 are compared to those of the reference cycle in Table 5-6. OC
5.2 PHYSICS AilALYSIS METH005 O
- 5. 2.1 S Uncertainties in Measurec Pcwer Distributions The pcwer districution measure.een; uncer:aincies which are appliec to Cycle 4 are:
Fq
- 7.0 percent where Fq = Fxy XgF , lccal ecwer density Fr =
5.0 percent " C- . h inese values are :o be used f:r :.cnitoring ?cwer distri:utio n parameters during operation. 5.20 2 tiuclear Design Me:Pocology The analyses have been erformed in the same manner anc aith tne same methcdologies used for the reference cycle analyses exceo: for the use of FIE3TA (Reference 13) . i M O
TABLE 5-1 St. Lucie Unit 1 Cycle 4 Physics Characteristics o
- Units Re erence Cycle 4 Dissolved Bor m ', .
Cycle Dissolved Bar on Content for Criticality, cIAs Nithdrawn Hot full power, equilibrium PPM 850 xenon, BOC 1077 Boron Worth Hot Full Power 80C PPM /%ao. 90 104
Hot Full Power EOC PPM /%4o 80 83 i
Reactivity Coefficients (CEAs Withdrawn) , Moderator Temcerature Coeffi-cients, Hot Full Power Beginning of Cycle O{) (Equilibrium Xe) End of Cycle 10-4 ao/*F -0.2 0.0 10-4 ao/*F -1.8 -2.06 Docoler Coefficienc Hot 80C Zero Power 10-5 ao/*F -1.44 -1.64 Hot 30C Full Power 10-5 ao/*F -1.13 -1.25 Hot ECC Full Pcwer 10-5 aa/aF .l.22 -l.39 1 Total Delayed Neutron Fraction, 3eff Seginning of Cycle
.0060 .0063 End of Cycle
.C051 .0051 4
Neutron Generation Time, t' 80C 10-6 sec 28 24 : EOC 10-6 sec 33 29 ' v l l l l 1
! h- TbE5-2 St. Lucie Unit 1 [ W{g f F - O D o .f gg[g, Limiting Values of Cycle 4 CEA REACTIVITY 110RTilS Aft 0 ALL0l!AtlCES, ,
%Ao DOC EOC Reference Cycle Reload Cycle Reference Cycle Reload Cycle llorth Ava ilable*
llorth of all CEAs inserted 10.5 94 11,4 10.6 Stuck CEA allowance 2. 7 2.4 3.1 2.9 llorth of all CEAs less highest worth 7.8 7. 0 8.3 7.7 CEA stuck out llorth Reguired (Allowances) Power defect, llFP to ll2P (Doppler, Tavg. l.7 1.9 2.2 redistribution) 2.4 Moderator voids 0. ~0 0.0 0.1 0.1 CEA bite, baron deadband and maneuvering 0.6' O.5 band 0.6 0.6 Required shutdoun nurgin (tap) 3.3 4.3 3.3 4.3 Total reactivity required 5.6 6.7 6. 2' 7,4 Available llorth less Allowances
- Margin available 2.2 0.3 2.1 0.3 ofor every accident or A00 considered in the safety arialysis, a calculational uncertainty of 10% is deducted from the worth available.
e e G G G
TABLE 5-3 () ,. ST. LUCIE UtlIT I CYCLE 4 REACTIVITY WORTH OF CEA REGULATING GROUPS AT HOT FUL'L POWER, 140 Beginninc of Cvele End of'Cvele Requiating Reference Reference CEAs Cycle Cycle 4 (} Cycle Cycle 4 Group 7 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 Note Values shown assu.me sequential group inser:fon. l .(! O l lO o r _ _ . _ _ _ _ . . _ . _ . . _ . _ _ . _ __ _ - .... .. ,.. _ _ _~._.- _ _ _ ._
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l TABLE S-4 l ST. LUCIE Utill I CYCLE 4 CEA EJECTioll DATA limiting Value Referbnce Cycle Cycle 4 Safety Maxianum Radial Power Peak Sa fety Analysis Value Analysis Value Full power with Bank 7 inserted; worst CEA ejected 3.60 3.60 7ero power with Banks 766*5 inserted; worst CEA ejected 8.34 9.40 flaxintum fjected CEA Horth (%Ap) full power with Bank 7 inserted; worst CEA ejected .29 .28 2ero power with Banks 7e6t5 inserted; worst CEA ejected .65 .63 tlutes:2)1) Uncertainties and allowances are included in the ' 've data. The Cycle Cycle 4 safetyvalues. 4 calculated analysis values are conservats.e with respect to the actual e - e 9 9 8 - --
l 1 1 l i 1 l TABLE 5-5 O fs s.. St. Lucie-1 Cycle 4 Full Length CEA Orop Data Limiting Values l Reference Cycle Cycle 4 Minimum Worth %ao .04 . 04 l i () Maximum Percent Increase in Radial Peaking Factor 17 16 l l 1 Mates:
* (1) CEAs are either fully withdrawn or fully inserted for radial calculations.
(2) Thess are Cycle 4 safety analysis values which are , conservative with respect to Cycle 4 calculated values. l , O 1 )
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TABLE 5-6 St. i.ucie Unit 1 Augmentation Fac:ces and Gap Sizes for Cycle 4 and Reference Cycle Reference Cycle Cycle 4 Core Core Height Noncollapsed Gap Height Clad Augmen-Noncollapsed Gap IPercent) Size Clad Augmen-IInches) tation Factor Size (Inches _) tation .: actor (Incnes) 98.5 134.7 1.058 2.04 86.8 1.071 1.74 118.6 1.053 1.80 1.067 1.54 77.9 106.5 1.050 1.62 66.2 1.063 1,38 90.5 1.044 1.38 1.057 54.4 74.4 1,038 1.18 1.14 1.050 ' 45.5 62.3 0.97 1.033 0.96 33.8 1.045 0.82 46.2 1.025 0.72 1.035 22.1 30.2 0.52 1.018 0.48 I32 1.025 0.41 13.i 1.013 0.30 1.017 1.5 2.0 0.26 1.003 0.06 1.C04 0.05 1 1 1 Note s: 1)
/alues are based on accroved medel described in ?,afs .ne. : ' ' '
9 sy hIset$Ee'$clja*"j"cjestemvaluesarecon$3ry,[y, y calcula:ed values. O
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" !3"2s samoa scapam IIWIl NOI183SNIIN30N3d30 B3M0d apnris 0)n6B O
w FRACTION OF RATED THERMAL POWER N P .o P .o P P P P P ~ o "o
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E l E i 8 88 I I I 8 i E 8 i t
- 8. 8 I
8 - LONG TERM STEADY STATE TNSERTION LIMIT a W 8 - I l 8 - l _ m _ ISHORT TERM f g _ l5NSERTION LIMIT a o e - i s m a
-n W '
h- - m m a Z w m
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z M g _ _ _-1 Z o M Z _ _ m s d o Z e -< g Z l l
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- 0. 75 1.03 X
0.75 1.02 0.98 1.06 1.03 0.73 1.02 0 1.09 1.22 1.21 1.18 0.73 0.90 0.85 1.17 1.03 1.13 0.85 i 0.75 1.01 0.85 1.14 1.06 1.19 0.87 0.91 1.01 1.08 1.16 1.05 1.18 1.04 1.05 O 0.88 u 0.98 1.22 1.02 1.19 1.03 1.14 0.90 0.89 ! l 0.75 1.05 1.21 1.13 0.86 1.05 0.90 0.98 0.85 1.03 1.18 0.85 0.91 0.88 0.89 0.85 0.65 NOTE: X = MAXIMUM 1 - PIN PEAK = 1.48 i st. Lucie CYCLE 4 - ASSEMBLY RELATIVE POWER DENSITY Figure 9 """fn"; *E'.slati " BOC, EQUILIBRIUM XENON 5-2 I
0.68 0.87 0.68 0.91 0.97 0.95 0.93 0.72 0.93 1.00 1.12 1.15 1.25 0.72 0.96 0.84 1.22 1.00 1.24 0.92 0.68 0.93 0.84 1.10 1.04 1.17 0.92 0.98 0.91 1.00 1.22 1.04 1.29 1.06 1.22 0.97 X 0.97 1.12 1.00 1.17 1.06 1.17 1.00 1.00 0.68 0.95 1.15 1.24 0.92 1.22 1.00 1.21 0.99 0.87 0.93 1.25 0.92 0.98 0.97 1.00 0.99 0.80 i NOTE: X = MAXIMUM 1 - PIN PEAK = 1.46 st. tucie CYCLE 4 - ASSEMBLY RELATIVE POWER DENSITY Figure i"
""*'"f ,Pa* '.1 MOC, EQUILIBRIUM XENON 5-3 t
l
1 O' O.70 0.85 0.70 0.91 1.02 0.94 0.92 0.78 0 0.95 0.98 1.08 1.11 1.27 l 0.78 1.07 0.88 1.24 0.98 1.26 ! 0.94 0.70 0.95 0.88 1.08 1.01 1.11 0.92 0.98 l O.91 0.98 1.24 1.01 1.26 1.02 O' 1.24 0.97 1.02 1.08 0.98 1.11 1.02 1.11 0.99 0.99 0.70 0.94 1.11 1.26 0.92 1.24 0.99 1.24 1.00 0.85 0.92 1.27 g 0.94 0.98 0.97 0.99 1.00 0.84 ! X ' NOTE: X = MAXIMUM 1 - PIN PEAK = 1.43 I i st. tucie 9
'8 CYCLE 4 - ASSEMBLY RELATIVE POWER DENSITY Figure ""*j,";[.70. / " EOC, EQUILIBRIUM XENON 5- 4
i I > BANK 7 CEA INSERTIONS
/ 0.63 0.84 0.65 0.91 0.90 0.93 0.85 0.53 0.89 1.06 1.19 1.08
'////,,
,0.74
,/ / /
0.53 V/6 0.51 0.78 1.19 1.10 1.14 0.83 y/
/ /
0.65 0.89 0.78 1.15 1.19 1.35 1.02 1.05 0 0.91 1.05 1.18 1.17 1.37 1.25 1.27 1.09 0.89 1.19 1.10 1.35 1.25 1.39 1.13 1.11 0.63 X 0.92 1.08 1.13 1.01 1.27 1.13 1.15 0.96 O' 0 4 >
'/ / /
/d. 4
/
' ///
0.85 0.83 1.05 1.09 1.11 0.96 /0.50/ (! / '// / NOTE: X = MAXIMUM 1 - PIN PEAK = 1.64 1 st. Lucie CYCLE 4 ASSEMBLY RELATIVE POWER DENSITY Figure
"""$n";lE',slati " WITH CEA BANK 7 INSERTED AT HFP BOC 5-5 l
- 6. THERMAL-HYDRAJ'LIC CESIGil 9
mm oe3 9 .
*WWf e ib d E "
i
- 6.1 OfiBR Analyses g
Steady state DilDR analyses of Cycle 4 at the rated scwer level of 2700 i&t have been cerformed using the TORC comocter code (Ref.10) and the CE-1 critical heat flux correlation (Ref.11). , , Table 6-1 contains a list of pertinent thermal-hydraulic design parameters used for both safety analyses and for generating reactor protective system setpoint information. Also note, that the calculational facters (engineering heat flux factor, engineering factor on hot channel heat input and rod piten, bewing and clad diameter factor) listed in Table 6-1 have been ecmbined statistically with other uncertainty factersata.95/95 confidence / probability Ir. vel 4 (Ref.12) to define a new design limit on CE-1 minimum ONSRG.23)mhen iterating on power as discussed in Ref. 12. Investigations have been made to ascertain the effect of the CEA guide tuce wear problem and the sleeving repair on OfiCR mar, gins as established by this type of analysis. The findings were reported to the !!RC in P.eforence 4 which concluded. that, the wear problem an'd the sleeving repair do not adversely affect OliSP. margin. 6.2 Effects of Fuel Rod Ewing en OfiER fiargin C' Effects of fuel red bowing on oiler margin have been incorporated ta the sare:7 2nc satactac 2,atzses in tae same maaaer as discussed in Reference 3. This reference :entains penaities on minimum Di!BR g due to fuel red bowing as a function of Ournup ganerated using i!RC
' guidelines contained in Reference 9.
O e
- r. O
Table 6-1 St.1.ucie Unit 1 Thermal-Hydraulic Parameters at Full Power-General Characteristics Reference Unit . Cycle 3 Cycle 4 Total Heat Output (core only)
- NWt 2560 2700 100 BTU /hr 8737 9215 Fraction of Heat Generated in -
.975 Fuel Rod -
.975 Primary System Pressure O Nominal Minimum in steady state Maximum in scaady state psia psia 2250 2200 2250 2200 psia 2300 2300 Destgri Inlet Temperature 'F 544 549 Total Reactor Coolant Ficw gptg 370,000 370,000 (minimum steady state) 100 lb/hr 140.2" 139.3*
Coolant Flow Through Core 106 lb/hr 135.0* 134.10* Hydraulic Diameter ' ft 0.044 0.044 (nominal channel) - Average Mass Velocity 106 lb/hr-ft2 2.53* 2. 51
- Pressure Orop Across C m O C> ("'"'*"""'"''"
irreversible ap over entire psi 10.3 10.4 psi fuel assemoly) Total Pressure Orop Across Vessel psi 33.5 33.5 psi (based on nominal dimensions and minimum steady state flow) Core Average Heat Flux (accounts for BTU /hr-ft 2 above fraction of heat generated in 174,400 183,843 fuel rod and axial denst fication factor) Total Heat Transfer Area (accounts for ft 48,860 48,872 axial densification factor) Film Coeff'cient at Average Conditions BTU /hr-ft 2 F 5820 5820 Maximum Clad Surface Temperature F 657 657 Average Film Temperature Of fference F 31 33 Average Linear Heat Rate of Undensified kw/ft 5.83 6.14 Fuel Rod (acccunts for above fraction of heat generated in fuel red) Average Core Enthalpy Rise BTU /lb 65* 68.7 * (
.
- Calculated at design inlet temperature, ncminal primary system pressure.
_ ,,,-,-q
Table 6-1 (cont. ) j' Reference fculationalFactors Cycle 3 . Cycle 4 Engineering Heat Flux Factor *' 1.03 1.03 Engineering Factor on Hot Channel Heat Input ** 1.03 .
- 1. 02 ' '
Inlot Plenum .1cnunfiorm 01stributien 'l.05 No't applicable Rod Pitch, Bcwing and Clad Diameter" 1.065 1.065 Fuel Densification Factor (axial) 1.01 1.002 Fuel Rod Bewing Augmentacion Factor on Fr 1.018 1.'018 9 Based on "Asbuilt" infor. nation.
**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 ir. Reference 12.
O e e
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O
REFEREi!CES (Sections 1 through 6) A CEN-79-P, " Reactor Operation with Guide Tube Wear", February 3,1978
- 2. Letter, Robert E. Uhrig (FP&L) to Victor Stello (iiRC), dated February 22, 1979, "St. Lucie Unit 1.0ccket tio. 50-335 Proposed Amendment to Facility
. Operating License DPR-67" i
- 3. CE;tPO-187, "CEPAll liethod of Analyzing Creep Collapse of Oval Cladding",
June, 1975. ,
- 4. CEft-80(H)-P, " Millstone Unit 2 Reactor Operation with Modified CEA Guide Tubes", February 8,1978
- 5. CEllPO-139, "C-E Fuel Evaluation Model Topical Report" July 1,1974 :-
- 6. St. Lucie fluclear Pcwer Plant (Formerly Hutchinson Island) Unit One, Final Safety Analysis Report, in support of Occket tio. 50-335
- 7. (rhere is no Reference 7)
- 8. Supplement 3-P (Proprietary) to CE!!PD 225P, " Fuel and Poison Rod Scwing",
June 1979
- 9. Letter frem D. B. Vassallo (?!RC) to A. E. Scherer (C-E) dated June 12, 1978 O o CE"Pc-lei-e. ,0aC C;ee.
- ComPeter Ccee er Determ4nine the rnermei Margin of a Reactor : ore", July 1975
- 11. Critical Heat Flux Carrelation for C-E Fuel Assembif es with Standard Spacer Grids Part 1, Uniform Axial Pcwer Distribution, CE?lPD-162-P-A
. (Proprietary) and CEi!PD-162-A (iten-Proprietary), April,1975
- 12. CEN-124 (S)-P, " Statistical Combination of Uncertainties, Part 2",
January, 1980
- 13. CEN-122(F), " FIESTA", ttovember,1979.
O - e oG -
1 l i l I 7.0 TRANS!ctlT AtlALYSIS 9 The purpose of this section is to present the results of Florida Power and Light St. Lucie Unit 1, Cycle 4 f4cn-LOCA safety analysis at 2700 ftlt. 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:
- 1. 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 Limit;.
t
- 3. Postulated Accidents. :
For all DBEs so indicated in Table 7-1, an explicit analysis was nerformed tn determine the consequences of these events durinq stretch power operation. A few events were not reanalyzed (See Table 7-1). These events are elininated by Technical Specification restrictions. O i i 0 O
~
TABLE 7-1 ST. LUCIE UNIT 1 CYCLE 4 DESIGN BASIS EVENTS COP;SIDERED IN STRETCH POWER SAFETY ANALYSIS Analy_ sis Status 7.1 Anticipated Operational Occurrences for which intervention of the RPS is necessary to prevent exceedino 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 fialfunction Reanalyzed 7.1.7 Reactor Coolant System Depressurization Reanalyzed 7.1.8 Control Element Assembly Withdrawal l Reanalyzed 7.1.9 Loss of Coolant Flow 2 Reanalyzed 7.1.10 Loss of AC Power Reanalyzed O 7.1.11 Transients Resulting from the Malfunction of One Steam Generator 3 Reanalyzed 7.2 Anticipated Operational Occurrences for which RPS trfps and/or sufficient initial steady state thermal nargin , 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 fialpositioning 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 Line Rupture Reanalyzed 7.0.3 Steam Generator Tube Rupture Reanalyzed 7.3.4 Seized Rotor Reanalyzed O I Requires High Power and Variable High Power trip; event is discussed in Section 7.2. 2 Requires low Flow trip i event is discussed in Section 7.2. 3 Requires aP across the Steam Generator Trip; event is discussed in Section 7.2.
i O 7.1 AflTICIPATED OPERATIONAL OCCURRErlCES FOR WH?CH THE RPS ASSURES tl0 VIOLATION OF LIMITS The events in this category were analy:ed for stretch power operation of Florida Power and Light St. Lucie Unit 1. Cycle 4 to determine that Acceptable Limits on DflBR, CTil, Reactor Coolant System (RCS) upset pressure, and 10CFR100 site boundary dose rate guidelines will not be exceeded. Each of the event writeuos in the section identifies which criterion the event in question addresses. Protection against violatin will continue to be assured by the Reactor Protection System (g these limits RPS) Limiting Safety Systen Settings (LSSS) ntpoints. The setpoints will be modified (as necessary) to include changes 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 Tri/LP ; and ASI RPS trips is discussed in CEti-123 (F)-P, (Reference 14). For those events in this section where DflBR or CTM values were calculated ' and quoted, the calculations were performed using the nominal values of key flSSS paraceters listed in Table 7.2. Uncertainties were accounted , I for in determining the values cf DNBR or CTil by applying appropriate values ! of aggregate uncertainties identified in CEN-123 (F)-P to the limiting rod j power. For those events analyzed to determine that the RCS upset pressure ! limit or 10CFR100 Mse limits are not exceeded, the methods used are the i same as previously .eported in the FSAR or subsequent reload licensing subnittals. Effects of NSSS parameter uncertainties on these limits are not assessed statistically. Instead, applicable uncertainties are assumed to occur simultatieously in the most adverse direction. When values of the NSSS parameter used in evaluation of the RCS pressure and dose I limits differ from those given in Table 7.2, they will be specifically I noted. The results of the analyses are provided in the following sections. l 6 I O
l l I l l O 7.1.1 BORON DILUTION EVENT The Baron Dilution evant 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 i operation. It is also analyzed to establish corresponding shutdown ' j margin requirements for modes 3 through 5 as they are defined by the 4 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 CTH limits. Since the TM/LP ,
trip system monitors the transient behavior of core power level and I 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 setting of the Variable High Power Level trip. For more rapid power t excursions the Variable High Power Level trip initiates a reactor trip. The approach to the CTM limit is 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 i j trip prior to approaching the limits. l 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 i' effects by reducing the calculated time to criticality. The time to criticality was detennined by using the following expression:
C at
- I I" crit BD C
crit where 6t erit = Time interval to dilute to critical i T BD
= Time constant C
crit
= Critical boron concentration (ppm)
C 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 a; tion to mitigate the consequences of this event. 9 a-,-- -. , ,.,w- -_~,,..~,-,.v.-,_..,e - y 7 3,..y7 .,e ,y,, , . , -,,,y.m,, ,y.,y ,..._-m.m , , _ _ . , , . ._ ,_,,
TABt.E 7.1.1-1 - KEY PARA!1ETERS ASSUltED Ifl Tile 80R0ft DII.tITI0ft AllALYSIS
-O Reference Parameter Cycle *
. Cycle 4 Critical Boron Concentration, PPli (All Rods Out, Zero Xenon)
Power Operation (!!cde 1) 1200 1330 Startup (flode 2) ifot Standby (14cde 3) I300 1300 1420 1420 g liot Shutdor:n (ftoce 4) . 1-300 1420 Cold Shutdown (l4cde 5) . 1300 1420 Refueling (!! ode 6-) 1200 1280 Inverse Boron Worth, PPli/5Ap 1 Pouer Operation 95 70 Startup llot Standby 65 55 90 70 h llot Shutdown 55 70 Cold Shutdown 55 70 Refuelin9 55 70 . 1 liininum Shutdown !!argin Assumed, %As ' Power Operation -- -- Startup -3,3 -4,3 Hot Standby
-3.3- -4.3 liot Shutdown -3,3 -4,3 <
Cold Shutdown -1.0
-2.0 l Refueling -9,45 -6.28
- l
{ I' i
*' Cycle 2- last detailed analysis presented e i
O e 6 h
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TABLE 7.1.1-2 RESULTS OF T}tE BOR0tl DILUTI0ff EVEitT i j ,
- . l i ,
- \
l Time to Lose Criterion For flinirnum ! liodo Prescribed Shutdoun Time to Lose ! ! liarqin (ftin) Proscribed Shutdosn i W2 Cycle 4 Itargin (itin) I l Startup 95.1 128.,9 15 l!ot Standby 1 69.3 102.8
- 15 llot Shutdown 69.3
- 102.8 15
- f. Cold Shutdown .22.6 25.0 '
15 j - I 1 Refuelin9 56.0 . 46.5 ! i 30 i e F t t i i i - 1 I \ - E __ -_ _ __ . . _
q O\ 7.1.2 STARTUP OF All IflACTIVE 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 pemit operation at power (modes 1 and 2) with less than 4 Reactor Coolant pumps operating. O' :
.a O
I i O' O
O b 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 generator 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 DNBR. The approach co the CTM limit is terminated by either the Local Power Density trip, Variable High Power Level trip or the DNB related trip discussed above. As presented in the FSAR, the most limiting load increase evencs 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 calyzed since it is the more limiting (i.e., approaches closer to the acceptable DNBR limit) case. TheExcessLoadeventatfullpowerwasinitiatedatthecondigionsgiven in Table 7.2. A Moderator Temperature Coefficient of -2.5X10~ ao/F was O assumed in this analysis. This MTC, in conjunction with the decreasing coolant inlet temperature, enhances the rate of increase of heat flux at the time of reactor trip. A Fuel Temperature Coefficient (FTC) corresponding to beginning of cycle conditions with an uncertainty of 15% 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 DNBR. 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 DNBR 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 KW/ft compared to the design CTM limit cf 21.7 KW/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 DNBR and CTM limits will not be violated. [ t I
1 l O TABLE 7.1.3-1 SEQUENCE OF EVENTS FOR THE EXCESS LOAD EVENT AT FULL POWER TO CALCULATE MINIMUM DNBR e Time (Sec) Event Setpoint 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
%nerated -
8.2 Trip Signal Reaches CEA --- Holding Coil ! 8.7 CEA's Begin to Drop Into Core --- l 9.1 Maximum Power 113.6 ' 9.1 Maximum Local Linear Heat t Rate Occurs, KW/ft 18.3 ! I 9.6 Minimum DNBR Occurs 1.54 ; i Note: The Reference Cycle for this event is the FSAR. l el
O 120- , , , 100 - - O - E 8 m 80 - - 55
==
f5 3 60 2 w O 8 o 40 - - , 20 - - 0 0 10 23 30 40 TIME, SECONDS Pow [Ri[!E,*HT CO. Figure EXCESS LOAD EVENT sr. Luci. Plant CORE POWER vs TIME Unit 1 7.1.3-1
O l 120 . , , 100 e s
- E - -
g 80 m 8 - e x 60 - _ 3 u. s: 40 - _ 9 m 8 u 20 - _ 0 10 20 30 40 4 TIME, SECONDS O FLOR [DA Figure POWER & LIGHT co. EXCESS LOAD EVENT l St. uucie Plant CORE AVERAGE HEAT FLUX vs TIME 7.1.3-2 Unit 1 I l ,
O 620 i i i 610 - - 600 - - O 590 T - OUTLET , O g' 580 - - 5 : E 570 - - 5 560 T
~
AVERAGE O 550 - 540 - - I INLET 530 _ 520 - - 510 - - l l O 500 O 10 20 30 40 TIME, SECONDS O FLORIDA Figu re POWER & LIGHT CO. EXCESS LOAD 3/ENT sr. L" i Plat RCS TEMPERATURES vs TIME uI 7.1.3-3
0 2300 i , , 2200 - O 5 . T 2100 - ul 5 -: :
$1 y 2000 -
I a. m o , c: ; 1900 - 1800- _ I i i 1700 0 10 20 30 40
$l TIME, SECONDS O
Figu re POWEk I HT CO. EXCESS LOAD EVENT sr. Lucie Plant RCS PRESSURE vs TIME 7.1.3-4
O 1050 , , , 900 - 5 Q .
- 750 -
W 5? O m
' 600 -
8 ti ei , z Os 8 450 - 3 . 6 5 3W - 150 - l O ! i i 0 i
- 0 10 20 30 40 TIME, SECONDS .
O FLORIDA Figure POWER & UGHT CO. D(CESS LOAD EVENT sr. Lucie Plant Unit I STEAM GENERATOR PRESSURE vs TIME 7.1. 3-5
O 7.1. 4 LOSS OF LOAD EVErlT The Loss of Load event was reanalyzed to deternine that the DNRR limit and the RCS pressure upset limit of 2750 psia are not exceeded during Cycle 4. The assumptions used to maximize RCS pressure during 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 renoval 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. b) The steam duep and bypass system, ta pressurizer spray systen, and the power operated pressurizer relief valves 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 paraneters 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 analyze this event are identical to those described in the FSAR except TORC /CE-1, rather than COSfiO/W-3, was used to calculate DilBR '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 required to , mitigate the pressure and heat flux increases. The fioderator Tenperature Coefficient (MTC) of +.5X10-4ao/*F was assumed in this analysis. This itTC in conjunction with the increasing coolant temperatures, enhances the rate of change of heat fkx 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 anount of negative reactivity feer.back to mitigate the transient increases in both the core heat flux and the pressure. The uncertainty on the FTC u::ed in the analyses is shown in Table 7.1.4-1. The lower limit on initial RCS pressure is used to maximize the rate of chang'e 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 prassure 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 I open at 5.1 seconds. The secondary pressure reaches its maximum value I 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 DNBR limit is not violated. The mininum transient Of BR calculated for the event is 1.48 as conpared to the design limit of 1.23.
4 Table '.l.4-2 presents the sequence of events for this event. Figures 3 7.1.4 i to 7.1.4-5 show the transient behavior of power, heat flux, RCS coolant temperatures, the RCS pressure, and the steam generator pressure. j j The results of this analysis demonstrate that the Loss of Load event will l not produce OflBR's or pesk RCS pressures which exceed the DNBR limit l or the upset pressure limit, i i L i
, i 4
g
)
4 Y
+
d l , < 1 i i l l l i i
=
[ 1 m -. e a- s--r-e -~w_- wr aw-=w e- w. e+ -wmvwe --+ ----iv--3-M-W"t*-T 1*--*- r^pe-m T t vyeM-- e - - -w, g ggg- ge---go-m+-www--a--t-e-e--y-g W ww -e =me wwe- -'y 9--y w rw m we y9M-v7
TABLE 7.1.4-1 l XEY PARAftETERS ASSufiED Ifi THE LOSS OF LOAD At1ALYSIS T0 ftAXIMIZE CALCULATED RCS PEAK PRESSURE Reference
- Parameter Units Cycle Cycle 4 Initial Core Power Level MWt 2611 2754 Initial Core Inlet Coolant Temperature *F 544 551 0 138.3 Core Coolant Flow X10 ltw/hr 134.9 Initial Reactor Coolant System Pressure psia 2250 2200 Initial Steam Generator Pressure osia 848 820 floderator Temperature Coefficient X10-4ao/*F +.5 +5 Doppler Coefficient Multiplier .85 .85 CEA Worth at Trip %Ao -2.4 - 4. 7 -
Time to 90% Insertion of Scran Rods sec 3.0 3.1 Reactor Regulatino System Operating liode Manual Manual Steam Dump and Bypass System Operating ibde Inoperative Inoperative O ;
- FSAR !
i i O'
t i O TABLE 7.1.4-2 SEQUENCE OF EVENTS FOR THE LOSS OF LOAD EVENT TO MAXIMIZE CALCULATED RCS PEAK PRESSURE Time (sec) Event Setooint or Value 0.0 Loss of Secondary Load --- 5.1 Steam Generator Safety Valves 1010 psia Open 7.8 Hi h Pressurizer Pressure Trip 2422 psia Si nal Generated 9.0 Pressurizer Safety Valves Open 2500 psia 9.2 CEAs Begin to Drop Into Ccre --- 11.0 Maximum RCS Pressure 2572 psia 11.2 Maximum Steam Generator Pressure 1057 psia 13.5 Pressurizer Safety Valves are 2500 psia Fully closed 4 i
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20 - - 10
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0 0 40 80 120 160 200 gli ' TIME, SECONDS '
'l
'1 FLORIDA LOSS OF LOAD EVENT Fisme PO7ER 5 wc .& LI l]O. CORE POWER vs TIME 7.1.4-1 l
O 120 , , i i i i i i i 110 - 100 -
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's j 7.1.5 LOSS OF FEEDWATER FLOW EVENT The Loss of Feedwater Flow event was reanalyzed to detemine that the DNBR 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 feeduater flow to the steam generators without a corresponding reduction Q(3 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 pg of core power, core average 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 system, and the pressurizer 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 spray system and relief valves could potentially lead to an earlier reactor trip on high pressurizer oressure. An initial secondary pressure of 893 psia was also assumed to neximize steam releases from the steam generators via the secondary safety valves. The analysis 7m shows that a reactor trip on low steam generator level occurs at 12.8 I i seconds. This corresponds to a water level which is 60 inches below V the normal operating level. The analysis shows that the water remaining in the steam 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 th4t the acceptable DNBR limit will not be exceeded. The minimum transient DNBR calculated for the event is 1.53 as compared to the design DNBR limit of 1.23. N.)
i TABLE 7.1.5 1 KEY PARAliETERS ASSUMED IN THE LOSS OF FEEDWATER FLOW ANALYSIS TO MAXIMIZE CALCULATED RCS PEAK PRESSURE Reference
- Parameter Units Cycle Cycle 4 Initial Core Power Level itWt 2611 2754 Inlet Coolant Temperature 'F 544 551 6
Core Mass Flow Rate X10 1bn/hr 134.8 138.3 Reactor Coolant System Pressure psia 2250 2200 Steam Generator Pressure psia 841 815 fioderator Temperature Coefficient X10~4ao/*F +.5 +.5 Doppler Coefficient fiultiplier ---
.85 .85 R; actor Regulating System Operating fiade Manual fianual ** '
Steam Dump and Bypass System Operating fiode Auto Inoperative ** Fe:dwater Regulating System Operating fiode Inoperative Inoperati ve ** Auxiliary Feedwater System Operating Mode Manual fianual ** Pressurizea Pressure Control System Operating Mode Auto Inoperati ve ** Pressurizer Level Control System Operating Mode Auto Inoperati ve **
- FSAR Th:se modes of control system operation maxinize the peak RCS pressure.
O l l O
TABLE 7.1.5-2 1 SE0VENCE OF EVENTS FOR
' LOSS OF FEEDWATER FL0lt ANALYSIS TO MAXIMIZE CALCULATED RCS PEAK PRESSURE Tine (sec) Event Setpoint or Value O.0 Loss of Main Feedwater ---
28.8 High Pressurizer Pressure Trip 2422 psia Signal Generated 1
- 30.2 CEAs Begin to Drop into Core ---
s 30.9 Steara Generator Safety Valves 990 psia - 1 Begin to Open 32.4 Primary Safety Valves Begin 2500 psia to Open O 32.8 Maximum RCS Pressure 2506 psia i 36.0 Maximum Steam Generator Pressure 1046 psia i O O
TABLE 7.1.5-3 KEY PARAMETERS ASSUMED Ifl THE LOSS OF FEEDWATER FLOW ANALYSIS 0 T0 t1It1It1IZE CALCULATED STEAM GEtlERATOR DRYOUT TIf1E Reference
- Parameter Units Cycle Cycle 4 Initial Core Power Level tiWt 2611 2754 Inlet Coolant Temperature 'F 544 551 0
Core Mass Flow Rate X10 lbm/hr 134.8 138.3 Reactor Coolant System Pressure psia 2250 2200 Steam Generator Pressure psia 841 893 Moderator Temperature Coefficient X10~44p/*F +.5 +.5 Doppler Coefficient liultiplier ---
.85 .85 Reactor Regulating System Operating Mode Manual itanual ** ,
Stea:n Dump and Bypass System Operating Mode Auto Auto Fe:dwater Regulating System Operating ffode Inoperative Inoperative ** Auxiliary Feedwater System Operating tiode 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 minimize the steam generator dryout time. O O g eemeem w eem pammumDW 4 6-m m=**
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I l O 7.1.6 EXCESS HEAT REMOVAL DUE TO FEEDUATER MALFUtiCTION EVENT The Excess Heat Removal was reanalyzed to demonstrate that the DNBR limit is not exceeded during Cycle 4. The event is assumed to result from the instantaneous loss of the high pressure feedwater heaters wiiich reduces the temperature of the main feedwater supplied to the steam generators and leads to increased heat extraction from the primary 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 tems 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 DNBR during the event is less limiting than the minimum transient CE-1 DNBR for the Excess Lnad event (see Section 7.1.3). Consequently the results of the Excess Heat Removal event are not presented. O O O
i l O U 7.1.7 RCS DEPRESSURIZATION EVENT The RCS Depressurization event was reanalyzed for Cycle 4 to detemine the pressure bias factor for the Tli/LP trip setpoint. The RCS Depressurization event is one of the DL = analyzed to detemine the maximum pressure bias factor input to the Tfi/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 f \ and axial shape index during the transient are monitored by the T?i/LP trip directly. ' Consequently, with TM/LP trip setpoints and the bias tem detemined 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 DNBR 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 DNBR.
O v
- 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 teminate the decrease in DNBR 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 to the DNBR 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 detemined by this event in conjunction with the TM/LP trip, will prevent exceeding the DNBR design limit for O U A00's which require TM/LP trip protection. O
, 1 O
7.2 ANTICIPATED OPERATI0f1AL OCCURREllCES WHICH ARE DEPEflDENT ON INITIAL OVERPOWER MARGIN AND/OR RPS TRIPS FOR PROTECTION AGAINST VIOLATION O 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, CTM and upset pressure limits will not be exceeded during any of these events. The initial margin required to prevent the appropriate limits from being exceede.d 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 A00 in this category. The method of generating Limitina 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 differ from those given in Table 7.2, since for these limits the effects of NSSS parameter ,, uncertainties are not combined statistically. O O l
.. . --+ -. .--
(D %) 7.2.1 CEA WITHDRAWAL EVEflT The CEA Withdrawal event was reanalyzed for Cycle 4 to determine the initial margins that must be maintained by the LCOs such that in conjunction with the RPS (Variable High Power Trip) the DNBR and fuel centerline to melt (CTit) 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 DNBR and centerline to melt limits are not violated by virtue of sufficient initial steady state thermal margin provided by the DNBR and Linear Heat Rate (LHR) related v Limiting Conditions for Operations (LCO's). Depending on the initial conditions and the reactivity insertion rate associated with the CEA Witndrawal, either the Vaif able High Power Level or Thermal flargin/ Low Pressure (Tit /LP) trip, in conjunction with the initial steady state LCOs, prevents DNBR 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 analysis only took credit for the Variable High Power Trip to detennine the required initial overpower margin for - DNBR. The zero power case was analyzed to demonstrate that acceptable DNBR and centerline to melt limits are not exceeded. For the zero power case, a reactor trip, initiated by the variable high power trip at 25% (15% ' p + 10% uncertainty) of rated thermal power, was assumed in the analysis. V The key parameters for the cases analyzed are reactivity insertion rate due'to ro f 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 of reactivity insertion rates considered tn the analysts ts gtyen in Tpble 7.2.1-1. The values of other key parameters used in the analysis of tftis event are also presented in Table 7.2.1-1. The zero power case initiated at the limiting conditions of operation results in a minimum CE-1 DNBR of 1.86. Also, the analysis shows that the fuel-centerline temperatures are well below those corresponding to the acceptable fuel centerline melt limit, The sequence of events for n the zero' power case is presented in Table 7.2.1-2 Figures 7,2,1-1 to V 7.2.1-4 present the transient behavior 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 initial steady state therr:al margin which is maintained by adhering to the Technical Specifications' LCOs on DNBR , margin and by the response of the RPS which provides an automatic reactor ! trip on high power level. The minimum DNBR for this event, when initiated 1 from the extremes of th" LCOs, is 1.52 . Tne analysf3 ihows that the i fuel centerline te?.sr uures are well below those corresponding to the acceptable CTil limt. The sequence of events for the full power case is presented in Table 7.2.1-3. Figures 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 Spec LCOs (a conjunction with the O Variable High Power Trip if required) will not lead to a DflBR or fuel temperature which exceed the DriBR and centerline to melt design limits. l 1 1 Ol 1 l l O O J O
TABLE 7-1 ST. LUCIE 1 CORE PARAftETERS INPUT TO SAFETY ANALYSES FOR DNB AND CTM (CENTERLINE TO MELT) DESIGN LIMITS Reference Cycle 4 Physics Parameters Units Cycle Values Values
.tadial Peaking Factors For DNB Margin Analyses (F7 )
O, Unrodded Region 1.59 1.65 1
- V Bank 7 Inserted 1.80 1.90f For Planar Radial Component (F*Y) of 3-D Peak (CMT Limit Analyses)
Unrodded Region 1.58 1.65 Bank 7 Inserted 1.82 1. 90 ** Maxinun Augmentation Factor 1.071 1.071 Moderator Temperature 10-4ao/*F -2.5 - +.5 -2.5 + +.5 Coefficient Shutdown Margin (Value assumed in -4.1/-3.3 -S.1/-4.3 Zero Power SLB) (1 loop /2 loop)
~
\ U Safety Parameters Power Level Mut 2611 2700 * ,** Maximum Steady State Core Inlet *F 544 549
- Temperature Minimum Steady State RCS psia 2200 2225
- Pressure Reactor Coolant Core Flow 106 lb/hr 134.9 138.3*
Negative Axial Shape Index LC0 I p .23 .11 * , ** extreme assumed at Full Power Maximum CEA Insertion at % Insertion of 25 25 Full Power Bank 7 Maximum Initial Linear Heat KU/ft 16.0 16.0 Rate for transient other than L0CA Steady State Linear Heat KW/f. 21.0 21.7 Rate tc Fuel Centerline Melt CEA Drop Time fron Removal sec 3.1 3.1 of Power to Holdino Coils to 90% Insertion s
.
- For DNBR calculations, effects of uncertainties on these paraneters were
] **
accounted for statistically. For CTM calculations, effects of uncertainties on these parameters are l accounted for statistically. Numerical values of these uncertainties and the procedures used in tne statistical combination of uncertainties as they pertain to ONB and CTM limits are detailed in Reference 14.
9' 1 TABLE 7.2.1-1 l KEY PARAMETERS ASSUt1ED IN THE CEA WITHDRAWAL ANALYSIS i Parameter Units Cycle 4
*hc"$"
Rang 2 of Initial Core Power Level MWt 0 - 102% of 2560 0 - 100% of 2700 , Core Inlet Coolant Temperature 'F 532-544 532-549 i i R: actor Coolant System Pressure psia 2200 2225 ffoderator Temperature Coefficient 10~4Ao/*F +.5 -2.5 to +0.5 Doppler Coefficient Multiplier .85 .85 9, CEA Worth at Trip - FP 10~26o -4.32 -4.70 CEA Worth at Trip - ZP 10~260 -3.3 -4.3 "enge of Differential Rod Worth X10-4Ao/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 9i 3.1 (Including Holding Coil Delay)
- Cycle 3 l 9
l j O TABLE 7.2.1-2 SEQUENCE OF EVENTS FOR ! CEA WITHDRAWAL FROM ZER0 POWER j Time (Sec) Event Setpoint or Value O 0.0 CEA Withdrawal Causes Uncontrolled --- Reactivity Insertion 4 26.8 High Power Trip Signal Generated 25% of 2700 MWt 27.2 Reactor Trip Breakers Open --- ! 27.7 CEAs Begin to Drop Into Core --- 0 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 e l 32.5 Maximum Pressurizer Pressure, psia 6 2397 'O i e !O u I (
- l. . . _ _ - . . - _ _ , _ . _ , . - . . . - . . - - - - - - - _ . - - - - - , - , . . . ~ . . - - . - - - . - - - . - - - . - , - - - - . . - - - - - - - - - - - - - -
TABLE 7.2.1-3 SEQUENCE OF EVENTS FOR CEA WITHDRAWAL FROM FULL POWER Time (Sec) Event Setooint or Value 0.0 CEA Withdrawal Causes Uncontrolled --- Reactivity Insertion 2.4 High Power Trip Signal Generated 110% of 2700 Mwt l 2.8 Reactor Trip Breakers Open --- I 3.3 CEAs Begin to Drop Into Core --- l' j r 3.6 Maximum Core Power 115.4% of 2700 tiWt 4.1 Maximum Heat Flux 106.3 of 2700 tiWt t 4.1 Minimum CE-1 DNBR 1. . ' 5.4 fiaximum Pressurizer Pressure, psia 2260 1 O O
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o 40 - - 30 N - - O 10 . . 0 - 0 20 40 60 80 100 TIME, SECONDS l O e<Oa to. POWER & LIGHT CO. CEA WITHDRAWAL EVENT Figure St. Lucie Plant CORE POWER vs TIME Unit 1 7.2.1-1 l
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i i O 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 Onerations (LCOs) such that in conjunction with the RPS (low flow trip), the DNBR limit will not be exceeded. The methods used to analyze this event are consistent with those 1 discussed in Reference 14. The computer code TORC (Reference 5) was used for all DNBR calculations. 1 This is consistent with methods used by C-E, and approved by NRC, to j calculate the DNB margin requirements. The 4-Pump Loss of Coolant Flow produces a rapid approach to the DNBR t linit 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 thennal margin which is maintained by adhering to j the Technical Specifications' LCOs on DNBR margin and by the response of
; the RPS which provides an automatic reactor trip on low reactor coolant i 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 O present analysis. i 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 ( .11) allowed by the DNBR related shape index LCO. The low flow trip setpoint is reached at .86 seccnds 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 i 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. 4
- o
o . i 1 :_._-,-_,- . _ _ _ _ _
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TABLE 7.2.2-1 KEY PARAMETERS ASSUMED IN THE LOSS OF COOLANT FLOW ANALYSIS Parameter Units Reference Cycle
- Cycle 4 Enitial Core Power Level MWt 2611 2700 lnitial Core Inlet Coolant *F 544 549 Temperature 6
Knitial Core Mass Flow Rate 10 lbm/hr 134.9 138.3 Reactor Coolant System Pressure psia 2200 2225 Moderator Temperature 10~4ao/F +.5 +.5 - Coefficient i Doppler Coefficient Multiplier --
.85 1.00*** !
i LFT Response Time sec 0.65 0.65 l CEA Holding Coil Delay sec 0.5 0.5 CEA Tine to 90% Insertion sec 3.1 3.1 (Including Holding Coil Delay) CEA Worth at Trip (all rods out) 10~260 -5. 41 ** -5. 60 ** Total Unrodded Radial Peaking 1. 64 ** 1. 70 ** Factor (FT) 4-Pump RCS Flow Coastdown Figure 7.3-1 of Figure 7.2.2-1 1 Reference 1 ; O o Cycle 3 C* The most limiting of the allowed full insertion cases is used to establish LCO limits. o** Since this is a second order effect and the nost limiting doppler multiplier varies during the transient, a nominal value is used. O
. . _ - ~ _ _ _ _ _ _ _. . _ . _ _ _ _ -
r l. 1 I l i i t i l TABLE 7.2.2-2 SEQUENCE OF EVENTS FOR i . LOSS OF FLOW E Time (Sec) Event Setpoint or Value l l ! 0.0 Loss of Power to all Four Reactor ---- ! Coolant Pumps O.86 Low Flow Trip Signal Generated 93*. of 4-Pump Flow
- 1.51 Trip Breakers Open ----
I 2.01 Shutdown, CEAs Begin to Orop ---- into Core 4
; 2.5 Minimum CE-1 DNBR 1.23 j 5.26 Maximum RCS Pressure, psia 2326 i
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- 7. 2. 2- 1
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- O e o w e'a u r r c o. ' LOSS OF COOLANT FLOW EVENT st. Lucie etant CORE POWER vs TIME Figure unit i . 7.2.2-2
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O 630 , , , , 620 - - T o' 610 _ OUTLET _ vi E 600 - - i2 [x 590 - - c. 3 T
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- St. Lucie Plant REACTOR COOLANT SYSTEM TEMPERATURE vs TIME unit i 7.2.2-4
4 d O 2330 , , , , BM - 2310 - g 2300 -
$ 2290 -
g' 2280 5? m 2270 - x m E 2260 - h 2250 - 2240 - - 2230 - - 2220 - 2210 ' ' 0 2 4 6 8 10 TIME, SECONDS t i FLORIDA POWER & LIGHT CO. Figure St. Lucie Plen' LOSS OF COOLANT FLOW EVENT Unit I REACTOR COOLANT SYSTEM PRESSURE vs TIME 7. 2. 2-5
f t O ; 2.2 . . . 3 ~ g 2. 0 - - E 7 O w v d z-1.8 - - z
<c z
O E3 z 1.6 - - S a 1 iili O E . 1.4 1.2 - e 1.0 O 0 2 4 TIME, SECONDS 6 8
- O ,catagh co LOSS OF COOLANT FLOW EVENT Figure St. Lucie Plant MINIMUM LOT CHANNEL CE-1 DNBR vs TIME 7.2.2-6 Unit I '
7.2.3 LOSS OF ALL tt0N-EliERGEtiCY A-C POLIER EVEtiT Identification of Cause The loss of all Non-Emergency A-C Power event was reanalyzed for Cycle 4 to determine that the DNBR limit will not be exceeded and the site boundary
~
doses will not exceed the 10CFRlCO 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 maintaining 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 atnospheric steam dump valves. Analysis of Effects and Consecuences The site boundary dose analysis was perforned with an initial power level ' of 2754 tillt and core inlet temperature of 551*F. The DNBR was evaluated using the same assumotions as given in Section 7.2.2. The following additional assumptions have been nade 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 l by natural circulation. I
- 4. Energency diesel generators start automatically after the loss of all non-emergency A-C power.
O
B. Manual action is taken to:
- 1. Initiate auxiliary feedwater flow 15 minutes subsequent to -
initiation of the event;
- 2. Actuate the steam generator atmospheric steam dump valves 15 ninutes subsequent to initiation of the event to initiate plant cooldown to 325'Ff To determine the maximum possible radioactivity release associated with a loss of all non-emergency A-C power, the following additional assumptions are made:
- 1. 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 pCi/gm (I-131 Dose Equivalent Curies);
- 3. The secondary system specific activity equals the Technical Specification limit of 0.1 nCi/gm (I-131 Dose Equivalent Curies);
- 4. The primary to secondary leak rate is the Technical Specification -
linit of 1 GPM (0.5 per steam generator).
- 5. Atmospheric steam release is required until the reactor coolant temperature is reduced to the point where-shutdown cooling can i be initiated at 325'F. i
- 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 whole N dy 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 minimun liquid mass occurring during that period. In this analysis the major q periods of time for radiological releases are: 0 - 2 hour accident condition;
- 1. 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 generaiars was calculated by the following equation: n/ (_ Concentration during period (Ci/1b)= Initial Conc. (Ci/lb) + [ Amount of activity leaked to steam generators assuming Tech Soec primary to secondary leak rato + minimum steam generator liquid mass during period].
The thyroid dose is then calculated using the following equation: O 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 hour atmospheric dispersion coefficient X dose conversion factor I" 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 j body dose is calculated by the following equation: l 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 hour 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 sumarizes the assumptions used in the calculation of radiological release. A fioderator Temperature Coefficient (MTC) of +.5X10-40.o/*F was used in the analysis since this causes a positive reactivity change duri q 1 the initial portion of the transient. This positive reactivity cb 9 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 O the first few seconds of the transient, the Loss of All Non-Energency 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. i Table 7.2.3-4 lists the stean releases during a loss of All Non-Emergency AC. event. Based on the releases, the 0 - 2 hr site boundary doses l are: Thyroid (DEQ I-131) : 0.6 REM Uhole Body (DEQ XE-133) : .7X10 3 Ret l l t
t i ; i i l 1 f
- From the analysis it can be concluded that the loss of All Non-Emergency !
l A-C power event, initiated at the conditions given in Table 7.2, would l 1 lead to a hot channel CE-1 DNBR during the transient of not less than [
! the design limit of 1.23. The radiological consc:;uences for this event .
- are a small fraction of 10CFR100 guidelines.
I. f ' 1 l \, O ;. l l 4 i 1 i 1 O , 4 l 4 l J l i i ! I i d . l 1 I i i, 1 l-i j i . 1
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e TABLE 7.2.3-1 KEY PARAMETERS ASSUltED IN THE LOSS OF ALL NON-EliERGENCY AC POWER FOR THE DETER!ilNATION OF SITE BOUNDARY DOSES FSAR Cycle 4 Parameter Units Value Value Initial Core Power Level liWt 2611 2754 Core Inlet Coolant Temperature 'F 544 551 Core Mass Flow Rate 6 X10 lbm/hr 117.5 133.8 , Reactor Coolant System Pressure psia 2250 2300
- Steam Generator Pressure psia 841 909 Moderator Temperature Coefficient X10~4ao/*F +.5 +.5 Doppler Coef'ficient Multiplier ---
.85 1.15
- CEA Ucrth at Trip %Ao -4.6 -5.3 Reactor Regulating System Operating Mode fianual fianual Stean Bypass System Operating Mode Inoperative Inoperative Auxiliary Feedwater System Operating flode Manual Manual With the set of assumptions used to detemine dose rates, these are liniting.
1
)
h -e _
i 4 F i i !O TABLE 7.2.3-2 ! 4 l ASSUMPTIONS FOR THE RADIOLOGICAL EVALUATION FOR THE LOSS OF ALL fl0N-EMERGENCY AC POWER i i Parameter Units Value Primary to Secondary Leak Rate l GPri 1.0 Reactor Coolant System Volume (excluding Ft 3 9601. Pressurizer) Reactor Coolant System liaximum Allowable uCi/gn 1.0 - Concentration (DEQ I-131)l Steam Generator Maximum A]10wable uCi/gm .1 Concentration (DEQ I-131)I 1 Reactor Coolant System Maximum Allowable uCi/gm 100 Concentration of floble Cases (DEQ Xe-133) p i Stean Generator Partition Factor -- 0.1 3 Atmospheric Dispersion Coefficient sec/t1 8.55X10-5 Breathing Rate 3 3.47 X10
-4 M /sec Dose Conversion Factor (I-131) REM /Ci 1.48 X 10 6 I
I Tech Spec limits 2 0 - 2 hour accident condition u
. _ . . __ _ _ ~ _ . _ . - ._- - - . - _ __ _ _ _ _ _ _ _ _ _ . - - - . ..
TABLE 7.2.3 3 SEQUENCE OF EVENTS FOR THE LOSS OF ALL NON-EMERGENCY A-C POWER Time (Sec) Event Setpoint or Value 0.0 Loss of All Non-Emergency AC Power --- 0.86 Low Flow Trip Signal, *. 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 Maximum 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 i i eL .l O'
i TABLE 7.2.3-4 1 I STEAtt RELEASES DURING A LOSS OF ALL NON-EMERGENCY AC EVENT i Integrated Steam Releases Value 5 Steam Release Through Safety Valves 1.63X10 1bn 5 Steam Release Through Atmospheric Steam Dump Valves 5.90X10 1bm and Feedwater Pump Turbines Atmospheric Dump 'Ialves 5 Total Amount of Steam Released During 0 - 2 hr 7.53X10 1bm - i 5 Total Amount of Steam Released Until Shutdown Cooling is 9.03X10 1bm i Initiated (325*F) lO i t l O L . O J
i l e 120 , , , , , 3 100 - g . 2 i 8 ' N 80 st ' 3 60 2 - W l 8 40; - 20 - 0 k ' ' ' ' ' e . 0 150 300 450 600 750 900 l TIME, SECONDS ll i POWER HT CO* sr. Lucie Plent LOSS OF NORMAL ON-SITE OFF-SITE ELECTRICAL POWER EVENT Figure h unit i CORE POWER vs TIME 7.2.3-1
O ! 120 i i > > > 100 l. - O si
- E g _
8 N
. 60 - -
5 d 22 w O 4 ~ ~ a a 20 - - 0 0 15 0 300 450 600 750 900 0 T1Me. SeCONoS LOSS OF NORMAL ON-SITE OFF-SITE Figu re POW [R HT CO* ELECTRICAL POWER EVENT sr. L" . un;,'['"' CORE AVERAGE HEAT FLUX vs TIME 7.2.3-2
640 O' i i . . , 620 _
- O y 600 - _
E 4 T 5 OUTLET , 580 s l I c: 1 T ' AVERAGE i 1 540 - l l T INLET ! 520 ' : 0 150 300. 450 600 750 900 TIME, SECONDS l POWE HT CO. LOSS OF NORMAL ON-SITE OFF-SITE Figure l St. Lucie Plon, ELECTRICAL POWER EVENT l unit i REACTOR C00l. ANT SYSTEM TEMPERATURES vs TIME 7.2.3-3
O 2600 , , , , , 2400 O 2200 - (, - 0;
. 2000 - -
U 5? O E
' 1800- -
ce 1600 - 1400 ( 0 150 300 450 600 750 900 TIME, SECONDS i FLORLDA LOSS OF NORMAL ON-SI 0FF-SITE Figure POWER & gGHT CO. ELECTRICAL POWER EVENT sr. u; L" ', ['"' REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.2.3-4 i
1040 i ' O 1030 - 1020 -
~
< 10001010l _
O G - 990 - - N R 980 '- - - g ! E 970 -
'8 ';i- 960 -
( N - l 5 O-
$ 950 - -
,l E i 940 -
m 930- - 920 - _ 910 - - h-900 ' ' ' ' ' 0 15 0 300 450 600 750 900 TIME, SECOND5 Ft.ORIDA POWER & LIGHT CO. LOSS OF NORMAL ON-SI 0FF-SITE Fiq' u re ELECTRICAL P01 R 5"y['"' u STEAM GENERATOR PRESSURE vs TIME 7.2.3-5
\
d 7.2.4 FULI. LENGTH CEA DROP EVEffT The Full Length CEA Drop event was reanalyzed for Cycle 4 to determine the initial therma 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 key input parameters used for Cycle 4 and compares d them to the reference cycle values. Conservative ass uptions used in the analysis include:
- 1. The most negative moderator and fuel temperature coefficients of reactivity (including uncertainties), because these coefficients Droduce the minimum RCS coolant temperature decrease upon return to 100% power level and lead to the minimum DNBR.
- 2. Ch:arging pumps and proportional heater systems are assumed to be inoperable during the transient. This maximizes the pressure drop during the event.
- 3. A . other systems are assumed to be in manual mode of operation and p have no impact on this event.
V 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. Values 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-D 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 praents the sequence of events for the Full Length CEA Drop p 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 V to 7.2.4-5. The transient initiated at the most negative shape index LCO ( .l'l) and at the maximum power level allowed by the LCO, results in a minimum CE-1 DflBR of 1.29. A maximum allowable initial linear heat generation rate of 17.9 KW/ft could exist as an initial condition without exceedino the acceptable fuel centerline nelt limit of 21.7 KW/ft durino this tra'nsient. 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. g The event initiated from the Tech Spec LCOs will not exceed the DNBR and g centerline to melt design limits. l l
l l TABLE 7.2.4-1 O XEY PAR.AMETERS ASSUMED IN THE FULL LENGTH CEA OROP ANALYSIS Parameter Units
Reference:
Cycle
- Cycle 4 Initial Core Power Level MWt 2611 2700 Core Inlet Temperature F 544 549 Reactor Coolant System Pressure psia 2200 2225 O
Core Mass Flow Rate x106 lbm/hr 134.9 138.3 "odcrator Temperature Coefficient x10~i-ap/0F -2.5 -2.5
- oppler Coefficient Multiplier -- 1.15 1.15 CEA Insertion at Maximum Allowed % Insertion of Bank 7 25 25
?cwer ,
2repped CEA Worth %ap unrodded .10 .04 PDIL .04 .04 Maximum Allowed Power Axial Shape ,21 _,11 Index at Hegative Extreme of LCO band Integrated and Planar Rr.uial Peaking Unrodded Region 1.17 1.16 Distortion Factor Bank 7 Inserted Recion 1.17 1.16 o O O
- Cycle 2 O
i O O l
i . . , TABLE 7.2.4-2 , SEQUEtlCE OF EVENTS FOR FULL LEtlGTH CEA DROP Event Setooint er Value Time (Sec) 0.0 CEA Begins to Drop into Core 1.0 CEA Reaches Full Inserted Position 100% Inserted 1.2 Core Power Level Reaches Minimum and 91.7 of 2700 MWt 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 tiinimum Value 547.5 200.0 Core Power Returns to its Maximum Value 100% of 2700 MWt 200.0 Minimum DNBR is R2 ached 1.29 e 9
- O e
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O 120 i , , , , , , , , - 110 - 100 g 90 - 5 2 m - 8
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. , , , O' 120 140 160 180 200 TIME, SECONOS t POWER HT CO*
St. Lucie Plon, FULL LENGTH CEA DROP CORE POWER vs TIME h 7.2.4-1
4 O i E0 , , , , , , , , , 110 - 100 e_ 4% E@
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6@ x o 30 o 20 - 10 - 0 0 0 20 @ 60 80 100 12 0 140 160 180 200 TIME, S ECONDS l O etoaio^ POWER & LIGHT CO. FULL LENGTH CEA DROP
e -
St. Lucie Plant CORE AVERAGE HEAT FLUX vs TIME 7.2,4-2
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600 , , , , , , , , , .. o, ( m T OUTLET G 590 - a W g. CL ' 3 i 3 5M - to . g ._ T AVERAGE s 5 570 - 8 B 0 y SM e: 550 T -' INLET 540 O 0 20 40 60 80 100 120 140 160 180 200 4 i TIME, SECONDS
'l Figure I POWER LI HT CO. FULL LENGTH CEA DROP St. Lucie Plant REACTOR COOLANT SYSTEM TEMPERATURES vs TIME 7.2.4-3
O 2260 -, , , , , , , , , O , 2230 - - w c- - 2240 - N g 2230 - - a g 2220 - 3 - G R10 - O = g 2200 5 8 o 2190 -
@ 2180 -
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$ 2170
- 2160 -
2150 0 20 40 60 80 100 120 140 160 180 200 TIME, S ECONDS r . _ _ - _ _ . _ , . _ _ _ _ _ . - - _.-__, .
O 2.2 ; i i
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O E E y1.8 - ~~ U a W A 1.6 - - O sx O 1.4 - - s 3
- 1. 2 - -
1.0 I I I 0 0 40 80 120 160 200 TIME, SECONDS FLORIDA FULL [fNGTH CEA DROP R 9 "" O POWER & LIGHT CO. St. Lucie Plant MINIMUM DNBR (CE-1)vs TIME 7.2.4-5
l [ f I
- L j- 7.2.5 PART LENGTH CEA DROP j The Part Length CEAs have been removed; hence, this event was not analyzed.
t i i
., i l
i i l i . l I 7.2.6 PART LENGTH CEA fMLPOSITIONING i
- The Part length CEAs have been removed; hence, this event was not analyzed. -
i I 4 . J i s I 1 { 2 i l I l ! l 1 1 i I t - i 1
O 7.2.7 A00'S iMSULTING FROM THE fiALFUNCTI0ft OF ONE STEAli GENERATOR The transients resulting from the malfunction of one steam generator were analyzed for Cycle 4 to determine the initial nargins that nust be maintained by the LCO's such that in conjunction with the RPS (asymmetric . steam generator protective trip) the OflBR 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 COS!!0/W-3 to calculate the DNBR. In addition, the Asymmetric Steam Generator Protective Trip (ASGPT) replaces low steam generator level trip as the prinary 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, it has been determined that the Loss of Load to One Steam Generator (LL/lSG) transier.t 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 asyncetry 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 l is used in the analysis. With this assumed sequence of events, the LL/1SG ; event results in the greatest asynnetry in core inlet temperature distribution ; and the most limiting DNBR for the transients resulting from the mal-function of one steam generator, j 4 The LL/lSG 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/lSG event is 1.42, as compared to the acceptable DNBR limit of 1.23.
_ ~ _ . . . - . . - . . i i 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 durina this transient. This amount of margin is assured by setting the Linear Heat Rate LCO based on the i nore limiting allowable linear heat rate for LOCA. . The event initiated from the extremes of the LCO in conjunction with the ASGPT protective trip will not lead to DNBR or centerline fuel terperatures which exceed the DNBR and centerline to melt design limits. 4 O i l
- O ,
1 i O l i I i 1 l
- O 1
t
- . . _ _ . - - . . _ . ~ . _ . . - . _ . - - - , . . _ - - -_ .
TABLE 7.2.7-1 O 1 KEY PARAliETERS ASSU!1ED Ifl THE ANALYSIS OF LOSS OF LOAD TO OflE STEAfi GEtlERATOR*
" Cycle 4 Parameter Units Cyc e Initial Core Power MWt 2611 2700 Initial Core Inlet Temperature *F 544 549 Initial Reactor Coolant 2200 2225 System Pressure Moderator Temperature ao/*F -2. 5 X10-4 -2.5X10-4 Coefficient Doppler Coefficient 0.85 0.85 Multiplier 9
This event was not analyzed in the FSAR, but was evaluated in CEllPD-199-P (Reference 2). Thus Reference 2 is the Reference Cycle. O O
P 1 4 TABLE 7.2.7-2 SEQUENCE OF EVENTS FOP. LOSS OF LOAD TO ONE STEAtt GEilERATOR i 1 Time (sec) Event Setooint or Value O.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 4 generator l 3.0 ASGPT signal generates signal to open - -
- dupp and bypass valves to condenser
- and to trip turbine 3.4 Trip Breakers open 3.9 CEAs begin to drop into core - -
i 6.0 Minimum DNBR occurs 1.42 9.6 Maximum staam generator pressure 1063 psia 1 i
- ASGPT - Asymmetric Steam Generator Protection Trip J
4 O iO
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- 50 - -
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t 0 I I I ' ' ' ' ' ' i 0 40 80 120 160 200 TIME, SECONDS g ll; 1 LOSS OF LOADIISTEAM GENERATOR EVENT Figure FLORIDA POWER & l.IGHT CO, St. Lucie Plant CORE POWER vs TIME 7.2.7-1
O 120 , , , , i i i i i 1% q - O s
*w 8
m 8 x- 60 5 u O G@ m 8 a 20 - - I I I I I ' ' ' ' 0 O 0 40 80 TIME, SECONDS 120 160 200 O Fl.ORIDA LOSS OF LOADl1 STEAM GENERATOR EVENT "S** POWER & LI HT CO, CORE AVERAGE HEAT FLUX vs TIME 7.2.7-2
g i i i I i i I I I I 2200 - O y 2100 - - G c. EE i 5 2000 - - l to E C
" 1900 - -
h!. l 1800 - - i i l ! I I I I I I I I 1700 40 O 80 120 160 200 TIME, SECONDS l FLORIDA LOSS OF LOADl1 STEAM GENERATOR EVENT Figure POWER & LIGHT CO. St. Lucie Plant REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.2.7-3
O 620 ; i i i
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i i i I 600 - O E-9 vi
$580 - ~
H T AVERAGE ' b s W 560 - - 0 O cc T OUTLET 540 - - T s INLET I I I I I I I I I 520 0 40 80 120 160 200 TIME, SECONDS O . l l lO ,1.ogtg4 POWER & t.IGHT CO. LOSS OF LOADI1 SEAM GENERATOR EVENT
. REACTOR COOLANT SYSEM TEMPERATURE vs TIME Figure 7.2.7-4 St. Lucie Plant
1100 ,- , , , , , , , , g ; IC.ic h - . 1000 -- - g
- AFFECTED SG
& 950, - l g _
u a 8
$ 900 - -
5 . s Si ' g 850 ' - UNAFFECTED SG m : 800 - _ l l l I I I ' I I I I 750 0 40 80 120 160 200 TIME, SECONDS 1 I FLORIDA LOSS OF LOADl1 STEAM GENERATOR EVENT Figwe O1 POWER & LIGHT CO. St. Lucie Plant STEAM GENERATOR PRESSURE vs TIME 7.2.7-5
. . . .. - . . . . - = .. - . ..._ - , - . . . - . - .-_ - - - . - . . - . _ _ _ _
i 1
- 7.3 ' POSTULATED ACCIDENTS i l
! The eventt 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. ., 4 ihe following sections present the results of the .al yses. O i 4 O
- O lO 4
,,w e ~~> m .
_...___._..-s_. _ . . __ _ _ _. _ .___. .. _ _ _ ,. . _ _ . _ _ _
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 this 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 O these key parameters, selected to add conservatism, the procedure outlined in Figura 2.1 cf Reference 8 is then used to determine the average and centerline enthalpies in the hattest 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 valu?s 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 B0C moderator temperature coefficient of +0.5X10-4ao/ F was used because a positive MTC 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 Overpcwer trip is conservatively ; assumed to initiate at 25% (15% + 10% uncertainty) of 2700 MWt and terminates ! the event. 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. l l 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. '
1 i
- The results of the two CEA ejection ca;r- analyzed (Table 7.3.1-2) show l e that the maximum total energy depositea during the event is less than i the criterion for clad damage (i.e., 200 cal /gm). Also, an acceptably
, small fraction of the fuel reaches the incipient centerline melt threshold. j Consequently, no fuel pin failures occur. , I !O : O I i l I 4 ,O F
- .O
TABLE 7.3.1-1 KEY PARAMETERS ASSUMED IN THE CEA EJECTION ANALYSES Reference Cycle Parameter Units Cycle 3 Cycle 4 , Full Power Core Power Level itWt 2754 2754 Cora Average Linear Heat KW/ft 6.29 6.43 G:neration Rate at 2754 M!it
~4 Moderator Tenperature 10 ap/*F +.5 +.5 Co:fficient Ejected CEA llorth %Ao .29 .31 Oslayed Neutron Fraction, S .0047 .0044 Post-Ejected Radial Power Peak 3.6 3.6 !
Axial Power Peak 1.39 1.35** CEA Bank llarth at Trip %Ao -3.0 -3.0
+
Tilt Allowance 1.03 - Doppler liultiplier 0.85 0.85 Zero Power Cora Power Level felt 1.0 1.0 Ejected CEA tlorth %Ao .65 .63 Post-Ejected Radial Power Peak 8.34 9.40 Axial Power Peak 1.59 1.75 CEA Bank llorth at Tng %Ao -1.47 -1.50 Tilt Allowance 1.10 1.10 CEA Drop Time
- Doppler fiultiplier 0.85 0.85 i
- See Table 7-2. '
- The axial peak has decreased because the axial shape index band has decreased.
+
Included in Ff limits stated in Table 7.2. - O
J TABLE 7.3.1-2 CEA EJECTION EVENT RESULTS Reference Cycle Cycle 3 Cycle 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
;O Pellet (cal /gm) 0 Fraction of Rods that Suffer Clad Damage 0 (average Enthalpy 1 200 cal /gm)
Fraction of Fuel Having at least Incipient .028 .040 Centerline Melting (Centerline Enthalpy 1250 cal /gm) Fraction of Fuel Having a Fully Molten Center- 0 0 line Condition (Centerline Enthalpy 1 310 cal /gm) Reference Cycle O. Zero Power Cycle 3 Cycle 4 Total Average Enthalpy of Hottest Fuel Pellet 186.0 140.0 (cal /gm)
, Total Centerline Enthalpy of Hottest Fuel 209.5 218.0 Pellet (cal /gm)
Fraction of Rods that Suffer Clad Damage 0 4 (Average Enthalpy 1 200 cal /gm) Fraction of Fuel Having at least Incipient 0 0 Centerline Melting (Centerline Enthalpy 1250 cal /gm) l Fraction of Fuel Having a Fully Molten Centerline 0 0 Condition (Centerline Enthalpy 1310 cal /gn) !O
-----m- . - - - - - .- - . - - - - - . -- - - - , - , . - . - , . , , . . , ,
O' FULL POWER 3.0 -l a n 2 8 Er M5 2 2.0 - S i. G t e . u a w 3 O i o ; a i E - o 1.0 - u - I O' 0 ' ' ' ' O 1. 0 2.0 3. 0 4. 0 5.0 TIME, SECONDS Ft.ORIDA Figure POWER & LIGHT CO. CEA EJECTION EVENT sr. Luci. Pront , CORE POWER vs TIME 7.3.1-1 j 1
l l i l O I I I I ZERO POWER 10.0 - O g - _ 8 E - - u-o 2 o
;: 1. O _-- -
O - 4 . O e g n.a 3 - o a- - N o - O 0.1 - - o : O.03 ' ' ' 0 1.0 2. 0 3.0 4.0 5.0 TIME, SECONDS i l l , - .. i l - FLORIDA "9** l
\ POWER & LIGHT CO. CEA EJECTION EVENT j St. Lucie Plant CORE POWER vs TIME 7. 3.1-2 ;
I
-- -- -. . ._ -. .. _ _ - .. - _ - _ . . _ _ . . ._A
l 7.3.2 STEAM LINE RUPTURE EVEffT 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 reactnr core region. The analysis of the Steam Line Rupture event was performed with the - methodology reported in the FSAR. The three iteam line rupture events considered during stretch power operation wer9:
- 1) 2 Loop Full Load - 2754 MWt
- 2) 2 Loop - no load
- 3) 1 Loop - no load The one-loop case for operation at power has not been analyzed since this l1 i
operating condition is precluded by the Technical Specifications (paragraph 3.4.1). The 2-loop no load case analyzed with the associated i j 2-loop Technical Specification requi ed shutdown margin of -4.3%ap is more ' adverse (i.e., closer approach to criticality) than tae 1-loop no load ; case with the associated 1-loop Technical Specification required shutdown margin of -5.1%ap. Consew intly, only the 2-loop no load results are presented. l Two-Loop - 2754 ffWt The Two Loop - 27% MWt case was initiated at the conditions listed in Table 7.3.2-1. The Moderator Temperature Coefficient (tiTC) of reactivity assumed in the analysis corresponds to end of cycle, since this MTC results in the greatest positive reactivity change during the RCS cooldown caused by tne 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 l' versus temperature (i.e., moderator cooldown curve) rather than a ! single value of fiTC 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 itTC of-2.5X10-4c/*F at not full power conditions. The reactivity defect associated with fuel temperature decreases is also based on end of cycle Doppler 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 8 fraction assumed is the maximum absolute E0C value including uncertainties. This is. conservative since it maxinizes the contribution of delayed acutron 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 tiWt) is 6.25%. This
shutdown worth includes an allowance fnr the most reactive CEA being
- s. stuck in the fully withdrawn position during a scram. The analysis y consarvatively assumed that the boron injected from the safety injection i
tank is worth -1.0%Ap per 105 PPli. Table 7.3.2-2 presents the sequence of events for the case initiated at the liniting conditions given in Tab 1'e 7.3.2-1. The reactivity insertion as a function of time is given in Figure 7.3.2-2. As seen from the figure, the Steam Line Rupture event initiated at the maximum allowed power level (2754 tnit) remains at least .064% during the event compared to .43%Ap for Cycle 2. A p subcritical The transient behavior of core pnuer, heat flux RCS pressure, RCS temperatures, and steam generator pressure are prese,nted in Figures 7.3.2-3 to 7.3.2-7. O id Two Loon - No Load The Two'-Loop - no load case was initiated at the conditions given in Table 7.3.2-3. The coderator cooldown cu ~ corresponds to .an initial f1TC of -2.SX10 gve given in Figure 7.3.2-1 ap/*F. The end of cycle liTC was used fur 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 f4'.it case. The minimum CEA shutdown worth available is conservatively ssumed to bc -4.3%Ap. A maximua inverse boron worth of 100 PPil/%Ap was conservatively assumed for the no load case for the time interval subsequent to when the safety injection has been actuated.
- V The :cquence of events for the two-loop no load case is given in Tab?e 7.3.2-4. The reactivity insertion as a function of time is given in Figere 7.3.2-8.
reactivity of .038 The results of the analysis show a peak total
%Ap during the evint in conparison to .12%Ap for the FSAR.
Since the peak total reaccivity is negative, there is no return to pcaer during a two loop-no load Steam Line Rupture event - initiated at zero power for stretch power-long cycle operations. The transient behavior of the core power, core average heat flux, RCS
- pressure, RCS coolant temperatures, and steam generator pressures are presented in Figures 7.3.2-9 to 7.3.2-12.
Conclusirg The results of the full power and zero pow:r Steanline Rupture indicate that the core remains subcritical by .064Mp and 0,038"Ap, respectively. Since there is no return to criticality for both the full cower and zero power cases, the results confirm that the critical heat flux would
.not be exceeded. '
4 Je K% l \ L. .
%ea _ er
l l I O TABLE 7.3.2-1 l KEY PARAftETERS ASSUMED IN THE STEAf1 LINE RUPTURE Af1ALYSIS 2 LOOP - 2754 f1Ht . Reference
- Parameters Units Cycle Cycle 4 Initial Core Power fiWt 2700 2754 Initial Core Coolant Inlet F 544 551 Temperature Initial RCS Pressure psia 2250 2300 Initial Core Mass Flow Rate 0 X10 lbm/hr 116,8 133.8 Initial Steam Generator Pressure psia 841.3 909 Minimum CEA Worth Available %ao -3.2 -6. 2.5 at Trip Doppler fiultiplier 1.15 1.15 floderator Cooldown Curve See Figure 7.3.2-1 See Figure 7.3.2-1 Inverse Boron Worth PPM /%Ao 92 105
~4 Effective MTC X10 F/%Ao -2.2 -2.5 8 fraction (including uncertainty) .0045 .0060 l
l
- Cycle 2 01
. . _ . - - . - . _ _ _ - . _. . - _ = . _ . -. - - - _ . _ _ _ _ _ - _
. . :. . . -- - - b
~
TABLE 7.3.2-2 SEQUEllCE OF EVEllTS FOR STEAti LIttE CREAK IllSIDE i C0llTAltit!EllT UNILC OPEP.ATItiG AT FULL POWER, ' 2 LOOP C0ft0lT10fl5 Time Event . Value
.0.0 Steam Line Break Occurs 1.3
' Low Steam Generator Pressure Alarm Actuated 678 psia 2.3 ,
Steam Generator Low Pressure Trip Signal Generated 578 psia - 3.2 Main Steam Isolation Valves Begin to Close - --- Trip Breakers Open for Trip on Low Steam Generator Pressure i 3.7 Shutdown CEAs Begin to Drop into Reactor Core --- 3.8 Peak Power Resulting from Overshoot Folloaing Reactor Trip 108.4 % of 2710 MWt 3.95 Peak Heat Reactor Trip Flux Resulting from Overshoot Following 102.9 % ] ,9.2 Main Staam Isolation Valves are Closed --- 4 15.7 Pressurizer Empties --- 16.8 - Safety Injection Actuation Signal is Actuated 1578 psia
, 62.1 Ruptured Steam Generator Slows Dry 14.7 psia ! j 65.1 Peak Total Reactivity O
' I
.064 %Ao 65,,6 '
Peak Power Following Reactor Trip ' 16.71; of 2700 MWt l-E e O . D e 6
~
j _ , _ _ _ . _ , _ _ . _ ..,. _ .._, _ __ m-._ ._ .,_ . . _ _ . _ _ . . , , _ _ - _ _ .. . . _ _ _ _ . _ _ . . _ .__ _ _ , . , , .
j O TABLE 7.3.2-3 KEY PARAMETERS ASSUMED IN THE STEAli LIllE RUPTURE AtlALYSIS 2 LOOP - NO LOAD Parameter Units FSAR Cycle 4 1.0 1.0 O fnitial Core Power Level MWt i Iniital Core Coolant Inlet F 532 532 Tencerature Znitial RCS Pressure psia 2250 230 ; Initial Core Mass Flow Rate 0 X10 lbm/hr 118.6 137.2 psia 900 900 Znitial Steam Generator Pressure i Minimum CEA Horth Available %ao -2.45 -4.3 ; at Trip ! I Doppler Multiplier * ,
.85 1.15*
Moderator Cooldown Curve See Figure 7.3.2-1 See Figure 7.3.2-1
?.J,erse Baron Worth PPM /%Ao 87 100 l Effective fiTC X10 F/%ao -2.2 -2.5 S fraction (inc' : ding uncertaintyl .0045 .0060 l
- 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 a since I.
there is no return-to-power the 1.15 Doppler Multiplier is used since i it maximizes the Doppler feedback. O
. 1
. I
()
. TABLE 7.3.2-4 -
SEQUENCE OF EVEllTS FOR ZERO P0llER (fl0 LOAD), 2 LOOP OPERATI0fl FOR A Sta ItiSIDE CottTAlftttEtlT Time Event . Value
~
. 0.0 . Steam Line Rupture occurs l 1.4 Low Steam Generator Pressure Alarn Initiated 678 psia 2.4 Steam Generator low Pressure Signal Generated '578 psia 3.3 Main Steam Isolation Valves Actuation Signal Trip Breakers Open for Trip on Low Steam
- Generator Pre.ssure 3.8 Shutdown CEAs Begin to Orop Into Reactor Core ---
9.3 Main Steam Isolation Valves are Closed --- () 11.3 16.2 Pressurizer Empties Safety Injection Actuation Signal Initiated 1578 psia 1,05.2 Ruptured Steam Generator Blows Dry 14.7. psia 108. 7 Peak Total Reactivity .038%ap 109.4 Peak Power Following Reactor Trip .252 IUt ! e O -
~ ~
( . e e l . I _ , , . , ,_m___. _ . . _ - . _ _ . . - _ _ _ , , , _. - m. . .,_m.,,, m-,. , . ~ . . , ,.y,,, ,.m -n
, 1 7.0 g l l l l
.q 6.0 - -
5.0 - CYClf 4 - FULL POWER O 4.0 - -
- c. CYCLE 2 - FULL POWER g 3.0 CYCLE 4 l -
-ZERO POWER ;
C . E i 2.0 - FSAR - ZERO POWER _ $ i i
- 1. 0 -
i 1 0 - - O f I I I I
-1.0
, 300 350 400 450 500 550 600 l AVERAGE MODERATOR TEMPERATURE, F l FLORIDA STEAM LINE RUPTURE EVENT R S "' $ l "0[,ERwc;.
&L Hlf0. MODERATOR C00LDOWN CURVE 7.3.2-1 l l
O - 2-LOOP FULL LOAD INITIAL CONDITIONS 10 - 1 I I I 8 - O a 6 9 MODERATOR
- 4 -
d DOPPLER E, 2 _ 5 SAFETY INJECTION
$0 O 5 o TOTAL g-2 - -
-4 - _
CEAs
-6 -
O -8 0 40 80 120 160 200 TIME, SECONDS i - l ' ' ~ STEAM LINE RUPTURE EVENT Figure t FLORIDA POWER & UGHT CO. REACTIVITY CHANGES vs TIME 7.3.2-2 St. Lucie Plant I
1 l l l 2-LOOP FULL LOAD INITIAL CONDITIONS 120 - i i i i 110 - - J 100 90 -- - g gg _. - E 8 70 -- - M M5 60 -- - 8 g' 50 -- - 3:: 2 40 u h 8 30 - - i 20 -- - l I, 10 - - I ' ' ' 0 0 40 80 120 160 200 m W TIME, SECONDS FLORIDA STEAM LINE RUPTURE EVENT Figure "Uj7,ER t
&] l]O. CORE POWER vs TIME 7.3. 2-3
O . 2-LOOP FULL LOAD INITIAL CONDITIONS 120 , , , , , ,, i i i 110 - - 5 100 2- - O n - 6 x 90 -- lM 2 a 70 - io 60 - - 50 - b 5 a C@ - - 6I - - 30 E o o 20 - - 10 O o 0 40 80 120 160 200 , TIME, SECONDS lQ Ft.ORIDA STEAM LINE RUPTURE EVENT Figure l POWER & LIGHT CO. CORE AVERAGE HEAT FLUX vs TIME 7.3.2-4 . - - _ ______v v -- -% +- y Mrw
I I O: 2-LOOP FULL LOAD INITIAL CONDITIONS 2400 , , , 5 2000 E G E O 1600 - 0 E s . hi p 1200 I w 5 ! g 800 - - 9 8 6 6 e
. 400 - -
0 120 TIME, SECONDS 160 200 h ' 1 STEAM LINE RUPTURE EVENT Figwe FLORIDA l POWER & LIGHT CO- REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.3.2-5
2-LOOP FULL LOAD INITIAL CONDITIONS . 700 ; ; ; ; 600 T - OUT O T
- e. AVG N 500 _
T IN ie g - E We m E TOUT = CORE OUTLET COOLANT TEMP 300 - TAVG = CORE AVERAGE COOLANT TEMP - TIN = CORE INLET COOLANT TEMP I I I I 200 0 40 80 120 160 200 TIME, SECONDS O O FLORIDA STEAM LINE RUPTURE EVENT Figure LI POyER . H]f0. TEMPERATURE vs TIME 7.3.2-6 l
l
-h 2-LOOP FULL LOAD INITIAL CONDITIONS -
1050 i i i 1 - STEAM' GENERATOR ISOLAED FROM RUPTURE _ 875 s h r g700' - l' 5? ! E g525 t2 5 350 - - h
- E
< Si M GENERATOR WITH
[ R TURED LINE 175 . - 0 80 10 160 200 h , TIME, SECONDS i sl SEAM LINE RUPTURE EVENT Figure FLOR [DA POWER & LIGHT CO. STEAM GENERATOR PRESSURE vs TIME 7.3.2-7 St. b;cie Plant ___n_ - - _ - _ _ _ _ - _
1 l I O - 2-LOOP NO LOAD INITIAL CONDITIONS 6 i i i i . 1 MODERATOR l 4 - O a l 9
" 2 -
vi y DOPPLIR - 50 g SAFETY INJECTION O p o g -2 - TOTAL x CEAs _
. -4 -
I I I I
-6 O
0 40 80 120 160 200 TIME, SECONDS O FLORIDA STEAM LINE RUPTURE EVENT Figure POWER & LIGHT CO. REACTIVITY CHANGES vs TIME 7.3.2-8 Sr. Lucie Plant l
-O 2-LOOP NO LOAD INITIAL CONDITIONS ~
120 , , , i . 110 51% - - d
$90
=
h 5m 3:: o
" 70 - -
-1 a :
[o 60 - - j
- 50 -
I s' d@ - - 9l D w i. I 30 - - E !' O 20 - - l 10 - - l A ' I ' I 0 40 80 120 160 200 $' TIME, SECONDS 1 l l l STEAM LINE RUPTURE EVENT Figure FLORIDA POWER & l.IGHT CO. CORE AVERAGE HEAT FLUX vs TIME 7. 2-9
.t. Lucie Plant
O - i 2-LOOP NO LOAD INITIAL CONDITIONS 2# 1 1 I i : 9 .g
< 2000 -
O E d' 5 1600 - 0 E . 8 - g 1200 - m
@n - -
8 t3 6 m 400 _ _ O 0 0 i 40 80 i i 120 160 i 200 TIME, SECONDS 1 l O Ft.ORIDA STEAM LIlE RUPTURE EVEN risure POWER & t.IGHT CO. REACTOR COOLANT SYSTEM PRESSURE vs TIME 7.3.2-1C St. Luc,ei Plant i
-v ,- --
O 2-LOOP NO LOAD INITIAL CONDITIONS 550 , , TOUT = CORE OUTLET COOLANT TEMP TAVG = CORE AVERAGE COOLANT TEMP 500 - TIN = CORE INLET COOLANT TEMP h T OUT o" T AVG si450 - T E2 IN h 4@ - - cx
- 350 - -
. l I I I I 300 0 40 80 120 160 200 TIME, SECONDS i
STEAM LINE RUPTURE EVENT R"9 FLORIDA POWER & LIGHT CO. St. Lucie Plant E TBMRE vs TIE 7.3.2-11
O - 2-LOOP NO LOAD INITIAL CONDITIONS - 1050 ; i i i , 875 O 5 r i700 - STEAM GENERATOR ISOLATED FROM RUPTURE - 5? O . ^ E m 525 - - -
&?
350 - - E STEAM GENERATOR
@ WITH RUPTURE LINE w
175 I I I I 0 'O o 40 80 I20 TIME, SECONDS I60 200 l O FLORIDA STEAM LINE RUPTURE EVENT R S"' ' PONER & Li HT CO. STEAM GENERATOR PRESSURE vs TIME 7.3.2-12
7.3.3 STEAM GEHERATOR TUBE kUPTURE EVENT O The Steam Generator Tuoc 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 coo: ant transported to the secondary stean 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 maxinizes the primary to secondary leakage. For this event, the acceptable ONBR limit is not exceeded due to the action of the Thermal Margin / Low Pressure (TM/LP) trip which provides a reactor trip to maintain the DNBR 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, j The Thermal fiargin/ Low Pressure trip, with conservative coefficients which } account for the limiting radial and axial peaks, naximum 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 maxinize the coolant transported from the prinary to the i secondary and thus the radioactive steam releases to the atmosphere, the i analysis was performed assuming the reactor does not trip until the minimum setpoint (floor) of the Themal Margin / Low Pressure trip is reached. This prolongs the steam releases to the atmosphere and thus maximizes the site l 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-Energency 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 l heat flux, the RCS pressure, the RCS coolant temperatures, the steam ! generator pressure and the ruptured tube leak rate. l The results of the analysis are that 63,200 lbs, of primary 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 (DEQ I-131) : 5.3X10-3 REM Uhole Body (DEQ XE-133) : 0.06 REM These results compare with the respective values quoted in the FSAR cf 9.8X10 -5 and 0.0344 REM respectively. 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 primary concentration at a core power of 2700 MWt, are significantly below the guidelines of 10CFR100.
i ' l , i I . l TABLE 7.3.3-1 ! KEY PARAL 1ETERS ASSUMED IN THE STEAM GENERATOR TUBE RUPTURE EVENT I l Reference Cycle
- Cycle 4 i j Parameter Units Value Value !
[ Initial Core Power Level MWt 2611 2754 ' !O
- Core Inlet Temperature 'F 544 551 Initial RCS' Pressure psia 2300 2300 l l
6 l Core itass Flow Rate X10 lbm/hr 117.5 133.8 i Initial Steam Gencrator psia 841 810 , Pressure CEA Worth at Trip %Ao -4.8 -4.7
! Moderator Temperature X10~4ao -2.5 -2.5 l
Coefficient i Doppler Multiplier 1.15 1.15 ' 4
- FSAR i
a !O c I
- - . - - - . . - - . . .--.--..-.---,,,---.,...-.n - _ . . - . . - - , . . -
l TABL? 7.3.3-2_ SEQUENCE OF EVENTS FOR THE , STEAff GEllERATOR TUBE RUPTURE EVENT l 1 l l Time (sec) Event Setooint or Value I 0.0 Tube Rupture Occurs -- l 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 tiaximum Steam Generator Pressure 903 psia 552.2 Safety Injection Actuation Signal 1578 psia I Generated ' 554.6 Dunp Valves Close -- 592.6 Bypass Valve Closes -- 1800.0 Operator Initiates Appropriate -- O Action and Begins Cooldown to 325 F 8892.0 RCS Average Temperature 325*F Operation Initia!:s Shutdown Cooling O
-. ~,
1 O TABLE 7.3.3-3 ASSUMPTIONS FOR THE RADIOLOGICAL EVALUATION FOR
' THE STEAM GENERATOR TUBE RUPTURE
, i Cycle 4 l' l = Value Paraneter Units Reactor Coolant System Maximum pCi/gm 1.0 Allowable Concentration (DEQ I-131)j i Stean Generator Maximum Allowable uCi/gm .1 , Concentration (DEQ I-131)l Reactor Coolant System Maximum Allowable uCi/gm 100/E Concentration of Noble Gases (DEQ Xe-133) Stean Generator Partition Factor
* .)
O Air Ejector Partition Factor *
.0005 3
Atmospheric Dispersion Coefficient2 sec/'4 8.55X10-5 3 , Breathing Rate M /sec 3.47X10~4 6 Dose Conversion Factor (I-131) REM /Ci 1.48X10 O Tech Spec limits 2 0 - 2 hour accident condition
- For the FSAR the combined Partition Factor of the Steam Generator and Air Ejector was 2.0X10-6
0 120 i i 110 - - 1M 90 _ i 2:: 80 E i N 70 - - LL. O 60 - - et m' e 40 - - o
" 30 - -
20 - - 10 - ( 0 600 1200 1800 TIME, SECONDS I FLORIDA STEAM GENERATOR TUBE FAILURE EVENT "S" O. POWER & LIGHT CO* sr. Luci pion, CORE POWER vs TIME 7.3.3-1
'O 120 i i i 110 - I 100 - Q g - 90 - hm - 8 70 - - l g
~
N 60 - - if s 6 x 50 - - 0 g o 40 - - 30 - 20 - 10 I ' 0 O 6 TIME, SECONDS 200 1800 FLORIDA STEAM GENERATOR TUBE FAILURE EVENT Rs"* POWER & Li HT CO. CORE AVERAGE HEAT FLUX vs TIME 7.3.3-2
1 O J , 2600 - i , 2400 - - 2200 - - h
< 2000 -
Di
' 1800 - -
Y
- 551600 - -
0 . E 1400 - - 0
- 1200 - -
e ( 1000 800 I I 600 0 600 1200 1800 TIME, SECONDS 1
<1 '
1 I! FLORIDA R S "*
" STEAM GENERATOR TUBE FAILURE EVENT L
l[,ERLucie f- REACTOR COOLANT SYSEM PRESSURE vs TIME 7.3.3-3
mmM 'O 610 , , . OUTET _ 600 O e 590 - g z 580 T AVERAGE - i?
~
[x570 O. h.560 - g T INLET 5 550 <O 8 o 540 - C
- 530 -
520 I I 510 0 600 1200 1800 TIME, SECONDS l I Figure FLORIDA STEAM GENERATOR TUBE FAILURE EVENT
" [,'" &
tuci',IY,In,co. REACTOR C001. ANT SYSTEM TEMPERATURE vs TIME 7.3.3-4
O 910 , i
}
900 - - 890 - - - 5 880 E h g 870 - -
?>
g MO - - E
~
i e 850 - - l f2
& MO - -
C E0 S
$820 810 k 800 -'
0 6 1200 TIME, SECONDS 1800
$l '
t FLORIDA SlEAM GENERATOR TUBE FAILURE EVENT F.igwe G PO ER & l1 5 wc. Hl]O. STEAM GENERATOR PRESSURE vs TIME 7.3.3-5
O P 100 , i i t O 80 - ! S m - 70 - E tx 60 - -
$ 50 -
B@ - - O e 5 30 - - t 5 20 - - 10 - I I 0 O 600 1200 1800 TIME, SECONDS 0 . 'O FLORIDA STEAM GENERATOR TUBE FAILURE EVENT Figur e POWER & LI HT CO. RUPTURED TUBE LEAKAGE RATE vs TIME 7.3.3 4 l l - -- . .- . _. -. _ - _ . - -, __ _ _ , . -. . . _ _ - _ - . .
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 only 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 detennined 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, of- 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). 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 imediately to the asymptotic three pump core flow value of 77.2% of four pump flow. For conservatism in the analysis, it is assured that the flow at the core inlet 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 reactor 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. [See 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 to 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 l peaking factor is taken from a cumulative distribution of the fraction l l l
O of fuel rods with nuclear radial peaking factors in a given range. This yields c distribution of the fraction of pins with a particular DNBR as a function of DNBR. This information is then convoluted with a probability of burnout vs. DNBR to ootain 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 Unit 1, Cycle 3 (Reference 1). The nethods used to analyze the Seized Rotor event are consistent with
/7 the methods previously used and approved for Calvert Cliffs (Reference 15)
(j and Millstone 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 .99". 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 resultino 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. O b)
e, TABLE 7.3.4-1 KEY PARAMETERS ASSUMED Ill SEIZED ROTOR AftALYSIS Parameter Units Cycle 3 Cycle 4 fnitial Core Power Level MWt 2754 2700* Core Inlet Coolant Temperature *F 544 549* 6 4 Pump Core tiass Flow Rate 10 1bm/hr 134.9 138.3* 6 3 Pump Core tiass Flow Rate 101bm/hr 104.1 106.8* i Reactor Coolant System Pressure psia 2200 2225* ! floderator Temperature Coefficient X10~4ao/*F +.5 +.5 l Doppler Coefficient tiultiplier --
.85 .85 CEA Ucrth on Trip %Ao -5.4 -5.6 !
i fntegrated Radial Peaking 1.64 1 .70
- FactorwithTilt;FJ Axial Shape Index .23 .11*
o Uncertainties on these parameters were combined using the methods discussed in Section 7.2 and are consistent with LOF. O l
i I l TABLE 7.3.4-2 I i ! ! SEQUENCE OF EVENTS FOR SEIZFD ROTOR 4 ! Time (Sec) Event Setpoint or Value l 1 ,
- 0.0 Seizure of One Reactor Coolant --
i Pump j 0.0 Low Coolant Flow Signal 93% of Initial 4-pump Flow i Generated t l, 0.65 Trip Breakers Open -- ' ) 1.15 CEAs Begin Dropping into Core -- i ( 3.75 Maximum RCS Pressure, psia 2306 I l : i T l t I s !O 4 1 d
1 I O l 120 . - i i - n 110 -
-100 h -
90 - E 2 % - 8
% 70 -
8 t
- 60 -
d a. 50 -
$l' -
LA.J g 40 o 3; 30- - 20 - 10- - ' t y 0 4 i i 8 i 12 i 16 20 h ' TIME, SECONDS l FLOR!DA - POWER & LIGHT CO. Fiq'ure ; SEIZED ROTOR EVENT ! Sr. Lucie Plant Unit I CORE POWER vs TIME 7.3.4-1
. . _ _ _ __ - i
O 120 , , , , 110 - - O 100 E % - - 1
@~
80 - -
$ 70 - _
e f - 60 - u-g~3 U % 50 - - M M 40 - - 8 30 - - 20 10 - - 0 0 - 0 4 8 12 16 20 TIME, SECONDS l l lO FLORLDA Figure POWER & LIGHT CO. SEIZED ROTOR EVENT sr. Lucie Plant CORE AVERAGE HEAT FLUX vs TIME unit i 7.3.4-2 !
1 l l O i l 2400 , , , , , 1 i 2300 - - O
@ 2200 - _
l y .. 51 m M a. 2100 - _ w a e1 2000 - 1%0 - _ 1800 O i 4 i 8 e 12 i 16 20
$!i TIME, SECONDS i
FLORIDA POWER & LIGHT CO. SEIZED ROTOR EVENT Figure G St. Lucie Plant REACTOR SYSTEM PRESSURE vs TIME 7.3.4-3
m e. p * '
- m 7w 4. -,e O
630 , , , , t 620 - - O 610 . 7 0uTi.er - 600 - E-vi 590 - - w g T AVERAGE y sm - - 5 - 570 - - O E 1 g 560 - INLET - o:: 550 540 - - 530 - O 520 0 4 8 12 16 20 i TIME, SECONDS I O FLORIDA Figure POWER & LIGHT CO. SEIZED ROTOR EVENT St. Lgcie
, , Plan' REACTOR COOLANT SYSTEM TEMPERATURES vs TIME 7.3.4-4
i I REFERENCES
- 1. Letter, Robert E. Uhrig, (FP&L) 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 tiethodology," April,1976. --
- 3. CEllPD-98, "C0AST Code Description," April, 1973.
Sys e , dp 74
- 5. CEflPD-161-P, " TORC Code - A Computer Code for Determining the Themal fiargin 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, (FP&L) to Victor Stello (NRC), dated March 22, 1978, "St. Lucie Unit 1 Docket No. 50-335 Prooosal Arendment to Facility Operating License DPR-67". i
- 8. CENPD-190A, "CEA Ejection, C-E Method for Control Element Assembly )
Ejection," July, 1976. I
- 9. GEMP-482, H. C. Brassfield, et. al., "Recomendeo 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 U0 2
'" #P"II' 1968. .
- 10. Idaho Nuclear Corporation, tienthly Report, Ny-123-69, October,1969. i
- 11. Idaho Nuclear Corporation, fionthly Report, Hai-127-70, fiarch,1970. l
- 12. CEflPD-183, "C-E fiethods for loss of Flow Analysis," July,1975.
- 13. CEft-126 (F)-P, "CEAU, liethod 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 (BG&E), 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 flo. 50-336, DPR-65.
O l
SECTI0ri O.0_ . St. Lucie Unit 1 Cycle 4 Large Break LOCA ECCS Perfonnance Resules .
~
i 1.0 IttTR000Citor: Arto SUt4 MARY A large break loss-of-coolant accident ECCS perfonnance evaluation for St. Cycle 4, presented herein demonstrates confonnance with the Acceptance Cr III. Conformance is for Light-Water-Cooled Reactors as presented in 10CFR50.46 The evaluation demonstrates acceptable ECCS perfonnan.ca summarized in Section 4.0. for St. Lucie 1 during Cycle 4 at a reactor power level of 2754 Mwe and ' The nethod of a peak linear heat generati0n rate (PLHGR) of 15.0 kw/f t. analysis and results are presented in the following sections. 5 2.0 METil00 0F Ai!ALYS[5 the flRC approved C-E The calculations perfonned for this evaluation used p Large Break Evaluation Model which is described in References 2 through S. V Blowdcwn, refill /reflood, and temperature calculations were perfonned to incorporate the Cycle 4 fuel characteristics and reactor power level of l The blowdcwn hydraulic 2754 Mwe into the CCCS perfonnance evaluation. calculations were performed with the CEFLASH-4A(4) code while the refill / reflood hydraulic calculations were perfonned with the CCHPERC-II(5) The hot rod clad temperature and clad oxidation calculations were performed with the STRIKIft-(((0) and PARCH $0) codes. Core wide clad oxidation calculations were also performed in this analysis, i O The ECCS analysis assumptions are the same as those stated in Reference 9. The core and system parameters which differ frem the previous ana are shown in Table Al which is consistent with the PLHGR of 15.0 kw/f I The containnent parameters pertinent to this analysis are listed in Table A2. . P
-y , . , - - _ - - , . ,.. .-. _ - ~- ,
- 3 . All possible break' locations are considered in a LOCA analysis.
It was demonstrated in Reference 2 that ruptures in the cold leg pump discharge location prcduce 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 perfonned for the cold leg pump discharge breaks for both guillotine and slot breaks over a range of break sizes from 5.89 f2t to twice the flow area of the cold leg. 3.0 RESULTS 9 Included in the Cycle 4 chre are 88 fresh Batch F fuel assenblies, along with previously irradiated assemblies: 68 Batch E assemblies, 60 Batch 0 assemolies and one Batch C assembly. Burnup' dependent calculations for the various fuel types
.were performed with the FATES (7) and STRIKIN-II(6) codes. The results denon-strated that the most limiting fuel rod during Cycle 4 operation is a rod in dne of the partially depleted Batch E assemblies retained fecm Cycl'e 3'.
For the limiting Batch E assenoly rod, clad rupture was predicted to occur . during the reflood period. As a consequence this analysis was performed at the time of minimum fuel-clad gap conductance, when the fuel stored energy is , at a maximum. The fuel pin pressure was not nign encugh to cause rupture j during bicwdown for any break size. Therefore, all break sizes were analy:ed ;
.at the time of maximum fuel stored energy. .
h The break spectrum analysis described 'in Section 2.0 was performed for tne limiting Gatch E assembly rod. It was determined fecm this analysis that the allowable peak linear neat generation rate (PLHGR) for tne E assenoly rod is 15.0 kw/f t with the limiting break size identified as the 1.0 DEG/PO' break. I 1 c0EG/p0 = Ocuble-Eitded Guillotine a: Pinnp Oischarge . {
7 ~\ The 1.0 OEG/PO break produced the highest peak clad temperature (2176'F) and ( -)
, the highest local clad oxidation percentage (<l6.0%). The 1.0 DEG/PO also resulted in the highest core wide clad oxidation which was less than
. 0.74%. The plHGR of 15.0 kw/f t is therefore demonstrated to be an acceptable
~
limit for Cycle 4 operation. *
- n m
.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 summary of the peak clad tenperatures and oxidation percentages for the- break spectrum. Table A5 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 DEG/PO break). Mass and energy release to the containment during bicwdewa is presented in Table A7 for the worst break. Also presented in this table i's the steam expulsion data during reflood. Figure A7 shews the peak clad tem-perature plottad versus break size and type, demonstrating that the worst break is the 1.0 DEG/PO rupture. The ECC water spillage and containment spray ficw rates are presented graphically in Figure A8.
4.0 CONCLUSION
(~'T The results of the ECCS performance evaluation for St. Lucie 1, Cycle 4 demonstrated a peak clad temperature o'f 2176'F, a peak local clad oxidation percentage of less than 16.0% and a peak core wide clad oxidation cercantage of less than 0.74%. The acceptance criteria are, respectively, 2200*F,17.0% and 1.0%.
~
Based on these ECCS performance results, it is concluded that cperation of St. Lucie I at a reactor power level of 2754 Mwt and a PLHGR of 15.0 kw/ft is acceptable for Cycle 4. 1 (<- 1
-d.
. l 1
b
e 5.0 CCMPUTER CODE VERSI0ft ICErlTIFICATICit The following itRC approved code verstor.? were used in this analysis: CEFl. ASH-4A Version 76041 COMPERC-II . Version 75097 STRIKI!1-II Version 77036 PARCH Version 77004 O t e e e 9 g 8- 9 e 9 C .
~
G. l a e ! L .
. ~ 1. -
6.0 References -
- 1. Acceptance Criteria for Ericrgency Core Cooling Systems (ci Light-t:ater
~
j Cooled fluelear Power Reactors, Federal Register, Vol. 39, !!o. 3 -
~
Friday, January 4,1974 ,
- 2. CEllPD-132, " Calculative Methods for the CE Large Break LOCA Evaluation Model". August 1974 (Proprietary).
CEllPD-132, Supplement 1, "tlpdated Calculative Methods for the CE Large-O Break LOCA Evaluation itadel", Occamber 1974 (Proprietary).
- 3. CENPD-132, Supplement 2, " Calculational f!cthods for the CE Large Break LOCA Evaluation itadel", July 1975 (Proprietary).
' ~
- 4. CDIPD-133, "CEFLASil-4A, A FORTRAtl IV Digital Computer Program for
~
Reactor Olowdoun Analysis", April 1974 (Proprictary). C CENPD-133, Supplement 2. "CEFLASH-4A, A FORTRAf! IV. Olgital Computer Program for Reactor Blowdown Analysis (f tadt ficatien)", Deccmeer 1974 (Proprietary) . 2
- 5. CEllPD-134, "COliPERC-II, A Program for Emergency Refill-Reflood of the Core", April 1974 (Proprietary).
CENPD-134, Supplement 1, "COMPERC-II, A Program for Emergency defill-Reflood of the Core (Modification)", Occcmber 1974 (Proprietary).
- 6. CStPD-135, "STRIXIrl, A Cylindrical Geometry Fuci Rod lleat Transfer Program April 1974 (Proprietary)."
CENPD-135, Supplement 2, "STRIXIt!-II, A Cylindrical Gecretry Fuel Rod Heat Transfer Program (Modification)", February 1975. ' lC0 - e
9 D**D '3~ VOf
- }flhL o
D CrNPU-135 Supplement 4, "STRIKIll-!!, A Cylindelcal GcuncLry Tuc1 Pod lica t Trans for Program", Augus t l'876 (Proprictary) . CENPD-135, Supplement 5-P, "STRIK!t -II, A Cylindrical Geometry Fuel Rod Heat Transfer Program", April,1977 (Proprietary). -
- 7. CENPD-139, "CE Fuel Ev.aluation flodel", July 1974 (Proprietary).
8 CEllPO-138, and Supplement 1 "PARCll, A FORTRAtt IV Digital Program to Evaluate Pool Boiling, Axial Rod end Coolant Heatuo", February, 1975. . CEtiPO-138, Supplenent 2, " PARCH, A FORTRAN IV Digital Program to
., Evaluate Pool Boiling Axial Rod and Coolant Heatuo*. January,1977. ;
- 9. St. Lucie Nuclear Power Plant Unit 1, Final Safety Analysis Report in ,
Support of Oceket No. 50-335, License No. OPR-67. . G . 9 l t e g
- - ..~_-- . ._._ _
i TABLE Al
~
St. Lucie Unit 1 Cycle 4 Core Parameters Quantity Value 2754 Mwt Core Power Level (102% of flominal) ' Average Linear Heat Rate (102% of flominal) 6.427 ku/ft Peak Linear Heat Generation Rate (PLHGR) 15.0 kw/ft i Core Inlet Temperature 551 F Core Outlet Temperature 602 F 6 SystemFlowRate(total) . 138.9x10 lbm/hr 6 I
~
Core Flow Rate 133.8x10 lbm/hr
- ~
2 Gap Conductance at PLHGR 1602 BTU /hr-f t - F l 0
- Fuel Centerline Tenperature at PLHGR 3538 F U
Fuel Average Temperature at PLHGR 2203 F Hot Rod Gas Pressure 1088 psia ! i Hot Rod Burnup 1522 MWD /MTU l ) l i 3 O 1 b
Table A-2 St. Lucie 1 Cycle 4 Containment Physical Parameters g 6 3 Net Free Volume 2.5111 x 10 Ft Containment Initial Conditions: Ilumidity 100% 0 Containment Temperature 60 F 0 Enclosure Building Temperature 38 F Initial pressure 14.6 psia O Initial Time for: Spray Flow s 25 seconds 0.0 seconds Fans (4) Containment Spray Water: Temperature 55 F Flow Rate (Totar, both pumps) 6750 gpm h FanCoolingCapacity(perfan) Vapor Terroerat'ure (OF ) Capacity (BTU /Sec) 60 0.0 120 3472.0 180 7388.8' 220 11611.1 264 20833.3 Heat Transfer Coefficient
- a. Containment structure to enclosure butiding atmosphere heat transfer coefficient - 13.0 BTU /hr-f t2 ,op, 2
- b. Sump to base slab - 10 BTU /hr-ft _op, 2
- c. Containment atmosphere to sump - 500 BTU /hr-ft oF.
l
L l O O O O O l Table A-2 Continued . St. Lucie 1 Cycle 4 Passive Heat Sink Information t k pCp Thickness Area BTU Rill Exposure Exposure Wall Mzterial Ft Ft2 lir-ft uF -- Ft3OF ' Side 1 Side 2
- 1. Containment Steel .1171 86700 25.9 53.57 Cont. Vapor Annulus Shell
- 2. Floor Slab Concrete 20.0 12682 1,0 34.2 Cont. Vapor Insulate <
]
- 3. Misc. Concrete Concrete 1.5 87751 1.0 34.2 Cont. Vapor Insulate <;
l /. Calvanized Zinc 0.0005833 130000 64.0 40.6 , Cont. Vapor Insulatet Steel Steel 0.01417 25.9 53.57 l
- 5. Carbon Steel 0.03125 25000 30.0 53.8 Cont. Vapor [nsslater l Steel .,
i
.T 6. Stainless Steel 0.0375 22300 9.8 .- 54.0 Cont. Vapor .
Insulatei q ' steel . j /. Misc. Steel Steel 0.0625 40000 25.9 53.57 Cont. Vapor Insulate-l; . Misc. Steel Steel 0.02083 41700 25.9 53.57 Cont. Vapor Insulate; j 2. Misc. Steel Steel 0.17708 '7000 25.9 53.57 Cont. Vapor Insulate;
)'.:. Imbedded Steel' O 0708 18000 25.9 53.57 Cont. Vapor Insulate' Steel Concrete 7.00 i.0 34.2 k
l - 1 .
.t n * * '
t,,, ; g .
- TABLE A3 _
St. Lucie Unit 1 Cycle 4 ' i ;.*,. TIMES OF INTEREST (SECONDS) I$ START OF TIME OF ANNULUS CONTACT TIME SAFETY BREAK- SAFETY INJECTION 001IrlFL01l TIllE 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 O.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 e
O O O O -- - - O
O O O O O TABLE A4 ' i: St. Lucie Unit 1 Cycle 4
- j f Hot Rod Pupture Peak Local Core-Wide
- Break Peak Clad Temperature (OF ) Time (sec) Clad 0xidation(%) Clad 0xidation (%)
2174 52.13 < 15.33 < .72 - 1.0 x DES /PD 0.8 x DES /PD 2173 53.52 < 15.26 * .70 2161 59.89 < 14.62 < .65. 0.6 x DES /PD* , 2176 51.24 < 15.44 < .74 1.0 x DEG/PD l 0.8 x DEG/PD 2175 52.13 < 15.36 < .74 1 0.6 x DEG/PD* 2057 61.8 < 14.16 < .61 P, i . -} . 2 4 A 4 e m , g .+ 1
. Table A5 .
St. Lucie Unit 1 Cycle 4 , Variables Plotted as a Function of Time for Each large Break in the Spectrum - Figure Variable Designation CorePoder . . . . , .. .. . -.
., .. , . ,.,. . _ . ., . , .,4.;. :. .. . A . ..- . ',]
Pressure in Center llot Assembly liode B 3 W C Leal: Flow .
!!ct Assembly Flow (below hot spot) . D.1 Ifot Assembly Flow (above hot spot) .
D.2
!!ot Assembly quality E .
Containc.:ent Pressure F
ass Added to Core During P.cflood G Pcak C1ad T::.::rature -
. . H .h
. .s .
~ ' '
. D**D *D T .
1 J.\ oo 6 ' a .
- e I
1 l l ;
,.,...._,...w.v.=wwr-_
Table A6 St. Lucie Unit 1 Cycle 4 , p U Additional Variables Plotted as a Function of Time for the Large Break Having l the Highest Clad Temperature , l Figure Designation
! Variables ,
Mid Annulus Flow
~ '
fJ
~
o O . ceeiit4es ^8 eve eed Beiew the Cere :
- K Core Pressure Drop .
L Safety Injection Tank Flow into Intact Discharge Legs Water Level in Downcemer During Reflood M N Hot Spot Gap Conductance Peak Local Clad-0xidation-
.' O Clad Tenperature, Centerline Fuel -Temperature', Average O
P Fuel Temperature and Coolant Temperature for Hottest !; ode Hot Spot Hdat Transfer Coefficient Q R Con.tainment Te:r.perature S Sump Temperature l ' T Hot Rod' Internal Gas Pressure , U Core Bulk Channel Flow Rate e N
~
I _ - - _ w ' e= _ , - , - , _ . . _ . .
TABLE A7 )'- i l l l INTEGRAL OF INTEGRAL OF_ _ TIME MASS FLOW ENERGY RELEASE MASS FLOW ENERGY RELEASE
~~ 'd SEC LBl1/SEC BTU /SEC ~~LBM~ i ~ ~ BTU ~ -
d i i , i ,
; ! ! i l i i l
L i.e.o s.o 4.0 s.O i vis t i 6 ___ _ i
! ! --- I-- l
! o.ar 7./e6..uo
- 3.88o 9 xao ' 3.s994.x zo ' A 1.17ov h o '
i j ! l
.L_L slo 8./487 4142.t . 14181 x.io ' '4/89L' 1 At.d 7Jord I 42929 s. slf/_ 20- LJ Bd_o i Y azo tw Niss7l u f9_8 I
& #235 a' 1
! i ! i i l '
jaf '9.1988 ;dD1 H ; 1/ 94/9 I .J A 3hJo'
! i i i ox L/_f3/ 'JJ2Bo ' j4A_7Ao l l/4538' .-
i I I l i !
; p.16 Loza::1 J. 824_4 I
IJ.JA3Y ' A 8tl$dl ! 1 i
! ! I i i l l
%o 6Aow 'L2s2s
. l4429s ' 2Aaa' i l
- I l ! l L. sc Bo 4.1sM4 {J MBS '& 9329l l Jas.z.99.!_-- I D NAo i
l A c29s z.66s3 i 2 a.21 ' i i s.frA9 l I h i ss! I dJB26 a.JBdf f.s4Jo_A_zo 4 '42488_L i l48 f.1330 p.24/9 l/ 2 ads _jo d 2.c]3Y . il I I i j i
'IA2 4 91s8 l;s2893l !
A 4.2 8 f 9._20/4 - T l t I l r I
- 2. 4 ]f0377 i
, xzt93 ;
. l4.43sz! .
i
/As3s.Lxto '-
i l i I i 1 i t 8 ' a.o ' 4d/24_ _ l24612 A B3LL ' ' Aso/s_i> 2a ' I i I
! i l 1 I,.- 2a.d :42904. _ ' A344L tLaof7' !^s198 .L J.3.__.Y0930 2,.2 s i s 2.124o A.zft7 _' Y f1
' ! i I.
i : A 4 4 -.- G..J993 210 70 L . .2dd80.! 432o8.L
! l ! l l l l )
.- ' Lda--.. d.Jo38. IA 99/0 '
' t
;2 4887_._
- ' Af794 ' '
l .
! l i
_ J.o . . . . . . J. 00/d. . __. . iAJf34 f JJ398 _._. I A4246 I I i i i
- 2. 797L l44.3f8 ' 13.j))d !
L. .i 4. 8 . Aff92 i l l l 1
- 86 .2.dJ/3 IAdofoj ; J.J8V3. '/._88J4
.84 .. 2.30Af.....Y. _i/.39d1 __ i J.Jyp i. _ 2.00/3 _ L. ._l . __ _ _ _ _
- 9s_ -..r.oss4.uo 4 l/.as 76.]x so ' Y.rsss. /os N2. iorf\x /o ' .-
i i . ; a i i I 3 l l
l l l TABLE A7 (CONT' D)_
~ '
~~ -
'~INTEGRAE OF ~ INTEGRAL OF~~~~~
,, TIME MASS FLOW ENERGY RELEASE ~ ~- MASS FLOW ENERGY RELEASE~~--~ ~ ~--
LBM ~ ~ -- " ii SEC -- LBM/SEC ~ ~ ~~ ~ BTU /SEC BTU
, j !
, 4 i i
/$. 0- /B2dz x.jo! : A /493 x./o ' ~.! 9/d4,.x./0 # L 2 01/ U /0
'4 C A.47881/o 9 6873 x so # 4 04 3.2. '
'L3d_2O
? l
-.- $ /4 6 A d728..x /0 -
# .8,/BB9 4./483' 'L3921 rm '
i l j N. u - b A1.6 '
- 2. 9.! ?2 X/2Lo M2SS.9 ~ '2613Y /
- ; i , , , .
i tdo ' 4 A 78 !4,.0Y87 ' 43268I 2.3J.96 ' .-- 3 i i l 1 ]i&D 4J.712- i4 82/8 ;4 .1.72D ' ' 2_ 4 2 4 / l t I I l l2.432/l
-i.24.0 l L3797 '
. l'. LA24d' 4.MtJ3 ' -.
' I i i i I L L7;& -U397 LJ.D8df 4M437 ' 2a42/d*;
l I ! i i i l l i 8.0 :/ 244Y Y I1. /Joo ' 'V '44682 14.980' F' i i i l Y9 R---. A/.94 6-.xJC3 44638 LO # {4 482f 421_49 g i .
- l
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- dBo.2dxjof '4dfta i
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.2.7253_w_-.i
- i i l 2DA! ---LAZ/$4)./0' ;/ J&2BY/0 # '< / 493ixzo d jd2$_dlx/o A I 6 ! i i.t I -
l TIME OF ANNULUS DOWNFLOW i l l : ! i j l l ,- ! START OF:REFLOOD (VALUES BELOW ARE FOR STEAM ONLY) m r l 8 h I i i ! i I I !
, i j l .
l p Jkl di O ;~ f0 N Yf].71X2d$ ' 2 22861 do ? 2 e 1 ; . - ; i
- I i i
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l i' .1JY 7 d,d - di0 ; YYf37 l. A2284 . --
;! I ! !
d 4 7 ..-.. ./. f4 48.x .so ' .2.sJJ3lx jo.' l +ffmo i I
!2 7348.- ,
l, 7Y 7 .-- ..A 9lok .- .232 Y3 , 'Yd/8b
--..,2 I$ //- , -
- i. 8$7. -.-.JA SWOll .-. 12. i d2 Y8 ' Wd]82. I --- . da 78dd. -.- -
1 i 2 f $ 7_ _ l /. $ / o $ . ,2. W840 L $Olf - . J. B//d - .. .-- (m wM 1o i _ p sia _:1_l.r.easo. i
]/sar . :/.e ni. f i y. w.u. ..
.I/>M 7 - y. ed/s' vo L U. 3 $sfx so C 44/3%s ' !.2. s 8 4 3 u o ' L ._
i I i i .
- l i
. . .[ ' . . .t_...
l i i
l TABLE A7 (CONT'0)_ l l
~
~~INifGRAL"0F --"
~ '
" ~
l i l H4TEGRAL 0F l TIME MASS FLOW l ENERGY RELEASE -
' FLOW MASS -" '-
ENERG( RELEASE ~ - LBM BTU i SEC ; LBM/SEC ~~ l - BTV/SEC ] , i i i
-.2dM 7 A 824s..x_/o'- 37s1.x_tod 44 Sol.xsod 2. 9J.2 L.vo #
i i i
..../4 47 A B23.7 2,3 7.24 4 4844 '2.9294
; i i ! i !'
I
/A&f A8271 J.3772 ? f22J / ' !3.02 20
! i
; 1.2o47 A.822.7 437t_3 42d97 310214 &
r !2247 s.84.zB ls.192f1 i 42fdf a.122d j j i 6 I I i
) ' l ~ i 1_74.42._18428 ;Mz3s! ! +'B3361 '. 2.22c4 ' i k sta y /. 9/89 2 2fts' 4' Bio 7 a .1 d o i l i l I < !
l l l ' I .7ff? 48.819 '2.4f23' l 4 908/ l
!<3. 1 4 7 7 \
b,&7 !JfAz ius9}l l 4 .94f7 als y l l i : i' ;334dBl-a.7_f7 :/.9922 l2.479'r l 4 9B36' 0 iafdy /.fato lM13L1.l lds_2/Y !s.<tss i l c a
, ,s. d 7 Lso17 \
i i
%si.9l i I load i
!.ueN i i I
i Y6d2 ' A fl2d ' \J.cV9_26[ d'a977 ! ' 7,d*/N ' I YsY 7 A 909 i M8d/ V d_,*j_340 1 3. Add 2 Y i i < i i '
, i I i
, ;-40 Y 7 ' A 9).Z2 Lo * ' 2. .-12cw_o 5 'af/f)7 l uc7 W 'a tJJff__Lk' 20 8
- l l i I l l l l i i i i
! l l f
! ! h I - -
- . ! . i i
, -- t e
' I
' k a
' l l i ! I. l
~ T i
U t l l l 1 f
! I l m-
~
. . _ . . . - _ . s _. _ _ . . .. _
! ! l [ ,
! l I I
. . L . __.__ _ u I !
i > f ' '
-~ - =- :
u .x = - :- n .. _. -
..._. .. c - . .
O ' FIGURE I.1-A
- ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG CORE POWER iO 1 2001 i 1 0000 i
i 8000 . Tu i l' l o$ - g 6000
' $5~
i i
.4000 k
2000 l
\
l 0.00000 o o a o o l a o o o a o ' i o a e o a o . R R R R R R o - N M v LO TIME, SECONDS
i FIGURE I.1-B G, ST LUCIE UNIT I STRETCH POWER 1,0 x 000BLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG _ _ PRESSURE _Ifl CEtlTER HOT ASSEMBLY N0DE 2400 0
..._.._-___1._.
h I 2000.0 . 1600.0
&l' G
W W 1200 0 5-
=
N . n m 800.0 -- s i b _ i O 400 0 s 0
-m >
0.O g a g a
- 8. _ _. . .g_ _. - _ g- __.___g o g o
C a L N 4 g TIME, SECONDS
,w--- , ----
.1 R
1 O eiGuRe 1.1-C ' i ST LUCIE UNIT I STRETCH POWER
- 1.0 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG LEAK FLOW 120000 100000 80000 NM 60000 -
B-a' 40000 O ! 20000 , O. o- o 8 8 8 8 o o o o o o o a . . . . i i
.O o .
TIME, SECONDS i
,,.----,.-.--,------------,---------,,,-----.--,.--.--~.---+,-.-,--.,.,---,,,,.--r., ~ , ~
FIGURE I.1-D.1 ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 16, BELOW HOT SPOT 30 000 h t I 20.000 - 10.000 $ l O B %h W' 0.000 , j f
-10.000 4 /
~
O
-20 000 -
j< l
-30.000l g g g g l
8 8 8 8 8 8 9 o 9 o a a a m a a O TIME, SECONDS
- O ~
I FIGURE I.1-D.'2 ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG i FLOW IN HOT ASSEMBLY-PATH 17, AB0VE HOT SPOT _ 30.000 i , l l 20.000 10 000 'Q a \ i i 8 s i
%A 0.000 I
-10 000 s
/
/
lO
-20.000
-30.000- a g i
C) 8 e 8 e 8 . 8 . 8. 8. E a S S S $ TIME, SECONDS
FIGURE I.1-E g ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG HOT ASSEMBLY QUALITY N0DE 13, BELOW HOT SPOT
----- N0DE 14, AT HOT SPOT h
- - - N0DE 15, AB0VE HOT SPOT 1.0 ;
, i ,! lq l i, i , , ,
3 b \ ', I . { ', Ov l ! ' hY <
~
i l
,\'
i
'\ . ' , '/ .'
Oii 0.6 -! .- .s C l . / . D j i n ./ 8' - s i I i / 0.4 -i g ,c - i V 0.2 i I h l J I 0.0 0.0 5.0 10.0 15.0 20.0 25.0 TIME, SECONDS h
FIGURE I.1-F O ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED SLOT-BREAK IN PUMP DISCHARGE LEG CONTAINMENT PRESSURE i I i 6G.000 , O ' 50.000 40 000 h 30.000 N - E en - W '20 000 o_ O- 10.000 , ;
, @ 8 y 8 8 o
-8 8 m
8 8 8
- en ,, m TIME AFTER RUPTURE, SECONDS I l
l
' -- - ~
- - , . . . ^*
- _ _ -L- _ - _ . ..:-.--_. _ . , - 1
FIGURE I.1-G ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG i _ _ _ . MASS ADDED T0_ CO.RE DURI_NG_ REFL.00D .._ ___
;20000
, g i
10000c. en 80000
!! o-
=
g 60C00 / 8 M g . . 40C00 ' 20000. e a a 8 8 8 8 8
.-. w m v m TIME AFTER CONTACT, SECONDS l
" ' ~ ~
. FIGURE I.1-H ST LUCIE UNIT I STRETCH POWER
'1.0 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG O PEAK CLAD TEMPERATURE . . . . . . .
2200 . 2000
/ \ N
. O
/
/ N x 1800 -
1600 - g- . C-1400 Pa
~
j , 5
~
~ ,
i
~
a
< 'l d 1200 i 'O 1000 800
- O 600
! 0 100 200 300 400 500 600 7 4
i I TIME, SEC0t!DS _ =- _ . _ _ .. .
- . - . = . - - . . - - .
O FIGURE I.2-A ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG CORE POWER O 1 2001 1.0000 8GGG 5 5 a_ g .6G00 R
.4000 f 9\l 2GGG G . G C GQ) o o a a a
?
a .- ~ m . ,., TIME, SECONDS
O riGuRe 1.2-B ST LUCIE UNIT I STRETCH POWER , 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG PRESSURE IN CENTER HOT ASSEMBLY N0DE O 2400.0 i 2000.0 1600 0 O G o_ d 5 '200'0 a.
\
800 0 - O 400 0 i
\
\
O :a :a ie ie ia W r. TIME, SECONDS
- am,, m - - - - - - , - - - , - r -
g - ,--,
i O l FlGURE I.2-C ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG LEAK FLOW 120000 100000
$ 80000 g W
2 h 5 60000 5 cd 40000
\
O 20000 s 2 g 6 a S 8 1 TIME, SECONDS
O eisuaE 1.2-D.1 ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 16, BELOW HOT SPOT iQ . 30 000
~
20 000 in , u 10 000 f , s
? &
d 0 000 1 3
"~
-10 000
\\ /
0 --
-20 000
-30.000 o a a a 8 8 8 8 8 8 O : 9 m s s s s TIME, SECONDS
O FIGURE I.2-D.2 ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 17, AB0VE HOT SPOT 30.300 20 000 i g R. 10 000 ;
- l. .
g m
\
0.000( )y . [i
-10.000 % /
1
-20 000 -30 000 a a o a 8 8 8
8 8 s 8 s d g i TIME, SECONDS
FIGURE I.2-E ST LUCIE UNIT I STRETCH POWER O .8 x D UBLE ENDED SLOT BREAK Ifl PUMP DISCHARGE LEG HOT ASSEMBLY QUALITY O N0DE 13, BELOW HOT SPOT
---- N0DE 14, AT HOT SPOT
- - NODE 15, AB0VE HOT SPOT 1.0 ,
1
.f .
L i 'l li ; i
, i 08 I .L Ov /
i
- \
, j
, / .
O n >
,- j'/
i i , ,- s 9,g . , , ~~< t C !
'sh , ,' '
j
.j .
,/'s..
O.4 , l t .< '
.)
O 0.2 i i i 3 (I l 0.0 l 0.0 5.0 10.0 15.0 20.0 25.0
~
O TIME, SeC0tDS .
1 1 1 l FIGURE I.2-F ST LUCIE UNIT I STRETCH POWER g. 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG CONTAINMENT PRESSURE 60.000 0 50.000 40 000 s T 30.000 N _ R l0 - 2 20 000 O 10.000 ., a 8 8 8 8 8 t 0 - ~ m , m g TIME AFTER RUPTURE, SECONDS 1
l FIGURE I.2-G ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG MASS ADDED TO CORE DURING REFLOOD O : cccc. i i00000 e . j . _.. ui 80000. ' O B S a
$ S0000.
l .. N . l . . - __ 40000 O 20000.
~ ~ ~~
O. O- 8 8 8 m 8 v 8 m 0 - a , l TIME AFTER CONTACT, SECONDS I
~ =. -
FIGURE I.2-H ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG PEAK CLAD TEMPERATURE 22C0 'g lh N 2 0 C O '-
/ N 1800 -
~g 1600 o"- !
1400 ; 5 ; O E I 5 i [1200t-5 4 - U . 1000 1 9 8CC 600 - i l 4UCt_.. I j 0 100 200 300 400 600 600 7C TIME, SECONDS 3
l O eieuaE 1.3-A ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG CORE POWER I
'1.2001- -
4 l'.0000
.8000 i ) 03 o_
g 6000 a;
.4000 0 2000 0.000Q, a a a a a 8 8 8 .8 8 a
8 a a a a a
- b C (b Lb TIME, SECONDS I M' v - . = = .
- -, _-. . ?
~
(- FIGURE I.3-B O ST LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG PRESSURE IN CENTER .n'T ASSEMBLY N0DE 2400.0 g 2000.0 - 1600.0 5 e 9 1200 0 5 \ m E 800.0 400.0
\
0.0 o a o a 8 8 8 8 8 8 3 3 5 5 $ 5 $, TIME, SECONDS l i I wo=, _
-m
. _. . . . _ . --. ~--.._ -._ __
l O FIGURE I.3-C ST LUCIE UNIT I STRETCH POWER i 0.6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG ,
- LEAK FLOW r
i
] 1.20000
! 100000 -- 80000 M i O R d 60000 ; . EE g i d , 40000 O 20000 0 O a O O O o O O O O O O O O O O
^ -
9 a a a a U C u, - - ~ ~ TIME, SECONDS l 1 4 l I i- - . _ . ..
-l
FIGURE I.3-D,1 g ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 16, BELOW HOT SPOT 30.000 - e 20.000 - ll o 10.000 hki ) N H 0.000 5 h
! \,k / fr
-10.000 i
-20.000i
! o i
-30.000 o a a a 8 8 8 8 8 8 N N N k g TIME, SECONDS 1
l I __ -_=r., 3 l
O FIGURE !.3-D.2 ST LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 17, AB0VE HOT SPOT , I '30.000 1 20.000 . i 10.000 O u N s 3 ui -- r 0.000 ' N \
-10.000
\ !
[ l i, -20.000 l .
+
-30 000 o a o a 8 8 8 8 8 8
'Q ) 5 s N N TIME, SECONDS
- _. .______._---m
s 1 FIGURE I.3-E O ST LUCIE UtilT I STRETCH POWER 0.6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG HOT ASSEMBLY QUALITY N0DE 13, BELOW HOT SPOT
---- N0DE 14, AT HOT SPOT
- - NODE 15, AB0VE HOT SPOT 1.0 ,. l g j-a
.' i 1, .i lj i i' / ii 08- I' !'I ^ I f $ -
j.' ,
.' ,)
' i .i a ~
i !' ,- ,' j k ' ', 2 0.6 .,
/ --
[ .! ' 's
. j f , e !
- s 3 s .
i
/
i .- i 0 . 11 i i'
; V
.i
! o2 l e
! l 1
e f d O 0. 0 '0 5.0 10.0 15.0 20.0 25.0 TIME, SECONDS e
's
~4g
/
U FIGURE I.3-F ST LUCIE UNIT I STRETCH POWER 0,6 x DOUBLE ENDED SLOT BREAK IN PUMP DISCHARGE LEG CONTAINMENT PRESSURE 60.000 , (ms' I e 50 000 40 000 C's . U g E
, 30.000
=,
u _
.O E
20 000 g G - 10.000
.S S S S S g
8 8 8 8 8 m w l
$ o - m y l
TIME AFTER RUPTURE, SECONDS w- _ ,
^~
FIGURE I.3-G ST LUCIE UtlIT I STRETCH POWER 0,6 x DOUBLE ENDED SLOT BREAK Ifl PUMP DISCHARGE LEG MASS ADDED TO CORE DURIfiG REFLOOD
;20000 ,
100000 m 80000 B - - a 60000, a w O .. . _ . . .- .. - . . .. _ _ . . - 8 / m 40000 f
$ [ '
e 20000 a k k k k k o 8 8
~
8 m 8 8 to
$11 TIME AFTER CONTACT, SECONDS l
FIGURE I.3-H ST LUCIE Ut1IT I STRETCH POWER 0.6 x DOUBLE ENDED SLOT BREAK Ill PUMP DISCHARGE LE PEAK CLAD TEMPERATURE (m ;200 N N
/ x' 2000 -
i
\ -
s v .1800 1600 : O N= E1400 hP f a 51200 l W 100c v 800 - j I 600 --
\%/
100 _. . __. 600 70 0 100 200 300 400 SCO TIME, SECONDS
~
FIGURE I,4-A O ST LUCIE UtlIT I STRETCH POWER 1.0 x DOUBLE EtlDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG CORE POWER 1.2001
~
g 1.0000 8000 O es B
] .6000 .
s
'4000 0
2000
\
0 000b o o a o o 8 8 8 8 8 8 o o o o o o a .: a a 4 a O TIME, SECONDS
- --- ~
i FIGURE I.4-B Os ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG PRESSURE IN CENTER HOT ASSEMBLY N0DE , 2400.0 O 2000.0 , 1600.0 ' O $
$ 1200.0 5 \ '
20 ; EE , 8.00.0 s O 400.0 s 0.0 a a a E
. 8 8 8 8 8 8 2 5 E 5 5 O TIME, SECONDS
._- . _ . _ - - ~: r E _
FIGURE I.4-C ST LilCIE UNIT I STRETCH POWER g 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG LEAK ELOW PUMP SIDE REACTOR VESSEL SIDE 120000. , i i i O 100000. - 80000. - M g 60000. - E ! _d t,, 40000. 'N
\ ,
\
20000. -
s, s
g , 'm_& 0. 0.0 5.0 10.0 15.0 20.0 25.0
~
TIME, SECONDS _ _ _ _ ~ _. -- ,
~~
FIGURE I.4-D.1 O ST tuCie unit I staE1CH e0wea 1.0 x DOUBLE EllDED GUILLOTINE dREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 16, BELOW HOT SP01 30.000 'O t
- 20.000 Fd
. 10 000 !j' M R < 5 O i
~d 0.000
~g N x
A/
=
-10 000 Y/y O -20.000
-30.000- a a a e 8 8 8 8 8 8 l ~
2 /> 5 5 5 N !O TIME, SECONDS 9 i
FIGURE I.4-D.2 ST LUCIE UNIT I STRETCH POWER g' 1'O x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 17, AB0VE HOT SPOT
~ ~
30.000 O li 20 000 , 1 10.000 , E s ' O Ad N 0.000 '. I M s l M i ,\/
-10.000!
L/ -
-20.000!
-30.000 g a g g 8 8 8 8 8 8 o m N 5 N N g TIME, SECONDS
-.- - - - - - -_ _ = _.
FIGURE I.4-E O ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG HOT ASSEMBLY 00ALITY O - - - - N0DE 13, BELOW HOT SPOT N0DE 14, AT HOT SPOT N0DE 15, AB0VE HOT SPOT 1.0 j i ,, i g I* I, ' l
; ', l8 n ',
0.8 , G Ie i ) O - i j ii E
,~,
g#
/'/
0.6 i I' ,' / C i A.,'
; (
3 i /
@ s l . /* ~ ~ /
O - / 0.4 ' l. ,_./ - l n! -
, v I
O O.2 , I ' ' ' ' l 0.0 0 5 10 15 20 25 ( TIME, SECONDS
I I i FIGURE I.4-F ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DIUCHARGE LEG CONTAINMENT PRESSURE 60 000 . O 50.000 40.000 5 U m 30.000
'20 000 10.000 8 8 8 8, 8 1 0 - ~ m o g
TIME AFTER RUPTURE, SECONDS l l
. - . . _ - = - - - .
~
FIGURE I.4-G ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCH MASS ADDED TO CORE DURING REFLOOD i O 120000 100000 b g 80000 O. e m O 60000
/
a M 40000
/
O . 20000 a k k k k k O o 8 8 m 8 m 8 y 8 m TIME AFTER CONTACT, SECONDS M---^ mm e *= m A[
FIGURE I.4-H ST LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG PEAK CLAD TEMPERATURE g 2200 i
~N 2000
\ N
/
/
/
\ \ #
1300
!/ \ N s
/ N
/
u_ 1600 t f\\' , G G $ 1400 \b PEAK CLAD TEMPERATURE N0DE [= RUPTURE NODE 4 e ' _J u 1200 h 1000- _ 800 600 0 100 200 300 400 500 600 7i TIf1E, StCONDS
FIGURE I,I4-1 O Sr. tUcie uNir i Sraerca e0Wea 1.0 x DOUBLE ENDED GUILLOTINE BREAK Ill PullP DISCHARGE LEG MID ANNULUS FLOW 15000 iO 10000 ) 5000 I l O 9 pI W 0 e N // 8 < d
-5000 I
4 f ( 'O -10000 c
)
-15000.'d a a a a 8 8 8 8 8 8 2 3 5 5 5 $
lO TIME, SECONDS l
l 1 FIGURE 1,4-J .$' ST. LUCIE UillT I STRETCH POWER 1.0 x DOUBLE Ei'lDEU GUILL0 Title BREAK Ill PUliP DISCHARGE LEG QUALITIES AB0VE A'lD BELOW THE CORE AB0VE THE CORE
- - - - BELOW THE CORE g 1.0 i i ,;,. j gj ,,,. i i ft' l
, i, ,
,' s s O.8 - ' 'v' -
i I i I - 0.6 - C i i 3 i e : Ei' } 8 l 0.4 - ; f f \ l
' \ /
0.2 - s u h f f I 0.0 ' ' ' '
~
O.0 5.0 10.0 15.0 20.0 25.0 Tli1E, SEC0ilDS O
FIGURE I A-K ST, LUCIE UNIT I STRETCH POWER O 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG CORE PRESSURE DROP 30 000 O 20.000 10.000 j V
*j O $
" 0.000 0 n .
Y '
^'(&
? t h td .
8:2
-10.000 -
-20.000
-30 000 er- a a a 8 8 8 8 8 8 3 5 5 5 N 1.
~
TIME, SECONDS l
~
-"' ~
, ______ [. , _ _ . _ . _ _ _ , , _ _ _ , _ _ _ _ _
..~. - . . . ..
~
FIGUREI.4-l. ST. LUCIE UllIT I STRETCH POWER 1.0 x DOUBLE EllDED GUILLOTINE BREAK Ill PUMP DISCHARGE LEG SAFETY IllJECTI0l1 TAllK FL0ll IllTO DISCilARGE LEGS I 8000 i , , , , i i B m . E a 6000 - - u. 8 4000 - - p B
- =
C 2000 - W 0 O. 10. 20, 30. 40. 50. 60. 70. 80. TIME, SEC0iiDS
. . . ....... ~ . . . .
l
L . . l . i lO FIGURE I.4-H ST, LUCIE UNIT I STRETCH POWER l 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUf1P DISCHARGE LEG WATER LEVEL IN DOWNCOMER DURING REFLOOD I 18.000 - l 15.000 i I f - l l s 12 000 !O 1
=
W "j 9.000 m 22 2 6.000 4 0 3 000 l . 0 000 a a a a a O 9 9 9 9 9 C C O O O O
- . A
!U C 8 8 8 TIME AFTER CONTACT, SECONDS
-- - . .-__. == =u=.
FIGURE I.4-N ST. LUCIE UNIT I STRETCH POWER . 1.0 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG il')T SPOT GAP CONDUCTAt:CE O, 900 800 0 700 u o 600 sR S ca ul 500 7 6 7'N L3 a N i N m ~ S 400 / 300 g 200 100 0 100 200 300 400 500 600 , TIME, SECONDS
i
~
~~ ~ ~ ~~~
FIGURE I 4-0 ST, LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTIt1E BREAK Ifl PUt1P DISCHARGE LEG bq./ PEAK LOCAL CLAD OXIDATION I
* ~
16 p-
/
14 n / U /
/
12 /
/ PEAK CLAD TEMPERATU RE NODE
/
RUPTURE tDDE 10 (! l - N' / 5 / 7 a /
- I 6 ,
(
)
n v 4 j
/
l
/
I 2 7
/
p'a
, /'
0 0 100 200 300 400 500 600 70: TIME, SECONDS
- r!OUKt 1.9-r
! ST. LUCIE UNIT I STRETCH POWER 1.0 x DOUBLE ENDED GUILLOTIllE BREAK If1 PUf1P DISCHARGE LEG CLAD TEliPERATURE, CEf1TERLIllE FUEL TEfiPERATURE, AVERAGE FUEL TEf1PERATURE AND COOLANT TEllPERATURE FOR HOTTEST N0DE g
4000 3500 0 3000 2500 F JEL CENTER LINE A 2000 g I [/[ AVERAGE F JEL
/
C _AD
/ '
1500 L l 1000 ; O l l 500 j CC DLANT 3 O 0 100 200 300 400 500 600 h TIME, SECONDS
i FIGURE I.4-0
! 5T.LUCIEUNITISTRETCHPOWER l 1.0 x DOUBLE Ei1DED GUILLOTINE BREAK Ill PullP DISCHARGE LEG O
HOT SPOT HEAT TRANSFER COEFFICIENT 400 1 350 0 . m 300 1 *id-
't
=
$ 250 ,
$5 3
s Q s 200 i i 8" I e E 150 . E .' E 100: i l 50 ! . O O r 0 100 200 300 40u 500 600 70 Tit 1E, SECONDS l
FIG RE I.4-R ST. LUCIE VillT I STRETCH POWER O, 1.0 x DOUBLE EllDED tUILLOTIflE BREAK If1 PUMP DISCHARGE LEC , C0i1TAliiMEf1T TEMPERATURE 300 , , , , O 250 - - 200 - - O a O 150 h m 8 EU 100 - _ 50 - _ h
' ' ' i 0
0 100 200 300 400 500 TIME, SECONDS f
i l lQ FIGURE I.4-d ST. LUCIE UillT I STRETCH POWER I 1.0 x DOUBLE EtlDED GUILLOTlilE BREAK lll PUMP DISCHARGE LEG
- SUMP TEMPERATURE i
- 300 i , i i 4
250 - I
& t 200 - -
u_
- O w
! i3 150 - - :
y . E w 1 100 - - 50 - i
- O 0 .100 200 300 400 500
~ TIME, SEC0iiDS O
~-,---,--,--w -,,,,-w- , ,+--ew- m- 1-m - , -we w , --, ,,~c,-, -
-v -- vs ,w,--,,ws--~m erg-r--,---g--mm -
~~
g
~ ~ ~
FIGURE I,4-T ; ST LUCIE UNIT I STRETCH POWER 1,0 x DOUBLE ENDED GUILLOTIflE BREAK Ill PUflP DISCHARGE LEG HOT R0D INTERilAL GAS PRESSURE 9 1200 ig,7;3 ,67,7 N P IA p m ! RIJPTURE=51. 24 sEc e 800 , i g
~
5 ' d 600 8 i 400 0 200 0 0 20 40 60 80 100 Tli1E, SECONDS
FIGURE I .14-U l ST. LUCIE UillT I STRETCH POWER > \ 1.0 x DOUBLE EilDED GUILLOTlilE BREAK IN PUMP DISCHARGE LEG ; CORE BULK CHAilllEL FLOW RATt. CORE INLET
- - - - CORE EXIT -O 50000. , , , ,
1 20000. - 1 I l 10000. O y q "i -
'i u3 9'
"+ A
~
x S u_ '
-10000. -
BULK CHANNEL REPRESEllTS 98% O / OF TOTAL CORE FLOW AREA l -20000. -
' I i i
, -30000. 0.0 5.0 10.0 15.0 20.0 25.0 Q TIME, SECONDS
. ~ , "*
, ._~
O FIGURE I.5-A ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG CORE POWER 1 2001 g
- s
. 1 0000 e-8000
- O w
8' d 6000 a r
.4000 -
O 2000 0.000b a a o a a 8 8 8 8 8 8 9 9 9 9 9 9 m o - ~ cn v m W l TIME, SECONDS
-Q-- __f__ , , _ ---'w- i gm-5,yw ypw ,i,-,.-
~"T
O eteuRe I.5-8 ST LUCIE UNIT I STRETCH POWER
- - 0,8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG j PRESSURE IN CENTER HOT ASSEMBLY NODE 2
2400 0 2000.0
~
1600 0 a s 1200.0
\
u o_ 800 0 s C 400 0 s I 00 a a a a 8 8 8 8 8 8 O s s s s TIME, SECONDS 1 1-, _ __
~
_ _7- . _ _ ~ 7
i FIGURE I.5-C ST LUCIE UNIT I STRETCH POWER g 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG LEAK FLOW PUMP SIDE REACTOR VESSEL SIDE 120000. , , i i g 100000. - it! m 80000. - B G s - ll 60000. - E cd L10000. -
's, g 20000. -
s ,
~- I l l 0.0 5.0 10.0 15.0 20.0 25.0 O
TIME, SECONDS l
O FIGURE I.5-D.1 ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 16, BELOW HOT SPOT O 3o ooo 20 000 10 000 3 a 0.000 4 W m % #
-10.000 !/
0
-20.000
-30 000 a a a a 8 8 8 8 8 8 0
u b b b TIME, SECONDS
- - - ._--_x, .
O FIGURE 1.5-D.2 ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 17, AB0VE HOT SPOT 30 000
~
h i 20 000
'I 1
10 000 b 5 \ O s 0 000 E ! b J B
\g # ~ -10.000:
h/
;j O
-20.000-
- ~~
-30.000 O a a o 8 8 8 8 8 8 9
a 9 m e-a e a a m O l TIME, SECONDS _ . _ , . _ _ - m
i FIGURE I.5-E O sT LUciE unit i sTaeTca e0wEa ! 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG HOT ASSEMBLY QUALITY i >O n0DE 13, set 0w a0T se0T
---- N0DE 14, AT HOT SPOT N0DE 15, ABOVE HOT SPOT 1.0 g i g., , i j s, , ;-
!8, f g' ,,
- l
, I/ I
/-l 0.8 j,,' g l
' I -
O i i ;,
/
.i
.i 0.6 p
I 'i, ~, ' t-
\ lj
-j ,! .l .
f s./ 0.4 A
)
\ l -
if ( v
;O !
0.2 t I.
;i 0.0 I 0.0 5.0 10.0 15.0 20.0 25.0 O TIME, SECONDS 4
FIGURE I.5-F ST LUCIE.UtilT I STRETCH POWER 0.8 x DOUBLE EtlDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG g CONTAINMENT PRESSURE 60.000 e t 50 000 { t h 1 40.000 1 5 m
- e 1
! =
\
I E 30 000 3 3
,..j 20 000 't 10.000 l
o
- . 8 8 8 m
8 8 m a 0 - m y t TIME AFTER RUPTURE, SECONDS G
's
= -,w--
FIGURE I'.'5-G ST LUCIE UNIT I STRETCH POWER 0.8 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHAR i MASS ADDED TO CORE DURING REFLOOD O :cocco. 100C00 i
- 80000 O W '
8 S 60C00 7 S . 8
- a 40000
/
z [ - 0 20000 t o k k k k k 8 !O o 8 8 m 8 m 8 v m ; TIME AFTER CONTACT, SECONDS l -
~
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 g [h 2000 X
~
1800 - - i 1600 " ! g1400 ;I, b' E . h1200'j.^ a a 1000 O 800 i I 600 l l le 1 400__ _... _ _ t _ . TIME, SECONDS I
O FIGURE I 6-A ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARG CORE POWER O t zoot i i i 1.c000 j l ,
.0000
~ O $ 3 c. g .6000
$5
.4000 N
a o 0.000b a a a 8 8 8 8 8 8 9- 9 9 9 9 9
- O a - a m v m TIME, SECONDS
...-,I ~"L. -E' _. .- _ . . . - . - - , . - - . .
FIGURE I.6-B a W ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG PRESSURE IN CENTER HOT ASSEMBLY N0DE 2.:00 0 . O 2000.0 1600 0, 5 O d 1200.0 23 E c 800.0 ' 400.0 h 0.0 o o a A o 8 8 8 8 8 8 c; 3 5 5 5 d TIME, SECONDS l
O~ FIGURE I.6-C ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG LEAK FLOW PUMP SIDE O 120000. ,
---- aEAC10a vESSet SIDE i i m
100000. - O e 80000. - e - B u2 - 60000. 3 E d 110r 9 _ O <, 20000. - -
'e,
'N l
\ ~~~
' ~4~-
0' 2s.0 10.0 1s.0 20.0 O O.0 s.0 TIME, SECONDS
, ., _. - - . _ . ._ ___ __ . . , _ . . . _ . . ,r.,, . ,, , ,. _
FIGURE I.6-D.1 ST LUCIE UNIT I STRETCH POWER g' 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG FLOW IN HOT ASSEMBLY-PATH 16, BELOW HOT SPOT 30.0C0 , 1 l O 20.000 - fl y a 10 00L; , U l 2 <^ a ul l - 0.000 f
-10 000 .
L i
-20000f $ -30.000 a a a a 8 8 8 8 8 8 ,
3 5 5 5 d TIME, SECONDS
O FIGURE I 6-D 2 ST LUCIE-UNIT I' STRETCH POWER 0.6 x DOUBLE ENDED GUILLOTINE BREAK-IN PUMP DISCHARGE L FLOW IN HOT ASSEMBLY-PATH 17, AB0VE HOT SPOT
~
30 000 7 20.000 s 10.000 h a w R
,N 0 000
\/
'@ Q /
-10 000 O
i
-20'.000 l
i
-30.000 .a o a a 8 8 8 8 8 8 O
9 9 6 3 a sN
~ ~ N O LD :
TIME, SECONDS
. _ _ _ ~ _ .
O FIGURE I.6-E ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG HOT ASSBiBLY QUALITY N0DE 13, BELOW HOT SPOT O
----- N0DE 14, AT HOT SPOT
- - N0DE 15, AB0VE HOT SPOT i i a 1.0 .. i i.t l' c, le
' - l -
'! I ', !
j -
/.'i
.i I' '-
i If .
' ' I 0.8 k 1'
' ,l ) O F ,
/ /
i r,
' i' i
/, /
0.6 i i '. '
/ ' ' '
1 -
'i C 2
.i i
3 e y l 8 1 1 /
,. , ,. /
0.4 ' \ i i./ l i v g l j 0.2 4 ' i i c} I 0.0 5.0 10.0 15.0 20.0 25.0 O.0 0 TIME, SECONDS ~ e -w- . - - . - . . . , ,
O eiGURE 1.s-e ST LUCIE UNIT I STRETCH POWER 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE L CONTAINMENT PRESSURE e 60 000 j 50 000 3 40.000 O E E
. h 30 000
'20 000 0- 10.000 l
c 9 9 9 8 8 8 8 8 m
- ~ ~ ~
.O TIME AFTER RUPTURE, SECONDS
.c.
s .
.--m_ _ __
F FIGURE I.6-G
~~
e ST LUCIE UNIT I STRETCH POWER l 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE LEG NASS ADDED TO CORE DURING REFLOOD i
;20000 g
=
- 100C00 - _-- .-..- - - - - - - - - -
i g 8GC00 e e w 0 g socco. I / S 8
~
$ 40000 E [ - i o!
20000 O. _g g __ g _g g _ 8 a e e a a a a a e a s e TIME AFTER CONTACT, SECONDS
-l
~ . .
L -
FIGURE I.6-H ST LUCIE UNIT 1 STRETCH POWER l I 0.6 x DOUBLE ENDED GUILLOTINE BREAK IN PUMP DISCHARGE PEAK CLAD TEMPERATURE gGO
'c000 x 7
(, 100
\ x v
1600 f ( . 1400 j 4 g i j . 251200 H. E . E r a
@l000 \_j 800 .
600 l (-, l L; l 400 - 600 70' l 0 100 200 300 400 500 TIME, SECONDS
FIGURE I.7 ST. LUCIE UNIT I STRETCil POWER PEAK CLAD TEMPERATURE vs. BREAK AREA 1 2200 , , , , , , _ _ - -o 2100 - u_ o N 2000 - ODISCHARGE LEG SLOTS -
$ O DISCHARGE LEG GUILLOTINES 5
n= b - 1900 - [ u 1800 - DISCHARGE LEG BREAKS -
"'
- o .
O O e-i 1700 I I "1 11 11 I 0 2 4 6 8 10 12 14 BREAK AREA, FT 2
, Table 1
, Characteristics of St. .Lucie 1 and Millstone 2
.c
. St. Lucie 1 St. Lucie l. Millstone 2 Full power level, nse (102% of Ncminal) 2754 2754 Peak linear heat rato, kw/f t 16.0 16.0 Average linear heat rate, kw/ft 6.43' 6.40 g Core inlet temperature, 'F 551 551 -
( Core outlet tamperatura, 'F ' 602 602 Active core height, ft 11.39 11.39
. Fuel rod 00, in ~0.44 0.440 '
. Number of cold legs -
, 4 4 Number of hot legs 2 -
2 Cold leg diameter, in 30 30 Hot leg diacetar, in . 42 42
.' Total primary system volume, ft 3 10.867 10 ~,853 Active core volume, It 3 O C .erimary system volu=C 00VG tCp # core, ft 655 8280 653 8129 Low pressuri:er pressure scram setpoint, psia 1750 1750 Initial 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 215/1107
. psia /ft3 High pressure safety injection pump runcut ficw, 640** 655*
gpm High pressure safety injection pump ficw at 315** 294* steam generator secondary relief valve setpoint, (985 psig), spm High pressure safety injection pump shutoff head, 1245 1225 psia low pressure safety injection pump runaut flow, 40C0 3750 gpm Low pressure safety injection pump shutoff head, 192 207 l psia s C
- includes charging pump flow.
" Excludes charging pump flow. .
6 (
~
l Section 9 G ST. LUCIE UNIT 1 REACTOR PROTECTION SYSTEM ASYMdETRIC STEAM GENERATOR TRANSIENT PROTECTION TRI9 FUNCTIO
~ .
LICENSING DESCRIPTION C . O G O e 1 l e b . _m
. o. o i
pg y 9 l 1.0 INTR 000CTION
*~
- IL & -]\- '
This document describes the Reactor Protection System (RPS) Asymetric Steam
' Generator Transient Protection Trip Function (ASGTPTF) ar.d its design bases.
The ASGTPTF is designed to protect against Anticipated Operational Occurrences (A00s) associated with secondary system malfunctions which result in asymmetric primary loop temperatures. The most 1,i'miting event- is the Loss of Load to
~
One Steam Generator (LL/ISG) caused by a single Main Steam Isolation Valve (MSIV) closure. The St. Lucie 1 RPS presently employs an analog thermal margin trip calculator as part of the Thennal Margin / Low pressure (TM/LP) trip function. To provide a reactor trip for asymetric design basis events, pressure in each of the O two steam generators will be monitored and these signals input to the thennal margin calculator. Secondary pressure imbalances between the two generatocs
. will be calculated and a corresponding factor applied in the TM/LP calculator to generate a trip signal. ,
Protection against exceeding the ON8R and maximum Kw/Ft Specified Acceptable Fuel Design Limits (SAFDL's) during the LL/ISG event is presently provided by the Low Steam Generator Level reactor trip in conjunction with sufficient initial margin maintained by the Limiting Conditions for Operation (LCO's). The 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 C fuai cycias for st 'ucie t. cyc1e 4. by assurins that the asv=atric.
transients would not be limiting ACO's for establishing tne LCD's. e9
~
O I - l l l O U . l e
1
~
~ i
\
l 2.0 SYSTEM OESCRIPTION , 1 2.1 General .
.The ASGTPTF consists of: _ . 1.
Existing steam generator prassure sensors '(one for each steam generator per channel) and associated process equipment. 2. Existing Thermal Margin / Low Pressure (TM/LP) calculators modified to include a bistable with an input of the absolute value of the pressure difference between the tw steam generators [P3g7 - PSG2l. The output of the bistable signals the TM/LP calculation wnen trip conditions are reached. 3. Existing- RPS trip logic and Reactor Trip Switchgear. ^ Hodifications to the existing TM/LP calculator will be discussed next as the rest of the system consists of previously licensed installed equipment. A functional Figure 1. block diagram of this portion of the system is provided in 2.2 TM/LP Modi fications 1 steam from eachgenerator pressure signal is input to each of the TM/LP calculators steam generator. the two pressure signals is calculated.In each TM/LP calculator, the difference between amount, a bias is input to the TM/LP calculatien.If the difference exceeds a set reactor trip. Titis wil'. result in a the asycuetric factor signal (Fas).The additional bias input to the TM/LP trip ca enough more level than tne to ensure setpoint value. a trip if the steam generator pressures differ byT between the absolute value of the pressure difference, [PFigure 2 illustra 3gy - PSG2j, and the asymetric factor signal, Fas. i I
. l O'
g
3.0 OESIGN BASES
- 3.1 Design Basis Events r, .
N. The ASGTPTF is designed to provide a reactor trip for those design basis events associated with secondary system malfunctions which result in asymmetric primary leap coolant temperatures. The most limiting event is the LL/ISG caused by a single Main Steam Isolation Valve (MSIV) closura. 3.2 Design Criteria . The ASGTPTF is designed to the following critaria to ensure adequate performance of its trip function:
- a. The trip function is designed in cuoliance with the applicable criteria Os of the General Design Criteria for Nuclear Power Plants, Appendfx A of
;10 CFR 50, July 15, 1971. * ; b.
Instrumentation, function and operation of the trip logic conform to the requirements of IEEE Standard 279-1968, Criteria for Protective Systems for Nuclear Power Plants. .
- c. The trip function is designed consistent with the recomendations of Regulatory Guide 1.53, Application of the Single-Failure Criterion to
" Nuclear Power olant Protective Systems, and Regulatory Guide 1.22, Periodic Testing of Protection System Actuation Functions. ,o c.
d. e. Four independent c:easurement channels are provided. ' The protective system ac power is supplied frem.four separate vital instrument buses. f. The ASGTPTF can be tested with the reactor in operation or shut down. g. Trip signal is preceded by a pretrip alar n to alert the operator of undesirable operating conditions in. cases where operator action can correct the abnornal condition and avoid a reactor trip. h. The ASGTFTF ccmponents which will be used are of the same type presently in use at SL1, and will meet the same industry standard as applied to the original RPS (i.e., IEEE-279, August 1968). The operation of the O, ASGTPTF is not required during or subsequent to any Design Basis Event
~ which significantly alters the containment environment (LOCA, Main Steam Line Break or Feedwater Line Break). Therefore, it is not required that additional in-containment equipment installed specifically for the ASGTPTF be qualified for the adverse environments associated with these events.
1. The trip function is designed so that protective action will not be initiated due to normal operation of the generating station. J. All equipment will be designed in accordance with the OACM. Vendor quality control will be in accordance with C-E Procedure WOC 11.1, OL Revision 0. k. Modification to the TM/LP Calculator for the ASGTPTF will not jeopardize previous qualification of this equipment.
3.3 Performance Recuirements , 3 The selection of a trip setpoint is such that adequate protection is provided when accounall
- t. sensor and processing time delays and inaccuracies are taken into Final determination of an equipment set::oint is based on equipment characteristics, operating environment, N555 performance and safety analysis.
The nominal setpoint, uncertainties and response time are provided in Table 1.
# 4 G
6 L-e O i,
?
e
~
G
O O O O . O (> O TABLE 1 s % ASYMETRIC STEAM GENERATOR TRANSIENT PROTECTION TRIP FUNCTION NOMINAL CilARACTERISTICS N - ti@ Nominal System Accuracy 135 pst @ Analysis Setpoint +175 psid - c:==s Hominal Equipment Setpoint +140 psid g# Hominal Pretrip Setpoint +100 p.ld i Nominal System Response Time- , <.9 seconds Nominal: Expected value only. Final values are to be determined . later, and included in the plant Technical Specifications as appropriate. O e 9 e 4
3 (- O
- S3: FLOW DEPENDENT SETPOINT -
.I SELECTOR SWITCil IN RPSCIP C
3 i i POSITIONS - 1. 4 PUMPS Z N< I ( PSCIP)
- 2. 3 PUMPS
.l. 2 PUMPS-OPP. LOOPS '
~
O # -
- 4. 2 PUMPS-LOOP 1 yTCAt -
x A CAL T 5. 2 PUMPS-LOOP 2 wy 5 a _xj= f "I 'K e ' K C C pSCle) O 4 C g 53 O 4 QA AXIAL g4 3e AX1AL Off5U FNCT j h (RPSCIP) l 4 N/y ^ 9
/~~
5 A ICAL
~
OR 3
,9 -
i ---- I VA" '
og (Coniloue2500 - -
l i l ,
Fas i
i' !
I t
'l 1
t -
l . ; i . m
; a ; a
- e t
Setpoint i psid i !
- !PSGI - PSG2! -
i t j . i a
- 1 i .. t
- r
! i FIGURE 2 i L I 4 i Fasvs.lPSGI - PSG2l l i
; .ASYMMETHIC FACTOR SIGNAL I . i t
I I.
.I l t
l
J ATTACHMENT 4 l 1 ! i l t i l Ol l ST. LUCIE LHIT 1 STRETCH POWER , t ENVIRONMENTAL REPORT , O { i O \, l t O l
\
TABLE OF CONTENTS Page Section 1 - INTRODUCTION 1 Section 2 - THE SITE AND EINIRONMENTAL INTEPEACES 2 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 N 2.7 Geology 3 2.8 Regional Historic Features 3 Section 3 - THE PLANT 4 3.1 External Appearance 4 3.2 Reactor and Steam Electric 5/ stem 4 3.3 Plant Water Use and Heat Dissipation 4 3.4 Radwaste System 4 3.5 Chemical'and Sanitary Wastes 4 3.6 Electrical Distribution 4 Section 4 - ENVIRONMENTAL EFFECTS OF PLANT OPERATIONS 5 4.1 Non-Radiological Effects 5 4.2 Radiological Effects 5 Section 5 - EFFLUENT MONITORING 6 5.1 Non-Radiological Monitoring 6 5.2 Radiological Monitoring 5 Section 6 - ENVIRONMENTAL EFFECTS OF ACCIDENTS 7 () 6.1 6.2 Loss of External Load Accident and/or Turbine Stop Valve Closure Excess Load Accident 7 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 Generatcr Tube Failure 16 6.6 Control Element Assembly Ejection Accident 23 6.7 Steam Line Break Accident 29 Section 7 - ALTERNATE ENERGY SOURCES 35 3 \ i t
ATTACIDENTS
- l. St. Lucie Unit 2 Environmental Report - Operating License, Sections 2.1.1, 2.1.2 and 2.1.3
- 2. St. Lucie Unit 2 Final Safety Analysis Report, Section 2.1.2
- 3. St. Lucie Unit 2 Final Safety Analysis Report, Section 2.3
- 4. St. Lucie Unit 2 Environmental Report - Operating License, Section 2.2
- 5. St. Lucie Unit 2 Environmental Report - Operating License, Section 2.4
- 6. St. Lucie Unit 2 Environmental Report - Operating License, Sections 3.3 and 3.4
- 7. St. Lucie Unit 2 Environmental Report - Operating License, Section 6.1 O
l n I l
1 i . 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 Mwe (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 l d present level, i.e., from 2560 Mwt (thermal) to 2700 Mwt (thermal). 4 The primary objective in obtaining a stretch rating is to reduce some j future capacity additiors to FPL's system and to allow a reduction in the amount of
- stroleum consumed by FPL. The stretch power developed at St. Lucie Uait I would save approximately 450,000 barrels of oil per year thus providing economic benefits to FPL's customers and assist the nation towards the goal of endtgy 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 $8.5
; million per year could be realized at this differential by increasing j the generating capacity of St. Lucie Unit 1.
l The following report demonstrates that stretch power at St. Lucie Unit 1 will have no adverse impact on the environment. i l iO f ) l O f i 4 i : ? 1
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 Section 2.1.1 of the St. Lucie Unit 2 Environmental Reporr - 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) i 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 vegetetion, wildlife, and aquatic ecology of Hutchinson Island and the surrounding area. (See Attachment 4) lh 2.6 Hydrology The Atlantic Ocean, east of the plant site, provides most cf the water required for plant optration, and receives liquid wastes and waste heat from plant operation. Surface water hydrology and v;ter qualicy ,
- .iaracteristics of the Atlantic Ocean in this area are described in I Section 2.4 of the St. Lucie Unit 2 Environmental Report - Operating -
- ~- G l
O 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. O 2.8 Regional Historic Features The regional historic, archeological, architectural, scenic, cultural, and natural features of the area surrounding St. Lucie Unit I will not be impacted by stretching core power. O O h !O l 1
Section 3 - THE PLANT 3.1 External Appearance No change in 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 lb/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 Dissipation . 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 will remain unchanged while heat rejection is increased during operation at stretch power, the delta T of th3 cooling water will increase l h; from 24' F to about 25.5" F at full circulating water flow (1150 cfs).
No modification in the heat dissipation system is rcquired to accommodate the increased power level. The environmental impact of the thermal discharge is discussed in Section 4.1 below. 3.4 Radwaste System As' described in Chapter 11 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. I i i 3.5 Chemical And Sanitary Wastes I operation at stretch power will not affect chemical and sanitary waste ' systems at St. Lucie Unit 1. 3.6 Electrical Distribution ' Operation at stretch power will not require any modification to the existing discribution facilities. O 1 I l l
Section 4 - ENVIRONMENTAL EFFECTS OF PLANT OPERATION 4.1 Non-Radiological Effects Applied Biology, Inc (1978)* analyzed the effects of thermal discharge for St. Lucie Unit 1. The analysis describes the effects of thermal discharges of up to a delta T of 28* F at full circulating water flow and up to 32' F at reduced circulating water flow. Operation of St. Lucie Unit 1 at stretch power will result in a delta T of 25.5* F (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 water of 26' F. a 4.2 Radiological Effects As indicated in Section 3.4, modification of the radwaste system is not required to support operation at stretch power, and no significant 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. rh U t
, v
- Applied Biology, Inc. 1978. Effects of Increased Water Temperature on Marine Biota of the St. Lucie Plant Areas. Decembe r, 1978.
i j l l 1
l Section 5 - EFFLUENT MONITORING 5.1 Non-Radiological Monitoring Non-radiological conitoring 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-radf ological 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. O i O Section 6 - ENVIRONMENTAL EFFECTS OF ACCIDENTS h 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 on those 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 g 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 Clot.ure 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 is a turbine trip. This accident can also be postulated to result from abnormal variations in network frequency. v 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 Cs Table o.1-3. As shown la Table 6.1-4, the offsite doses which result from this accident are small fractions of the 10CFR100 exposure limits. i ) a I l
TA?1Z 6.1-X Sequence of Events for a toss of toad Accident Ti:::e (sac) Event 0.0 Complete loss of secondary load 5.1 Secondary saf ety valves open 7.8 High pressurizer pressure reactor trip (2422 psia) 70R7's fail to open. Steam Du=p and Bypass valves fail to open. Feedvater flow ra=ps to 5".. 9.0 Primary safety valves open (2500 psia) 9.2 CEAs start to drop into the core 13 Primary safety valves close 380. Secondary safety valves close 1800 Plant cooldown initiated using steam dump to atmosphere. 9000 Average reactor coolant temperature < 325 F, shutdevn cooling initiated O O t l 1
4 TABLE 6.1-2 Assumptions 1 4 O- unicial Power (including pump heat) 2764 MWt Initial RCS Pressure 2200 psia Initial Main 5 team Pressure 820 paia Moderator Temperatura Coefficient +0.5(-4)4P/ F 4 Pressurizer PORVs are not operable Steam Du::p and Bypass System is not operable Operator initiates plant cooldown procedure at 30 minutes. DEC of I-131 Reactor Coolant 60 uC1/gm Secondary Coolant 0.luci/gm Noble Gas Conc. in Raactor Coolant FSAR Table 11.1-1 Primary-to-Secondary Leakage 1 gym i Atmospheric Diffusion 3 0-2 Hour at the EA3 1.2(-4)sec/m 3 0-8 Ecur at the LPZ 6. 6(-5) sec/m 3reathing Rate 3.47(-4)m /sec Mass of Steam Released Secondary Safety Valves 0-30 minutes 112000 lbm Atacspheric Duc:p Valves 0.5-2.0 hours $29000 lbm 2.0-2.5 hours 166000 lba V
~
TABLZ 6.1-3 Radionuclide Releases Release (Curies) 0-2 hours Duration I-131 DEC 5.6 7.1 Kr-85m 6.8 (-1) 8.5 (-1) Kr-85 4.0(-1) 5. 0 (-1) llll Kr-87 3.7(-11 4.6(-1) Kr-88 1.2 1.5 Ie-131s 6.7(-1) 8. 4 (-1) Ie-133 8.2(+1) 1.0(+2) Ie-135 34 4.3 Ie-138 .1.6(-1) 2.0(-1) O 1 1 0
I 4 TABLZ 6.1-4 i 1 ' Radiological Consecuences of a : i Loss of External Load Accident t. Doce (Rem)
.QIsan _
l , t l At the EAB l l '4 hole Body 2. 3. (-4) l Thyroid 3.4 ( -1) l I 4 j At the IJZ l
'4 hole Body 1.6 (-4)
I Thyroid 2.4 (-1) [ 1 , I i , l [ n e l i 1 P f I f 1 l' .
- i l
l l 11 - t f l i F
- -m.,__md...-.-r -,.,.my.. ,,w-c,,, 3.,,.,..
1 l l 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
- ncreases in steam flow result in a power mismatch between core power and steam generator load demand. Consequently, there is a decrease in reactor coolant temperature and pressure. Under these conditions a negative moderator temperature coefficient of reactivity causes an increase in 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. The assumptions used to calculate the radiological conse-quences are 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, O i i i i O: O
i f
- TAst.E 6.2-1 Assumptions Initial Power 1.0 Mwt (2 loop, no load)
Core Inlet Temperature 534*F Secondary Pressure 915 psia i i Atmospheric Dump valve Flowrate 85 lbs/sec Credit was not taken for the reduction in secondary pressure during the event which would reduce the atmospheric dump valve flovrace. 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 uC1/gm Secondary Coolant 0.1 uC1/gm Noble Gas Reactor Coolant 7SAR Table 11.1-1 Primary to Secondary Leakage 1. gym O Atmospheric Diffusion 3 0-2 hours at the EAS 1.2(-4)sec/m 0-8 hours at the LPZ 6.6(-5)sec/m3 3 3 reaching Race 3.47(-4)m /sec - Mass of Staam Released
'O Atmospheric Dump Valves 0-10 minutes 51000 lbc
l TEG 6.2-1 Radionuclide Releases Release (Curies)_ I-131 DEC 4.6(-1) Kr-85m 5.6(-2) Kr-85 3. 4(-2) O Kr-87 3.1(-2) Kr-88 9. 8 (-2) Ie-131s 5.6(-2) Ie-133 6.9 Ie-135 2.9(-1) ll h Ie-138 1.4(-2) O l l lh
l 3 f I l t TABI.E 6.2-3 I t Radiological Consecuences of An Excess Load Accident , i l Orjtan, Dose (Rem) l 1 j At the EA3 Whole Body 2. 0.' (-5) l Thyroid 2.8 . (-2) l l ! 1 At the LPZ Whole Body 1.1.(-5) l l Thyroid 1.6 :(-2) i
- F l
i l a s s l I I e i % m-,e,a a r, , - ,-. n ----m,,,w,,,,.----,e,,ere-,e-,--r~
6.3 Major Reactor Coolant System Pipe Rupture (Loss-of-Coolant Accident) The radiological consequences of a major reactor coolant system pipe rupture (LOCA) have not been recalculated for the stretch power case. This was not done because the analysis presented in the PSAR was based upon Regulatory Guide 1.4 assumptions and was performed at 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) fo.11owing a LOCA, it will not have any effect on the core release fractions assumed. 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 af ter one day) regardless of the post LOCA containment pressure. The power level assumed in the analysis of a large LOCA would have an effect on the core radionuclide inventory. 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 le'al of 2764 Mwt. This is well within the uncertainty of this type of calculation. 6.4 Waste Gas Decay Tank Leakage or Rupture i As with the LOCA, the radiological consequences of a vaste gas decay j tank rupture have not been reanalyzed for the stretch power case. l 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. Sinct 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 well 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 i the trar.sfer of reactor coolant into the main steam syster. Radicactivity contained in the reactor coolant mixes with water in the shell side of 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 Cv'] 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. Q 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 t. ell within the 10CFR100 exposure limits for this accident. O o O
\
v l
l l TABLE 6.5-1 Sequence of Events Of A Steam Generator Tube Failure Time (sec) Event 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 944 Pressurizer begins to refill 1800 Plant cooldown initiated using steam dump to condenser. 9000 Average reactor coolant temperature <325*F, shutdown cooling initiated. O i 1
l TA31E 6.5-2 As sunctions Initial Power 2764 MRt Cincluding pump heat) Initial RCS Pressure 2300 psia Initial Main Steam Pressure 810 psia i (low initial steam pressure leads to slightly greater releases) A double ended rupture of one steam generator tube occurs instantaneously. The discharge race through the break is assumed to be proportional to the square root of the pressure differential between the primary side and the secondary side. 1 Under full load operating cond1:1ons, 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 from the reactor coolant system. The reactor coolant pump 4 are lef t in operation even af ter saf ety injection occurs. At the end of 30 ninutes 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 I-131 Reactor Coolant 60 uCi/gm Secondary Coolant 0.1 uC1/gm O b Noble Gas Concentration in Reactor Coolant 7SAR Table 11.1-1 No credic vas taken for the reduction of the specific fist.. n product inventory in the reactor coolant system resulting from dilution, safety injection and charging flow. Primary-to-Secondary Leakage 6.3(+4) lbm Stesm Generator Iodine Deconemmination Factor 10 0 _
TABLZ 6.5-1 (. cont'd) Assumecions Atmospheric Diffusion 3 0-2 Hours at the EA3 1.2(-4) sec/m 3 0-8 Hours at the LPZ 6.6(-5) sec/m 3 Breaching Race 3.47(-4) m /sec Mass of Steam Released Condenser via che Turbine 0-0.5 Hour 1810000.lba Condenser via the SD&3 Valves 0-0.5 Hour 46000 lbm
- 0. 5-2.0 Hours 549000 ihm 2.0-2.5 Hours 158000 lba
'l O
O
. . - - - - - - , _ _ - ~
i l - i i J !O 1 TABLE 6.5-3 4 i f Radionuclide Releases ! Release (Curies) , t l I-131 DEC 1.8(+1) l i Kr-85a 4.3 (+1) Er-85 2.5(+1) l Ir-87 2.3 (+1) ! tr-88 7 .4 (+1) Ie-131m 4. 2 (+1) l Ie-133 5.2(+3) l i Ie-135 2.2(+2) i i Ie-138 1.0(+1) ( 1 l I i l !O i i I i ' l. I I, r O l l . , - , . , - - - - - ~ . . , . - . . . - . . , - , , - _ _ . _ . . , , _ _ _ . _ . _ . . - _ _ , . . . _ ._ -., . _ ~ , . -..___ ,. _ . . , _ _ _ _ . _ . _ , , _ . -
i TABII 6.5-4 I l Radiolegical Consecuences Of A Stens Generator Tube Failure OI ' Organ Dese (Rem) At the EA3
'4 hole Body 1.3 (-2)
Thyroid 1.1 (+1) At the I2Z
'4 hole Body 7.1.(-3)
Thyroid 6,2 O O O
6.6 Control Element Asserably Eject?.a Accident t 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 housing and CEDM nozrie are an extension of the reactor coolant boundary and designed and manufactured to Section IIT of the ASME Boiler and Pressure Vessel Code. Hence, the occurrence of such a failure is considered highly unlikely. A typical CEA ejection tre behaves in the following manner: Af ter ejection of a CEA f 11 power or zero power (critical) initial conditions, the < rises rapidly for a brief period. T The rise is terminated b) ler effect. Reactor shutdown is initiated by the high pos . rip, and the power transient is then completed. The core ted against severe fuel damage by the allowable CEA patte ,a by the high power trip. The radiological consequences of this type of accident have been determined for two types of radionuclide pathways: 1) leatage 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 O consequences of the CEA ejection accident are well within the guidelines of 10CFR100. O G
TABLE 6.6-1 Assumotions Initial Power 2764 .Wt (including pump heat) DEC of I-131 Reactor Coolant 60 uC1/gm Secondary Coolant 0 1 uC1/gm Noble Gas Reactor Coolant FSAR Table 11.1-1 Fuel Rods in which: Centerline P.elting is Experienced 4: Cladding is 3 reached 0: At=ospheric Dif fuston 0-2 hours at the EAH 1.2( 4)sec/m 3 0-8 hours at the LPZ 6.6(-5) sec/m3 8-24 hours at the LPZ 1.2(-5)sec/m3 3reathing Rate 3.47(-4)m3 /see Releases f rem the Containment Pri=ary Coolant Released to the Contai==ent 5.2C+5)1bm (total inventory) Containment Leak Rate 0.5:/ day Iodine Composition: Inorganic Iodines 90: Organic Iodines 10: SEVS Filter Efficiency Inorganic Iodines 90: Organic Icdines 70 Noble Cases 0" l i 1
- 24
TABLE 6.6-1 (Cont'd) 4 Assumetions
!()
l Released frem the Secondary Side Core Inlet Temperature 551. F Luitial RCS Pressure 2200. psia Main Steam Pressure 893. psia
'( )
CEA Ejection Time 0.5 seconds Worth of Ejected CEA -0.31' A P 4 (bounding worth of an ejected CEA at full power) Pressurizer power operated ralief valve are inoperative No rupture of CIDM. housing following the CEA ej ection; this saxdmizes steam release from the secondary system. Autenatic trip for this event is initiated by a high power level t.*1p signal. Cooldown Race 100 F/hr (Tech Spec) Primary-to-Secondary Leakage 1. gym Mass of Steam Released Steam Dump and Bypass to Condenser O 0-30 minutes 0.5-2.0 hours 128500 ihm 18000 lbs 2.0-2.46 hours 148000 lbm SG Safety valves to Atmosphere 0-30 sinutes 18000 lbm Turbine to Condenser 0-30 sinutes 500 lba l
TA32.E 6.6-2 Radionuclide Releases Released Frcm the Contai=nent Release (Curies) 0-2 hours 0-8 hours 0-24 hours I-131 DEC 7.1(-1) 2.8 8.5 Kr-8SM 1. 5(-1) 5.9(-1) 1.8 Kr-85 8.7(-2) 3.5(-1) 1.0 Ir-87 8.0(-2) 3.2(-1) 9. 6 (-1) K:-88 2.6(-1) 1.0 3.1 l Ie-1.lls 1.5(-1) 5.8 (-1) 1.8 Ie-133 1.8 (+1) 7.1(+1) 2.1(+2) Ie-135 7.4(-1) 3.0 8.9 Ie-138 3.6(-2) 1.4(-1) 4.3(-1) O O
. . . - . _ - _ - . - . - - _ _ . . - . _. =. . .__ __ . _ - _ _ _ _ - - _ _ - _ _ _
i . 4 TABIZ 6.6-2 (Cont'd) Releases Frem ::he Secondar-r Side !O Release (Curies) i '0-2 hours 2-2.46 hour _s I I-131 5.7 1.3
, Kr-85m 6.8(-1) 1.6(-1) :
Kr-85 3.0(- 1) 9.2(-2) Kr-87 3.7(-1) 8.5(-2) Kr-88 1.2(-1) 2.7 ( -1) Ie-131s 6. 7 (-1) 1.5(-1) Ie-133- 8.2(+1) 1.9(+1) Ie-135 3.4 7.9(-1) O Ie-138 1.6(-1) 3.S(-2) i i
'O J
i 4
TABLE 6.6-3 Radiological Consecuences of a control Element Assemblr Eiection Accident Doses Frem the Containment Release Organ Dese (Rem) At the EA3
% tole Body 4.6(-5)
Thyroid 4.4(-2) At the I2Z ktole Body 1.4(-4) hyroid 1.3(-1) Doses Frem the Secondarv Side Releases Organ Dese (Rem) At the EAB Whole Body 2.9(-4') Thyroid 3.3(-1) At the I2Z Whole Body 1.9(-4) Thyroid 2.3(-1) O O
.~-.- . . , - . - _ . - - . .. . .. . .
q: . I. -
- 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 i generator will also initiate closure of the feedwater isolation and i feedwater pump discharge valves on both steam generators, a five percent flow has been conservatively assumed. If the break occurs f between the steam generator and the isolation' valve, blowdown of the ' rO affected steam generator continues. Flow from the intact steam genecator stops with closure of both isolation valves, either of which
' is capable of stopping flow.
4
- Since the steam generators are designed to withstand reactor coolant '
a system operating pressure on the tube side with atmospheric pressure on the shell' side, the continued integrity of the raactor coolant i 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 j' p presented in Table 6.7-3. As shown in Table 6.7-4, the offsite doses l- () from this accident are small fractions of the 10CFR100 exposure limits. 4 4 d 1 k i i j i + 1
TABLE 6.7-1 Sequence of Events for a Stean Line 3ceak Accident Tim , (sec) Event 0 Steam line rupture occurs. 7.9 Steam generator pressure - lov trip signal is generated (578 psia). Main steam isolation valves begin to close. 8.S Trip breakers open for trip on lov i steam generator pressure. 9.3 Shutdown CEAs begin to drop into the i reactor Core. 14.S Main steam isolation valves are closed; intact steam generator is isolated. 17.5 The pressurizer empties. 22.8 Safety inj ection actuation signal actuated on low RCS pressure (1578 psia). 182.4 Affected steam generator blevs d:f. 1800 Plant cooldown initiated using atmospheric dump valves. 7200 Average reactor coolant temperature ~< 325 7, shutdown cooling initiated. O, , I i l i I i l
P 4 TABLE 6.7-2 Assumotiens_ Initial Power 1..'We l Required Shutdown Margin -4.3%A P Only one of tha threo HPSI pumps is assumed to be available. No credit was taken for charging and letdown flows. , O V The break assumed is a double ended rupture of a main steam line outside containment and upstream of a MSIV. Blowdown from the affected steam generator is saturated steam; no credit is taken for moisture carryover. Automatic trip of the reactor for this event is initiated by a Low Steam Generator Pressure Trip Signal. No credit is taken for the check valve in the main steam isolation valve assembly of the ruptured steamline which teminates the blowdown from ne steam generator with intact steamline. The teactor coolant pumps are left in operation even after safety injection occurs. At 30 minutes the operator initiates plant cooldown via acnospheric dump valves . DEC of I-131 Reactor Coolant 60.uci/gm Secondary Coolant 0.1.uC1/gm Noble Gas Reactor Coolant FSt.R Table 11.1-1 Primary-to-Secondary Leakage 5 spm Upon entering the affected steam generator, all of the leaking coolant is assumed to instantaneously flash to steam which is released to the atmosphere. Atmospheric Diffusion 0-2 hour at the EA3 1.2(-4)sec/m3 0-8 hour at the LPZ 6.6(-5)sec/m3 O a s
i i l TABLE' 6. 7-2 ~ (Conc *d) Assumetions i 3reath1=g Race 3.47(-4)m /sec ; Mass of Steam Released Intact Steam Generator l 0-0.5 hours 41314 lbm l 0.5-2.0 hours 175936 lbm Affected Steam Generator I O -04 hours 246181 lbs
- 0. 5-2.0 hours 1084 1ho O
J O i l l
i TA3 T 6.7-3 Radionuelide Releases 4 Release (Curies) 4 I i 1.5(+2) i '
- 1-131 DEC l l
I i I 4 l Kr-85m 3.4 Kr-85 2.0 i 1.8 4 i Kr-87 Kr-83 5.9
,t Ie-1312 3.4 ;
i ! Ie-133 4.1(+2) , i I ! Ie-135 1.7 (+1) r Ie-138 8.2(-1) i f l l l l t i e l i
TABLE 6.7-4 Radiological Consequences of a O l Scea= Line Break Accident organ Dose (Rem) At the EA3 Whole Body 1.4 (-3) Thyroid 9.1 At the I2Z Whole Body 7.5 (-4) Thyroid 5.1 0 E. 4 4 O r 49
')
i O
4. l Section 7 - ALTERNATE ENERGY SOURCES
~
i l l
< There are several alternate energy sources available to replace the
- . stretch power of St. Lucie Unit 1. Purchased 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 j
fossil fuels and by a fuel cost analysis alone, render them inferior to the St. Lucie Unit 1 stretch power. Other considerations are; j capital requirements, envi onmental impact and potential for the l reduction!of oil consumption which is the primary goal of the National Energy Policy. All of these considerations results in the St. Lucie Unit i stretch power option as the superior choice. - l i l d i i i I i b ! O. I v l # i l 8 35 - 1 T"SC g e+'u'-tyr e*--gr M q w y w-vwvowwevir-?mg-
O , i t O ATTACIDIENT 1 ST. LUCIE UNIT 2 ENVIRONMENTAL REPORT - OPERATING LICENSE, l SECTIONS 2.1.1, 2.1.2 AND 2.1.3 0 I O O i 1 1
)
SL2-ER-OL ,' po o q-cwI o .S_ _a n 2.1 CEOGRAPHY AND DEMOCRAPHY (v)' 2.1.1 SITE LOCATION AND DESCRIPTION 2.1.1.1 Speci fication and Location Florida Power & Light Cnmpany's (FP&L) St Lucie site is located ou Hutchinson Island, St Lucie County, Flortda. St Lucie Unit 2 is located at latitude 27 20' 55" north and longitude 80" 14' 47" west; the Universal Trans-verse Mercator (UTM) coordinates are 3025150 meters north and 574500 meters east in Zone 17. Approximately 300 feet co the north of St Lucte Unit 2 is FP&L's St Lucie Unit 1, which has been operational since 1976. The coordt-( nates for St Lucie Unit I are latitude 27" 20' 58" north and longttude
)
80 14' 48" west; the UTM coordinates are 3025250 meters north and 574450 meters cast.
The eastern boundary < f 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 miles to the west-southwest of the site and a portion of the Everglades approx - mately 24 miles to the south of the site. Figure 2.1-1 shows the site tn relation to the region wi thin 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 seien miles to the northwest of the site; Port St Lucie, 4.5 miles to (s')
the .auth southwest of the site; and Stuart. 8.0 miles to the south of the site. The largest urbanized area within 50 miles of the site in West Palm Beach located 36 miles to the south southeast . All distances are straight
~
line measurement. fran the site to the closest boundary of each city or area. Transportation facilt ties a than five miles of the site include U S Highway 1; State Roads (SR) A1A, 712 and 707; the Florida East Coast Railroad, ship-pang on the Atlantic Ocean and .ne Intracoastal Waterway which is located in the Indian River. SR A1A, the major north-south route on Hutchinson Island, t raverses FP&L's property to the east of St Lucie Units 1 and 2. Figure 2.1-2 shows the location of these transportation f ac i li t ies. 2.1.1.2 Site Description (O) A map of FP&L's St Lucie site is shown in Figure 2.1-3, ent i t led 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 of land. The site is generally flat , and has dense vegetation characteri stic of Florida coastal mangrove swamps. At the ocean shore, the land rises sitghtly 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 factitties fo r S t Lucte 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.
,a 6 I
\ / u-
. 2.1- 1 r
i D**0 90 9 SL2-ER-OL w@! S 1.' }t
. o
~
There are no industrial, cretmercial, institutional, recreational or resi-dential structures within the plant area. SR A1A' traverses FP&L's property approximately 1,000 feet east of the St Luete Unit 2 containment building. The exclusion area and the low population zone are shown in Figure 2.1-3. The radtus of the exclusion area is 0.97 miles frna the St Lucie Unit 2 containment butiding. The low population zone includes that area wi thin approximately one mile of the St Lucie Unit 2 reactor. 2.1.1.3 Boundartes for Establishing Effluent Release Limits The mtntmum boundary distance for establishing gaseous effluent release limits is that noted on Figure 2.1-4, Property Plan, directly north of the St Luete Unit 2 reactor containment building. Also indicated in Figure 2.1-4 are other boundary line distances frm plant liquid and gasesous re- : lease points. The restricted area, as defined in 10CFR20 includes the fenced area shown in Figure 2.1-5. [ 2.1.2 POPUIATION DISTRIBUTION 2.1.2.1 Population Within Ten Miles Table 2.1-1 and Figure 2.1-6 show the di stribution af present and projected j population within ten miles of St Lucie Unit 2. The estimated 1979 popula- j t son vithin ten miles of the plant ts 71,051 persons, concentrated in the etties of Fort Pierce and Stuart which are the seats nf government and g[ centers of activity for St Lucie and Mart i n Count i e s, respectively. Most 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 , fall wi thi n Martin County. The gal populat ion in 1973 for St Lucie County ia estimated to be 75,500 persons . The 53.095 residents of St Lucie County, wi thin the ten stle radius, represent 75.9 percent of the county total. In the same manner, t he 12,956 residents of Martin County, within the ten mile radius, comp 24.4 percent of the total est tmated county population of 53,100 in 1978 2.1.2.1.1 Cities, Towns and Settlements Cities, towns and settlements wi thin ten at ter. of St Lucie Unit 2 are shown in F tgure 2.1-7. All or part of several incorporated areas fall within the ! ten male radius. The largest of these as the city of Fort Pierce, with an estimated 1973 population of 33,083. The mainland portion of Fort Pierce f alls in sectors NW and NNJ, while the sect ion of Fort Pierce on the northern end of 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 populat ion i s located wttuan tne itve to ten stle annulus. A oart of the Fort Pierce i ncorpora t ed area, a long narrow extension to the southeast , emes wi thin 4.1 miles af St Lue te Uni t 2. How- [' ever, most of this area consists of the Savannahs Recreation Area and has few residents. 2.1
- Il f l
i .
- SL2-ER-OL I The second incorporated area in St Lucie County' wi thin the ten mile radius .
St Lucie in is the city of Port St Lucie.ge total population for Port 19.78 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 i the S to W sectors. Although lots have been platted and sold in many sec-tions, residential development ig978isconcentratedinannularsectorSW
-five to ten and WSW ' five to ten . In 1978, that part of Port St Lucie east of US Highwa i tial development {4), (US 1) within five miles of the site, has no res den-L
! A portion' of the incorporated area of the city of Stuart falls within an-I nular five Sector to ten. 'Ihn estimated 1978 population for the city of j Stuart is.10,760 persons. As in the Fort Pierce area, the city of Stuart 4 v of fers residents services and employment, proximiry to the Atlantic Ocean and beaches, and access to Hutchinson 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 crumunity 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. 4 g Along the western shoreline of the Indian River (paralleling SQ7 east of the Florida East Coast Railroad) is a ridge of- dry sandy soils . This area, which is predominately low density residential throughout the five atle 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. Ap p ximately 40 e percent of its land was developed for residential use in 1973 . Collins a Park Estates, also 'in' annular sector WNW four to five, is west of Indian 1 River Estates and is smaller in area but more densely settled. Together, I these developments contain about 500 dwelling unit s. Spanish Lakes is another major development in the unincorporated county
- insigthe five mile radius. This mobile home community, which has 1387
! lots , is located in annular sector WSW four to five, east of US 1.
3 t To the . west of US 1, in sector WSW, the developers of.Spanish Lakes have coepigd a second which has a total of 620 In both project called Riverfront, 4 1- units . projects, a significant proportion of dwelling units j are owned or occupied by seasonal vt stors rather than residents. There are extensive areas of vacant land south of Indian River Estates 4 between US 1 and the coastal ridge. Portions-ofthisareaarebeg i acquired by the State of Florida for the Savannahs State Preserve' . On Hutchinson Island, in 1973, all resident population within the five mile , radtus'was limited to annular sector SSE four to five. The 1928 persons in 4 SSE' four g f tve included residents of Nettles Island, a trailer park of 1583 lots , most ~ of which are located in a man-made island reached by {
". 2.1- 3 '
- -_ . - , _ . , f . -- - . - -- -I
SL2-ER- OL o short causeway. Many of the lots are owned or rented by persons who are . s;asonal vistors. 3 2.1.2.1.2 Population by Annular Sectors The most heavily populated annular sectors are those which cover the towns cnd developments mentioned above. The most heavily populated annular sector in 1978 was NW five to ten, which includes much of the city of Fort Pierce with an estimated 36,483 residenta. 2.1.2.1.3 Population by Annuli In 1978, the annulus between five and ten miles of St Lucie Unit 2 was more , dansely populated than the area within five miles. Population density for , the five to ten atle annulus (excluding the seven sectors over the Atlantic Ocean) has 473 persons per square sile. Inside five miles, the four to five , crie annulus has a density of 427 persone per square mile. In 19 78, the area within four miles of the plant wcs sparsely populated , wi th ; cn overall density of 46.1 persons per square mile (excluding the five sec- i tors over the Atlantic Ocean). Within two miles of St Lucie Unit 2, there j was an estimated total of 97 residents, a population density of approx- j imately 11 persons per square mile. The entire area wi thin one mile of the ; plant is owned by FPSL and is included in the exclusion area and low popula- i tion zone. Much of the area in the one to two mile annulus is over water. 2.1.2.1.4 Population by Sectors The most populous sector within ten miles of St Lucie Unit 2 is the NW sector which, because of the large concentration of resident population in the city l of Port Pterce, contains 36,657 persons. The second most heavily populated l s:ctor is SSE, which has 9140 persons and includes Hutchinson Island, the , l Atlantic Coast in the vicinity of Stuart, and Nettles Island. The adjacent
- s
- ctor, S, is thtrd highest with 7179 residents in 1978.
2.1.2.1.5 Proj ected Population - The population wi thin ten miles of St Lucie Unit 2 is expected to more than l double during the life of the plant , from 71,051 in 1978 to 158,851 in 2030. This represents an increase of 123.6 percent over the 52 year period, l cn average annual rate of growth of 2.4 percent. The State of Florida is t expected to grow by an average annygi g yate of 2.1 percent, or by 88 percent i ovar the period from 1978 to 2020 , as discussed in Section 2.1.2.2.5. It is expected that in the year 2030, as in 19 7*, sector NW will have the j highest population of all sectors, 54,756 persons, but will have the slow- ' est rate of growt h, 49.4 percent over 52 years . Li ke wi se , annular sector NW fi ve to ten is expected to grow from 36,483 to 54,497, a gain of 49.4 pareent. In 2030, the second highest population by sector is expected to bs in sector WSW, which will grow by 268.7 percent from 6691 residents in 19 78 to 24,669 in 2030. i , 2.1-4 :
e . _ . . __ 9 9 ~F W]D 0 D 6 Ju 6 L u 3 SL2-ER-OL 4 () v Wi thin the ten ma le rad tus, the sectors expected to experience the highest growth rate are sectors SW and SSW. They are estimated to grow by more than 1200 percent, from 812 to 13,971 residents, and from 1,434 to 19.i27, respecttvely. Both sectors will shev an increase from the expecteo con-4 t anued growth of Port St Lucie. The Fort Pterce area vill maintain a significant share of the total popula-tion within ten miles of St Lucie Unit 2. However, Port St Lucie will gain a n sta 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 of fers more moderately priced housing than traditionally available at beachfront locations.
" Port St Lucie is one of the strongest growt h areas in St Luc is 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 tnerease of approximately 1900 percent .
If building permit activities of 1975,1976 and 1977 were to continue , it is possib hat Port St Lucie would reach a population of 36,000 by the year 2000 Within the etty limits of Portg Lucie, a proposed development of 2,200 dwelling units, called Midport , has begg0a ggy ved under State Develop-ment of Regional Impact (DRI) regulations It s estimated population q of approximately 5000 people will reside an annular sectors SSW and SW be-j tween 3.5 and 5 5 miles of St Lucie Unit 2. be completed and fully occupied by 1983. It is expected that Midport wi ll Therefore, the 1983 population
! estimates include tne 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 will 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 occupted by seasonal visitors rather than residents. The part of Hutchinson Island which falls within the five mile radius is another ares expected to undergo considerable growth. In 1978, there was a total of 1,923 residents; this population is expected to reach 2,678 by 2030, a gain of 39 percent. These residents will prooaoty represent only y a fraction of the Island's future population since sany new dwelling units for seasonal visitors and tourist accommodations will be constructed on this highly valued beachfront property. In annular sector SE one to two, a project called Sand Dollar Vilias is under construct son and schedg for ennplet inn in 1980. It will have 203 apartments and 32 townhouses . Wh11e it is likely that development wi11 continue to occur in the fonu of projects such as Sand Dollar Villas, it is simpossible to predtet the size and locat ion of such project s until they are i initiated. County planning of ficials have indicated that congestionofthebggg i i
,") frna the matniand to Hutchtnson Island could restrict development A bridge has been proposed which would cross the Indian River at SR 712 2.1-5 am. 1 e'm --
w++ ty - y m W
SL2-ER-OL andligg3 1, the Florida Turnpike , and Interstate. 95 to !!utchn.un Island An additional rtver crossing would induce development on the Island. However, it i s uncertain i f, when, or Jtere another river crossing will be constructed because the yg s of the TnAian oiver 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, wi thin ten atles ot' St Lucie Unit 2, is presented in Table 2.1-2. In each annular j sector, the number af people under 11 years of age; between 12 and IS; and over 18 have been estimated, d on the distribution of these age groups in the United States in 19 70 . 2.1.2.2 Population Between Ten and 50 Miles Table 2.1-1 and Figure 2.1-8 show the distribution of the est 3 mated 1973 population between ten and 50 miles of St Lucie Unit 2. The estimated 1978 population is 412,714 persons (see Sect ion 6.1.4.2, Methodology) and repre-sents 85.3 percent of the totti population within 50 miles of the plant. This population is confined to sectors SSE through NNW since sectors N through SE, beyond the ten atie radius, include only the Atlantic Ocean. The major concentration of population occurs in annular sector SSE 40-50, which includes the ;s ty of West Palm Beach. West Palm Beach is the northern itmit of the Florid: Gold Coast development extending north from Miami through Dade and Broward Counties into Palm Beach County. The 126,615 resi- f dents in annular sector SSE 40-50 live on approximately 48 square miles of j land (the eastern three quarters of annular sector SSE 40-50 extends over the : Atlantic Ocean). Annular sectors S 40-50 and SSE 3)-40 have the second and third highest populations, respectively, per annular sector, and re flect that Palm Beach County is more highly developed than any other n,1rt of the region. In the 1970 Census, Palm Beach County was one of the nine Standard Metropolttan Statistical Areas (SMSA's) in Florida. Of the total 525,200 l' resident s of Palm Beach County in 1978, 277,881 lived within 50 miles of St Lucie Unit 2. 2.1.2.2.1 Cities and Towns Between Ten and 50 Miles Table 2.1-3 1: st s towns, cities, and ensmunities wi th a 1973 population of more than 5,000 persons (see Figure 2.1-9). There are eight towns with a l population of = ore than 10,000, the largest of which i s West Palm Beach, wi th l a 1973 population of 62,616 (see Methodology, Sectica 6.1.4.2). The second largest is the etty of Fort Pierce, with 33,083 persons; the third largest is } Rivtera Beach an Palm Beach County, with 27,735 persons; and the fourt h I lardest ts Vero Beach, seat of government for Indian River County, wi th f 16,800 pe rsons. Of the etght largest towns gve 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 city in Martin County, has.an estimated 1973 popuation of 10,760. I 2.1- 6 ,j I
?
i
4 J SL2-ER-OL i l Of the esght towns with populations between 5,000 and 10,000, four are l- within the We st Pilm Et ..h Urbanized Area. These include the towns of Palm
~ Beach, with 9,952 persons; Lake Park, with 8,652 persons; Greenacres City, with 6,773 persons; and Royal Palm Beach, with 5,598 persons. Pahokee, with an estimated 1973 population of 5,864, is also in Palm Beach County but as Iocated in the northwestern quarter of the county, on the shore of Lake Oksechobee.
i~ There are three other towns wi th populations between 5,000 and 10,000 persons. These include Gi f ford, located in Indian River County, with an estimated 1978 population of 9,485; Jupiter in Palm Beach C..unty vi th 9,156(p$ople; and Port St Lucie, in St Lucie County with 6,465 resi-dents . e e W e ? , e e E 9 ) l ! l i 1 2.1- 7 s s 1
SL2- ER-OL 2.1.2.2.2 Populat ton by Annular Sectors .
~
The e st heavily populated annular sectors between ten and 50 miles from St Lucte Untt 2 are those which enempass the cities and towns with the greatest populations an di scussed in Section 2.1.2.2.1. The an s t po pulou s canular sector, SSE 40-50, includes West Palm Beach, Palm Beach S' ores, Rtviera Beach, and Palm Beach (see Figure 2.1-3). Immedi a t e ly t o t he we s t of annular sector SSE 40-50 lies the second most populous annular sector, S 40-50,' including Greenacres City (6,773 p]rsons) and Haverht11 (1,004 persons estimated fo r 19 78 ) , afld ll "" numerous large residential developments of up to 7,400 acres . The third most populous annular sector between ten and 50 miles from ~ St Lucie Unit 2 Ites north of West Palm Beach on the Atlantic Coast (SSE 30-40). Although tts land area is less than half of the 137 square miles which emprise the annular sector, it includes Lake Park, , North Palm Beach, Juno Beach, portions of Riviera Beach, Palm Beach Ostdens, and the tow of Jupiter, all of which are heavtly populated. When the above three annular sectors are cmbined , they emprise 59.6 parcent of *.he total population between ten and 50 miles of the St Lucie Unit 2, 2.1.2.2.3 Population by Annuli Populations by annuti between ten and 50 miles of St Lucie Unit 2 range in number of restdents from the largest, with a total of 211,061 persons (the t 40-50 miles annulus), to the smallest, with 51,504 persons (the ten to 20 ctle annulus). The annulus between 30 and 40 miles has the second largest population of 83,240, while the annulus between 20 and 30 miles contains 66,909 persons (see Figure 2.1-3). The 40-50 mtle annulus has not only the largest popialation (211,061 ) and the greatest overall area (approximately 1,590 square miles, excluding the i stven sectors over the Atlant se Ocean), but also the highest popula t i on dinsity in the regton. The population density of the 40-50 mile annulus is 133 persons per square at te. Ni nety-one pe rcent of the population is located on 22 percent of the tot al annulus area, in sectors 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 Lucte Unit 2 are those which cover the West Palm Beach area and the Atlant te Coast. Sectors SSE and S have est tmated 19 73 populat tons of 206,199 and 90,040, respective-ly, and denstt tes of 433 persons per square mile and 133 persons per square { mile, r e s pe c t i ve l y. 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 l* populat ton of 19,037 and a density of 40 persons per square mile. The ftve remaining sectors have densttles whtch range fem two to 31 persons per square atle. - The sparseness of population in the ftve interior sectors can be attributed to extens tve acreage covered by wet lands and surface water (Lake Okeechobee), Ol 2.1-8
S L2-ER-OL (r) v inaccessibility' to population centers, and the extent of range and cropland. 2.1.2.2.5 Proj ected 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 19 78 and 2030, or from 412,714 to 913,463. The average annual growth rate for this area would be 2.14 percent i for the 52 year period. Thts rate of growth can be compared to the rate per year from for the Statg og) Florida, which is expected to be 2.1 percent 1978 to g Florida and 0.76 percent pe r ye ar fo r the Uni t ed S t a t e s from 1973 to2025({}0 is presently one of the most rapidly growing states O
\'.
in the US. Between 1970 and 1977, the state grew by 23 percent , a net addition of almost twomilijggpeople. 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 51 miles of St Lucie Unit 2 occurs in Palm Beach County in the sectors including 2nd tdjacent to the Atlantic Coast. Major development activity outside of Palm Beach i s 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 Martin, St Lucie, Indian River; and southern Brevard Counties. Land to the west of this region is mostly used for pasture, agricultural production (citrus, sugar cane, and truck farming), or remains un-N 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 of these projects which lie west of the Atlantic corridor has yet taken place. Deve lopment is focused in the Atlantic corridor for reasons such as the following:
- 1) Proximity to existing population centers and services;
- 2) Access to the Atlantic Ocean and Indian River, and the amenities they provide: scenic beauty, sports and re-
-g creation, tourtst industry potential; \-' 3) Presence of sotis suitable for developmen: on the coastal ridge;
- 4) Zontng and planning policies developed by county and ,
regional agencies which permit development in these areas; and
- 5) Availabili ty of land sui table for development .
Only three signif teant clusters of development occur out side 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 [)
%- WSW between 30 and 50 miles of the plant). On the southeaste n shore of the 2.1-9
S L2-ER-OL Icke an Palm Beach County, the community of Pahnkee serves the agricultural communt ty of the western sect ton as well as the sport fishing community using the lake. A few miles north of the lake tn Okeechobee County, a regional crater has developed at Okeechobee Ct ty. The third location where signt-ficant deve lopme nt i s occur ring is Indt antown , in south central Martin County, at the intersection of the St Lucie Canal and the Seaboard Coast
. Rcti Line.
The following is a summary of development trends by county withi~n 50 miles of St Lucte Unit 2. c) Palm Beach County The principal area of growth within 50 miles of St Lucie Unit 2 is in the northeastern quadrant of Palm Beach County, which lies south of the plant, at a distance of more than 27 miles. About 40 percent of Palm Beach County f alls within 50 miles of St Lucie Unit 2; the total . population of this area is expected to increase from 2 77,381 i n 19 73 l to 617,422 in 2030. This increase represents a growth of 122 percent , } over the entire period, or 2.3 percent averaged annually. The cor- ' ' rtdor in Palm Beach County between the Atlantic Ocean and the Florida Tur np tke t s intensively developed wi th cont iguous towns and ctries , ; such as Palm Beach, West Palm Beach, Riviera Beach and Lake Park. l Resident tal development activi ty in 1977 included a sizable number of ; dwelltn ts under construction west of the Turnpike in sectors S and SSW Deve lopme nt is expected to continue in this area because of strong growth to date and its reputation as a desirable ' place to itve. Many developments include self contained recreation ; < amenttles. The Professional Colfers' Associa{g (PCA) has recently located its headquarters in Palm Beach County Another area of growth exist s in the northwestern quadrant of Palm Beach County where Pahokee is located on the shore of 7 2ke Okeechobee. Pahokee is one of the 15 largest e tt ies and towns wi tnin 50 miles of j St Lucie Unit 2 (see Table 2.1-3). It has an estimatei population for 1973 of 5,364. b) Martin County While Palm Beach County has the greatest population, Martin County has the highest rate of growth. Nearly all (75 percenti of Martin County's 1978 population resided between ten and 50 miles of the plant. The remaining residents were wt thin ten miles of St Lucie Unit 2. The 1973 total of 39,359 persons between ten and 50 miles ! , as expected to grow by 139 percent to 94,359 by the year 2030. This ! representa an ave rage annual growt h rat e of 2. 7 pe rcent . The city l of Stuart is the major populatton center for the county; in 1973, t t s estima ted populat ion of 10,760 represent s 20 percent of the total county populatton of 53,100. Population is expected to grow in and , around the city of Stuart g on the barrier beaches in the Atlantic { Corridor in Martin County Indi antown , wi th an est imat ed 19 73 population of 3,411, is an in-corporated area locat ed approximately 26 mt les sout hwest of St Lucie 2.1-10 1 (
. SL2-ER-OL Unst 2, at the intersection of SR 710 and SR 76. FP&L i s presently const ructing at the Martin County site two generating units and a .
] 6,600 acre cdoling lake w g of Indiantown. Two addi t i onal un i t s will be constructed there .
The western part of Martin County is largely range and cropland , wi th few permanent restdent s out side of Indiantown. A project fomerly known as " Rotunda", and now called Palm Beach Heights, was proposed for land west of the Turnpike and was platted and sold for home sites. To date, there has been no actual development of these properties, and the wetness of sotis is e ed to ilmit'the development of many lots which have been sold c) St Lucie County St Lucie County extends from the plant site west to the 30 mile radtus. Of the County's total estimated population of 76,500 in 19 78, approximately o'ne quarter, or 19,131 persons, are estimated to reside outside the ten mile radius. This number is expected to grow at the rate of 120 percent (or 2.3 percent average annual rate) to a population of 42,226 in 2030. St Lucte County's major population center is the city of Fort Pi e rce , with an estimated 1973 population of 33,083, located inside and out of the ten at te radius. While the county as a whole grew 29.4 percent between(g0and1970,thecityofFort Pierce grew only 17.7 percent . As Fort Pterce te built up, development is expec $ ) ' to occur within the Atlantic corridor, outside the city limits ' .
- In St Lucie County, the only coastal area outside the ten mile radius lies north of the St Lucie Unit 2. Sectors NW and NW con-tain more than 85 percent of the 1973 St Lucie County population -out-side of ten miles. The western portion of St Lucie County is dominat-ed by pasture and croplands.
In 1974, Ashland Ot t proposed a refinery and new town fggghe north-west corner of the county where the Turnpike runs NW-SE No f tra plans or schedules exist for the development of this area, d) Indian River County All of Indian River County falls wt thin the ten to 50 mile radius. The county populat ion, g amated at 50,776 in 1973, is expected to v grow to 109,270 by 2030 . Thi s overall growt h of 115 percent represents an annual average growth of 2.2 percent. The principal communtty in the Atlantic corridor is the county seat , Vero Beach, wtth an estimated 1973 population of 16,765 persons (one-third of t he tot al county populat ion) . Other enties and towns inc lude Gi f ford, 9,475 persons for 1978; Sebastian, 1,556 persou. m 197d; and Indian River Shores, 1,013 persons i n 19 73. Only oae settlement, the Town of Felismere, wtth a 1978 population of 1,056, is locateu out side t he Atiantic corridor. , Astde from the ennmuni ty at "elismere 'NW 10-40), the area west of Interstate 95 is for the most part protected wet lands which are part of the St Johns River Flood Cont rol Di st rict . . O ! 2.1-11 l l
SL2-ER- OL o) Brevard County , The portion of Brevard County (about 18 percent of tot al county land area) which lies within the 50 mile radius of the St Lucie Unit 2 has a 1978 population of 3,185. This number, which represent s 1.2 percent of the county's total 1973 population ts expected to increase by 80 percent, to 6,023 by 2030. Brevard has the slowest expected growth rate of the nine counties included in the 50 mile radius. Major development is Brevard County has taken place at Cape Canaveral, Cocoa Beach, Merrit Is. land, and Melbourne, all ao r ti, of t e 50 mile radius. In southern Brevard County, development has occurred al ong the Indi an Rtver and Atlantic Coast. Small communit ies include Micco, Melbourne Shores, and Floridana. The only incorporated town entirely wi thin the 30 mile radius of St Lucie Unit 2 is Malabar, which in 1970 had a population of 625. The town of Palm Bay lies to the north of Malabar, just outstde the 50 mile radius, on the Indian River. However, part of Palm Bay's incorporated area falls within the 50 mile radius. In this portton, a large-scale development called Port Malabar has been proposed. Because of lot sales and prmsot s on, development will be i directed to this area, but there is no definitive schedule which could be incorporated into project ions made at the present time. In southern Brevard, as in Indtan River County, development will be confined to the eastern coastal area because of restrictions impo sed in the western region by the St Johns River Flood Control District . f) Okeechobee County ) Located inland of Martin, St Luc te , and Indian River Count i es , Okeechobee County account s for approximately 4.5 percent of the _ residents between ten and 50 miles of St Lucie Unit 2. About 98 percent of tts estimated 1978 population, or 18,6 29 persons , reside wi thin the ten to 50 mile area. By the year 2030, this number is expected to increase by 130 percent to 42,762. With this rate of growth, averaged annually to 2.5 percent, Oke echobee County ranks second (behind Martin, with a 2.7 perccat maaaal growt h rate) in rate of growt h of all counties within 50 miles of St Lucie Unit 2. Okeechobee's populat ion is concentrated in and around the county seat of Okeechobee City. The county seat is at i the convergence of US 98 and US 441 and SR 70, SR 78 and SR 710, less than five miles north of Lake Okeechobee. This accessibtlity is ex-pected to ensure its continued growth as a regional center. The city's 1978 population of 4,490 represent ed about 24 nercent of the county total. The adjacent town of Cypress Quarters nas a population of approximately 2,176. In 19 78, t hese towns together comprised 35 percent of the total county population. A large scale de has been proposed for sectors W and WNW at the 50 mile radius {gggpment 2.l-12 l
SL2-ER- OL g) Glades, Osceola, and Highlands Counties
)^ Three counties on the periphery of the 50 mile study area contribute a total of only 739 persons to the 1978 population between ten and 50 miles of St Lucie Unit 2. In Glades County, on the northwest shore of Lake Okeechobee, a community known as Buckhead Ridge has developed since 19 70. Although only 12 percent of Glades County's land area falls within they*gigadius, its most s i gni fi cant growth occurs in this location '
. The only other settlement of greater size is the county seat of More Haven, whigad a 1970 population of 974, an increase of 23.3 percent from 1960 . Buckhead Ridge 's
$66 permanent residents represen g proximately ten percent of the total county populat ton for 1978 lo)
V Osceola County is included in the 50 mile rad tus in sectors NW and WNW. Approximately three percent of the county's 1,313 square miles are included in the 50. mile radtus. There, the small se g ment of Yeehaw Junction is estimated to have 119 persons in 1979 . The population is expected to increase by 123 percent to 265 in 2010, which is an average annual growth rate of 2.37 percent. Like Osceola, Highlands County nas roughly three percent of its land area within the 50 mt In this area, a small set e t=ent has developed on SR 70 t35fius. Its 1978 estimated populatinn of 100 is expected to grow by 106 percent, to 206 in 2030. The average annual growth rate is expected to be two percenr. Highland = County's predominant growth is expected to continue outstde of the 50 mile radius in the vicinity of gr%3pvon Park and te" Discid, in the central part of the county ALL three interior counties (U) reflect the low levels of development taking place in Florida's central regions, which are not adjacent to the Atlantic or Gulf coasts. 2.1.2.2.7 Projected Crowth Rates Between Ten and 50 Miles The total population between ten and 50 miles is expected to grow by 121.3 percent frna an estimated 412,714 persons in 197S to 913,463 in 2030. The area of greatest growth between ten and 50 miles of St Luete Unit 2 is in Palm Beach County, in the three annular sectors surrounding West Palm Beach. Annalar sector S 40-50 is expected to experience the highest rat e of growt h, with its 1978 populat ton growing by 183.4 percent from 65,250 to 176,411 in
,s 2030. Annular sectors SSE 30-40 and S 30-40 are each expected to grow by 170 parcent over the enttre 52 year pertod. In contrast, a relatively low rate
(()) of growt h a s expected for annular sector SSE 40-50 which contains the city of West Palm Beach. This can be attetbuted to the shi ft in development from heavtly urbant ed areas to vacant land in the north and west as well as to the recognt ed tendency of heavily populated areas to exhibit low growt h rates pt surrounding areas wt th low denas t ten undergo high rates of growt h Another area showing relatively intensive growt h is locat ed sout h and sout h-west of the plant between ten and 30 miles. This includes Martin County's Atlantic corridor and the etty of Stuart . Because the method for est ima t ing growth by annular sector ts based on projected growth far eaca county, the i -
/
2.1-13 W
SL2-ER-OL annular sectors refleet the growt h rates for the county occupying the major ! portton of the sector, s
'\
4 The fastest growing annulus is expected to be between 30 to 40 miles of St Lucte Unit 2. This band is influenced by the high rates of growth expected for south and southeast sectors located just north of b'est Palm ! B2ach. The greatest growth by sector is expected to occur in sector S which Encludes the expanding area west of the Turnpike in Palm Beach County as wall as the area surrounding Stuart in Martin County. 2.1.2.2.8 Age Dietribution The age distribution of the projected popula't ton for the year 2000, between tcn and 50 miles of St Lucie Unit 2, is presented in Table 2.1-4. In eech ' t ennular sector, the numbers of persons under 12 betwee.n 12 and 18, and over troups in the 18 were estimated basggn the, distribut ton of these age United States in 1970 2.1.2.3 Transient Population Transient population within 30 miles of St Lucie is estimated to be 74,363 psrsons in 1978. This figure is based on estimates in each annular sector of peak datly tourist s and seasonal visitors. These estimates are presented in Table 2.1-5 and in Figures 2.1-10 and 2.1-11, and represent both daily cnd seasonal variations in the movement of persons or their temporary radistrtbution within the 30 mile radius. I, As in much of Florida, this region experiences signi ficant fluctuations in s population as thousands come to the area for the wanter season (generally frcci Christmas /New Year to Easter) or for succer or winter vacation. Many j at tract tons and events are held throughout the year which draw thousands ; of people. Although few in number, major industries and colleges draw many _ wc.rkers and students every day. The population from each of these sources has been estimated , and projected for the required years through 2030. Estimates and projections for these three components are presented in Tables 2.1-6, -7 and -8, and discussed in the sections which follow. Transtent populat ion result ing from transportation by road , rail, water-way, and air is estimated by calculating the average daily passengers at locations where vehicles or passenger counts have beea cade. To avoid double counting, passenger estimates have not been incorporated into transient totals by annular sector. . Throughout the region, Atlantic Coast beaches are enjoyed for thei r scenic beauty and recreat ion potential. Both St Lucie and Martin Counties provide
;...blic access st ri ps to the beaches, and State sovereignty guagees public access to all lands seaward of the mean high water line .
Because of the lack of cmprehensive data concerning both the use of the beaches and the number of users, estimates were not included in peak daily transient totals. The only data available on beach usage is as fnllows: 2.1-14
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,o c o N. h .L :2 Best estimates available from St Lucie Councy(36) indicate that average daily beach usage was 656 persons at four guarded beaches on llutchinson ' V Island. Between October 1,1977 and September 30, 1978, a cumulative total of approximately 239,000 persons attended all four beaches in sec-tor NNW. If beach usage were to grow at the same rate of growt h as resi-dent and seasonal population, average daily beach usage would reach 1,503 by the year 2030.
In Martin County, there were two guarded beaches within ten miles of St Lucie for both was estimated at Unit 2(insectorSSEg)Averagedailyusage 2,340 persons in 1973 . This number could be expected to reach 5,362 by 2030. Attendance is the greatest in the summer. It was estimated that as many as 2,000 persons attend Jensen Beach, at the junction of 42nd Street ( frnet the Jensen Beach Bridge) g SR A1A on holidays such as Q Memorial Day, Fourth of July and Labor Day 2.1.2.3.1 Tourists and Seasonal Visitors The total of tourists and seasonal visitors within ten miles of St Lucie Unit 2, in 1978, is estimated to be 28,179 (see Table 2.1-5). This figure includes persons staying in tourist accommodations, campgrounds, d we lli ng units occupted by seasonal visitors, and visitors staying with friends and relatives. Inside the ten mile radius, the following annular sectors had the higher.t transtent population totals in 1978: p a) NW, zero to ten, had an estimated 7,804 tourists b) SSE, zero to ten, had an estimated 11,572 tourists These num'acrs reflect the fact that both sectors have the greatest number of tourt^t accomtendations as compared with the other annular sectors. Sector SSE, fo r instance, contains three campgrounds on Hutchinson Island: Vent ure Out ; Windmill Village and Holiday Out - St Lucie. Sector NW has a .high resident population which presuma,bly houses out-of-town vi si tors. Between ten and 30 ailes of St Lucie Unit 2, the greatest number of touri st s in 1978 were located in sectors NNW, with an estimated 19,460 visitors, and SSE, wi th an est imated 11,755 vi si tors. These numbers reflect the fact that between ten'and 30 mtles of St Lucie Unit 2, these sectors af forded the largest number of tourist accommodations, such as motels, campgrounds and 1 pe rmanent restdents' homes. Estimates for the 1978 tourist population and project s through 2030 are presented in Table 2.1-5. 2.1.2.3.2 At tract ions and Event s Many attractions and events draw large crowds in this part of Florida; they include high school football games, major league exhibition games, county fairs,jat alas frontons and a dog t rack, tournaments, rodeos, and fest i-vals. Attendance at events within 50 miles of St Lucie Unit 2 is presented in Table 2.1-6 for the years 19 78 to 2030.
- q (O
f 2.1-15
~ ~
e
SL2-ER-OL Wi thin the ten mile radius, peak daily attendance in 1973 occurred at two w;1k through events. Each lasts two days, and has a total est imated . cttendance of 40,000 persons. The Art-on-the-Creen Festival brought 20,0 g rsons per day to the Indian River Memorial Park in January of 1978 In March, 20,000 persons walked through(g auto Snow, neld ct the St Lucie County Civic Center in Fort Pierce . The third icrgest eve nt was the Jensen held .in the Jensen Beach Causeway each Fourth of July (gchOther Fireworks, attractions include p school football games held at Lawnwood Stadium in Fort Pi erce 'ghigh , and cnnual eventg473ch as the Saa lfish Festival Regatta (a hydroplane event on t in Jensen Beach in Marc;.ge 3E 0 l Lucie River) , the October Art , i ths Sandy Shoes Festival (a weekg) events with a cauntry and western theme) in Fort Pierce in January the Sea Turtle Watch at Jensen B cch on HutchsngIsland in June , and Leif Erikson Day in Jensen : Buch an October . In Febnsary of 1978,($63 tal f 20,800 persons attended the week long . St Lucie County Fair , which is held at the County Fai rgrounds in Fort Pierce, loe g approximately 12 miles from St Lucie Unit 2. The Martin County Fair , held at the fai rgrounds in Stuart, had a peak daily attendance of 7,559 and a total attendance of 27,000 persons. Other cttracttons and events include the football games at Vero Beach High School Stad t um and at Martin County High School, exhibi tion games by the Los Angeles Dodgers at Dodgertown Sports Complex in Vero Beach, and at tenaance et jat alat games in Fort Pi e rce . Between 30 and 50 mtles from St Lucie Unit 2, there are several attractions and events held annually. The highest daily attendance at any event (in fact, for the entire 50 stle radius) took place at the South Florida Fair, at the Palm Beach County Fairgrounds. In gg 8, 470,752 people at tended the Fair, wi th 38,000 persons on the peak day . Other events, such as fireworks, football games, and festivals , may draw froa 1,033 to 10,000 persons on a single day. These are li sted in Tabic 2.1-6, P irt C, and shown on Figure 2.1-12. 2.1.2.3.3 Major Indust rial Employe rs Mc.s t industrial employers wi thin the 30 mile radius have fewer than 50 workers each and are involved in citrus growing, pac ki ng and processing; const ruct ion materials; or ma rine indust ries. Major employe rs are included in Table 2.1-7 and in Figure 2.1-13. Three employers in the 50 mile radius employ 500 or more workers per shi f t ; none i s wi t hi n t en mi le s 7f St Lucie Unit 2. Between the 20 and 30 mile rad t s , two employers are con ~ 'dered signi fi-cant. The fi rst , Paper Aircraft, at the Vero Beach Airy -t in Indian River County in sector NNW, has a total em me s. t of 2,337 persons and a peak daily shift of 2,000 persons in 1978 The second , Grumman Aerospace , i n 19 73 g* ioyed 731 worke r.4 at its Stuart plant near the Martin County Airport . The peak daily shift is 700 workers. Grumman is located in sector SW, between ten and 20 miles of St Lucie Unst 2. 2.1-16 J J 1
. a Between the 30 and 50 mile radii, Pratt & Whitney Aircraf t is located on . SR 710 in Palm Beach County. Tot al employg is 7,261 at the plant , wtth a peak shtft of 6,094 'pe rse.ns in 19 73 1 2.1.2.3.4 Enrollment at Major Collegen Two major colleges are located inside the 30 mile radius. Escimates and projections of their enrollments are presented in TaNie 2.1-7. In annular sectorg f tve to ten, Florida Institute of Technol,3y-Jensen Beach Campus has a peak enrollment of 900 students with dormitories ac-condat 4 ng approximately 300 student s. Enrollment ranges from 200 in the summer trimester to 800 in the fall trimester and 900 in the winter ses-ston. The Jensen Beach Campus has a capaci r 1,200 students, which administrators expect to be reiched by 1982
.)
V Indian River Community College (IRCC)( has a total enrollment of 16,000 students on four campuses within the 50 mile radius. The main campus is located in Fort Pierce, in sector NW between the ten and 20 mile radit. Seventy percent of the students, who come from St Lucie, Martin, Indian River and Okeechobee Counties, attend classes in Fort Pierce. Peak daily attendance in 1978 is an estimated 1,500 student a. Between ten and 30 miles of St Lucie Unit 2, there are campuses in /ero Beach and Stuart. In Stuart (SSW 10-20), approximately 1,230 student s, or a maak daily esti-mate of 171, atter.ded class in 1978, while in Vero Beach, the total is 3,200 student s, or an estimated peak daily attendance of 428. Only two percent of the students attended class on the Okeechobee Campus, located outside the 30 mile radius with peak daily enrollment estimat ed at 43 stu-dents. O Proj et.* t ons for IRCC, included in Table 2.1-7, incorporate the ten percent annual rate of growth expected through 1983 (expansion of facilities under-way in 1978); in subsequent years, it is assumed that enrollment would grow at an annual average rate of 2.4 percent, the rate for the 50 mile radius area. 2.1.2.3.5 Transporation Sources of Transient Population The transtent population result ing frra the four basic modes of transports-tion is estimated by calculating the average daily number of passengers at locations on roads, waterways, rails, and airports where vehicles, vessels or passengers are counted. Since there is no way to know which or how s many annular sectors people have traveled through and to avoid count-s U) ing people as both residents and as passengers, transtent population re-sult ing from transporatton has not been incorporated into the transient population totals by annular sector (Section 2.1.2.3). Estimates and projections of passengers for 1978 through 2030 are presented in Tables 2.1-8, 2.1-9 and 2.1-10; estimates for 1978 also appear in Figures 2.1-14 j and 2.1-15. i 2.1.2.3.5.1 Highway Traf fic Wi thin ten V .es of St Lucie Unit 2, highways and roads are a major source of transtent population. SR A1A, SR 707, and US 1 are major north-south arterials. SR A1A passes wi thin approximately 1000 feet of St Lucie a
, 2.1-17 t'
SL2-ER-OL Unit 2 on Hutchinson Island. SR 707 als ng the mainland coast is less than . two miles frm the St Lucie site at its nearest point. US 1 is not only a - i l major arterial north and south, but also a focus of commercial activity in St Lucie County. At its closest potat, US 1 is approximately 4.3 miles from St Lucte Unit 2. , At or near the ten mile radius, four majar river crossiogs concentrate traffic over the St Lucie and Indian Rivers (Figure 2.'.-14). These , include the South Bridge , Jensen Beach Bridge and Stutrt Causeway from the ' mainland to Hutchinson Island and the Roosevelt Briige on UC 1 in St uart. In Febnsary and March, traf fic congestion in the Fort Pierce area and at in fact, it is the access points to HutchingIsland is a severe problem; considered a licii t to growth . Recmmendations for an additional bridge crossing the Indian River have been made for the northern end op 4) h Hutchinson Island, within Fort Pierce City limits or in adjacent areas'g . Traffic frm the larger region.comes within ten miles of St Lucie Unit 2 on Florida's Turnpike , Interstate 91. Ar its closest po i nt , the Florida Turn- r pike is approximately 7.5 miles from St Lucie Unit 2. At Interchange 56, in sector NO at the ten mile r g s, the southbound average daily t raf fic (ADT) count was 5,920 vehicles in 1977. Northbound traf fic on the Turnpike in sector SSW had an ADT count of 9,980 vv .itcles. Passenger esti-mates for major state roads and interstates withi . ten miles of St Lucie Unit 2 in 1973 are di splayed in Table 2.1-8 and in Figurea 2.1-14 and 2.1-15. Between ten and 30 miles, in sector NW, Interstate 95 (I-95) terminates ap-proximately one mile east of the Florida Turnpike at SR 70. At the 30 miln ; rad i us , southbound t ra f fic on I-95 had an ADT count in 1977 of 3,396, whil a / t he Turnpike , in sector WNW at the 30 mile radius, had a southbound ADT . coun t of 5,920. To the south, in sector SSE, the northbound traf f te on the Florida Turnpike had an ADT count of 10,365. In 19 73, I-95 was agximately 85 percent emplete from the Georgia state The 55 males of I-95 remaining to be built are line to South Miamt . , located in St Luc t e , Mart i n and Palm Beach Count ie s. In St Lucie County, an eight mile section between SR 614 and SR 70 is under construction and i scheduled to open tn 19 79. The rematning 47 miles sout h of SR 70 to com-pleted sect tons in Palm Beach County are in the planning and/or design i stages. In St Lucie County , the proposed corridor is located west of the Turnptke. In Martl35g unty, serveral alternate routes have been considered at public hearings , but as of early 1979 no decision had been reached. Ave rage daily t raf fic count s for interstate lighways have been cnnverted into average daily passengers (2.5 passengers per vehicle) in Table 2.1-8 and on Figures 2.1-14 and 2.1-15. ( See Met hodology, Sect ion 6.1.4.2) . 2.1.2.3.5.2 Waterway Traf fic The potential tot al of average daily passengers on waterways wi thin ten atles of St Lucie Unit 2 in 1978 is 1,999 persons. This total is derived frm available vessel or passenger count s for cmmercial and pleasure craf t (see Table 2.1-10) . As in the case of highways, the ftgure represents an approximation of potential passengers because there i s no way t o know in O 2.1-18
SL2-ER-OL l which or through how many annular sectors . persons on the waterways may have traveled. v . The St Lucie site on Hutchinson Island is bounded to the west by the Indian . River, in which is located the Intracoastal Waterway, a major north-south route for canmercial and pleasure craf t along the eastern seaboard. Be-tween Jacksonville and Miami, the US Amy Corggf Engineers estimated a total of 518,841 excurston passengers in 1976 , or an estimated average daily passenger count in 1978 of 1,490 passengers. This number is for the total length of the Intracoastal Waterway section between Jackson-vtLie and Miami and therefore is a conservative estimate of the actual number of passengers within one mile of St Lucic Untt 2. There is no way to estimate how many passengers actually pass within one mile of the 3ite from the data available.
%) Located in sector NW at the ten mile radius, Fort Pierce Harbor is the only sht pping port within 30 miles of St Lucie Unit 2. The harbor is reached fron the Atlantic Ocean shipping lanes via Fort Pierce Inlet, at the northern end of Hutchinson Island. Fort Pierce Harbor is a US Army Corps of Engineers project; in 19 76, thf 5ggrps recorded a t tal of 7,800 passen-gers on ships entering the harbor .
The Florida peninsula is transversed froct Fort Myers to Stuart by the Okeechobee Waterway, a cross-land lock system providing access fro,a the Gulf of Mexico to the Atlantic Ocean and Intracoastal u a terway. fg September 1977 to September 1978, 9,671 vessels uset tue Waterway . These vessels we re pleasure craf t , cargo ships, and shrimpers unde r eight foot draft (maxtmum draft on Lake Okeechobee in 19781 The Waterway (Q) runs from Fort Myers Harbor to Lake Okeechobee. At Port Mayaca in Martin County, the Wattrway enters the St Lucie Canal. Heading north and east through Indt antowc, t he Canal connect s wi th the South Fork of the St Luc te River in Stuart. This eastern terminus of the Waterway lies within the ten mile radius in sectors S and SSE. In 1973, the average daily num-ber of passengers on ships going through the locks was estimated to be 108 pe rso ns . Wi thin the ten nile radius, t n secto rs NW, S and SSE, five drawbridges must be opened for large vessels on - the St Lucie and Indian Rive rs . In 1973, bridge openings represent an average daily estimate of 379 passenger g These passenger estimates supplement the Intracoastal Waterway data which include only commercial vessels. Although there are no data avatlable on the numbers of small craft passing under the b rid ge s , it is itkely that those passengers are local residents or transtent population accounted for in estimates of resident and seasonal ( population. Estimates and projections of waterborne passengers are presented in Table 2.1-10. Ftgure 2.1-14 shows estimates for 1973 and the locations where passenger and vessel counts were taken. . 2.1.2.3.5.3 Rat t Passengers Within ten atles of St Lucie Unit 2, the Florida East Coast Rail Line passes at a distancegapproximately two miles from St Lucie Unit 2. It carries no passengers To the southwe st , Amt rak t rains on the Seaboard Coast Line carried a total of 135,336 passengers between ]cenber 1,1976 to September 30, 1977. At its closest po i n t , the Seaboard Coast Line is s approxtmately 26 miles from St Lucie Unit 2. Peak daily c1picity, which 2.1-19 e ,e- r,..sh., e m .
, - - - - --- - <. ..g -
I l l l SL2-ER-OL - l l vallaLie on all six trains' on. the line, was 2,474 in
.neans all seg As indicated in Table 2.1-9 and Figure 2.1-14, the August, 1978 Seaboard Coast Line, which passes through the 30, 40 and 50 mtle annuli, -
had a daily average of .789 passengers in 1978 betseen Sebring, Florida and West Palat Beach. A cutback in the nu of passenger trains is expected to reduce passenger totals after 1978 2.1.2.3.5.4 At rpo rt Passengers No regularly scheduled atriine passenger service was available at any of , b the airports within 30 miles of St Lucie Unit 2 in 1978. Although no ai r-ports exist wi thin the ten mile radius, both St Lucie and Martin Counties have airports located between the ten and 20 mtie radii . The St Lucie l County Airport is located north of the city of Fort Pierce La sector NW. St Lucie is a landing rtghts airport with cmplete 3c Cusrem 'ac i li t i e s . In 1979, a small cnamuter airline known as Golden South expect s to begin operat ton with five round trip flights to West Palm Beach, Melbourne, and t Orlando. Longer range plans (1982-1985) include expansion or the runwydO50 accoatmodate DC-9 's and improvement s of the tower to meet FAA Standards . In developing scheduled passenger semce, St Lucie County Ai rport has the cdvantages of suf ficient land area for runway expansion and US Custom Service fac t 11 t t es to r non-US de s t i na t i ons in the Bar.amas or the Caribbean. The Stuart/ Martin County Airport is located south of Stuart in annular sector S ten to 20. As of 1973, its use was limited primartly to test finghts for Crumman Aeros pace . No plans exist fo r ex pans t on of s t ruc t ure s or factitties. . Between 20 and 30 miles of St Lucie Unit 2, in Indian River County', the Vero Beach Munter pal Airport will resume scheduled passenger service in 1979. Eastern Airlines di scontinued its service into Vero Beach in 1973. A11edheny Commuter Service will of fer round trip servtce for 150 passengers l da.ly between Vero Beach and Orlando. Allegheny has found a good fr eque n- ! cy/small aircraft type of gvg a success in other parts of the US, and expect s strong growt h here The West E :, Beach International Airport is located in sector SSE, inside the 50 mile radius (Figure 2.1-14). In 19 7 7, a t o t al o f 1,603,971 arriving and departing passengers used the airport. In 19 7 8, the average daily number of passengers is estimated to be 4,878. Althoueh the number of landings grows at a rate of only two percent per year (see Section 2.2), the use of lar e,er ai rcraf t accommodates the i ncreasi ng d amad Fnr seats. It is expected that at least 4,4 74, g pa s senge rs will use the West Palm Beach Internat ional Ai rport an 1990 . Plans are underway for con-st ruc t ion of new t emi nal, runway , and road facilities. In addi tion to passengers, airport of ficials est imat ed that in 1973 there were 1,300 worke rs at the airport on a peak day, and that passengers were accompanied on the average by two persons each prior to departure and upon arrival. If passengers, wo rke rs and persons accm panyi ng passengers are totalled fo r 1978, the average daily number of persons at the West Palm Beach Interna-t ional Airport fo r 19 73 wou ld be 6,992. Est imates and proj ect ions of average daily passengers are i nc luded i n Table 2.1-9. O , 2.1-20 f-
SL2-ER-OL 2.1.3 ,USES OF ADJACENT LANDS AND WATERS 2.1.3.1 Existing Land Uses'on App'.icant's Property 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 i the'Sc Lucie site. ~A detailed discussion of the site area breakdown is given in Section 4.1. 2.1.3.2 Land Uses Within The_ Exclusion Area The exclusion area falls within FP&L property boundaries, and encompasses-4 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 AIA, undeveloped mangrove, sandy
' beaches tn/. dirt trails along the eastern coast of Hutchinson Island.
2.1.3.3 Future Land Use on the Applicant's Property 4 There are no proposed land uses within the applicant's property boundaries 6 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-wall, no disturbance to existing land is expected. Power generated by St Lucie Unit 2 will be transmitted by existing switchyard and transmission ) I lines constructed . for St Lucie Unit 1. Therefore,- land use changes on the
/ spplicant's property will be minimal.
- 2.1.3.4 Nearest Residences and Agricultural Activities I
j Table 2.1-11 gives the location of the nearest cow, goat, meat animal, j vegetable garden (greater than 500 square feet in area), and residence i found within five miles of St Lucie Unit 2. The location of these items j isgig*g*gggularsector. The following is a discussion of this Table l
- The nearest milk cows are located outside the five mile radius, 14 i 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 i 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. 6 l-
- The ground survey showed the nearest vege'.able garden of 500 square feet or greater to be located 1.9 miles W3W of the facility.
- The nearest residence lies 1.9 miles ,4 of the plant site.
- O 2.1-21 l l !
c 1 l i
)
1
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SL2-ER- OL 2.1.3.5 Existing x Land Uses Within Five Miles of St Lucie Unit 2 Table 2.1-12 lists each land use found within five miles of St Lacie Unit ' 2 with the acreage involved for each categogggureThe 2.1-16 is a map site surve.y and i showing the distribution of these land uses . land use classification methodologies are discussed in Section 6.1.4.2.1. , A detailed discussion of existing land uses n. five miles of St Lucie Unit 2 is given below. 2.1.3.5.1 Land Use/ Land Cover by USGS Categories a) Residential The residential category of land use includes single fami{y units, multiple f amily units , group quarters , mobile home parks, and tran-sient lodgings, (motels and hotels). Permanent residents live, for the most part, in single f amily units consisting of f ree standing houses and mobile homes. Transient accommodations include residential units which are rented out, motels, hotels and individual housing units chich 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 a re , for the most part, transient accommodations. These residential units are used by seasonal visitors throughout i the year and include motel rooms, condominiums and mobile home rark j facilities. Residential developments within five miles of St Lt cie Unit 2 are discussed below. See Figure 2.1-7 for their location. Mainlanj Residential Units Indian liver Estates, located between three and five miles of St Lucie Unit 2, easr. of US 1, and just south of Fort Pierce, is a single f ag hou ting development A thouth designed streets and primarily plots were laid for outpermanent for residents . this development n, sny 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 much less land area than does Indian River Estates, bu g more densely settled. Most of the residents are permanent Taken together, these developments contain more than 500 dwelling units (Section 2.1.2). of US 1 and contains Spanish Lagis a mobile home community east l 1,337 lots . Although most of the occupants are peraanent residents, a significant number of dwelling units are owned or l occupied by seasonal visitors. West of Spanish Lakes and US I is a mobile home project known as Riverfront. A small portion of this development extends into the area within five miles et St Lucie Unit
- 2. Like Spanish Lakes, it accommodates both permanent ar.d transient residents.
2.1-22 O F
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 relidential units are used by both permanent residents and O(,/ seasonal visitors. ParallelingSR7g6 a strip of individual houses on the shore of the Indian River Typically, these houses sit on lots which extend back from the shoreline approximately 1000 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 predomir.antly owned and occupied ( , by permanent residents. The multiple housing units built on the mainland are primarily located alongside US 1. 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 knogg Nettles Island. It has 1588 tots (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-4 A) t V ings: Hutchinson Island Inn (21 room rooms) and Oceana (7 26 condominiums) g f aton Resort Inn (122 Under e m. auction are a housing development called Sand Dollar Villas and an expansion of Oceana. Sand Dollar Villas is 1.4 miles frcm the plant site and will contain 203 apartments and 32 town-houses on the ocean. ** Sand Dollar Villas is It is expected scheduled to attract in for completion seasong0N'The 1980 . condminium development known as Oceana is currently Feing expanded to add anotber 160 condomig# s. This expansion is scheduled for com-pletion by December, 1979 b) 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 totst of la acres within five miles of St Lucie Unit 2 fall within thi- category.
Commercial , Of the total area under consideration, only 22 acres consist of commerci.tl and service esttblishments. Most of these facilities, such as drycleaners and supermarkets, serve local residents. There are two shopping centers within five miles of St Lucie Unic 2, n v 2.1-23 1 mw e y - - -
, e r, ,%_s, , , -.,-c --a ,m .a g p- - , - - ,
l SL2-ER OL located on US 1. Most other commercial establishments are related to the automotive industry (gas stations, used car lots, mechanic's shops) or tourists. There are few commercial and service establisLments on Hutchinson Island. For the most part, they are specialized f acilities such as As a result, people on the j beauty shops, and bait and tackle shops. ; island have to cross over to the mainland for 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 Jensan Beach. ; All three centers are located outside the five mile radius. i lystitutional - Schcals, Medical Facilities, Churches Tae classification of co=mercial and services, includes institutional . land uses such as schools and hospitals. ThereThe are nearest no schoolsschool, i Located within five miles of St Lucie Unit 2. { White City Elementary School, is about six miles WNW from St Lucie Unit 2. There is one medical facility, approximately five miles WSW f rom the plant site, called the Port St Lucie Medical Center. Several churches f all 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. ! I g c) Industrial h The General Development Corporation (GDC) owns approximately 32 ! acres, used as a small industrial park located of f 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 fien and one is a ' plumbing supplier. The 18 acres leased by FP&L is classified as utility use. The remaining 14 acres, leased by other firms is classified as light industrial. d) Transportation, Communications , and Utilities This category encompasses major transportation routes, such as high-ways and railways, and communications and andutilities areas , "such transportation as of water, thoseinvolvedinprocess{cg) treatment, gas, oil, and electricity ..." , Uithin five sites of St Lucie Unit 2, 964 acres can be classified as transportation, cc=munications, 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 facilitias.. All of these are owned and operated by FP&L. Most of this However, acreage supports St Lucie Units 1 and 2, and related structures. as mentioned above, FP&L leases an 18 acre storage and maintenance yard in CDC's Industrial Park. l l 2.1-24 .
- 1
.- .. . ~ =- - . .
SL2-E R-OL Transportation 1 1 5 r~s . The principal transportation corridors .on the mainland are US 1, f 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 parallelo 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 ailes south of Weatherbee Road, waere 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). ' t The only major paved road on Hutchinson Island is SR AI A. It has ('~'/
\m, a width of two to three lanes and transects the entire length of the island.
Communications 1 With the exception of an underground telephone line which' transects the western rim of the five mile arer , there are no ecmmunications i areas within five miles of St Lucie 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 I and 2 and their .related structures. Roughly 386 acres i accommodate the transmission lines which extend fro: the plant site to the circumference of the area within five miles. For most of its
. . langth, the transmission line right of way is 660 feet in width; d to the Indian however, River, the for a short
- width distance is 1,200 feet {g79.iately The adjacent remaining 18 acres support a utility storage area within the CDC Industrial Park.
e) Urban or Built-Up Land Included in this category are miscellaneous urban land uses such as e cemeteries, urban parks, undeveloped urban land, and recreational
- facilities. Approximately 235 acres (or less than 1/2 percent) have
- been classified as urban or built-up land. Forty-seven of these
! acres comprise both a cemetery of f SR 707, and pockets of undeveloped j urban land contingent to US 1. A total of 188 acres are given over to both public and private recreational f acilities. The private
- facilities consist of the golf course within the Spanish Lakes'com-
, pound and the Tu 3ahd Saddle Club. The public establishments are
- the southern end of the Savannahs Recreational Area (a park in the NW l quad ran t , owned by the City of Fort Pierce and used for picnicking, boating and camping) and public picnicking and beach f acilities en 2.1-25
, , . . - _ - - .--- -.v--,,. ,,.,- _ . , , - . _ , _, ,, ,,,7 ,r .. , y-_,- -- - ~
1 SL2-ER-OL Hutchinson I'sland. Recreational beach usage is discussed in Section 2.1.3.9.2. f) Agricultural 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 i supports citrus groves. InIg37 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. g) Forest Lanc' "etlands 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 draineg ) sandy, and belong to the Myakka-Immckalee-Basinger Association Much of the undeveloped land Letween the Florida East Coast Railroad and US 1 is ma. shy, and supports a scattering of pine trees. The ridge along SR 707 has drig ils and supports a denser forest canopy consisting mostly of pines The fores St Lucie Unit 2 is not commercially logged {3y hin five miles of The other principal vegetation community within five miles of St Lucie Unit 2 is the mangr "re community located on Hutchinson - Island. For a discussion of this community, see Section 2.2.1. 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 of ten merp,e with the surrounding marsh. The rest of the water is concentrated in small man made penda and canals located towards the western boundary of the five mile perimeter. i) 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 L Located at the site of the sand mining operation, just west c i the Florida East Coast Railroad tracks and - on either side of Wes;herbee Road. Roughly 195 acres serve this ex-traction operation. 2.1-26 O 1 l t
l ri t ;m n '?t,,, j4i . 'r' ' r r.-J N i St.2-ER- OL The second type of barren land is found along the Atlantic Coast of* (3 liutchinson Island in the form of beaches. Almost 100 acres of V beaches occur within five miles of St Lucie Unit 2. The third type of barren land is found wi thin s'.te so-called t ransi-tional areas. . "The Transitional Areas category is intended for those ag "whten 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 Weathe-bee Road and appear to have once supported agricultural activity. The third is located near the southern boundarf of the five mile circumference. It contains land which has been cleared and draingor a commercial / residential development known as
/ "Midport" 2.1.3.6 L e Land Uses Within Five Miles of St Lucie Unit 2 To determine future land uses within five miles of St Lucie Unit 2, the R Lucie County Growth Mana:;ement Plan (ThePlan)andothercriticaigagng
- documents, such as The Plan for tiutchinson 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 2.1-13 present the pro-posed land uses.
The Plan states, "Af ter adopting a plan, local governments and their agen-e t :s may not issue building permit s, approve zoning changes or subdivision (N reaue st s, underf.ake public development projects or approve development (") ae* ions that are inconsistent with the plan for the area. In addition, the
, adoption or a=endment of land development regulations (e.g., zoning, sub-divisionregulations)shyl e consistent with the adopted comprehe asive 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-struct ion activi ty will be necessary to accocmoda te pooni.t r ian ersweh. p> (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 fla twood/ f resh water marsh. It is anticipated that with the projected increase in ,opulatton, much of this land will be cleared and drained to accommodate new dwelling units. In the followi ng di scussion of future resident ial development , separate consideration is given to the mainland and to Hutchinson Island. v 2.1-27 4 t-
D F*D "D Q 9 ]Y
- _m S t.2- ER- OL c) future Residenttal Development on the Mainland .
According to The Plan, land abutting the eastern right of way of US 1, south of General Development Corporation's (CDC) Ind us t ri a l i Park, will be set aside for mediuct and low density residential use. It is expected that those areas designated for residential develop-ment by The Plan will support dwelling units in the future. In addttton, residential development is anticipated in other areas. ; Most of the undeveloped land extending from US 1 to t he west ern ; border of the Flortda East Coast Railroad right of way ts designated i in The Plan for Agrtcultural Use. In practtce, however, po rt i on s r l g this "agrtcultural" land have already been commi t t ed for residential use. Colf Village , fo r exam'ple , as an approved prnject of 740 mobale of Spanish home units which wil{ g constructed by the managers Lakes and Riverf ront . It will be located south of CDC's Industrial Park and east o f US 1. Another example of the pressure being placed on " agricultural" land for residential use is the project known as Midport. Madport is located north and south of Walton Road and east of US 1 'see Section 2.1.2.1.51. It will introduce 2,201 gling units which will be both stngle and mult tple family units . Much of the Midport development will fall within the five mile area, although it ts difficult to speci fy exactly how many resident ial units will te butit within five ma les of S: Lucie Unit 2. The Midport Pg t has been tssued a DRI (Development of Regional Impact ) pe rm i t The locat tens of both Golf Village and Madport are shown on F tgure 2.1-7. b) Future Residential Development on Hutchinson Island That portion of Hutchtnson Island which falls within the five mile radtus is expected to experience ' considerable development. Specif- l 1 teally, the 1973 estimated population of 1,928 is expected to grow to 2,673 by the year 2030 (see Table 2.1-1). These projections reflect the fact that most of the Atlantic Coast of Hutchinson Island is undeveloped, and the demand for beach front property is growing. , In recognition of this, The Plan has designated most of the land area within five miles of St Lucie Unit 2 as low or medium density ' residential. However, there are some considerations .hich may af fect the rate + at which demand for Hutchinson Island property will increase. For example, there are no fre sh wa t e r we lls on Hutchinson Island ; therefore, all potable water has to be piped in fr<in the mainland. In t he pa s t , the ctty of Fort Pterce has suppit ed po t ab le wa te- to the Island. & <ever, at thts time, the distributton system supply-ing the t s '_ a nd ha n reached its capacity. Until this( g ten is expanded, development on the i s taad will be hampered . O 2.1-28 Y
I SL2-E R-OL In general, it is anticipated that residential development wi thin , five miles of St Lucie Unit 2 will consist of a mixture of single () f amily and multiple family units. It is also expected that these units will house both permanent residents and seasonal visitors. , Commerecel 14' Services , a) Commercial Commercial establishments on the mainland are concentrated along US 1. It is expected that there will be an increase in commercial land uses in conj unction with the predicted increase in residential land use, and that this increase will occur adjacent to US 1 on the mainland. As is currently the case, it is anticipated that new commercial establishments will serve both local residents and high-A way travellers. Two car dealers, Buick and Cadillac, are planning to move (jgjo tha area, and other automotive related services may i follow On Hutchinson Island, it is expected that the new residential pro-jects will house commercial establishments such aa beauty shops, sports equipment outle t s , etc . In addition, other commercial es-tablishments may be constructed along SR A1A. In fact , The Plan has zoned pockets of land on Hutchinson Island for auch commercial development. b) Institutions t 1 At the present time, there are no plans to caustruct any schools or medical facilities within five miles of St Lucie Unit 2. Ilow-ever, pressure has been brought by local citizens on the General. Development Corp , ration and other developers to provide school facilities for children residing within developments. For example , Port St Lucie, a development run by the GDC, hp schools be built to accommodate their children's needs '9 jsked . GDC that has pro-vided land for three schools within the Midport development. If these schools are built , a middle school-high school will be located about 3.5 miles south-west of St Lucie Unit 2, and an elementary school will be located about 4.5 miles south southwest of the plant. i Industrial a ( - Currently there a s ve ry li t t le industrial land use (roughly 14 acresT within five mil., of St Lucie Untt 2.
\s It is not expected that a signifi-cant amount of new industrial activity will be initiated in this area.
According to The Plan, only the area currently abutting the GDC Industrial Park (roughly 130 acres) will be zoned light industrial. According to local planning of ficials, there a re-locate within the 130 zoned acres [g79o new firms currently seeking to I 2.1-29 ( 4
. , - - . + . ~~,n . ~ ."
p -- - er-- - - ,
SL2-ER-OL Transportation, ~;c=munic ation , and Utilities Within the transportation, communications and utilities classification, limited growth is anticipated. The Plan calls for the videning 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 af fect 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 _raf fic volumes. The report recommended that a fourth bridge be constructed at SR 712 (White _ CityRoad)whichwougg nk US 1, the Florida Turnpike, and Interstate 95 to Hutchinson Island However, it is uncertain if, when, or .here another river crossing will be constructed because g waters of the Indian , River in this area are part of an aquatic preserve . No etpansion of the communications category is anticipated at this time. . Futurt utility land use associated with the construction of St Lucie Unit 2 is discussed in Section 2.1.3.~. Other Urban.and Built-Uo Land The other urban and built-up land category encompasses miscellaneous urban 2 land uses, such as urban parks, and recreational f acilities. A major land use change which will occur is the establishment of the State g Savannahs Preserve. Using state funds, 3372 acres of land located at the western edge of the Florida East Coast Railroad right of vty gparal-1eling SR 707 have been purchased for a conservation preserve . It is intended that the property which is eventually included in this preserve will be restricted to public access, and will serve primarily as l a wildlife refuge. According to the Recreation and Parks Division of l the Natural Resources Dept. .aent, most of the J.ndwhichwy e included in the State Savannahs Preserve has been purchased to date With the increase in residential and commercial land uses, it is expected that some growth in private recreational f acilities will also occur. New l 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 area becomes more developed. For example, it can be Sxpected 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 cccur. However, it is likely that most of this type of development will occur along US , I and other major roads, such as White City Road and Walton Road. Agricultural Land There are currently roughly 450 acres of actively used agricultural land I within five miles of St Lucie Unit 2. It is unlikely that there will be ; an expansion of agricultural activities in the future. According to the 2.1-30 ! l-d
SL2-ER-OL local County Agricultural Agent, the expansion of agricultural activities is Igy to occur to the west of US I and not within the five mile y/ area The soils found within five miles of the plant, belonging to the Myakka-Immokolee-Basinger Association, have low potential for citrus , f production, wb ^ of the plant"yh is the primary agricultural activity within five miles l 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 future 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 *.otal forested acre-
. age will be af fected.
At this time, no major changes are projected within the barren land cate-
, gory. The transitional areas will eventually support one or mora other land uses. Specifically, the transitional land north of Weatherose Road,
, which was once agricultural, wil', probably evolve back into forested land. l 2.1.3.7 Agriculture and Fisheries Within 50 Miles of St Lucie Unit 2 2.1.3.7.1 Introduction i i This section consists principally of tabulated data concerning agricul-tural, livestock, and commercial and recreational marine landings within j 50 miles of the St Lucie Unit 2 nuclear generating facility. 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 v 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 pr.rcent of Palm Beach County and :'9 percent of Brevard County f all within the 50 mile radius. Less than five percent of Osceola, Highlands, Glades and Hendry Counties are conta'.ned within th e 50 mile area. I Agricultural data for those counties whose land area is not comp le te ly within the 50 mile area was allocated to the 50 mile area in the following manner: ,b 2.1-31 'o 1 -mm -e m n=m-* e a . . ~ ,4 ,
SL2-ER-OL The area of the entire county was analyzed usLng 1972 US Ceological Survey Maps (Scale 1:250,000) to exclude those arets where agriculture or live-stock farming could not occur. This would include water, wetland, urban recreation or " forested areas". The remaining "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 agricultural production f alls within 50 miles of the site. For fisheries production, data on marine landings for each county are used since data 'n fishing locations are not available. 2.1.3.7.2 Beef Production i Beef cattle production is one of the primary agricultural activities in l southeastern Florida counties, with a production of approximately 137,000 head within the 50 mile study area. Table 2.1-13 shows Okeechobee, Martjn and St Lucie coung as the major becf producers, producing 10,020 x 10 kilograms in 1977 Presently there are 77 bee! cattle ranches in St Lucie County, occupying 200,000 acres or 57 percent of the county area. Of this, 80,000 are is-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 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 princg pasture feeds; hay grasses rank second, and bermuda grasses, third . In the cooler months from mid-November through January, small grains, hay and grass silage are necessary feed supplements, though in some aregg$ghe tvaila-bility of white clover allows year around pasture feeding 2.1.3.7.3 Milk Production . 6 Milk produr tion wjbin the study area totaled approximately 151 x 10 kilograms in 1977 '. Okeechobee County accounted fo{g ut two-thirds of this total, producing 102.5 x 10 kilograms in 1977 With'.n the Okeechobee araa, corn and grass silage are the principal dai.y cow feeds, although S'.at.e figures show that commercial mixed Seds consisting of corn, cotton seed meal, wheat beghorts and alf alf a pellets, are fed on the average at 16 pounds per day 1 Table 2.1-14 identifies dairy herds and milk production within 50 miles of i the proposed f acility. Table 2.1-15 shows that approximately 97.5 percent I 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 mig ream and butter; 0.3 is fed to calves; and 1.5 percent is sold locally O . 2.1-32
l i L L y. 1 SL2-ER-OL ; , f 2.1.3.7.4. Egg Production t l Egg production, frompoultryfarmswg the study area, accounts for less ! Within the study area there f ! . than nine percent.of the s5 ate t ta are approximately 109 x 10 layers producing 26 x 10 eggs. Indian I River, Martin and St Lucie counties are the largest egg producers in the i i ! 50 mile area. Each of these counties has 25,000 layers producing on the I average of 16,250 eggs per day. Table 2.1-16 is a breakdown by county of . 3 the egg production within 50 miles of St Lucie Unit 2. [ ) i I ' . ~ n i l i ) l I 7 E s + g 1 4 E e t i 2.1-33 t i
,ws ._-- v-.- , "
. l SL2-ER-OL 2.1.3.7.5 Commercial Vegetables, Fruit and Sugarcane Crops .
Commercial vegetables and ci':rus frui t i are the main agricultural products in the area. Table 2.1- 17 provides vegs able harvest statistics for the 0-50 mile radium area. Toruces and watemslon are the principal produce , within Su miles of the site, accounting for agl harvests of approxi- i mately 3,000' acres and 650 acres respectively . Table 2.1-18 pro-vides yield statistics for those counties in the southeastern part of the state; Ltble 2.1-19 shows state-wide yield statistics. Cit rus crops are grown throughout the study area. Table 2.1-20 li st s, by county, the amounts and types of citrus crops grown in the 50 mile area. St Lucie and Indian River Counties are the largest prod uc ers in the area. In 197 7, gSt Lucie County pWuced 3.7 x M Wgrau M manges aM f 3.3 x 10 kilograms of grapefruit . In the same ygar Indian River pro-duced g x 10 kilograms of oranges and 3.3 x 10 kilograms of grape-fruit . These two counties accounted for 73 percent ofthetotakl00) citrus produced in the study area and 13 percent of the state total . Florida statistics show a net decline in Florida citrus acreage since 1970. In 1977, 21,538 acres were removed freu production. St Lucie and Martin Counties sere major contributors to the decline, while Hendry and Palm Beach Counties were the only two counties within the study area (and two of threggnties within the State) showing significant gains in citrus aereage . G Sugarcane is produced in the Everglades in the south and southwest po rt ion of the study area in G ades, Martin, and Palm Beach counties. Table 2.1-21 lg i list ggarcane production in Florida was produced in the 50 mile study lW area . 2.1.3.7.6 Commercial Fii.h and Shellfish Landings ; l Cocice rci al landing statistics of fish and shellfish for the coastal coun- { ties within 50 miles of St Lucie Unit 2 (Brevard, Indian River, St Lucie, l Martin, and Palm Beach counties) are presented by total landing in 1976 and ' principal species in Table 2.1-22. Wh coast landings in l 1976 dropped by four percent from 1975{ glorida , east total fish and shellfish L landings for the coastal counties within 50 ctiles of the si te showed a j marked increase. Total landi ng s for these counties wers up approximately g 18.6 percent from 1975 (See Table 2.1-23). The increage was the result of a 33.6 percent tgerease in fish landings from 7.1 x 10 kilograms in , 1975 to 9.5 x 10 kilograms in 1976. jotalshellfish landings howeveg, i decitned 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 fish and shellfish landt ngs, wi th a 3.9 percent decrease in fish land- I ings and 26.1 percent decrease in shellf tsh landings between 1975 and 1976. I I Table 2.1-23 ca:1 pares 19 76 to 19 75 tot al fi sh and shellf t sh marine landings j for Brevard, Indian River, St Lucie, Martin and Palm Beach counties. Ap- g prom mately 90 percent of the fish caught is consumed by hgg (See Table 2.1-26). Twenty percent of fish catch is consumed locally . Princt-pal ta nf t sh species taken we re black mullet , menhaden , Spani sh macke ral , b l ue fi s h , pocipano and red snapper. The ciajor commer cial port s wi thin 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 dif ficult 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 an-past sg1 years has been a decline of from two to four percent nually . 2.1.3.7.7 Recreational Fishing J (, Principal sport fishing areas within 50 miles of the plant site include the waters off Hutchinson Island, where pompano, blue fi sh, false albacore, ki ngfish, sailfi sh, dolphins, amberj ack , flounder, mackerel and barracuda are common, and the St 7 "" k>
- P "' **
- Sh>
LuciaInlekl0357""t*db spotted sea trout and bot tom 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 in the area. The variety of species of fish which may be caught wh h fishing in-ciude kingfish, pompano, palometa and spot fin mojarra{ {g49 ore 2.1.3.7.8 Hunting Statistics Hunting statistics have been tabulated for the J W Corbett Wildlife 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 last s from September 10 throu ; March 26; the second week of January through the end of February eacg jris small game season and the month of March is spring turkey season , . Quail, snipe and duck are the most common fowign while deer, hogs and squirrels are the prin-ca pal wild animals taken The game biologist for the J W Corbett / ' ' Wildlife Management gg assumes that 100 percent of the wild game harvest j is consumed locally 2.1.3.8 Surface Water Use 2.1.3.8.1 Consumptive Use This is no potable water usegany water resource which would be affected by St Lucie Uni t 2 discharge . Since drinking water supplies are brought to Hutchinson Island by pipeline and since groundwater flows are from west to east tog the ocean, no contamination of drinking water is considered plausible . Therefore , no analyses of con'.umpt ive sur f ac e g wat er use were per formed. ? j
,J _
2.1-35 l
- . - - . 1
SL2-ER-OL 2.1.3.8.2 Recreational Water Use -g i Since the discharge of St Lucie Unit 2 is into the Atlantic Ocean, only those recreational uses associated with saltwater activities have been con-s id e red . These include beach activities, fishing , boating , and sur fing , as defined in Outdoor Recreation in Florida 1976,)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 on the places at which people take pas t inrecrest{gggjpursuits. However , by utilizing the results of state user surveys , a general order of magnitude estimate of saltwater recreational activities with 50 miles of St Lucie Unit 2 can be generated. Statewide 1975 annual per capita par-tacipation rates for each saltwater related activity were =adified to re-flect average d.2 tly 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 10 miles of St Lucie Unit 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 following assumptions : a) Recreational users will pursue their activities 'only within 50 mties of St Lucie Unit 2. Residents and tourists in this area will sometimes journey out of the area for saltwater recreation, and, in s t urn, people frna outside this area will enter it for these pur- ) po s e s . However, it is felt that these movements largely counter-balance one another, and because of the lack of more speci fic data, the numbers shown in Table 2.1-26 reflect a reasonable estimate of recreational saltwater use, b) Recreational participation rates will not change over time. As not stated in Outdoor been accurately estRecreation t=ated and In Florida quanti 1976 fied"' ' )such factors "have
. 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) w' .1d apply in the study area. Indian River and Brevard Counties fall in a dif ferent Region, where parti-cipation rates are considerably lovar. However, it was felt that using the Region X rates would result in a more conseriative esti-mate, t aking into account possible future increases in participa-tion. A 19 73 average daily 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 of saltwater recreational activity is di scus sed in the following paragraphs: O l 2.1-36
SL2-ER-OL 7- s Beach Activities 5 Beach activities include saltwster 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 lifygg93d s). For excmple , according to a survey of beaches in Martin County Performed in 1978, guarded beaches had an average density of 0.9 persons per li neal foot , while unprotected areas had as few as 0.0036 people per linear foot. In a survey of ggggges within two miles of St Lucie Unit 2 conducted by FP&L in July, 1975 , the average density was 0.0122 people per lineal foot on
,-ss the July 4th weekend. On other weekends this dentity was as low as 0.0025 people per lineal foot. The beaches near St Lucie Unit 2 have relatively
(\d} few access po int s . The di fferences in user density along the coast wi thin 50 miles of St Lucie Unit 2canbeshowngenerallybymappfpg9'g103 t ** ** "" # ~ cess points. This is done in Figure 2.1-19' The public beaches closest to the St Lucie Unit 2 discharge are on Hutchinson Inland about four miles NNW of the plant. Average daily usage at egggg) beaches was 656 persons between October 1, 1977 and September 30, 1978 . In general, the public beaches tend to be clustered near bridges over the Indian River. Saltwater Fishing j, Saltwater fishing activities account for 18.4 percent of recreational water ( users within 50 males 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.
Boating I 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 of these facilities. Marinas within 50 miles of St Lucie Unit 2 are shown in Figure 2.1-19. Most of these facilities are located near the populated areas and the Indian River inlets. The nearest public marina to (N-/) StLugjT2yntt 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. Surftng Surf tng is a relatively untmportant activity in this area, with only 1.8 I percent of the recreational saltwater users involved in this pursuit. '
/n h O
2.1-37 j
SL2-E R-OL l l l 2.1.3.9 Groundwater Use ,1 I Field permeabita ty tests at the plant site have indicated a seepage or flow of about 15,000 feet per year in the top 30 feet of the sand deposit s. ' Taking the highest permeablis ty coef ficient obt ained and a hydraulic gra-dient of 100 percent, any discharge introduced into the ground at the plant site would reach the Indian River in about a day. The d.acharge would then be grea tly diluted. Because of the width of Indian River and presence of a continuous flow of groundwater toward the coastline, there i s no po s s i-bility of subsurface flow fran the site to the mainland. This preclud any intrusion of plant releases into the mainland groundwater supplies {gg) . In addgg{gn, no successful fresh water wells have been found on Hutchinson Island For these reasons, no analysis of groundwater users has been made.
\
O O 2.1-38 O1 . 1 9
. ~ . - - - - . . .
1
l
' ~
O SL2-ER-OL . Q SECTION-2.1: REFERENCES L
- 1. Smith, Stanley K. " Projections of Florida Population by County, l - 1980-2020". ' Bureau of n'-onomic and Business Research, Division of Population Studies, Bulletin 44, July 1978 I 2. City of Port St Lucia City Planning Dep. rtment, Comprehensive Plan-ning Program,'" Population Estimates and Projections", February 1978
- 3. .' Aerial Photograph Indices, Florida Depaetment of Transportation, t
1969, 1974 j 4. Aerial Photographs by Aerial Cartographics Inc, Orlando, Florida, October 21 and November 2, 1978
- 5. Sales Office, Spanish Lakes, Port St Lucia, Ficrida, La.tter Dated January 5, 1979 i 6. " Savannahs State Preserve", 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 'stimates 1970-1985, for Florida and Florida Counties, Issued s me 9, 1978 - Florida Depart-ment of Administration, Tallahasse4, Florida j 9. " Master Development Plan, Mi. aport - City of Port St Lucie, Florida,"
(Map H4) Prepared by Gene.al Development Corp, Environmental Plann-ing Department, April if78
; 10. Rules of the Department of Administration, Administration Commis-sion, Chapter 22F-2, Land Planning, Part II, Developments Prestmied f '
to be of Regional Impact. Undated.
- 11. DR1 Coordinator, Treasure Coast Reg. Planning Council, Stuart, Florida, Letter Dated January 29, 1979, and Personal Communication, May 22, 1979.
- 12. Sales Of fices, 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 Study, Prepared r for Board of -County Commissioners, St Lucie County, Florids, 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 Population Reports (P-25), No. 704, July 1977. (Series II Projections Used)
- 18. PMeet Manager - PGA Complex, Florida Realty Building Company, Letter Dated December 11, 1978
. Regional Planner, Treasure Coast Regional Planning Council, Stuart, Florida, Meeting on October 13, 1978
- 20. Planner. Martin Coun*;y, 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 Regional Profile - 1977, Prepared by Treasura Coast ;
Regional Plannit.g Council, Stuart, Florida, September 1977
- 23. Director of Building and Zoning Department, Okeechobee County, Okeechobee, Florida, Personal Co=munication, 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 Plar. Summary, Southwest Florida Regional Planning Council, Fort Myers, Florida, 1978. (Includes Glades County)
- 26. "Osceola County Development Areas Map", Osceola County, Board of County Ccm=issioners. (No Date)
- 27. " Average na ily Beach Usage, Martin County, Florida", prepared by the Martin County Planning and Zoning Department, Stuart, Florida, November, 1973 2S. Supervisor of Elections, Glades County More Haven, Florida -
Letter Dated December 8, 1979 )
- 29. Planner, Osceola County Board of County Commissioners, Kissi=mee, l Florida, Letter Dated November 3, 1973 l
- 30. Planner Responsible for Existing Land Use Map of Highlands County; l l
Candeub, Fleissig & Associates, Newark, New Jersey, Letter Dated Noveber 3, 1978 2.1-40 t
1 I SL2-ER-OL
'l SECTION 2.1: REFERENCES (Cont'd) 31., " Existing Land Use, Highlands County, Florida", Prepared for High- l Lands County Zoning Department by Candeub, Fleissig & Associates, Planning Consultants, 1978
- 32. "Ceneral Development Plan, Highlands County, Florida - 1972", Pre-pared for the Highlands County Planning Commission by Candeub, Fleissig & Associates. Supplement to the Sebring News and Avon Park Sun, August 31, 1972
- 33. Central Florida Regional Planning Council, Existing and Projected f- s
() Land Use Central Florida Region, 1976-1955, June 1978
- 34. " Population Studies'I, in Waste Water Engineering, 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, Florida, May 1976
- 36. Superintendent of Recreation, St Lucie County, Ft Pierce, Florida, Letter Dated December 5, 1978 j 37. Director of Lifeguards for Martin County, Robe Sound, Florida,
. -- Personal Communication, November 16, 1978
38. Supervisor of Special Facilities, St Lucie 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 Commerce, Jensen Beach, Florida, Letter Dated November 17, 1978
- 41. Director, Stuart/ Martin County Chamber of Commerce, Stuart, Flo ida, i Letter Dated November 22, 1978
. 42. Student Activities Of fice, Florida Institute of Technology - Jensen
,' y Beach Campus, Jensen Beach, Florida, Personal Communication, November 27, 1973
- 43. Finance Office, Inlian River County Schools, Vero Beach,' Florida, Letter Dated November 27, 1978
- 44. Office of the Vice President, Indian River Community College, Fort Pierce Campus. Fort Pierce, Florida, Letter Dated November 28, 1978
- 45. Personnel Department, Piper Aircraft Corporation, Vero Beach, Florida, Letter Dated December 4, 1978
[h 46. Fair Secretary, St Lucie County Fair, Fort Piere s, Florida, Letter
\_ l Dated November 20, 1978 1
- 2.1-41
,,r-- -,7 g y ,- --y- v-.--w ,-- ---.- -e--
?
i i SL2-ER-OL l SECTION 2.1: REFERENCES (Cont'd)
- 47. Fair Secretary, Martin County Fair Association, Stuart, Florida, 6l '
Letter Dated November 20, 1978
- 48. Personnel Department, Gruman Aerospace, Stuart, Florida, Letter Dated November 30, 1978
- 49. Maintenance Foreman, St Lucie County Sch;ol Board, Fort P.erce, 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 Of fice, Pratt & Whitney Aircraf t , Covernment Products Division, Palm Beach County, Florida, Personal Communication, November 30, 1978
- 53. Average Daily Traffic Counts, Bureau of Planning, State of Florida, Departmenti of Transportation, Tallahassee, Florida, February 20, ;
1978
- 54. S.;:*e of Florida , Department of Transportation, Division of Trans-portacion Planning, Florida Interstate System Bi-Monthly Progress j Report, Tallahassee, Florida, September 1978
- 55. State of Florida, Department of Transportation, Map of " Alternate Corridor Locations". (Undated)
- 56. U S Arniy 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 Analyst - 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 Communication, December 6, 1978
- 61. Director of Public Relations, Allegheny Airlines - Allegheny Com-muter Service, Washington National Airport, Washington, D.C., Letter Dated December 6, 1978
- 62. Allegheny Coma. uter Passenger Traffic Statistics, 1970 - 1977, Allegheny Airlines, Wasiington National Airport, Washington, D.C.
2.1-42 O F 4
SL2-ER-OL ' SECTION 2.1: REFERENCES (Cont'd)- . 'V l 63. Director of Planning, Palm Beach International Airport, West Palm , Beach, Florida, Letter Dated November 30; 1978 , I
- 64. St Lucie County Development Coordinator - Map of Planning Units, , ,
Prepared for Population Count, 1978
- 65. U S-Dept. of Commerce, Bureau of the Census. 1970 Census, Characteristics of the Population, U S Summarv. Issued June, 1973
- 66. Letter L-76-416, to D L Ziemann, Chief Operating Reactors Branch #2 Division of Operating Reactors, USNRC, Washington D C, from R E I
Uhrig Vice President of Florida Power and Light, December 7, 1976. $ 67. Letter FLO-1376, to L Tsakiris, Project Manager, Ebasco Services : from .C S Kent, Project Manager, 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.
1 , [ 69. Unite'd States Geological Survey, "A Land Use and Land Cover Classi- F fication System for Use with Remote Sensor Data." Geological Survey 4 Professional Paper 964. United States Government Printing Office, Washington, 1976. ? O' 70. U S Department of the Interior, Geological Survey, U S Department of Commerce, National Ocean Survey, Coastal Mapping Handbook, U S Government Printing Office, Washington, 1978. l' 71. Florida Department of Administration, Bureau of Comprehensive Plann-ing Generalized Soils Map of St Lucie County, Florida, i i 72. Davis, J "The Natural Features of Southern Florida", Geological , J Survey Bulletin No. 25. Florida Department of Conservation, 1943. i
- 73. Representative, Allen Real Estate, Port St Lucie, Personal Communi-j cation, February 27, 1979.
I 1
- 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, s October 21 and November 2, 1978. l 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
-- . ~
e n - , , . -= .c -wm w w -e'y -- m-w-v ws 7 -w- .ag- i-p+- -- - w wwwry--'c - c- --v- w , -- --v--
. SL2-ER-OL SECTION 2.): REFERENCES (Cont'd)
- 79. Representative, Oceana, Histchinson Island, Personal Communication, April 10, 1979.
- 80. Sales Of fice, Sand Dollar Villas, Personal Communication, January 15, 1979.
- 81. Florida Power and Light Company, St Lucie Plant Unit No. 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 Manastement 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 af County Commissioners by RMDR Planning / Design Group, Tampa, Florida, Augtss t 1973. ,
- 66. The Savannas Plan - Prepared for the St Lucie Board of County Commissioners by the Planning / Design Group, Tampa, Florida, undated.
- 87. Representative, Treasure Coast r.egional Plannin'g Council, Stuart, Florida, Personal Communicatioa, April 10, 1979.
- 88. Superintendent, Water Distr ou".on and Wastewater Collection, Fort Pierce, Florida, Personal Communication, March 12, 1979.
- 89. Tipton Associates, Inc. Hutchinson Island Traf fic Study, Prepared for the Board of County Commissioners, St Lucie County, Florida, June, 1978.
- 90. " Savannas State Preserve", Base Map Prepared by the Department of Natural Resources, 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. 1977 Florida and USDA of ficial estimates from, " Florida Agricultural l Statistics - Livestock Summary, 1977", Florida Crop and Livestock Reporting Service , Or lando , Florida. l
- 94. South Florida Water Management District, Water Use Plan, Volume II, Appendix A, 1977.
O . . 2.1-44 s==
SL2-ER-OL (} V SECTION 2.1: REFERENCES (Cont'd)
- 95. University of Florida, Beef Cattle in Florida, Bulletin 23, ,
provided by T Bordelon of Florida Crop and Livestock Reporting Ser-vice in a personal communication to G Jandegian, Envirosphere Company, March 1979.
- 96. Florida Crop and Livestock Reporting Service, " Florida Agricultural Statistica - Dairy Suasary, 1977", Orlando Florida.
- 97. Florida Crop and Livestock Reporting Service, " Poultry Summary 1977 - Agricultural Statistics,"'Orlando, Florida.
[\ () 98. Florida Crop and Livestock Reporting Service, " Vegetable Summary 1977 - Florida Agricultural Statistics," Orlando, Florida.
- 99. Florida Department of Agriculture and Consumer Services, " Commercial Citrus Tree Inventory - Preliminary Report" Orlando, Florida, August 25, 1978.
100. Florida Crop and Livestock Reporting Service, " Field Crops Summary 1977 - Florida Agricultural Statistics," Orlando, Florida. 101. Florida Department of Natural Resources, Division of Marine Re-sources, Summary of Florida Commercial Marine Landings, Tallahassee, Florida, 1976. (m) x 102. J E Snell, Supervisory Fishery Reporting Specialist, National Marine Fisheries Service, Miami, Florida, Personal Communication, January 1979. 103. Stuart/ Martin Co. Chamber of Commerce, Stuart Resort and Business Guide, 1978. 104. Applied Biology Inc St Lucie Plant Annual 'Non-Radiological Moni-toring Report, Vol II, 1978. 105. B Lusander, J W Corbett Wild Life Management District, Personal communication, January 1979. laA. Outdoor Recreation in Florida 1976, State of. Florida Department of (s)
'~'
Natural Resources, Division of Recreation 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. Regional Profile, Treasure Coast Regional Planning Council, Stuart, Florida, September, 1977. O V 2.1-45 e
. l SL2-ER-OL I
SECTION 2.1: REFERENCES (Cont'd) 110. Florida Department of Natural Resources, Division of Recreation and Parks, Letter Dated May 2, 1979.
'll. Superi~ntendent of Recreation, St Lucie County, Ft Pierce, Florida, letter dated December 5, 1978.
112. Boating Almanac, Vol 6, Boating Almanac Co., Inc. Severna Park, Maryland, 1978. 113. Florida Crop and Livestock Reporting -Service, " Citrus Summary 1977 - Florida Agricultural Statistics," Orlando, Florida. O e
~
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SL2-Ek-OL TABLE 2.1-1 Sheet 2 of 8 RESIDtNT POPULATION WITHlW 50 Mil _ES OF ST LUCIE UNIT 2
, 1980 Annular 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 i
N O 17 0 0 0 0
- 17
- O O O O
- 0* 17 NNE O O O O O O
- 0* O O O O
- 0* O NE O O O O O O
- 0* 0 0 0 0
- 0* O LNL 0 0 0 0 0 0
- 0* 0 0 0 0
- 0* O E O O O O O O
- 0* O O O O
- 0* O ESE O O O O O O
- 0* O O 0 0
- 0* O SE o 15 0 0 0 0
- 15
- 0 0 0 0
- 0* 15 SSE O 10 0 29 1983 6487
- 8509
- 8385 19776 60385 132498
- 221044
- 229553 S 0 0 0 218 240 6965
- 7423
- 20043 633 7022 73024
- 1D0722
- 108145 SSW 0 0 112 208 520 2754
- 3594
- 1957 3435 171 4378
- 10391
- 13985 SW O 20 74 93 2543 2117
- 5447
- 1957 1838 83 18941
- 15819
- 21266 Wsw 0 63 5 22 2878 $938
- 8906
- O O 10032 608
- 10640
- 19546 W 0 20 51 560 559 738
- 1928
- 2070 0 9196 1343
- 12609
- 14537 WNW 0 0 l14 402 1309 3414
- 5239
- 745 0 0 129
- 874
- 6113 NW 0 0 0 34 146 37962
- 38142
- 17084 1859 2318 0
- 20568
- 58703 NNV O 8 12 10 16 3619
- 3665
- 4471 45154 3322 2272
- 55219
- 58b84 Total 0 153 368 1576 10194 70594
- 82885
- 56712 72445 92529 226193
- 447879
- 530764 O O O O O -
- - - _ . . - - . - . , . - . , _ _ .. . , . - _ . ~ - . ~ . .- . - . . - - - . .. . .- . - . - - . . . . _ . . _ . - .._
l 1 i
) \
i I 1 4 1
# l 3
in N o o o o o N N e e o =f e N @ o 4 ** GD N 1
- 4 A @ m m e Q @
l O "eo @ e d N in m N N me e M e -. W e h ! M M en
=P N am M N m e o -
gf N = @ @ e l 4 c L e d * * * * * * * * * *
- e e e e e e
== c o o o o o o o en N
m N e m o @ O N
~ *eo e M o e.
N
< e N h W en e o N
= en o N M t e en ao
@ ==
en 4 N N o =P 0* =o= .Oe == -e m. om 4 e N == 4
# # e e e e e e e e e e e e e e e e o
en o o o o o o o o e 4 N e
== .oe o
m
==
o m.t o e en N N e == o m 9 @ en am m == 4 o o m 4 m == H 4 =r e == 4e en f N J i N' o o o o o o o o o N N o e e o e N e o e e k 4 e m S N .e N e oe "**
** N N tn en N
! E o' 4
==
= =
o N m 4 a o l ** he il O o
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o o o o o o o mo e e o o o o 4 N N 4 N 4 e-w c
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N N
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e. c N e N == e e 4 N km r .i O M o N o o o o o o o N m .e
=
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==
m N N N N N N N e m e 4 e o 4
. = - e l
d o g # # e e e e e e e e e e e e e 'e e e e E' W W d 3 *
** + o o o o o N N N
m e e N e e en n <n e o 4o N W @ % N e ,p c '
@ @ e o m e N
a w - $ o N O n g b 3
$ 4 9 4 4 4 E * * * * * * * * *
- l c * *
.i ~ j o o o o o o o o e== o m m 4 e e or m o en e e S S 4 i E N == o e e e e m
@ N m o @ c m N 4 m e e m
- C 4
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; o'** e o o o o o o o oO e e .e .* k n m ao n
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= c
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==
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N c o o o N e
@ N =
N. 7l o o o o o o o o o o o o o o o el o of 6 4 he
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C U W W la3 3 m' e 3 jMe E 2 E W E 3 W W w3 W laJ M M 3 M 3 3 2 3 Z a c
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- . - - , , . - - , , . - - - - - , , , , , - , - - , ~ , - , . , , , _ . - - , - - - - , , - - - - - . , , , - _ . - , . , , . - - . - .
SL2-ER-OL TABLE 2.1-1 $neet 4 of 8 PESIDENT POPULATION WITillN_50 MILES OF ST LUCIE UNIT 2 1990 Annular Totat Totat Total sector 0-1 1-2 2-3 3-4 4-5 5-10
- 0-le
- 10-20 20-30 30-40 40-50
- 10-50
- 0-30 N O 68 0 0 0 0
- 68
- O O O O
- 0* 68 IGE O O O O 0 0
- 0* 0 0 0 0
- 0* O NE O O O O O O * 'O* O O G 0
- 0* O LNE O O O O O O
- 0* O O O O
- 0* O E O O O O O O
- 0* O O O O
- 0* 0 ESE O O O O O O
- 0* O O O O
- 0* O hE O 60 0 0 0 0
- 60
- 0 0 0 0
- 0* 60 SSE O 38 0 119 2144 7155
- 9456 e 11369 25837 84538 155048
- 276792
- 286248 5 0 0 0 237 298 7582
- 8110
- 27175 855 9830 102232
- 140092
- 148202 SSW D 0 133 269 700 5022
- 6124
- 2653 5226 220 5641
- 13740
- 19864 SW 0 25 86 146 2730 3955
- 6942
- 265) 2492 113 15385
- 20643 a 27585 Wsw 0 75 21 54 3214 12495
- 15859
- O 0 13296 '83
- 14079
- 29938 W 0 21 71 641 680 1563
- 2976
- 2668 0 12188 1774
- 16630
- 19606 WNW 0 0 133 451 1542 3685
- 5821
- 960 0 0 168
- 1828
- 6949 NW 0 0 0 39 160 41058
- 41257
- 21980 1472 2944 0
- 26396
- 67653 NNW 0 30 42 38 62 3898
- 4070
- 5731 57R 4115 2650
- 69838
- 73908 Total 0 317 486 2004 11523 86413
- 100743
- 75189 93224 127244 283681
- 579338
- 680081 O O O O O - --
= _ - - -a - - u---, - - . . - .. - - . . . - . - - ~ . - - - - .. . ~ . - . - - . - - . . . - . . ._.
[ l 1 e en O O O O O N 4 == pm in O ers e p. O O
== O N == N e 4 N e e 4 W == @ .N h @ ar @ M O I
- o
=8 oc
& art
=*
ce
.n P=
**t e
N ee fi 4 8 M N r.t N N e e O en O $ M se e. p
>O
,1 w i e ! e j g e . e e e e e e e e e e e e e e 4 1 O O O O O O O e O O N = O @ M j =* O -e N @ e eri N - @ P= O e ePt P= % et e M M M @ me O M f @ == 689 @ Os == O *= ci > OO me @ .tr4
= N == en est e e=
I' be == tot ase @ e e . e e e e e e e e e e e e e e Q O O O O O O O e% N O ** N e O e F= 0 e ==== in *= == @ e e= en wi @ or9 e e O == O .e 9 se M @ run N M d4 O P= N *= N e == = M N O O O O O O O 40 en == P= 0 O N N w% O .O. M wi M 4 @ es ao .e be .e . W N == 4 em 4 >= m y me q es se ett =F M et - 3 O O ae == == ors D ri em == i hl
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O O O O O O O O < -N e Q O O ,M @ v., .N. e e .. ,,
.O3 8 O e o e P= 4 c9 O O @ N me @ 00
>= N M @ C >
@ ==
tan O O O O O O O O O Po @ N N O e in M eo w% J ee O @ e no e == M ers 4 1 M f N tr% C O O == ori @ M O M == M Wi 79 en v% 4 P= ] J ., as
= -e M w e 4
. E se aJ
- O e e e e e e e e e e e e e e e e e e O t1 eri O e O O O O O O N e == P= >= N 4 4 == e e= ,
e 3 O == .ars
== O O O in as *** N == N == ci W == N eC - ==
- ei M *= P= M N O N O 9 8 3 ed == On a G4 G3 M 4 @ N 4 P N 4 De O e N 4 -
> g HC -
e e e e 4 e e e e e e e e e e e e e e
>= O O O O O O O e N O M O N O @ >= in 4 af ** == N O O e O Pe ==
J O M em O trt O e= r= en e ao
- s =e r= em eO tr4 O N M == M C
% 9 N 4 O in .O
.h
>=
h O O O O O O O e e r= 4 e ** ao ci vm e mi as ei @ O es e in >= O e 4 eri N M 40 m wi P* P= me == >= me N et M === N rn .fe me a O O O O O O O == 4 @ c 4 em. @ *e 4 e t 4 O in N cm a0 == == 4 @ es t N N M == P= ori M ei N M O O O O O O O O O 4 a= *= O O O O so i 3 e ci e e= m 2 ce e.
. ws. wg N ett O O O O O N at O O to @ M C O N O a == O @ N 00 N eri P=
ao me en =r n t =,= O O O O O O O O O O O O O O O of C 4 O i ew me Q ase ii 3 w a l d e ed ini hl lal naa 3 3 3 3 w ] j ce 2 :e3 3 M W M M 3 M z 3 = o 4 rn E 2 3 at tot h3 W3 (#3 m res W3 3 3 3 3 3 De S 4 1 1 4 l 1
. . , - . - - , - - - - , - , ,,n. , - - . - - - - - - - - . , , - - - <
SL2-ER-OL TABLE 2.1-1 Sheet 6 01 8 SESIDENT POPULATION WITttlN 50 MILES OF ST l.UCIE UNIT 2 2010 Asmial a r 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 N 0 155 0 0 0 0
- 155
- O O O O
- 0* 155 NNE O O O O O O
- 0* O O O O
- 0* O NE O O O O O O
- 0* 0 0 0 0
- 0* O ENL 0 0 0 0 0 0
- 0* O O O 0
- 0* O E O O O O O O
- 0* O O O O
- 0* O ESE O O O O O O
- 0* 0 0 0 0
- 0* O SE O 137 0 0 0 0
- 137
- O O O O
- 0* 137 SSE O 85 0 272 2421 8163
- 10941
- 14758 33537 116302 185967
- 350564
- 361505 S o 0 0 268 375 8551
- 9194
- 35277 till 13524 140645
- 190557
- 199751 SSW 0 0 172 374 1009 18103
- 12'18
- 3444 6784 285 7322
- 17835
- 30493 SW 0 32 107 237 3049 6863
- 10;88
- 3444 2236 146 199fd
- 26795
- 37083 WSW 0 96 49 110 3788 20000
- 24043
- O O 17262 s019
- 18281
- 42324 W 0 25 106 781 887 3343
- 5142
- 3463 0 15823 2304
- 21590
- 26732 WNW o 0 164 562 1942 4200
- 6868
- 1247 0 0 218
- 1465
- 8333 NW 0 0 0 46 183 46391
- 46620
- 28533 1912 3824 0
- 34269
- 80889 NtJW 0 70 94 S5 140 4348
- 4737
- 744l 74482 5344 3439
- 90706
- 95443 Total 0 600 692 2735 13794 112962
- 130783
- 97607 121062 172510 360883
- 752062
- 882845 s
9 9 9 9 . 9 - - - - -
.. .. -- ~-. - ..-. =.. . - - - - ~. _ . - , . ~ . _ . . , ..... . ~
+
4 4 s 1 J f , e 4 O O O O O == c O e N em = 4 4 4 e*
==
a P= em e M in o%
=on O
*= M 4
=e == me em e e @ 4 M e
== 0 in.e eC en N e =e 4 O @ #4 ri w in @ N M 4 4 M # C P*
pm og M N == @ MC u. g . . . . . . . . . . . . . . . . O O 3 c, O O O N M r= M on in 4 N 4 ==
=* O O =* in M 4 * == *= P= = '
ac in .s @ in == em @ N @ on se M N 04 Cr* O M == em e e3 ! oC e == == N N N M @ N De == ri N 00 O O O O O O O e on O O s** @ O O == O O en - N M 4 @ M O e 4
@ O O == in N ** M in N M *^
t cri *= 6 N = C m e N c M' 4 =e == [ N O O O O O O O 4
- 4 == @ O O em O Cr*
O @ in m N 4 == @ @ De 4 M == M -@ O 4 N eo e i
== g . O em os em 4 e N 3 O M = == =* GF6 !
M == =* 3 h3
==
0 C O O O O O O O 4 M P= @ O O O e 4 N 3 M @ N em 4 O @ M
' =J e os N 4 er* == 0 4 O @ == P= a=3 N N M H N M e M r4 ==
i fun i O O O O O O O O O 4 N 4 e O 4 4 @ = O N @ e on o - em 4 O l m o c. e em e= ao M 4 N .so m W O @ e ci M M == == 40 ** J == == ri M O g
- a. == ==
8 3
==
,. =3
- O . . . . . . . . . . . . . . . e . .
O N in o en @ O N O O e N 4 O O O O O == M N A @ at hl E o on em in @ == == 4 os @ @ O in Ina .J == N =.= O == == 10 ** ae == M M 4 in N == e e Z u == == @ em ce 4 4 r= O e 4 N 4 k O $ == == == N in 4 g he =* >* O == 5
==
> O O O O O O O in N 4 O O 4 in em to 4 4 @ em ce O O N in == == P=
-4 O e N an in O 4 in M em P=
3 == m @ 4 ao O 4 4 O 4 4 4 h 9 - N e N C e == 1 2 O O O O O O O M M @ == 4 O O @ in el sea 4 == 4 og 4 ao N a. en Q c e in 4 == - O as - == == co
== t H == M 4 N 4 W 4 ==
O O O O O O O on N = e= vn 4 P= os @ O 4 m e N em M 4 O 4 O 4 1 M N 4 N == a0 @ == 0 M M M C C O O O O O O O em @ N N 10 0 P= 4 s as == 4 N em a. co N - - - - - - N 4 O O O O O == @ O O in em @ C C P= 4 i 0 on P= 0 M C N e N j
== == - == - c=
j , 4 1
== 0 O C O O O O O O O O O O O O Cl O f
C i i.n Le
== 0 =.*
2 en c eJ tal 4 W m3 3 3 3 3 u C s E eaa E W EmJ un m 3 m E 3 E o 4 un E E E Ena Esa h3 M V3 (A f4 f4 3 3 3 E E b 4
. . - - , _e#. . w.
Weem--e-m s---ep -9.
*cw w+ v --i-.i e yyp, + -- y-- --+ *p,,,,,- w ww-- +w"TP"'F'1 *TP'Ff"Y9T-T"fT&f' $ rpm'-
SL2-Ek-OL TABLE 2.1-1 Stient 8 of 8 kESIDENT POPULATION WIT aN 50 MILES OF ST LtJCIE UNIT 2 2030 Annuter Total Total Total Sector 0-1 3-2 2-3 3-4 4-5 5-10
- 0-10
- 10-20 20-30 30-40 40-50
- 10-50
- 0-50 N O 237 0 0 '
0
- 237
- O O O O
- 0* 237 NNE O O O O O O
- 0* O O O O
- 0* O l NL 0 0 0 0 0 0
- 0* O O O O
- 0* O 4
LNE O O G 0 0 0
- 0* 0 0 0 0
- 0* O E O O O O O O
- 0* O O O O
- 0* O ESE O O O O O O
- 0* O O O O
- 0* O SE O 209 0 0 0 0
- 209
- O O O O
- 0* 209 SSE O 129 0 414 2678 9869
- 13090
- 17925 40735 145878 215143
- 419681
- 432771 S 0 0 0 298 456 10306
- 19060
- 42848 1349 16963 176411
- 237571 a 248631 SSW 0 0 208 473 1298 17148
- 19127
- 4183 8240 346 8893
- 21662
- 40789 SW 0 38 126 322 3349 10136
- 13971
- 4183 3930 177 24255
- 32545
- 46516 WSW 0 115 76 152 4326 20000
- 24669
- 0 0 20966 1237
- 22203
- 46872 W 0 28 139 912 1082 5506
- 7667
- 4206 0 19219 2798
- 26223
- 33890 WNW 0 0 194 656 2316 5066
- 8232
- 1514 0 0 265
- 1779
- 10011 NJ 0 0 0 52 207 54497
- 54756
- 34657 2323 4645 0
- 41625
- 90381 NNW 0 108 143 129 214 5239 * $833
- 9038 90468 6491 4177
- 180i74
- 336007 Total 0 864 886 3408 15926 137767
- 158851
- 118554 147045 214685 433179
- 913463
- 1072314 e - - - - -
e e e @
...m.__ - . _ _. _ . _ - _ - - . . _ . ., _
et # ar5 o e o e P= N gr O- O O O O O ar% @ *=
=* e en es == e ** e P= sr% N e a @ M eOe e == == m tri Oe 00
==. =#.
ri M. O. e e efi. e w == O e On M @ M 4 P= O 9 e.==e eri tri
= ==
*= N 4 be O O == **
4 4 O O O M @ N O N O e= no 4 O M C O 4
- P= O m a == e =r M C M e 4) te% e3 efi F4 g em e.
. e e e e N. me. 3= a p N egg
@ tri eri Fi er% e4 d d =e N P=
e W me me e =es e N O M o N e em i WG e e O O O O O eri =r @ e O == == == 0 er% N er% N e e= a eg 3e erg 4 == P= @ 00 c=. kO
== N 9 e e N. N. .
. ** -e me ci agg egg I I == =. O O O O @ * *9 @ M e as 4 4 e e O O N .= == N d == N.y eg @ p p N N F9 == 4 @ e O 4>
== e. O. N. M. .
og. e
. N == M == n we == 4 N
{ O O O O O O O N e M N O O e e M N e - M O ar = N e e e N @ erg i
; e ee ee ==. efi c1 e
==.
M m. N e N e. P= N1
. M.
4 .N. @ N l f' "G O O O O O g @ a= M C3 irt == N ist O e= eg O O er N N tri 6 @ P9 N @ @
.==e =. O O == @ P= =r iri m3 v%
0s* 3 9 ee == == N eri 79 O N == O O = c == N t *= N 00 0 P= 80 *e N er% C O O O O O O me
*= @ @ e- m.3 O @
N ei ett as P* a.= e3 O P= W .4e e oe g 4 == e P. e =r. p am == == nm 4 e eq N e tua E O O O O O O O O ar9 @ ** *= == N
- P= m e O N e O N ci em == e= er y
to == gr% N N M tri = at% j e e M. ==. e 5 N ** N == 4 O g I' lhe la == @
==
- se 3 3 3 == 0 O O O O O O @ N N 4 e N 4
=p 4 @ r=
j c 3 e
= 4 @ @ ao == n = ci e
me if% N M =# == N
==
4 he Ea3 9 == 4 == =r == e M ao =e e. p= 4 J U N O O O O O O O P. at 3 3 == N P= O O O no O ci N em 4 b .4 tri == == e3 == =r N. N O N 9 en k
=e W3 O O O O O O O O O O @ @ O P. its N en 4 i % .J O N ins b en
== *e @ O 80 @ P= =r N =r e 8 >* O e =* == == =r M er e
a est U e == anB .J W U3 == 0 S =4 W **e e O M C N @ a N 4 O 4 5 == 0 C O O O O O tr% a= m3 at wJ De m =* 9 Fi Fi N an == O Pm O eg
==
v3 en E 4 N t = tal E M E eat N
==
O O O O O O O == tri an art e ci O ci
==
N ors
==
e e ==
==
se
@ q O
erg - the E e O ~ ce 3 O O O @ e
>= O O O O O O O O M tf% P= N et 3 * -
e o @ N @ e erg O es O 3 == == 4 O
"fa e e D e ne d == e O O N =r @ 0 *= a
= ==* == 0 C O O O O O ei == ==
60 g GB S E N m se N en N h to 4r3 P4 == g
>e 1 g Q N O O @ N e == e O O e N O O O O O O O es P.
=p u In3 = ci N N ==
= g O ee 4 ee W
e9 O O O O O =r e O O e3 @ O O e M + c = eo.
. a5 e= @ ==ch ori == ci M to u he e M e w e ne e n a0 c > ==
.=.=e == == 0 9 8 ao O O O O O e O O O 4 N Pi O O 33 O O e N == == == == P= h3 se N am w Q E.
t 0 3e e
==
N es O O O O O @ 4 O O @ O ers O O es t .rs = se g +=e e
== N N == N == l == - 30 9 1
e ? 4-e -. me O e ne* U e oce ap C O O O O O O O O O O O O O O O O e t-
==
a e no e s e e d h e ee
==we h c w e C e S a= 0 0 0 0 C" O O O O O O O O O O O O ce w t
wew
== n > 3 e
== .G. e,n..f.
t C W =D C e N ee e t ' =e O O O J O O O O O O O O O O O O O C C C O Q O e9 e em to to em O 9 W W 4e &L& U W !al an3 W 3 3 3 3 e e e e a sm3 E v3 tal era 44 3 un 3 - 3 3 e e U3 E E E Esa tal ina U3 U3 U3 e va 3 3 3 E E e
- . - - . , _ - - . , - -. ,- - - - - . _ , .~-~w- ~ n.
SL3-Ek-OL
- TABLE 3.1-3 CITIES TOWNS AND COMMUNITIES OF OVER 5,000 PERSONS WITHIN 50 MILES OF ST LUCIE UNIT 2 ESTIMATED POR 1978 a) Communities of over 10,000 Parsons 1976 1976 1970 Population Population ,,
_ City or Town County Populatios. (E s t ima t ed ) (Estimated) west Palm Beach'** Palm Beach 57,375 61,236 62,616 Fort Pierce St Lucie 29,721 32,182 33,083 kiviera Beach *** Palm Beach 71,401 25,892 27,735 Vero Beach Indian River 11,908 15,303 16,800 North Pale bg gh Pale seach 9,035 13,026 15,014 Palm Springs ,,, Palm Beach 4,340 8,437 18,300 Palm Beach Cardens Palm Beach 6,102 9,182 10,792 Stuart Hartin 4,820 8,479 10,760 b) Communities of between 5,000 and 10,000 Persons 1976 1978 1970 Population , Population .. County or Town County Population, (Estimated) (Es t im a t ed ) Palm Beach Palm Beach 9,086 9,724 9.952 Cifford , ludian River 3,509 5.772 9,485 Lake Park ,,, Palm neach 6,993 8,182 8,652 Creenacrea City Palm Beach 1,733 4,447 6.773 Pahokee Palm Beach 5.663 5.813 5,864 Port St Lucie** St Lucie 330 4.463 6,465 Royal Palm Beach Palm Beach 475 2,380 5,598 Treasure Coast Regional Planning Council, Regional Profile, September 1977 Table 30. an Hethodology discussed in Section 6.I.4.2. ama Part of West Palm Beach Urbanized Area, 1970 Census. Florida Number of inhabits ta, Table it and Figure 11-45. 1377 pwpulation estimated on baala of annual average growth rate from the
- 1000 population of 3,509 to the 1970 population of 5.772 (1970 Census, Florida Number of Inhabitants, Table 6) because 1976 estimate was not available.
" Population Estimates and Projections", Comprehensive Planning Program, prepared by the City Planning Dept, Port St Lucie, Florida February 1978.
O O O O _ O
_ ..n. . . _ _ __a . _ . ~ _ --. - e O O e e M=. O @ , M e O O O O O O O N == @ O I e =e N @ h P=e ee e M @ i , see O e es G N e in e e est e e M. .
. o.
S em W M @ Os == S == M M 0 ** @ Pm pg po
.in se g3 T O O *se
>*=e S me
** M g
===
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J J U I, 6 S t.2-ER-OL TABLE 2.1-6 Sheet 2 of 4 TRANSIENT POPULATION: ATTENDANCE AT ATTRACTIONS AND EVENTS 1978-2030 wuebe r o f Pe r sons 1978 Total for Events i ; Annular . Time of (of more Peak Sector Location Year than one day) Daily Manimum 1980 1983 1990 2000- 2010 2020 2030 l.
- b. Attractions and Events Between 10 and 30 Miles of St Lucie Unit 2
, 10. Dodgert g Sports NNW 20-30 Vero beach March 7405 10000 7541 7712 9248 10000 10000 10000 10000 I Comptes JaiAlgotbort Whw 10-20 Fort Pierce Year-Round 3200 4000 3352 3428 4000 4000 4000 4000 4000 Pierce
- 12. HartgCounty S 10-20 hartin March 27000 7559 7917 8096 9709 11500 13292 15083 16857 Fair County Fair- ,
grounds, in Stuart i
- 13. Martin County g S 10-20 Stuart Fall Football 4500 4500 4500 4500 4500 4500 4500 4500 School Stadium
- 14. St L g County NW 20-30 St Lucie February 20800 8300 8693 8890 10660 12628 14595 16562 18509 Fair County Fair-
- grounds, in a Fort Pierce
- 15. VeroBeachSengHigh NW 20-30 Vero Beach Fall Football 8000 8000 8000 8000 6000 8000 8000 8060 School Stadium C. Attractions and Events Between 30 and 50 Miles of St Lucie Unit 2
- 16. Fish Fry. Volun g NW 40-50 Crant February 30000 15000 15711 16778 19266 22821 26375 29931 i'450 Fire Department Brevard County t l 17. Horse S 40-50 Palm Beach Year-Bound 2000 2095 2142 2569 3043 3517 3991 4460 Complex baargrounds
- 18. Labor Day kodeu and WSW 30-40 (Aeechobee Se pt embe r 12000 10000 10474 10711 12844 15214 17584 19954 22300 II I Bluegrass Convention city 1
4
, .,w- -
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- O e e a= 0 0 C in N l @ Q O 3 O e se 3s O O O
=
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==
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O 8 O O O O N et* g w N 40 ao ao O O O O O O O O O M == 20 eo m P= @ @ P' N eA A me H C O 4 O O 9. N O O O O 4 O ep ao O + N N so O O 35 l @ O O N O 4 O 4 O O O e 3s O m == GO em n @ @ m ** C == ^ ** g * -e e
- be 4 O O == O N e= @ O O O g m ca o O e= 0 == en e o O O 6 m S et. O O O O N N A O O O e O M == 3 e 4 en @ @
en me @ @ O he 4 O em O e -e *= 0 O O s O N O .s O *= r= m O O O a e I en Q d O O == N O O O g e m == m3 @ es en @ e P= 3 == m E V3 4
>* E 3 3 O O O w g C O O 3 a i O O O w as @ @ P*
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+== 4 == w e o e O w Q -e eo O 4 = w 4 >
De -as es ** m3 C to 4 sa he 42 .e he at he g Se C 83 eb 4 *3 E W e ad C W e4 50 es 4 a0 u J Q 4 & en E 4 W 4 37 > as 3 he I he es W g he W h ed u OG E ed u es8 ** O 3 s"* A ** me a-o be o g e ame e e g e g e,s e 4 g == e 4 g *3 en *J 4 # C =8 4 4 gC= me 4 4 g g g g 4 m se &W 4 4 W W == 3 48 as V3 ** *C lb. Q & &a. As sa. .B e se ime OQ 3 m3 E a. 3 aa a he 9 4 <3 2
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- vre u u w S 3 *3 e pw 5 U w .g ena e h Gem 3 =. =3 .e = = = mEwa.a. me8 4== e aw H 09 he O 88 W hs U C D 4 UN W 4 g hs 4 4 4 2e k he V Q 'a 3 4 + 3a eO m3 Q 13 3 ann N .D* > a. 3 2. == 3. e = 3 g he 4 C 4 =e J 3 -e 3 w m., .g ..e es *C u 4 3 he C 4 e ha - Q. O e E es 8 g 33 u ais ad *= =* *i8 8 *3
.s 3 =* ** 3 Q g a me == u g 3 3..=. y a e7 e* a 'C = .a me -=* 4 ** O + J 4 se g 3 ==
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$ 12-E R-OL TABLE 2.1-6 Sheet 4 of 4 i
j TkANSILNT POPULATION - ATTENDANCE AT ATTRACTIONS AND EVENTS 1978-20}0 SObBCES OF INFOL ' TION 1 (1) Chairsan, Ar t-on-the-Creen Festival, Fort Pierce. Florida. Latter 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 November 28, 1978 (4) Director, Stuart/hartin County Chamber of Commerce Stuart, Florida, Letter Dated November 22, 1978 (5) Supervisor of Special Facilities, St Lucie County Civic Center, FL Fierce. Florida. Letter Dated November 17, 1978 (6) Executive Secretary Sandy Shoes Festival (1979) Fort Pierce Florida, Letter Dased November 27, 1978 (7) Of fice of Eastern Division Manager, Los Angeles Dodgere Baseball Team, Dodgertown 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 November 17, 1978 (9) Fair Secretary, hartin County Fair Association, Stuart, Florida, Letter Dated November 20, 1976 (10) Athletic Director. Hartin County High School, Stuart. Florida. Letter Dated November 28, 1978 ' (11) Fair Secretary, St Lucie County Fair Fort Pierce. Florida, Letter Dated November 20, 1978 (12) Finance Officer. Indian River County Schools. Vero Beach, Florida. Letter Dated November 27, 1978 (13) Chairmaa, Fish try in Grant, Melbourne, Florida, Personal Communication, December 14, 1978 (14) Horse Complex, Palm Beach County Fairgrounds, West Palm Beach, Florida, Personal Communication, November 21, 1978 (l' . Okeechobee Chamber of Commerce. Okeechobee, Florida. Latter Dated November 17, 1978 (16) Difice of Public Felations. Lion County Safari, Royal Palm Beach, Florida Letter Dated November 20, 1978 (17) Chaissan, Offshort Sport Fishing Tournament, Sebastian, Florida. Letter Dated December 13, 1978 (18) Froject manager, PGA Comples. Florida Realty Building Company, West Palm Beach, Florida Letter Dated becember 11, 1978 (19) Of fice Hana;er, Pahokee Chamber of Commerce, Pahokee, Florida, Letter Dated November 20, 1978 (20) Palm Beach Auto Auction, Palm Beach County Fairgrounds, kest Palm Beach, Florida, Personal Communication, Dec embe r 11, 1978 (21) South Florida Fair, Pale beach County Fairgrounds, West Palm Beach, Florida. Personal ;.amunications, November 23 and 27, 1978 (22) Peta beach kennel Club - Greyhound Racing, West Palm Beach, Florida, Letter Dated November 21, 1978 (23) Went Palm Beach Auditorium, West Palm Beach, Florida,14tter Dated November 22, 1978 (24) Office of Public Relations, West Palm beach Jai Alai, West Palm Beach, Florida, Letter Dated November 21, 1978 (25) Sprind Training Coordinator Atlanta Braves West Palm Beach Municipal Stadium West Palm Beach, Florida.
Letter Dated November 20, 1978 a
S L2- E R-OI. table 2.5-7
! TRANSIENT POPULATION: MAJOk INDUSTRIAL LMPLOYERS AND COI.LEGES 1978-2d30 1978 Annular Total Peak Daiiy Sector Location Employment Em ployment 1980 1983 1990 2000 2010 2010 2010 A. Mj or Industrial Engiovers I. Crumman Aeaospace S 10-20 Hartin County Airport, St uar t 731 700 700 700 700 700 700 700 700
- 2. Piper Aircrate(2) NW 10-20 vero beach Municipal Airport 2887 2000 2000 2000 2000 2000 2000 2000 2000 Indian River County
- 3. Psatt & Whitney I3 S 30-40 Route 770, South of koute 710 7261 6094 6094 6094 6094 6094 6094 6094 6094 Government Palm Beacle County Prctuct. Division Total Peak Daily Enrollment Enrollment B. H jjor Colleges
- 4. FloriJa In tute of SSE 5-10 Jensen Beach Campus 900 1050 l200 1200 1200 1200 8200 120C Tec tinol og y
- Har tin County
- 5. Indian kiver g NW 5-10 Fort Pierce Campus 11200 1500 20'0 2417 2818 3486 4312 5334 6599 Couimunity College St Lucie County S 10-20 Stuart Campus, Martin 1280 171 234 276 322 J98 492 609 753 County WSW 30-40 Oke echobee Campus, Okeect obee 320 43 59 69 80 100 t23 152 188
- b. Hajor Colleges County Mn.- 2 0- 30 Veio Beact Campus, Indian 3200 428 585 691 806 997 1233 1526 1888 River County (1) Personal Communication, Pe r sonnel Depar tment , Gruimaan Aerospace, November 30, 1978.
(2) Pe r sonal Com.annic ation, Per sonnel Department, Piper Aircr alt Corp, December 4,1978. (3) Per son:ll Communication. Employment Office, Pratt & Whitney Aircratt. November 30, 1978. (4) Personal Communication, Student Activities Office, Florida laatitute of Technology, Jensen beach Campus, November 27, 1978. (5) Personal Communication, Office of the Vice President, Indian kiver Conanunity College, Fort Pierce Campus, November 28, 1978. O O O O _ O
1 ,
,i' 8 6 6 1 6 4 9 7 8 6 7 1 5 7 4 _
4 8 1 5 4 4 7 8 0 5 4 9 3 8 4 _ 0 3 2, 5, 0, 5 4, 8 1, 7, 2, 9, 6, 9, 2 7, 1, 0 6 5 2 4 8 4 3 3 2 6 6 8 2 3 9 _ 2 3 1 1 1 3 5 4 1 2 3 5 ._ 0 7 2 7 1 3 0 6 5 4 1 9 2 6 1 9 9 4 1 0 3 9 2 7 5 3 8 9 2 1 0 2 5, 9 6, 0, 5, 3 7, 2, 9, 9, 7, 9, 8, 2, 9, ( 0 5 4 8 3 6 4 1 0 1 0 1 6 9 0 2 s 2 2 1 1 1 3 5 4 1 1 3 5 r e g n 6 4 0 1 0 8 0 5 0 1 7 1 9 5 8 e 2 0 4 7 4 1 9 3 4 0 6 7 2 3 1
. s s
0 1 9, 4, 2 4, 5 8, 3, 6, 7, 9, 7, 9, 5 6, 6, a 0 4 4 5 1 4 3 0 6 1 4 6 4 7 6 6 P 2 2 1 1 1 2 4 3 1 1 2 4 f o 3 0 8 6 0 9 8 3 8 2 1 5 2 4 2 2 r 5 0 2 7 0 8 3 0 2 7 4 5 3 9 e 0 2, 8, 8, 19, 5, 3, 9, 0 5, 8, 7, 9, 1, 0 2, T b 0 I m 0 4 3 1 9 2 3 8 3 1 8 1 2 5 3 0 H u 2 2 1 2 3 3 1 1 2 4 b N E y I l 9 7 0 1 3 0 1 0 2 5 2 8 7 0 9 C i 9 1 4 8 2 9 9 6 7 0 6 3 0 6 5 U L D a 0 9 5, 2, 4, 3, 6, 7, 5, 4, 2, 8, 8, 9, 8, 4, 0, 9 3 3 8 8 0 2 7 9 1 2 6 0 2 9 4
- T e 1 1 1 1 3 2 1 1 1 3 S g a
F r O e 4 2 8 8 1 9 0 6 7 8 9 5 3 6 8 v 3 0 5 9 5 2 1 4 0 6 9 2 5 4 6 S E 2 A 3 8 1, 8, 0 2, 2, 4, 6, 9, 1, 5, 3, 5, 1 9, 6, L t d 9 3 2 6 7 9 2 6 6 1 8 3 9 1 6 9 I i e 1 1 1 2 2 1 1 2 M n t U a 0 m 3 e i 5 4 8 4 3 5 0 9 7 2 1 0 4 9 2 .- i t 3 2 3 3 6 7 9 6 3 5 1 2 2 4 6 8 N c s 9, 8, I u E 0 8 6, 0 8, 6, 2, 1, 8, 0, 7, 9, 9, t 4 7, H L 9 2 2 5 6 8 2 6 5 1 6 1 8 i 0 5 7 T 1 1 1 2 2 n 1 1 2 I t U W S e S f i D o c o A u t O s 2 5 7 5 1 2 0 1 0 1 2 6 L 1 1 7 . R e 8 0 0 5 2 7 7 1 5 9 4 2 1 7 5 2 s l 7 8, 5, 3 5, 2, 1, 9, 1, 9 5, 9, 5, t 9, 1, 5, r - R i 9 S e . O M 1 2 2 4 6 8 2 5 5 5 0 8 9 5 6 b y 8 J 1 1 2 2 f 1 2 mt - - A 0 o un 1 H 0 1 nu L 3 s o 2 N 0 n e ec
+ O 2 i l d k E h i oh E L S 8 t M cc
- B R 7 i ) a 2 A E 9 W d 0 se L T G 1 n 3 n S N a ) u gn E d y o n ii S a a b i s S o w h h sn A R e t t ae P r s r i k e e u d d o W d d d ga Y t b a n n N n n n nt L a m C u u / s u u u i I t u o o e y o o o ne A S N 4h 8 1 9 1 4 6 b 9 b 3 g 4 a b b b nr D 1 c 6 2 9 5 7 0 h 7 h 1 d 4 w h h h aa d n 1 a 2 1 1 1 2 1 t 2 t 1i 1 h t t t l E n o e u r r g u u r P s C a i B o o B i o o o t A t S N H S S N f n R s a h t ou E y t t l o V a S r e uc A w o v a h N e e)
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I ( . T nc A oi L r if U e tf P v e h aa O i e c t r . P y e e e e e e e e e e R b a rt 2 t i i i i i i i i i i o e o T n c c c c c c c c c c n n n h B py 8 N u u u u m u u u u u u i i a c sl t o L L L I l L L L L L t t i e m ni 3 i C r r d c l aa . S t t t t t t t t t t a a n k a rd 1 N S S S S S S S S S S M H I O P T . A e 2 R f g T oa n r o t e i pv t ea c D e e S
, r ae y e e e idh w g e r o
, k k k k on l i p i p i p i p l o o Fi d n n n n t o r r r r f a h u u u u ot t T t T T s e e H e s s s s t h t ac e u A 'a 'a 'a 'a t a e o A 5 7 1 d 9 d A d d S e S N 1 0 0 8 1 0 /i 0 /i I /i /i A 6 I 6 6 6 7 1 r 7 1 r I A 5 r 5 r k R S R R R R 9 o R 9 o 9 19 o 9 o ) )
- l l S k - - l - l 1 2 S S U S S S S l F S 1 F U S l I F I F ( ( !i4 l l :1 ii 1 4
SL2-ER-OL table 2.1-9 TRAhSILNT POPULATION: AVERACE DAILY PASSENGERS bY RAll AND AIR WITHIN 50 HILES OF ST LUCIE UNIT 2 1978-2030 county Location 1978 1980 1983 1990 2000 2010 2020 2010 A. kail I. Amtrak -S card - Scbring - West Palm Beach 3f (2) g95(3) 206 240 289 338 387 436 Coast Line B. Ap
- 2. West Palm beach Palm Beach rest Palm Beach 4.878(2) 5,387 7,086 12,258 IS,163 18,068 20,973 23,878-International Airport (4}
III Peak daily capacity (that is, all seats available on all sin traina on the line on one day) was 2,474 in 1978 (August). Pe r sona l Coeusun ic a t iori , Route Analyst, Eastern Routes, Marketing Research, Amtrak, Washington, DC, November 22, 1978. (2) See Methodology, Se c t ion 2.1. 3. 8. III In May, 1979. Congress accepted a Department of Transportation plan to reduce service to Florida from three traina each day to one t'.ain. It is expected that ridership will be reduced to half the 1978 levels with this change in service. Sources: Personal Communication, Hanager - Eastern Routes, Marketing Research, Amt rak, Washington, DC, May 22, 1979. (4) Data include implanements and deplanements. Pe r sonal Commun ic at ion. Director of Planning, Palm Beach International Airport, West Palm Beach, Florida November 30, 1978. O O O O O
3 9 1 3 8 8 4 0 2 4 4 0 9 3 3 3 0 3, 2 1 1 1 1 2 3 3 4 6 2 8 4 0 0 7 4 1 9 7 2 2 2 1 1 1 ( 2 0 9, 2 2 0 9 0 1 7 9 6 0 2 3 9 8 5 0 0 1 0 6, 1 1 1 1 - 2 2 7 3 4 0 5 4 1 0 6 3 6 7 3 9 9 1 0 2, 1
. 0 2 2 4 8 9 9 4 0 7 2 0 1 2 3 5 1 8 7 7 8
. E 9 9 9, 1 1 3 7 I 1 1 1 9 C 1 U , L 5 , 7 5 1 1 0 9 7 3 0 8 T 3 6 2 2 5 0 6 6 1 1 7 S 8 6, 1 1 p 9 9 8 r 1 F 1 1 p 7 e O 9 b , t 1 m 4 S c e 1 E 1 3 3 8 3 5 3 i , v L 0 6 2 1 4 9 6 6 r 0 o r I 8 5, 1 t 1 N e M 9 s b 1 1 i r d m 8 0 D e n e 7 3 b a t 9 e o p 1 N 0 2 8 0 9 2 0 l t 4 e I 8 9 2 0 4 8 6 6 l c 1 S , H 7 4 1 i O 4 T 9 v r , 1 I 1 1 n d e n 8 W o n b o 7 r _ s a m i 9 e S d k e t 1 b Y n c 4 t a m A a a 1 p t , e W l J e r 4 t R s r S o p 1 p E I 6 e e T 7 b . s r S A n 9 m a n e 0 W o 1 e d a b , 1 s t i r m a
- N0 t n , p r T e d 1 O10 r n i I e o t i I V L O
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i j SL2-Ek-OL TABLE 2.1-12 Sheet 1 of 2 LAND USES AND LAND COVER WITHIN FIVE MILES OF ST LUCIE UNIT 2 Level 1 Land Use Ac reage Level II Land Use Acreage Level III Land Use Ac re age Classilication Percent of Total Classification Percent of Total Classification Percent of Total
- 1. UkBAN Ok bulLT-UP LAND 3.541 7.0 II. Residential 2,300 4.6 111. Single-family Resi- 2,220 4.5 dances 112. Multiple-family 20'
- Residences
- !!6. Transient Lodgings 60 .!
- 12. Commercial and Services 28
- 122. Retail, Commercial 22
- Services 123. Institutional Ser- 6
- vices
- 13. Industrial 14
- 131. Light Industrial 14 *
, 14. Transportation, Communi- 964 2.0 141. Highway, Principal 210 .4 catJans, and Utilities Road ] 142. Railroad 50 .I t 143. St Lucie ! & 2 300 .6 Facilities 144. Transmission Lines 386 .8 145. Utility Storage Ib *
- 17. Other Urban or Built-up 235 .5 171. Cemetery 10
- Land 172. Undeveloped Land 37 .I 173. Recreation Facilities 188 .4 ,,
I 2. - ACRICULTURAL LAND 54I 1.1 21. Cropland and Pasture 449 .9 212. Citrus Groves 449 .9
- 22. Other Agricultural Land 92 .2 221. Nurseries 9
- 222. Old Field 83 .2 l
- 4. FOREST /MARSu COVEk' 10,653 21.2 41. Coniterous Forest / 7,910 15.6 410. Fine Flatwood Forest / 5,594 !!.!
Freshwater Harsh Freshwater Marsh 411. Freshwater Marsh 2,316 4.6
- 42. Other Forested Wetland 2,743 5.5 421. Mangrove 2,743 5.5
SL2-LB-OL TABLE 2.1-12 Sae e t 2 of 2 Level I Land Use Acreage Level 11 Land Use Acreage Level 111 Land Use Acreage Classification Percent of local Classification Percent of Total Classification Percent of Total
- 5. bATLk 34,649 69.3 Freshwater 1,243 2.5 510. Streams and Canals !!3 .2 511. 1.a k e s 1,130 2.3
- 52. Fresh / Salt Water 10,656 21.2 520. Estuary 10,656 21.2
- 55. Salt Water 22,950 45.6 550. Open Marine Water 22,950 45.6
- 7. BAkkEh LAhD 652 1.4 71. Natural barren Land 97 .2 710. Beaches 97 .2
- 74. Han-made Barren Land 585 1.2 740. transitional Areas 390 .8 741. Estractive 195 .4 50,266 1002 50,266 100% 50,266 100%
'The forest cover is to a great estent cor.centrateJ in a t ransitional area which is primarily marshy but includes relatavely dry sites. In addition, the Florida lanJ use/ccver classification syst em consiJers mangroves as a type of wetland - hardwood forest. To account,for these considerations, the USGS categories of Forest and Wetidnds were combined, a Less than .It O O O O O
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i SL2-ER-OL TABLE 2.l-13
~
TOTAL BEEF CATTI.E AND BEEF SLAUCHTER WITHIN D-50 MILES OF SITE t Countv Total No. of Head
- Total Staathter/Yr kg/yr (10 )
BrevarJ 2.250 675 231.5 Glades 3,000 900 308.6 lii gh l and s 1,680 504 '12.8 Indian kiver 15,000 4,500 1,543.1 ; Martin 35,000 10,500 3,600.7 l t Okeechobee 36,400 10,920 3,744.7 Onceola* - - - j Pala beach 17,600 5,280 1,810.6 l St. Lucie 26.000 7,800 2.674.8 1 4 [ t 136,930 41,079 14,086.8
*No beef production assumed since that portion of county within 0-50 miles of site la wetland, !
according to USGS maps. 4 a) 1977 Florlds and USDA of ficial estimates from, " Florida Agricultural Etatistics-Livestock , i
~
Summar y 197 7,** Florida Crop and Livestock Re por ting Service,1222 Woodward St., Or lando, 1 4 Florida 32803. b) Only those portions of county within 0-50 mile radius of alte considered, excluding wetland areas. c) Estimated f rom county totals assiuming equal distribution of cattle throughout county. i i j ! l 4 I 4
SL2-ER-OL { TABLE 2.1-14 DAIRY llERDS AND HILK PRODUCTION ** WITilIN 50 HILES OF ST LUCIE UNIT 2 Ileifers lleifers 1977 Annual Number of Over Under No. of Milk Prodiaction Coimty Dairies 500 lb 500 lb Hilk Cows (1000 lb) Brevard 1 85 75 300 3,000 liighl and s 1 145 140 720 7,600 Indian River 3 445 310 1,830 , 15,900 Hartin 6 800 710 2,710 25,400 Okeechobee 20 7,260 6,440 22,300 226,000 Palm Beach 6 430 590 4,140 33,900 St. Lucie 4 595 420 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 Woodward Street, Orlando, Florida 32803. (b) Estimated from county totals for 0-50 mile radius, assuming equal distribution of dairies throughout county. O O - --- O O . 9
I i SL2-ER-OL TABLE 2.1-15 MILK UTILIZATION FROM DAIRY HERDS- l i WITHIN 50 MILES OF ST. LUCIE UNIT 2 a) l
- 1. Average Annual Milk Production per Cow = 9,666 lbs = 4,385 kgs
- 2. Milk Fat (aversge) = 3.52
) = 330.0 x 106 lbs = 151.0 x 10 kgs 6
- 3. 1977 Annual Milk Production
- 4. Milk Utilization 0
(a) Used on Fars = 3.1 x 100 lbs = 1.4 x 10 kgs
- 1) For milk, cream, butter = 2.0 x 100 lbs = 0.9 x 106 kgs 6
- 2) Fed to calves = 1.1 x 106 lbs = 0.5 x 10 kgs (b) Milk Sold Directly to consumers = 5.1 x 106 lbs = 2.3 x 106 kgs (c) Milk Sold to Plants for
= 324.8 x 106 lbs = 147.3 x 106 kgs I
Manufacturing Dairy Products l
- 1) For frozen products-ice cream, ice milk, sherbert = 7.6 x 106 gal
- 2) For cottage cheese -curd, 6
creamed = 8.9 x 106 lbs = 4.0 x 10 kgs
- 3) For skim milk and butter 6 6 milk products. = 23.2 x 10 lbs = 10.5 x 10 kgs
- 4) For whole milk products = 61.0 x 100 lbs = 27.7 x 100 kgs (e) 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.
O
SL2-ER-OL TABLE 2.1-16 EGG PRODUCTION WITHIN 50 MILES OF ST LUCIE UNIT 2(* County (b) Number of Layers Number of Eggs /D y Brevard 4,500 2,925 l Glades 750 488 Highlands 750 488 Indian River 25,000 16,250 Martin 25,000 16,250 0 Okeechobee 16,250 10,563 Palm Beach 11,950 7,768 St. Lucie 25,000 16,250 (a; 1977 data frw " Poultry Summary 1977 - Florida Agricultural Statistics", Florida Crop and Livestock Reporting Service, 1222 Woodward Strest, Orlando, Florida 32803. (b) Accounts only for those portions of county within 50 miles of plant site; assumes equal distribution of layers throughout county. O O
, SL2-ER-OL TABLE 2.1-17 Sheet 1 of 2 FLORIDA COMMERCIAL VEGETABLES . PRODUCTION IN 0-50 MILE RADIUS STUDY AREA (a,b) Principal Production Acres Harvested County Species Center 1976-77 1973-74 ) Brevard Tomatoes Fort Pierce (1) 126 Watermelon (1) 36 Glades Tomatoes Pahokee 60 101 Highlands (2) O. Corn Pocacoes (1) (1) (2) Indian River Tomatoes Fort Pierce (1) 700 Watermelon (1) 200 Okeechobee Tomatoes Pahokee 273 754 Watermelon 228 650 Ma rtir. Pocacoes Stuart 7503 (2) Tomatoes (1) 500 Waterme lon (1) 200 Palm Beach Be ans Pompano 6,070 7,816 O Cabbage Celery Corn Pahokee (1) (1) 404 3,476 16,280 (1) Cuciunbe rs 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 O St Lucie Tomatoes Watermelon Fort Pierce 745 (1) 875 200 4
I l SL2-ER-OL TABLE 2.1-17 Sheet 2 of 2 Principal P roduction Acres Harvested County Species Center 1976-77 1973-74 Other Counties Snap Beans 1,'i70 1,190 Cabbege 2,900 3,340 Celery (2) (2) Sweet Corn (2) (2) Cucumoer 2,550 2,190 Eggplant 680 540 870 1,660 GreenPegrs 3,650 4,950 Pocacoes 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 (a) From " Vegetable Summary 1977 - Florida Agricultural Statistics", Florida Crop and Livestock Reporting Service, Orlando, Florida 32803. (b) Estims ed 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. (c) Counties throughout the state whose production was not large enough to warrant special statistics by individual county. O l O
SL2-ER-OL TABLE 2.1-18 O FLORIDA COMMERCIAL VEGETABLE ACREAGE ANQ_} PRODUCTION - SOUTHEAST COUNTIES 1976-77'" Acreage Yield Per SE Production State Produc-Crop 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 Cucumbe rs 1,850 1,700 279 474 3,802 O Eggplant 1,350 1,175 760 893 1,367 l Green Peppers 3,750 2,650 478 1,268 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 11,580 555 5,941 24,210 From " Vegetable Summary 1977-Florida Agricultural Statistica", NM Reporting Service, 1222 Woodward Street, Orlando, Florida 32803 l i O ' l i O q .--- , ---, -,
. - - , , ,,,y, y ,<yw
SL2-ER-OL TABLE 2.1-19 FLORIDA COMMEICIAL VECETABLE PRODUCTION, CEOP YEAR 1976-77(8) Net Wt. Acreage Average Yield per Acre Production Con.inod i ty Unit Ib/ Unit Plasted liarvested Units _l b L 1,000 Units beans Bushel 30 39,600 29,500 125 3,750 1,701 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 15,73: 5,833 Sweet Corn crate 42 63,300 50,300 238 9,996 4.534 !!,990 Cucumbers Bust el 48 16,100 15,000 253 12,144 5,509 3,802 Eggplant Bushe! 33 2,250 1,950 701 23,133 10,493 1,367 Escarole Crate 25 6,900 6,000 513 12,825 5,817 3,080 Le t t uc e Cwt. 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 Putatoes Sack 100 30,500 30,800 206 20,600 9,344 6,207 Radishes Carton !!.5 31,000 27,300 291 3,347 1.578 7,933 Squash Bushe! 42 12,600 12,000 ISS 6,636 3,010 1,893 Strawberries !!at 10.25 1,500 1,500 1.418 14,535 6,593 2,127 Touatoes Carton 30 43,200 34,000 751 22,530 10,220 24,210 Wa t e rme lon s Cwt. 100 65,000 51,000 175 17,500 7,938 6,925 I*I t r osa "Vege t able Suaumary 19 77 - F? cida Agricult ural St atist ic.", Florida Crop and Livestock Reporting Service, 1222 Woodward Street, Orlando, Florida 31803 O O O O O - - - -
SL2-ER-OL TABLE 2.1-20 Sheet 1 of 2 FLORIDA CITRUS ACREAGE AND PRODUCTION 1976-77(* Est. Unit Prod. Harvest We, 1,000 Total County Fruit Unit Ib Boxes Acreage Brevard All Oranges Box 90 807 2,517 Early & Mids Box 90 507 1,351 Valencias Box 90 300 1,135 3 O All Grapefruit Seedy Seedless Box Box Box 85 85 85 203 194 9 636 53 527 2 201 Specialty Fruit Box 90 39 All Citrus Box 1,049 3,354 Glades (b) All Oranges Box 90 33 96 Early & Mids Box 90 24 59 Valencias Box 90 9 37 All Grapefruit I Box 85 2 5 Seedy Box 85 0 0 Seedless Box 85 2 5 2 Specialty Fruit Box 90 1 12 All Citrus Box 36 113 Highlands (b) All Oranges Box 90 265 847 Early & Mida Box 90 98 225 Valencias Box 90 166 603 All Grapefruit Box 85 71 143 Lady 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 I Box 90 5,120 22,947 Early & Mids Box 90 2,937 10,972 Valencias Box 90 2,183 11,572 All Grapefruit I Box 85 8,537 30,477 x Seedy Box 85 42 350 d Seedless Specialty Fruit Box Box 85 90 8,495 427 28,182 2,782 ,
All Citrus Box 90 14,084 56,206 - Okeechobee All Oranges' Bc x 90 482 1,872 Early & Mids Box 90 284 864 ) Valencias Box 90 198 999 All Grape!ruit Box 85 170 636 Seedy Box SS 1 3 , Seedless Box 85 169 632 Specialty Fruit 2 Box 90 31 198 All Citrus Box 683 370
, - - y - - - = , w- - -g-9 ,- -- = = w --*e,
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I SL2-ER-OL TABLE 2.1-20 Sheet 2 of 2 1 Est. Unit Prod. Harvest Wt, 1,000 Total County Fruit Unit Ib Boxes Acreage Martin All Oranges I Box 90 6,.97 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 2 4,733 Specialty Fruit Box 90 288 All Citrus Box 8,486 40,264 Palm Beach All Oranges 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 912 7,669 St Lucie All Cranges I Box 90 8,984 36,619 Early & Mids Box 90 4,668 14,997 Valencias Box 90 4,316 21,009 All Grapefruit I Box 85 9,306 30,050 Seedy Box 85 39 372 Seedless Box 85 9,267 27,746 2 Specialty Fruit Box 90 1,072 7,243 All Citrus Box 19,362 73,912 State Total All Oranges' Box 90 186,800 628,567 Early & Mids Box 90 115,000 318,832 Valencias Box 90 71,800 298,236 All Grapefruit 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 Sucznary 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.
. _ _ . ~ . - _ . - - . _ . . .- - _
O i I SL2-ER-OL i TABLE 2.1-21 SUCARCANE PRODUI p,.,N WITHIN 50 MILES OF ST LUCIE UNIT 2
- Acres Harvested Yield Per Acre (tons) Production (tons)
County 1976 1977 1976 1977 1976 1977 Clades 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 j 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.
l l SL2-ER-OL 1 TABLE 2.1-22 Sheet 1 of 5 FLORIDA MARINE LANDINGS: FOOD FISH, SHRIMP AND SHELLFISH MARINE LANDINGS SY COUNTY, 1976'"' Weight Weight Shellfith, et al (kg) County Fish (kg) Brevard Amberj ack 6,804 Clams 22,928 Angelfish 1,242 Crab, Blue (Hard) 715,338 Blue Runner 526 Crab, Blue (Soft) 107 Bluefish 70,760 Crab, Stone 1.378 Bonico 1,437 Lobster, Spiny 1,558 Catfish, Fresh-Water 710 Oysters 11,187 Catfish, Sea 1,374 Scallops 193,460 Cigarfish 9 Shrimp 237,673 Cobia 642 Squid 1,275 Crevalle (Jacks) 3,206 Total Shellfish, Croaker 865 et al 1,184,902 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 Jew fish 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 195,972 Spot. 34,031 Swordfish 37,486 Tenpounder 159 Tilefish 9,091 Trigger Fish 1,402 , Tripletait 406 Wahoo 405 ; Warsaw 3,797 I Unclassified for Food 17,948 I l l e w
l 1 l SL2-ER-OL TABLE 2.1-22 Sheet 2 of 5 Weight Weight County Fish (kg) Shellfish, et al (kg)
. Unclassified for Miscellaneous 29,778 Total Fish 1,430,449 Indian River Amberjack 321 Class, Hard 2,922 Angelfish 101 Crab, Blue (Hard) 4,137 Blue Runner 1,165 Lobster, Spiny 258 O Bluefish Bonito Catfish, ses 36,743 306 60 Oysters Total Ghe11 fish, et al 452 7,769 Cobia 1,482 Creville (Jack) 981 Croaker 15 Dolphin 1,005 Drum, Black 464 D ru.a . Red 2,805 Flounder 162 Goatfish 86 Grouper and Scamp 16,487 Jewfish 1,083 King Mackerel 374,212 i
King Whiting 3,043 Menhaden 373,970 Mullet, Black 105,069 Mullet, Silver 3,402 Pa.rait 275 Pigfish 319 Pompano 49,539 Sea Bass 3,082 Sea Trout 27,850 Sheepshead 607 Snapper 28,589 Spanish Mackerel 79,510 Spot 77,787 Tilefish 5,582 O Trigger Fish Tripletail Wahoo 236 88 49 Unclassified for ! Food 13,416 l Total fish 1,209,890 l l Martin A:sberj ack 2,215 Lobster, Spiny 885 Angelfish 327 Total Shellfish, 885 Blue Runner 14,206 et at Bluefish 237,057 Bonito 47 Catfi '1, Fresh-Water 503 Cat a... Sea 5,644
SL2-ER-OL TABLE 2,1-22 Sheet 3 of 5 h) Weight Weight County Fish (kg) Shellfish, et al (kg) - 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 Hcgfish 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 Mackstel 1,441,118 Spanish Sardines 7,278 Spot 16,477 Swordfish 3,037 Tilapia (Nile Perch) 136 Tilefish 1,344 l Trigger Fish 87 l Tripletail 604 I Warsaw 38 Unclassified for Food 12,699 i Unclassified for l Miscellaneous 51,165 1 Total Fish 2,238,715 I Palm Beach Ambe rj ack 1,464 Crab, Blue (Hard) 953 l 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 4 Weight Weight County Fish (kg) Shellfish, et al (kg) ' 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 O ,
Flounder Goatfish 726 1,037 6 Grouper and Scamp 3,074 Grunt 363 Hogfish 11 Jewfish 35-King Mackarel 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 O Scup Sea Bass 20 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 Amberjack 15,895 Crab, Blue (Hard) 1,633 Angelfish 489 Lobster, Spiny 3,110 Barracuda 998 Total Shellfich, i Blue Runner 10,795 et al 4,743 Bluefish 125,705 Bonico 6,592 Cobia 2,294 Crevalle (Jack) 4,132 _ . - . _ . - , _ _ _ _ . . _ _ ._ _ __ _ _ . _ . _ - . _ _ . . _ . ._ , _ _ _ __ __ l
SL2-ER-OL TABLE 2.1-22 Sheet 5 of 5 Weight Weight County Fish (kg) Shellfish, et al (kg) St Lucie Croaker 1,067 (Cont'd) Dolphin 6,032 Drum, Black 4,534 Drum, Red 1,227 Flounder 1,167 Coatfish 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 Sheepshead 7,322 Snapper 24,859 Spanish Mackerel 1,636,766 Spot 31,125 Swordfish 3,701 Tenpounder 48,932 Tilefish 770 Tripletail 420 Wahoo 937 Warsaw 1,111 Unclassified for Food 22,497 j Unclassified for Miscellaneous 323 Total Fish 3,255,905 (a) From " Summary of Florida Commercial Marine Landings, 1976", Florida Department of Natural Resources, Division of Marine Resources, l Tallahassee, Florida. l
~
O
l SL2-ER-OL TABLE 2.1-23 COMMERCIAL MARINE LANDINGS OF ' COUNTIES WITHIN 0-50 MILE RADIUS (10 'tg)(* l County 1976 1975 Percent Change l 1 Brevard
)
Fish 1,430.5 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 l 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 /.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
' O' Palm Beach (b)
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 Shellfish 1,216.2 1,926.5 -36.9 (a) From "Sammaary of Florida Commercial Marine Landings,1976", Florida Department of Natural Resources, Division of Marine ; Resources, Tallahassee, Florida. l O
SL2-ER-OL TABLE 2.1-24
SUMMARY
OF HARINE LANDINGS F{ COUNTY, 1976(a) Chellfish Food Fish Non-Food Fish (excluding Ehrimp) Shrimp Total County Weight (kd Weight (kg) Weight (kg) Weir,ht (kg) Weight (kg) Brevard 1,147,852 282,597 947,229 237,673 2,615,351 Indian River 835,920 373,970 7,769 0 1,217,659 Hartin 221,863 16,853 885 0 239.601 Palm Beach 1,401,123 103 17,939 0 1,419,165 St Lucie 3,239,018 16,887 4,743 0 3,260,648 Total 6,845,776 690,410 978,565 237,673 8,752,424 (a) From "Sunuaary of Florida Commercial Marine Landings, 1976", Florida Department of Natural Resources, Division of Harine Resources, Tallahassee, Florida. O O O O O
i i i 1
- 1 1
SL2-ER-OL t j TABLE 2.1-25 j 1 1 J.W. CORPETT WILDLIFE MANAGEMENT AREA
' "NTING DATA (a) ,[
Species Number Taken Number Taken Common Name Sept 9, 1977 - Jan 7, 1978 Jan 8, 1978 - Mar 26, 1978 i
- Dee r 71 86
, Dove 53 468 i l Duck 15 e } - Hog 19 7 175 l Quail 658 If#,569 Rabbit 8 82 i Raccoon 13 7 . Snipe 226 661 , Squirrel 50 43 l Turkey 0 3 (a) From data provided by B. Lusander, J.W. Corbett Wildlife Management District, January, 1979. i i
SL2-ER-OL TABLE 2.l-36 kECREATIONAL WATER USE WITHIN 50 MILES OF ST LUCIE UNIT 2 Average Daily , per Capita Participation kate Average Daily Recreational Saltwater Users within 50 miles of St Lucie Unit 2 i Recreational 2020 2030 Activity besidents III Tourists 1978 1980 1983 1990 2000 2010 Be ach Ac t i-vitica (salt- 135,478 149,325 66,666 73,159 80,879 94,703 110,017 122,940 water) .5095 .3264 Fishing * (saltwater) .0403 .0228 20,423 22,227 24,574 28,777 33,430 37,357 41,172 45,374 Boating (saltwater) Power 40,099 44,194 Boating .0362 .0550 19,820 21,650 23,936 28,029 32.560 36,385 1,529 1,698 1,877 2,197 2,553 2,853 3,143 3,465 Sailing .0018 .0157 1,993 2,230 2,465 2,886 3,353 3,746 4,127 4,550 Surfing .0017 .0279 Population within 50 miles of St Lucie Unit 2 (see Section 2.4.2) 483,765 530,764 580,742 680,081 790,040 832,845 973,061 1,072,314 kesident Peak limity Tourists and 72,026 80,485 88,631 97,758 Seasonal visitors 41,953 47.927 52,965 6l,993 Notes: (I) Assinaes that daily usage of resident population is limited to weekends. Hay through October. Therefore, the 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 aver age daily per capita par ticipation rate (e.g., 0.1095 f or beach activi-ties). Region X raten used. 'l (2) Assinues that tourista atay 13 days. Annual per capita rates are therefore divided by 83. Region K rates eised. Source: Outdoor Necreation in Florida 1976. State of Florida Dept of Natural Resources, Division of kecreation and Parke, Tallahassee, Florida, May, 1976. 197 7 Florida Tourist Study, An Executive Summary, Florida Department of State. Division of Tourism Tallahassee, Florida, 1977. 9 O O O e
i 4 ) i i ; SL2-ER-OL ' i i
= TABLE 2.2-1 VEGETATIVE COMPOSITION OF .
i FP&L PROPERTY I i j Vegetation Cover Type Acres Hectares Percent
~
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