ML17264A401
| ML17264A401 | |
| Person / Time | |
|---|---|
| Site: | Ginna  |
| Issue date: | 02/24/1996 |
| From: | ROCHESTER GAS & ELECTRIC CORP. |
| To: | |
| Shared Package | |
| ML17264A399 | List: |
| References | |
| NUDOCS 9603140438 | |
| Download: ML17264A401 (29) | |
Text
GINNA STATION COLR Cycle 25 Revision 0 CORE OPERATING LIMITS REPORT
{COLR)
Res onsible Hanager Effective Date Controlled Copy Ho.
1 9gPgg4Q4QB 9EIOS~
PDR ADQCK 05000244
R.E.
Ginna Nuclear Power Plant Core Operating Limits Report Cycle 25 Revision 0
This report is not part of the Technical Specifications.
This report is referenced in the Technical Specifications.
TABLE OF CONTENTS 1.0 CORE OPERATING LIMITS REPORT....... -.......
2 2.0 OPERATING LIMITS 2.1 SHUTDOWN MARGIN.
2.2 MODERATOR TEMPERATURE COEFFICIENT 2.3 Shutdown Bank Insertion Limit.
2.4 Control Bank Insertion Limits 2.5 Heat Flux Hot Channel Factor (Fo(Z))
2.6 Nuclear Enthalpy Rise Hot Channel Factor (F"~)
2.7 AXIAL FLUX DIFFERENCE 2.8 RCS Pressure, Temperature, and Flow Departure from Boiling (DNB) Limits 2.9 Boron Concentration Nucl
~
~
cate 3
3.3' 4
4 5
5 3.0 UFSAR CHAPTER 15 ANALYSIS SETPOINTS AND INPUT PARAMETERS.....
5
4.0 REFERENCES
6 FIGURE 1 -
REQUIRED SHUTDOWN MARGIN...................
7 FIGURE 2 -
CONTROL BANK INSERTION LIMITS FIGURE 3 - K(Z) - NORMALIZED Fo(Z)
AS A FUNCTION OF CORE HEIGHT 8
9 FIGURE 4 - AXIAL FLUX DIFFERENCE ACCEPTABLE OPERATION LIMITS AND TARGET BAND LIMITS AS A FUNCTION OF RATED THERMAL POWER 10 TABLE 1 - UFSAR CHAPTER 15 ANALYSIS SETPOINTS AND INPUT PARAMETERS.....
11 COLR Cycle 25, Revision 0
RE E.
Ginna Nuclear Power Plant Core Operating Limits Report Cycle 25 Revision 0
1.0 CORE OPERATING LIMITS REPORT This Core Operating Limits Report (COLR) for Ginna Station has been prepared in accordance with the requirements of Technical Specification 5.6.5.
The Technical Specifications affected by this report are listed below:
3.1.1 3.1.3 3.1.5 3.1.6 3.2.1 3.2.2 3.2.3 3.4.1 3.9.1 "SHUTDOWN MARGIN (SDM)"
"MODERATOR TEMPERATURE COEFFICIENT (MTC)"
"Shutdown Bank Insertion Limit" "Control Bank Insertion Limits" "Heat Flux Hot Channel Factor (Fo(Z))"
"Nuclear Enthalpy Rise Hot Channel Factor (F"~)"
"AXIAL FLUX DIFFERENCE (AFD)"
"RCS Pressure, T~emperature, and Flow Departure from Nucleate Boiling (DNB) Limits" "Boron Concentration" COLR Cycle 25, Revision 0
2.0 OPERATING LIMITS The cycle-specific parameter limits for the specifications listed in Section 1.0 are presented in the following subsections.
These limits have been developed using the NRC approved methodologies specified in Technical Specification '5.6.5.
All items that appear in capitalized type are defined in Technical Specification
- 1. 1, "Definitions."
- 2. 1 SHUTDOWN MARGIN (LCO 3. 1. 1)
(Limits generated using Reference 1)
- 2. 1. 1 The SHUTDOWN MARGIN in MODE 2 with K,<< < 1.0 and MODES 3 and 4 shall be greater than or equal to the limits specified in Figure 1 for the number of reactor coolant pumps in operation.
2.1.2 2.1.3 The SHUTDOWN MARGIN in MODE 4 when both reactor coolant pumps are not OPERABLE and in operation and in MODE 5 shall be greater than or equal to the one loop operation curve of Figure l.
The SHUTDOWN MARGIN required in LCOs 3. 1.4, 3. 1.5, 3. 1.6,
- 3. 1.8, and 3.4.5 shall be greater than the limits specified in Figure 1 for the number of reactor coolant pumps in operation.
2.2 MODERATOR TEMPERATURE COEFFICIENT (LCO 3..1.3)
(Limits generated using Reference 1) 2.2.1 The Moderator Temperature Coefficient (MTC) limits are:
The BOL ARO/HZP -
MTC shall be less positive than +5.0 pcm/
F for power levels below 70%
RTP and less than or equal to 0 pcm/
F for power levels at or above 70% RTP.
The EOL ARO/RTP -
MTC shall be less negative than -42.9 pcm/ F.
where:
ARO stands for All Rods Out BOL stands for Beginning of Cycle Life EOL stands for End of Cycle Life HZP stands for Hot Zero THERMAL POWER RTP stands for RATED THERMAL POWER 2.3 Shutdown Bank Insertion Limit (LCO 3. 1.5)
(Limits generated using Reference 1) 2.3.1 The shutdown bank shall be fully withdrawn which is defined as ~ 222 steps.
COLR Cycle 25, Revision 0
2.4 Control Bank Insertion Limits (LCO 3. 1.6)
(Limits generated using Reference 1) 2.4.1 2.4.2 The control banks shall be limited in physical insertion as shown in Figure 2.
The control banks shall be moved sequentially with a 100
(+5) step overlap between successive banks.
2.5 Heat Flux Hot Channel Factor F
Z (LCO 3.2. 1)
(Limits generated using References 1 and 2) 2.5.1 Fo(Z) s ~F J"K(Z)
P F (Z) s ~F g"K(Z) 0.5 when P > 0.5 when P ~ 0.5 where:
Z is the height in the core, Fo = 2.32, K(Z) is provided in Figure 3, and THERMAL POWER P
=
RATED THERMAL POWER 2.6 Nuclear Enthal Rise Hot Channel Factor F" J (LCO 3.2.2)
(Limits generated using Reference 1) 2.6.1 F"
s F"
- (1 +
PF
- (1-P))
where:
F ATP PF~
= 0.3, and THERMAL POWER P
=
RATED THERMAL POWER 2.7 AXIAL FLUX DIFFERENCE (LCO 3.2.3)
(Limits generated using References 1 and 3) 2.7.1 2.7.2 The AXIAL FLUX DIFFERENCE (AFD) target band is + 5%.
The actual target bands are prov'ided by Procedure RE-11. 1.
The AFD acceptable operation limits are provided in Figure 4.
COLR Cycle 25, Revision 0
2.8 RCS Pressure Tem erature and Flow De arture from Nucleate Boilin Li (L
(Limits generated using Reference 4) 2.8.1 2.8.2 2.8.3 The pressurizer pressure shall be a 2205 psig.
The RCS average temperature shall be ( 577.5 F.
The RCS total flow rate shall be a 170,200 gpm.
2.9 Boron Concentration (LCO 3.9. 1)
(Limits generated using References 1 and 5) 2.9. 1 The boron concentrations of the hydraulically coupled Reactor Coolant System, the refueling canal, and the refueling cavity shall be a 2000 ppm.
3.0 UFSAR CHAPTER 15 ANALYSIS SETPOINTS AND INPUT PARAMETERS The setpoints and input parameters for the UFSAR Chapter. 15 accident analyses are presented in Table 1.
The values presented in this table are organized based on system and major components within each system.
The failure of a component or system to meet the specified Table 1 value does not necessarily mean that the plant is outside the accident analyses since:
(1) an indicated value above or below the Table 1
values may be bounded by the Table 1 values, and (2) the setpoint or parameter may not significantly contribute to the accident analyses final results.
The major sections within Table 1 are:
1.0 Reactor Coolant System (RCS) 2.0 Hain Feedwater (HFW) 3.0 Auxiliary Feedwater (AFW) 4.0 Main Steam (HS) System 5.0 Turbine Generator (TG) 6.0 Chemical and Volume Control System (CVCS) 7.0 Emergency Core Cooling System (ECCS) 8.0 Containment 9.0 Control Systems 10.0 Safety System Setpoints 11.0 Steam Generators COLR Cycle 25,'evision 0
4.0 REFERENCES
2.
3.
5.
WCAP-9272-P-A, Westinghouse Reload Safety Evaluation Methodology, July 1985.
WCAP-9220-P-A, Westinghouse ECCS Evaluation Hodel-1981 Version, Rev.
1, February 1982.
OR WCAP-10054-P-A and WCAP-10081, "Westinghouse Small Break ECCS Evaluation Hodel Using the NOTRUHP Code," August 1985.
WCAP-10924-P-A, Volume 1, Rev.
1, and Addenda 1,2,3, "Westinghouse Large-Break LOCA Best-Estimate Methodology, Volume 1:
Model Description and Validation," December 1988.
WCAP-10924-P-A, Volume 2, Rev.
2, and Addenda, "Westinghouse Large-Break LOCA Best-Estimate Methodology, Volume 2:
Application to Two-Loop PWRs Equipped with Upper Plenum Injection," December 1988.
WCAP-10924-P-A, Rev.
2 and WCAP-12071, "Westinghouse Large-Break LOCA Best Estimate Methodology, Volume 2:
Application to Two-Loop PWRs Equipped With Upper Plenum Injection, Addendum 1:
Responses to NRC Questions,"
December 1988.
WCAP-10924-P, Volume 1, Rev.
1, Addendum 4, "Westinghouse LBLOCA Best Estimate Methodology; Hodel Description and Validation;'Model Revisions,"
August 1990.
WCAP-8395, "Power Distribution Control and Load Following Procedures Topical Report," September 1974.
WCAP-11397-P-A, "Improved Thermal Design Procedure",
April 1989.
WCAP-11596-P-A, "Qualification of the PHOENIX-P/ANC Nuclear Design System for Pressurized Water Reactor Cores,"
June 1988.
COLR Cycle 25, Revision 0
3 tU 2 Cl Cf CL g1 0
0 (1600, 1A5)
(1500, 1lN)
ACCEPTABLE OPERATION ONE LOOP
%NO LOOP OP ERA'nON UNACCEPTABLE OPERATION (0,2AS)
(0, 1 1500 1000 500 COOLANTBORON CONCENTRATION (ppm)
FIGURE I REQUIRED SHUTDOWN MARGIN COLR Cycle 25, Revision 0
~ 220 I> 200 2 180 Q 160
~ $ 40 B 120 o )00 o
80 60 ca 40 o
20 0
0 8 Bank
- ddd, C Bank OB 10 20 30 40 50 60.
70 80 90
'f00 Core Power (Percent of 1520 MNIT)
The fullywithdrawn position is defined as ~222 steps.
FIGURE 2 CONTROL BANK INSERTION LIHITS COLR Cycle 25, Revision 0
0.75 Total Fq = 2.320 0.25 Core Height 0.00 6.00 10.80
$ 2.00 K(Z) 1.000
$.000 0.940 0.647 0
a 4
6 8
CORE HE}GHT(ft}
FIGURE 3 K(Z) -
NORMALIZEO Fo(Z)
AS A FUNCTION OF CORE HEIGHT COLR Cycle ZS, Revision 0
(-1 $,90)
DO NOT OP ERA1% IN THIS AREA iIVITHAFD OUTSIDE THETARGET SANO
(<180) 80 0
60 lL 40 (44,60)
ACCEPTABLE OPERATlON NlfH AFD OUTSGE THE TARGET 8AN9 NITHcf HR PENALTY DEMATION ThlE P1/0)
ACCEPTABLE OP ERATION 20 0
<0
-20
-10 0
50 20 30 AXIALFLUXDIFFERENCE (%)
FIGURE 4
AXIAL FLUX DIFFERENCE ACCEPTABLE OPERATION LIMITS AND TARGET BAND LIMITS AS A FUNCTION OF RATED THERMAL POWER COLR 10 Cycle 25, Revision 0
Table 1:
UFSAR Chapter 15 Analysis Setpoints and Xnput Parameters Xtem g Xtem/Name Value Remarks:
1.0 Reactor Coolant System (RCS)
Upper head volune, ftn Upper Plenun volune, ft'op of fuel volune, ft Inlet nozzle(s) volune, total of two, ft Outlet nozzle(s) volune, total of two, ft Active fucL voLune, Bottom of fuel volunc, ft Lower Plenun volune, ft Downcomer volune, above bottom of cold leg, ft Oowncomer, lower core plate to elevation of thc bottom of the cold lcg volunc, ft Barrel baffle, lower core plate to upper ccrc plate volune, ftn Total volunc, ft'ot lcg pipe volune per loop volune, ftn Cold lcg volune per loop + cross over, ftn RC pump volune per pump, ft Cold leg pipe ID, in. /Pump suction IO, in.
Hot lcg pipe ID, in.
Design prcssure, psig Design tenperature, F
Cold Lcg and Hot Leg Centerline ELevation 300.0 580.2 50.3 43.2 37.4 367.6 11 ~ 0 514.3 138.4 278.2 128.5 2449.1 78.7 cross over ~ 140.7 cold Lcg = 46.8 192 27.5/31 29 (28.969) 2485 650 246'0" Above upper support plate.
Bottom of upper core plate to top of upper support plate.
Includes outlet holes in the barrel.
Top of active fuel to bottom of upper core plate, inside barrel baffle.
Includes nozzle forging protrusion into vessel.
Does not include mating hole in barrel, this is included in the Upper Plenun votune.
Bottom of fuel to top of fuel Top of lower core plate to bottom of active fuel.
Below top of lower core plate Above bottom of cold leg clcvation to bottom of upper support plate Top of lower core plate to elevation of bottom of cold leg Top of lower core plate to bottom of upper core plate.
Includes nozzles Reactor Coolant Pmp Head-Capacity and HPSH curves for reactor cooLant pumps/Homologous Curves Rated RC punp head and flow, ft 8 gpm Rated RC punp torque and cfficicncy Q rated head/flow, ft-lb, fraction RCP Pump Rated Power (hot, 556 dcgrces F)
RCP Hotor Rated
- Speed, RPH Homent of inertia of pump and motor, lb-ft See HSILL 252; 90,000 84y. efficiency at hot conditions 4842 BKP 1189 80,000 Homologous Curves are available in RETRAH COLR Cycle 25, Revision 0
Table 1:
VFSAR Chapter 15 Analysis Setpoints and Xnput Parameters Xtem 4 Xtem/Name Value Remarks:
-RC pump power, HMt (max/min) 10, 8 Purp power varies with RCS tarp from approx 8 KMt to 10 HMt 1.2 Core Rated power, IQt Reactor power uw:ertainty,
)! RTP
- Bypass,
)!
Upper head bypass,
)(
Upper head tcaperature, degrees F
Heat transfer area, ft Average core heat flux, Btu/hr-ft*
1520 4.5 LI proprietary 590 26,669 189,440 Thimble plugs removed.
1.3 1.3.1 Fuel Assanbties Height Total, inches (length from bottom of assarbty to top nozzle)
Fuel Rod Length, inches (length fran bottom of pin to top of pin)
Active, inches 159.935 149.138 141.4 Fuel Assarbty Geanetry Hoss of fuel, tbm Hass of clad, ibm Hunber of fuct pins per fuel assarbty (FA)
Ho. of Fuel Assarblies Fuel pin pitch, in.
Bottom nozzle weight and volune Top nozzle, w/ insert, weight and votune Fuel Assembty resistance (core dP f(flow)], psi f(tb/hr)
Fuel Asscnbty frcc flow area, inn 105,500 25,927 179 121 0.556 9.1 lbs.
31.5 in'8.15lbs.
62.9 in'ore delta P n 20 psi 9 flow = 170,200 gpm 34.75 Thimbte plugs removed.
SingLe assarbly 1.3.3 Fuel pin geometry Pcltet diamctcr, in.
Clad 00/IO, in./in.
0.3444 0.400/0.3514 1.3.4 Control Rod B Instruncnt Guide Tubes Ho. of control rod guide tubes Ho. of instruncnt guide tubes Control Rod Guide tube upper part 00/IO, in./in.
instruncnt Guide tube OD/IO, in./in.
Guide tube lower part OD/ID, in./in.
16 0.49/0.528 0.395/0.350 0.4445/0.4825 COLR 12 Cycle 25, Revision 0
Table 1:
UFSAR Chapter 15 Analysis Setpoints and Input Parameters
(
Xtem g
Item/Name Value Remarks:
Control Rod Drop Times,
- maximuns, sec.
Control rod maxiaxxa withdrawal rate, in./min.
Control rod maximua insertion rate, pcm/scc.
Control rod insertion limits Hot channel radial peaking factor Heat Flux Kot channel factor FQ Hon-LOCA 2.4 LOCA 3.0 45 90 Sce COLR 1.66 2.32 Allowances arc added to the Tech Spec allowable value.
1.4 Pressurizer Code safety valve flow capacity, ibm/hr Code safety Code safety Spray valve Spray valve Spray valve Spray valve PORV nunber valve open time valve setpoint number flow capacity, gpn/valve setpoint-start open/full open time constant, sec.
PORV flow capacity, ibm/hr PORV Cv PORV open time PORV close time Backup Heaters Hinimua hcatcr capacity required for LOOP, kW Kcatcr bank controller type PORV setpoint (normal) open/close, psig PORV sctpoint
[LTOP] open/close, psig PORV blowdown characteristic Heater capacity w/ bank capacity and sctpoints, kW Control banks 288,000 0.8 sec seal clearing time 2485 psig 2
200 2260/2310 5
2
.179,000 50 gpm/(psid)1/2 1.65 sec
+ transmitter 3.95 sec
+ transmitter 2335/2315 430 800 0
kW at 2250 psig and 400 kW at 2220 psig Full on at 2210 psig and resets at 2220 psig 100 proportional 400 kW Rating at 2485 psig plus 3X accunulation Crosby Hodel HB-BP-86, size 4K26 Tolerance is + 2.4X/-3X.
Proportional Assumed value Steam flow at 2335 psig Rating is for liquid relief. Valve characteristic is quick opening see Copes Vulcan Selecting and Sizing Control Valves 8/75, page 8, Table 18 for Cv vs travel curve.
LTOPs transmitter is Foxboro E11CH-HSAE1, with a time response of 1 sec (time to 90X of final value for step input)
LTOPs transmitter is Foxboro E11CH-HSAE1, with a time response of 1 sec (time to 90X of final value for step input) 1.4.1 Pressurizer voluae(s)
(100X / OX power)
Water, ft (100X / OX power)
Steam, ft (100X / OX power)
Total, ft 396/199 404/601 800 COLR 13 Cycle 25, Revision 0
Table 1:
UFSAR Chapter 15 Analysis Setpoints and Input Parameters
(
Item Item/Name Value Remarks:
Pressurizer ID, ft-in Surge linc ID, in.
Spray line ID, in.
Surge line voiure, ft 83.624 in / cladding thickness is 0.188 in 8.75.
3.062 18.4 Surge line is 10 in schedule 140 1 4.2 Pressurizer Level Lower level tap elevation Upper level tap elevation Pressurizer level vs X power Distance Hot Lcg Centerline to Lower Tap, ft Haximm level allowed for steam bubble, X
257' 275' Xpower Level 0 X 19.5X 100 X 49X 10.750 87 Pressurizer level is rampcd linearly bctwecn these points.
1 5 RCS Flows, Tcaperature and Pressures Total reactor coolant flow, gpm (15X plugging)
Total reactor coolant flow, gpm (15X plugging)
Average reactor coolant tettperature, degrccs F
(Full power/HZP)
Reactor coolant prcssure, psig Reactor coolant flow uncertainty, X nominal Reactor coolant temperature uncertainty, degrccs F
Reactor coolant prcssure uncertainty, psi DHB Limit (safety analysis) 170,200 173,800 573.5/547 2235 3.1 a 30 1.52 typical cell 1.51 thimble cell Use for non DNB Use for statistical DHB 1.6 Low Tesperaturc Ovcrpressurc Protection (LTOP)
Hinimua RCS vent size, square inches Ho. of SI pumps capable of injection (PORVs/vent)
Haximua pressurizer level for RCP start, X
0/1 38 1.7 Fuel Handling/Dose Calculations Maxiaxln reactor coolant gross specific activity Haximun reactor coolant dose equivalent I-131 Haximua secondary coolant dose equivalent I-131 Hinimm reactor coolant boron concentration, ppm Hininxm reactor coolant level Hiniaxia spent fuel pool level Kinlaam spent fuel pool boron concentration, ppm Spent fuel pool tecpcrature, degrees F (min/max)
Hinimla spent fuel pool charcoal filter efficiency, X methyl iodine removal 100/E pCi/gm
~ 1.0 pCi/gm 0.1 pCI/gm 2000 23 ft above flange 23 ft above fuel 300 50/180 90 COLR 14 Cycle 25, Revision 0
Table 1:
UFSAR Chapter 15 Analysis Setpoints and Xnput Parameters
(
Xtem g Xtem/Name Value Remarks:
Hinimm post accident charcoal filter efficiency, X methyl iodine removal Ninisxln control room charcoal filter efficiency, X methyl iodine removal Hininua time between reactor criticality and fuel movement, hrs.
Source Terms used for dose calculations Haximm Gas Oecay Tank Xenon-133 concentration, Ci 90 90 100 TIO 14844, WCAP-7823 100,000.
2.0 Nain Fecdwater (NRI)
Fecdwatcr tceperaturc versus load Power Temperature 102X 425 F
70X 385 F
30X 322 F
OX 100 F
100X design temp is 432 dcgrces F
2.1 Feedwater Suction Tecperature vs Power, nominal Fcedwatcr Suction Pressure vs Power, nominal Head-Capacity and NPSN curves Head-Capacity and NPSN curves for main fecdwater IxmlPS Hain Fccdwater pmp - Rated Head Nain Fcedwatcr pmp - Rated Torque Nain Fecdwatcr purp - Nomcnt of Inertia ELevation of steam generator inlet nozzle Elevation of main feedwatcr pump, ft Elevation of condensatc punp, ft HFW regulating valve open time on demand, scc HFW regulating valve close time on demand, sec HFW regulating valve Cv, full stroke Low load NFW regulating valve Cv, (bypass valves)
Power 98X 70X 50X 30X Power 98X 70X 50X 30X Tempcraturc 345 F
319 F
295 F
259 F
Pressure 277 psig 282 psig 305 psig 370 psig See NSILL 2150'89.612 257.75 250.833 10 990 48.7 Selected flow splits are provided for model validation.
Elevation is at center of shaft HFW transients use 20 scc stroke time Assuaed vaLue.
Actual value "-493.6.
Effective Cv: includes bypass line 3.0 HFW Neater rcsistancc (delta P)
Auxiliary Fccdwatcr (ARI)
Ninimm design tccperature of thc water source se'rvicc water / CST (degrees F)
Haximrn design tcaperaturc of the water source service water / CST (degrees F) see NS8L 32(+),
50 80, 100 Oesign data on the Nigh Pressure Heaters (2 in parallel) is provided Initial AFW water source are the CSTs located in the Service Bldg. Safety Related source is thc Service Water system (lake).
- Value different for CNHT integrity.
Initial AFW water source are thc CSTs located in the Service Bldg. Safety Related source is thc Service Water system (lake).
COLR Cycle 25, Revision 0
Table 1:
UFSAR Chapter 15 Analysis Setpoints. and input Parameters
'I item 4
Xtem/Name Ualue Remarks:
Startup time for thc auxiliary fecdwater
- pumps, sec Hininxrn delay for AFM start, sec Haximm delay for AFM start, sec AFM control valve open time on demand, scc AFM control valve Cv(flow is f(dP)]
TDAFMP, maximun flow, gpm AFM, minimus flows, both generators intact, gpn Hinimun delay for standby AFM start, min TOAFM - 0, HOAFM -
1 HOAF'M - 47, TOAFM at LO Level both SGs N/A 600 TOAFMP 200/SG HOAFMP 200/SG 10
HOAFM starts on SI (seq), or LO level either SG, or trip of both HFP or AHSAC HOAFM acceleration time test results show approximately 1.5 s.
For HDAFM, LOOP on sequencer is 47 sec.
TOAFM starts at nominal 17X in both SGs HOAFM control valves are normalLy open and throttle closed to control flow between 200-230 gpm HOAFMP valves are 3 Rockwell model g A4006JKHY stop check valves.
TOAF'M control valves (4297, 4298) are 3 Fisher 0470-NS.
SBLOCA assunes 300 gpm pcr SG with the failure of onc DG 4.0 Hain Ste~ System (HS)
Location (and elevation) of condenser dunp valves and atmospheric relief valves Full load stcam line pressure drop, psi HS Isolation valve close time (full open to full close] close time, sec HS Isolation valve Cv (flow is f(dP)]
CSO - elcv 256'.875 ARV - elev 289'.563 approx 45 HSIV - 5.0 check valve - 1.0 HSIV - 23500 check valve - 17580 This estimate, to the governor valves, is provided for cocparison purposes only.
Thc check valve is assumed to close in 1 scc under revcrsc flow.
4.1 Hain Stoma Code Safety Valves Number of valves (4 pcr Line)
Valve flow capacities - Total, ibm/hr Valve Flow vs SG pressure (psia),
total per bank (4 valves)
, ibm/sec.
8 6621000 1110 1115 1120 1125 1131 1136 1141 1151 1161 1166 1173 1181 1190 1200 1205 1209 1211 0
40 91 141 191 222 223 225 227 228 342 494 646 799 859 920 931 Rated flow (3X accunulation per ASHE,Section III):
1085 psig
~....
~..........
797,700 ibm/hr (each) 1140 psig
~......
~.
~ ~.. ~... 837,600 ibm/hr (each)
COLR l6 Cycle 25, Revision 0
Table 1:
VFSAR Chapter-15 Analysis Setpoints and Input Parameters
{
Item g
Item/Name Value Remarks:
Nurbcr of valves in bank Valve setpoint(s), (first/last three),
- nominaL, ps ig Valve blowdown characteristic 4
1085/1140 15X max isun Valves are Crosby ¹HA-65 6R10 Setpoint tolerance is +1X / -3X.
Model valve setpoint at 1.01 (nominal),
and full flow at 1.04 (nominal).
4.2 Atmospheric relief valves No. Atmospheric relief valves Atmospheric rclicf valve sctpoint/Air-operated, psig Atmospheric relief valve sctpoint/Booster, psig Atmospheric relief valve capacity, ibm/hr 2
1050 1060 313550 at 1060 ps ig During Hot Standby operation sctpoint is lowered to controL no load Tavg Max flow is 380000 5.0 5.1 Turbine Generator (TG)
Condenser No. of condenser dutp valves Condenser dump valve open time, scc Condenser dump valve close time, sec Condenser chmp valve setpoint(s)
Condenser dump valve Cv (flow is f(dP))
For TT: Tavg>555 4 valves,
>563 4 valves; no TT: Tref +12 4 valves, Tref+20 4 valves Assuaing close time "-opening time On TT valves control open at 6.7X/F (PID) above 547 with full open setpoints as described.
On 10X step load decrease same ratio with a 6F deadband from Tref Design Cv (240) from design conditions (302,500 ibm/hr sat steam at 695 psig) 6.0 Chemical and Voluac Control System (CVCS)
CVCS capaci ty/pump CVCS minimumlpump, gixa Type of controller (c.g.,
P + l) and gains 3 pumps, 60 gpm max each 15 PLD 100X,180 sec,10 sec Normal ops:
2 charging pumps - onc is manuaL at 15-20 gpm and the other in automatic.
Charging ixmps are PDPs w/ 46 gpm total - 8 gpm to seals
- 3 gpm leakage
+ 5 gpm into RCS. 40 gpn letdown 6.1 Reactor Makeup Mater System (RMM)
RKM capacity/pwp 2 pumps, 60 gpa each 7.0 Emergency Core Cooling System (ECCS) 7.1 7 1.1 ECCS Delivery vs RCS Pressure Residual Heat Removal (RHR) Delivery vs RCS Pressure COLR 17 Cycle 25, Revision 0
v
~
Table 1:
UFSAR Chapter 15 Analysis Setpoints and Xnput Parameters item g
Xtem/Name Value Remarks:
Hinimm RRR Delivery, train failure Hiniaun RHR Dclivcry, two punps running, one linc blocked RCS Pressure (psia) 155 152 150 140 120 100 80 60 40 20 14.7 RCS Pressure (psia) 155 154 152 150 140 120 100 80 60 40 20 14.7 Delivery (gpm) 0 0
0 250 648 836 985 1115 1232 1338 1365 Dclivcry (gpm) 0 0
160 252 516 830 1056 1243 1406 1552 1686 1720 LOCA Appendix K case.
Train failure results in one pump running with 10K degradation with one line blocked.
LOCA Appendix K case (offsitc power available).
Two pumps running with 10K degradation, with onc line blocked.
7.1.2 Safety Injection (Sl) Dclivcry,vs RCS Pressure Hininxsn Sl dclivcry, 2 pumps operating, one linc spilling Press (psig) 1375 "1300 1200 1100 1000 900 800 700 600 500 400 300 200 100 0
Delivery (gpa) 0.0 62 125 167 201 229 253 273 289 305 321 336 352 368 394 Spill (gpm) 465 465 465 465 465 465 465 465 465 465 465 465 465 465 465 LOCA Appendix K case.
Train failure results in two pumps running with SX degradation with one line spilling to contaiwent.
Hinimm Si delivery, 3 pumps operating, non-LOCA Press (psia) 1390 1315 1215 1115 1015 915 815 715 615 515 415 315 215 115 15 Delivery (gpm)
Loop 'A'oop Igl 16 19 87 97 147 163 193 214 231 257 266 295 297 '29 325 360 352 390 377 418 400 444 423 469 445 493 465 516 485 538 Used for non-LOCA transients, 5X pump degradation COLR 18 Cycle 25, Revision 0
'V
~
lO Table 1:
UFSAR Chapter 15 Analysis Setpoints and Xnput Parameters
(
Xtem g
Xtem/Name Value Remarks:
Kininun Si delivery, 2 pimps operating non-LOCA KaxisxIa SI dclivcry, 3 punps operating, SGTR Press (psia) 1390 1315 1215 1115 1015 915 815 715 615 515 415 315 215 115 15 Press (psig) 1375 1300 1200 1100 1000 900 BOO 700 600 500 400 300 200 100 0
,Delivery Loop
'A'BI 8
69 121 162 197 228 255 281 305 328 350 370 390 409 427 Loop A (gpa) 76 128 180 221 258 290 320 348 374 398 421 443 464 485 504 (gpm)
Loop 8
71 126 169 206 239 269 296 322 346 369 391 412 432 452 Loop B (gpm) 84 141 198 245 285 321 354 385 413 440 466 490 514 536 558 Used for non-LOCA transients, 5X pwp degradation.
The KYPIPE model assuncs no pump degradation.
Loop A and 8 pressures are set equal.
Used for SGTR.
COLR 19 Cycle 25, Revision 0
lN'able 1:
UPSAR Chapter 15 Analysis Setpoints and Xnput Parameters Xtem g Xtem/Name Value Remarks:
7.3 Acct' ate ra Naker of accunulators Total velum, each, ft Liquid votune, ft' min/max Liquid voiune, ft - Best Estimate Initial prcssure, psig - Hininun / Haxlmua Initial tccperature, F
Boron concentration, ppm (min/max) 2 1750 1126/1154 1140 700/790 105 1800/2600 LBLOCA Note -
EQ analyses use a maxinxm concentration of 3000 ppm 7.4 RMST Tecperature, min / max, degrees F
Hinimxn RNST volunc, gal RNST boron concentration, ppm (min/max) 60 / 80 300,000 2000/2600 Note -
EQ analyses use a maximua concentration of 3000 ppm 8.0 Contaireent Initial containment pressure, psia Initial contaireent tenperaturc (LOCA/SLB) degrees F
Initial relative humidity, )l SM tettperature min/max, degrees F
Haximun contaiment
- leakage, wtX/day min - 14.5 max - 15.7 90/120 20 35/80 0.2 Hiniaun is used for LOCA analysis.
Haximun is used for the containment integrity cases (SLB).
LOCA temperature lower for PCT calculations.
SLB higher for containment integrity 81 Contairment Neat Sinks Listing of Passive Neat Sinks, quantities, materials, and configurations see NSSL 8.2 Dcnsitics, Thermal Conductivitics and Neat Capacities of Neat Sinks Insulation density, conductivity, capacity 6.67.ibm/ft 0.0208 BTU/hr F ft 2.0 BTU/ft F
141 ibm/fta to 150 lbm/fta 0.73 to 0.81 BTU/hrFft 0.21 BTU/ibm F note: minimun conductivity corresponds to maximm density, and maxinua conductivity corresponds to minimxn.density.
Stccl density, conductivity, capacity Stainless steel density, conductivity, capacity Containment free volune, min / max, cu. ft.
Ground Temperature (degrees F)
Outside Air Temperature, min / max, dcgrces F
490 ibm/ft 28 to 30 8'IU/hrFft 0.111 BTU/ibm F 496 ibm/ft 15 BTU/hrFft 0.11 B'IU/ibm F 1,000,000 / 1,066,000 55
-10 / 100 below grade tettperature COLR 20 Cycle 25, Revision 0
0 Table 1:
VFSAR Chapter 15 Analysis Setpoints and Input Parameters
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Item g
Item/Name Value Remarks:
HTC for outside surfaces Contairaent fan cooler performance Contairment spray flow, min / max, each, gpm Tcap (dcg F) 120 220 240 260 280 286 Hin Hax (X106BTU/hr) 2.05 4.55 35.1 99.2 40.8 113.8 46.8 129.3 52.9 145.5 54.7 150.4 1300 / 1800 1.65 BTU/hr fta degrees F
8.3 Delays for CRFCs and Spray Pcs CRFC delay, offsite power avaiLable, seconds CRFC delay, offsitc power not available, seconds Contairaent
- Spray, 1300 gpm each
- pump, maxiaaia
- delay, sec Contairmcnt Spray, 1800 gpm each pip, minicua
- delay, sec Containnent Design pressure, psig Distance Basement floor to Springline, feet Distance Springline to top of dome, fcct 34 28.5 - one lxlp 26.8 - two pumps 9 / (14 w LOOP) 60 95 52.5 includes 2.0 sec SI delay includes 2.0 sec Sl delay This delay is from thc time Contairaent Hi-Hi setpoint is reached. It incLudes instrunent delay and spray linc fill time.
This delay is from the time of break.
8.4 Contairmcnt Suap Hinimua wtX of NaOK Tank 30 9.0 Control Systems (Reactor, FM, Przr Level, Turbine, AFN)
Tavg versus power Pressurizer pressure and level algorithms SG secondary Level algorithm N/A N/A N/A Tavg ramps linearly from 547 degrees F at OX power to 573.5 degrees F at 100X power Pressurizer prcssure sctpoint is constant at 2235 psig
~ Pressurizer lcvcl ramps from 19.5 X to 49X for 0 to 100 X power (547 - 573.5 dcgrces F).
Level rasps from 39X at OX power to 52X at 20X power and remains constant at 52X to 100X power.
(Power from turbine 1st stage press.)
10.0 10.1 10.1.1 Safety System Sctpoints Reactor Protection System Power range high neutron flux, high setting nominal accident analysis delay time, sec 1.09 1.18 0.5 10.1.2 Power range high neutron flux, low setting nominal 0.250 COLR 21 Cycle 25, Revision 0
~v Table 1:
UFSAR Chapter 15 Analysis Setpoints and Input Parameters
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Item g
Item/Name Value Remarks:
accident analysis delay time, scc 0.350 0.5 10 1.3 Overtaaperature delta T nominal accident analysis delay time, sec 10.1.4 Overpower delta T nominal accident analysis delay time, sec Variable Variable 6.0 Variable Variable 2.0 Total delay time - from the time the tenperaturc difference in the coolant loops exceeds the trip setpoint until the rods are free to fall Not explicitly modcllcd in safety analysIs 10.1.5 High pressurizer pressure nofninal ~ psig accident analysis, psia delay time, scc 2410 2.0 C
10.1.6 Lou pressurizer prcssure nominal, psig accident analysis, psia delay time, sec 1873 1775 (non-LOCA) 1715 (LOCA) 1905 (SGTR) 2.0 10.1 7 Lou reactor coolant flow nomina l accident analysis delay time, sec 91X of normal indicated flow 87X per loop 1.0 10.1.8 Lou-lou SG level nominal accident analysis delay time, sec 17X of thc narrou range level span OX of narrow range level span 2.0 Mhile trip sctpoint could bc as low as
- 16X, AFW initiation limits to 17X 10.1.9 Turbine Trip (lou fluid oil pressure) nominal, psig accident analysis delay time, scc 45 N/A 2.0 Not explicitly modeled in safety ann lys'Is COLR 22 Cycle 25, Revision 0
Table 1:
UPSAR Chapter 15 Analysis Setpoints and Xnput Parameters
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Xtem g
Xtem/Name Value Remarks:
10 1
10 Undervoltagc
- nominal, V
accident analysis delay time. sec 3150 1.5 Safety analysis assunes RCCAs are released 1.5 scc. after sctpoint is released.
10.1.11 Underfrectuency
- nominal, Hz accident analysis delay time 57.7 57.0 1.2 Analysis is performed but not explicitly modeled in safety analysis.
Safety analysis assunes RCCAs arc released 1.2 sec after sctpoint is reached.
10.1.12 Intermediate range
- nominal, RTP safety analysis, RTP delay time, sec 0.25 H/A N/A Hay fluctuate due to core flux Hot explicitly modclcd in safety analysis 10.1.13 Source Range nominal, cps accident analysis, cps delay time, sec 1.4E+5 1.0E+5 2.0 Highest nominal value 10.1.14 High Prcssurizcr level nominal accident analysis delay time, sec 0.90 0.938 2.0 10.2 10.2.1 10.2.1 1
Enginccrcd Safety Features Actuation System Safety Injection System High contairelent pressure Nominal setpoint, psig Accident Analysis setpoint, psig Delay time, scc 4.0 6.0
- 34 44 u/
- only modeled in accident analysis for start.of contaireent fan coolers.
Time delays arc for start of contaiwent fan coolers.
10.2.1.2
'Lou pressurizer prcssure Nominal setpoint, psig Accident Analysis setpoint, psia Delay time, sec 1750
- 1785, SGTR
- 1730, non-LOCA
'A Table 1:
UFSAR Chapter 15 Analysis Setpoints and Input Parameters
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Item 4
Item/Name Value Remarks:
10.2.1.3 Low steam linc pressure Nominal setpoint, psig Accident Analysis setpoint, psig Delay time, sec 514 372.7 2.0 Sec NS&L See NS&L 10.2.2 Contairwcnt Spray Nominal Setpoint, psig Accident analysis setpoint, psig Delay time, sec 28 32.5 28.5 Sec NS&L Delay tine includes time to fill lines.
See HS&L 10.2.3 AFM System Low-low st~ generator water level Hominal Sctpoint Accident analysis setpoint Delay time, scc 17 X of narrow range instrunent span each stcam generator 0 X of narrow range instruaent span each stcam generator 2.0 A positive 11K error has been included to account for thc SG level measurement system at a containment temperature of 286 F
10.2.4 10.2.4 1
Stems Linc Isolation High contairioent pressure Hominal Setpoint, psig Accident analysis setpoint Delay time 18 N/A N/A Hot explicitly modeled Not explicitly modeled
'10.2.4.2 iiigh steam flow, coincident with low Tavg and SI Nominal Sctpoint Accident analysis sctpoint Delay time 0.4E6 lb/hr equivalent stcam flow at 755 psig and Tavg <<
545 F
N/A H/A Hotc: flow setpoint is below nominal full power flow and therefore this port'ion of logic is made up at power Not explicitly modeled Not explicitly modeled.
Steam line isolation is assuaed concurrent with SI (i.e.
2 s delay + 5 s valve stroke) 10.2.4.3 High-high stcam flow, coincident SI Nominal Setpoint Accident analysis setpoint Delay time
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10.2.5 Feedwater isolation 3.6E6 lb/hr equivalent stcam flow at 755 psig N/A
~
H/A Hot explicitly modeled Hot explicitly modeled.
Steam line isolation is assuaged concurrent with SI'(i.e.
2 s delay + 5 s valve stroke)
COLR 24 Cycle 25, Revision 0
0 Table 1:
UFSAR Chapter 15 Analysis Setpoints and Xnput Parameters
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Item 4
Xtem/Name Value Remarks:
10.2.5.1 High stem generator water Level Nominal Sctpoint Accident analysis setpoint Delay time 67X of thc narrow range Instrunent span each SG 100X of thc narrow range instruaent span each SG 2.0 Instrunent Loop only 11 0 Original Steam Generators OSG secondary outlet prcssure at OX full power, psig Steam teayeraturc at OX full power, F
OSG collapsed liquid lcvcL at OX fuLL power, X
HRS OSG total Liquid mass per SG at OX full power, ibm OSG secondary outlet pressure at 100X full power, psig Steam temperature at 100X full power, F
OSG collapsed liquid level above tube sheet at 100X full power, ft OSG total liquid mass pcr SG at 100X full power, Lbm I
Heat load per SG, Btu/hr Primary flow pcr SG, Lb/hr - Design Stcam flow per SG, Lb/hr - Design Secondary design pressure, psig Secondary design temperature, F
No. of tubes per SG Tube DO, in.
Tube avcragc wall thickness, in.
Haximua moisture carryover, X
Secondary heat transfer area, ft~ per SG Primary heat transfer area, fthm per SG Tube length(s)
Haximua, ft Hinimm, ft Average effective length, ft Overall OSG bundle height, ft Harrow range level tap locations (clcvations),
ft Wide range level tap locations (elevations), ft Secondary nozzle to nozzle dP Q full power, psi 1005 547 39 130,120 815 522.5 38.75 85,410 2602000000 33600000 3290000 1085 556 3260 0.875 0.05 0.25 44,430 39,406 71 ~ 365 57.146 59.5 elevation - 286.549 ft or 33.031 ft above bottom of tube sheet 287.474/299.401 256.349/299.401 16.5 ASD setpoint to control Tavg at 547 F ~
Assumed m to Tavg Hominal value, analysis east Justify asswed error band CIRC run using ncw SG conditions with water lcvcl at 55.5X NRL (38.75'bove tubcshect)
This value is for OX plugging and a fouling factor of.00002.
This value is for ncw SG conditions This is a maximus value, used to generate this mass value below. A minimua value would be 35.5 XNRL.
Value considered steam generator new conditions, with water Level at 55.5X narrow range (38.75'bove tubeshect)
Hinimua wall thickness not specified",
Includes tube sheet (2*22)
Includes tube sheet (2*22)
Above tube sheet Tube shcct thickness is 22 inches Estimate value COLR Cycle 25, Revision 0
{
Table 1
UFSAR C apter 15 Analysis Setpoints and Xnput Parameters Item g
Xtem/Name Value Remarks:
Primary nozzle to nozzle dP with no plugged tubes Secondary volune, ft (water volune Q 1525/0 Kwt) - nominal Secondary volune, ft (steam volune Q 1525/0 Kwt) - nominal Primary total volunc per SG, ft'ot leg head volune per SG, ft'old leg head volune per SG, ft Tube primary volunc per SG, ft Downcomcr level versus downcomer volwe profile Circulation ratio (100X power)
Total volune versus level SG Primary Head Cladding Thickness Kaxinzln SG tube leakage, gpm 32.3 psi 9 flow ~ 33.64E6 lb/hr 1681/2821 2898/1758 942.3 133.4 133.4 675 ~ 5 Sce NSSL 4,4 Sec NSCL 5/16 0.5/SG An Al'HOS model of the OSG's was used.
Thc Circulation ratio is the downcomcr fLow divided by the outlet flow. Confirmed with CLRC run.
ActuaL value limited to 0.1 gpn/SG due to stress concerns COLR 26 Cycle 25, Revision 0
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