ML100470426
| ML100470426 | |
| Person / Time | |
|---|---|
| Site: | Catawba  |
| Issue date: | 02/02/2010 |
| From: | NRC/RGN-II |
| To: | |
| References | |
| Download: ML100470426 (581) | |
Text
Appendix D Scenario Outline Form ES-D-1 2009 NRC EXAMINATION c Facility: Catawba Nuclear Station Scenario No.: 1 Op-Test No.: 2009 D-1 SNAP 141 Examiners: Operators:
- Unit 1 is recovering from a reactor trip 2 days ago
- Conditioned power level is 100%
- EFPD is 25 days
- Boron Concentration is 1929 ppm 8
- Your crew has stabilized the plant in Mode 2 at 1 x 10-8 amps and critical data gathering has been completed
- OP/11A161 OP/1/A16100 00 001 (Controlling Procedure for Unit Startup), Enclosure 4.1, Unit Startup is in progress and has been completed through step 2.166
- Increase power to 1 % per OP/11A161 1% OP/1/A161 001001 00/001 Event Malf. No. Event Event No. Type* Description 1 RO R Increase power to 1%
2 RO I I/R IIR N35 Loss of high voltage failure/re-zero SUR SRO TS 3 BOP C KC pump 1A21A2 trips SRO TS 4 BOP C Loss of offsite power to 1B essential train/1 RN-292B fails to open SRO TS 5 BOP C NC system leak (DCS)
SRO TS 6 RO C Loss of normal feed to S/Gs 11A
/1A CA pump fails to autostart 7 ALL M Steam line break on 1A 1A S/G Additional Failures 1BB-56A fails to auto close 1A ND pump fails to autostart
- (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
SIMULATOR SETUP Reset to 10-8 amps BOL snap Roll Charts Clear EHC alarm and any OACI 1.47 bypass alarms Sign off OP/1 OP/1/A/61 IA/61 00/001 001001 enclosure 4.1 thru step 2.166 (students start at 2.167)
MALFUNCTIONS, REMOTES, and OVERRIDES Malfunction # Description Value Event Ramp Delay Trigger ANN-AD11-B03 TRANSFORMER A TROUBLE ON ANN-AD11-E03 TRANSFORMER B TROUBLE ON MAL-DG007B DIG 1B OUTPUT BREAKER OPEN FAILURE VLV-RN033A RN292B DSL GEN B HTX INLET ISOL VLV FAIL AUTO ACTIONS OVR-KC003D PMPA2 OFF PB ON 4 OVR-FWP019C CFPT 1A MOP 1A2 AUTO PB OFF VLV-SG007A BB56A S/G 1A BLDN CONT ISOL INSIDE FAIL AUTO ACTIONS MAL-ND001A ND PUMP A FAILURE AUTO MAL-CA004A FAILURE OF CA PUMP A TO AUTO START MAL-ENB009A I/R CH 35 HI VOL LOSS OF IIR VOLT T 2 OVR-EP051D ETB NORM FDR FRM ATD ON 4 TRIP PB MAL-NC013B NC COLD LEG BLEAK 0.22 5 OVR-FWP018C CFPT 1A MOP 1A1 AUTO PB OFF 6 MAL-SM008A STM LINE BRK OUTSIDE 4.125E6 7 CONTAINMENT LOOP A LOA-NV078 SEAL WATER LOW FLOW LCL ACKN 21 180 REFLASH ACK (AD7,C4)
LOA-CA015 CA66B - CA PMP #1 DISCH TO 0 22 120 300 S/G A ISOL VL V
EVENT TRIGGERS (other than manual)
Event Trigger Ii Description NONE CRITICAL TASKS (See attached documentation)
E-O H - Manually start at least one low-head ECCS pump before transition out of E-O.
E-2 A - Isolate the faulted S/G before transition out of E-2.
QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1-2 2 Abnormal events 2-4 5 Major transients 1-2 1 EOPs entered/requiring substantive actions 1-2 2 EOP contingencies requiring substantive actions 0-2 0 Critical tasks 2-3 2 REFERENCES OP/1/N6100/001 OP/1/A/6100/001 (Controlling Procedure for Unit Startup), Enclosure 4.1 revision 217DCS AP/1/N5500/016 (Malfunction of Nuclear Instrumentation System) revision 024DCS AP/1/A/5500/016 AP/1/N5500/021 (Loss of Component Cooling) revision 036DCS AP/1/A/5500/021 AP/1/N5500/007 AP/1/A/5500/007 (Loss of Normal Power) revision 057 AP/1/N5500/010 AP/1 /A/55 00/0 10 (Reactor Coolant Leak) revision 051 DCS AP/1/A/5500/006 AP/1/N5500/006 (Loss of S/G Feedwater) revision 039 EP/1/N5000/E-0 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection) revision 036 EP/1/N5000/E-2 (Faulted Steam Generator Isolation) revision 012 EP/1/A/5000/E-2 EP/1/N5000/ES-1.1 (Safety Injection Termination) revision 025 EP/1/A/5000/ES-1.1 OTHER NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES. The NRC lead examiner will direct timing of events unless otherwise noted.
NOTE: Any groups or individuals (IAE, Rx Grp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the information they provide unless otherwise noted.
NOTE: Any operators dispatched should repeat back information provided. Call back items are listed below when necessary for the scenario.
Event 1 - Increase power to 1%
This event will be entered once the crew has taken turnover and evaluated plant conditions.
Anytime after a stable positive startup rate is achieved, the next event can be started.
Event 2 -I/R
- I/R N35 Loss of high voltage failure, SRO Technical Specification Initiating Cue: 1AO-2, C/1, N35 failed to bottom of scale AP/1/A155001016 is completed, and the SRO has completed consulting Technical When AP/1/A/55001016 Specifications, the next event can be inserted TS - 3.3.1 Item 4 Condition F Event 3 - KC pump 1A2 trips. trips, SRO Technical Specification Initiating Cues:
- 1AO-6, C/1 - C/4, 0/1 - 0/4, E/1 - E/4 and others AP/1/A155001021 is completed and the SRO has completed consulting Technical When AP/1/A/55001021 Specifications, the next event can be inserted.
If an operator is dispatched to checkout 1A2 KC pump and breaker, after a few minutes state "nothing abnormal was noted".
TS - 3.7.7 Condition A Event 4 - Loss of offs ite power to 1B essential train/1 offsite trai nl 1RN-292B fails to open.
open, S RO SRO Technical Specification Initiating Cue: Multiple electrical alarms on 1AO-11, UV status lights for 1ETB on 1SI-14 When operator is dispatched to manually open 1RN-292B, after 3 minutes call back and state "1RN-292B cannot be opened".
When called by the crew to open 1 EOF-F01 F and load shed 1ETB, RUN SCHEDULE Load_Shed_1 ETB.sch (under Operations folder).
Load_Shed_1ETB.sch Call back when schedule is complete and state: "1 B DIG Load sequencer has been de-energized and 1ETB1ETB has been load shed per Enclosure 9. No lockout relay targets are picked up."
AP/1/A155001007 case 2 is completed and the SRO has completed consulting When step 22 of AP/1/A/55001007 Technical Specifications, the next event can be inserted.
TS - 3.8.1 Conditions A, B, 0, F 3.8.9 Condition A 3.7.8 Condition A
Event 5 S - NC system leak. SRO Technical Specification Initiating Cue: 1AD-13, 1AO-13, AI?,
Al7, F/5 AP/11A15500101 0 is completed and the SRO has completed consulting Technical When step 11 of AP/1/A15500/01 Specifications, the next event can be inserted.
If annunciator for seal water low flow comes in and directed by the crew, insert EVENT 21.
Call back when alarm is cleared and state "Seal water low flow has been locally acknowledged. "
TS - 3.4.13 Condition A, 3.6.4 Condition A, SLC 16.? -9 Condition A 16.7-9 Event 6 - Loss of normal feed to S/Gs/1A CA pump fails to autostart 1AO-1 Al6 and 1AD-5 Initiating cue: 1AD-1 1AO-5 Al1, Al4 AP/11A155001006 is completed, the next event can be inserted. This will begin the major When AP/1/A15500/006 event.
TS - TS 3.3.2 Item 6a, Condition H Event 7 - Steam line break on 1 A SIG 1A S/G Initiating cue: 1AD-3, 1AO-3, Al1 This is the major event.
Additional failures
- 188-56A BB-56A fails to auto close
- 1A ND NO pump fails to autostart In E-2 Step ?c.3) 7.c.3) RNO, when dispatched to close 1CA-668, 1CA-66B, insert EVENT 22.
Call back when 1CA*66B 1CA-668 is closed and state "1CA*66B "1CA-668 is closed."
In E-2, Step1 O.c if asked to sample S/Gs for activity state "I will sample Unit 1 SIGs Step10.c S/Gs for activity and report the results back in about an hour."
In E-2, Step 10.c if asked to frisk cation columns for activity state "I will frisk Unit 1 cation columns for activity and report back the results in a few minutes.
Call back in 5 S minutes and state "Unit 1 cation columns indicate no abnormal activity."
Scenario End Point AFTER NV 5/1 S/I FLOWPATH IS ISOLATED PER STEP 9 of EP/1/5000/ES*1.1.
EP/1/S000/ES-1.1.
CREW INFORMATION
- Unit 1 is recovering from a reactor trip 2 days ago
- Conditioned power level is 100%
- EFPD is 25 days
- Boron Concentration is 1929 ppm
- Your crew has stabilized the plant in Mode 2 at 1 x 10-88 amps and critical data gathering has been completed
- OP/1/A/61 OP/1 IA/61 00 001 (Controlling Procedure for Unit Startup), Enclosure 4.1, Unit Startup is in progress and has been completed com pleted through step 2.166
- Increase power to 1 1% OP/1 IA/61 001001
% per OP/1/A/61
I I
I I
Duke Energy Procedure No.
Catawba Nuclear Station OP/l;A/6100/001 OP/l!A/6 100/00 1 Revision No.
Controlling Procedure For Unit Startup 217 Des Electronic Reference No.
Continuous Use CN005FK3 CNOO5FK3
OP/l!A/61 OP/I/A/61001001 00/00 1 Page 2 of7 Controlling Procedure For Unit Startup
- 1. Purpose 1.1 To outline the steps necessary to take the plant from cold shutdown to 15% full power.
1.2 To provide a procedure for startup from any shutdown condition.
- 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration, temperature, steam flow, and power level. (R.M.)
2.2 The following Limits and Precautions are Reactivity Management related: (R.M.)
2.2.1 A stable startup rate of 0.5 dpm is administratively recommended. Do NOT exceed a stable startup rate of 1 dpm. When approaching the POAH, a startup rate of < 0.2 dpm is recommended; this rate shall NOT be exceeded until the turbine is placed on line.
2.2.2 Overlap between the source and intermediate ranges and between intermediate and the power ranges shall NOT be less than 1 decade.
2.2.3 During Modes 1 & 2 and prior to diluting for ECB, the PZR boron concentration shall be within +/- 50 ppm ofthe of the NC System boron concentration. During Modes 3, 4,5,6, or No Mode, PZR boron concentration is NOT required to be maintained relative to the NC System provided the following conditions are met:
- PZR outflow can be verified
- NC System boron concentration> 100 ppm over the required SDM 2.2.4 With the reactor critical at low power, steam withdrawal from the S/Gs may be used only for auxiliary uses (i.e., warm steam lines, operate air ejectors, supply gland steam, some turbine warming) or for controlling heatup rate via the steam dumping system. Use caution to ensure the steam drain is slow.
2.2.5 Ensure reactivity management guidance outlined in SOMP 01-02 (Reactivity Management) is followed during reactor startup and power operation.
OP/l/A/61 00/0011 OP/l!A/61 00/00 Page 3 of7 2.2.6 The Shutdown Margin MonitorlBoron Dilution Mitigation System shall be monitored during heatup and/or when reactivity changes cause the count rate to increase. Failure to reset the "ALARM SETPOINT" prior to the count rate exceeding this setpoint will result in a system activation causing borated water from the FWST to be injected into the NC System.
2.2.7 During any planned boron dilution operations in Mode 3, all shutdown banks shall be fully withdrawn. After refueling, the startup will be controlled by PT/OIA/4150/001 (Controlling Procedure for Startup Physics procedures PT/0/A/4150/001 PT/O/A/4150/00lJ (Zero Power Physics Testing).
Testing) and PT/0/A/4150/00lJ 2.2.8 When changing reactor power, refer to Unit One R.O.D Section 2.4 (Fuel Maneuvering Limits) for allowable rate changes.
2.2.9 During a power increase, other indications of reactor power shall be observed along with power range and secondary thermal power indications to aid in determining the reactor power level. Using indications like turbine impulse pressure, CF flow rate, NC loop ~Ts,
~Ts, and others may help in detecting the miscalibration of a nuclear instrument.
2.2.10 Control rods shall NOT exceed rod withdrawal limits. Prior to changes in boron concentration, reactor power, or control rod position, refer to Unit One R.O.D Section 2.3 (Temporary Rod Withdrawal Limits).
2.2.11 Two positive reactivity additions shall NOT be made simultaneously per NSD 304 (Reactivity Management). {PIP 96-0S86}
96-0586}
2.3 NC System heatup rate of 50°F in anyone hour period is the heatup rate limit for normal operation. Under abnormal or emergency conditions, the Tech Spec NC System heatup limit of 60°F in anyone hour period shall NOT be exceeded.
2.4 It is recommended that the Heatup rate of the PZR NOT exceed 80°F in anyone hour period. SLC 16.5-4 heatup limit of 100°F in anyone hour period shall NOT be exceeded.
2.5 During heatup in Mode 3 it is recommended that the ~T between the PZR and the NC loops be maintained approximately 100°F to provide adequate subcooling sub cooling while minimizing PZR and spray fluid ~T.
OP/l!Al6 I 00100 I OPIl!A/61001001 Page 4 of7 2.6 Ifthe temperature difference between the PZR and the spray fluid is greater than 260 oo P, it is recommended that spray NOT be initiated. A ~T ~T of of320oP 320 0 P shall NOT be exceeded.
The following control room indications may be used to determine the ~T ~T between the PZR steam space and the PZR spray fluid:
- OAC OACCIP1361 (PZR STM TEMP - PZR SPRAY B TEMP DIT)
C1P1361 (PZRSTMTEMP-PZRSPRAYBTEMPDIT)
OAC CIP1362
OAC CIP1363
OAC CIP1364
- INCP5380 (Pressurizer Vapor TEMP) (lMCI0) 1NCP5380 (lMC10)
- 1NCP5390 INCP5390 (PRESS Spray Line Temp Loop A) (lMCI0) (lMClO)
- 1NCP5400 INCP5400 (pRESS (PRESS Spray Line Temp Loop B) (lMCIO)(lMClO)
- INVP5100 (Regen HX Chrg TEMP) (lMC5) 1NVP5100
- INDCR5070 (ND HX 1B 1NDCR5070 IB Inlet &
& Outlet TEMP) (lMC7)
- INDCR5060 (ND HX 1A 1NDCR5060 lA Inlet &
& Outlet TEMP) (lMC7) 2.7 Observe the limitations ofTS Table 3.4.12-1 (Reactor Coolant Pump Operating Restrictions Por Low Temperature Overpressure Protection) for NC pump operation during LTOP conditions.
2.8 It is recommended that the NC System temperature NOT exceed 160 00 P until at least one NC pump is in service during solid operation of ofthe the NC System.
2.9 Whenever there is a thermal power change greater than or equal to 15% rated thermal power within a one hour period (OAC point CIP2375C1P2375 (Max Thermal Power Change in Last 60 Min>>:
Min)):
- NotifY Chemistry to take an isotopic analysis for iodine within 2 to 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> following the last power change that is greater than or equal to 15% rated thermal power within a one hour period. (TS SR 3.4.16.2)
- When thermal power has stabilized, notifY Radiation Protection to sample and (S.L.c. 16.11-6) analyze gaseous effluents. (SLC.
2.10 2.1 0 This procedure may be entered and exited at various points. To avoid possible omission of valid steps, all procedure steps shall be signed off or indicated as NOT applicable.
2.11 When manually operating any motor operated valve, minimize the torque applied to the handwheel.
2.12 After manual operation, maintenance or packing adjustment of any motor operated safety related valve, it shall be cycled electrically to ensure reliable automatic operation.
OP/l/A/6100/001 OP/lJA/61 00/00 1 Page 5 of7 2.13 It is recommended that S/G reverse purge flow be maintained at all times when the S/Gs are pressurized and CF flow is NOT aligned to the main feedwater nozzles. This ensures the main feed containment penetration piping is maintained above brittle fracture temperature of 107°F.
- IfIfthe the temperature on both sides ofthe penetration is greater than 107°F during Mode 1, I, reverse purge flow can be secured, but reverse purge shall be re-established before temperature reaches 107°F (decreasing) to ensure compliance with the commitment to the NRC on 10CFR50 Appendix A GDC51 (temperature greater than 107°F during power operation-Mode 1). I). The temperature between the feedwater isolation valves and S/Gs shall be greater than 107°F during Mode 1. (CIAOI41, CIAOI48, CIA0125, C1A0148, CIAOI25, CIA0154, CIAOI54, CIA0275, CIA0160, CIAOI60, CIA0815, C1A0815, CIAOI66, CIA0166, OAC Group Display GD OPCFTEMP)
- During Modes 2, 3 and 4 reverse purge can be secured to aid in plant heatup. It is desirable to have reverse purge at all times during plant heatup to prevent a possible delay in entering Mode 1.
2.14 When feeding the S/Gs from a source other than main feedwater, notify the Secondary Chemist of this and specify the feed source so accurate chemistry data may be obtained.
ofthis 2.15 If the RC System condenser inlet temperature drops to less than or equal to 60°F when Ifthe the reactor is shutdown or less than or equal to 55°F when the reactor is critical, the RC System shall be aligned as follows:
- One RC pump running (throttled).
- One tower inlet isolated.
- All three riser bypasses open.
2.16 Maintain an outflow on the PZR to minimize PZR thermal stratification. PZR outflow may be confirmed by the following:
- Extra heater capacity energized.
- NC, NV or ND PZR spray indicated by valve positive demand.
- PZR surge line temperature and PZR water space temperatures are approximately equal.
- PZR spray valve for idle NC Pumps closed.
2.17 If situations occur causing PZR liquid space temperature to decrease due to PZR level increase, then the PZR level shall be maintained at the elevated level until PZR liquid space temperature recovers. PZR liquid space temperature is directly affected by PZR level during plant conditions requiring a saturated PZR and cooler NC loop temperatures.
tern peratures.
OP/l!A/6100/001 OP;1/A/61001001 Page 6 of7 2.18 It is recommended that the NC System and PZR heatup be as linear as possible. Do NOT do a step heatup of 25° in 10 minutes, then wait 50 minutes before increasing temperature again.
2.19 Ifthe If the temperature differential between the PZR and NC loops exceeds lOO°F, minimize the cycling ofPZR spray or otherwise induced surge line flow.
2.20 To reduce CRDM misstepping due to crud buildup, limit RCCA movement until after all NC Pumps have been started and NC System suspended solids are less than 350 ppb.
Maximizing NV letdown prior to Mode 4 (or as soon as possible thereafter) will help clean up the NC System which will reduce stationary gripper delay times. {PIP 98-1200, 99-2054}
2.21 Stroking CF Containment Isolation Valves (CF-33, CF-42, CF-51, CF-60) during heatup may cause them to stick in the closed position during nozzle transfers. To prevent this, it is recommended that these valves NOT be cycled unless final feedwater temperature>
250°F and pressure> 1000 psig.
2.22 In accordance with INPO best practices when personnel are accessing areas that could experience significant dose rate changes resulting from increasing power, it is recommended that Operations maintain Reactor Power steady or decreasing.
- 3. Procedure Refer to Section 4 (Enclosures).
OP/l!A/61 00/0011 OP/I/A/61 00/00 Page 70f7
- 4. Enclosures 4.1 Unit Startup 4.2 Operations Pre-Heatup Checklist 4.3 Support Pre-Heatup Checklist 4.4 Operations Mode 4 Checklist 4.5 Support Mode 4 Checklist 4.6 Operations Mode 3 Checklist 4.7 Support Mode 3 Checklist 4.8 Operations Mode 1 & & 2 Checklist 4.9 Support Mode 1 & & 2 Checklist 4.10 1000 psig Critical Valve Checklist 4.11 Normal Temperature And Pressure Critical Valve Checklist 4.12 Secondary Heatup Checklist 4.13 PZR Spray Bypass Valve Setup
LL PREVIOUS STEPS WILL BE ALL SIGNED OFF AND ARE NOT Enclosure 4.1 OP/l/A/61 OP/l!Al6100/001 00/00 1 INCLUDED HERE.
Unit Startup Page 50 of66 2.166 Ensure Steps 2.137 - 2.139 have been completed to ensure automatic steam dump control has been established.
mP1fti NOTE: Control
- 1. ,(I}
1&$ ... rodmiWgrg_ftilm'l.m'Qlt¢!til:.tl1:~l~iQ,Qf~~~~~i#1Qt~tflfcijprits'$j;!~Ji.
withdrawal shall NOT.exceed the temporaryrQd withdrawaLlimits specified g.~.Jllim~~~t~),iQ~
in UnitOne.R.O.D.Section 2.3.
2; Refer to Unit One R,O.D; Section 2.4 for the rate at which rei;lctor power can be changed.
The throttling ofaS/G bypass reg valve affe~ts the othe(;S/G:bypass reg valves;
- 3. .~'_}1;I.g,\.fa\'~~*"~_m:.'\it!4~~tft.j~~1~JPi}.SS:r~~I~;.
I:'
- .#e.~£t.~F~{*i~lt
- .I~.frijf@~fl~*.Jn(~I~_~l1e!i'~Q.~
'Fherefore,SM/CF M> needs tobetnonitored 'Cis the ubit approaches POAR.
- ms~l~4tJ:tf~~il.i~y._te:r.@**~O~'it1liJiiB~IP~~JF~trQIt~~;:te*.v_;
- 4. IfNC boron concentration is greaterthan 1OOQ ppmB,J-AVG control may be very
,s~~~<.Si-1A>;¥i~\].l;frAi¥lfiifMli'a;;ry()'Sitiv~:J\~f;R>>;~$<tfj;\\f~.il;~it;(~h,D,iiQYT1:'\**
sensitive a1;)ove the POAR due,toa positive MTC. Refer to.Vnit One R.O.D.
- . *~,M',&X:~;N'lM0J#~\~~,*;~;/im~,~~~..5?v:- ;~i.Pl."',,"~' -. **.~,~~y+~t"d~"*,:;~~~J.,~~y<~~, :~. "'7~~ .,,' ~;,~
tf~Il[9I{._t:(tlt~~1;'ti.w&l1i,c~mtm:l!s*~
Section 5.10 for the MTC at the current conditions.
- BJ~
5.. When * *e."w~I>~.~*raf~lf!l.Q_.$_Q~~~~1f,i~*,~$
,apprqaching the POAR, ;l;l,startuP rate of < 0.2 dpm is recommended; it is 4A~~~iiq:f$k;i'i<:*UHJ¥;",'i£~j:Al'am;k' ** .....i&,,****A'lic'iil: ')t\"i!i'liN'imT_~'WJ:i1" recomrhend¢d that this rate NOT be exceeded.._~~~~,~,!1_fl~:f<;
if;"l;~R~~Yi~J~.\;5~~W",,~~~-*blx:,?~~~e,*~, until the turbine is placed'!ttl" A&<';I'th.mll;;";",; " *JtCfR\i1\'JfiD'.
online. (SOMP
. ~""~i;~~!WY~:"~2l;r~:'
,Q:IiRfl * *il 01-02), (R.M.)
--:---::------:-----~-->----:-.------,
- - 2.167 Increase reactor power to 1%. (KM;) I pull rods to have a positive stable S/U rat 2.168 Begin reviewing the items listed in Step 2.176 so that Unit 1 will NOT enter Mode 1 until all substeps of2.176 are signed off.
- - 2.169 IF necessary, continue heatup to no load I-AVG T-AVG (557°P). (557°F).
- - 2.170 Increase S/G blowdown flowrate as recommended by Secondary Chemistry for S/G chemistry control and within guidelines of OP/1/A/625 OP/lIA/625 0/008 (Steam Generator Blowdown).
(R.M.)
recommendation'--_ _
Person making recommendation'--_ __ __ _ __ __ __ ___
2.171 Coordinate with Chemistry to determine when blowdown flowrate can be subsequently reduced.
Initiating Iinitiatin g Cue: 1AD-2, C/1, N35 failed to bottom of scale 1AD-2, I
I
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO.
AP/1/A/55001016 1 of 14 DC~
Rev 24 DCt A. Purpose
- To verify the proper response in the event of a nuclear instrumentation malfunction.
B. Symptoms Case I. Source Range Malfunction
- Indication lost or erratic
Case II. Audio Count Rate Malfunction
- Audible count rate lost.
Case III. Intermediate Range Malfunction
- Indication lost or erratic
- 1AD-2, C/1 "I/R HI VOLTAGE FAILURE" - LIT
- 1AD-2, C/2 "I/R COMPENSATING VOLTAGE FAILURE" - LIT
- 1AD-2, C/3 "I/R HI FLUX LEVEL ROD STOP" - LIT
- SIR failure to re-energize during shutdown.
Case IV. Power Range Malfunction
- Indication lost or erratic
- A11 "P/R HI NEUTRON FLUX RATE ALERT" - LIT 1AD-2, A/1
- A13 "P/R HI NEUTRON FLUX HI SETPOINT ALERT" - LIT 1AD-2, A/3
- 1AD-2, 8/3 "COMPARATOR P/R CHANNEL DEVIATION" - LIT
- 1AD-2, 8/5 "P/R HI VOLTAGE FAILURE" - LIT
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO.
AP/1/A/5500/016 AP/1/Al5500/016 8 of 14 Case III Rev 24 DCl:
DC::
Intermediate Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c.
C. Operator Actions
_ 1. Verify: reactor power,;. GREATER THAN _ Stop any power increase.
IRO ! 10%.
'Will
.Will insert rods to achieve a SUR of 0 ---
_ 2. Verify 1AD;'2, C/3 "I/R HI FLUX LEVEL _ Adjust turbine load to maintain T -Avg at ROD STOP" -DARK. T-Ref.
j r
- 3. Identify affected IIR channel:
o Il-
- N-35 OR
- N-36.
NOTE 1AD-2, G/4 "Nil SYS SIR & I/R TRIP BYPASS"wilfactllatein thefollowing step, u()"",P!
IrRll r I j
- 4. At the affectedllR Qrawer, perform the fol/owing:
_ a. Place:the"LEVEL TRIP" switch for affected channeUr,"SYPASS".
_ b. Verify !he "L,E;VI;LTHIP BYPASS" light, on the affectetlllR drawer -,LIT.
IIBOP I
- 5. Verify the affected IIRchanrfel trip bypass status light (1S1-19)- LIT.
IIBOP I
- 6. Verify 1AJi)-2, Cf4 "~IISYS SIR &lfR TRIP BYPASS"- LIT.
Ensure t,he "NIS RECORDER" - ALIGNED TO THE'OPERABLE IfRCHANNEl;:~
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO.
AP/1/A155001016 9 of 14 Case III Rev 24 DC~
Intermediate Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. WHENtheQR~r~pl~*
WHEN the operable Jl~~b~Qn~l'i~le$s IIR channel is less
~~~l tbaii10:-
than 10-1 10O****Attips,THEN~nsu Amps; THEN ensure ..eSl~
SIR chaiinelsa"e.tesim channels are reset.
- 9. DetermineaiidCQtteClcausepfl/R Determine and correct cauSe of I/R malfunction.
10.
1O. 1:i:J$urecQtnRIJ~nceW!tbl1~~b§Pe~~$~~1 EnSure compliance with Tech spec'3.3.1 4 Condition F (Rea~tQrnip§Y~lem(Rl1§>
(Reactor Trip System (RTs)
InsttumetltaUq:n)
Instrumentation)..
- 11. Determine required notifications:
REFER TO RP/OIAl50001001
- REFERTORP/O/At5QQQ/QQ1 INone (Qla$sifieElfiqrtQf.*EfTlerg~R¢Y)
(Classification*Of Emergency)
REFERTO\~PI01B/5QQQ/Q13(~RC
- REFER TO RP/O/B/50001013 (NRC NqtificationR~quireme.ntsJ, Notification ReqUirements).
- 12. NqtifyReactpt§:tQUP'.l:n9iiiegtof Notify Reactor Group Engineetof occurrence.
CAUTION Installing fiR fus~s with any P/R channel inoperable,or in.atripped l.ii$t~II. ing.i"~fu$~$Wit"'anYRJ~Ichant:\~I****.*inQPetal).I:~:QriQ:a?Jripp~d
~Qnd.itiQi:J;*;iP~ytl.~$ultil'ii'.a*
conditioni:rnayresult ina ....reactor tripon P/R rate trip* . d*ye*!tq*volta9~
eactorttipibn:*RlRirateittip due to voltage sRike$'~
spikes.
- 13. WHEN.
WHEN theaffectedllRchaniiel/is the affectedl/R channel is r~paireqi:THI:N~n$*uF~'~l:t~tqrn$*tb~
repaired,THEN en$l,Ire rAE returns the cbannel.*tP$erVi~~i channel to service' 14 .t;)~teFiPi
- 14. Determine l'ie IQI'i9/Jetmplai:Jt$!atqs, long term<plant status, REml!JRN.m0****.*PFQq~qqt~*.iii**~ff~~t.
RETURN TO procedure in effect.
END
Initiating Cues:
- 1AO-6, C/1 - C/4, 0/1 - 0/4, E/1 - E/4 and others
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/11A155001021 AP/1/A/5500/021 1 of 39 Rev 36 DC~
A. Purpose
- To verify proper response in the event of a loss 1055 of Component Cooling.
B. Symptoms
- 1AD-10, Al1 "KC SURGE TANK A LO-LO LEVEL" - LIT
- 1AD-10, Al2 "KC SURGE TANK B LO-LO LEVEL" - LIT
- 1AD-9, F/5 "KC TRAIN A SINGLE PUMP RUNOUT" - LIT
- 1AD-9, FIG "KC TRAIN B SINGLE PUMP RUNOUT" - LIT
- 1AD-9, F/7 "KC TRAIN A TWO PUMP RUNOUT" - LIT
- FIB "KC TRAIN B TWO PUMP RUNOUT" - LIT 1AD-9, F/8
- Abnormal KC discharge pressure and flow indications
- Low flow alarms on components supplied by KC System
- High temperature alarms on components supplied by KC System.
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP 111Al55001021 AP/1/A/5500/021 2 of 39 DC~
Rev 36 DC:::
ACTIONIEXPECTED RESPONSE ACTION/EXPECTED RESPONSE NOT OBTAINED C. Operator Actions OP DOES THIS PROCEDURE CAUTION CAumlON FaUute to restore.NC pump seaJ.cooling via thermal ~arriercooling or *.NV 17q'lq~@tQrel;tQr@'J""C.*.PIJ*Il1.p'$'@~I;~QQlingj~i~thert)1~.1'J:>a,tri~rC()QI.i.ng()r l;e~lii1jgpti()n\IVitl)itJ seal injection within 10'l1i nut@§\IV'Uip~u§@'.~~m~get()tl)e*'
10 minute.s will cause damage tothe ""C** NC *pump*
pump $eall; seals r~sumi1gli1*.
resulting in NC*inV@\1.tory**.los$.
NC inventory loss,
- 1. Monitor Enclo~ure 1 (Foldout Page).
- 2. Verify at least one KCpump
- ON. P~rformtl)~followii1g:
Perform the following:
- a. StartEit~.ast$m$'*~C'pumJ).
a; Start at least one KC pump.
- b. IF no KC pump can be started, THEN mHEN perform the following:
_ 1) IF SII S/I has actuated on either unit, mHEN GO mo THEN TO Step 4.
CAumlON CAUTION YO can only supply one Unit's NV pump at a time.
_ 2) Determine which unit will receive alternate NV pump cooling from YD.
_ 3) IF Unit 2 selected to receive YO cooling to 2A NV pump, mHEN THEN GO TO Step 4.
mo (RNO continued on next page)
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/11A155001021 AP/1/Al5500/021 30f39 DC::
Rev 36 DCE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. (Continued)
- NV pumps may be started without regard to cooling water alignment.
- Operating NV Pump will reach high temperature conditions in approximately 15 minutes with no cooling water.
_ 4) Dispatch operator to align YD cooling to NV pump 1A. REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A).
_ 5) Maximize NV pump run time.
REFER TO Enclosure 7 (Maximize NV Pump Run Time).
_ 6) IF AT ANY TIME an SII occurs on either unit, THEN notify dispatched operator to realign NV Pump 1A cooling to normal. REFER TO Enclosure 4 (Alternate Cooling To NV Pump 1A).
_ 7) GO TO Step 4.
- 3. .IF .AT ANY.TIMEaU::~CJJlJmps are>lost, THEN RETURN TO;STI;P2.
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/11 AP Al55001021 111A155001021 4 of 39 DC~
Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED NomE Uhcooled letdown may result in loss of NV pumpswithin a matter of minutes.
- 4. Verify th~folloWing: IF KC flow unavailable to letdown HX, mHEN THEN isolate letdown as follows:
- **1ADl.~I::I7"/S 1AD~7,F/3nLETDN..*"I.:.E;T1T(liJNFI)<!;.QIlI"'
HXOUTLET I.:.C;T1T.***HI HI mEMR~;.(~
- Dh\RK; TEMP"., DARK a. Ensure the following valves - CLOSED:
1!ND
- 1NV-10A (Letdn Orif 1B Otlt Cant Isol)
_
- At Jeasto.heKC PLJmp - ON.
- 1NV-11A (Letdn Orif 1C 1C Otlt Cant Isol)
- 1NV-13A (Letdn Orif 1A Otlt Cant Isol).
- b. Control charging to stabilize Pzr level at program level while maintaining seal injection flow.
- d. Ensure 1NV-172A (3-Way Divert To VCT-RHT) - ALIGNED TO RHT.
- e. Ensure VCT makeup - IN AUTOMATIC
- f. WHEN time and manpower permit, mHEN THEN REFER 7170 TO AP/1/A155001012 (Loss Of Charging Or Letdown).
- g. IF 1!m AT 1!NY ANY miME TIME the following conditions exist:
- VCT level - LESS THAN 23%
- PZR level - GREATER THAN 85%
AND INCREASING.
_ mHEN THEN GO 7170 TO Enclosure 8 (Rx Trip Sequence).
- h. GO 7170 TO Step 6.
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A155001021 AP/1/A/5500/021 5 of 39 Rev 36 OCt DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 5.IFATANYTIIVI1Z1AD~?',I2/~:~LETl:)fSI!:'IX
- 5. IF AT ANYTIME 1AD-7, F/3 "LETDN HX Ql1J;r~a:rl:il*nEMe'~}LI'F,iTBEN***perf()rijJ OUTLET HI TEMP" LIT, THEN perform st~p~aNQ.~.*
StE~p4RNO.
- 6. ,yerify both KC surge *.tank M~tifY~otI1K~::I§]Jtg~ ~I"I.kl~¥~I$.,.5Q9fci:"
levels .;. 50% - _ GO TO Step 8.
~O% AND STABLE.
9Qo/ciANDSTABllIE,;;
7 .S.t~"~QQlitiQ'ijal*'KCi;f,pl.lijJp($)~$
- 7. Start ad<:liti()OaIXqpump(s) as _ IF KC pump(s) damaged by fire, THEN ti~c~ss~Wii,tQi§p,ppl~~pYI:Kelo~cJs necessaty:tosupply any KC loads notify notifY IAE to repair cables to pumps pt~s~nt!*~):tI"lIi$~tvj~~f presently in,serVicei needed for recovery. REFER TO IP/1/A138901027 A (Fire Damage Control IP/11A13890/027 Procedure).
CAUTION CAUTICIN A loss ()f KC cooling to the NC pumps results
- in AiIQ$$:i:Qfl::K~t;Q'QUtigito*tlle*.*N~.**.*.pl~ijJps.*.t~§ylt$ i.n . . agt~g"~lappt()fJt;!1to.***.an agradUClJapproachto an OV.~...li~iit~.g?.G()gcJitiorril"l*
overheated condition in .* (lppr()~i.rnat~l.yi1QijJinl.lt~~~Iilc!1,.vvIII.*
approximately 10 minutes whichwillresuJtin *.:.resl.l't*in sllaft.s~iziJt~;
shaft seizure;
- 8. Verify KC flow to NC pumps as follows: Perform the tile following:
1AD-20,A/1 "Ke SUPPLY HDR FL(!)W
- .1A[,)+/-2():;:AtlI1K~:::~lJJ~m*ij!'(.*.*I].L)~:I* FLOW a. Ensure the following valves - OPEN:
TaiNCP**8RG$E<DWl':'~.**[')ARK TO NCP BRGS LOW" -DARK
- 1KC-425A (NC Pumps Ret Hdr Cant
- .~IA[,)~21 N1 "KC SUPPLY HDR FLOW
,1AO-21...At1?"KC$WPPL!,('I][')RIPE(!)W 1501)
.\T"<DN*CP6RGSl:'OW"**-[')ARK:
irdNCP BRGS LOW" - DARK.
- 1KC-3388 KC-338B (NC Pumps Sup Hdr Cant 1501)
- 1KC-424B (NC Pumps Ret Hdr Cant 1501).
(RNO continued on next page)
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A/55001021 AP/1/A/5500/021 6 of 39 60f39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. (Continued)
- b. IF AT ANY TIME any of the following conditions are met:
- Time since loss of KC - GREATER THAN 10 MINUTES OR
_ .* Any NC pump trip criteria from Enclosure 1 (Foldout Page) is met THEN perform the following:
- 1) IF letdown is isolated, THEN:
a) Ensure NV pump suction aligned to FWST as follows:
_ (1) 1NV-252A (NV Pumps Suct From FWST) - OPEN
_ (2) 1NV-2538 (NV Pumps Suct From FWST) - OPEN
_ (3) 1NV-188A (VCT Otlt Isol)-
Isol) -
CLOSED
_ (4) 1NV-1898 (VCT Otlt Isol)-
CLOSED.
_ b) WHEN Reactor is tripped, THEN attempt to establish and maintain a slow cooldown as required to maintain PZR level.
_ 2) Ensure steam dumps - IN PRESSURE MODE.
_ 3) Ensure the Reactor - TRIPPED.
(RNO continued on next page)
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/Al5500/021 AP/1/A/5500/021 7of39 7 of 39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. (Continued)
- 4) WHEN reactor power less than 5%,
THEN perform the following:
_ a) Trip all NC pumps.
_ b) Ensure the normal spray valve associated with the tripped NC pump(s) - IN MANUAL AND CLOSED.
_ 5) Secure any dilutions in progress.
- 6) IF the reactor trip breakers were closed, THEN perform one of the following while continuing with this procedure as time and conditions allow:
_ . IF above P-11, THEN GO TO EP/1/Al5000/E-O EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).
- IF below P-11, THEN GO TO AP/1/A/5500/005 (Reactor Trip AP/1/Al5500/005 Or Inadvertent S/I SII Below P-11).
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/
AP 111Al5500/021 Al55001021 8 of 39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. Verify KC . available Ver:~fyKC a",~n@J:>I~asfc:)I1c:)ws:
as follows:
- a. VstifMtI1Sfql!q\&ig9 Verify the following Train A K(4 1tr§}ll1~ KC 110n'+essentiall'iead.eeisolation*val~ess non-essential header isolation valv,e$ -
OREN:
OPEN: The KC non-essential header valves can be
- .1KC;,23*())~':KRxBlgg:lNqgt~
1KC-230A (Rx Bldg Non::Ess *.ssfidr.
Hdr reopened when the Isol) l*sPI) appropriate train's level switch is reset. This
- 11**K(4;,(3.~*'*(~:IB'dg*lNq!1lmEssnRetmdt KC-3A (Rx BJdgNon-EssRet Hdr should occur between Isql)
Isol) 40% and 48% KC surge tank level.
.j.!s;@'5QA
- 1KC-5PA K~I.j'*-l3ldg:lNqQ~~ssfldt (Aw( Bldg Non-ESs Hdr Isol) a. WHEN OAC alarm C1 D2215 02215 (KC Train A Low-Low Level Surge Tank Isol) is
- 11*'!s;(441~{AliIx::l3ldglNqDi.Essg~l.,**.flgr KC-1A{AuxBldg Non-EssHet Hdr "NOT ACTUATED", THEN ensure the Isol).
ISOl). affected valve(s) are open.
b*Verify.thefqHo\&Il1gi::';[Wair:ll3l~~
- b. Verify the following Train BKC
!1Ion.,e$sen.tia!.**l1eag~risQlatio!1lMaJM~S::;;
non-essential header isolation valves -
OPEN: The KC non-essential header valves can be
- 1 1K(4":22813~Rxl3ldgNoQ",EssHdr KC-228B (Rx Bldg Non-Ess Hdr reopened when the Isol>
1501) appropriate train's level switch is reset. This
.1KC"1*813(:~'l3ld9:,lN()r1~Ig$SRe.t**:fldr
- 1KC-18B (RxBldg:,Non-Ess Ret Hdr should occur between Is.ol) 1501) 40% and 48% KC surge tank level.
- 1 1KC~5313(~liIxl3ldgNol1",f~ssHdr KC-53B (Aux Bldg Non-EssHdr Isol) 1501) b. WHEN OAC alarm C1D2214 C1 D2214 (KC Train 13 B Low-Low Level Surge Tank Isol) is 1KC-2B{A.LJx ~Idg Non-Ess Ret .',fldr
- lK(4~213;(~l.jx::l3ldg*lNqntES$iRe.t: Hdr "NOT ACTUATED", THEN ensure the 15(1).
1501). affected valve(s) are open.
§tart,qdditioQali~(4gllfQP(s)as
- c. ptart additional KC pump(s) as c. IF KC pump(s) damaged by fire, THEN
.nSces$~!¥;tostil?l?I~~I1~~~i.lqa.ds riecessary:to supply anyKC .loads notify IAE to repair cables to pumps pre$ebtl~)ibs~rYi~e; prese(1tly.itl service. needed for recovery. REFER TO IP/1/A138901027A (Fire Damage Control IP/1/Al3890/027A Procedure).
none will be needed i I
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A155001021 AP/1/N55001021 90f39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED O.Jl.Ml~~;llI'g!*;';J'"Q~I~Y:~t~~p~rtmijn:AS' 10.
1 Verify KC surge tank'ieveis n()rmal as
!mtJpJt~'i follows:
- a. .tttl~~Qtf1:t1I~{.j;~.tm:.'S{~~~,);,;
_ (ali Verify both KC surgetall!<le~els - 50% - a. Perform the following:
.%'~fI~'~.~_;
90% AND STABLE.
- 1) Dispatch operator to initiate makeup to surge tank{s) by opening the appropriate valve(s):
1KC-1 07 (1A KC Surge Tank YM
_ . 1KC-107 M/U) (AB-601, PP-59, Rm 500)
_ . 1KC-111 (1 B KC Surge Tank YM M/U) (AB-601, PP-59, Rm 500).
_ 2) Dispatch operators to locate and isolate KC System leakage.
_ 3) WHEN the affected KC surge tank(s) level is greater than or equal notify dispatched to 90%, THEN notity operator to secure makeup.
_ 4) GO TO Step 11.
_ b.. GO TO Step 14.
- 11. Verify at least one KC surge tank above Perform the following:
10-10 level as follows:
Verify the following:
- a. Verity
_ .* 1AD-10, 1AD-1 0, N1 Al1 "KC SURGE TANKA TANK A
- LO-LO LEVEL" - DARK _ 1) Both Unit 1 RN Essential Headers -
PRESSURIZED.
_ 2) IF only one RN Essential Header is
- 1AD-10, N2Al2 "KC SURGE TANK B pressurized, THEN use it for surge LO-LO LEVEL" - DARK. tank makeup.
_ 3) IF AT ANY TIME the RN Essential Header being used for makeup becomes depressurized, THEN notify dispatched operator to secure makeup from RN.
(RNO continued on next page)
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A15500/021 AP/1/A/5500/021 10 of 39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 11. (Continued)
Preference should be given to the surge tank with the highest stable level and available pumps.
- b. Dispatch operator to makeup to available train of KC from YM and RN.
REFER TO Enclosure 5 (Surge Tank Makeup).
- c. Dispatch operators to locate and isolate KC System leakage.
- d. Notify Chemistry of RN makeup to KC System.
- e. WHEN the KC surge tank level is above the 10-10 level setpoint, THEN:
_ 1) Ensure the KC pumps on the affected train - ON.
(RNO continued on next page)
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A/55001021 AP/1/A155001021 11 of 39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 11. (Continued)
The KC non-essential header valves can be reopened when the appropriate train's level switch is reset.
This should occur between 40% and 48% KC surge tank level.
- 2) Open the non-essential header isolation valves for the affected train as follows:
- Train A:
- 1KC-230A (Rx Bldg Non-Ess 1501)
Hdr Isol)
- 1KC-3A (Rx Bldg Non-Ess Ret 1501)
Hdr Isol)
- 1KC-50A (Aux Bldg Non-Ess 1501)
Hdr Isol)
- 1KC-1A (Aux Bldg Non-Ess 1501).
Ret Hdr Isol).
- Train B:
- 1KC-228B (Rx Bldg Non-Ess Hdr 1501)
Isol)
- 1KC-18B 1KC-18B (Rx Bldg Non-Ess 1501)
Ret Hdr Isol)
- 1KC-53B (Aux Bldg Non-Ess 1501)
Hdr Isol)
- 1KC-2B (Aux Bldg Non-Ess 1501).
Ret Hdr Isol).
- f. WHEN one train's non-essential header isolation valves are opened, THEN perform Steps 12 through 13.
(RNO continued on next page)
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A15500/021 AP/1/A/55001021 12 of 39 DC~
Rev 36 DCE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 11. (Continued)
_ g. GO TO Step 14.
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A15500/021 AP/1/A/5500/021 13 of 39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 12. Verify 1AD-10, Al1 "Ke SURGE TANK A Perform the following:
LO-LO LEVEL" - DARK.
- a. Ensure the following valves - CLOSED:
- 1KC-230A (Rx Bldg Non-Ess Hdr Isol)
- 1KC-3A (Rx Bldg Non-Ess Ret Hdr Isol)
- 1KC-50A (Aux Bldg Non-Ess Hdr Isol)
- 1KC-1A 1KC-1A (Aux Bldg Non-Ess Ret Hdr Isol).
- b. Ensure both Train B KC pumps - ON.
- c. IF KC Surge Tank 1A level continues to decrease OR is empty, THEN:
- 1) Ensure the following Train B essential equipment -IN
- IN SERVICE AS NEEDED:
- NV Pump 1B
- NI Pump 1B
- ND Pump 1B
- NDHx1B
- CA Pump 1B
- NS Pump 1B
- KF Pump 1B.
- 2) Ensure the following Train A essential equipment - OFF:
- NV Pump 1A
- NI Pump 1A
- ND Pump 1A
- CA Pump 1A
- NS Pump 1A
- KF Pump 1A.
_ 3) Ensure both Train A KC pumps -
OFF.
_ 4) Locate and isolate leak on Train A essential header.
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A155001021 AP/1/Al5500/021 14 of 39 Rev 36 DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 13. Verify 1AD-10, Al2 liKe "Ke SURGE TANK B Perform the following:
LO-LO LEVEL" - DARK.
- a. Ensure the following valves - CLOSED:
- 1KC-228B (Rx Bldg Non-Ess Hdr Isol)
- 1KC-18B (Rx Bldg Non-Ess Ret Hdr Isol)
- 1KC-53B (Aux Bldg Non-Ess Hdr Isol)
- 1KC-2B (Aux Bldg Non-Ess Ret Hdr Isol).
- b. Ensure both Train A KC pumps - ON.
- c. IF KC Surge Tank 1B level continues to decrease OR is empty, THEN:
- 1) Ensure the following Train A essential equipment - IN SERVICE AS NEEDED:
- NV Pump 1A
- NI Pump 1A
- ND Pump 1A
- ND Hx 1A
- CA Pump 1A
- NS Pump 1A
- KF Pump 1A.
- 2) Ensure the following Train B essential equipment - OFF:
- NV Pump 1B
- NI Pump 1B
- ND Pump 1B
- CA Pump 1B
- NS Pump 1B
- KF Pump 1B.
_ 3) Ensure both Train B KC pumps -
OFF.
_ 4) Locate and isolate leak on Train B essential header.
CNS LOSS OF COMPONENT COOLING PAGE NO.
AP/1/A/55001021 AP/1/A155001021 15 of 39 Rev 36 DCS DC~
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 14. §n§YfeK:P:f!~~tiexghapg~f***()yt!;~t.mQd~
En~lJre KCheatexchanger outlet mode
$Witgh~S.i"~.R@PERI..i;YAl;IGN§[)i switches - PROPERLY ALIGNEDL If a B train pump is started instead of the available AA train pump, these will need to be swapped.
___ __~ ~ ___________ ~ _ _ _ _w _ _, _ _ _ _, _ _ ~
- 15. p~t~rmip~a.Pd***cQrf~gtcal1seQf:IQ~~()f Determine and correct cause of loss of KG~
KC.
16.§nsYf~gpmpri~p¢~Witf!
- 16. Ensure cornpriance with .*appropriate ~pptppl'j~t~
iF~¢h. Specsand'Serected Tech sp~¢§~n'd'~~r~('?t~d*. *l..ii¢~n.~~~;
Licensee PQmmitm~.nts;Manu~H Commitments Manual:
TS 3.7.7 Condition A
- ~l.Q1:Q;;~;i.7.(8(!)rati(!)i;j*/~y$ter'l"!.$ITI(!)WPatb SLC 16,:9-7 (BorationSystems FIQ'N Path
- c:~h.ut<:l(!)Wtl~
.;:ShutdQwn)
- S:I.,.Qfl.Q:i*~S.8*
.SLC * (~Qtatiom:SY$t~Q;t$FfQWJ?atb 16,9-8 .(Boration Systems Flow Path
~bOp~~~{Ing)
Operating)
- S*LYi~6;9:-9**(~.btatibt1~Y$te:m~iPu*m~s.i SLC 16;9-9 (BorationSystems Pumps-Sl1i:1f90 Shutdown) wrl
- SI.,.Y'16.9i:
SLC16.9-10 1Q.*.(8PtElJiorl}Syste:trls (Boration Systems PI1~rQlngf?um~$-:Qper~tiogl Charging Pumps - Operating) 3:5:2 (ECCS ..-Operating)
**~;5r2(i;;YY8 0perati(1Q)
- 3,~,3{EQyS:
3;5.3 (ECCS,.. . SI1I.:ltdowh) Shutdown)
.~1f).6.'{YQ.t1tallitrlent~Qnay~ysteQ;t~
- 3.6.6 (Containment Spray Syster:n)
* ***~W7JI):~:{~IJ~ilia.~7Fe:e:<:IW~~e:~(AI?V"I.f}
3.7~5 (Auxiliary Fe¢dwater (AFW)
~Y$ter'l"!)
System)
~,ri* ri,(y(!)Q;tfiiQi;jentPQ(!)tii;jQWate:r~YY'Y!!l~i
- 3.7.7 (Component Cooling Water (CCW)
~ystero'~
System).
- 17. Delerrnioetequired notifications:
REI7ERlm().***Igf?/.(l)IN.~(l)(l)OI(l)(l)1
- REFERi;TO
.(Qjlassi~iGatiQ@L*Of RP/O/A/50001001 i;;merge:@'GY)
(Class]ficationOf EtTrergency) RBI7ER'F(ll:.Igf?I(l)/al~OQ(l)/QJ3(1>J:1gQj.
- REFER TOHP/OfB/5000/013 (NRC NQtift~tiQi;jslgeqi:liiferoent~~;
Notificationi~equirements).
CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/A/55001021 AP/1/AJ55001021 16 of 39 Rev 36 OC~ DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 18. IF*.~~ii:~,~I~~t<t9~Ni~i$u~p~ctecb::THEN IF KC Hx leak to RN is suspected, THEN p~t'f6/Jl;1tQef6116Wihg; perform the following:
- Notify Radiation Protection that a potential unmonitored release may have occurred.
- Notify Station Management to evaluate a KC Hx to RN leak.
- 19. Ver,ify KCsurge tanks I~vel as follows: _ RETURN TO Step 9.
- Greater than 50%
- Stable or increasing.
- 20. WHEN planfconditionspermit, THEN:
RE)f~rt:li~CI,p~@;!.p~itQ'@@rmal,,@pE)rat.i@n:
- Return KC pumps to normal operation.
REEERTO@H71/A/6~007005. REFER TO OP/1/AJ6400/005
~GQmp(Jri~rit':C;;Q@I,iog'WatE)~**§Y$tE)@;!n (Component Cooling Water System).
- Return NV Pump 1A to normal cooling as applicable. REFER TO Enclosure 4 ~
(Alternate Cooling To NV Pump 1A).
- 21. Verify the following: Perform the following:
1*~I:i);:7t;flt3YI;.IiETj])l:'J*'*:**I::I~.q\JfII;.EII::II
- 1A[)';'7, F/3 "tETON HX OUTLET HI a. IF letdown isolated, THEN refer to TEMHt!.;:E:)~R.~
TEMP" -DARK AP/1/A/55001012 (Loss Of Charging AP/1/AJ55001012 Letdown) . Or Letdown).
* *1AO-7;H/3 1f1;.l:i)iq;:'H/p**!1~CITP**ttl;IpMg(':;:i'@f1;.g~
"\.{CTHI*TEMP"::.DARK
- b. Do 00 not continue in this procedure until
- No~hialletdown - IN SERVICE. Step 21 conditions are met.
CNS LOSS OF COMPONENT COOLING PAGE NO. AP/1/Al5500/021 17 of 39 DC::: Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. I;h§Yrg:¥~iJj~h(:f>lgl<foWh:patt:!~lig.hg<fit§ Ens.QteVCTandletdown.path aligned as folloWs':
follows: a a..IF.(1esjt:ed.toali~h'f'iJX1pl1rnp*'.$~ctiojj,*t.o. IF desired to align NV pump suetiohio
¥'<>\['rtl1ejjperfQtlTlfh~to.UqWIl)g; VCT, then perform the following:
1)'*<EJ,Pehtl1efqHQWlpg
- 1) Open the following valves: \lalves:
*.11t>JX1"'~:~8~*('\.1G)iJj**(3)~lt\l~ol).
1NV-188A(VCT Otlt Isol}
****mt>Jv4a~~(¥,G)T:(3).tltJ§ol).;
1NV-1898 (VCT OtIUsol}. 2) 2} *.G)lo$e.th~tC?lloWifil~y?l\les:. CloSe the following valves:
*.1:t>J'\.1"4~2~:(N¥'*'f?lJrnps.SQqt.p'rQ*t'(:I 1 NV-252A (NV Pumps Suet From FWSJ)
FWS:n
- 11.'t>JV"~~~~(N'\.1:PI!lr;l:)p~S!4CrprgrU NV-2538 (NVPumps Suet From FWS\['lJ:
FWST). b,
- b. WHEN.*
WHEN *.N'\.1sl!lctioAia1i0@e(itgVG)\['i NV suction aligned to VCT, rrflfENtn0me@Jat:ily THEN momentarily PJace1t>J'\.1h'place 1NV-172A 7~ (p"'W?Y~iyertToVG)T8.FR&l\[,}Jottie (3-:-Way Divert To VCT-RHT) tothe
"¥,G)rr"*posi~iQo***ar;\(1{fetg*r~rJg::r~qT(3)".
"VCT" position and return to."AUTO".
- c. IF,!1desi(ed**tl3>,resfofeletdowjjflow
- e. IFdesiredtorestoreletdoW'n flow ttl fg*~.~l1tl1e'f)lVQ~r;l:)il'l~ral*i~etS;*'rrH through theNV demineralizers, THEN EN momehtqt:ily:place,N'\.1:'19pA momentarily place 1NV-153A (l$et(1Il:*mx. (Letdn Hx Otlt 3-Way Vlv) to the **.*,~ql'S1.1N~I*pOsi~ign
~t!t.~~WaYVly).tq.Jh~ "DEMIN"* position ahd::retuthto**At.Jro~lr and return to "AUTO".
23..Q~~grmin:g'.**lollg"~errtll.:lpIahtist~~u§~ 23 Detennine long term planO;tatus. FRErrt:.JJ~N'TO RETURN pli()~g.<fyrein** TO procedure in . ~ff@~t~ affect.
I I
Duke Energy Procedure No. Catawba Nuclear Station API 1 IA/5500/007 AP/I/A/5500/007 Loss of Normal Power Revision No. 057 Electronic Reference No. CN005CEB Continuous Use PERFORMANCE JI
- UNCONTROLLEDFORPruNT**********
(ISSUED) - PDF Format Initiating Cue: Multiple electrical alarms on 1AD-11, UV status lights for 1ETB on 181-14
CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A155001007 AP/1/A/55001007 1 of 154 Revision 57 A. Purpose
- To verify proper response in the event of a loss of normal power to an essential train.
- To verify proper response in the event of a loss of all power to an essential train.
- To verify proper response in the event of a loss of all 6.9KV busses.
B. Symptoms Case I. Loss of Normal Power to an Essential Train:
- DIG starting or running status lights (1SI-15) - LIT
* "BLACKOUT LOAD SEQ ACTUATED TRN A" status light (1SI-14) - LIT * "BLACKOUT LOAD SEQ ACTUATED TRN B" status light (1SI-14) - LIT.
CNS LOSS OF NORMAL POWER PAGE NO. AP/11A15500100? AP/1/A/55001007 2 of 154 Revision 57 RevisionS? Case II. Loss of All Power to an Essential Train:
- 1ETA de-energized
- 1ETB de-energized
- Loss of normally operating components supplied from affected bus
- Affected DIG - OFF
- Affected DIG breaker - OPEN
- Affected sequencer not loading essential loads.
Case III II. If both 1ETA and 1ETB are powered "I is normally entered from Case I or ". 11/ may be entered directly. from Unit 2 and Unit 1 offsite power only is lost then Case III Case III. Loss Of All 6.9KV Busses
- Case I (Loss of Normal Power to an Essential Train),
Train). Step 12 Case II (Loss of All Power to an Essential Train),
- Case" Train). Step 22 1AD-11. F/4 "ZONE G LOCKOUT TRIP" - LIT
- 1AD-11,
- Loss Of Switchyard
- Swgr Tie Bkrs Closed status lights (1SI-14) - LIT
- Emergency lighting - LIT
- Numerous transformer trouble annunciators 1AD LIT
* "DRPI BON EMERG POWER" (1SI-3) - LIT
- DRPI indication - DARK
- 1SA-5 failed open.
CNS LOSS OF NORMAL POWER PAGE NO. AP/11A155001007 AP/1/A/5500/007 20 of 154 Case /I Revision 57 Loss of All Power to an Essential Train LossofAIIPowerlo**atiEssentiaITraih AClION/EX,PECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Monitor Enclosure 1 (Foldout Page).
- 2. V~rify th~:~ssentiallpads al*I.~~~,sp9W~redfr6m powered from energized<trainas follows:
a*$-f\J,p9m~f~~iFlrtJS~~Y'I~§AS
- a. ~N pump(s):' IN S~.!RVltE AS a. Manually start pump(s).
NEE[DE[D. NEEDED: lJ1R(§l~ .
- IN,'SERVICEAS
- b. KC pump(s)- If\J!':~I~!~~J~~',I,X~ b. Perform the following:
Em NEEDED. _ 1) Manually start pump(s). II' If the crew chose to start a B train KC KCI pump during EVENT 3 they will do the I,' _ 2) Ensure KC Hx outlet mode switches IRNORNO of this step. ! - PROPERLY ALIGNED.
- c. At least:on~ NV pump - ON. AP/11A155001012 (Loss of
- c. REFER TO AP/1/A/5500/012 Charging or Letdown).
- d. CA pump -ON. d.l~;;~~
- d. IF GA pump *req'Ui~~(l't()*im~iht~inS/G is .* required p".*is to maintain S/G l~y~lsj THEN levels, manually start pUn;lp.
EN".'rnanuallystartpultl.P, e.VCfYC chiller -ON .* e. REFER TO OP/0IAl64501011 OP/0/A/6450/011 (Control Room Area Ventilation/Chilled Ventilation/Chilied Water System).
- 3. Verify eA Pump #1~ ON;* _ IF CA Pump #1 is required to maintain SIG levels, THEN start CA Pump #1.
- 4. eal;{t9rg(iw~.t Maintain reactor le$$*h~i:I power. less than . (i~
or 0%; equal to 100%;
- 5. Verify DIG on the affected bus
- _ GO TO Step 7.
RUNNING. The DIG[DIG IS running, but the output breaker will not close. Also the cooling water valve will not open and the D/G DIG will be secured eventually.
CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A/55001007 21 of 154 Case II Revision 57 Loss of All Power to an Essential Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. VerifyRN cooling to theaffectec:f DIG. 1\>~a,c)rl)1thefolloY'li[lg*
Perform the following fortlieaff~ctetf for the affected DIG: DIG: .
- DIG 1A:
- a. Depress and hold the DIG "OFF" pushbutton.
- b. Dispatch operator to open 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496).
- c. WHEN 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) is open, THEN release the DIG "OFF" pushbutton.
OR
- D/GtB.:
- a. QepressS.a~dnold and hold tile the D/G!tOFFt' DIG "OFF" pushButton.
tton. .
- b. Dispatch operator to open 1EPF-F01 F (Diesel Generator Load Sequencer .PaneI1DGLSB) (AB-560, 8B"4p, Rm372).
j~§!3~!301 F c;WHEN 16DF-F01 F~f)i~sel (Diesel Generator Load~o?9:gequeq*9~~tP:~ri1! SequencerPanel 1DGLSB).ds ei~* *. open, 9~~n,* . *TH.EN* ~e*reasgt!:i*ii THEN .* . release the DIG "OFF!'l'iPI:J~hQl.,ltton, pushbutton.
- 7. DisRatchQPerator;\vith a screwdriver to' Idati shed. the affected essential bus as follows:
_ . REFER TO Enclosure 8 (Manual Load Shed Of 1ETA) OR
** REFER TO" EncJosure 9 (Mariual.Load Shed at~ I;TB).
- CNS LOSS OF NORMAL POWER PAGE NO.
AP/1/AJ55001007 AP/1/AJ5500/007 22 of 154 Case II Revision 57 Loss of All Power to an Essential Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 8.~~riNQP~t~tiriij'B~"pl.lmp(§)'IQW-~e$s
- 8. Verify operatingR~ pump(s) flow - LESS _ REFER TO AP/O/Al5500/020
_ AP/OIAl5500/020 (Loss of TI-f'AN23';OQQ:::~1'I\IIP THAN 23,000 GPM) Nuclear Service Water).
- 9. .stop "any dilutions in progress.
- 10. Vefify$/lsJaJ.,.sa;sf61IoWs~
Verify S/I status as follows: a.S/Ii-HAS
- a. SII '-HAS ACmI.i.lA"TIEE);
ACTUATED. a. GOTO Step 11.
- b. GO TO Step 12.
CNS LOSS OF NORMAL POWER PAGE NO. AP/1/A/55001007 AP/1/A/5500/007 23 of 154 Case II Revision 57 Loss of All Power to an Essential Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 11. "ei:lfyNO$Vs~~msl~lf.ls~sf()now~:;
Verify NO System status as follows:
- a. NQ~M§t~n')L:~1,.1 NO System- ALlGN~D iNIRE+/-$IOt.1J,\L INHESIOUAL a. GO.TOStep 12.
PfEAl"'IREM0\lALM.. HEAT REMOVALMQOE. E.
- b. At least one ND NO pump - ON. AP/1/A/55001019 (Loss of
- b. REFER TO AP/1/A/5500/019 Residual Heat Removal System).
- c. 1AO-11, B/O BUS FTA 1AD-11, K/3 "4KV BIO c. Perform the following:
VOLTAGE LO" - DARK. OARK. Both NO ND Hx Bypass valves fail closed on 1LXI loss of 1LXI (1FTA). (1 FTA).
- 1) IF NO ND Pump 1A is operating in Residual Heat Removal Mode, THEN perform the following:
_ a) Place the "PWR DISCONOISCON FOR 1N1173A" in "THROT". _ b) Throttle 1NI-173A (NO (ND Hdr 1A To Cold Legs C&O)C&D) to stabilize NC temperature. _ c) WHEN 1AO-11, 1AD-11, K/3"4KVB/O K/3 "4KV BIO BUS FTA VOLTAGE LO" dark, THEN return 1NI-173A 1NI-173A to normal alignment.
- 2) IF ND NO Pump 1B is operating in Residual Heat Removal Mode, THEN perform the following:
_ a) Place the "PWR DISCONOISCON FOR 1N1178B" in "THROT". _ b) Throttle 1NI-178B (NO (ND Hdr 1B To Cold Legs A&B) to stabilize NC temperature. _ c) WHEN 1AO-11, 1AD-11, K/3"4KVB/O BUS FTA VOLTAGE LO" dark, THEN return 1NI-178B 1NI-178B to normal alignment.
CNS LOSS OF NORMAL POWER PAGE NO. AP/1 /Al5500/007 AP/1/A155001007 24 of 154 Case II Revision 57 Loss of All Power to an Essential Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 12. Ensure CA SystElm ~. RESET.
- 13. Control S/Glevels asfoJl6ws:
- a. Verify CF flow - MAINTAINING STABLE a. Perform the following:
S/G LEVELS; _ 1) REFER TO Enclosure 16 (S/G Level Control). _ 2) GO TO Step 14.
- b. IF AT ANY TIME CF flowicontrol to S/Gs is 10st"TRENperformStep 13.
CAUTION Battery depletion may occuras early as two hours. Battery depletion results in affected CA control valves failing full open. Failure to take local control of S/G level prior to battery depletiorimay result in S/G overfill.
- c. IF AT ANY TIME any vitaloraUxjljary.
control channE:j1 pattery chargE:jrhas been de-energized for gr~aterthan 1 hour, THEN dispatch operators to locally control affected CA flow path. REFER TO Enclosure 16 (S/G Level Control).
CNS LOSS OF NORMAL POWER PAGE NO. AP/1/AJ5500/007 AP/11N55001007 25 of 154 Case II Revision 57 Loss of All Power to an Essential Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 14. Verify "C-9 COND AVAILABLE FOR 5"fM To prevent overpressurizing the DUMP" status'light (151-18) - LIT. condenser perform the following:
- a. Dispatch operator to close the following valves:
- 11SA-22 SA-22 (Main Steam To CSAE)
(TB1-594,1M-32) (TB1-594, 1M-32)
- 1 SA-27 (Aux Steam To CSAE) 1SA-27 (TB-594, 1M-27).
- b. WHEN notified by dispatched operator that the SA supplies are closed, THEN perform the following:
_ 1) Open "COND A-B-C VAC BKR VLVS".
- 2) IF power not available to operate "COND A-B-C VAC BKR VLVS",
THEN dispatch operator to open the following valves:
- 1CM-368 (1A Main Cond Shell Vacuum Bkr) (TB-600,1 (TB-600, 1F-26)
(Ladder needed)
- 1 CM-369 (1B 1CM-369 (1 B Main Cond Shell Vacuum Bkr) (TB-603, 1F-24)
(Ladder needed)
- 1CM-370 (1 C Main Cond Shell Vacuum Bkr) (TB-605, 1F-22)
(Ladder needed). _ 3) WHEN time permits, THEN dispatch operator to complete breaking condenser vacuum. REFER TO OP/1/B/6300/006 OP/1/B/63001006 (Main Vacuum). _ 4) Shutdown steam seals. REFER TO OP/1/B/6300/005 OP/1/B/63001005 (Steam Seal System).
CNS LOSS OF NORMAL POWER PAGE NO. AP/1/AJ55001007 AP/1 I Al55001007 26 of 154 Case" Revision 57 Loss of All Power to an Essential Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 15. Control ct1~rgingas~ol'iows:
_ a.'Maihtain'chargingflowless than
;180'GPM.'
- b. 'Adjust charging flow as necessary to maintain PZr level in progtarn"band.
- 16. '~Jflti(ifIIlljlm_.,
Control letdown as.follhws[ _ a. a. li.iJ_.tfl.~II.I\lI. Verify nOrmal'letdowri - IN SgRVICE. a. Perform the following: _ 1) Attempt to restore letdown. REFER TO API11AJ55001012 AP/1/A155001012 (Loss of Charging or Letdown). _ 2) WHEN normal letdown has been established, THEN place additional letdown orifice in service as necessary to control Pzr level. _ 3) GO TO Step 17.
- b. Place additional letdown orifice in to service as necessary contrql' Pzr level.
- 17. D~termine,and correct cause,of blackout.,
- 18. V~rify Vlipres,sure - GREATER THAN _ REFER TO AP/O/Al5500/022 (Loss of 85;PSJ~>AND STABLE. Instrument Air).
- 19. IF SPent fuel pool Jhstrumeptatiqnl~ ,
failed low, THEN. di~p~ltch operator to monitor spent fuel :pool cop:i;titions, REFER TO Enclosure 14 (Spent)i=ue:li Pool:,MQOitoring).
CNS LOSS OF NORMAL POWER PAGE NO. AP/1/AJ55001007 AP/1 IAl55001007 27 of 154 Case II Case" Revision 57 Loss of All Power to an Essential Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 20..Sn~~r~~~Ql:pli~ri~~w.t~.*.~ppfQPri~t($ 20 Ensl:-Jre compliance with appropriate r.e~Il.****. Specs: Tech §p~~?:
* ~*4*9'~~~~§sl.Jtf~eF) 3.4.9(Pressurizer)
TS 3.8.1 Condition A, B, D,0, and F
.', .*3.. a,1~tx~§l:>~rc~s*-
* * *.* 3.8.1 (AC Sources -*.
- Operating)
Ope.ratifig) TS 3.8.9 Condition A iTS TS 3.7.8 Condition A
**3;a;2*(e-~Sl:>41.*tC~$+gntJt9l:>wrjJ 3.8.2 (AC Squrces -: Shutdown)
*.a;6;6I-.i~~<>i$QGrrG~$*+>~I~eti~tit"lg) 3.8.4 (DC Sources-,Operating)
*.a).~.R~~<>\$qqtGeSf*$Il.utd($~t"I) 3.8.5 (DC'Sources-Shutdown)
* **ai$;7'*~.I'R¥~r;tee§;~(9perating) 3.8.7 (Inverters-'Operating)
- 3,8i~(I.il:Y&r;t~t$qSIl*qtdown) 3.8.8 (InVerters ~ Shutdown)
- 3.$!9~[;)istpitj~ti~Jl9&steI))S*"
3.8.9 (Distribution Systems- *Ow~.~afing.~. Operating)
- 3,a;~Q~gi$t~.ibt;iti(}R*.Sysf~lilS.
3.8.10 (Distribution Systems - Sht.Jt9l:>~W), Shutdown). 2'1. Determil'le,requirednotifications:
- REFERTO f~At()/t!J.~()()QZQg1 RP/OIAJ50001001 (Classification Of Emergency)
($ni*qfEtlJe.pgency'
- REFERTO,RP/O/S/50001013 (NRC Notification Requtr'ements).
- 22. Verify 6.9KV busses- ENERGIZED~ _ WHEN time and manpower permit, THEN perform applicable portions of Case III.
REFER TO Case'" Case III (Loss Of All 6.9KV Busses). 23..DgijeJ9gilJ!:n~~i:'9t~i~~r9~~tli1lr~g.t"I!II; 23 Do not continue,in thi§ procedure untjl NEXT EVENT the tnefp!lp\r"{lI19.** .~r~i*?@ti§fi~d: following~resatisfied:
- The status of all lockout targets have been determined
- Station management has approved power restoration to the affected bus.
I I I II I I
Initiating Cue: 1AD-13, All, F/5 CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A155001010 AP/1/A/5500/010 1 of 154 Rev 51 DC~ A. Purpose
- To verify proper response in the event of a Steam Generator tube leak within the capability of the normal charging system while in Modes 1, 2 and 3.
- To verify proper response in the event of a reactor coolant leak within the capability of the normal charging system.
B. Symptoms Case I. Steam Generator Tube Leak:
- Any of the following EMF indications - INCREASING OR IN ALARM:
- 1EMF-33 (Condenser Air Ejector Exhaust)
- 1EMF-71 1 EMF-71 (S/G A Leakage)
- 1EMF-72 (S/G B Leakage)
- 1EMF-73 1 EMF-73 (S/G C Leakage)
- 1EMF-74 (S/G D Leakage)
- 1EMF-26 (Steam Line 1A)
- 1EMF-27 (Steam Line 1B)
- 1EMF-28 (Steam Line 1C)
- 1EMF-29 (Steam Line 1D)
- 1EMF-36 (Unit Vent Gas).
- Any of the following primary to secondary leak rate computer points:
- C1 P0187 (Estimated Total Pri To Sec Leakrate)
- C1P0189 C1 P0189 (Pri To Sec Leakrate 15 Min Running Avg).
- Charging flow indication --INCREASING INCREASING
- Pzr level - DECREASING
- Pzr pressure - DECREASING
- CF flowrate and CF flow regulating valve position indication - DECREASING ON ANY S/G
- Chemistry Calculation.
CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A/55001010 AP/1/A/5500/010 2 of 154 Rev 51 DC~ Case II. NC System Leak:
- Charging flow indication -INCREASING
- Pzr level- DECREASING
- Pzr pressure - DECREASING
- Any of the following EMF indications --INCREASING INCREASING OR IN ALARM:
- EMF-41 (Aux Bldg Ventilation)
- 1EMF-38 (Containment Particulate)
- 1EMF-39 (Containment Gas)
- 1EMF-46A (Component Cooling Train A)
- 1EMF-46B (Component Cooling Train B).
- Containment floor and equipment sump level(s) - INCREASING.
CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A/5500/010 AP/1/N55001010 54 of 154 Case II1/ Rev 51 DC~ NC System Leak ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. C. Operator Actions BOP DOES THESE ACTIONS
!BOP I
- 1. M<>t"!il<>t':;hcl<>siifueg, Monitor Enclosure 2 (q~SQUNC
{Case nNC Syst~m'.J.;eakF;91(f9qtBage), System Leak FoldoutPage).
- 2. Verify Unit 1 -lNMOPE5. _ GO TO Step 4.
- 3. Ensure containment integrity as required:
- a. IF leak known to be in Auxiliary Building, THEN GO TO Step 4.
- b. Initiate Containment Closure.
- c. Initiate additional action as required to ensure Containment Equipment Hatch -
CLOSED.
- d. Initiate additional action as required to ensure Containment Air Locks -
CLOSED. 4.V.~r~~:B~uIQ"Qli
- 4. VerifyP~r lev~l-.. STABLE
§;P~~J.;EOIi OR Perform the$foHowing:
l~qgEASING.*. INCREASING; l\I1aint~lo~l;I!gr'gihg'fl()VYless
- a. Maintain chargingflow"ess . than 180GERI'\l1j 180 GPM.
b~ Manually
- b. l\I1§nl:l§ll¥:t.l;I!:r()ttlei1NV~~94'.*(NV*'Pmps throttle 1NV-294 (NV Pmps A&B Di§chFlow Gtrl) .!Q***st
~~J:3***ldis:Q~cI()W:{Dtrl) pbiliz6iPzt to stabilize Pzr level.
PZR level will still be _ c. IF Pzr level is stable OR increasing, decreasing and the crew THEN GO TO Step 5. will have to reduce (RNO continued on next page) letdown. I
CNS REACTOR COOLANT LEAK PAGE NO. AP/11A155001010 AP/1/A/5500/010 55 of 154 Case II Rev 51 DC~ NC System Leak ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
- d. IFJ?zr level continues to decrease, THEN: .
- 1) Reduce letdown flow to 45 GPMas follows:
a) IF1 NV-1 OA (Letd n Orif 1B Otlt Ctlnt Isol) open, THEN peiform the following: _ (1) Manually control 1NV::-148 (Letdn Press Control) to establish letdown pressLire between 375 - 400 PSIG. _ (2) Throttle 1NV-849 (Letdn Flow Var Orif Ctrl) for*45 GPM letdown flow. _ (3) WHEN 45 GPMletqbwn flbw established, THEN adjust 1NV-148 {Letdn Press Control) to maintain letdown pressure at 350PSIG. _ (4) WHEN letdown pressure is
$tabl~>:at 350 PSI G., THEN piace'i1NV-148'. (Letdn Press Control) in auto.
(RNO continued on next page)
CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A155001010 AP/1/A/5500/010 56 of 154 Case II Rev 51 DC~ NC System Leak ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued) b) IF 1NV-13A (Letdn Orif 1A Otlt Cont Isol) open, THEN perform Cant the following:
_ (1) Manually control 1NV-148 (Letdn Press Control) to establish letdown pressure between 150 - 200 PSIG. _ (2) Open 1NV-11A (Letdn Orif 1C Otlt Cant Cont Isol). _ (3) Adjust 1NV-148 (Letdn Press Control) to establish letdown pressure between 375 - 400 PSIG. _ (4) Close 1NV-13A (Letdn Orif 1A Otlt Cant Cont Isol). _ (5) Adjust 1 NV-148 (Letdn 1NV-148 Press Control) to maintain letdown pressure at 350 PSIG. _ (6) WHEN letdown pressure is stable at 350 PSIG, THEN place 1NV-148 (Letdn Press Control) in auto.
- 2) IF Pzr level continues to decrease, THEN ensure the following valves closed:
- 1 NV-1 NV-1 OA (Letdn (Letd n Orif 1B Otlt Cont Cant Isol)
- 1 NV-11A (Letdn Orif 1 C Otlt Cont 1C Cant Isol) 1501)
- 1NV-13A (Letdn Orif 1A Otlt Cont Cant 1501).
Isol). _ 3))IF'g4nlev~,llsstable 3 IFPzr level is stable o.R:'incn~~~jii9) ORincreasing, mHE~Go.ifo.§tep5. THEN GO TO Step 5. (RNO continued on next page)
CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A155001010 AP/1/Al5500/010 57 of 154 Case II DC~ Rev 51 DC:::: NC System Leak ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
- 4) IF Pzr level continues to decrease OR cannot be maintained greater than 4%, THEN:
a) IF in Modes 1, 2, or 3 with CLAs in service, THEN perform the following: _ (1) Manually trip the reactor. _ (2) WHEN reactor trip verified, THEN manually initiate S/I. S/!' _ (3) GO TO EP/1/A15000/E-O EP/1/Al5000/E-O (Reactor Trip Or Safety Injection). _ b) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A155001027 AP/1/Al5500/027 (Shutdown LOCA). _ c) IF in Mode 5, THEN GO TO AP/1/A155001019 AP/1/Al5500/019 (Loss of Residual Heat Removal System).
- 5. IF AT ANY TIME Pzr leyer d~creases iI),
an,uncQntrolled manner or,cannot be maint~ihedgreater than 4%, THEN GO TO Step 4.
CNS REACTOR COOLANT LEAK PAGE NO. AP/1/A/5500/010 58 of 154 Case II Rev 51 DC~ NC System Leak ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. ¥~rifYpir/fj~.RrE!S~YX~::7,JlRl;fjQlfjG Verify Pzr/NC pressure - TRENDING Perform the following:
r~~RST TO OR STABLE.t\t3q.g.t\T*'QEZSIREZQ AT DESIRED PRESSURE. PRESSURE, a. IF Pzr level is greater than 17%, THEN ensure Pzr heaters on as required.
- b. Ensure Pzr spray valves - CLOSED.
- c. Ensure all Pzr PORVs - CLOSED.
- d. IF any Pzr PORV is leaking or has not reseated, THEN close its associated Pzr PORV isolation valve.
- e. IF Pzr/NC pressure is decreasing in an uncontrolled manner, THEN:
- 1) IF in Mode 1, 2 or 3 with CLAs in service, THEN:
_ a) Manually initiate S/I. _ b) GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection). _ 2) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A/5500/027 (Shutdown LOCA). _ 3) IF in Mode 5, THEN GO TO AP/1/A/5500/019 (Loss of Residual Heat Removal System).
- 7. l:)i~R~JQb OR~~~JQ~(~)'jt9JoQ~J~i~l"lc;t Dispatch operator(s)t()locat~:and i~9.I~t~;fj~SM~J~tn.,.'*le~l<;
is()lateNC System leak.
- 8. v..erifYRt9Re~"v..~~~~M~tetn.9R~tf~ti91"l;*
Vel"ifyproper VCIYC system operation. REFERrO<I;I"lQJ9§Yte1~*(P0t1tr91 REFER TO Enclo§ure 14 (Control Room v..el"ltil~J'91"l1:*§y§tetn:iv..erifIQ~U91"l). Ventilati()mSyst~m"Verification).
CNS REACTOR COOLANT LEAK PAGE NO. AP/1 IAl550010 10 AP/1/A/55001010 59 of 154 Case II DC~ Rev 51 DCS NC System Leak ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. BIB.~]"II\1JIi;,'.Bf'lIt.tfr_~l;P}i~"l,.4g; IF AT.ANYTJME1AD-7, 111 "VeT LO LVL" This wont happen.
aJ.arm-v *. '. LJI,'. THEN
'rV{.,iMAL align NV pump suction .
iJar~~8IlRIfl8Ni\fiillr'i!t*~,*'M~!Jn:(.~"'i;"'*i*lf~'.t
. .. .. . ';*MLtt:lD!;;:t"'.0;R!J&~.g~"A,*lj
;tQ;.fft~1<1i1l~1ti~';f911";'
to thEfFWST as follows:
- a. Open 1NV-252A (NV Pumps Suct From FWST).
- b. Open 1NV-253B (NV Pumps Suct Suet From FWST).
- c. Close 1NV-188A (VCT Otlt 1501). Isol).
- d. Close 1NV-189B (VCT Otlt 1501). Isol).
- e. IF Reactor trip breakers are closed, THEN perform the following:
_ 1) Continue concurrent use of this procedure for the NC leak. _ 2) Manually trip the reactor. _ 3) IF Unit was in Mode 3 below 1955 PSIG, THEN GO TO AP/1/A/55001005 AP/1/A155001005 (Reactor Trip or Inadvertent S/I SII Below P-11). _ 4) GO TO EP/1/A15000/E-O EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).
CNS REACTOR COOLANT LEAK PAGE NO. API1IA155001010 AP/1 IA/5500101 0 60 of 154
~it~~;l]f' Case II DC~
Rev 51 DCS
~C System Leak flGj;§:Y~~m~~'g~Is:'"'
ACT ION / EXP EClED .RESPONSE RESPONSE NOT OBTAINED
- 10. Determine NCI~akrate by any of the following methQdl?:
_ .* ~Qm~~;~~mBlijr;l~I_.l1lf:t~~lI' Compare chatgiligflow and I.etdown floW 9pm-Leak is approximately 60 gpm
'leak E,lf;l, OR
_ .icit '1I.'JI~Wll>";Ji'!fl\fr;!Hkn"I;~'_ti(h\mt MonitorOAC NV'::~J~~~>\~J~ Grapliic _ F' ;jJ,),(.~J$t1~Mrt+~!?~~;~,~y;~ OR _ .Ini,tiate OAO Program "N$NCLEAK'\
~OR
__ .,~; I1tWilP<<;Q~GJ{'(O}\?Ef~;li~~K/ Monitor OAC point ER.oRLEAK
~~t OR
_ ~"I1~~~m';R~jlJft~.I~~.
- Monitor OACpoint 01P09.76 (Gross NO
~,_t\f:t;,~~~~mm;~;
System LeakRate, Ten Min;Run .. ~.~,g:[. Avg).
- 11. Ensure compliance with ~ppropriate Tech Specs and Selecte<;l Licensee Commitments Manual: TS 3.4.13 Condition A
- 3.4.4 RCS Loop§-Modes 1*ahd 2 TS 3.6.4 Condition A SLC 16.7-9 Condition A
_!i+ * ;~~4*';5\flCSrL.~~~fj~;~' 3.4.5 RCS Loops-Mode 3
** iik',,(,~<<..,tn9/:l1i~*~"lb1ry>:l>'<ii91~
3.4.6RCS Loops-Mode 4 _ ',.,~"~~~'~?;~~""~,;.fY~~~~'
- 3.4.12 Low Temperature Qverpressure Protection (LTOP) System
- 3.4.13.(RCSOperational] Leakage) j3A.l~ (RCS PressUrel.lsCllation Valve (PIV):Leakage)
- 3.5.5 (Seal Injection Flow)
EVENT 6 can begin here.
- 3.6.3 Containment Isolatipn Valves
- 30T 17 (Secondar:y,§pecific: ~cti¥ity)
- SLC 16.7-9 (stabdpy Shutdown SystemH.
\ \I \ I \
\
!Initiating Initiating cue: 1AO-1 A/6 and 1AO-5 A/1, A/4
CNS LOSS OF S/G FEEDWATER FEEOWATER PAGE NO. AP/1/A/5500/006 1 of 20 Rev 40 DC~ OC~ A. Purpose
- To verify proper response to a 1055 loss of feedwater supply to the S/Gs.
- To verify proper response to a 1055 loss of normal supply of auxiliary feedwater.
B. Symptoms Case I. Loss Of CF Supply To S/Gs:
- CFPT A and B 8 - TRI PPED PPEO
- 1AD-3, 1AO-3, C/6 "CF ISOL TRN A" - LIT
- 1AD-3, 1AO-3, D/6 0/6 "CF ISOL TRN B" 8" - LIT
- Any S/G 10 level alert alarm on 1 AD LIT 1AO-4
- Any S/G flow mismatch 10 CF flow alarm on 1AD-4 1AO LIT.
Case II. Loss Of Normal CA Supply:
- Any CA Auto Start 1AO-5, H/4 "CACST LO LEVEL" - LIT
- 1AD-5, 1AD-8, 8/1 "UST LO LEVEL" - LIT.
- 1AO-8,
CNS LOSS OF S/G FEEDWATER PAGE NO. AP/1/A/55001006 AP/1 IA155001006 2of20 2 of 20 Case I Rev 40 DCSDC~ Loss of CF Supply To S/Gs ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. C. Operator Actions
-0 Verify reactor power-l£SS,THAN5%. IF AT ANY TIME all CF supply to 5/G(s) lost, THEN perform the following:
S/G(s) IRQ I a. Manually trip reactor.
- b. GO TO EP/1/A/5000/E-0 EP/1/A15000/E-0 (Reactor Trip Or Safety Injection).
- 2. Veri;fy;,aU S/G;hiwhi level alert ~Ia.rms V~~!fY]~II~/G'flHflil~M~lal~rt alarms IF 2/4 S/G N/R levels on anyone 5/G 214 5/G S/G are IROII (1.6(1)l).~~.,*D.6(R.~J (1AD\4) w DARK. greater than 83%, THEN:
- a. Verify all Feedwater Isolation status (1 SI-5) - LIT.
lights (1SI-5)
- b. IF any Feedwater Isolation status light is not lit, THEN:
_ 1) Manually initiate Feedwater Isolation. _ 2) IF proper status light indication is not obtained, THEN manually close affected valve(s).
\f~tifYJgtaIC.6(i:flgWi~GR..ES.6(~pR.TI--I.6(N Verify tofal CAflow "GREATER THAN Perform the following:
450 GPN!; 4.50 GPM. rvlallLJa.lr¥:.§~aqf~~P4miP§' a; ManuallystartGApurnps. a. M<:IOuall*y**Ettig.OG~yal&<?($')c:l!?
- b. Manually alignGA valve(s)as *. *r~ql.lil'~9 required CAPT #1 should have toestablish.1'Io"W:
to establish flOW. been secured already and since B train has no power and A CA pump autostart is failed, they will start A CA manually.
CNS LOSS OF S/G FEEDWATER PAGE NO. AP/1/A155001006 AP/1/N55001006 3 of 20 Case I Rev 40 DC~ Loss of CF Supply To S/Gs ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED GontrorS15]evelsasfdlldws: Control S/G levels as follows: a .MerifM~II$/(j3N/R.,leve!I~bG~E>>'T~R
- a. Verify all S/G N/Rlevels:- GREATER a. Maintain total feed flow greater than TH*,N"'**'*.~~%.
THAN 11%. 450 GPM to intact S/Gs until at least one S/G N/R level greater than 11 %. b.WHEN
- b. WHEN ,*atleastr0ne:S~GNZ~'le.vel'ls at least:one'S/G N/Rlevel is greater than,11 %,
- THEN.,.*.ttl~~ft!.~*.feeg greqt~l"tnat:}'i;lnCYo, THEN thrqttle feed fl~wtQ".hlaiJn~i~'i;lu.rS/c:?'*:lf:\I~B.le.vels flow tomaintail"iall SfG N/Rlevels oetween.\1~%I.'+'50%;
between 11 % - 50%:
- 5. REFER . me>,,(ia§e>II':lLo!?!?'f.QfNQrroal(iA 5.REItER TO Case II (Loss}of Normal CA NOT REQUIRED Supply).
§upplYll
- 6. *En$i,J.te:G~l)')pri.Qr1'cewitflQPptQPr'iQ~e Ensure compliance withapptopriate T.e~I:(I§peQ$a!l(:t Ter;hSpecs and I,SL(i!?;: SLCs:
TS 3.3.2 Item 6a, Condition H
~'~.lt(~SP>>'S**1
- 3.3.2 nstl'url);et:}ti;l(IQt:})
(ESFAS Instrumentation)
*.~;*;5(~~*iH~ryFeegWCiters¥!?t~m~
3.7.5 (Auxiliary Feedwater System)
- SLC 16;'7.1 (AMSAC).
7; Determine required notifications: REFERme>"~F'/0ZN50Q.0za01
- REFERTO RP/O/Al50001001 (Cla.~si~iq~tiQt:l)<3>f"~rm:el"get:l.qM)
{Classification Of EI:nergency) REFER TO .gF'Zot13/5000/0'j~(NB.C
- REliEIlm0 RP/O/B/50001013 (NRC f:\IQtifica!jQt:l';B.eglJir~rm:en.l~);
*Notification Requirements).
8. 8i** ~e~e.rroi.r1ear1g(Q~r'reQtIQQg$e;of.IQ$!?.Qf Determine and: correct cause* of loss of (iFsUPRIY; CF supply.
- 9. Verify at least one CF Pump - ON. _ Perform a hot flat restart of one Git CF Pump.
REFER REitER me> e>P/1/A16250/001 (Condensate TO OP/1/A16250/001 (Gondensate and Iteedwater Feedwater System).
CNS LOSS OF S/G FEEDWATER PAGE NO. AP/1/A/5500/006 AP/1/A/55001006 4 of 20 Case I DC~ Rev 40 DCS Loss of CF Supply To S/Gs ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. P~t~rmit1~I()t1gt~rm"RI~f:1f$l~Jg~;
Determine long term plant status. RETOURN?'1'Opfo<?ed RETURN .I,J.*t:~i*tI*eff~<?Jl TO procedure in effecb
MAJOR EVENT IMAJOR EVEN"T START Initiating cue: 1AD-3, N1 !Initiating AJ1 I I I I L _ _ _ _ _ _"_ _ _ _ _ _ _ _ _ _ "
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/A15000/E-O 1 of 61 DC~ Rev 36 DCS A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 5/1 above P-11, valid 5/1 below P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 EP/1/A/5000/E-0 2 of61 of 61 DC~ Rev 36 DC:: B. Symptoms or Entry Conditions
- 1. The following conditions are symptoms that require a Reactor Trip:
- 1 of 2 SIR channels - GREATER THAN 105 CPS WHILE BELOW P-6
- 1 of 2 21!R I/R channels - GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10
- 2 of 4 P/R channels - GREATER THAN 25% FULL POWER WHILE BELOW P-10
- 2 of 4 P/R channels - GREATER THAN 109% FULL POWER
- 2 of 4 P/R channels - +5% FULL POWER IN 2 SECONDS
~Ts - GREATER THAN THE OPL1T
- 2 of 4 loop L1Ts OP~T SETPOINT
- 2 of41oop ~Ts - GREATER THAN THE OTL1T of 4 loop L1Ts OT~T SETPOINT
- 2 of 4 Pzr pressure channels - GREATER THAN 2385 PSIG
- 2 of 4 Pzr pressure channels - LESS THAN 1945 PSIG WHILE ABOVE P-7
- 2 of 3 Pzr level channels - GREATER THAN 92% WHILE ABOVE P-7
- 2 of 4 S/G N/R level channels on 1 of 4 S/Gs - LESS THAN LO-LO SETPOINT
- 2 of 4 NC pump buses - LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7
- 2 of 4 NC pump buses - LESS THAN 56 HERTZ WHILE ABOVE P-7
- 2 of 3 NC flow channels on 2 of 4 NC loops - LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8
- 2 of 3 NC flow channels on 1 of 4 NC loops - LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8
- 4 of 4 turbine stop valves - CLOSED WHILE ABOVE P-9
- 2 of 4 turbine stop valves EHC pressure - LESS THAN 550 PSIG WHILE ABOVE P-9
- 1 of 2 S/I SII trains - ACTUATED
- 2 of 2 SSPS trains - GENERAL WARNING ALARM.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O EPf1 fA/5000fE-O 30f61 3 of 61 DC~ Rev 36 DCt
- 2. The following are symptoms of a Reactor Trip:
- Any Reactor Trip annunciator - LIT
- Neutron level-level - RAPIDLY DECREASING
- Rod bottom lights - LIT.
- 3. The following are symptoms that require a Reactor Trip and 511:
- 2 of 4 Pzr pressure channels - LESS THAN 1845 PSIG
- 2 of 3 containment pressure channels - GREATER THAN 1.2 PSIG.
- 4. The following are symptoms of a Reactor Trip and 511:
- Any S/I Sfl Reactor Trip annunciator - LIT
- NV, NI, and ND pumps - ON
* "SAFETY INJECTION ACTUATED" status light (1SI-13) - LIT
- EfS E/S Load Sequencer Actuated status lights (1SI-14) - LIT.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/N5000/E-O 4 of 61 40f61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- c. Operator Actions C. RO DOES FO ~.~A_G_E_ __
THIS PAGE DOES THIS
- 1. Monitor Enclosure 1 (Foldout Pa.ge).
o _
"~rifY,'~~actorE1iijiFi; Verify Reactor Trip:
.~II
*. All tdqt>dij6roHgIjjX~::?LIT rod bottom /ights- LIT Perform the following:
- a. Manually trip reactor.
_ *.~IJ*rea<:torlripg@qit>ypa~~l::t>F~aJ~ers All reactor trip and bypass breakers - b. IF reactor will not trip, THEN OPEN GPEN concurrently:
- IIR amps - DECREASING.
- Implement EP/1/A/5000/F-O EP/1/N5000/F-O (Critical Safety Function Status Trees) .
- GO TO EP/1/A/5000/FR-S.1 EP/1/N5000/FR-S.1 (Response To Nuclear Power Generation/A Generationl ATWS).
TWS). G)
@ Verify Turbine Trip:
*V.ei'ifYTfu".blhe]ripl Perform the following:
- P511tt.lrbit1est~p:V~IMes:.,QI.i~SEO All turbine stop valves - CLOSED a. Manually trip the turbine.
- b. IF turbine will not trip, THEN:
_ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.
- 3) IF turbine will not run runback, back, THEN close:
- All MSIVs
- All MSIV bypass valves.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O 5 of 61 50f61 Rev 36 DC~ I ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED -0 VerifY 1ET~afid:1ETB _0~~r;iftsJ~;e:1l4c{a'~.¥~jO§g,~R~1~qg~
..:ENERGIZED. Perform the following:
BOP DOES THIS PAGE IBOP --l a. IF 1ETA AND 1ETB are de-energized, THEN GO TO EP/1/A15000/ECA-O.O 1ETB is NOT (Loss Of All AC Power). energized
- b. WF:lBNlijj~~tloW~foi[a8tT.~~pt~lq:
WHENrtime allows, THEN attempt.to r:~~QtEt~Q~~tQ:~~~~.t.M~~ restore power to de-energized s.*.wj:fen"'Iiat,wl;illeA",¥&.,r~'iM!ml?'lWli'ilttiithls switchgear
._./;,> " **,,:J:'/.'d~~"*'/ ,c_,while continuin*g,with
..~1k~~:-'k;;~_tJ~~; .)~k:'UJ,,*-'W~this
":.'. ,',~'
'prQJI\~(.flJj~~j*eEfmR*1f~
procedure. REFER TO iJVD.</' 'ft"Wlhlr;J;:QQ.ill!fm~?l1lg&"""""~""'iIi\'r~Q'lc AP/1/A15500100T(Loss of Normal
- ~~ ..:*1,f~;~~~~ ~i~~;,?~§.m~1XJ?lM).Hft~5!.c:-
'po~)i Power). @ VerifY S/I.is actuated:
- a. "SAFETY INJECTION ACTUATED" a. Perform the following:
status light (1 SI::'13)- LIT.
- 1) Verify conditions requiring SII:
_ . Pzr pressure - LESS THAN 1845 PSIG OR _ . Containment pressure - GREATER THAN 1.2 PSIG. _ 2) IF SII is required, THEN manually initiate S/I.
- 3) IF SII S/I is not required, THEN concu rrently:
concurrently: _ .* Implement EP/1/A15000/F-O (Critical Safety Function Status Trees) . Trees).
- GO TO EP/1/A15000/ES-O.1 (Reactor Trip Response).
- b. BothE/$;l9aqsequencer actuated b. Manually initiate S/I.
status lights (1SI~14) - LIT. They may choose to manually initiate
- 6. Arinoun'ce "Unit 1'Safety Injectl()n~':. SII S/I but the B sequencer breaker was opened previously and this step will not accomplish anything.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/AlSOOO/E-O EP/1/N5000/E-0 6 of61 of 61 DC~ Rev 36 DC!: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. DeterminE! required' notificati()ns:;
- REFER TO RP/0IN50001001 (Classification Of Emergency)
- REFER TO. RP/O/B/50001013 (NRC Notification Requirements).
- 8. Verify all Feedwater IsgIation status Perform the following:
fRo I lights (151-5) -LIT.
- a. Manually initiate Feedwater Isolation.
- b. IF proper status light indication is not obtained, THEN manually close valves.
Verify Phase A Containment Is()lation
*~tatus asJoliows:
_ tl!l
- a. '~Ii~~;~f~fi§~I7"1~;:lill\);~iI~_i Phase A "RESET" lights- DARK. a. Manually initiate Phase A Isolation.
_ b. irtJ~iihi$;:;;J):41;:ihtil:l>";nel;i:Gr:ot1l""'15;~$iFli*':'l\'ts**r;t Monitor Light f>anel Group
; .~'~W$\~**",J~.*,*",,, .. ",."f):/5.' St
,,,,,, ..lights
,t!lSL .. ' '0- b. :MEitilI2lnYIIIJgf)1~~~1~~;
b;. Manually align valves. LIT. blJf4 1BB-56A has failed to close and B train BB valve is not closed
- 10. Verify pr.oper Phase B actuatiorras due to loss of power, so there is a direct path from containment.
IBOP I follows:
- a. Containmentprel?p,ufe~,HAS a. Perform the following:
REMAINED LESS THAN 3 PS!G. This time may be used later to determine when to align ND NO Aux spray. _ 1) Record approximate time of reactor trip. _ 2) Verify NS pumps -INDICATING
- INDICATING FLOW.
_ 3) IF flow is not indicated, THEN manually initiate Phase B Isolation for affected train(s). (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/A15000/E-O 7of61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued)
- 4) Verify Phase B 8 Isolation has actuated as follows:
_ a) Phase B 8 Isolation "RESET" lights - DARK. _ b) IF Phase B 8 Isolation "RESET" lights are lit, THEN manually initiate Phase B 8 Isolation. c) Verify following monitor light panel lights - LIT:
- Group 1 Sp lights
- Group 5 Sp lights U11 and
- Group 5 St lights Ll11 Ll12.
_ d) IF monitor light panel not in correct alignment, THEN ensure correct alignment. e) IF NS pump(s) did not start, THEN perform the following for the affected train(s): _ (1) Reset ECCS. _ (2) Reset DIG load sequencer. _ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a 8/0 B/O SII occurs, THEN restart S/I equipment previously on. _ 5) Stop all NC pumps. _ 6) Maintain seal injection flow. _ 7) Energize H2 igniters. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 80f61 DC~ Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued) 8} Dispatch
- 8) operator to perform Dis/Datch o/Derator /Derform the following:
_ a) a} Secure all ice condenser air handling units. REI?'ER REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ b} Place containment H2 b) REI?'ER analyzers in service. REFER TO OP/1/A/64501010 OP/1/A/6450/010 (Containment Hydrogen Control Systems). _ 9} WHEN 9 minutes has elapsed, 9) THEN verify proper VX system REI?'ER TO Enclosure 7 operation. REFER (VX System Operation). _10) GOTO _10} GO TO Step 11. b .1
. *FAT ANY TIME.c~(jtaimrn~filti'r!lEe$l?tJije 1?'::.A.m .A.N¥ TIME .containment pressure e*¢e~dS~P$lqvvhil~. *.jl(jthisr!lijifj¢~QtJrei exceeds3PSIGwhile .jn this wocedure, mHENr!let;for'rnst~p THEN 10:~,
perform Step 10.a. 11..M~~jfYproper~J(p.ul'np~tcit~~a~/fQUqV'is: 11 Verify proper CA pump status asfollows:
- a. lY1~t~r.dr'i\?el.1~.t\/DumpS;'rON; Motor driven CA pumps - ON. a. Perform the following for the affected train(s}:
train(s): _ 1) 1} Reset ECCS. No B train power so should not go to RNO. _ 2) 2} Reset D/G DIG load sequencer. _ 3} Manually start affected motor driven 3) CA pump. _ 4) IF 4} II?'.A.T ANY TIME a B/O occurs, AT .A.NY THEN restart S/I SII equipment previously on. b.aj's/<aN/IRle\?els*.;.*~~E~TEZ~"]"HAN
- b. 3jS/G N/R levels - GREATERTHAN b. Ensure CA Pump #1 - RUNNING.
11%. 11'%.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O 9 of 61 90f61 Rev 36 DC~ ACTIONIEXPECTED ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 12. Ve~ify~JliQf't~efoUQWingiSfl'PtimpsHQN:
Verify aU of the following 5/1 pumps -ON: R~,ijQ~mth.~.foIIQWIij9f9".**af{~cl~d Perform the following for affected lr~in(~l: train(s): IBOP I -.c""
- NV p'umps NV'p'l,.Imw§
** ND pumps
~DWUlO1WS a, Re$et*'E:PC~.
- a. Reset ECCS.,
.' fI;llptlrnWs:
NI pumps. 1A NO P 1AND pump um p] must be Ri3$etr::>/GI()capsEJ~LJence(.
- b. ResetD/Gloadsequencer.
b, manually started. I CRITICAL TASK!I TASK! c. Manually
- c. IY1Eif1.\1~IIY$tart~1:fl:lqtEJP****',WuttlW; start affected pump.
d.;IF;*~m'.AN¥mIM*E*.~i*EJIQ,.()qcl,.lrs;mIl'lEN*
- d. IFATANY TIME a B/Ooccurs, THEN re§tEimpJl.***eqt.iiWrni~rltpf"~yidLJ$IY'orj; restart SllequipmentptevioLisly on.
- 13. Verify alkKC pumps .;ON~ Perform the following for affected train(s):
~O~ No B train power so should not go to RNO. a. Reset ECCS.
- b. Reset DIG load sequencer.
- c. Manually start affected pump.
- d. IF IF.AT ANY TIME a BIO occurs, THEN AT .ANY TIl'IEN restart S/I equipment previously on.
jU'-' I 14..V~tifYalll;Jiji~:\~a.nd!\iliji~ 14 VerifyaliUnit.1 and ,Unit * .* 2 ~.* RN,'*.p~mp$:.r RN pumps .. Perform the following: ClN; ON.
- a. IF any Unit 2 RN pump is off, THEN TIl'IEN No B train power so manually start affected pump(s).
should not go to RNO.
- b. IF any Unit 1 RN pump is off, THEN TIl'IEN perform the following for affected train(s):
_ 1) Reset ECCS. _ 2) Reset DIG load sequencer. _ 3) Manually start affected pump. _ 4) IF AT .ANY IF.AT ANY miMETIME a BIO occurs, THEN restart SII equipment TIl'IEN previously on.
- 15. Vg~ifY,prQpg~~gnlil~~iQo**~ystgro!i Ve~ify proper ,ventilation systems Qpgr~tidij~~fQIIQW$:
operation asfoJlows:
- REFEe::mQ"l;;m~I.9sl,.lt~ ** 2
.REFERTOEncl,osur$ (Ventilation f(VentjIEiti.()r"1 Systerni'Vi3:rip~~!I()mJ.;
System Verification) .
*.***~()tifyi,l;fr"1jlJ~J9J>~rEi'9~tC)
Notify Unit 2 operator to **J>.~.rf()rrn! perform EhG)IQ§l1!t~{~(~WWQ$itel;fni.tVet;jtilcatiQr"1 Enclosure 3 (Opposite Unit Ventilation
\/el'ip~'i.QnI~
Verification ).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/A/5000/E-0 10 of 61 Rev 36 OCS DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 16. Verify all 5/Gpressures
- GREATER l?ertdrm*.**.the.loll~w:ii'19i Perform the following:
THAN 775P51G. IRO i a;"erlfytheJoIIQWif:1gya~y~s"':QLOSEO!
- a. Verify the following valx~s - CLOSED:
- All MSJVs lI'AIIMS1Vls
_.~II:I'v'ISI"I:l.ypassyalv~~ _
- AIIMSIV bypass valves
- All S/G PORVs.
.*AlI*S/GPORVs.
- b. IF any valve is open, THEN:
_ 1) Manually initiate Main Steam Isolation. _ 2) IF any valve is still open, THEN manually close valve.
- 17. Verify proper 5/1 flow as follows:
I ~~'""1 ~-::-:::::--; IBOP a. Manually start NV NVI pump(s) and align
- a. "NYSII FLOW" -INDICATING FLOW.
valves.
- b. NC pressure .. LESS THAN 1620 PSIG. b. Perform the following:
_ 1) Ensure ND NO pump miniflow valve on operating NDNO pump(s) - OPEN.
- 2) IF NDNO pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):
_ a) Reset ECCS. _ b) Reset D/GDIG load sequencer. _ c) Stop ND NO pump. _ d) IF AT ANY TIME a BIO B/O occurs, THEN restart S/I equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND NO pump. _ 3) GO TO Step 18.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 11 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 17. (Continued)
NlplJ(t;lps.,.IN(:lIC~WIN(3:Fl-QW.
- c. NI pumps -INDICATING FLOW. c. Manually start NI pump(s) and align valves.
IBOP ! !R,()P I
- d. NQpressure -LESS THAN 285PSIG. di Perform lhefqUowil'@i
- d. the following:
_ Ensuf'~Nl#pYi11prIJiflilfqwval\le*qn
- 1) Ensure ND pump miniflow'valve on qp~l"qtjflg operating *f'&~PLJi11p(s)~QPEN.
ND pump(s)- OPEN.
- 2) IF the ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):
_ a) Reset ECCS. _ b) Reset DIG load sequencer. _ c) Stop ND pump. _ d) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18.
- e. ND pumps --INDICATING INDICATING FLOW TO e. Manually start ND pump(s) and align C-LEGS. valves.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/A1S000/E-0 12 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 18*~}MfM'~I~t~J~~a~~1@1'.W~~
- 18. Contro(S/G levels as follows:
jsop _ :f~;I~rlf¥ltQtIj!fm.~~.,c<i1l~~1Ke~~~~~
- a. Verify:,totaIGA floW- GREATER THAN a. Perform the following:
1..--.----1 l(la<<i: ** 4'Q0 GPM. _ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.
- 2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 4S0450 GPM cannot be established, THEN concurrently:
_ .* Implement EP/1/A1S000/F-0 EP/1/A/5000/F-0 (Critical Safety Function Status Trees) . EP/1/A/5000/FR-H.1
- GO TO EP/1/A1S000/FR-H.1 (Response To Loss Of Secondary Heat Sink).
- b. WHEN at least one S1G N/R level is, grea,ter than 11% (29% ACC):,THEN throttle feed flow to maintain all S/G NIH levels between 11 % (29% ACC) and 50%.
- 19. Verify ~nCAisolation Valves* OPEN. _ Manually open valve(s).
Verify Sllequiplj1entstatus based on _ Manually align equipment. mOriitor light p~nel
- IN PROPER ALJGNMi:NT.
EncJosure4 (NC Temperature Control) shall remain in eff~ct until subsequent procedures provide alternative NC temperature control guidc3nce.
~-J
- 21. Control,NC temperature. REFER,TO Encl~~Vfe 4 (NC Temperature Contr'pl).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O EP/1 I A/5000/E-O 13 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED V~ti~P~r'P<:>R.V'iitlldfpzr.*spr'aY'.:yaIV~ Verify Pz;rPORV ,and'Pzr spray.valve status as follOWS:*' status follows:*
- a. All Rzr PORVs - CLOSED. a. IF Pzr pressure is less than 2315 PSIG, THEN:
_ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve.
- 3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:
_ a) Energize H2 igniters. b) Dispatch operator to perform the following: _ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1/A164501010 OP/1/A/64501010 (Containment Hydrogen Control Systems). (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/A15000/E-0 14 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. (Continued) c} IF both the following conditions c) exist,
- Containment pressure -
GREATER THAN 1 PSIG
- Containment pressure - HAS REMAINED LESS THAN 3PSIG
_ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently: d}
- Implement EP/1/A/5000/F-0 EP/1/A15000/F-0 (Critical Safety Function Status Trees).
- GO TO EP/1/A/5000/E-1 EP/1/A15000/E-1 (Loss Of Reactor Or Secondary Coolant).
- b. NormalPzr spray valves - CLOSED. b. IF Pzr pressure is less than 2260 PSIG, THEN:
_ 1) Manually close spray valve(s}. 1} valve(s). 2} valve(s} cannot be closed,
- 2) IF spray valve(s)
THEN: _ a) a} Stop NC pumps 1A and 1B. 1B. _ b) IF NC pressure continues to b} decrease, THEN stop third NC pump as required.
- c. At leastone. **F'Z;nF'O",*\lts~latiQl1valVe~
At*lefil.$t:Qi'i~ pzr PORVisolation valve- c. IF power is available, THEN open one OPEN; OPEN. Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV.
¥~~i~::N~*$gI)P9Qli*qg}I)~$~g91j1.c9~~e5(if Verify NC.subcooli fl 9 based on core exit IF any NV OR NI pump is on, THEN:
TICs .;.. GREATER THAN O°F. T/Gs.;;'GRE~TERTH~N***OQF'~.*.*
- a. Ensure all NC pumps - OFF.
- b. Maintain seal injection flow.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/11A15000/E-O 15 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 24 .\t'i:tri.IYrn~iij$ti:t~mUni:t.s~reinf~Qt:a$
- 24. Verify main steamlines are intact as :lfi~t~.$.$l!r~lnanySfGisd~ci'i:ta$il)gln IF Pi;~,s~ure in any SfG is decreasing in follOws:
follows: ~l)l(ij~Ql)tr()lled:tnan clnudCi:)ntrolied l1~r0RanySZC;ls manner ORany S/Gis d~pres~urized, THEN
~i:t~ri:t$$Priz:i:td,orFi perform the ENperforrnthi:t
_ .** *,*II:~/G*j:;)r~§$UresOi:Sm,*BUWQR AIIS/G pressures - STABLE OR following:
.JolloWiijgl INCREASING INCREASlt\JG
- a. IFlfi both the following conditions exist,
.**ALt*8/<3s+RRESSLJRIZED.
- ALLS/Gs - PRESSURIZED.
- Containment pressure - GREATER THAN 1 PSIG
- Containment pressure - HAS REMAINED LESS THAN 3 PSIG
_ THEN manually start one VX fan. REfiER REFER TO T0 Enclosure 5 (VX Fan Manual Start). C6[1d!\rr~nt!y:
- b. Concurrently:
_
- lmj:;)J~trl~l1tERI1IA15000lF Implement EPf1/A15000/F-O (Critical
..q:i(Ctitical Saf~t5'Fi.lnctiQn.Status]'re~§J1 Safety Function Status Trees).
_ .G01"Oil;:F?/11A15000fE-~*(l?aUlted
- GOTOEP/1/A15000/E-2 (Faulted
~t~C3.rl':rGeneratorlsOlati()~);
Steam Generator Isolation).
- 25. VerilY S/G tubes are intact as follows:
Verify IF any EMF trip 1 light is lit OR 0R any S/G level is increasing in an uncontrolled
- Verify the following EMF trip 1 lights - manner, THEN concurrently:
DARK: _ .* Implement EP/1/Al5000/F-O EP/1/A15000/F-O (Critical
- 1EMF-33 (Condenser Air Ejector Safety Function Status Trees).
Exhaust) _ .* G0 GO T0 EP/11A15000/E-3 (Steam TO EP/1/A15000/E-3
- 1EMF-26 (Steamline 1 1A)
A) Generator Tube Rupture).
- 1EMF-27 (Steamline 1B)
- 1EMF-28 (Steamline 1C) 1EMF-29 (Steamline 10).
- 1EMF-29 1D).
- All S/G levels - STABLE OR INCREASING IN A CONTROLLED MANNER.
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- 26. Verify NC System is intact as follows:
- a. Verify the following NC pump thermal a. Perform the following:
barrier alarms - DARK:
- 1) Ensure the valve for the affected
- 1AD-6, E/1, "NCP A THERMAL NC pump(s) - CLOSED:
BARRIER KC OUTLET HIILO FLOW"
- 1KC-394A (NC Pump 1 1A A Therm Bar Otlt)
- 1 AD-6, E/2, "NCP B THERMAL 1AD-6, BARRIER KC OUTLET HIILO
- 1KC-364B (NC Pump 1B Therm FLOW" Bar Otlt)
- 1AD-6, E/3, "NCP C THERMAL
- 1KC-34SA KC-345A (NC Pump 1C Therm BARRIER KC OUTLET HIILO Bar Otlt)
FLOW"
- 1KC-413B (NC Pump 1D Therm
- 1AD-6, E/4, "NCP D THERMAL Bar Otlt).
BARRIER KC OUTLET HIILO FLOW". 2) IF the valve for the affected NC pump will not close, THEN perform the following: _ a) Trip all NC pumps. (RNO continued on next page)
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- 26. (Continued) b) Perform the following:
_ (1) Dispatch operator with radio to standby at 1KC-425A KC-42SA (NC Pumps Ret Cant Isol) (AB-588, Hdr Cont (AB-S88, GG-52, Rm 419) (Ladder GG-S2, needed). _ (2) Close 1KC-425A KC-42SA (NC Pumps Ret Hdr ContCant Isol) from Control Room. _ (3) IF 1KC-425A KC-42SA (NC Pumps Ret Hdr Cont Cant Isol) will not close completely from Control Room, THEN have operator locally close 1KC-425A KC-42SA (NC Pumps Ret Hdr Cont Cant Isol) (AB-S88, (AB-588, GG-S2, GG-52, Rm 419). _ (4) WHEN 1KC-425A KC-42SA (NC Pumps Ret Hdr CantCont Isol) has been closed, THEN close 1KC-424B (NC Pumps Ret Hdr ContCant Isol). _ (5) (S) WHEN 1KC-425A KC-42SA (NC Pumps Ret Hdr CantCont Isol) is closed, THEN notify the dispatched operator to return. (6) Close the following valves:
- 1KC-338B (NC Pumps Sup Hdr Cont Cant Isol)
- 1KC-430A (Rx Bldg Drn Hdr Cont Cant Isol)
- 1KC-429B (Rx Bldg Drn Hdr Cont Cant Isol).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 EP/1/A/5000/E-0 18 of 61 DC~ Rev 36 DC:::: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 26. (Continued)
- b. Verify NC System is intact as follows: b. Perform the following:
_ .* Containment pressure - LESS THAN _ 1) Energize H2 igniters. 1 PSIG.
- 2) Dispatch operator to perform the
_ .* IF normal off-site power is available, following: THEN verify containment pressure less than 0.3 PSIG. _ a) Secure all ice condenser air handling units. REFER TO
- Containment high range EMFs - Enclosure 13 (Securing All Ice LESS THAN 3 RlHR: Condenser Air Handling Units).
_ . 1EMF-53A (Containment Trn A) _ b) Place containment H2 analyzers _ . 1EMF-53B (Containment Trn B). in service. REFER TO OP/1 IA/6450101 0 (Containment OP/1/A164501010
- Containment EMF trip 1 lights - Hydrogen Control Systems).
DARK:
- 3) IF both the following conditions
- 1EMF-38 (Containment exist, Particulate)
- 1EMF-39 (Containment Gas)
- Containment pressure -
GREATER THAN 1 PSIG level-- STABLE.
- Containment sump level
- Containment pressure - HAS REMAINED LESS THAN 3 PSIG
_ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start).
- 4) Concurrently:
EP/1/A/5000/F-0
- Implement EP/1/A15000/F-0 (Critical Safety Function Status Trees).
EP/1/A/5000/E-1 (Loss
- GO TO EP/1/A15000/E-1 Of Reactor Or Secondary Coolant).
- 27. Verify 5/1 SII termination criteria as follows:
- a. NC subcooling based on core exit TICs a. GO TO Step 28.
- GREATER THAN O°F. OaF.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/A15000/E-0 19 of 61 DC~ Rev 36 DC!: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- b. Verify secondary heat sink as follows: b. GO TO Step 28.
NIR level in at least one S/G
- N/R SIG -
GREATER THAN 11% OR
- Total feed flow to S/Gs SIGs - GREATER THAN 450 GPM.
- c. NC pressure - STABLE OR c. GO TO Step 28.
INCREASING. level-- GREATER THAN 11
- d. Pzr level 11%.
%. d. Perform the following:
_ 1) IF NC pressure is increasing AND normal Pzr spray is available, THEN attempt to stabilize NC pressure using normal Pzr spray. _ 2) RETURN TO Step 27.a. SII - RESET:
- e. Ensure S/I
_ 1) ECCS. 1) Perform the following: _ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ b) Concurrently implement Enclosure 8 (ECCS Master Reset) while continuing in this procedure. _ 2) DIG load sequencers. 2) Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA)
(AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB)
(AB-560, BB-46, Rm 372). _ 3) IF AT ANY TIME a B/O occurs, THEN restart S/ISII equipment previously on.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 20 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- f. Ensure only one NV pump - ON.
_ g. Verify NC pressure - STABLE OR g. Perform the following: INCREASING. _ 1) Implement EP/1/A15000/F-0 (Critical Safety Function Status Trees). _ 2) GO TO EP/1/A15000/ES-1.2 (Post LOCA Cooldown And Depressu rization). Depressurization).
- h. Verify VI pressure - GREATER THAN h. In subsequent steps, control room 50 PSIG. control is lost for the following valves and local operation will be required:
- 1NV-294 (NV Pmps A&B Disch Flow Ctrl)
- 1NV-309 (Seal Water Injection Flow).
- i. Isolate NV S/ISII flow path as follows:
flowpath
- 1) Verify the following valves - OPEN: 1) Perform the following:
- 1NV-203A (NV Pumps A&B _ a) Open affected valve(s) valve(s)..
Recirc Isol) _ b) IF 1NV-203A AND 1NV-202B
- 1NV-202B (NV Pmps A&B Recirc are open, THEN GO TO Isol). Step 27.i.2.
c) Dispatch operator to open affected valve(s):
- 1NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)
- 1NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed).
_ d) Close 1NV-309 (Seal Water Injection Flow). (RNO continued on next page)
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- 27. (Continued) e) IF control of 1NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:
_ (1) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ (2) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps. f) Open the following valves:
- 1NV-312A (Chrg Line Cont Isol)
- 11NV-314B NV-314B (Chrg Line Cont Isol).
g) IF 1NV-312A OR 1 NV-314B cannot be opened, THEN dispatch operator to open the affected valve(s). Refer to the following enclosure(s) for the affected valve(s):
- Enclosure 10 (Locally Open 1NV-312A)
- Enclosure 12 (Locally 1NV-314B).
Open 1NV-314B). _ h) Do not continue in this procedure until 1 NV-312A and 1NV-314B are open. _ i) IF NC pressure is greater than 1950 PSIG, THEN throttle 1NV-309 or 1NV-311 to 50% open. (RNO continued on next page)
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- 27. (Continued)
_ j) Open 1NV-294 (NV Pmps A&B Disch Flow Ctrl). k) k} IF control of 1NV-294 is lost from the control room, THEN: _ (1) Place the controller for 1NV-294 in the 100% demand position. _ (2) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) to control charging flow as required in subsequent steps. I} I) Close the following valves:
- 1NI-9A (NV Pmp C/l Inj Isol)
- 1NI-10B (NV Pmp C/l Inj Isol).
m} m) IF 1 NI-9A OR 1NI-1 OB cannot be closed, THEN dispatch operator to close the affected valve(s}. Refer to the following valve(s). enclosure(s} for the affected enclosure(s) valve(s): valve(s}:
- Enclosure 9 (locally Close 1NI-9A)
- Enclosure 11 (locally Close 1 1NI-10B).
N 1-1 OB). n) Throttle charging and seal n} injection to maintain the following:
- Charging line flow between 60 GPM and 180 GPM
- NC pump seal injection flow.
(RNO continued on next page)
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- 27. (Continued)
_ 0) WHEN 1NV-203A AND 1NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ p) GO TO Step 27.k.
- 2) Close the following valves: 2) Dispatch operator to close the affected valve(s). Refer to the
- 1NI-9A (NV Pmp C/l Inj Isol) following enclosure(s) for the
- 1NI-1 OB (NV Pmp C/l Inj Isol). affected valve(s):
- Enclosure 9 (locally Close 1NI-9A)
- Enclosure 11 (locally Close 1 NI-1 OB).
- j. Establish charging as follows:
_ 1) Throttle 1NV-294 (NV Pmps A&B 1) Perform the following: Disch Flow Ctrl) for 32 GPM charging line flow. _ a) Place the controller for 1NV-294 in the 100% demand position. _ b) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551 (AB-551,, JJ-55, Rm 231) for 32 GPM charging line flow. _ c) Throttle 1NV-295 to control charging flow as required in subsequent steps. _ 2) Close 1NV-309 (Seal Water 2) Dispatch operator with radio to Injection Flow). perform the following: _ NV-308 (Seal Wtr Inj a) Close 1NV-30B Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (ladder needed). _ b) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 24 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- 3) Open the following valves: 3) Dispatch operator to open the affected valve(s). Refer to the
- 1NV-312A (Chrg Line Cont Isol) following enclosure(s) for the
- 1NV-314B 1NV-314B (Chrg Line Cont Isol). affected valve(s):
- Enclosure 10 (Locally Open 1NV-312A)
- Enclosure 12 (Locally Open 1NV-314B).
_ 4) Verify 1NV-309 - ABLE TO BE _ Step 27.j.6.
- 4) GO TO StP OPERATED FROM THE CONTROL ROOM.
_ 5) Place 1NV-309 in auto.
- 6) Perform the following:
- Maintain charging flow less than 180 GPM.
- Maintain 32 GPM seal water flow.
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- 27. (Continued)
- k. Control charging as follows:
_ 1) Control charging flow to maintain Pzr level stable. _ level-- STABLE OR
- 2) Verify Pzr level 2) IF Pzr level is decreasing, THEN:
INCREASING. a) Open the following valves:
- 1NI-9A (NV Pmp C/l Inj 1501)
Isol) 1NI-1 OB (NV Pmp C/l Inj _ . 1NI-10B Isol). b) Close the following valves:
- 1NV-312A (Chrg Line Cont Isol)
- 1NV-314B (Chrg Line Cont 1501).
Isol). _ c) Implement EP/1/A15000/F-O EP/1/A/5000/F-0 (Critical Safety Function Status Trees). _ d) GO TO EPI1IA15000/ES-1.2 EP/1/A/5000/ES-1.2 (Post lOCA Cooldown And Depressurization ). I. Ensure the following containment isolation signals - RESET: Phase A
- PhaseA
- Phase B.
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- 27. (Continued)
- m. Establish VI to containment as follows: m. Perform the following:
- Ensure 1VI-77B (VI Cont Isol)- 1) Align N2 to the Pzr PORVs by OPEN. opening the following valves:
- Verify VI pressure - GREATER THAN
- 1NI-438A (Emer N2 From CLA A 85 8S PSIG. To 1NC-34A)
- 1NI-439B (Emer N2 From CLA B To 1NC-32B).
_ 2) IF VI pressure is less than 85 8S PSIG, THEN dispatch operator to ensure proper VI compressor operation.
- n. Concurrently:
- Implement EP/1/A15000/F-0 EP/1/A/SOOO/F-0 (Critical Safety Function Status Trees).
- Monitor EP/1/A15000/ES-1.1 EP/1/A/SOOO/ES-1.1 (Safety Injection Termination), Enclosure 1 (Foldout Page)
- GO TO EP/1/A15000/ES-1.1 EP/1/A/SOOO/ES-1.1 (Safety Injection Termination), Step 12.
- 28. Implement EP/11A1S000/F-O EP/1/A15000/F-O (Critical Safety Function Status Trees).
- 29. Control S/G levels as follows:
- a. Verify N/R level in all S/Gs - GREATER a. Maintain total feed flow greater than THAN 11%. 450 GPM until at least one S/G N/R 4S0 level is greater than 11 %.
- b. Throttle feed flow to maintain all S/G b. IF N/R level in any S/G continues to N/R levels between 11 % and SO%.50%. increase in an uncontrolled manner, THEN GO TO EP/1/A15000/E-3 EP/1/A/SOOO/E-3 (Steam Generator Tube Rupture).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 EP/1/A/5000/E-O 27 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 30. Verify secondary radiation is normal as follows:
- a. Ensure the following signals - RESET:
_ 1) Phase A Containment Isolations _ 2) CA System valve control _ 3) KC NC NI NM St signals.
- b. Align all S/Gs for chemistry sampling.
- c. Perform at least one of the following:
_ . Notify Chemistry to sample all S/Gs for activity. OR _ . Notify RP to frisk all cation columns for activity.
- d. Verify the following EMF trip 1 Iights-lights- EP/1/A15000/E-3 (Steam
- d. GO TO EP/1/A/5000/E-3 DARK: Generator Tube Rupture).
- 1EMF-33 (Condenser Air Ejector Exhaust)
- 1EMF-26 (Steamline 1A) 1A)
- 1EMF-27 (Steamline (Steam line 18) 1B)
- 1EMF-28 (Steamline 1C)
- 1EMF-29 (Steamline 1D).
- e. WHEN activity results are reported, e. Perform the following:
THEN verify all S/Gs indicate no activity. _ 1) Notify station management to evaluate S/G(s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, EP/1/A15000/E-3 THEN GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O 28 of 61 DC~ Rev 36 DCt ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 31. Verify auxiliary building radiation is Evaluate cause of abnormal conditions normal as follows: as follows:
- EMF-41 (Aux Bldg Ventilation) trip 1 light a. Monitor OAC EMF alarms, OAC VA
- DARK
-DARK Graphic, and area monitor EMFs to determine location of activity.
- All area monitor EMF trip 1 lights - DARK
- b. Dispatch operator to locate potential leak.
- c. IF cause of alarm is LOCA outside containment, THEN GO TO EP/1/A/SOOO/ECA-1.2 (LOCA Outside Containment).
- 32. Verify PRT conditions are normal as Evaluate following possible causes of follows: abnormal PRT conditions:
- PRT pressure - LESS THAN 8 PSIG
- Pzr safety temperatures
- Pzr safety relief flow indicated
- PRT level - LESS THAN 89%
- Pzr PORVs
- Rx head vents
- PRT temperature - LESS THAN 130°F.
- NC pump seal return header relief
- Letdown orifice header relief.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O EP/1/A15000/E-O 29 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 33. Ensure S/I 5/1 - RESET:
- a. ECCS. a. IF either reactor trip breaker is closed, THEN:
_ 1}
- 1) Ensure reactor trip breakers -
OPEN. _ 2}
- 2) WHEN trip breakers open, THEN reset ECCS.
- b. DIG load sequencers. b. Dispatch operator to open the affected sequencer(s) control power breaker:
sequencer{s}
- 1EDE-F01 F {Diesel (Diesel Generator Load Sequencer Panel 1DGLSA}
DGLSA) {AB-577, (AB-577, BB-46, Rm 496} 496)
- 1EDF-F01 F {Diesel (Diesel Generator Load Sequencer Panel 1DGLSB}
DGLSB) {AB-560, (AB-560, BB-46, Rm 372}. 372).
- c. IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on.
- 34. Ensure the following containment isolation signals - RESET:
Phase A
- PhaseA
- Phase B.
- 35. Establish VI to containment as follows: Perform the following:
- Ensure 1VI-77B {VI (VI Cont Isol}
Isol) - OPEN. a. Align N2 to the Pzr PORVs by opening the following valves:
- Verify VI pressure - GREATER THAN 85 PSIG.
- 1NI-438A {Emer (Emer N2 From CLA A To 1NC-34A}
NC-34A)
- 1 NI-439B {Emer (Emer N2 From CLA B To NC-32B).
1NC-32B}.
- b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-0 EP/1/A/5000/E-O 30 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 36. Verify criteria to stop operating NO pumps as follows:
- a. NC pressure - GREATER THAN a. GO TO EP/1/Al5000/E-1 EP/1/A/5000/E-1 (Loss Of 285PSIG.
285 PSIG. Reactor Or Secondary Coolant).
- b. NC pressure - STABLE OR b. GO TO Step 37.
INCREASING.
- c. At least one ND pump - ON. c. GO TO Step 36.e.
- d. Ensure all ND pump(s) with suction aligned to FWST - STOPPED.
- e. IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart ND pumps.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 31 of 61 Rev 36 DC:: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 37. DIGs Verify conditions to stop operating D/Gs as follows:
- a. At least one D/G DIG - ON. a. GO TO Step 38.
- b. Verify 1 ETA is energized by offsite b. Perform the following:
power as follows: _ 1} Attempt to restore offsite power to 1)
* "DIG "D/G 1 A BKR TO ETA" - OPEN 1A affected switchgear. REFER TO AP/1/A/55001007 (Loss of Normal AP/1/A/5500/007
- 1ETA-1ETA - ENERGIZED. Power).
_ 2) GO TO Step 37.d. 2}
- c. Dispatch operator to stop 1A D/G DIG and place in standby readiness. REFER TO OP/1/A/63501002 OP/1/A/6350/002 (Diesel Generator Operation).
- d. Verify 1ETB is energized by offsite d. Perform the following:
power as follows: _ 1} Attempt to restore offsite power to 1)
* "DIG "D/G 1B BKR TO ETB" - OPEN affected switchgear. REFER TO AP/1/A/5500/007 (Loss of Normal
- 1ETB - ENERGIZED. Power).
_ 2) GO TO Step 38. 2}
- e. Dispatch operator to stop 1B D/G DIG and place in standby readiness. REFER TO OP/1/A/6350/002 (Diesel Generator Operation).
- 38. RETURN TO Step 21.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 32 of 61 Enclosure 1 - Page 1 of 1 Rev 36 DC~ OCt Foldout Page
- 1. IF any S/G(s) suspected ruptured, THEN perform the following:
- WHEN the following conditions met:
- Total CA flow - GREATER THAN 450 GPM
- All intact S/G(s) N/R level- GREATER THAN 11%(29% ACC)
THEN throttle feed flow to ruptured S/G(s) to maintain ruptured S/G(s) N/R level between 11 %(29% ACC) and 39%.
- 2. NC Pump Trip Criteria:
- IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:
- At least one NV or NI pump - ON
- NC subcooling based on core exit TICs - LESS THAN OR EQUAL TO O°F.
- 3. CA Suction Source Switchover Switch over Criteria:
- IF either of the following annunciators are lit, THEN REFER TO AP/1/A/55001006 (Loss of S/G Feedwater):
1AD-5, H/4 "CACST LO LEVEL"
- 1AO-5, OR
- 1AD-8, 1AO-8, B/1 "UST LO LEVEL".
- 4. Position Criteria for 1NV-202B and 1NV-203A (NV Pumps A&B Recirc Isol):
- IF NC pressure is less than 1500 PSIG AND NV S/I flowpath is aligned, THEN close 1NV-202B and 1NV-203A.
- IF NC pressure is greater than 2000 PSIG, THEN open 1NV-202B and 1NV-203A.
- 5. Cold Leg Recirc Switchover Criterion:
- IF FWST level decreases to 37% (1AD-9, (1AO-9, 0/8 "FWST 2/4 LO LEVEL" lit), AND an SII has occurred, THEN GO TO EP/1/A/5000/ES-1.3 (Transfer To Cold Leg Recirculation).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O EP/1/A/5000/E-O 33 of 61 Enclosure 2 - Page 1 of 7 Rev 36 DC~ Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1.'(~rifYptgp~rMGlYC'QP~ratiQnaS
- 1. ~(erify proper VCNC operation as BOP OP DOES THIS ENCLOSURE follows:
verif~::@r;l~lt~in.:@ftbefqllqwing
- a. Verifyonetrainofthe following a. Perform the following:
eqiliiti>*I"r\~m~:;j~ili.@R~(9ti@n: equipmentis in operation: _ 1) 1} Shift operating VCIYC trains.
- YC chiller
.)"C\chiller. REFER TO Enclosure 6 (Shifting
- CRAHU-1 YR~f:!UJh.~) Train) .
Operating VCIYC Train).
~ . . (;)~~f:!UJ1~
ii' ,QRAAHU-1
- C~PFT71§
.' ,eRA PFT-1. 2) IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:
- OP/OIAl64501011 OP/O/A/6450/011 (Control Room Area Ventilation/Chilled Water System)
- EM/O/A/5200/001 EM/OIAl52001001 (Troubleshooting Cause For Improper Operation of VCIYC System).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A1S000/E-O EP/1/A/SOOO/E-O 34 of 61 Enclosure 2 - Page 2 of 7 Rev 36 DC~ Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. (Continued)
\t~tifytll?fQUoWil1g~larrps4(?AJRK:
- b. Verify the following alarms - DARK: b. IF chlorine odor is detected in the Control Room, THEN perform the
*.tl\D"'18,~a'!IJ~I~***1INTAKt=
1AD-1B,A/B"UNIT 1 INTAKE .HI HI following based on the status of given CfI!£ORINt=:nA!" CHL:ORINE 1A" alarms:
- 1AD;1B,S/8~'VN.IT 1 INTAKE HI 1**A(?;t:~a,**.*.~ta'.:1;hl~lrni1il~IDAKt=*HI 1)) IF detectors on both unit intakes are 1
Qfll4QIRJ*.~t="1r;~;~ CHLORINE1S" in alarm, THEN: 1AD:..l~,D/8i"l!:INIT2INTAKE HI
**tA(?T~:a;iJi)fa~,ljlJ~lm:2INmAKt=;:**'.fll a) Ensure the following VC intake CfI.!£OR*rN.ffi2'A" CHLORINE 2A" CLOSED:
dampers - CI+/-OSED:
*.1A(?Hta;\*t=l8r~I;IJNIID2;;1 1AD-18,.E/8'lUNIT2INTAKE NIDAKE'.H;IHI
- 1VC-S8 (CRA Filt Inlet)
CflI+/-Q.IRINf:*2.~'l; CHLORINE2S;
- 1VC-6A (CRA Filt Inlet)
- 2VC-S8 (CRA Filt Inlet)
- 2VC-6A (CRA Filt Inlet).
_ b) GO TO Step 1.d.
- 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN:
a) Ensure the following VC dampers - CLOSED: CI+/-OSED: _ . 1VC-S8 (CRA Filt Inlet) _ . 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers - OPEN: _
- 2VC-S8 (CRA Filt Inlet)
_
- 2VC-6A (CRA Filt Inlet).
_ c) GO TO Step 1.d. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O EP/1/A/5000/E-O 35 of 61 Enclosure 2 - Page 3 of 7 DC~ Rev 36 DC:: Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. (Continued)
- 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN:
a) Ensure the following VC dampers - CLOSED: 2VC-58 (CRA Filt Inlet) _
- 2VC-5B
_ .* 2VC-6A (CRA Filt Inlet). b) Ensure the following dampers - OPEN: _ . 1VC-5B 1VC-58 (CRA Filt Inlet) _ . 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d.
- c. Ens,u(~ the following VC dampers -
OREN: _ . ~* *. It~iMI:t~.J6Jt'it~U: 1VC-5B (CF~AFilt Inlet) _ ~;* ;t~~~~.t~:IlAt~~ 1VC-6A (CRA,Filtlrilet) i' *9\'Irr~£lI,",*mEa4\1sGII'diii1iS~, 2VC-58 (CRA,Filt Inlet)
* "~fV.;i~~~:~+~!1s)K~fttJfft+l~~:9.f
'.~~>V
_ ~'?~~'~l~"'J¥~.~
- 2V,C-6A (CRA'Filtlnlet).
d*~~l\i~t1it~j*JI.(~t1;1t!1I1:~:ttt.b$;~Jj!itl(
- d. Repeat Step 1 of this enclosure ,until notified by ~tation rnanagel1lentas
*flo!l.~~~ltilJ§i;\liill~liIilJA~~Qt~5' fgll>R'~'
follows: _ iYAt;~~J'i~dfii>~J!Mi~~0Rlj(Il[~
- At,least once every 8 hou({)
-,.,.;. ~.~'X~,>;.",.~9,,~v~,"A~~Y~~"ilt~\l)t~0t.~
OR
- Any tirne:cVC/yC relat~d anriunGiators on 1AD-j 8 aCtuate,
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 36 of 61 Enclosure 2 - Page 4 of 7 Rev 36 DC~ Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. l;nsure.* *.prQP~fA*M{i.*.*.~y§t~m.9P~rEltiQt!.as Ensure properNASyst~rn*operation as follows:
Ensur¢**ttie:if91.19Will§j{~f'lS***;:;~88:
* . Ensure the following fans- OFF: 1B FXF is off due to no power. 1B FXF off causes 1B UXF to secure.
*tt*****ABUX,F1A ABUXF1A
- ABUX,IF1B.
411 ABUXF 1B.
- VA System * {!lt¢ri§*iJh!5er;yiceas ehsqrre\{~~Y~ferl1*
Ensure filter is in service as followS: follows:
- 1ABF-D-12 1.*A~E~l2!lt1*g**.8t*19*i.<\{~fijlt¢r**A*~ypass
& 19 (VA Filter A Bypass Dal't1l.p~rs~;tOI.:.~~e*Q Dampers)::: CI..OS,ED
*.1ABEtDlt~:*.8t*2~{\{~.Eilt¢~*B 1ABF-D-5:& 20 (Yl(Filter B *Bypass Bypass l2!aru.pe.r!5l*f\OI.:.~~e.[J; Dampers) .. CLOSED.
- Ensure the following fans;:. ON:
iABFXEf1A
- ABFXF-1A
- ABFXF1B.
ABFx,e*1iB;
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-0 EP/1/N5000/E-0 37 of 61 S of 7 Enclosure 2 - Page 5 DC:: Rev 36 DCE Ventilation System Verification ACTION/EXPECTED RESPONSE ACTION/~XPECTED RESPONSE NOT OBTAINED
- 3. M'jl~~cQti'll~Ve§~Jjm"'~~l!ftij(n~~.
Veri~ proper VE System operation as (~l'fi.I' follows: a.J~ft!($j~;"::~N;i
- a. VE fans - ON. fan(s).
- a. Manually start fanes).
- b. br~nul'lls;iSr:l$~:i!J~AilI£N, Annulus pressure
".,;~!jr",.". ,*~,.,,,,,ff - BETWEEN
... ~~~J._(2A~~it! ~.~~" ... ,/ b. Perform the following:
-1lW:*IN~?W~._1takiV¥!ll~:
-1.4 IN. WCAND-1.B:/N. WC.
- 1) IF annulus pressure is more positive 1}
than -1.4 in. WC, THEN: a) Verify flow indicated on the a} This will be correct for A train , IThis following indications: no power to B train.
* "VE 1A1A FLOW TO STACK"
* "VE 1B FLOW TO STACK".
b) IF flow is not indicated, THEN b} dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":
- 1AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-51 JJ-S1,, Rm SOO) - CLOSED 500)
- 1AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-52, HH-S2, Rm SOO) - CLOSED 500)
- 1AVS-D-3 (VE A Trn Exh JJ-S2, Rm Damp) (AB-603, JJ-52, SOO) - OPEN 500) 1AVS-D-B (VE B Trn Exh
- 1AVS-D-8 HH-S2, Rm Damp) (AB-603, HH-52, SOO) - OPEN.
500) _ c) Consult plant engineering staff _c} and notify IAE/Maintenance to troubleshoot and repair. REFER EM/1/A/S2001002 TO EM/1/N52001002 (Troubleshooting Cause For VE Hillo Pressure). System Hi/lo _ d) GO TO Step 3.c. d} (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/N5000/E-O 38 of 61 Enclosure 2 - Page 6 of 7 DC~ Rev 36 DCt Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued)
- 2) IF annulus pressure is more negative than -1.8 in. WC, THEN:
_ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours, ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A/52001002 EM/1/N52001002 (Troubleshooting Cause For VE System Hi/Lo Hillo Pressure). RepeatSt~p~i~eY.~ryQ()tni{;lutE'.!s
- c. Repeat Step 3.b every 30hlinutes *.until until notified,p~i~tatibn notified manag~tnejjt.
by station .. management.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/N5000/E-O 39 of 61 Enclosure 2 - Page 7 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. Record time ventilation systems are verified on following table:
TIME SYSTEM INITIALS (VC. (VC, VE)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 40 of 61 Enclosure 3 - Page 1 of 1 Rev 36 DC~ Opposite Unit Ventilation Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Ensure proper Unit 2 VA System operation as follows:
- Ensure the following fans - OFF:
- ABUXF-2A
- ABUXF-2B.
- Ensure VA System filter is in service as follows:
- 2ABF-D-12 & 19 (VA Filter A Bypass Dampers) - CLOSED
- 2ABF-D-5 & 20 (VA Filter B Bypass Dampers) - CLOSED.
- Ensure the following fans - ON:
- ABFXF-2A
- ABFXF-2B.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 41 of 61 Enclosure 4 - Page 1 of 4 Rev 36 DC~ NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Vetifyafleast one NC pump* ON. Perform the following:
r=":::::-=::-::::-:='----. ROo DOES THIS ENCLOSURE a. Use NC T-Colds to determine NC temperature as required in subsequent steps.
- b. GO TO Step 4 4..
- 2. Use NC T,..Avg todeterrniJie NC temperaJure?as requited il':1 subsequent st~ps~
3., IF\ATANYTIME NC pumps are tripped;' THEN use NC T -Colds to 'determine NC temperature as ,required,ill subsequent steps.
- 4. Verify one of the following: GO TO Step 7.
- NC temperature - STABLE AT LESS 55rF.
THAN OR EQUAL TO 557°F. OR 55rF.
- NC temperature - TRENDING TO 557°F.
- 5. Continue to monitor NC temperature.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/11A15000/E-O 42 of 61 Enclosure 4 - Page 2 of 4 DC~ Rev 36 DeS NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. Do not continue in this enclosure until one of the following occurs:
- NC temperature - GREATER THAN 55]oF 557°F AND INCREASING IN AN UNCONTROLLED MANNER.
OR
- NC temperature - GREATER THAN 55]oF AND STABLE.
55rF OR
- NC temperature - LESS THAN 55]oF AND DECREASING IN AN 55rF UNCONTROLLED MANNER.
77..~~ri~NG,~~'rop~ra~!;I*re~(J";IES~i;rti~N VerifyNC temperature. LESS THAN Perform the following: 557'~FAND DECREASING~ 55:Z-'~E"**':AND)[)ECREASING;'
- a. IF IE" NC temperature is greater than 55]oF AND increasing, THEN stabilize 55rF NC temperature at 55rF 55]oF as follows:
- 1) IF steam dumps are available, 1)
THEN use steam dumps.
- 2) IF steam dumps are not available, THEN use S/G PORVs.
- b. IF the following conditions exist:
- NC temperature is greater than 55]oF and stable 55rF
- Time and manpower is available, THEN stabilize NC temperature at 55]oF as follows:
55rF
- 1) IF steam dumps are available, THEN use steam dumps.
- 2) IF steam dumps are not available, THEN use S/G PORVs.
- c. GO TO Step 9.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 43 of 61 430f61 Enclosure 4 - Page 3 of 4 Rev 36 DC~ OC~ NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. ~ft@mllrgtjlgp:lll~2f'~Bp;i)lt1AWi;;;$;
Attempt b:>"s1op theNC cooldownas ittillBl:t fQlloVl(s: eJ a't~ltMliU*§f<<g~$\f$.l~lIa~ a:~nsure all steam dumps ::: ,C:;LOSED. p;. 'ilfiJi!tfllfIl~~.lIt~iQl.)".Q~ ii, Ensure all SIG POR}/$-CLOSED: b. IF any S/G PORV cannot be closed, THEN close its isolation valve.
- c. ,~tBtt.B.~!:f~it§!i,i~l~lit~~L Ensur~S/GbroWdown}s isolated.
- d. . Close
!!t~ * *_m~1l.[ml~ijJ~1§3 thefbllowing valves:
* 'li"~';~.G,fc1F1~iQllIJttttl'lt!Wfl*
'i" 1SM::';??A (S/G 1A Otlt Hdr Bldwn
~CN)
~.;
* '~J3i;~I(fi'1I:,p,)nt~ffltt~11Wr1 1SM96B (S/G 1B Otlt Hdr Bldwn
~;
.M' CN),
* %tI?t;lzj~~r~:G~~[rlfl{;~mIWfll; 1SMQ5A (S/G 100tlt Hdr Bldwn m1lilfi CN)
.~_l~J!~~t~~lfl~lIJI(t1il
~ 1SM-?4B (S/G 10 Otlt Hdr Bldwn
~:
ON).
~. Depress and hold ',lSN BEFORE SEAT g;~.tt:tt:;IB~bl"fiii1lil~e-f7~&,'I~
QIII~~~.:':;.~fj,tit~(jijtie:':M~~)$l0 DRN" '.'CLOSE" pushbutton (1MC-3) to
'(llJ&;.~=.*I:lwi_~~;
close the fOllbwi!1gv~lves;
- i:iali.~~;;i$tqlJt~V:lIIMm.Ji.~~
- JSM-41 (Stop Vlv#1 Before Seat i_D; Om)
* ;Jt_I~.ICli~LI:~.~~~iIIEilt:
'i'. 1SM-44 (stop Vlv #2,Before,$eat
.lial1 Om)
* ,'.1'1icu.'lIfc'A*9:q~t':Ji!i;*'\I',*;Ha.::~~&jp'~~~
idS $M-43 (Stop Vlv: #3 Before Seat
"":i,S1J!.1";ft~.'(\\,?qIi'0Y¥:~~~.M!~E~*
~,.{
Om)
.~:~
* {ff~M1illli1~A:li~Ii\~~i'z4J'If;lIef~ref;c;le'+'
1SM-42 {Stop VI"'#fl B~fqrE)
~il~}~q,~~;~.~~J¥$¥?*)!!0?\:~-. Segt
_,'., .>:"~,>,.,.,~,,,~~;v.~* Dfn):,~
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O EP/1/A/5000/E-O Enclosure 4 - Page 4 of 4 44 of 61 Rev 36 DC~ NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. {Continued)
- f. Verify NC cooldown - STOPPED; f.1 P.coQIc!own
- f. IF C()tltinti~§iTHEN.throtll~
cooldown . *continues, THEN throttle feed >floWasJolloWs: flow as follows:
- 1) IFSIG*
IF S/G N/R* N/R .
- level.is level is Je.ss than * **.**.l1WJ less thah 11 %
(29% ACC) in all S/G's; THEN (29%A<iD<iD)ih*'aU'g/G'§.<THEN** throttle feed * .**fIQw.*to.**.achieve**.the throttl~**.**fe~d flow to acMieve the follQWi hg: folloWing:
- Minimize coolddwn M;:tir:lt;:ti*ntQt<:i*lfe~c!.flpw:greater
- Maintain total feed floW greater thah450GPM.
than450 GPM. 2~
- 2) WHEN*f}J/Rl~Meli$.greaterthah WHENN/R level is greater than 1.*19fQ(~~%ACCljrl*;:tt.Je;:t§t 11 %(29% ACe) in at least *or:l~.§lG, one S/G, THENlhrottle'feed.flaWflilrtherto THEN throttle feed ,flow further to cl(~hie\tethe'fQI.lowitilg:
achieve the following:
- Minimizecooldown
- Maintaina.fJeastol1e.*S1G***M/R Maintain at least one S/G N/R le\teJ level* ***greater.*.tha.h**1*.*.~%
greater than 11 % (29% ACC). ACC).
- 3) IFcooldown continues,~THEN 3)IPi.?Qaldowr),conti tilLleSiT'HEN'i.?lose close tmefolloy.(ir:lg\taIM~s:
the following valves:
~*.... AIIMSIVS All MSIVs
*.:AIIMgJV*oypasSvaIM~§*
All MSIV bypass valves.
- 9. Continuelq perfQrm the actions of this 9*CQl'ltim.le;i*fo***peJ::fQ:rm.the*a¢t.ioij§*of*:*this enclosur~as re.quired to ensure one of enclo*sUre~s~eg:Qirec.ft()*~n~Q~eQn*eigf tl1e following:
ttlefoilQ\Il.ing:
- NC temperature - STABLE AT LESS THAN OR EQUAL TO 55rF.
OR
- NC temperature - TRENDING TO 55rF. 557°F.
Duke Power Company Procedure No. Catawba Nuclear Station EP/I/A/5000/E-2 Faulted Steam Generator Isolation Revision No. 012 Electronic Reference No. CP0094CZ Continuous Use PERFORMANCE I
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
(ISSUED) - PDF Format
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/AlSOOO/E-2 EP/1/A/SOOO/E-2 1 of 21 Revision 12 A. Purpose This procedure provides actions to identify and isolate a faulted S/G. B. Symptoms or Entry Conditions This procedure is entered from:
- a. EP/1/AlSOOO/E-O EP/1/A/SOOO/E-O (Reactor Trip Or Safety Injection), Step 24, with the following symptoms:
- 1) Any S/G pressure decreasing in an uncontrolled manner.
- 2) Any S/G completely depressurized.
EP/1/A1S000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 2, EP/1/A/SOOO/ECA-3.1
- b. EP/1/A/SOOO/E-1 EP/1/A1S000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired), Step 11, EP/1/A1S000/ECA-3.2 EP/1/A/SOOO/ECA-3.2 (SGTR With Loss Of Reactor Coolant - Saturated Recovery Desired), Step S with the following symptoms and/or conditions:
- 1) Any S/G pressure decreasing in an uncontrolled manner.
- 2) Any S/G completely depressurized.
- 3) Faulted S/G isolation not verified.
- c. EP/1/A1S000/FR-H.S (Response To Steam Generator Low Level), Step 4, when the EP/1/A/SOOO/FR-H.S affected S/G is identified as faulted.
- d. Foldout page of other procedures whenever a faulted S/G is identified.
- e. EP/1/AlSOOO/ECA-2.1 EP/1/A/SOOO/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators),
Enclosure 1 (Foldout Page), if any S/G pressure increases.
CNS eNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 2 of 21 20f21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Monitor Enclosure 1 (FbldoutPage).
- 2. Maintain ahy{aultecfS(Gor secondary break isolateddufil19sui:Jsequent recoverY actio,ns u'nl.E!ss,needed for NC Systemco'oldo\VI1:.
- 3. Verify thefQllo..ying valves* CLOSED: _ valve(s)..
Manually close valve(s)
- AIiMSIVs
_
- All MSIVpypassvalves.
- 4. Verify at leastol1eS/Gpress'ufe- SIGs are faulted, THEN GO TO
_ IF all S/Gs STABLE OR INCREASING. EP/1/A15000/ECA*2.1 (Uncontrolled EP/1/A15000/ECA-2.1 Depressurization Of All Steam Generators). fR5l 55. 'denfitYi'filqlfe~)!Si.~(~)::a~t,fQII.Q~$: Perform the following: IRQ I. Identify faultedS/G(s) as follows: _ ** \l~fify~nY9yt:ipr~$s _ Verify any S/Gpressure-OECREASING a. Dispatch operators to search for IN AN UNCONTROLLED,MANNER l'i'kJAN*'1..JNCOrslTROt.J3E initiating break at the following locations: QR OR
- Main steamlines Veo.tY*.aQ~i;~r~TP~R~.E$.SSOOR!gl:,Q.
** Verifyany.$/G.DEPRESSURIZED.
- Main feedlines
_
- Other secondary piping.
_ b. GO TO Step 8.
- 6. Verlfy at leas!.oneintact'S/G.- Maintain one S/G SIG available for NC AvAILABLE FOR NC SYSTEM System cooldown in subsequent steps.
COOLDOWN.
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/11A15000/E-2 EP/1/A/5000/E-2 3 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. Isqlate~llif~'ul(~(l$fG(~li:~§'f~U~W~r Isolate all faulted SlG(sla~ follows:'
*** S/G1A:
S/G 1A: IRQ I - aa{V~(itX*P!~1AF~~~W~1@ril.S()lati0it
. Verify S/G ....... 1A FE:).edwater Isolation a. Perform the following:
L_J ~tatu~.*'ligJjt(1'RI?9),...I,:.IT; status light (1SI ..5) - LIT. _ 1) Manually close valve(s).
- 2) IF 1CA-185 (S/G 1A CA Nozz Tempering Isol) cannot be closed, THEN:
a) Manually close the following valves:
- 1CF-100 (S/G CA Nozz Tempering Ctrl)
- 11CF-156 CF-156 (8yp Valve For 1CF-100).
b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s): 1CF-1 00 (S/G CA Nozz
- 1CF-100 Tempering Ctrl) (T8-580, 1H-33) (Ladder needed)
- 1CF-156 (8yp Valve For 1CF-1 00) (T8-577, 1H-33) 1CF-100)
(Ladder needed).
- b. VerifyS!G 1APORV c CLOSED. b. Perform the following:
_ 1) Manually close S/G PORV.
- 2) IF S/G PORV cannot be closed, THEN:
_ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.
CNS FAULTED FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/11A15000/E-2 EP/1/A15000/E-2 40f21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- c. Close the following valves:
_ 1) 1SM-77A (S/G 1A Otlt Hdr Bldwn _1) _ 1) Dispatch operator to close N). 1SM-77A (S/G 1A Otlt Hdr Bldwn CN) (DH-583, FF-GG, 43-44, Rm 591). 591 ). _ 2) 1qA~62A (CA Pmp A Disch To _2) 2) Perform the following: S/G1 A ISol). _ a) Close 1CA-60 (CA Pump 1A Flow To S/G 1A). _ b) Dispatch operator to close 1CA-62A (CA Pmp A Disch To S/G 1A Isol) (DH-587, DD-EE, 44-45, Rm 591). IBOP 1-_ 3) 1CA-66B (CA Pmp 1 Oisch To 3) S/G tA Is()l)~
- 3) Perform the following:
_ 1CA-64 (CA Pump #1 a) Close 1CA-64 Flow To S/G 1A). _ b) Dispatch operator to close 1CA-66B (CA Pmp 1 Disch To S/G 1A Isol) (DH-584, DD-EE, 44-45, Rm 591).
- d. Verify the following blowd6\?Jn isolatio,n valves - CLQSED:
_ 1) lBB-56A (stG 1ABldwn Cont 1501 _ 1) Manually close, valve. Insd). This should already have been done in E-O but will be done here if not. CRITICAL TASK!!!
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 5 of 21 50f21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
_ 2) tE3B;;.~4t3B(S/G~A.E3lm~tTCQnt 1BB-148B (S/G 1A Bldwn Cont 2) Perform the following: Isol Byp). Iso[.Byp). _ a) Manually close valve. b) IF valve will not close AND 1BB-56A is open, THEN No power last known position was perform the following: closed _ (1) Ensure "S/G A BLDWN FLOWCTRL"- FLOW CTRL"- CLOSED. (2) Dispatch operators to ensure the following valves - CLOSED: _ .* 11BB-148B BB-148B (SIG(S/G 1A Bldwn Cont Isol Byp) (DH-580, EE-FF, 44-45, Rm 591) _ .* 1BB-81 (1A SIG Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 EP/1/A15000/E-2 6 of 21 6of21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
_ 3) 1BB:.57B (S/G 1A aJdwnC6ntl~QI _3) ).tfft~tt~~fct(~lti~~~ 33)Performthe following: btsd). _ gl£~aB~~~IW1~r<l~~M~!~&,*; a) Manually close valve. b) IF valve will not close AND No power last known position was INo .1 BB-56A is open, THEN perform the following: IoPEN OPEN _ (1) Ensure. "f3/G. A BLDWN FLOW CTRL" - . CLOSE.D. (2) Dispatch operators to I ensure the following valves - CLOSED: _ . 18B-57B (S/G1A Bldwn Cont Isol Otsd) (DH-580, EE-:FF, 44.:.45, Rm 591)
.1BB-81(1A S/G Blowdown Penetration Valve Test Is61) .
(DH ..583,EE-FF ,44, Rm 591).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 EP/1/A/5000/E-2 7 of 21 70f21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- S/G 1B:
- a. Verify S/G 1B Feedwater Isolation a. Perform the following:
status light (1SI-5) - LIT. _ 1) Manually close valve(s).
- 2) IF 1CA-186 (S/G 1B CA Nozz Tempering Isol) cannot be closed, THEN:
a) Manually close the following valves:
- 1CF-1 00 (S/G CA Nozz Tempering Ctrl)
- 1CF-156 (Byp Valve For 1CF-100).
b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):
- 1 CF-1 00 (S/G CA Nozz 1CF-100 Tempering Ctrl) (TB-580, 1H-33) (Ladder needed)
- 1CF-156 (Byp Valve For 1CF-1 00) (TB-577, 1H-33) 1CF-100) 1H-33)
(Ladder needed).
- b. Verify S/G 1B PORV - CLOSED. b. Perform the following:
_ 1) Manually close S/G PORV.
- 2) IF S/G PORV cannot be closed, THEN:
_ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 EP/1/A15000/E-2 80f21 8 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- c. Close the following valves:
_ 1) 1SM-76B (S/G 1 1BB Otlt Hdr Bldwn _ 1) Dispatch operator to close CN). 1SM-76B (S/G 1B Otlt Hdr Bldwn CN) (DH-583, FF-53, Rm 572). _ 2) 1 CA-58A (CA Pmp A Disch To 1CA-58A 2) Perform the following: S/G 1B Isol). _ a) Close 1CA-56 (CA Pump 1A Flow To S/G 1B). _ b) Dispatch operator to close 1CA-58A (CA Pmp A Disch To S/G 1B Isol) (DH-586, DD-EE, 52-53, Rm 572). _ 3) 1CA-54B (CA Pmp 1 Disch To 3) Perform the following: S/G 1B Isol). _ a) Close 1CA-52 (CA Pump #1 Flow To S/G 1B). 1B). _ b) Dispatch operator to close 1CA-54B 1CA-54B (CA Pmp 1 Disch To S/G 1B Isol) (DH-584, DD-EE, 52-53, Rm 572).
- d. Verify CA Pump 1A or 1B - d. IF CA Pump #1 is the only source of AVAILABLE. feedwater, THEN perform the following:
_ 1) Maintain steam flow to the CAPT from at least one S/G. _ 2) IF desired to isolate steam supply to CA Pump #1 from 1B S/G, THEN GO TO Step 7.e. _ 3) GO TO Step 7.f.
- e. Dispatch operator to unlock and e. Dispatch operator to unlock and close 1SA-1 (1B S/G Main Steam to close 1SA-3 1SA-3 (1 B S/G Main Steam to CAPT Maintenance Isol) (DH-624, CAPT Stop Check) (AB-551, DD-53, FF-53, Rm 572) (Breakaway lock Rm 217) (Breakaway lock installed).
installed).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 EP/1/A15000/E-2 90f21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- f. Verify the following blowdown isolation valves - CLOSED:
_ 1) 1BB-19A{S/G 1B Bldwn Cont Isol _ 1) Manually close valve. Insd). _ 2) 1BB-150B (S/G 1B Bldwn Cont 2) Perform the following: Isol Byp). _ a) Manually close valve. b) IF valve will not close AND 1BB-19A is open, THEN perform the following: _ (1) Ensure "S/G B BLDWN FLOWCTRL"- CLOSED. (2) Dispatch operators to ensure the following valves - CLOSED: 1BB-150B (S/G 1B
- 1BB-150B 1B Bldwn Cont Isol Byp)
(DH-580, FF, 52-53, Rm 572)
- 1BB-83 (1 B S/G Blowdown Penetration Valve Test Isol)
(DH-580, FF-53, Rm 572).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 EP/11A15000/E-2 10 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
_ 3) 1BB-21 B (S/G 1B Bldwn Cont Isol 3) Perform the following: Otsd). _ a) Manually close valve. b) IF valve will not close AND 1BB-19A is open, THEN perform the following: _ (1) Ensure "S/G B BLDWN FLOW CTRL"- FLOWCTRL"- CLOSED. (2) Dispatch operators to ensure the following valves - CLOSED:
- 1BB-21B (S/G 1B Bldwn Cont Isol Otsd)
(DH-580, FF, 52-53, Rm 572)
- 1BB-83 (1 B S/G Blowdown Penetration Valve Test Isol)
(DH-580, FF-53, Rm 572).
CNS FAULTED STEAM GENERATOR FAULTED GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 EP/1/A15000/E-2 11 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- S/G 1C:
- a. Verify S/G 1C Feedwater Isolation a. Perform the following:
status light (1SI-5) - LIT. _ 1) Manually close valve(s).
- 2) IF 1CA-187 (S/G 1C CA Nozz Tempering Isol) cannot be closed, THEN:
a) Manually close the following valves: _ .* 1CF-100 (S/G CA Nozz Tempering Ctrl) _ .* 1 CF-156 (Byp 1CF-156 (Syp Valve For 1CF-100). b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s):
- 1CF-100 (S/G CA Nozz Tempering Ctrl) (TB-580, 1H-33) (Ladder needed)
- 1CF-156 (Byp Valve For 1CF-100) (TS-577, 1H-33) 1CF-100)(TB-S77,1H-33)
(Ladder needed).
- b. Verify S/G 1C PORV - CLOSED. b. Perform the following:
_ 1) Manually close S/G PORV.
- 2) IF S/G PORV cannot be closed, THEN:
_ a) Manually close S/G PORV isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 12 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- c. Close the following valves:
_ 1}
- 1) 11SM-75A SM-75A (S/G 1 1C C Otlt Hdr Bldwn _ 1}
- 1) Dispatch operator to close CN). 1SM-75A (S/G 1C 1SM-75A 1C Otlt Hdr Bldwn CN) (DH-580, GG, 52-53, Rm 572).
_ 2}
- 2) 1CA-46B (CA Pmp B Disch To 2} Perform the following:
2) S/G 1C Isol). _ a} a) Close 1CA-44 (CA Pump 1B Flow To S/G 1C). _ b} b) Dispatch operator to close 1CA-46B (CA Pmp B Disch To S/G 1C Isol) (DH-586, DD, DO, 53-54, Rm 572). _ 3} 1CA-50A (CA Pmp 1 Disch To
- 3) 3}
- 3) Perform the following:
S/G 11C C Isol). _ a} Close 1CA-48 (CA Pump #1 a) Flow To S/G 1C). _ b} b) Dispatch operator to close 1CA-50A (CA Pmp 1 Disch To S/G 1C Isol) (DH-584, EE-53, Rm 572).
- d. Verify CA Pump 1 A or 1B -
1A d. IF CA Pump #1 is the only source of AVAILABLE. feedwater, THEN perform the following: _ 1} Maintain steam flow to the CAPT 1) from at least one S/G. _ 2}
- 2) IF desired to isolate steam supply to CA Pump #1 from 1C S/G, THEN GO TO Step 7.e.
_ 3}
- 3) GO TO Step 7.f.
- e. Dispatch operator to unlock and e. Dispatch operator to unlock and close 1SA-4 (1 C S/G Main Steam to 1SA-4 (1C close 1SA-6 (1C S/G Main Steam to CAPT Maintenance Isol) (DH-624, CAPT Stop Check) (AB-551, DD-53, DO-53, FF-53, Rm 572) (Breakaway lock Rm 217) (Breakaway lock installed) installed). (Ladder needed).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 EP/11A15000/E-2 13 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- f. Verify the following blowdown isolation valves - CLOSED:
_ 1) 1BB-60A (S/G 1C Bldwn Cont Isol _ 1) Manually close valve. Insd). _ 2) 1BB-149B (S/G 1C Bldwn Cont 2) Perform the following: Isol Byp). _ a) Manually close valve. b) IF valve will not close AND 1BB-60A is open, THEN perform the following: _ (1) Ensure "S/G C BLDWN FLOWCTRL" - CLOSED. (2) Dispatch operators to ensure the following valves - CLOSED:
- 1BB-149B (S/G 1C Bldwn Cont Isol Byp)
(DH-578, FF-GG, 52, Rm 572)
- 1BB-82 1BB-82 (1C (1 C S/G Blowdown Penetration Valve Test Isol)
(DH-583, FF-53, Rm 572).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 14 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
_ 188-618 (S/G 1C 3} 1BB-61B 1C Bldwn 81dwn Cont Isol 3} Perform the following: Otsd). _ a} Manually close valve. b} IF valve will not close AND 188-60A is open, THEN 1BB-60A perform the following: _ (1) Ensure "S/G C BLDWN 8LDWN FLOW CTRL"- CLOSED. (2) Dispatch operators to ensure the following valves - CLOSED: 188-618 (S/G 1C
- 1BB-61B 81dwn Cont Isol Otsd)
Bldwn (DH-578, FF-GG, 52, Rm 572) (1 C S/G 188-82 (1C
- 1BB-82 810wdown Penetration Blowdown Valve Test Isol)
(DH-583, FF-53, Rm 572).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/11A15000/E-2 EP/1/A/5000/E-2 15 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- S/G 1D:
- a. Verify S/G 1D Feedwater Isolation a. Perform the following:
(1SI-5) status light (1 SI-5) - LIT. _ Manually close valve(s).
- 1) Manua"y valve{s).
- 2) IF 1CA-188 (S/G 1D CA Nozz Tempering Isol) cannot be closed, THEN:
Manually close the following a) Manua"y valves:
- 1CF-100 (S/G CA Nozz Tempering Ctrl) 1CF-156 (Byp Valve For
- 1CF-156 1CF-100).
b) IF 1CF-100 OR 1CF-156 cannot be manually closed, THEN dispatch operator to close the affected valve(s): _ .* 1 CF-1 00 (S/G CA Nozz 1CF-100 Tempering Ctrl) (TB-580, 1H-33) (Ladder needed) 1CF-156 (Byp Valve For
- 1CF-156 1CF-1 00) (TB-577, 1H-33) 1CF-100)(TB-577,1H-33)
(Ladder needed).
- b. Verify S/G 1D PORV - CLOSED. b. Perform the following:
_ 1) Manua"y Manually close S/G PORV.
- 2) IF S/G PORV cannot be closed, THEN:
_ Manually close S/G PORV a) Manua"y isolation valve. _ b) IF S/G PORV isolation valve cannot be closed, THEN dispatch operator to close the valve.
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 16 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- c. Close the following valves:
_ 1) 1 SM-74B (S/G 10 1SM-74B 1D Otlt Hdr Bldwn _ 1) Dispatch operator to close CN). 1SM-74B (S/G 10 1SM-74B 1D Otlt Hdr Bldwn CN) (DH-583, FF-GG, 44-45, Rm 591). 591 ). _ 2) 1CA-42B (CA Pmp B Disch To 2) Perform the following: S/G 10 1D Isol). _ a) Close 1CA-40 (CA Pump 1B Flow To S/G 1D). _ b) Dispatch operator to close 1CA-42B (CA Pmp B Disch To S/G 10 1D Isol) (DH-586, DD-EE, 43-44, Rm 591). _ 3) 1CA-38A (CA Pmp 1 Disch To 3) Perform the following: S/G 10 1D Isol). _ a) Close 1 CA-36 (CA Pump #1 1CA-36 Flow To S/G 1D). _ b) Dispatch operator to close 1CA-38A (CA Pmp 1 Disch To S/G 10 1D Isol) (DH-584, DD-EE, 43-44, Rm 591).
- d. Verify the following blowdown isolation valves - CLOSED:
_ 1) 1BB-8A (S/G 10 1D Bldwn Cont Isol _ 1) Manually close valve. Insd).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A/5000/E-2 17 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
_ 2) 188-1478 1BB-147B (S/G 1D Bldwn 1D 81dwn Cont 2) Perform the following: IsoI8yp). Isol Byp). _ a) Manually close valve. b) IF valve will not close AND 88-8A is open, THEN 1BB-8A perform the following: _ (1) Ensure "S/G D BLDWN 8LDWN FLOW CTRL"-- FLOWCTRL" CLOSED. (2) Dispatch operators to ensure the following valves - CLOSED:
- 188-1478 1BB-147B (S/G 1D 81dwn Cont Isol Byp)
Bldwn 8yp) (DH-582, EE-FF, 44, Rm 591)
- 188-80 1BB-80 (1 D S/G 810wdown Penetration Blowdown Valve Test Isol)
(DH-583,EE-FF, 44, Rm 591).
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/ A/5000/E-2 EP/1/A/5000/E-2 18 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
_ 3) 1BB-1 OB (S/G 1 1BB-10B 1DD Bldwn Cont Isol 3) Perform the following: Otsd). _ a) Manually close valve. b) IF valve will not close AND 1BB-8A is open, THEN perform the following: _ (1) Ensure "S/G D BLDWN FLOW CTRL"- CLOSED. (2) Dispatch operators to ensure the following valves - CLOSED:
- 1 BB-10B (S/G 1 1BB-10B D 1D Bldwn Cont Isol Otsd)
(DH-582, EE-FF, 44, Rm 591)
- 1BB-80 (1 D S/G Blowdown Penetration Valve Test Isol)
(DH-583,EE-FF, 44, Rm 591).
- 8. WHENNC T-Hots ~$** *~t~~t?i~pt~as~ln~HEN' start to il1c::reas~,THEN dump steam from m.*.intijplSlG*9PRXls)to.
intact SIG PORVs to stiifbilize NCT-Hots.
- 9. ~~rify the folloWing annunci,ators- _ REFER TO AP/1/A15500/006 (Loss of S/G
=--------. DARK. Feedwater). _ ~k 1AD~5, H/4 "CACST lOLEVEl"
.tAD-8,B/1 i'UST J.o lEVEL".
CNS eNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/Al5000/E-2 EP/1/A/5000/E-2 19 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. Verify secondary radiation is normal as follows:
- a. Ensure the following signals - RESET:
_ 1) Phase A Containment Isolations _ 2) CA System valve control _ 3) KC NC NI NMSt signals.
- b. Align* all S/Gs for chemistry sampling.
- c. Perform at least on~t'ofthe following:
_ . Notify Chemistrytp periodically sample all S/Gsror activity. OR _ f\J.(}tl~YiRet()
- Notify RP to periodically frisk all cation columns.for activity.
oaftonicoluni d:
- d. Vet[y 1he*.*.fql.I(,)W'i@?I::i~:N1f=.lhl.p1Iii;itlt$**
Verify..the following EMF trip 1 Iights- d. GO TO EP/1/A/5000/E-3 EP/1/Al5000/E-3 (Steam O~gl\; DARK; Generator Tube Rupture). Rupture) . 1iE;Mf.,;2.6***.(St~$ninhe1~~}
- 1EMF..;26 (Steamline 1A)
*.1il+/-Mf=B~~* E~t~~l1ill)h:~*:;1~)
1EMF-27 (Steamline:1 8)
*.~~N1f=72$*:E$.tea~lil't~di~)
1 EMF-28 (Steamlibe 1C)
*.~:.EfMr72Q.*. (§fe$Q;lline i 1*DII 1EMF-29 (Stearnline 1D).
- e. Verify theS/G(s)fauli~INSIDE
- ~¥~(~j::jf~olljii~;:IN$I@~ e; Requel:)t'gp to perform the following:
CONJAINMENT. MENiiF. _ 1) Monitor the area oftheSteam fault for. radiation. _2)~ .*gti.£~f~~?Gn~~~lir()brJ"lrofaf1y _ 2) Notify the control roornof any ap13Qrmalradiatlo.oconditions; abnormal radiation conditions: f. f.WHEN.pctivityresults'rep0rted; adtHEN tHEN
'--->t~7~~
- f. Perform the following:
verify an S/GsJndi.9ate no aCtivity. yi~y~ _ 1) Notify station management to evaluate S/G(s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, THEN GO TO EP/1/A/5000/E-3 EP/1/Al5000/E-3 (Steam Generator Tube Rupture).
eNS CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 20 of 21 Revision 12 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 11. Verify S/rtermination criteria~s follows:
- a. NC subcooling based()n cdte exit TICs - a. GO TO Step 12.
- GREATER THAN OOt'>
RO/BOP
- b. Verify secondary heat sink as follows: - b. GO TO Step 12.
-
- N/RleVel in at least one intact S/G -
GREATER THAN 11%(29'% ACC) OR
-
- rota! fe)d flow loall intact~plGs,"7 GREATER THAN 450;:GPM;
- c. NCpressure - STABLE OR - c. GO TO Step 12.
INCREASING.
- d. Pzrlevel .. GREATER THAN 11 % - d. GO TO Step 12.
(20% ACC).
- e. GO TO EP/MAI~OOO/E$-1.1.(Safety Injection Terminatibn).*
Termination criteria should be met and
!Termination-criteria the crew should transition Ithe ES-1. 1.
transrtion to ES-1.1. li I
- 12. GO TO EP/1/A15000/E-1 (Loss Of !
Reactor Or Secondary Coolant). I! l I END
CNS FAULTED STEAM GENERATOR ISOLATION PAGE NO. EP/1/A15000/E-2 EP/1/A/5000/E-2 21 of 21 Enclosure 1 - Page 1 of 1 Revision 12 Foldout Page
- 1. Cold Leg Recirc Switchover Criterion:
- IF FWST level decreases to 37% (1AO-9, 0/8 "FWST 2/4 LO LEVEL" lit), THEN GO TO EP/1/A15000/ES-1.3 (Transfer To Cold Leg Recirculation).
EP/1/A/5000/ES-1.3
- 2. Position Criteria for 1NV-202B and 1NV-203A (NV Pumps A&B Recirc 1501): Isol):
_ .* IF NC pressure is less than 1500 PSIG AND NV SII flowpath is aligned, THEN close 1NV-202B and 1NV-203A.
- IF NC pressure is greater than 2000 PSIG, THEN open 1NV-202B and 1NV-203A.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/NSOOO/ES-1.1 EP/1/A/5000/ES-1.1 1 of 76 Rev 25DCS Rev2SDCS A. Purpose This procedure provides the necessary instructions to terminate Safety Injection and stabilize plant conditions. B. Symptoms or Entry Conditions This procedure is entered from:
- a. EP/1/A/5000/E-O EP/1/NSOOO/E-O (Reactor Trip Or Safety Injection), Step 27, EP/1/A/5000/E-1 EP/1/NSOOO/E-1 (Loss Of EP/1/A/5000/E-2 (Faulted Steam Generator Reactor Or Secondary Coolant), Step 7, and EP/1/NSOOO/E-2 Isolation), Step 11 when specified termination criteria are satisfied.
- b. EP/1/NSOOO/FR-H.1 EP/1/A/5000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 48, after secondary heat sink has been re-established and S/I has been terminated.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 2of76 20f76 Rev 25DCS ACTIONIEXPECTED RESPONSE ACTION/EXPECTED RESPONSE NOT OBTAINED C. Operator Actions
- 1. Monitor Enclosure 1 (Foldout Page).
- 2. Ensure 5/1 - RESET:
- a. ECCS. a. Perform the following:
_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) Concurrently implement Enclosure 6 (ECCS Master Reset) while continuing in this procedure.
- b. DIG load sequencers. b. Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB) (AB-560, BB-46, Rm 372).
- c. IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on.
- 3. Ensure the following containment isolation signals - RESET:
- Phase A
- Phase B.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 30f76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. Establish VI to containment as follows: Perform the following:
- Ensure 1VI-77B (VI Cont Isol) - OPEN. a. Align N2 to the Pzr PORVs by opening the following valves:
- Verify VI pressure - GREATER THAN 85 PSIG.
- 1NI-438A{Emer N2 From CLA A To 1NC-34A)
- 1NI-439B (Emer N2 From CLA B To 1NC-32B).
- b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 40f76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED lBOP! 5.
- 5. Verify proper NS pump operation as follows:
- a. Containment pressure - HAS a. GO TO Step 6.
EXCEEDED 3 PSIG.
- b. Verify the following valves - OPEN: b. Perform the following:
- 1FW-27 FW-27AA (ND Pump 1A Suct From _ 1) WHEN containment pressure is less FWST) than 1 PSIG, THEN perform Steps 5.d through 5.f.
- 1FW-55B (ND Pump 1B Suct Suet From FWST). _ 2) GO TO Step 6.
- c. Containment pressure - LESS THAN c. Perform the following:
2.4 PSIG. _ 1) WHEN containment pressure is less than 2.4 PSIG, THEN perform Step 5. _ 2) GO TO Step 6.
- d. Reset NS.
- e. Stop NS pumps.
- f. Close the following valves:
- 1NS-29A (NS Spray Hdr 1A Cont Isol)
- 1NS-32A (NS Spray Hdr 1A Cont Isol)
- 1NS-15B (NS Spray Hdr 1B Cont Isol)
- 11NS-12B NS-12B (NS Spray Hdr 1 1B B Cont Isol).
- 6. Ensure only one NV pump - ON.
~
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 EP/1/A/5000/ES-1.1 50f76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. Verify NC pressure - STABLE OR Perform the following:
INCREASING.
- a. Ensure Pzr spray valves - CLOSED.
- b. IF NC pressure continues to decrease, THEN GO TO EPI1IA15000/ES-1.2 EP/1/A/5000/ES-1.2 (Post LOCA Cooldown And Depressurization ).
Depressu rization).
- 8. Verify VI pressure - GREATER THAN 50 In subsequent steps, control room PSIG. control is lost for the following valves and local operation will be required:
- 1NV-294 (NV Pmps A&B Disch Flow Ctrl)
- 1NV-309 (Seal Water Injection Flow).
- 9. Isolate NV 5/1 SII f10wpath flowpath as follows:
- a. Verify the following valves - OPEN: a. IF NV pump suctions are aligned for Cold Leg Recirc, THEN:
- 1NV-252A (NV Pumps Suct From FWST) _ 1) Close 1NV-309 (Seal Water Injection Flow).
- 1NV-2538 NV-253B (NV Pumps Suct From FWST). 2) IF control of 1NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:
_ a) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ b) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to control seal injection flow as required in subsequent steps.
- 3) Open the following valves:
- 1NV-312A (Chrg Line Cont Isol)
- 1NV-3148 NV-314B (Chrg Line Cont Isol).
(RNO continued on next page)
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 60f76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued)
- 4) IF 1NV-312A OR 1NV-314B cannot be opened, THEN dispatch operator to open affected valve(s). REFER TO the following enclosure(s) for affected valve(s):
- Enclosure 8 (locally Open 1NV-312A)
- Enclosure 10 (locally Open 1NV-314B).
_ 5) Do not continue in this procedure until 1NV-312A and 1NV-314B are open. _ 6) IF NC pressure is greater than 1950 PSIG, THEN throttle 1NV-309 or 1NV-311 to 50% open. _ 7) Open 1NV-294 (NV Pmps A&B Disch Flow Ctrl).
- 8) IF control of 1NV-294 is lost from the control room, THEN:
_ a) Place the controller for 1NV-294 in the 100% demand position. _ b) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) to control charging flow as required in subsequent steps.
- 9) Close the following valves:
_ . 1NI-9A (NV Pmp C/l Inj Isol) _. 1 NI-1 OB (NV Pmp C/l Inj Isol). 1NI-10B (RNO continued on next page)
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/N5000/ES-1.1 EP/1/NSOOO/ES-1.1 7 of 76 70f76 Rev 25DCS Rev2SDCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued)
- 10) IF 1NI-9A OR 1NI-1 08OB cannot be closed, THEN dispatch operator to close affected valve(s). REFER TO the following enclosure(s) for valve{ s):
affected valve(s):
- Enclosure 7 (Locally Close 1NI-9A)
- Enclosure 9 (Locally 1NI-1 OB).
Close 1NI-108).
- 11) Throttle charging and seal injection to maintain the following:
_
- Charging line flow between 60 GPM and 180 GPM
_ .* NC pump seal injection flow. _ 12) GO TO Step 11.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 EP /1/A/5000/ES-1 .1 8 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued)
- b. Verify the following valves - OPEN: b. Perform the following:
- 1NV-203A (NV Pumps A&B Recirc _ 1) Open affected valve(s).
Isol) _ 2) IF 1NV-203A AND 1NV-202B are
- 1NV-202B (NV Pmps A&B Recirc open, THEN GO TO Step 9.c.
Isol).
- 3) Dispatch operator to open affected valve(s):
- 1NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)
- 1NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed).
_ 4) Close 1NV-309 (Seal Water Injection Flow).
- 5) IF control of 1NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:
_ a) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ b) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to control seal injection flow as required in subsequent steps.
- 6) Open the following valves:
- 1NV-312A (Chrg Line Cant Cont Isol)
- 1NV-314B (Chrg Line Cant Cont Isol).
(RNO continued on next page)
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 9 of 76 90f76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued)
- 7) IF 1NV-312A OR 1NV-314B cannot be opened, THEN dispatch operator to open affected valve(s). REFER TO the following enclosure(s) for affected valve(s):
- Enclosure 8 (locally Open 1NV-312A)
- Enclosure 10 (locally Open 1NV-314B).
_ 8) Do not continue in this procedure until 1NV-312A and 1NV-314B are open. _ 9) IF NC pressure is greater than 1950 PSIG, THEN throttle 1NV-309 or 1NV-311 to 50% open. _ 10) Open 1NV-294 (NV Pmps A&B Disch Flow Ctrl).
- 11) IF control of 1NV-294 is lost from the control room, THEN:
_ a) Place the controller for 1NV-294 in the 100% demand position. _ b) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231) to control charging flow as required in subsequent steps.
- 12) Close the following valves:
- 1NI-9A (NV Pmp C/l Inj Isol)
- 1NI-10B (NV Pmp C/l Inj Isol).
(RNO continued on next page)
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 EP/1/A/5000/ES-1.1 10 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued)
- 13) IF 1NI-9A OR 1NI-10B cannot be closed, THEN dispatch operator to close affected valve(s). REFER TO the following enclosure(s) for affected valve(s):
- Enclosure 7 (locally Close 1NI-9A)
- Enclosure 9 (locally Close 1NI-10B).
- 14) Throttle charging and seal injection to maintain the following:
- Charging line flow between 60 GPM and 180 GPM
- NC pump seal injection flow.
_ 15) WHEN 1NV-203A AND 1NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ 16) GO TO Step 11.
- c. Close the following valves: c. Dispatch operator to close affected valve(s). REFER TO the following
- 1NI-9A (NV Pmp C/l Inj Isol) enclosure(s) for affected valve(s):
- 1NI-10B (NV Pmp C/l Inj Isol).
- Enclosure 7 (locally Close 1NI-9A)
- Enclosure 9 (locally Close 1NI-10B).
TERMINATE SCENARIO HERE fTERMINATE I
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 EP/1/A15000/ES-1.1 11 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. Establish charging as follows:
- a. Verify all of the following valves - a. IF all the valves are closed, THEN OPEN: perform the following:
- 1NV-44A (NC Pmp A Seal Supply _ 1) Open 1NV-309 (Seal Water Cont Isol) Injection Flow).
- 1NV-55A (NC Pmp B Seal Supply _ 2) IF control of 1 NV-309 (Seal Water Cont Isol) Injection Flow) is lost from the control room, THEN dispatch
- 1NV-66A (NC Pmp C Seal Supply operator with radio to open 1NV-311 Cont Isol) (Seal Wtr Inj Flow Ctrl Byp)
(AB-555, JJ-54, Rm 233).
- 1NV-77A (NC Pmp D Seal Supply Cont Isol). 3) Open the following valves:
_ . 1NV-312A (Chrg Line Cont Isol) _ . 1NV-314B (Chrg Line Cont Isol). NV-312A OR 1NV-314B cannot
- 4) IF 1NV-312AOR be opened, THEN dispatch operator to open affected valve(s). REFER TO the following enclosure(s) for affected valve(s):
- Enclosure 8 (Locally Open 1NV-312A)
- Enclosure 10 (Locally 1NV-314B).
Open 1NV-314B). _ 5) Throttle 1NV-294 (NV Pmps A&B Disch Flow Ctrl) to maintain charging flow less than 180 GPM.
- 6) IF 1NV-294 cannot be operated from the control room, THEN:
_ a) Place the controller for 1NV-294 in the 100% demand position. _ b) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & Ctrllsol) B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) to maintain charging line flow less than 180 GPM. (RNO continued on next page)
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 EP/1/Al5000/ES-1.1 12 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued)
_ 7) GO TO Step 11.
- b. Throttle 1NV-294 (NV Pmps A&B Disch b. Perform the following:
Flow Ctrl) for 32 GPM charging line flow. _ 1) Place the controller for 1NV-294 in the 100% demand position. _ 2) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231) for 32 GPM charging line flow. _ 3) Throttle 1NV-295 to control charging flow as required in subsequent steps.
- c. Close 1NV-309 (Seal Water Injection c. Dispatch operator with radio to perform Flow). the following:
_ 1) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ 2) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps.
- d. Open the following valves: d. Dispatch operator to open affected valve(s). REFER TO the following
- 1NV-312A (Chrg Line Cont Isol) enclosure(s) for affected valve(s):
- 1NV-314B (Chrg Line Cont Isol).
- Enclosure 8 (Locally Open 1NV-312A)
- Enclosure 10 (Locally Open 1NV-314B).
- e. Verify 1NV-309 - ABLE TO BE e. GO TO Step 10.g.
OPERATED FROM THE CONTROL ROOM.
- f. Place 1NV-309 in auto.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 EP/1/A/5000/ES-1.1 13 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued)
- g. Perform the following:
- Maintain charging flow less than 180 GPM.
- Maintain 32 GPM seal water flow.
- 11. Control charging as follows:
- a. Control charging flow to maintain Pzr level stable.
- b. Verify Pzr level - STABLE OR b. Perform the following:
INCREASING. _ 1) IF any S/G is faulted, THEN do not continue until faulted S/G depressurization stops OR Pzr level can be maintained stable or increasing.
- 2) IF no S/G is faulted OR Pzr level continues to decrease after faulted S/G depressurization stops, THEN perform the following:
a) Open the following valves:
- 1NI-9A (NV Pmp C/l Inj Isol)
_ . 1NI-10B (NV Pmp C/l Inj Isol). b) Close the following valves:
- 1NV-312A (Chrg Line Cont Isol)
- 1NV-314B (Chrg Line Cont Isol).
_ EP/1/A15000/ES-1.2 c) GO TO EP/1/A/5000/ES-1.2 (Post lOCA Cooldown And Depressurization Depressurization).).
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/11A15000/ES-1.1 EP/1/A/5000/ES-1.1 14 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 12. Verify conditions are met to stop NI pumps as follows:
- a. Verify the following conditions are a. Perform the following:
satisfied: _ 1) IF any S/G is faulted, THEN do not
- NC pressure - STABLE OR continue until faulted S/G INCREASING depressurization stops OR criteria for stopping NI pumps is met.
- NC pressure - GREATER THAN 1620 PSIG. _ 2) IF no S/G is faulted OR conditions for stopping NI pumps cannot be satisfied after faulted S/G depressurization stops, THEN GO EP/11A15000/ES-1.2 (Post TO EP/1/A/5000/ES-1.2 LOCA Cooldown And Depressurization ).
Depressurization). _ b. Stop NI pumps.
- 13. Ensure all ND pump(s) with suction aligned to FWST - STOPPED.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 15 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 14. Verify 5/1 flow not required as follows:
- a. NC subcooling based on core exit TICs a. Perform the following:
- GREATER THAN O°F. OaF.
_ 1) Manually start S/I pumps and align valves as necessary to restore NC subcooling. _ 2) GO TO EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant).
- b. Pzr level - GREATER THAN 11 % b. Perform the following:
(20% ACC). _ 1) Control charging flow to restore Pzr level to greater than 11 % (20% ACC).
- 2) IF Pzr level cannot be maintained greater than 11 % (20% ACC).
THEN: _ a) Manually start S/I pumps and align valves as necessary to restore Pzr level. _ b) GO TO EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant).
CNS SAFETY IINJECTION NJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 16 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 15. Transfer condenser steam dump to pressure control mode as follows:
- a. Verify condenser - AVAILABLE: a. Perform the following:
* "C-9 COND AVAILABLE FOR STM _ 1) Dump steam using intact S/G DUMP" status light (1SI-18) - LIT. PORV(s) in subsequent steps.
- MSIVs on intact S/G(s) - OPEN. _ 2) GO TO Step 16 .
- b. Ensure "STM DUMP CTRL" - SET AT 1090 PSIG STEAM HEADER PRESSURE.
- c. WHEN the steam dump valves are closed, THEN:
_ Reset C-7A and C-7B.
- 1) ResetC-7Aand
_ 2) Place "STM DUMP CTRL" in manual. _ 3) Adjust the "STM DUMP CTRL" to 0% demand. _ 4) Place the steam dumps in pressure mode. _ 5) Place the "STM DUMP CTRL" in auto.
- 16. Verify all NC T-Hots - STABLE. Throttle steam flow and total feed flow as required to maintain NC System temperatures stable.
- 17. Establish normal letdown as follows:
- a. Verify VI pressure - GREATER THAN a. Perform the following:
35 PSIG. _ 1) WHEN VI pressure is greater than 35 PSIG, THEN perform Steps 17.b through 17.0. _ 2) GO TO Step 18.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/11A15000/ES-1.1 E P111A/5000/ES-1.1 17 of 76 170f76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 17. (Continued) level-- GREATER THAN 25%
- b. Verify Pzr level b. Perform the following:
(34% ACC). _ 1) WHEN Pzr level increases to greater than 25% (34% ACC), THEN perform Steps 17.c through 17.0. _ 2) GO TO Step 18.
- c. Ensure the following valves - CLOSED:
- 1KC-56A (KC To ND NO Hx 1A Sup Isol) 1KC-81 B (KC To ND
- 1KC-81B NO Hx 1B 1B Sup Isol).
- d. Verify the following EMF trip 1 lights- d. Perform the following:
DARK: _ 1) Notify station management to
- 1EMF-53A (Containment Trn A) evaluate restoring normal letdown
- 1EMF-53B (Containment Trn B). with high NC System activity.
_ 2) Establish excess letdown. REFER TO Enclosure 2 (Establishing Excess Letdown). _ 3) WHEN station management approval to establish normal letdown is obtained, THEN perform Steps 17.e through 17.0. _ 4) GO TO Step 18.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 18 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 17. (Continued)
- e. Verify the following valves for the e. Manually open valve(s).
operating KC train(s) - OPEN:
- Train A:
- 11KC-1A KC-1 A (Au x Bldg Non-Ess Ret Hdr Isol)
- 1KC-50A (Aux Bldg Non-Ess Hdr Isol).
- Train B:
- 1KC-2B (Aux Bldg Non-Ess Ret Hdr Isol)
- 1KC-53B (Au(Auxx Bldg Non-Ess Hdr Isol).
- f. Ensure 1NV-849 (Letdn Flow Var Orif Ctrl) valve demand position - 0%.
- g. Open the following valves: g. Perform the following:
- 1NV-1A (NC Letdn To Regen Hx Isol) 1) Ensure the following valves -
CLOSED:
- 1NV-2A (NC Letdn To Regen Hx Isol)
- 11NV-1A NV-1A (NC Letdn To Regen Hx
- 1NV-15B (Letdn ContCant Isol). Isol)
- 1 NV-2A (NC Letdn To Regen Hx Isol)
- 1 NV-15B (Letdn Cont Cant Isol).
_ 2) Establish excess letdown. REFER TO Enclosure 2 (Establishing Excess Letdown). _ 3) GO TO Step 18.
- h. While performing the following steps, manually adjust charging flow to maintain letdown subcooled.
- i. Throttle 1 NV-148 (Letdn Press Control) 1NV-148 to 45% demand.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 EP/1/A/5000/ES-1.1 190f76 19 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 17. (Continued)
_ j. Open 1NV-10A NV-1 OA (Letdn Orif 18 1B Otlt Cont Isol).
- k. Throttle open 1NV-849 (Letdn Flow Var Orif Ctrl) in 1% to 5% increments until one of the following conditions is met:
_ . Letdown flow and letdown pressure increases OR _ .* Valve demand position is 60% open. I. Do not continue until one of the above conditions is met. _ m. Verify letdown flow and letdown m. Perform the following: pressure - HAS INCREASED.
- 1) Close the following valves:
- 1NV-849 (Letdn Flow Var Orif Ctrl)
NV-1 OA (Letdn Orif 18
- 1NV-10A 1 B Otlt Cont Isol)
- 1NV-1A (NC Letdn To Regen Hx Isol)
- 1NV-2A (NC Letdn To Regen Hx Isol).
_ 2) Establish excess letdown. REFER TO Enclosure 2 (Establishing Excess Letdown). _ 3) GO TO Step 18.
- n. Adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure between 150 - 200 PSIG.
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- 17. (Continued)
- o. WHEN 5 minutes have elapsed, THEN perform the following:
_ 1) Adjust 1NV-849 (Letdn Flow Var Orif Ctrl) in 1% increments to desired letdown flow.
- 2) WHEN letdown at desired flow, THEN perform the following:
_ 1NV-148 (Letdn Press a) Adjust 1NV-148 Control) to maintain letdown pressure at 350 PSIG. _ b) Ensure 1NV-148 (Letdn Press Control) -IN
- IN AUTO.
_ 3) IF AT ANY TIME additional letdown flow desired, THEN establish letdown with the 45 or 75 GPM orifice. REFER TO OP/1/A/6200/001 (Chemical and Volume Control System).
- 18. Ensure proper operation of VCT Makeup Control System as follows:
- a. Determine the required shutdown boron concentration. REFER TO ROD Book, Section 5.11.
- b. WHEN the required shutdown boron concentration is determined, THEN:
_ 1) Adjust VCT YCT makeup controls for a boron concentration that is greater than or equal to the required shutdown boron concentration. _ 2) Ensure "NC MAKEUP MODE SELECT" -IN "AUTO". _ 3) Place the "NC MAKEUP CONTROL" switch momentarily to the "START" position.
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- 19. Align NV pump suction to the VeT as follows:
- a. Verify at least one of the following NV a. Perform the following:
pump suction valves - OPEN: _ 1) Notify station management for _ . 1NV-252A (NV Pumps Suct From guidance to restore NV pump FWST) suction to the VCT. OR _ 2) GO TO Step 20. _ . 1NV-2538 (NV Pumps Suct From FWST).
- b. Open the following valves:
_ . 1NV-188A (VCT Otlt Isol) _ . 1NV-1898 (VCT Otlt Isol).
- c. Close the following valves:
- 1NV-252A (NV Pumps Suct From FWST)
- 1NV-2538 (NV Pumps Suct From FWST).
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- 20. Maintain Pzr pressure stable using Pzr Stabilize Pzr pressure as follows:
heaters and normal Pzr spray.
- a. IF normal Pzr spray is not available AND letdown is in service, THEN control Pzr pressure using NV aux spray as follows:
1)
- 1) Ensure the following valves -
CLOSED:
- 1NC-27 (pzr Spray Ctrl Frm Loop A)
- 1NC-29 (pzr Spray Ctrl Frm Loop B)
- 1NV-39A (NV Supply To Loop D 1501)
Isol)
- 1NV-32B (NV Supply To Loop A 1501).
Isol). _ 2) Maintain charging flow less than 180 GPM. _ 3) Throttle 1NV-37 NV-37AA (NV Supply To Pzr Aux Spray) and charging flow as required.
- b. IF letdown is isolated OR NV aux spray is not available, THEN control pressure using one Pzr PORV.
- 21. Control intact S/G SIG levels as follows:
- a. Verify N/R level in all intact S/Gs - a. Maintain total feed flow greater than GREATER THAN 11 % (29% ACe). ACC). 450 GPM until at least one intact S/G N/R level greater than 11 % (29% ACC).
- b. Throttle feed flow to maintain all intact b. IF N/R level in any S/G continues to S/Gs N/R levels between 11 % increase in an uncontrolled manner, (29% ACC) and 50%. THEN stop feed flow to that S/G.
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- 22. Verify NC pump cooling is aligned as follows:
- a. Verify KC aligned to Reactor Bldg Non a. Perform one of the following based on Essential Header: seal injection status:
- A train _ .* IF NC pump seal injection flow is greater than 6 GPM to each NC
- 1KC-3A (Rx Bldg Non-Ess Ret Hdr pump, THEN manually open the Isol) - OPEN affected valve(s).
- 1KC-230A (Rx Bldg Non-Ess Hdr
- IF NC pump seal injection flow is less Isol) - OPEN than 6 GPM to any NC pump, THEN:
- A train KC pump(s) - ON.
OR NC pump seals will be cooled during NC
- B train System cooldown .
- 1KC-228B (Rx Bldg Non-Ess Hdr _ 1) Maintain NC pump seal injection Isol) and thermal barrier cooling isolated to the affected NC 1KC-18B (Rx Bldg Non-Ess Ret
- 1KC-18B pump(s).
Hdr Isol) _ 2) GO TO Step 23.
- B train KC pump(s) - ON.
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- 22. (Continued)
- b. Verify the following valves - OPEN: b. Perform one of the following based on seal injection status:
- 1KC-394A (NC Pump 1A Therm Bar Otlt)
- IF NC pump seal injection flow is greater than 6 GPM to each NC
- 1KC-364B (NC Pump 1B Therm Bar pump, THEN perform the following:
Otlt) _ 1) Manually open the affected
- 1KC-345A (NC Pump 1C Therm Bar valve(s).
Otlt) _ 2) Monitor KC surge tank levels for
- 1KC-413B (NC Pump 1D Therm Bar signs of KC leakage.
Otlt)
- 3) IF AT ANY TIME KC leakage
- 1KC-424B (NC Pumps Ret Hdr Cont suspected, THEN close the Isol) following:
- 1KC-425A (NC Pumps Ret Hdr Cont
- 1KC-424B (NC Pumps Ret Hdr Isol) Cont Isol)
- 1KC-338B (NC Pumps Sup Hdr Cont
- 1KC-425A (NC Pumps Ret Hdr Isol). Cont Isol)
_ .* 1KC-338B (NC Pumps Sup Hdr Cont Isol).
- IF NC pump seal injection flow is less than 6 GPM to any NC pump, THEN:
NC pump seals will be cooled during NC System cooldown. _ 1) Maintain NC pump seal injection and thermal barrier cooling isolated to the affected NC pump(s). _ 2) GO TO Step 23.
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- 22. (Continued)
- c. NC pump seal injection flow - c. Perform one of the following based on GREATER THAN 6 GPM TO EACH NC seal injection status:
PUMP. _ . IF seal injection flow exists, THEN throttle 1NV-294 (NV Pmps A&B Disch Flow Ctrl) to maintain 32 GPM seal injection flow. OR
- IF seal injection flow has been lost, AP/1/Al5500/008 THEN REFER TO AP/1/N55001008 (Malfunction of Reactor Coolant Pump), Case II. (Loss of Seal Water Injection).
- 23. Establish NC pump seal return flow as follows:
- a. Verify NC pump seal injection flow - a. Perform the following:
GREATER THAN 6 GPM TO EACH NC PUMP. _ 1) WHEN NC pump seal injection is restored, THEN perform Steps 23.b through 23.g. _ 2) GO TO Step 24.
- b. Verify 1AD-7, D/1 0/1 "SEALWATER HX b. Perform the following:
KC HI/LO FLOW" - DARK. _ 1) Notify station management to evaluate restoring NC pump seal return flow. _ 2) WHEN notified by station management OR 1AD-7, D/1 0/1 dark, THEN perform Steps 23.c through 23.g. _ 3) GO TO Step 24.
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- 23. (Continued)
- c. Verify the following EMF trip 1 lights lights-- c. Perform the following:
DARK: _ 1) Notify station management to
- 11EMF-53A EMF-53A (Containment Trn A) evaluate restoring NC pump seal
- 1EMF-53B (Containment Trn B). return with high NC System activity.
_ 2) WHEN station management approval to establish NC pump seal return is obtained, THEN perform Steps 23.d through 23.g. _ 3) GO TO Step 24.
- d. Verify NCDT pressure - LESS THAN d. Perform the following:
VCT PRESSURE. _ 1) Consult with station management to establish normal NCDT pressure. REFER TO OP/1/A16500/014 OP/1/A/6500/014 (Operations Controlled Liquid Waste Systems). _ 2) WHEN NCDT pressure is less than VCT pressure, THEN perform Steps 23.e through 23.g. _ 3) GO TO Step 24.
- e. Open the following valves:
- 1NV-89A (NC Pmps Seal Ret Cont Isol)
- 1NV-91 B (NC Pmps Seal Ret Cont Isol).
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- 23. (Continued)
- f. IF AT ANY TIME NCDT pressure is greater than VCT pressure, THEN perform the following:
_ 1) Monitor NC Pump #1 seal dP. _ 2) Verify excess letdown - ISOLATED. _ 2) Align 1NV-125B (Excess Letdn Hx Otlt Ctrl) to "NCDT".
- 3) Close the following valves:
- 1NV-89A (NC Pmps Seal Ret Cont Isol)
- 1NV-91 B (NC Pmps Seal Ret Cont Isol).
_ g. Verify excess letdown -ISOLATED. _ g. Align 1NV-125B (Excess Letdn Hx Otlt Ctrl) to "VCT".
- 24. Verify all AC busses are energized by Perform the following:
offsite power as follows:
- a. Restore offsite power while continuing
- A Train: with this procedure. REFER TO AP/11A155001007 AP/1/A/5500/007 (Loss of Normal
* "FTA B/O NORM FDR FRM A TC" -
ATC" Power). CLOSED
- b. Manually start following equipment:
* "DIG 1A BKR TO ETA" - OPEN
- Start all available CRD vent fans.
1ETA - ENERGIZED.
- 1ETA-
- Dispatch operator to start available VI
- B Train: compressors.
* "FTB B/O NORM FDR FRM ATD" A TD" -
CLOSED
* "DIG 1B BKR TO ETB" - OPEN
- 1ETB - ENERGIZED.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/11A15000/ES-1.1 EP/1/A/5000/ES-1.1 28 of 76 Rev 25DCS ACTION/EXPECTED ACTIONIEXPECTED RESPONSE RESPONSE NOT OBTAINED Preference should be given to starting 1B NC pump to provide normal Pzr spray capability. If 1B NC pump is not available, then two or three NC pumps may need to be started to provide normal Pzr spray capability.
- 25. Verify 1B NC pump - ON. IF NC pumps need to be started to provide Pzr spray flow, THEN start NC pumps as follows:
- a. Start NC pumps. REFER TO Enclosure 3 (NC Pump Start).
- b. IF all NC pumps are off, THEN verify Natural Circulation until an NC pump can be started. REFER TO Enclosure 4 (Natural Circulation Monitoring Parameters).
- 26. Determine status of NIls as follows:
- a. Verify I/R channels - LESS THAN a. Perform the following:
10- 10 AMPS. _ 1}
- 1) WHEN I/RIIR channels are less than 10-10 Amps, THEN perform Steps 26.b and 26.c.
_ 2) GO TO Step 27. 2}
- b. Verify SIR channels - ENERGIZED. b. Place SIR select switches in "RESET".
- c. Transfer one channel of the "NIS RECORDER" to SIR instrumentation.
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- 27. Verify conditions to stop operating DIGs as follows:
- a. At least one DIG - ON. a. GO TO Step 28.
- b. Verify 1ETA is energized by offsite b. Perform the following:
power as follows: _ 1) Attempt to restore offsite power to _1}
* "DIG 1A BKR TO ETA" - OPEN affected switchgear. REFER TO AP/1/A/SSOOI007 (Loss of Normal AP/1/A15500/007
- 1ETA- ENERGIZED. Power).
_ 2) GO TO Step 27.d. 2} 1A
- c. Dispatch operator to stop 1 A DIG and place in standby readiness. REFER OP/1/A/63S01002 (Diesel Generator TO OP/1/A16350/002 Operation).
- d. Verify 1ETB is energized by offsite d. Perform the following:
power as follows: _ 1) Attempt to restore offsite power to _1}
* "DIG 1B BKR TO ETB" - OPEN affected switchgear. REFER TO AP/1/A/SSOOI007 (Loss of Normal AP/1/A15500/007
- 1ETB - ENERGIZED. Power).
_ 2}
- 2) GO TO Step 28.
- e. Dispatch operator to stop 1B DIG and place in standby readiness. REFER OP/1/A/63S01002 (Diesel Generator TO OP/1/A16350/002 Operation).
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- 28. Ensure the following signals - RESET:
- Containment Ventilation Isolation
- Temperature control valves:
OTLT TN Ss "1 RN-291 KC HX 1A OTLT
* "1RN-291 RESET"
* "1RN-351 KC HX 1B OTLT TN Ss RESET"
* "1 KC-57A NO HX 1A FLOW CTRL Ss RESET"
* "1 KC-82B NO HX 1B FLOW CTRL Ss RESET"
* "1 NO-26 NO HX 1A OTLT CTRL Ss RESET"
* "1NO-60 "1 NO-60 NO HX 1B1B OTLT OTLT CTRL Ss RESET"
* "1 NO-27 NO HX 1A BYP CTRL Ss "1NO-27 RESET" "1NO-61
* "1 NO-61 NO HX 1 1B B BYP CTRL Ss RESET".
* "KC NC NI NM TRAIN A ST VALVES"
* "KC NC NI NM TRAIN B ST VALVES"
- NW System valves:
- ST reset
- SP reset.
- Boric acid transfer pumps.
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- 29. Shutdown unnecessary plant equipment as follows:
- a. Verify turbine generator megawatt a. Perform the following:
output - LESS THAN OR EQUAL TO ZERO MW. ZEROMW. _ 1) Determine and correct cause of 1} continued turbine generator output. _ 2) WHEN turbine generator megawatt 2} output less than or equal to zero MW, THEN perform Step 29.b and Step 29.c. _ 3) GO TO Step 29.d. 3}
- b. Ensure the following breakers and MODs - OPEN:
MODs-OPEN:
- MOD 1BG and 1BT
- MOD 1AG and 1AT
- Generator Breakers 1A and 1B. 1B.
- c. Ensure main generator "EXCITATION"-
OFF
- d. Verify "MAN/AUTO REG" select switch d. Transfer to manual mode.
"MAN" mode light - LIT.
- e. Dispatch operator to secure NF chillers and pumps.
- f. Stop excess condensate booster pumps.
_ g. Stop excess hotwell pumps.
- h. Stop C heater drain pumps.
- i. Stop excess RC pumps and cooling tower fans. REFER TO OP/1/B/6400/001A (Condenser Circulating Water System).
_ j. WHEN CA is no longer needed to feed S/Gs, THEN shutdown the CA System following the automatic start and return CA System to standby readiness. OP/1/A/6250/002 (Auxiliary REFER TO OP/1/Al6250/002 Feedwater System).
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- 29. (Continued)
- k. Stop unnecessary KC pumps. REFER TO OP/1/A/6400/005 OP/1/A/64001005 (Component Cooling Water System).
I. Stop unnecessary RN pumps. REFER TO OP/0/A/6400/006C OP/O/A/64001006C (Nuclear Service Water System).
- 30. WHEN station management concurrence is obtained, THEN restore plant equipment to shutdown alignment as follows:
- a. Establish VI to containment airlocks by opening the following valves:
- 11ASV5080 (Upper PAL Air Sup CII)C/I)
C/I).
- 11ASV5160 (Lower PAL Air Sup CII).
- b. Isolate NW System as follows:
- 1) Close the following valves:
- 1NW-35A (Cont Vlv Inj Hdr 1A Cont Isol)
NW-1 058 (Cont Vlv Inj Hdr 1B
- 1NW-105B 18 Cont Isol).
_ 2) Restore NW System to standby readiness. REFER TO OP/1/A/6200/019 OP/1/A/62001019 (Containment Valve Injection Water System).
- c. Reset the following switches:
"NO&NSROOMSMPPMP1~
- liND & NS ROOM SMP PMP 1A" "NO&NSROOMSMPPMP1~
- liND & NS ROOM SMP PMP 1B" "NO&NSROOMSMPPMP2~
- liND & NS ROOM SMP PMP 2A" (2MC11)
"NO & NS ROOM SMP PMP 2B"
- liND 28" (2MC11).
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- 30. (Continued)
- d. Depress the "DEFEAT" push buttons on the following switches:
* "C-LEG RECIR FWST TO CONT SUMP SWAP SWAPTRN TRN A"
* "C-LEG RECIR FWST TO CONT SUMP SWAP TRN B".
- e. Restore cooling to NCDT Hx by opening the following valves:
- 1KC-320A (NCDT Hx Cool Supply Cont Isol)
- 1KC-333A (NCDT Hx Cool Ret Cont Isol)
- 1KC-332B (NCDT Hx Cool Ret Cont Isol).
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- 30. (Continued)
- f. Open the following valves:
- 1RF-457B (RF Cont 1501)
- 1VI-312A (VI To VP Cont 1501) 1YM-119B (YM Cont 1501)
- 1YM-119B Isol)
- 1WL-867A (VUCDT Cont 1501)
- 1WL-805A (NCDT Pump Disch Cont 1501)
- 1WL-450A (NCDT Vent Cont 1501)
- 1WL-825A (Cont Smp Pmps Disch Cont 1501)
- 1WL-869B (VUCDT Cont 1501)
- 1WL-807B (NCDT Pumps Disch Cont 1501) 1WL-451B
- 1WL-451 B (NCDT Vent Cont 1501)
- 1WL-827B (Cont Smp Pmps Disch Cont 1501)
- 1RN-839A (AB Sup Unit YV/RN Sup 1501) 1RN-841 B (AB Sup Unit YV/RN Ret
- 1RN-841B 1501)
- 1KC-430A (Rx Bldg Drn Hdr Cont 1501)
- 1KC-429B (Rx Bldg Drn Hdr Cont 1501).
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- 30. (Continued)
- g. Restore FWST to normal as follows:
_ 1) Open 1FW-33A (FWST Recirc Loop 1} Isol). _ 2}
- 2) Open 1FW-49B 1 FW-49B (FWST Recirc Loop Isol).
_ 3}
- 3) Start one FW recirc pump.
_ 4) Align to refill the FWST. REFER 4} TO OP/11A16200/014 OP/1/A/6200/014 (Refueling Water System).
- h. Restore KF System to normal. REFER TO OP/11A16200/005 OP/1/A/6200/005 (Spent Fuel Cooling System).
- i. Restore containment EMFs to normal by opening the following valves:
- 1MISV5230 (Cont (Cant EMF Sup Otsd Cont Cant Isol)
- 1MISV5232 (Cont (Cant EMF Ret Otsd Cont Cant Isol)
- 1MISV5231 (Cont (Cant EMF Sup Insd Cont Cant Isol)
- 1MISV5233 (Cont (Cant EMF Ret Insd Cont Cant Isol).
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- 30. (Continued)
- j. Restore the NM System to normal by opening the following valves:
- 1NM-191B (S/G 1ASmpi HdrCont Isol)
NM-201A
- 1NM-201 A (S/G 1B Smpl Hdr Cont Cant Isol)
- 1NM-211 B (S/G 1C Smpl Hdr Cont Cant Isol)
NM-221 A (S/G
- 1NM-221A {S/G 1D Smpl Hdr Cont Cant Isol)
Isol} 1 NM-190A (S/G 1A Bldwn Smpl Cont
- 1NM-190A Cant Isol)
- 1NM-200B (S/G 1B Bldwn Smpl Cont Cant Isol)
- 1 NM-21 OA (S/G 1 1NM-210A C Bldwn Smpl Cont 1C Cant Isol)
- 1NM-220B (S/G 1D Bldwn Smpl Cont Cant Isol)
Cant Isol)
- 1 NM-22A (Hot Leg A Smpl Cont
- 1NM-26B (Hot Leg Smpl Hdr ContCant Isol).
- k. Restore VE System to normal. REFER TO OP/11A164501002 OP/1/A/6450/002 (Annulus Ventilation System).
I. Restore NF System to normal. REFER TO OP/0IAl62001008 OP/0/A/6200/008 (Ice Condenser Refrigeration System). _ m. Restore VF System to normal. REFER TO OP/11A164501004 OP/1/A/6450/004 (Fuel Pool Ventilation System).
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- 30. (Continued)
- n. Restore Containment Ventilation System to normal. REFER TO OP/1/A164501001 OP/1/A/6450/001 (Containment Ventilation System).
- o. Restore VA System to normal. REFER TO OP/0IAl64501003 OP/0/A/6450/003 (Auxiliary Building Ventilation System).
_ p. Restore VC/yC VCIYC to normal. REFER TO OP/0IAl64501011 OP/0/A/6450/011 (Control Room Area Ventilation/Chilied Ventilation/Chilled Water System). _ q. Dispatch operator to restore Technical Support Center Ventilation System to normal. REFER TO OP/0/B/64501024 OP/0/B/6450/024 (Technical Support Center Ventilation System).
- r. Perform required steps in OP/1/A161 OP/1/A/61 001003 00/003 (Controlling Procedure For Unit Operation).
- s. WHEN the required steps of OP/1/A161 OP/1/A/61 001003 00/003 (Controlling Procedure For Unit Operation) are completed, THEN perform the required steps in OP/1/A161 OP/1/A/61 001002 00/002 (Controlling Procedure For Unit Shutdown).
- t. Restore BB System to normal. REFER TO OP/1/A162501008 OP/1/A/6250/008 (Steam Generator Blowdown).
- u. Notify Reactor Group Duty Engineer to investigate the cause of Reactor Trip.
PT/0IAl41501002 A REFER TO PT/0/A/4150/002 (Transient Investigation).
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- 30. (Continued)
- v. Reset automatic SII initiation logic as follows:
_ 1) Ensure all automatic SII 1} S/I and 1}
- 1) Perform the following:
Reactor Trip initiation signals - CLEARED. _ a) WHEN all SII AND Reactor Trip a} signals are clear, THEN perform Step 30.v. _ b} b) GO TO Step 30.w. _ 2}
- 2) Dispatch operator to shutdown the CRD M/G MIG sets. REFER TO OP/1/A/61501008 OP/1/A/6150/o08 (Rod Control).
3}
- 3) WHEN the CRD MIG sets are shutdown, THEN:
_ a} a) Close the Reactor Trip Breakers. _ b) Verify the "AUTO SII BLOCKED" b} status light (1SI-13) - DARK. c) Perform the following steps c} simultaneously:
- Depress the Feedwater Isolation "RESET" push buttons.
- Open the Reactor Trip Breakers.
- w. Verify power change - GREATER w. GO TO Step 31.
THAN OR EQUAL TO 15% RATED THERMAL POWER WITHIN 1 HOUR PERIOD.
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- 30. (Continued)
- x. Notify the following sections to take appropriate samples:
- Radiation Protection to sample and analyze gaseous effluents. REFER TO Selected Licensee Commitments Manual, Section 16.11-6.
- Primary Chemistry to sample for isotopic analysis of iodine. REFER TO Tech Spec 3.4.16.2 (Sample must be taken between 2 hours and 6 hours following last power change greater than or equal to 15% rated thermal power within a 1 hour period).
- 31. Maintain the following plant conditions stable:
- Pzr pressure
- Pzr level
- NC temperatures
- All intact S/G levels.
- 32. Verify MSIVs on all intact S/Gs - OPEN. Perform the following:
- a. IF MSIVs are closed to isolate a break downstream of the MSIVs, THEN GO TO Step 33.
(RNO continued on next page)
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- 32. (Continued)
- b. Reset Main Steam Isolation signal as follows:
- 1) IF any S/G pressure less than 775 PSIG, THEN perform the following:
_ a) IF "P-11 PZR S/I BLOCK PERMISSIVE" status light (1SI-18) is dark, THEN GO TO Step 33. b) IF "P-11 PZR SII S/I BLOCK PERMISSIVE" status light (1SI-18) is lit, THEN: _ (1) Depress ECCS steam pressure "BLOCK" pushbuttons. push buttons. _ (2) Verify main steam isolation blocked status lights (1SI-13) - LIT. _ 2) Ensure manual loaders for all MSIV bypass valves - ADJUSTED TO 0%. _ 3) Reset SM Isolation. _ 4) Reset S/G PORVs.
- c. Place "STM DUMP CTRL" in manual.
- d. Adjust the "STM DUMP CTRL" to 0%
demand.
- e. Place the steam dumps in pressure mode.
(RNO continued on next page)
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/11A15000/ES-1.1 EP/1/A/5000/ES-1.1 41 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 32. (Continued)
- f. Perform the following to equalize pressure across MSIVs on intact S/Gs:
_ 1) Open MSIV bypass valve on intact S/Gs. _ 2) IF AT ANY TIME pressure does not equalize as required, THEN isolate steam loads off main steam header. REFER TO Enclosure 5 (Equalizing Across MSIVs).
- g. WHEN all intact S/Gs pressure is within 50 psig of steam header pressure, THEN:
_ 1) Open MSIVs on all intact S/Gs. _ 2) Close all MSIV bypass valves. _ 3) IF "P-12 LO-LO TAVG" status light (1SI-18) is lit, THEN place the steam dump interlock bypass switches in "BYP INTLK." _ 4) Control steam dumps to maintain NC T-Hots - STABLE.
- h. GO TO Step 33.
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A15000/ES-1.1 EP/1/A/5000/ES-1.1 42 of 76 Rev 25DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 33. Verify 5/1 flow not required as follows:
- a. NC subcooling based on core exit TICs a. Perform the following:
- GREATER THAN O°F. OaF.
_ 1) Manually start SII S/I pumps and align valves as necessary to restore NC subcooling. _ 2) GO TO EP/1/A15000/E-1 EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant). level-- GREATER THAN 11
- b. Pzr level 11%
% b. Perform the following:
(20% ACC). _ 1) Control charging flow to restore Pzr level to greater than 11 % (20% ACC).
- 2) IF Pzr level cannot be maintained ACC),
greater than 11 % (20% ACC). THEN: _ a) Manually start S/I pumps and align valves as necessary to restore Pzr level. _ EP/1/A/5000/E-1 (Loss b) GO TO EP/1/A15000/E-1 Of Reactor Or Secondary Coolant).
- 34. Determine required plant recovery procedure as follows:
- a. Verify NC cooldown - REQUIRED. a. GO TO OP/1/A161 OP/1/A/61 001005 (Unit Fast Recovery).
- b. Verify all NC pumps - OFF. b. GO TO OP/1/A161 OP/1/A/61 001002 (Controlling Procedure For Unit Shutdown).
- c. GO TO EP/1/A15000/ES-0.2 EP/1/A/5000/ES-0.2 (Natural Circulation Cooldown).
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 EP/1/A/SOOO/ES-1.1 43 of 76 Enclosure 1 - Page 1 of 2 Rev 25DCS 2SDCS Foldout Page
- 1. S/I 5/1 Reinitiation Criteria:
- IF NC subcooling based on core exit TICs is less than O°F OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN:
- a. Manually start S/I SII pumps and align valves as required to restore subcooling and Pzr level.
EP/1/A/SOOO/E-1 (Loss Of Reactor Or
- b. IF Step 13 has been completed, THEN GO TO EP/1/A/5000/E-1 Secondary Coolant).
- 2. Secondary Integrity Criteria:
- IF pressure in any unisolated S/G is decreasing in an uncontrolled manner OR any un unisolated isolated EP/1/A/SOOO/E-2 (Faulted Steam S/G has completely depressurized, THEN GO TO EP/1/A/5000/E-2 Generator Isolation).
- 3. SGTR Transition Criteria:
- IF level in any S/G is increasing in an uncontrolled manner OR any S/G has abnormal radiation, THEN:
- a. Manually start S/I SII pumps and align valves.
EP/1/A/SOOO/E-3 (Steam Generator Tube Rupture).
- b. GO TO EP/1/A/5000/E-3
- 4. Cold Leg Recirc Switchover Criterion:
- IF FWST level decreases to 37% (1AD-9, 0/8 D/8 "FWST 2/4 LO LEVEL" lit), THEN GO TO EP/1/A/SOOO/ES-1.3 (Transfer To Cold Leg Recirculation).
EP/1/A/5000/ES-1.3 5. S. CA Suction Source Switch over Criteria: Switchover
- IF either of the following annunciators are lit, THEN REFER TO AP/1/A/55001006 AP/1/A/SSOOI006 (Loss of S/G Feedwater):
1AD-S, H/4 "CACST LO LEVEL" _ . 1AD-5, OR B/1 "UST LO LEVEL".
- 1AD-8, 8/1
CNS SAFETY INJECTION TERMINATION PAGE NO. EP/1/A/5000/ES-1.1 EP/1/N5000/ES-1.1 44 of 76 Enclosure 1 - Page 2 of 2 Rev 25DCS Foldout Page
- 6. Loss of Emergency Coolant Recirculation Criteria:
- IF emergency coolant recirculation has been established and is subsequently lost, THEN GO TO EP/1/A/5000/ECA-1.1 EP/1/N5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
Appendix D 0 Scenario Outline Form ES-D-1 2009 NRC ~XAMINATION Facility: Catawba Nuclear Station Scenario No.: 2 Op-Test No.: 20090-1 2009 D-1 SNAP 142 Examiners: Operators: Initial Conditions:
- 100% power
- EFPD = = 25 days
- Boron Concentration is 1348 ppm Turnover:
- 1A DIG was placed in Maintenance Mode and red tagged 2 hours ago for PMs and is expected back in 6 hours.
- Reduce power for control valve movement test to be done by the next shift per OP/1/N61 001003 (Controlling Procedure for Unit Operation), Enclosure 4.3, Unit Operation OP/1/A/61 Between 85% and 100% Power.
Event Malf. No. Event Event No. Type* Description 1 BOP N Borate for power decrease (DCS) 2 RO R Power reduction using turbine in auto Irods lrods as necessary 3 BOP C RN Strainer 1A high DIP SRO TS 4 RO C Steam dump valve 1SB-12 fails open 5 RO C Loss of condenser vacuuml reduce load with turbine in manual 6 BOP C PZR Spray valve 1NC-27 fails open with no manual control SRO TS 7 ALL M Tube rupture on 1A S/G Additional Failures Failure of automatic feedwater (CF) isolation Failure of 1NI-9 and 1NI-1 0 to automatically position S/G PORV 1SV-19 fails open
*(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (C)om ponent, (M)ajor
SIMULATOR SETUP Reset to 100% BOL snap Roll Charts Provide a boration/dilution borationldilution plan Clear EHC alarm and any OACI 1.47 bypass alarms Ensure SM is supplying steam seals Sign off OP/1 IN61 001003 enclosure 4.3 thru step 2.13 (students start at 2.14) OP/1/N61 MALFUNCTIONS, REMOTES, and OVERRIDES Malfunction # Description Value Event Ramp Delay Trigger VLV-NI001A NI9A B.I.T. DISCHARGE ISOL VLV VL V FAIL AUTO ACTIONS VLV-NI002A NI10B B.I.T. DISCHARGE ISOL VLV FAIL AUTO ACTIONS MAL-ISE007 MAL-ISE007A A AUTO CF ISOL SIGNAL TRN A BLOCK MAL-ISE007B AUTO CF ISOL SIGNAL TRN B BLOCK OVR-CM001B COND A-B-C VAC BKR VL VS OFF OPEN LT OVR-DG047 *DG-PNL* MAINTENANCE ON MODE PB BLACK PB OVR-DG015B DIG 1B MAINT MODE PB ON (11/378) INITIATE PB OVR-DG048A *DG-PNL
- MODE SEL 2 POS ON LOCKOUT RELAY SW TRIP POS MAL-RN002A RN STRNER 1A HI DIP 100 3 60 MAL-IDE003D STEAM DUMP VLV SB12 FAIL 50 4 TO POSITION MAL-IPE003B PZR SPRAY VLV NC-27 FAIL, 100 6 60 NO MAN CTRL MAL-MT003 LOSS OF CONDENSER 30 5 VACUUM (VLV LEAK)
MAL-MT003 LOSS OF CONDENSER 0 11 300 VACUUM (VLV(VL V LEAK) VLV-CM010F CM368 COND A VACUUM 1 8 BRKR VLV FAIL TO POSITION VLV-CM011F CM369 COND B VACUUM 1 8 BRKR VLV FAIL TO POSITION VLV-CM012F CM370 COND C VACUUM 1 8 BRKR VLV FAIL TO POSITION MAL-SG001A S/G A TUBE LEAK 650 7 MAL-SM002A S/G PORV SV19 FAILURE 100 8 5 LOA-IDE004 SB11 - INLET ISOL 0 21 120 180 OVR-CM001A COND A-B-C VAC BKR VL VS ON CLSD LT
BST-JPB7500H RN PMP A STRAINER HI DIP SET 3 MAL-RN002A RN STRNER 1A HI DIP 50 12 180 Del in 1 OVR-RN013A 1RN30A RN STRNER 1A OFF 12 7 7 BACKFLUSH ISOL SEL SW Del in CLSD LT 195 OVR-RN013B 1RN30A RN STRNER 1A ON 12 1 1 BACKFLUSH ISOL SEL SW Del in OPEN LT 185 EVENT TRIGGERS (other than manual) Event Description Trigger 8 Reactor Trip either train r[ jpplp4(1) I jpplp4(2) 1 11 SMSS < 1130.0 JTRUE (TRUE when turbine MW meter reads less than 1135 MW) 12 X11 i040n (TRUE when 1A Strainer switch is taken to ON] ON) CRITICAL TASKS (See attached documentation) E-O I - Establish flow from at least one high-head ECCS pump before transition out of E-O. E-3 A - Isolate feedwater flow into and steam flow from the ruptured S/G before a transition to ECA-3.1 occurs. QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1-2 3 Abnormal events 2-4 4 Major transients 1-2 1 EOPs entered/requiring substantive actions 1-2 1 EOP contingencies requiring substantive actions 0-2 0 Critical tasks 2-3 2 REFERENCES OP/11A161501009 (Boron Concentration Control) revision 068DCS OP/1/A/61501009 OP/1/A/61 OP/11A161 001003 (Controlling Procedure for Unit Operation), Enclosure 4.3 revision 106DCS OP/1/B/63001001 (Turbine Generator) revision 091 AP/0IAl55001020 (Loss of Nuclear Service Water) revision 037DCS AP/O/A/55001020 AP/1/Al55001028 (Secondary Steam Leak) revision 005DCS AP/1/A/55001028 AP/11A15500/011 (Pressurizer Pressure Anomalies) revision 022DCS AP/1/A/55001011 AP/11A155001023 (Loss of Condenser Vacuum) revision 018 AP/1/A/55001023 EP/11A15000/E-0 (Reactor Trip or Safety Injection) revision 036DCS EP/1/A/5000/E-0 EP/11A15000/E-3 (Steam Generator Tube Rupture) revision 034DCS EP/1/A/5000/E-3 OP/0IAl64001006C (Nuclear Service Water) revision 266 OP/O/A/64001006C
NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES. The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or individuals (IAE, RxGrp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back information provided. Call back items are listed below when necessary for the scenario. Event 1 - Borate for power decrease This event will be entered once the crew has taken turnover and evaluated plant conditions. When the first boration batch has been completed, the next event can be started. Event 2 - Power reduction using turbine/rods as necessary When turbine power has been reduced by 3-5 MW, the next event can be inserted. Event 3 - RN Strainer 1A high D/P. SRO Technical Specification Initiating Cues: 1AD-12 alarms A11,
- 1AD-12 AJ1 , A12, A15, C/2 AJ2, AJ5, When AP/0/AJ5500/020 AP/0/A15500/020 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted.
TS 3.7.8 Condition A If asked to check out RN pump 1A and/or breaker state, after 10 minutes state "Nothing unusual was noted." If asked to check on RN pump 1B following the state, state "It appears to be operating normally." normally. " Event 4 - Steam dump valve 1SB-12 fails open Initiating Cues:
- 1SB-12 indicating lights intermediate on 1MC-2
- OAC alarm C1Q0966 (SB-12 Mn Stm Bypass to Cond Control #12)
- Turbine MW decreasing
At Step 9.d RNO, when an operator is dispatched to manually close the condenser dump valve isolation valve, insert EVENT 21 "1S8-12 is closed." Call back when the valve reaches full closed and state "158-12 When step 18 of AP/1/A/55001028 is completed and 1S8-12 has been isolated, the next event can be entered. TS - 3.4.1 Condition A (based on NC pressure at the time) Event 5 - Loss of condenser vacuum Initiating Cues:
- 1AD1, F/7
- OAC alarm C1A0734 (Condenser C absolute backpressure)
- Turbine MW decreasing When load has been reduced to stop the loss of vacuum (See EVENT 11) and step 10 of AP/1/A/55001023 has been completed, the next event can be inserted.
When EVENT 11 actuates, call as the NLO sent out to evaluate the turbine building for vacuum leaks and state "Maintenance breached a system boundary that was isolated for work and air was being sucked in. It appears one of the isolation valve was not fully seated. It has been adjusted and the leak appears to have stopped." TS - TS - 3.4.1 Condition A (based on NC pressure at the time) Event 6 - PZR Spray valve 1NC-27 fails intermediate with no manual control NOTE: If the spray valve failure is not dealt with quickly, the reactor will trip and in that case, EVENT 7 should be immediately triggered. Initiating Cues:
- 1AD-6, F/8
- OAC alarm C1 L4455 (Normal Pressurizer Spray Flow Activated)
When AP/1/A/55001011 is completed and the SRO has completed consulting Technical Specifications, the next event can be inserted. This will begin the major event. TS - 3.4.1 Condition A (based on NC pressure at the time)
Event 7 - Tube rupture on 1A S/G Initiating Cues:
- 1RAD-1, B/1, 8/4, RAO-1, 8/1, B/4, E/5
- RAO-3, E/5 1RAD-3, This is the major event.
Additional failures
- Failure of automatic feedwater (CF) isolation
- Failure of 1NI-9 and 1NI-1 0 to automatically position
- S/G PORV 1SV-19 fails open Scenario End Point AFTER SAFETY INJECTION IS TERMINATED PER EP/1/A1S000/E-3 EP/1/A1SOOO/E*3 Step 2S.c.
CREW TURNOVER INFORMATION Initial Conditions:
- 100% power
- EFPD =25 days
- Boron Concentration is 1348 ppm Turnover:
- 1A DIG was placed in Maintenance Mode and red tagged 2 hours ago for PMs and is expected 1A back in 6 hours.
- Reduce power for control valve movement test to be done by the next shift per OP/1/A161 OP/1 IA/61 001003 (Controlling Procedure for Unit Operation), Enclosure 4.3, Unit Operation Between 85% and 100% Power.
Duke Energy Procedure No. Catawba Nuclear Station OP/l!Al6150/009 Revision No. Boron Concentration Control DCS 068 Electronic Reference No. Continuous Use CN005FKT
oP/VA/6150/009 OPIl!A/6150/o09 Page 2 of4 Boron Concentration Control
- 1. Purpose To describe the operation of the Boron Concentration Control System.
- 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration. (R.M.)
2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 When changing the boron concentration of ofthe the NC System, closely monitor the following for expected indication:
- Rod motion
- T-AVG
- Nuclear instrumentation 2.2.2 When performing dilutions at or near 100% power, batch additions to the VCT (instead of continuous dilution at low flow rates) are the preferred method. {PIP C99-0587}
2.2.3 Ifthe If the NC System is filled and vented and the boron concentration is being reduced in the NC System, at least one NC pump shall be in operation, recirculating the NC System. {PIP C99-251 C99-2510} O} 2.2.4 Ifthe If the boron concentration is being increased in the NC System, at least one NC pump or one ND pump shall be in operation, recirculating the NC System. 2.2.5 Following an increase or decrease ofthe NC System boron concentration of
~ 50 ppm, pressurizer spray shall be operated to equalize the boron concentration throughout the system.
2.2.6 When the reactor is subcritical sub critical and dilution is in progress, ifthe Nuclear Instrumentation increases by a factor of two, secure the operation immediately and evaluate the cause. 2.2.7 If the unit has operated continuously for several months, significant Boron 10 depletion may have occurred. The effective boron concentration of the NC System may be lower than indicated by Chemistry samples. NC temperature shall be carefully monitored following VCT makeup. 2.3 During continuous dilution operations, sample the NC System H2 concentration every eight hours.
OP!lIA/61501009 OP/l!A/6150/009 Page 3 of4 2.4 When manually operating any motor operated valve, minimize the torque applied to the handwheel. 2.5 After manual operation, maintenance or packing adjustment of any motor operated safety related valve, it shall be cycled electrically to ensure reliable automatic operation. 2.6 With the "NC MAKEUP MODE SELECT" switch in the "DILUTE" position, the makeup flow rate is limited by letdown flow, the VCT spray nozzle, and VCT pressure. The maximum expected makeup flow rate is approximately 95 gpm. 2.7 With the "NC MAKEUP MODE SELECT" switch in the "ALTERNATE DILUTE" position, the maximum expected makeup flow rate is approximately 130 gpm. 2.8 With BAT boron concentration greater than or equal to 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is
~1300
> 1300 ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1300 ppm. {PIP 03-7305}
03-730S} 2.9 With BAT boron concentration less than 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is ~ 1250 ppm. Automatic or manual makeup can be used when NC System boron concentration is
< 1250 ppm. {PIP 03-7305}
- 3. Procedure Refer to Section 4 (Enclosures).
- 4. Enclosures 4.1 Automatic Makeup 4.2 Boration 4.3 Dilution 4.4 Alternate Dilution 4.5 Manual Operation Of The Makeup Controls 4.6 Operation Of The Boric Acid Transfer Pumps In Miniflow 4.7 Placing Boric Acid Tank #2 In Service For Unit #1 4.8 Valve Checklist 4.9 Rapid Boration
OP/l!A/6150/009 Page 4 of4 4.10 Deboration Of The NC System Using A Mixed Bed Demineralizer 4.11 Unit # 1 Boric Acid Tank Cleanup 4.12 Boric Acid Addition To NCP Seals 4.13 Recirculation Of The Boric Acid Tank With The BAT Recirc Pump 4.14 Blend Control Verification
OP DOES THIS BOP Enclosure 4.2 OPfl!Af6150f009 OP/I/A/61501009 Boration Page 1lof3 of3
- 1. Initial Conditions o
D 1.1 Review the Limits and Precautions. 1.2 lfi:jl3,l\1gd~£r,,~F;2,;;enSIf4~tlt!~ft'ttfta'Mg~tll.lt'~j@Ji§bedpef;SO~,iQll~92t IF in Mode 1 or 2,ensui:¢R2reaclivitY management controls established per SOMP 01-02
~~~tE'tI~t1~~el1t}~%;(fLM.)
(Reactivity Management). (R:M.) D 1.3 V~rifY the NY System is in operation per OPfllAl6200fOOI (ChemicaL and Volume Control
~.:tY~_~tliJj'Sjlr.et~t~~lt;f~P:lW1\tq~QO/(:lO~~~~~~'W:~<<OO'e;.Cfj%Y'l
~~~~i' System).
D 1.4 :V:~rifY.s.§ll(f~lIIl_~,t$'i~~lt~*;t,({~~,*fi~tt)i;CQt)lant(n'$plij'~1;~!lt\i~gf. VerifY s~fficient,RHT vohime is available to receive the reactor coolant displaced duringthe
;platltied':QtPfi\ttwp~qR~~i'lfm}
planned boration operation:~
- 2. Procedure NOTE: This enclosure will affect reactivityoftlI.ecore and is therefore designated important to ReactivitY Management per the guidelirres.ofNSD.304 (ReactivitY Management). (R.M.)
oD I~l\ 2.1 Ensure valves are aligned per Enclosure 4.8(Valve Checklist). 2.2 Ensurethefqllowing valve control switches in "AUTO": D INV-238A (BfAXfer Pmp To Blender Cirl) D INV-186A (BfA Blender Odt To VCT Otlt) oD 2.3Dil:ftlteINN'~2:~.3~!;(~1~~*~t!:;Alilta11,~~~~!lItt~lf¢~ii!.~liif:Ql 2.3 Ensure INV-238A (BfAXfer Pmp }:oBlenderCtrl) controller in auto. oD 2.4.~m~;i,tll\._d\~iIi~~tt.$'_~m.iiyr~~.O!';()rl'O~Y~'* 2.4 :Ensure at least one boric acid transfer pump is in "AUTO" or "ON". o 2 *5 D 2.5 pA\iJilmiM;i.~Ii"~'ituij15ateII)!G1JunterfQ1*:me*desired.v,';11.lfn~;i1>i';Il~i£ii~fi.\J>~.lI<4:;<;&~ded, Adjust the boric acid
~~".~~,;~~~f.I!; ...*. ; batch counter
..*. , ..... to the desired
,.... '.' ;................... volume>ofbotic
........q,. ."..... acid
.*.*. ""~~.~ to be added.
.. ; .;~'!?., (RiS1\.~
(R.M;)
... /. .......:+~,
2.6 m~J~111~u~~ii§i~_pla.\Rg_."~1!f$.~~4J'J1;.qt\l1l~'ICjlM~euJl/~.!~t_4 IF the blenderjs set up {or;~utomatiq makeupp'er Enclosure 4.1 (Automatic Makeup), record
!I!~$~~!I&~'mtJtIB~~I~~~~~i;~~'FIt~HllleJder;,~I)'>
thesetpointoftH,e controller for INV-238A (BfAXfer Pmp To BlenderCirl). .,. 'rj~lI gpm D 2.7 Placethe "NC MAKEUP MODE SELECT" switch in "BORATE". NOTE.: Boric*Acid.flo~ ~at('js > 32'gpm maytesult in'a boric acid flow deviation annunciator. lI.. D 2.8 NOTE: A..dju~tthefcontroller foflNV-238A (BfAXfer Pmp To Blender Cirl) to the desired flow.
.._I~~1I~9~WQ~J!i,i~.ij~I,Jy~$~~t~ij~t;~~i:~tm If necessary, boration caI1 be manually secured at atiy tiw~byplacing
~tl1m~I;lij'~\~~it~tJ;~t!lli:llt~,~,lim~>>}~:!I!(t~li~~
CONTROL" switch to the '$ TOP" position.
* *tJ~~.~.~.~" the "NCMAKEUP D 2.9:p:lac~,tMNCMAI<EUP CONTROL" switch to the "START" position. (R.M.)
Enclosure 4.2 OPflfA/6150f009 OP/l!A/61501009 Boration Page 2 of3 2.10 VerifY the following valves open: D IN\1';.;W,38.~.(~f~.:x,f~rPtl}P'l7o~Je:iidet INV,;.238A (B/A Xfer Pmp To Blender Ottl) Ctrl) JlN0186~(B/~lBleildetOtlt*'l7oM(]T D INV-186A (B/A Blender Otlt To VCT Odt} Otlt) 2.11 IF in "AUTO", verifYthe boricacidttansfer pump starts. NOTE: The total makeup flow totalizer is inaccurate at low flow rates .. D 2.12 VerifY proper flow by observing the boric acid flow totalizer. {PIP96-0137} 2 .13WHJljlN'lll~**<l~$:itegl'yglpwepfbori.c?cidis 2.13 WHEN the desired volume of boric acid is *t~aQll~<l**ontlleQg~i¢acidbat($li*Qount~r, reached on the boric acid batch counter, :en~ure ensure th¢fqJlq~!t;lg¥al¥~$"'Qlg$¢: . *fR*M.) the fbl1o~ing valves close: (R.M.) 1~~W,~8~::(~!,~~!~tPtl}P D INV.-238A (B/AXfer Pmp To Blender Ctrl) TOl\UendetOfrl) Dl~~.r861X;,CB!'~lBl~nde.tt()tlt*.mq:MCT**()llt) D INV,.186A (B/A BlenderOtlt ToVCT Odt) NQ.l'E: NOTE: If additi()nal botatiohs w'ill be performed over the course of the 'shift, If.a<l<litigilaUboj)atioils~m***be:perfo~Wed**overllie.qourSeqftlle shift, flu.$lliI1glM flushing the makeUp makeup lineis'.NQ'Efecot:iit:iiended. line isNOTrecominended. 2.14 IF desired, flush the makeup line as follows: Flushing should not be 1I 2.14.1 Open the following valves: desired at this time. I D INV-242A (RMWST To BfA BIA Blender Ctrl) D INV-186A (BfA (B/A Blender Otlt To VCT Otlt) I D 2.14.2 Ensure one reactor makeup water pump is in "ON". 2.14.3 WHEN ~ 20 gallons of makeup water have been flushed through the makeup line, close the following valves: D INV-242A (RMWST To BfA BIA Blender Ctrl) D INV-186A (BfA (BIA Blender Odt Otlt To VCT Odt) Otlt) 2.14.4 Place the following valve control switches in "AUTO": D INV-242A (RMWST To BIA BfA Blender Ctrl) D INV-186A (BfA Otlt To VCT Odt) (B/A Blender Odt Otlt) 2.14.5 IF NOT NO'E required for current plant operation, place the reactor makeup water pump started in Step 2.14.2 in "AUTO".
Enclosure 4.2 OP/llA/6150/009 OP!lfAf6150f009 Boration Page 3 of3 2.15 IF automatic niaketipis desired,perform one~ofthe following: 2.15.1 IF it is desired to change the blender outlet boron concentration, refer to Enclosure 4.1 (Automatic Makeup). OR 2.15.2 IF makeup at the previous concentration is acceptable AND the system was prevIously aligned per Enclosure 4.1 (Automatic Makeup),.perform the following: o D 2.15.2.1 ._il~1m:~(~tiil~ilr~p'ToB~m~~rcttU'
- E;n:§lJ~re the controller for INV-238A (BfAXfer Pmp To Blender Ctrl)
._lJ\'1I10_ij~t~'\ljitj:!;I~,itt~_.)
is s;~tlto the value recorded in Step 2.6. (R.M.) o D 2.15.2.2 If#Jltij)1t'~~.Ql~_~l.~l~~~~'Ctr2* Placetthe flNC MAKEUP MODE SELECT" switch in "AUTO". o D 2.15.2.3 ;I:1i~~~l;~~~: __ Place:the "NC MAKEUP ~~~~{;f~.~f~J,t,~ CONTROL" switch to the "START" pil~I'~~~;::~~_ position,. (R.M.) 2.16 Do NOT file this enclosure in the Control Copy folder ofthis procedure.
Duke Energy Procedure No. Catawba Nuclear Station OP/l!A/6100/003 OP/I/A/61 001003 Revision No. Controlling Procedure For Unit Operation 106DCS 106 DCS Electronic Reference No. Continuous Use CN005FK5 CNOO5FK5
OP/liA/61 001003 OP/I/A/61001003 Page 2 of4 Controlling Procedure For Unit Operation
- 1. Purpose To describe the operation of the unit between approximately 15% and 100% full power.
- 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can effect core reactivity by the following: (R.M.)
- Control rod movement
- Turbine load changes
- F eedwater manipulations Feedwater
- Reactor power changes 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.)
2.2.1 Before returning reactor control to automatic, T-AVG shall be within +/- 1°F of T-REF. 2.2.2 Do NOT exceed rod insertion limits or temporary rod withdrawal limits. 2.2.3 Automatic control rod withdrawal is blocked when Control Bank D ~ 200 steps withdrawn. 2.2.4 The difference in boron concentration between the PZR and NC System is desired to be maintained within +/- 50 ppm. 2.2.5 Axial Flux Difference (AFD) shall be maintained within the allowable limits as defined in the ROD manual at all power levels above 50% reactor power. (Tech Spec 3.2.3) 2.2.6 During a power change, other indications of reactor power shall be observed along with power range and secondary thermal power indications to aid in determining the reactor power level. Using indications like turbine impulse
~Ts, and pressure, CF flow rate, NC loop L1Ts, and others may help in detecting the miscalibration of a nuclear instrument.
2.3 In the event of an inadvertent power reduction, it is recommended that the power level NOT be increased until an investigation has been conducted and corrective action taken.
OP/l!A/61 OP/l/A/61 00/003 Page 3 of of44 2.4 Ifreactor control is in manual, maintain T-AVG within +/- 2°F ofT-REF to prevent lfreactor receiving "T-REFIT-AUCT HIlLO"HIILO" alarm. 2.5 Whenever there is a thermal power change greater than or equal to 15% rated thermal power within a one hour period: (OAC point C1L4790 in alarm) NotifY Chemistry to take an isotopic analysis for iodine within 2 to 6 hours following
- Notify the last power change that is greater than or equal to 15% rated thermal power within a one hour period. (T.S. SR 3.4.16.2) notifY Radiation Protection to sample and
- When thermal power has stabilized, notify analyze gaseous effluents. (S.L.C. 16.11-6) 2.6 S/G blowdown flowrate shall NOT exceed a maximum of200 GPM per S/G.
2.7 After a thermal power change when plant conditions stabilize, 1EMF-39 setpoints shall be adjusted so the Trip 2 setpoint is set at three times the containment activity and Trip 1 setpoint is set at 70% of Trip 2 setpoint. 2.8 If the RC System condenser inlet temperature drops to less than or equal to 60°F when lfthe the Rx is shutdown or less than or equal to 55°F when the Rx is critical, the system shall be configured as follows:
- One RC pump running (throttled).
- One tower inlet isolated.
- All three riser bypasses open.
2.9 OAC point C1K0628 (CF Flow Venturi Correction Factor) shall be reset to 1.0 when either of the following conditions are met: ofthe
- A step load change such as a load rejection greater than 10% rated thermal power,
- A ramp load change of greater than 15% rated thermal power in a one hour period.
2.10 When the unit is engaged in a power maneuver resulting in a mismatch between OAC point C1P1385 (Reactor Thermal Power, Best) and any excore power channel in excess of2% refer to Tech Spec Basis for SR 3.3.1.2. 2.11 The insertion of Control Bank D will affect mismatch between OAC point C1P1385 (Reactor Thermal Power, Best) and the excore power range channels. This is due to shielding of the power range detectors by Control Bank D. Therefore, refer to ofthe Tech Spec Basis for SR 3.3.1.2 when mismatch between Reactor Thermal Power (Best Estimate) and the excore power range channels shall be observed to be exceeding 2%. 2.12 The Reactor Engineering Group normally provides information for planned power' maneuvers. The OAC xenon predict program can be used to help anticipate dilution and boration requirements. {PIP C99-0587}
OP/l!A/61 001003 OP/I/A/61001003 Page 4 of4 2.13 The Steamline Steam line N-16 Radiation Monitors (EMF-71, 72, 73, 74) become inaccurate at power levels below 40% due to inaccuracies in the algorithm used to calculate the output of these monitors. {PIP 99-3980} 2.14 It is recommended that Primary Chemistry be notified prior to all significant boric acid additions or dilutions to the NC System such that proper pH control may be maintained. Normal boric acid additions and dilutions should be communicated at the Control Room shift briefing. {PIP c-o C-01-665} 1-665} 2.15 In accordance with INPO best practices when personnel are accessing areas that could experience significant dose rate changes resulting from increasing power, Operations shall maintain Reactor power steady or decreasing.
- 3. Procedure Refer to Section 4 (Enclosures).
- 4. Enclosures 4.1 Power Increase 4.2 Power Decrease 4.3 Unit Operation Between 85% and 100% Power 4.4 T -AVG Coastdown T-A 4.4.1 T-AVG Coastdown Data T-AVG 4.4.2 Adjustment OfDCS ACCEPTED VALUE For T A AVG VG 4.4.3 T-AVG Coastdown Tracking Data (phase (Phase 1 and Phase 2) 4.5 Power Escalation Guideline
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- Enclosure 4.3 OP/l!Al61 001003 OP!l/A/61 Unit Operation Between 85% and 100% Power Page 4 of6 NOTE:
__ ~::l~ mlljllWf!llll!t~.11"f~:aI;~~~lrrg'~qlt!g~.liQnJ1/~'(Ql1_illg:.is~11lte:'1~&:' IJI'*']J 'li§91~~]:~*~Jigg~r~11~1
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t1l.m~'IiY:DIImij;1fI~rs()1fititt~i;;*.*'*.*:_{3!I;j;:~J;_l:ll{'11:_ SIGNED OFFTO OFF TO HERE 2.16 NotifY the SOC priortoreducinghnl.d per OPIl/B/63 00100 1 (Turbine-Generator). fRo/s6Pl---- 2.17 rRriMiPL_ I'L ,'-", ""'-'" r Begin the load reduction to the desired powerlevel. CAUTION: l. When Wl1j~ilt1j¢'1iPit:is¢Hgage(fiJ}:,(l.poW¢f'm<lll~uver, the unitis engaged in a power maneuver resulting re~ldtiJ}g"inajjj'ismatc1jbetWee.ti():AC in a mismatclfbetween OAC
,ppip~::([;?'1~l~.~.~,(~eMt<?r,'T:1j¢oollJ.ppwet;.:,'~.est)i{lp(f.,an)feXcore poirttCIP1385'{Reactor Thennal Power, Best) and any excore "power,'cnannelip power channel in e~9¢s$of~cpQ,,'re~~ttQ*T:~¢1j:i*~p¢¢;~1l$iS~9t;:~~"3.3!1)2, excess of2%, refer to Te9h Spec Basis for~SR 3.3.1.2.
- 2. ,~ttem{lte ip(fjQatipp~'."'Q~t¢a~~Qt:J)9W~ts1j~11.:I?¢tn.9n~~9te(ftP.ved~i~¢act<?t:.:p<?WetJeyel Alternate
- indications of reactor power shall be monitored to verifY reactor 'power level
~~(f1j¢lp,p~e-v~q~~twis911U:l?rllti9H~
and helpprevel1t NI miscalibration.
- - 2.18 IF a power decrease of more than 20% reactor power is planned, issue Model W10
#00874628 to IAE to prevent the mismatch between OAC heat balance point CIP1385 (Reactor Thermal Power, Best) and any excore power channel exceeding 2%.
Enclosure 4.3 OP/I/A/61 001003 OP/l!Al61001003 Unit Operation Between 85% and 100% Power Page 5 of6 N OTE :Sij4~'fCJt~Q~.ingtadiQ.i?4emistrM$amplesafeQ~!tlgreqiles~~.ogue***to NOTE: The following radiOchemistry samples are being requested due to stlspei?tedfaU¢gfilt:1suspected failed fuel.;. * *1'41$ This wiUQ~u$eg will be used .tQde~~ij1fi1teth~¢~ii~nto1:}tJ:j~Ig~m<lg~;;<ll1gi~!lJa.ll()w**v~tlgor*.suPP()rt;**~Q;Qe todeterrnine the ex'te(ltof the damage and wWallow vendor support to be
~ch~gilJ~~;gil*lijg .tne.*refu¢a~j;j.gCJiltag~,1'f:*~§:il1*~9..SijQ~$.:*$tepmaY*Qe*}\;fz~'g~it4QQlii?!lffel1pe scheduled<during the refueling outage, if requiied. This step may be NIA'd with concurrence ftom:'~~MtQrEngj1].eerillg;}
from l,teactor Engineering. .****{lllP0t1*':98f9} {PIP 04-:-0879} 2.19 IF failed fuel is suspected AND a power oecrease decrease of more tnan than 5% reactor power is planned AND Reactor Engineering concurs, notify Primary Chemistry Cnemistry to take NC gamma isotopic samples at one, tmee, three, and five hournour increments after the tne Unit has nas stabilized at tne the lower power level following the tne power change. cnange. Cnemistry person notified _ _ _ _ _ _ __ Chemistry Reactor Engineering contact - _- __ -_ -_ -_ -_- NOTE: Tne following radiochemistry The radiocnemistry samples are performed to detect potential fuel defects. This Tnis will allow vendor support to be scheduled scneouled ouring during thetne refueling outage, if required. This Tnis sample will typically be obtained prior to the tne snutdown shutdown for tne the refueling outage. This Tnis step snaIl shall be N/A'd if iftne the sample was obtained during a previous power reduction. 2.20 IE'*;~*p()~~rdyct~ase IRa pow~r decrease .*.of*ri.1.9retl1a.lilQ%i$pla@egAND;:;~n!\l;tle~t$94~g.ill~d*R¢'ft1elitlg of more than 10% is planned AND the next scheduled Refueling Ou~ijg~~*JL,Qg~£i.$a~a£i.5t19t~tY*.Priri.1.a.n'~4t:ri.1.~$trytCJ;ta:k~*~ni$otQP~~i;ttlijlys~;s>fQttQgij;j.e** Outage .:s'120 days away, notify Primary§hemistry tQ;takeanisotopiC analysis for ibdille w~t4t1].L,~Q6nQllr$*.*.f()Jlo\Viijg.tne.lijstpg~e(;94~ng~;*** within 2 to 6 hours followingthe l<l.st power change.* Chemistiypeisbnriotified_ _ _ _ _ __ NOTE: Outing a unit coastdown at BOL, AFD shall be m.aintained as directed by the Reactor Group, 22.21
.21wmLE.t.eg.l.).¢il1g.*power .*ri.1.~li~ttl:Gotlt(gltg!1s*a.bg:¥~*.*In~~rt;iotl.****limit.a.n!1AEIJ*
WHILEredUcjng powermaintain.contrOI*rodsabove inseftion limit and AFD .* Withitl*.it$ within its target banqby bo:t~tion.()r tatg~t*;:Q~j;j.!1:**Qy.*bQ(~tiQtlQtdilutiQ1].;p~r;*()RZJVA/61*~9/QQ!?:(1?()(QtlGOn~¢l1trati01].Ggl1~*QD. dilution per OP/1/A/61501009 (Boron Concentration Control). NOTE: The procedure may continue while perfonning Step 222. 2.22 222 IF shutting down for an outage where condenser vacuum will be broken, at approximately 85% turbine power (~1003 (~ 1003 MWe) complete the Heater Vent Orifice Return to Service Valve Alignment enclosure ofOPIl/B/6250/004 ofOP/11B162501004 (Feedwater Heaters, Vents, Drains and Bleed System).
Enclosure 4.3 OP/I/A/61001003 Unit Operation Between 85% and 100% Power Page 6 of6 CAUTION: Actuation of steam trap drain valves will result in a power change. NOTE: When aligned to BYPASS, the Manual Bypass Selector Valves will align air directly to the drain valve actuator to maintain the valve closed. When aligned to ENABLE, the Manual Bypass Selector Valves will align air through the level switch solenoid valve to allow the valve to cycle based on level. 2.23 IF reducing power to less than 85% thermal power, ensure the following Manual Bypass Selector Valves are in the ENABLE position: D lSPMV0190 (lSP19 Manual Bypass Selector Valve) (TB-599, lC-22) D 1lSPMV0230 SPMV023 0 (lSP23 Manual Bypass Selector Valve) (TB-598, lC-20) D lSPMV0290 (lSP29 Manual Bypass Selector Valve) (TB-597, ID-21) D lSPMV0330 (lSP33 Manual Bypass Selector Valve) (TB-598, lC-19) D lSPMV0370 (lSP37 Manual Bypass Selector Valve) (TB-598, IG-22) D lSPMV0400 (lSP40 Manual Bypass Selector Valve) (TB-600, lC-33) D lSPMV0990 (lSP99 Manual Bypass Selector Valve) (TB-598, lC-23) D lSPMV1230 (lSP123 Manual Bypass Selector Valve) (TB-606, IB-22) 2.24 IF reducing power to less than 85% thermal power, go to Enclosure 4.2 (Power Decrease). 2.25 IF return to 100% thermal power desired, start a new Enclosure 4.3 (Unit Operation Between 85% and 100% Power). 2.26 File this enclosure in the Control Copy folder of this procedure.
Duke Energy Procedure No. Catawba Nuclear Station op/1/B/6300/001 OP/l/B/6300/001 Turbine Generator Revision No. 091 Electronic Reference No. CN005F07 Multiple Use PERFORMANCE II
- UNCONTROLLEDFORPruNT**********
(ISSUED) - PDF Format
OP/l/B/6300/001 OP!l/B/63 00/00 1 Page 2 ofS of5 Turbine Generator
- 1. Purpose To describe the proper method for operating the Turbine-Generator.
- 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can effect reactivity. (R.M.)
2.2 Low load operation limits: 2.2.1 The unit can be operated continuously at low loads when exhaust hood 175°F. The load shall, however, be increased slowly until temperature is < 17soF. the temperature decreases below 125°F before increasing load at normal rate (Multipoint Recorder on 1MC3). IMC3). 2.2.2 Limit turbine/generator operation below 5%S% load to 1 hour to prevent moisture erosion unless directed by the Turbine Engineer for testing 2.2.3 Motoring of the unit is to be avoided. 2.2.4 Excessive use of ofthe the exhaust hood sprays shall be avoided to prevent accelerated blade erosion. 2.3 Journal bearings shall NOT be operated with metal temperatures above 2S0°F 250°F (OAC Turbine Bearings graphic (TGBRG)). 2.4 Lube oil cooler discharge temperatures shall be 1lOO°FOO°F to 120°F when at rated speed. 2.S 2.5 The lube oil temperature rise shall NOT exceed SO°F 50°F on the main bearings and 45°F on the thrust bearing. 2.6 Under no conditions shall the thrust bearing be operated above 190°F metal temperature (OAC Turbine Bearings graphic (TGBRG)). 2.7 Never allow a hot rotor to stand without rolling. If and when a hot rotor was allowed to stand still, when possible rotate the shaft 180° and allow to stand still again for one-half the time it first stood still, and then put the turbine on turning gear. 2.8 The minimum allowed cold gas temperature is 86°F for operation. The maximum cold gas temperature is 122°F. (OAC points C1AOS22 CIA0522 (Cold Gas from Hydrogen Cooler Turbine End) and C1AOS28 CIA0528 (Cold Gas from Hydrogen Cooler Exciter End), Main Generator graphic (MAINGEN)).
OPI l!B/63 00/00 1 OP/l!B/63001001 Page 3 of5 2.9 Do NOT exceed the load, hydrogen pressure, and power factor limits per the Unit One Revised Data Book Figure 43. 2.10 If the limits of the Unit One Revised Data Book Figure 43 (Generator Capability Curves) are exceeded, the Turbine Generator shall be tripped. 2.11 The generator shall NOT be operated without excitation. If the generator is operated without field, the unit shall be immediately tripped off the line and shutdown for inspection. 2.12 Following a trip-out due to differential phase relays, both the armature and field windings shall be meggered and inspected before attempting to resynchronize. 2.13 Do NOT allow turbine generator speed to exceed 2000 rpm on overspeed tests. 2.14 The turbine shall NOT be operated with condenser vacuum less than 24.3 inches Hg. 2.15 The maximum differential pressure between adjacent LP shell pressures shall NOT exceed 2.0 inches Hg. (main condenser vacuum gauges on 1MC13, OAC points C1P1669 (DIP between A & B Condensers) and C1P1670 (DIP between B & C Condensers) or Main Condenser graphic (CMCOND)). 2.16 Do NOT hold the turbine at speeds < 800 rpm for more than 5 minutes. 2.17 When steam seals are on the turbine, the steam packing exhauster shall be operating, and the turbine shall be on turning gear. The turbine may be taken off gear with steam seals established with concurrence from the Turbine Engineer. 2.18 When a condition arises that is serious enough to make a reduction in speed necessary, it shall be initiated by selecting "MANUAL" and "CONTROL VALVE LOWER" or by tripping the turbine. 2.19 Temperature of the LH System reservoir shall be 2: 90°F prior to turbine start (OAC ofthe point C1A0188 (LH TEMP)). 2.20 A sudden downward trend on an LP turbine's lower extraction temperature shall be investigated as a possible indication of water induction into the turbine. This is indicated on the recorder on the rear of 1MC8 labeled "TURBINE WATER DETECTION", using any of the LP 8th stage lower temperatures. 2.21 The time the turbine generator is on turning gear shall be kept to a minimum to prevent the buildup of copper dust in the generator coil slots. 2.22 When system is in "EMERG MANUAL" runbacks and limit circuits may NOT be available. 2.23 Control rods shall NOT exceed rod withdrawal limits. Prior to changing power, refer to Reactor Operating Data Book, Temporary Control Rod Withdrawal Limits.
opil IB/6300100 1 OP/I/B/6300/001 Page 4 of5 2.24 A "LOAD RATE" > "6.2 MWIMIN"MW/MIN" shall NOT be used during nonnalload normal load changes. 2.25 The main turbine oil temperature limit of 80 to 90°F shall be maintained when the turbine is on the turning gear. 2.26 Differential temperature between adjacent exhaust hoods shall NOT exceed 30°F unless evaluated and approved by the responsible engineer (Turbine Generator System Expert). (OAC points CIP1667 (A & & B Exhaust Hoods Metal Delta Temp) and CIP1668 (B & & C Exhaust Hoods Metal Delta Temp) or Main Condenser graphic (CMCOND)). 2.27 During turbine acceleration, the heat up rate of the first fIrst stage bowl inner surface
-surface (OAC Point CIP1283 (First Stage Metal Temp Rate)) shall be < 150°Fihr.
150°FIhr. 2.28 During turbine acceleration, the rate of change of the reheat steam temperature (OAC points CIP1287 to CIP1292 (CIV No.1 (to 6) Inlet Temp Rate) or Turbine Generator graphic (TG)) shall be < 125°FIhr. 125°F/hr. 2.29 Any deviations from this procedure that could affect steam admission rates shall require an engineering evaluation to be perfonned performed which specifIcally specifically addresses partial arc admission. 2.30 The 6.9KV Switchgear Automatic Fast Transfer Switches are placed in the ENABLE position whenever the generator breakers are closed and in the DEFEAT position whenever the generator breakers are open. If an autoswap auto swap of the tie breaker occurs when in the DEFEAT position, equipment being supplied by the 6.9KV Switchgear is more likely to trip than when the switch in ENABLE. {PIP 98-4093, PIP 98-3589} 2.31 Feedback loops shall NOT be taken inlout in/out of service during turbine control valve movement. Following turbine control valve movement, DEHC shall be allowed to stabilize prior to placing feedback loops in/out of service to prevent unexpected load changes. (PIP 03-5660) 2.32 The Main Turbine OID Work Station has the capability to perfonnperform control functions for the Main Turbine, including tripping and resetting of the turbine. If a control function window is inadvertently selected while manipulating the Main Turbine OIU Work Station, the window shall be closed to prevent actuation of the control function. 2.33 The Main Turbine shall NOT be run more than 3 hours at 1800 RPM, no load, unless directed by the Turbine Engineer for testing. 2.34 The Excitation System can affect the functioning of heart pacemakers. Personnel with pacemaker devices shall NOT enter the A AVR enclosure/building during operation or VR enclosurelbuilding testing. If the AVR enclosurelbuilding is NOT installed, personnel with pacemaker devices shall remain at least 20 feet away from the A VR during operation or testing. 2.35 Failure to confinn confirm steam isolation to the turbine prior to opening the generator breaker may result in destructive overspeed of the steam turbine power train. {PIP C-08-50 18} C-08-5018}
OPll IB/63 00100 1 OP/I/B/6300/001 Page 5 of5
- 3. Procedure Refer to Section 4 (Enclosures).
- 4. Enclosures 4.1 Turbine Generator Startup 4.2 Load Changing 4.3 Transfer Turbine From Auto Control To Manual Control And Transfer Turbine From Manual Control To Auto Control 4.4 Turbine Generator Shutdown 4.5 Placing (Removing) Core Monitor And Pyrolysate Collector In (From) Service 4.6 Valve Checklist 4.7 Generator Operating Limits 4.8 Turbine Generator Roll Computer Points 4.9 Lamp Verification 4.10 Operation of Turbine TSI Panel 4.11 Reboot of the Main Turbine OIU OID Computer 4.12 Transfer of the Main Turbine OIU OID Computer Alarm Switch That Drives the "EHC "ERC Fault Annunciator" 4.13 Voltage Regulator Operation From Control Room 4.14 Voltage Regulator Operation From VI Ul Gen Voltage Reg Local Control Panel
Enclosure 4.2 OP/l!B/6300/001 OP/I/B/63001001 Load Changing Page 1 of4
- 1. Initial Conditions 1.I1tnSl1te 1.1 Ensure R2 R2r~.*9tivitY-t11~~g*~lnentCl$nftJl$l$e$tab1is1:ledperStJ)1VW.Ol-Q4(Rya~tivity reactivity management controls established per SOMP 01-02 (Reactivity MMagel11e Management). (RM.)
lJ-f){*(.R:iJyf:1 1.2 Review the Limits and Precautions. 1.3 V¢flfY.ttli'Bm~g~n~tatQr.*f~j*PJ?ef~ting Verify turbine generator is operating p~rEn~iosut~.4.**r.**CTurbin~*G~n~B~t~rSt~uup).* per Enclosure 4.1 (Turbine Generator Startup) of o$dil$ this prQdydur~. procedure.
- 2. Procedure Ci\IHION: The load, liydtogert
'Tl1e16*d, hydrogen pressure and power factor limits per the Unit One,Revised Data Book 43 shall NOT.be ex.ceeded.
]J11gure4~s1tallN~{
Figure NO;,rE: ~~~erat of Several of~hepafa~ety the parameters required for this isJ?1"QgedUt~.(;anl)¢fo1.ll"lti:()ntJ)m(]Bi~ap1iic§~ procedure can be foundiQnOA graphics, and af!i}*. a~ li$tpf aUO~(l:p()int$ list of all OAC points are 6$W:¢i.4.8CWi.irbill~(li~U:~tatPtRdlr¢6mplltetJ?6t1lts~1 [omidon Enclosure 4.8 ('Turbine Generator Roll Computer Points). 2.1 IF increasing turbine generator load, perfonn the following: 2.1.1 Increase turbine generator load to rated load within the following limitations: D 2.1.1.1 Control valve casing difference, OAC point C1A0961CIA0961 (Turb ('Turb Valve Chest Inner Surface Metal 'Temp) Temp) minus C1A0967 CIA0967 (Turb ('Turb Valve Temp), shall NOT exceed curve Chest Outer Surface Metal 'Temp),
"Allowable 'Temp Temp Difference on Control Valve Casing" in the Unit 1 OAC Databook.
2.1.1.2 WHEN exhaust hood temperature is > 125°F, the load shall be increased slowly until the temperature falls to::::: to.::::: 125°F; then the load may be increased in accordance per the nonnal procedure. D 2.1.1.3 "Rate Of Change" of First-Stage Bowl inner surface temperature shall NOT exceed 150°Flhr {OAC (OAC point C1P1283 CIP1283 (First Stage Metal Temp Rate).
'Temp D 2.1.1.4 OAC point C1Al140 (Turbine Lower Inner Shell 'Temp)
CIA1140 ('Turbine Temp) vs. Percent (OAC point C1P1588 Steam Flow {OAC CIP1588 (Design 'TotalTotal Main Steam Flow, Measured (%))) shall be maintained above and to the left of the curve in the Unit One OAC Databook "Load-Changing Recommendations" . D 2.1.1.5 Verify Groups Band C valves on Enclosure 4.6 (Valve Checklist) close at 15% of full load (181 MW, 105 psig 'TurbineTurbine hnpulse Pressure).
Enclosure 4.2 OP/l!B/63 00/00 1 OP/l/B/6300/001 Load Changing Page 2 of4 o D 2.1.1.6 Verify the following valves close at 15% of full load (181 MW, 105 psig Turbine Impulse Pressure):
- 1SM-21 ISM-21 (Ctrl Vlv #2 Stm Lead Dm)
- 1SM-29 (Ctrl Vlv #1 Stm Lead Dm)
ISM-29 2.1.1.7 WHEN CV3 comes off of its fully closed seat (65% of full load, 783 MW), verify 1SM-25 ISM-25 (Ctrl Vlv #3 Stm Lead Dm) closes. 2.1.1.8 WHEN CV CV4 4 comes off of its fully closed seat (92% of full load, 1109 MW), verify 1SM-33 ISM-33 (Ctrl Vlv #4 Stm Lead Dm) closes. oD 2.1.1.9 S/G blowdown flowrates shall be adjusted to obtain maximum blowdown for the appropriate load. CAUTION: 1. Until it is recognized that the first stage shell metal temperature change rate stays (l50°FIhr), the following loading rate shall NOT be below the allowable limit (150°FIhr), exceeded:
- 1I2%/min - First Stage Inner Shell Temperature (IMC3 (lMC3 or OAC point CIA1140 C1Al140 Temp)).:s 350°F (Turbine Lower Inner Shell Temp))::s
- 1%/min - First Stage Inner Shell Temperature (1MC3 1%/min (lMC3 or OAC point CIA1140 C1Al140 (Turbine Lower Inner Shell Temp)) > 350°F
- 2. Normal steady-state load changes shall be made without exceeding the limits shown on Enclosure 4.7 (Generator Operating Limits) and in the Unit One OAC Databook "Recommended Startup and Loading Curves".
- 3. Unit One Reactor Operating Data, Section 2.4 shall be referred to for allowable ramp rates. A "LOAD RATE" > 6.2 MWIMIN shall NOT be used during normal load changes.
2.1.2 Increase turbine generator load by performing the following: oD 2.1.2.1 Select "LOAD RATE" and verify it illuminates. oD 2.1.2.2 Input the desired load rate. oD 2.1.2.3 Select "ENTER" or "OK" and verify "LOAD RATE" goes dark. oD 2.1.2.4 Select "TARGET" and verify it illuminates. o D 2.1.2.5 Input the desired load target. o D 2.1.2.6 Select "ENTER" and verify" TARGET" goes dark.
Enclosure 4.2 OP!l/B/6300/00 1 OP/1/B/6300/001 Load Changing Page 3 of4 o 2.1.2.7 Verify new load target appears on Target Display. o 2.1.2.8 Select "GO" and verify it illuminates to start load increase. o 2.1.2.9 S/G blowdown changes shall be coordinated with Secondary Chemistry. CAUTION: The lQad; ,hYclrogbI1 pressure' and power factor limits per the Unit One RevisedData Book Figrtfe 43 shall NOT be exceeded, 2.2 ml4tiQr~~Pi~~.1,it~Jf{~<<_:.J9~Wa: IF,tlecreasing turbine generatorioad, per(otm the foilowing: 2.2.1t~~~1IfI1IlIi4 2.2.1 * *flliitll:lfdn~lil1:.mlfiq~(* Decrease turbine;genet;atotiroau;SVithm the following limitations: o 2.2.1.1 Rate2f cliallge;pfFit,st~StageJ?owl Inner Surface Temperature shall NOr'~xc~yd l~;'ObF!li'r (OAC,!)oint CIP1283 (First Stage Metal TenipRate)), o 2.2.1.2 OAC* pointGlA;1140 (Tlirbine.Lower Inner Shell Temp) vs. Percent SteaniFlow (OAC pointClP.l588 (Design Total Main Steam Flow, Measured (%)) shall"bemaintaip;ed above and to the left of curve in the Unit OneOAC Dat~bo()k"LQad~Changing Recommendations". 02:'2.1.3 ControFvalve casing difference~ OACpoitit CIA0961 (Turb Valve Chest*,JunerSurfl;lce Metal Temp) minusCIA0967 (TtirbValve Chest'Outer Surface Metal Temp), shall NOT .exceed curve "Allowable:Temp pifference on C<mtrol Valve Casing" in the Unit 1 OAC Databook. o 2.2.,1.4 S/G blQwdownflowrates shall be adjusted to obtain maximum blowdo~ for the appropriate load. 2.2.1.5 IF CV4 iplly close~i/92% of,full 1pad, 1109 MWE), verify 1~M-33 (Ctrl Vlv #4 8tm ltead'Dm) opens. 2.2.[6 IF.C\f3f':fullY closes (65% offu1110ad, 783 MWE), verify lSM-25 (Ctrl Vlv#3$tn:l,Lead Dm) opens.
Enclosure 4.2 OP/l!B/63 00/00 1 OP/l/B/63 Load Changing Page 4 of4 ,C~U']:'lON:1. Norm~lsteady-state load chaqge shall be made without exceeding limits shown on Encl6~ure4.7 (GeheratorOper~til1gLimits)andin the Unit One OAC Databook "Recommended Starting.and.Lba'ding*CutVes";
- 2. Unit One Reactor Operating Data;Section 2.4 shall he referred to forallowable nlmp rates.
2.2.2 .lI~;;~'n;;~iffi,;(f~:b!wlffcBH:~;~\wt&M;';'i&lst1;1p~4W~1'1~+'ti$~fjij!wj~ Decrease turbine generator'load by p¢rforfuingthe following:
~~~~~{.,,",~~,,,_',\,/'b~ft; ,:~~/.~.;>L>;.".:~c~}~!Y>1*~'1*~)~~~~':h~~lW:~_a~,
o ,!I.".I.,"m, O 2.2.2.1
~'*"~~.h.""*n'~>"
~~1jii.~~iJ!f30.~fty'Zk)IDBt'*~~;1~.~~i;1I~~~0 Select "LOAD:R,ATE"
- ~~-;~;, and verif~it illtJni1r:tates.
.~:,,,;,,*.*,.'''A.,:~ .. "-.. .,.y:*~Wn'.~!fH.~i4f~~<".<;,,~y.~~~.
o 2.212.2 O_l ;jiJah~~.ia~):~f~~;; Input the desired load.rate. o 1.2:2.3 Select "ENTER" and verify" LOAD RATE" goesifatk o "~{''RtA& O 2.2.2.4
~~~.:,:;.~: II:~m:_.ft.it";if~ll~rl.i{&i~
.Select liTARGET" and verify it illuminates.
o .~.;{~~~' .tI(te~lIlt.d;: D_ 2.2.2.5
,.'i.~~~~~ Input the desired load target.
o 2.2.2.6 *il:.ji!~'1t.f9.ra~~ifi.}t:~Aa~E~~f';g~i.jJ Select "ENTERnand verify II TARGET II goes daik o 2.2.2.7 1l~.t~~w;llit Verify !jew loadfarget **.~~'Q.~tllt~Jl\~ appem:s on Target Display': o ,i~!~I~~~ O 2.2.2.8 Selecf"GO" and VerlfY..it i1l4minates' to ~tart!~oad decrease.
\s~,IR~~irt.~_I.I_jl~1~4.
o :z,~~2r4li O 2.2.2.9
.. .,.~;0.,.;,.,i!l:';/ S/G blowdown changes shall be coordinated with Seco1).daI)'
Chemistry. 2.3 Do NOT file this enclosure in the Control Copy folder of this procedure.
Initiating Cues:
- 1AO-12 alarms Al1, Al2, Al5, C/2 IALL STEPS PERFORMED BY BOP I
II t
~----------~----.----------------~
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/A/55001020 AP/O/A/5500/020 1 of 52 Rev 37 DC~ DC::: A. Purpose
- 1055 of RN train or normal suction.
To verify proper response in the event of a loss
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP 101Al55001020 AP/OIAl55001020 2of52 2 of 52 DC~ Rev 37 DeS B. Symptoms
- Case I. Loss of RN Train:
- 1AD-12, Al1 or 2AD-12, Al1 "RN PUMP A FLOW HI/LO" - LIT
- 1AD-12, Al2 or 2AD-12, Al2 "RN ESSENTIAL HDR A PRESSURE - LO" - LIT
- 1AD-12, Al4 or 2AD-12, Al4 "RN PUMP B FLOW HI/LO" - LIT
- 1AD-12, Al5 or 2AD-12, Al5 "RN ESSENTIAL HDR B PRESSURE - LO" - LIT
- 1AD-12, C/2 or 2AD-12, C/2 "RN PMP A STRAINER HI DIP" - LIT
- 1AD-12, C/5 or 2AD-12, C/5 "RN PMP B STRAINER HI DIP" - LIT
- RN PUMP 1A or 1 1B B - TRIPPED
- RN PUMP 2A or 2B - TRIPPED.
- Case II. Loss of RN Pit Level:
- 1AD-12, B/2 "RN PIT A SCREEN HI DIP" - LIT
- 1AD-12, B/5 "RN PIT B SCREEN HI DIP" - LIT
- 1AD-12, B/1 or 2AD-12, B/1 "RN PUMP INTAKE PIT A LEVEL - LO" - LIT
- 1AD-12, B/4 or 2AD-12, B/4 "RN PUMP INTAKE PIT B LEVEL - LO" - LIT
- 1AD-12, E/2 or 2AD-12, E/2 "RN PIT A SWAP TO SNSWP" - LIT
- 1AD-12, E/5 or 2AD-12, E/5 "RN PIT B SWAP TO SNSWP" - LIT.
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/OIN55001020 3 of 52 Case I Rev 37 DC~ Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Start idle.RNpump(s) as required *.
- 2. Ensure Unit 1 and Unit 2 OATC monitors Enclosure 1 (foldout Page).
- 3. Verify each op~ra~ing RN Rump Perform the following:
discharge flow'... GREATER THAN 8,600 GPM. a. Stop any RN pump(s) not required to support system operation.
- b. Ensure the following suction valves to
~"---------~--~
Should secure 1A RN lake - OPEN: pump due to another pump running.
- 1RN-1A (RN P/H Pit A Iso I From Lake)
- 1RN-2B (RN P/H PitA Iso I From LaKe)
- 1RN-5A (RN P/H Pit B Iso I From Lake)
- 1RN-6B(RN;P/HPit B Isol From Lake)~
cc.. Ensure the following essential header isolation valves for required trains -
~.~~,
OPEN:
*~'; '%4o;t,;.'1i1r~12fA0~IO\li!J'!L:'d*
*1 RN..:t3.IA (RN HdrJj)!ltJ\\i'CYr:ir\rtlui1iA~
~i!'~~~~~~l~Pj(*J?,.",~F* 1~',-~e*~MH;.'J~:~Vl' ASupply'lsol)
_ 'it* ~.~.Jlig~~f.~lIlJBilJi:~fj!JMtij~'J)i 1RN-69B (RN Hdr 1B Supply Iso/) _ 'it* 1.!5"l_Y~~~~~!l~if~~fs~'t, 2RN-67A (RN Hdr2ASupply Isol) _ .441lta,~e1;J~i(.NII~iJt.~~lf'lmlJ:*
- 2RN-69B (RN Hdr 2B Supply IsOI).
(RNO continued on next page)
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP101Al55001020 AP/OIAJ55001020 4 of 52 Case I Rev3? Rev 37 DC~ Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued)
Ensure the foUQ~idg*RNl0Rl;r
- d. Ensynllhe following RN toRL discharge valves - OPEN:
di$15ffi@i"9§N@lvesi;.G)PEN:
.1Rt\li:517A.(~t;;:!tiprlRN.Di$Gh:TO
.1RN~57A (Station RN Disch To *RL RL
~ys3 Sys)
*.. j~t\I'"{}4'aE3I{St~tipn
- 1RN-843B (Station.*'.*RNQj$bffi.*]p RN Disch To HI..
RL Sys).
§Y$j*
e; ~d$ltlf¢;Pl'le;9fthe.i()[lowi.rjg*.*Rl;
- e. Ens(jre one of the following RL djsGffi:;;:!~.g§Vl3lyeS>.**.o:.()PEN!
discharge valves - OPEN: _ .*. tRI.. _ 1RL-54.. 52I{RN~y$DischTo* (RN Sys Disch To RL Hdr A) Rllflc;ltG\} OR _ .1~>.tRL;:p2(RN~y$DischTo~L RL-62 (RN Sys Disch To RL I+lqrB}, Hdr B).
- f. EdsUJEl:tffieJollp~!ngstatipl1.*
Ensure the foll()wing station ..Rt\I Rf'J qJsgffi~rgElh.ea(jElr**.<3rosscNerv~lves discharge header crossover valves . *- OPEN: 0PEN: _ .*1RN~~G\*(~tatiprjiRN.*.**Ql$Gh+:ldr
- 1RN-54A (Station RN DisCh Hdr X),.()\7er) x,*Over)
_.:::lRN~~3B{~t§tipl'l
- 1RN"93B (Station RN,Qi$gl:lbldr RN Disch:Hdr
~~().'I(er~;
X-Oyer). (RNO continued on next page)
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/OIAJ55001020 AP/OIN55001020 5 of 52 Case I Rev 37 DC~ Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued) g.ll7i~ither***oft.Iif~.f<5]I<5Wing<::<5flditiori~fis*
- g. IFeither ofthe following conditions is met:
_ . RN cannot be aligned to the lake _ . No flow indicated on operating RN pump(s). THEN align RN to SNSWP as follows: _ 1) Align valves for RN swap to SNSWP. REFER TO Enclosure 2 (RN Valve Alignment for RN Swap to SNSWP). _ 2) IF WL discharge in progress, THEN coordinate with Radwaste Chemistry to secure all controlled WL discharges. _ 3) IF any RN chemical addition is in progress, THEN have Chemistry secure it. _ 4) WHEN corrective action has been taken, THEN restore RN to normal alignment. REFER TO Enclosure 3 (Returning RN alignment To Normal After Transfer To SNSWP).
- h. Verify the following alarms~DARK:
~.4.(2);'j2;iC/2;f~N}f?Mf?i~§J8A1
- 1AD-12, C/2 "RN. PMP.J:\STRAINER N'E~
HIg/P~' HI DIP"
- 1AD-12, C/5 "RN PMP B STRAINER HI DIP"
- 2AD-12, C/2 "RN PMP A STRAINER HI DIP"
- 2AD-12, C/5 "RN PMP B STRAINER HI DIP".
ii..JI7G~r:lM<5fjltl~*pr§lMi<5yst;!I~[t:l"isl JF;"any of the previous alarms lit"THENit"THiEN t:l"i.~i)UaIIMlig~9!<fjIYSIll~ft~91~Q§tr~ifl~t; ni~i1ually;backflllsll affected strainer. REFER;:TO~f?/Q/~p4Q(iMQOo.C REFERTO OP/O/.J:\/64001006C (Nucle'~r. Service'Water,$,Ystem).*. (Nycl~~rt'§e~i9~li't'$~t~.~*§Mst~t:l"i)
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/N5500/020 6 of 52 Case I DC~ Rev 37 DC:: Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4.~~rifMe~QI1.~J?~ratingRNJ?"'mp
- 4. Verify each operatingRN pump Perform the following:
dischargeflow-..*.*.L.ESS'J"tifJ:,.N'?3,Q()Q (J.il?gllarg*l:t*.flow LESSTHAN 23,000 GPM. CAUTION Closing of the RN supply x-over isolation valves may result in the momentary isolation of an essential header. NOTE Isolating the Unit 1 or 2 non-essential header will result in loss of cooling supply to the following unit related equipment:
- VA Supply Vent Units
- VF Supply Vent Unit.
- a. Ensure the following RN supply X-Over isolation valves - CLOSED:
- 1RN-4 RN-47A7A (RN Supply X-Over Isol)
- 1 RN-48B (RN Supply X-Over Isol)
- 2RN-47A (RN Supply X-Over Isol)
- 2RN-48B (RN Supply X-Over Isol).
- b. IF flow is returning to normal, THEN GO TO Step 5.
- c. IF flow is still excessive, THEN:
_ 1) Ensure both RN pump(s) on the affected train - OFF. _ 2) Dispatch operators to locate any piping leaks. REFER TO AP/O/N5500/030 (Plant Flooding). 55..Eg§,"'ti;£iRN:p"'rnp§:;i¥INIe~§~iflqN~s* Ens'ureRNpumps ~IN OPERATION AS' NE'EeEe~ NEEDED.
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/0/A/5500/020 7 of 52 Case I Rev 37 DC~ Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. eil~l,Ir~pr9per Ensure proper Cllignmeil~9fRtf~Ql<G alignment of RN tg KC Hxsas***fQllovvs:
Hxs as fOllows:
- a. "Vt§~.if~:r'!RN;".AL!.~N~'[j)'TO.***.*IN./§3.~!Rxtl~~
Verify RN,. AUG NED TO IN SERVI.CE a. Shift KC train in service as needed.
"C;;lfi~C§3)E*
KCHX(S}. REFER TO:
- OP/1/A/6400/005 (Component Cooling Water System)
- OP/2/A/6400/005 (Component Cooling Water System).
- b. EnsuteKCliixOtltlvlede*
Ensure KC Hx Otlt Mode switches swltct:les'"- PR@PERLYALIGMEO. PROPERLY ALIGNED.
- 7. Verify each operating RN
- putilp "erifYr~aeijQpg~Clting~tf.* pump Perform thett:le following:
di~~ij~tgefI9W~GReA:rER discharge flow* GREATER .TH~tf~,60Q THAN 8,600 GRM. GPM; a. Do not exceed 4650 GPM through an liix. NS Hx.
- b. Align RN flow through NS Hx(s}
liix(s) as needed to increase each operating RN pump's discharge flow to greater than 8,600 GPM. REFER TO OP/0/A/6400/006F (Nuclear Service Water System Flush Procedure).
- 8. "erifY.RNi."~"~I.I.;AI3JgeTO Verify RN
- AVAILABLE TO *. ALLiYJ~.I.T ALL UNIT Dispatch operator to locally remove any
**~:AtfQ:YN.IT:2IQlG(~l.
1.AND<UNIT 2 D/G(s). D/G(s) without a cooling water supply from standby readiness. REFER TO:
- OP/1/A/6350/002 (Diesel Generator Operation)
- OP/2/A/6350/002 (Diesel Generator Operation).
Operation ).
- 9. DetermineVCNc;:statusas follows: _ Align VCNC to operating RN train.
REFER TO OP/O/Al6450/011 OP/0/Al6450/011 (Control
**"Vt§l'if~:MC;;f?r.~)iPA,*I~N.~JJi1?@
Verify VCNG'- ALIGNED TO Room Area Ventilation/Chilled Water
@PERATING*RMfl'RAIM.
OPERATINGRN TRAIN . System).
- Verify YC Chiller- RUNNING.
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. 101N55001020 AP/O/A/5500/020 AP 8 of 52 Case I Rev 37 DCS DC~ Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. [)ete~mrQ'~ *. and Determine ati(;f~o~t~ptcat.lseofloS$*,of correct cause of loss of RN train~
RNtr~iim TS 3.7.8 Condition A 11 ..EJ1~i..lt~'~omplnllj~~.wiJJj.appI'QPtiat~ Ensure compliance with appropriate Te~Jj.§p~t;!)aodSel~t;t~d.] Tech Specs and Selected Licensee .. ic~l)§ee Commitments/Manual: Commitments Manual: _ *.' §tq)p;7,,"p*(if3JJ5I*.*IJi~phatg'~ SLC16.7-6 (RN Discharge IftI§trjjlmeftitaliQr)~ Instrumentation) _ .: ~lp*~(CQftlt~!Mfi1~nt:*~ir'*li~~perat(;jte) 3.6.5 (Containment Air Temperature) _ .', 3.6.6 ~Containment Spray System) i* ~ip.p(CC?nt?infi1~nt:i'§pr?y§ysf~.rn)
*~*~;p:17:{C9f')t?inme.Mt*'Y'C3.lv~"li8jectiQn 3.6.17 (Containment Valve I njection VWC3.terS}'st~fi1i.*QCVIVW§~~
Water System (CVIWS>>
- 3*7i\~~AI.l!Jtliary**'.,.IF~~dwC3.fet:(AIFW) 3.7.5 (Auxiliary Feedwater(AFW)
~ystem)
§.y~t.~m)
- 3.7.7 3;7.7*** (CC?m'PQn~f)i~iCC?oliJ1gVWC3.f~r(CCVW}
(ComponenVCooling Water (CCW)
§yst~m'>
System)
* ~**l*8*,(N(;j9Iear'Ser:vip~W?t~rSyst~1Tl 3.7.8 (Nuclear Service Water System (J5I§VWS))
(NSWS>>
- 3.7.10 (Control Room . Area
~.7.1*0{CG)ntrplr~QQm Y'entili3.tion Ar~a.* Ventilation Syst~~**.'Gc~VS'>~
System (CRAVS>>
- 3.7~ 11 (Control Room Area Chilled Water
*.~*7r;*1i1(qof)ttQF~C?Clifi1>At~:;i.iCt;)Illed.'VW~tet Sy~t~m(q~CVW§~)
System (CRACWS>>
.3:8;1(.l\;c.§QtirPe~
.3.8.1 .-~f¥lr:;itijjg)
(A ,G. Sources-Operating)
* *~18;~(A.G.§c?JjtQe~*,8§t;)'(;jlgG)Wnli 3.8.2 (A.C. Sourees-,Shutdown).
- 12. Determine required .rjotifications:
- RERERmmHP/01A,t50ooI00;1 REFER TO RP/0IN5000/001 (Cla~§it!Q.atipO'G>t**:gfi1~rg@n9Y~
(Classificc;ltion OfFmerg~ncy)
.;*. RERERTQf3J~to/~I~oooZOi;1i~I:'QJ5I~q REFER TO RPIOIB/5QOO/013 (NRC N9tjfi9~ti9ngeCj(;jir~'fi1'~jjt§)'(
Notification Requirernents)f 13. 1'31, ~oti~El1~Itol1m~l1Ital~Jj~fi1i§ti¥'.of* NgtifyEnvironmental Chemistry of.*any any: BN***'PuJjjp.~*Jjin$tJjatpa~~,pt;~Qr~e(;f; RN pump shifts that have.occurred.
CNS LOSS OF NUCLEAR SERVICE WATER PAGE NO. AP/O/A/55001020 90f52 Case I Rev 37 DC!: DCS Loss of RN Train ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 14. Qetermine long':t~rm pl:;mt s~atus.
RETURN TO:procedqre lin effect.
Initiating Cues: -1SB-12
- 1SB-12 indicating lights intermediate on 1MC-2 1MC-2
-* OAC alarm C1Q0966 (SB-12 Mn Stm Bypass to Cond Control #12) -* Turbine MW decreasing
CNS SECONDARY STEAM LEAK PAGE NO. APt1tAJSSOOt028 AP/1/AJ5500/028 1 of 41 RevS Rev 5 DCS A. Purpose To provide proper response for operator actions for a secondary steam leak when a Reactor Trip or Safety Injection has not occurred. B. Symptoms
- Reactor power greater than turbine power
- Reactor power greater than 100%
- NC T-Avg decreasing in an unexpected manner
- Steam pressure decreasing in an unexpected manner
- 1AD-2, Et8 E/8 "OVER POWER ROD STOP" - LIT
- 1AD-13, Al7 "ICE COND LOWER INLET DOORS OPEN" - LIT
- One or all of the following increasing without abnormal containment radiation:
- Containment pressure
- Containment temperature
- Containment humidity
- Containment floor & equipment sump level
- Loss of secondary condensate inventory
- Observed secondary steam leak.
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/55001028 AP/1/AJSSOOI028 2 of41 of 41 RevS Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions RO DOES THIS PAGE IEXCEPT 6 I
- 1. M.~:>nitbrEnclc)sure 1 (Foldout Page).
- 2. VerifYturbine- ONLINE. _ GO TO Step 6.
3~!lf'n~lJIlje'l,..niMi-":(8;"1
- 3. i!liL;~~'0
. VerifY the".M!,.OB~mS'V
... following: Perform the following:
_
- t~g~:cI9~.~dlI~~;1Il Reactorpower - LESSTHAN OR _ a. .li.JrJl~N~tr.:!t~l!i!'@ll~~f?jt\\:e;!pc;lltJIIJ Select "MANUAL" on turbine control t;~.t.?JL"i4W1_/j\~~Vl4l~)
EQUAL TO 100% POWER ,fill-panel. _ .* T-Avg - WITHIN 1.soF 1.5°F OF T-Ref. b. 1Qm._~Ji'~{tI#\1~}f,~;~'()It~~~, DepressCONTROL VALVES LOWER"
- 6WftHfj,{i~nVa_;rp""ilica¥ftit1tiin"<if?diil);tii pushbutton and
~'n.~~\~~?,. ,.... "~',.' reduce r, turbine
~~"Y" "."~*.".'_' load ..to
.. '~'.~'c .,.,~~~, " ..,.,
timing~ Depending on timing fI~i!Wjl~ maintain: reactor power will likely _ * *lKtf~~tlt(p,twer~~LqgS.::r:I'i(~~,*QtIl& Reactor power - LESS THAN OR exceed 100%. ;1~1lI~iliQt;1 EQUAL TO 100% OJ.i%~~w,aR' POWER _ i'?I'Hi'Al~~Willilf'llN,,1i!~~If;'.()Fl;-~~
.' T-AVg,- WITHIN 1.5°F OF T-Ref.
- 4. VerifY proper reactor response as _ IF T-Avg is greater than 1.soF 1.5°F higher follows: than T -Ref, THEN manually insert control T-Ref, rods as required to maintain T T-Avg
-Avg within
- Coritrol rods' - IN "AUTO" AND 1°F of T-Ref.
STEPPING IN
- P/R neutron ;flux .. DECREASING.
- 5. IF AT ANY !TIME,reactorpower is great~r than 100%,THENp~rform Step 3 RNO.
Isopl 6. VerifY Pzr lev~1 - STABLE OR Perform the following: I~CREASING.
- a. Maintain charging flow less than 180 GPM.
- b. Manually throttle 1NV-294 (NV Pmps A&B Disch Flow Ctrl) to stabilize Pzr level.
- c. IF Pzr level is stable OR increasing, increasing.
THEN GO TO Step 7. (RNO continued on next page)
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/5500/028 AP/1/Al5500/028 30f41 Rev 5 DCS RevS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. (Continued)
- d. IF Pzr level continues to decrease, THEN perform the following:
- 1) Reduce letdown flow to 45 GPM as follows:
a) IF 1 NV-1 OA (Letdn Orif 1B Otlt Cont Isol) open, THEN perform the following: _ (1) Manually control1NV-148 control 1NV-148 (Letdn Press Control) to establish letdown pressure between 375 - 400 PSIG. _ (2) Throttle 1NV-849 (Letdn Flow Var Orif Ctrl) for 45 GPM letdown flow. _ (3) WHEN 45 GPM letdown flow established, THEN adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure at 350 PSIG. _ (4) WHEN letdown pressure is stable at 350 PSIG, THEN place 1NV-148 (Letdn Press Control) in auto. (RNO continued on next page)
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/AJ5500/028 AP/1 / Al5500/028 40f41 4 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. (Continued) b) IF 1NV-13A (Letdn Orif 1A Otlt Cont Isol) open, THEN perform the following:
_ (1) Manually control1NV-148 control 1NV-148 (Letdn Press Control) to establish letdown pressure between 150 - 200 PSIG. _ (2) Open 1NV-11A 1NV-11A (Letdn Orif 1C Otlt Cont Isol). _ (3) Adjust 1NV-148 (Letdn Press Control) to establish letdown pressure between 375 - 400 PSIG. _ (4) Close 1NV-13A NV-13A (Letdn Orif 1A Otlt Cont Isol). _ (5) Adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure at 350 PSIG. _ (6) WHEN letdown pressure is stable at 350 PSIG, THEN place 1NV-148 (Letdn Press Control) in auto. _ 2) IF Pzr level is stable OR increasing, THEN GO TO Step 7. (RNO continued on next page)
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/AJ55001028 AP/11A155001028 50f41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. (Continued)
- 3) IF Pzr level continues to decrease OR Pzr level cannot be maintained greater than 11 %, THEN:
_ a) Trip reactor. b) Close the following valves:
- All MSIVs
_
- All MSIV bypass valves.
_ c) Initiate S/I. S/!. _ d) GO TO EP/1/AJ5000/E-O EP/11A15000/E-O (Reactor Trip Or Safety Injection). ((Q.EJ
- 7. IF AT"ANY, TIM E ..while in this procedure Pzr level is decreasing in ian uncontrolled manner; THEN RETtJRNTO Step . 6.
[Bop!
- 8. IF ATANYTIME VeT level gOes belo.w 23%, THEN align NV pump suction to FWST as follows:
- a. Open the following valves:
- 1NV-252A (NV Pumps Suct From FWST)
- 1NV-2538 (NV Pumps Suct From FWST).
- b. Close the following valves:
- 1NV-188A (VCT Otlt Isol)
- 1NV-1898 (VCT Otlt Isol).
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/55001028 AP/1/A/5500/028 6 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. Att~mpltp<id~nti'fY*'*atl*cI*.*.i§pl~t~I~~k~§ Attempt to identify and isolate leak as follows:
Isopl a.
- a. Verify the following c()nditiol1s,~
"YJerifythe,*follQWingc<;)t\difiOi')§;-;** a. Perform the following:
NORMAL: _ 1) Evacuate containment.
- Containmenttemperature CQnt~Il1m~ottef;tjjijf¥p?ture
- 2) Perform the following:
- Coht?iOr;neofjijrf¥§$ure Containment pressure
_ a) Start all lower containment
* ' Cotlt?iomf¥othllimidlly Containment humidity ventilation units in low sgeed.
speed. CQ[ltail"l.tl1~l"ltfIQQt
- Containment floor *.*.~*****.eqLligmf¥l"lt§Lltl115
& eqUipment sump _ b) Start all upper containment level. ventilation units.
_ c) Place all upper and lower containment ventilation units in "MAX" cooling.
- 3) IF AT ANY TIME containment pressure reaches 1.2 PSIG, THEN:
_ a) Ensure reactor tripped. _ b) Ensure SII initiated. c) Close the following valves:
- All MSIVs MSI"YJs
- All MSIV MSI"YJ bypass valves.
_ d) GO TO EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection). _ 4) GO TO Step 10. Disg?tQhLQjijer?t<;)~t<;)I<;)C;ptf¥<?Od
- b. Dispatc;:hoperator:g tqJocate and jdf¥otify*sqqrt:;f¥.qf$tf¥~f;tj*If¥?~:
identify sotlrc~of ste~m leak. Crew should already have noted that its a condenser dump valve and there is no need to send anyone to check for external leaks.
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/AJ55001028 AP/1/A/5500/028 7 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued)
\terity~tG,**p(])~VS~~LOS~P;
- c. Verify S/G PORVs - CLOSED. c. IF S/G pressure is less than 1090 PSIG, THEN perform the following:
_ 1) Close affected S/G POR\t. PORV.
- 2) IF S/G POR\t PORV is still open, THEN:
_ a) Close affected S/G POR\t PORV isolation valve. _ b) IF S/G POR\t PORV isolation valve still open, THEN dispatch operator to close S/G POR\t PORV isolation valve.
\terify.c6nq!ef1setdutnlJ'Vi:l;l~es
- d. Verify condenser dump valves- d. F?erforrr)the.f6fI6willg:
Perform the following: CLOSED. Select "OFFRESET'6Ilthe
- 1) Select "OFF RESET" onJhe following fol switches:
IQWing SwitcheS:
*-"STEJ,NMDI.JMP "STEAM DUMP INTLKBYPTRN INTLK SYP TRN A"
A" "ST~J,NM:QUMF?'INTI:;K<BYP
*II'* "STEAMDUMP INTLK SYP TRN TRN Stl.
B". _ "~) 'IF"V~1~eM{iJIQ6lcI6sei:rHEN:
- 2) IFvalve will not close, THEN q!JsA~1cl;jj}6IJef~!6cJocloseaffeeted dispatch operator to close affected condenser . dump
*CDQdellser* q!9tn:rkv~lve*is6Iatlbn valve isolation valve.
vaJve:.
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/Al5500!028 AP/1/Al5500/028 8 of 41 80f41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued)
- e. Verify atmospheric d~mp valves - e. Perform the following:
CLOSED.
- 1) Select "OFF RESET" on the 1}
following switches:
* "STEAM DUMP INTLK BYP TRN A"
* "STEAM DUMP INTLK BYP TRN B".
_ 2) IF valve will not close, THEN close 2} affected atmospheric dump valve isolation valve. _ 3) IF isolation valve will not close, 3} THEN dispatch operator to fail air to affected atmospheric dump valve.
- f. V~rify CA PMP #1 - OFF. f. IF operation of CA PMP #1 is causing uncontrolled cooldown AND flow from CA PMP #1 not required, THEN stop CA PMP #1.
CAPMP#1.
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A155001028 AP/1/A/5500/028 9 of 41 90f41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. (Continued) g . 'If..;~:.;'!Ie.
g.IF leak B.
--0;..<,,' - ...
*G.::~.;i&d.ij.i'qn4j'i\l'.'<!ld;im.
suspected to ~:~~ be .*in is ~'9J:"',~Q!l~"",c;;:;",~~~~~i'*V~Q~)
,~.~, *vh'~ :a,
*ii'!;.~*R"*.,1 d(l)Dh~lg~iig.;jclose doghouse, THEN close the following valves:
- Outside DH:
- 1SM-77A 1SM-77A(S/G (S/G 1A 1AOtitHdrBldwn Otlt Hdr Bldwn CN)
- 1 SM-74B (S/G 1D Otlt Hdr Bldwn 1SM-74B CN).
OR
- Inside DH:
_ .* 1SM-76B (S/G 1B Otlt Hdr Bldwn CN) _ .* 1SM-75A (S/G 1C Otlt Hdr Bldwn CN). 110. O. ..te<<mfj:~Kf!I'.Ir<<(lf~A.~til1i$:~ Determinereqoired notifications: _ ~\R.~ffSR.il}.ffJQ~.&&.*
- REFER TO RP/O/A/5000/001
~(t~$~f~~tt~1'I)Q.~tijmR (Classification Of Emergency) to§ D:JZ:IiiRDi*:rmliO;Jl1UVD4J;no**l¥lllll'l.;'O';1JIIlI'El1?!t REFER.TO .RP/O/B/500QI01~* (NRC
- M~~~~~4!~&1!f¥"~h~~"~~d~14~:;:;~~~;)J;'~.~~:BB ~------------------------
_ 'w"
~Q1;~fiX~'Ii'1;"'M£1J;~il'f""~~i!\'1fJ8);
Leak will likely not be isolated at Notification
'1P' , ;Yi!it~,}t~~~vm"v;;~ Requiremet;1Js)..
this time. 11 . NOJify RP of.leak:
- 12. V~rify - LEAKISOLATEIi>: _ GO TO§tep14..
- 13. Determine long term plant status.
RETURN TO procedure and step in effect.
CNS SECONDARY STEAM LEAK PAGE NO. AP/11A155001028 AP/1/A/55001028 100f41 10 of 41 Rev 5 DeS DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED "i¥~if&f'il;J§mJ~'!(el!"§"fA.BL..E VerifyUSTfevef -STABLE **QR OR Perform the following: lNOREA.SING~
,INCRI;ASING.
- a. Initiate makeup to UST.
- b. Notify Secondary Chemistry of increased makeup.
- 15. Verify - REACTOR QRITICAL _ GO TO Step 22.
- 16. Di¥ti¥ri1'(i!\ii¥;:~pptoJ{.ii1'(lU~st~~i1'(leal<$i~~
Determine apProximate steam leak size aSif9J.lpM($': as folloWS:
- a. Verify;. TURBINE ONLINE, a. Perform the following:
_ 1) Determine leak size from observed increase in reactor power.
- 2) IF leak size is less than 5%, THEN perform the following:
_ a) Notify RP of leak size. _ b) GO TO Step 17.
- 3) IF leak size is greater than or equal to 5%, THEN:
_ a) Notify RP of leak size. _ b) Trip reactor. c) Close the following valves:
- All MSIVs
_
- All MSIV bypass valves.
_ d) GO TO EP/11A15000/E-O EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/55001028 AP/1/Al5500/028 110f41 11 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 16. (Continued)
IRQ I b. etIsWtpt,st~IB:;jrylaf:;;:'nQjronli EnSure
~,="'o ",.,* stable plant
..,.~i'~'Lv,.g, conditions:
*.n)~ .. ,.L .Hi. b. Perform the following~
- Stable TAvg _ 11))W~I3~Il§;1aJl~J>I~I~~~~lti9tli~.~~i~~:
WHEN ~table plahtconditions exist;
'lliMBNt~~lf~I#1*:&t:~p~?ip';q, THEN perform Steps 16.c
- Condenser dump valves dosecj;. tJ!JtQWgb;i1J1§.~Zt through . 16.e.
2)
- 2) .~*QiJ"tJli0q¥;{nL'~j;7f.
GO TO
'~~r;,~' Step 17.
..0-:~f{~~~:.'.>:~:1f:~
Secondary plant configuration can affect Thermal Power Best Estimate. Diverse reactor power indications should be used to determine reactor power.
- c. Determine percent turbine power as follows:
_ 1) Divide turbine impulse pressure by 100% power value for turbine impulse pressure. REFER TO OAC Data Book for 100 % power value for turbine impulse pressure. _ 2) Multiply result by 100.
- d. Verify difference between reactor power d. Perform the following:
and turbine power - LESS THAN 5%. _ 1) Notify RP of leak size. _ 2) GO TO Step 19. _ e. Notify RP of leak size.
- 17. Verify reac.tor p.ower.:; GREATER THAN _ GO TO Step 22.
1%. Once the valve is closed, the next event can be entered.
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A15500/028 AP/1/A155001028 12 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 18. EYCJluateunitshutdown as follows:
- a. Verify unit shutdown .required based on a. Perform the following:
either of the following : _ 1) Maintain present plant conditions
- Steam lefik cannQtibe isolated or until leak can be isolated or repaired at power repaired.
_ 2) RETURN TO procedure and step in e:ffect. _
- OSM judgement.
- b. Initiate unit shutdown. REFER TO one of the following:
_ .* OP/1/A161 OP/11 A161 00/003 001003 (Controlling Procedure For Unit Operation) OR _ .* OP/1/A161 00/002 001002 (Controlling Procedure For Unit Shutdown) OR _
- AP/1/A15500/009 AP/1/A155001009 (Rapid Downpower).
- c. GO TO Step 20.
CNS SECONDARY STEAM lEAK PAGE NO. AP/1/AJ5500/028 AP/1/A/55001028 13 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 19. Perform the following:
- a. Verify steam leak*
leak - KNOWN TO BE a. Perform the following: ISOlABlE BY TURBINE TRIP. _ 1) Trip reactor.
- 2) Close the following valves:
- All MSIVs
_
- All MSIV bypass valves.
_ 3) GO TO EP/1/AJ5000/E*0 EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).
- b. Verify reactor power*
power - GREATER THAN b. Perform the following: 69%. _ 1) Trip turbine. _ 2) GO TO AP/1/AJ5500/002 AP/1/A/55001002 (Turbine Generator Trip).
- c. Trip reactor.
- d. GO TO EP/1/AJ5000/E*0 EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).
- 20. WHEN turbine is tripped, THEN verify Perform the following:
T-Avg can be controlled within 5°F of T-Ref while shutting down reactor to 1%. a. Trip reactor.
- b. Close the following valves:
- All MSIVs
_
- All MSIV bypass valves.
- c. GO TO EP/1/AJ5000/E*0 EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).
- 21. Verify reactor power - LESS THAN 1%.
1%. _ RETURN TO Step 18.
CNS SECONDARY STEAM LEAK PAGE NO. AP/11Al55001028 AP/1/A/5500/028 14 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. Verify NC temperature under operator control as follows:
- a. Verify one of the following: a. Perform the following as required:
_ . IF any NC pump on, THEN verify NC _ 1) Ensure steam dumps - CLOSED. T-Avg - TRENDING TO PROGRAMMED TEMPERATURE 2) Ensure the following valves - CLOSED: OR
- 1HM-1 (MSRH 1A&1B SSRH Stm
- IF all NC pumps off, THEN verify NC Source)
T -Colds - STABLE AT OR TRENDING TO 55rF.
- 1HM-2 (MSRH 1 C&1 D SSRH Stm 1C&1 Source).
_ 3) Ensure S/G PORVs - CLOSED.
- 4) IF any S/G PORV can not be closed, THEN:
_ a) Close affected S/G PORV isolation valve(s). _ b) IF affected S/G PORV isolation valve(s) can not be closed, THEN dispatch operator to close valve.
- 5) Close the following controllers:
* "S/G A BLDWN FLOW CTRL"
* "S/G B BLDWN FLOW CTRL"
* "S/G C BLDWN FLOW CTRL"
* "S/G D BLDWN FLOW CTRL".
(RNO continued on next page)
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/AJ5500/028 AP/1/A/5500/028 15 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. (Continued)
- 6) Depress and hold "SN BEFORE SEAT DRN" "CLOSE" pushbutton (1 MC-3) to close the following valves:
- 1SM-41 (Stop Vlv #1 Before Seat Drn)
- 1SM-44 (Stop Vlv #2 Before Seat Drn)
- 1SM-43 (Stop Vlv #3 Before Seat Drn)
- 1SM-42 (Stop Vlv #4 Before Seat Drn).
- 7) IF cool cooldown down continues, THEN control total feed flow as follows:
_ a) Maintain total feed flow greater than 450 GPM until at least one S/G N/R level greater than 11 %. b) WHEN N/R level greater than 11 % in at least one S/G , THEN throttle feed flow to:
- Minimize cooldown
- Maintain at least one S/G N/R level greater than 11 %.
- 8) IF cooldown continues, THEN close:
- All MSIVs
_
- All MSIV bypass valves.
_ 9) IF uncontrolled cooldown continues, THEN GO TO Step 23. _ 10) IF uncontrolled cool down stopped, THEN GO TO Step 24.
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A155001028 AP/1/A/5500/028 16 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. (Continued)
- b. IF AT ANY TIME while in this procedure NC temperature is decreasing in an uncontrolled manner, THEN RETURN TO Step 22.
- c. GO TO Step 24.
- 23. Complete the following for an unisolable steam leak that is causing uncontrolled cooldown:
- a. Verify all rod bottom lights - LIT. a. Perform the following:
_ 1) Trip reactor. _ 2) Direct RO to concurrently isolate S/Gs with steam leak. REFER TO Enclosure 2 (S/G Steam Leak Isolation). _ 3) GO TO EP/1/A/5000/E-O EP/1/A15000/E-O (Reactor Trip Or Safety Injection).
- b. Isolate S/G with steam leak. REFER TO Enclosure 2 (S/G Steam Leak Isolation).
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/5500/028 17 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 23. (Continued) level-- TRENDING TO OR
- c. Verify Pzr level c. Perform the following as required to STABLE AT PROGRAMMED LEVEL. maintain level:
_ 1) Discontinue monitoring Pzr level per Step 7. _ 2) Maintain charging flow less than 180 GPM at all times in subsequent steps. _ 3) Manually throttle 1NV-294 (NV Pmps A&B Disch Flow Ctrl) to stabilize Pzr level. _ 4) IF Pzr level is stable OR increasing, THEN GO TO Step 23.d.
- 5) IF Pzr level continues to decrease, THEN perform the following:
a) Reduce letdown flow to 45 GPM as follows: IF 1NV-1 OA (Letdn Orif 1B (1) IF1NV-10A(LetdnOrif1B Cant Isol) open, THEN Otlt Cont perform the following:
- 1. Manually control 1NV-148 (Letdn Press Control) to establish letdown pressure between 375 - 400 PSIG.
- 2. Throttle 1NV-849 (Letdn Flow Var Orif Ctrl) for 45 GPM letdown flow.
- 3. WHEN 45 GPM letdown flow established, THEN adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure at 350 PSIG.
(RNO continued on next page)
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/AJ55001028 AP/1/A/55001028 180f41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 23. (Continued)
- 4. WHEN letdown pressure is stable at 350 PSIG, THEN place 1NV-148 (Letdn Press Control) in auto.
(2) IF 1 NV-13A (Letdn Orif 1A Otlt Cant Cont Isol) open, THEN perform the following:
- 1. Manually control 1NV-148 1NV-148 (Letdn Press Control) to establish letdown pressure between 150 - 200 PSIG.
- 2. Open 1NV-11A (Letdn Orif 1C Otlt Cant Cont Isol).
- 3. Adjust 1NV-148 (Letdn Press Control) to establish letdown pressure between 375 -
400 PSIG.
- 4. Close 1NV-13A (Letdn Orif 1A 1A Otlt Cont Cant Isol).
- 5. Adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure at 350 PSIG.
- 6. WHEN letdown pressure is stable at 350 PSIG, THEN place 1NV-148 1NV-148 (Letdn Press Control) in auto.
_ b) IF Pzr level is stable OR increasing, THEN GO TO Step 23.d. (RNO continued on next page)
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/55001028 AP/1/AJ55001028 19 of 41 190f41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 23. (Continued)
- 6) IF Pzr level continues to decrease, THEN:
a) Start an additional NV pump as follows: _ (1) Open 1NV-252A (NV Pumps Suct From FWST). _ (2) Open 1NV-253B (NV Pumps Suct From FWST). _ (3) Close 1NV-188A NV-188A (VCT Otlt Isol). _ (4) Close 1 NV-189B (VCT Otlt Isol). _ (5) Start the desired NV Pump. _ b) IF Pzr level is stable OR increasing, THEN GO TO Step 23.d.6. c) IF Pzr level continues to decrease OR Pzr level cannot be maintained greater than 11 %, THEN: _ (1) Initiate S/I. _ (2) GO TO EP/1/A/5000/E-O EP/1/AJ5000/E-O (Reactor Trip Or Safety Injection).
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/5500/028 AP/1/Al5500/028 20 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 23. (Continued)
- d. Initiate boration of NC System as follows:
_ 1) Ensure at least one NV pump - ON. _ 2) Open 1NV-236B (Boric Acid To NV Pumps Suct). _ 3) Start boric acid transfer pumps. _ 4) Verify boration flow - GREATER 4) Align NV pump suction to the FWST THAN OR EQUAL TO 30 GPM. as follows: a) Open the following valves:
- 1NV-252A (NV Pumps Suct Suet From FWST)
- 1NV-253B (NV Pumps Suct From FWST) b) Close the following valves:
- 1NV-188A (VCT Otlt Isol)
- 1NV-189B (VCT Otlt Isol).
- 5) Ensure the following charging line isolation valves - OPEN:
_ . 1NV-312A (Chrg Line Cont Isol) _ . 1NV-314B (Chrg Line Cont Isol). _ 6) Verify Pzr pressure - LESS THAN 6) Perform the following: 2335 PSIG. a) Verify the following valves - OPEN.
- All Pzr PORVs
- All Pzr PORV isolation valves.
_ b) IF any Pzr PORV(s) OR isolation valves closed, THEN manually open Pzr PORV(s) and isolation valves as required to reduce Pzr pressure to less than 2315 PSIG.
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/55001028 AP/1/A155001028 21 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 23. (Continued)
- e. Ensure adequate shutdown margin is maintained. REFER TO ROD Book, Section 5.11.
- f. Maintain S/G NR levels greater than 11%.
- g. Continue plant shutdown. REFER TO one of the following:
_
- OP/1/A/61 OP/1/A161 001002 (Controlling Procedure For Unit Shutdown)
OR _ AP/1/A155001009 (Rapid
- AP/1/A/55001009 Downpower).
- h. IF intact S/G MSIVs must remain closed to isolate leak, THEN RETURN TO procedure in effect.
- i. WHEN cooldown stops, THEN open intact S/G MSIVs. REFER TO OP/1/A/62501006 OP/1/A162501006 (Main Steam).
_ j. RETURN TO procedure in effect.
- 24. Verify - LEAK ISOLATED. Perform the following:
- a. IF leak downstream of MSIVs, THEN perform the following:
- 1) Evaluate closing MSIVs using the following criteria:
- Location of leak
- Ability to isolate leak
- Secondary condensate inventory
- Size of leak.
(RNO continued on next page)
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/A/5500/028 22 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 24. (Continued)
- 2) IF determined that closing MSIVs is required, THEN:
a) Close the following valves:
- All MSIVs
- All MSIV bypass valves.
b) Control NC temperature at program temperature using one of the following: _ . Dump steam using S/G PORVs. OR
- Establish S/G blowdown.
REFER TO OP/1/A/6250/008 (Steam Generator Slowdown). _ 3) IF closing MSIVs is not required, THEN maintain present plant conditions until leak can be isolated or repaired.
- b. IF leak is upstream of MSIVs, THEN:
- Maintain S/G NR levels greater than 11% .
11%.
- Continue plant shutdown. REFER TO one of the following:
_
- OP/1/A/61 00/002 (Controlling Procedure For Unit Shutdown)
OR
- AP/1/A/5500/009 (Rapid Down power).
Downpower).
CNS SECONDARY STEAM LEAK PAGE NO. AP/1/AJ55001028 AP/1/A/5500/028 23 of 41 Rev 5 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 25. Determine long term plant status.
RETURN TO procedure in affect.
CNS SECONDARY STEAM LEAK PAGE NO. AP/11A15500/028 AP/1/A/SSOO/028 24 of 41 Enclosure 1 - Page 1 of 2 Rev S 5 DCS Foldout Page
- 1. Reactor trip criteria:
IF any of the following conditions exist:
- Steam leak is endangering personnel or jeopardizing plant equipment
- S/G levels - DECREASING IN AN UNCONTROLLED MANNER SOF less than T-Ref AND decreasing in an uncontrolled manner
- Tavg 5°F
- Reactor power - INCREASING IN AN UNCONTROLLED MANNER
- Secondary condensate inventory - DECREASING IN AN UNCONTROLLED MANNER.
- a. Trip reactor.
- b. Close the following valves:
- All MSIVs
- All MSIV bypass valves.
EP/11A15000/E-O (Reactor Trip Or Safety Injection).
- c. GO TO EP/1/A/SOOO/E-O
Duke Energy Procedure No. Catawba Nuclear Station 1 API IA/5500/023 Loss of Condenser Vacuum Revision No. 018 Electronic Reference No. CN005CER Continuous Use PERFORMANCE I
- UNCONTROLLEDFORPruNT**********
(ISSUED) - PDF Format Initiating Cues:
,Initiating I- 1AD1, F/7 II II.-
!- OAC alarm C1A0734 (Condenser C absolute backpr-essure)
,. Turbine MW decreasing I
II I I J
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/AJ55001023 AP/1/A/5500/023 1 of 15 Revision 18 A. Purpose
- To verify proper response in the event of a loss of condenser vacuum.
B. Symptoms
- Condenser vacuum indication - DECREASING
- Hotwel! temperature - INCREASING Hotwe"
- 1AD-1, F/7 "CONDENSER LO VACUUM" - LIT
- FIB "EXH HOOD HI TEMP (PRE-TRIP)" - LIT 1AD-1, F/8
- 1AD-5, Al4 "CFPT A LO EXHAUST VACUUM" - LIT
- 1AD-5, C/4 "CFPT B LO EXHAUST VACUUM" - LIT
- OAC point C1P1493 (Unit 1 C1&C2 Average RC Inlet Temp) -IN ALARM HI.
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/A/55001023 AP/1/Al5500/023 2 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions - 1. Monit<?rE;nclosuni'1 (Foldout Page).
- 2. Decrease turbine load as required to stabilize vacuum as follows:
- a. IF rapid power reduction required, THEN perform the following:
NOTE In "MANUAL" mode, the control valves are capable of full travel within',3 minutes. _1) Sel~ct "MANUAL" and "CONTROL Crew should stay in this AP at this thTSl VALVE LOWER":tQf(educe turbine loap as required. time. I I _ 2)*
- 2) REFER TO AP/1/A/55001009 (Rapid DowtlpOwer). '.. . I
_ 3) GO TO Step 3. I
- b. Perform the appropriate controlling procedure to reduce power: When turbine load has been reduced to
!When approximately 1135 MW, the leak will
!approximately
-_ .* OP/1/Al61 OP/1/A/61 00/003 001003 (Controlling get smaller and vacuum will recover.
Procedure For Unit Operation) OR
-
- OP/1/Al61 OP/1/A/61 00/002 001002 (Controlling Procedure For Unit Shutdown).
I 1 II
~
I I
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/AJ55001023 AP/1/A/5500/023 3 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. Verify proper RCSYstem operation as follows:
- a. V,¢rify average condenser inlet a. Perform the following:
temperature OAC point C1P1493 (Unit 1.C1'!&C2Average RC Inlet Temp) ,. _ 1) Start additional cooling tower fans LESS THAN 90°F. as necessary to maintain condenser inlet temperature less than 90°F. gO°F. OP/1/B/6400/001A REFER TO OP/1/B/64001001A (Condenser Circulating Water System). _ 2) Start additional RC pump(s) as necessary to maintain condenser inlet temperature less than 90°F. gO°F. REFER TO OP/1/B/64001001A OP/1/B/6400/001A (Condenser Circulating Water System).
- b. VerifS<,1AD,.8, B/4 "COOLING TOWER' b. IF cooling tower level is low, THEN BASIN~HII[O LEVEL" ,. DARK. perform the following:
_ 1) Ensure 1RL-853 (Train A RL To RC Makeup Control) (1MC-13)- (1 MC-13)- RESTORING NORMAL COOLING TOWER LEVEL.
- 2) IF 1RL-853 is not maintaining cooling tower level, THEN perform the following:
_ a) Contact Environmental Chemistry to secure cooling tower blowdown. _ b) Throttle open 1RL-855 1RL-855 (Train A RL To RC M/U Valve Bypass) (1MC-13) to maintain cooling tower level. _ c) Start additional RL pumps as needed. REFER TO OP/O/B/64001003 OP/O/B/6400/003 (Low Pressure Service Water System).
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/11/ Al55001023 AP/1 Al5500/023 4 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. ¥~flfy:'§1iM.ea§§$1iAl.~$~e" Verify"STM PRESS TO CSAE"-** Perform the following:
~~~ =-::~, GREATERTf:lAN1tO.PSIG~ GREATER THAN 110 PSIG.
- a. Adjust 1AS-2 (Main Stm To Aux Steam) setpoint to maintain AS header pressure 165 PSIG.
- b. IF 1AS-2 will not control in automatic, THEN manually adjust 1AS-2 to maintain AS header pressure 165 PSIG.
- c. IF 1AS-2 is functional, THEN GO TO Step 5.
CAUTION Aligning the Unit 2 AS system to supply Unit 1 AS headers may cause small reactivity changes on Unit 2.
- d. IF Unit 2 available to supply Unit 1 AS header, THEN perform the following:
_ 1) 1} Adjust 2AS-2 (Main Stm To Aux Stm) to maintain AS header pressure 165 PSIG.
- 2) Dispatch operator to align Unit 2 AS 2}
as follows: _ a) a} Ensure 1AS-33 (Unit 1 AS Hdr (TB-590, 1M-26) - OPEN. Isol) (T8-590, _ b) b} Open 1 AS-59 (Unit 2 AS Hdr 1AS-59 Isol) (TB-584, (T8-584, 2N-26).
- 3) WHEN 1AS-59
_ 3} 1AS-59 is open, THEN slowly close 1AS-2 (Main Stm To Aux Steam).
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1 / N5500/023 AP/1/A/5500/023 5 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. Verify steam seal header conditions as follows:
- a. Ensure attl~p.~t least *.prl§df*tfu$tPI.loVi,ing one of the following a. GO TO Step 7.
valves': OPEN: _ ~ . . 1Tk?:(Mai~ Stm _ . -1TL-2(Main To Stm
§>t.ll)!p Stm§>~~I~~g)
Seal Reg) _ *~:\:1 .*1l1Z~{3Jf{,L,\ux§ltr:rl1l():
;'1TL-8(Aux Sfm ToStm Seal . *. Reg),
* §lttn§§p..I* Reg*)}*
- b. I\Qjust 1TLA (Sthi SealReg Byp) as required to obtain steam seal header ptessurebetween 4psig and 6 psig.
- c. Verify OAC - AVAILABLE. c. GO TO Step 6 RNO.
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/Al5500/023 6 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Most TL val\fe positions cart be displayed by OACturn on code "TL -TF".
- 6. \'~r.~f¥ Verifysupplemental st~~~~!dwi9 steam flow into the Ensure 1TL-9 (Steam Seal Packing
§J~~rn st~~01 sealf'jeader.by at atJeasione least one of the Un loader Reg Valve) is partially open by fO!IOw fdl'lQwing: performing at least one of the following:
_
- Verify 1TL-3 (Steam Seal Reg Valve)-
- Observe indirect indication of 1TL-9 NOT CLOSED position as follows:
OR a. Observe current steam seal header pressure .
* **M~fifY'~.Qtl)tl)e~QlloWinQ:
Verify'both the following:
- b. Throttle open 1TL-4 (Stm Seal Reg
.' tJriit)1*;:~M*.*iJ@INIE.
- etJnit 1"ON UNE. Byp) until one of the following conditions are met:
- 1TL-1'O(E Bleed .~RSt~al~S~aIES~g Steam Seal Reg Valve)- NOT.Cl-OSE[D.
.CLOSEffi, _ . Steam seal pressure - GREATER THAN 6 PSIG.
OR
- Steam seal pressure - NOT INCREASING IN RESPONSE TO 1TL-4 POSITION POSITION..
- Coordinate local observation of 1TL-9 position as follows:
- a. Dispatch operator to locally observe 1TL-9 (Steam Seal Packing Unloader Reg Valve) (TB-594, 1G-31).
- b. Throttle open 1TL-4 (Stm Seal Reg Byp) until one of the following conditions are met:
_ . Steam seal pressure - GREATER THAN 6 PSIG. OR
- Dispatched operator reports 1 1TL-9 TL-9
- NOT CLOSED.
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/ Al5500/023 AP/1 I N55001023 7 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
,1.~~t.ors:or~~~§~f1 Starting C1dditional air ejectors or vacuum *.*.:pam!~.Ml!lr~~J::~~sl~r'~:vacuum*Wtleo pump will not restore vacuum when high RCtemperatute iss thereasorrforloss the reason for loss of vacuum, vacuum.
7 .~~~if¥i~:~jJjp~ri§ervagtidm$tati.l$:a.s
- 7. Verify condenser vacuum status as
~=-=-""'1 \f911 0 ws:
- fQUQWS;
- a. Cotldenseryacuum - STABLE QR a. Perform the folloWing:
INCREASING. t) IF additionahairremoval will ihcreasevacuum, THEN perform the following: a}*ii~l~ a} ** .* tcl1i:c;).~~ratorstoperiofm Dispatch operators to perform QUo\Ni!'lg: the following: _ i~*AIi~:8*1:m!ai~",acuuplpump($)
- Align main vacuumpump(s) for~~rvic~:;::iRTO.
for service. REFER TO J:;UpIOSUJ~~(... Enclosure 4 (Pla9in9 Main
. . gty1ai:ro V'9cuum.pumps:jgAfi§~).
Vacuum Pumps in Service).
*.AlignJcll~
Align idle s.~t() set ofCSAE jet(s) for service. REFER TO fOr.sei.R (Jfll1;1 . . . . . 0010 (Main OP/1/B/63001006 afn Vacuum). Vac;uurTJJ; _ b) o} WHEN condenser enservacuum vacuum: decreases to o less lesstha than 24 4: in. Hg;, THEN align ~ligryf1~i ... .uum mainvaquum pqmp(s) lothe cdndenser~ tn~;~.oPQ~p§* REFER TO. Enclosure !"l.8Iosl..l.rr~.*.4 4 (Placing ailJ':V9ct.O.J!tlI?(jrri~$ (fl19C i *..*.*.*.*.Maih Vacuum Pumps im~erviceJi in Service). _ 2) . GO TO Step 8,
- b. IF AT ANY TIME condenser vacuum decreases, THEN observe Note prior to Step 7 and perform Step 7.
Ensure proper opera,tion of ZP I?i§~~~~m; System. REFER TO OP/O/B/6250/011 (Vacuum Vacuum Priming System).
CNS LOSS OF CONDENSER VACUUM PAGE NO. AP/1/A15500/023 AP/1 IAl55001023 8 of 15 Revision 18 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. Dispatch'operator(s) to verify proper seal trough flows. , REFER TO Enclosure 2 IBOP I (Verification Of!S&al Flows).
- 10. Dispatch QPerat~r'fQenslJre!CFPr seal system andwaterboxes operating, prope(IY. REfER\ TO EncJpsure 3 (CFPT Stm Se.<il.I.An(:lWaterbox Vent Verification).
- 11. D~termn:le arid correct cause .011055 of vac,uurrL
- 12. Determine required notifications:
- REFER TO RP/0IAl5000/001 RP/OIAl50001001 (Classification Of Emergency)
RP/O/S/50001013 (NRC
- REFER TO RP/0/B/5000/013 Notification Requirements).
- 13. Verify Steam Seal System - IN NORMAL _ WHEN conditions permit, THEN align ALIGNMENT. steam seal system as required for current plant conditions. REFER TO OP/1/B/6300/005 (Steam Seal System).
- 14. Determine long term plant status.
RETURN TO procedure in affect.
Initiating Cues: Iinitiating e1AD-6, F/8 ,-1AD-6, FIB I-e OAC alarm C1L4455 C1 L4455 (Normal Pressurizer "Spray Spray Flow Activated) I I
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 1 of 9 DC~ Rev 22 DCE A. Purpose To ensure proper response in the event of abnormal Pressurizer pressure, assess plant conditions, and identify the appropriate steps for the following cases: Case I Pressurizer Pressure Decreasing Case II Pressurizer Pressure Increasing. B. Symptoms Case I. Pressurizer Pressure Decreasing:
- 1AD-6, E/10 "PZR PORV DISCH HI TEMP" - LIT
- 1AD-6, E/11 "PZR SAFETY DISCHARGE HI TEMP" - LIT
- 1AD-6, F/8 "PZR LO PRESS CONTROL" - LIT
- 1AD-6, Al8 "PZR HI PRESS ALERT" - LIT
- All Pzr heaters - ENERGIZED
- 1AD-6, D/11 "PZR LO PRESS PORV NC34 BLOCKED" - LIT
- 1 AD-6, D/10 "PZR LO PRESS PORV NC32 & 36 BLOCKED" - LIT 1AD-6,
- Pressurizer pressure less than 2235 PSIG and decreasing Case II. Pressurizer Pressure Increasing:
1AD-6, D/8 "PZR LO PRESS ALERT" - LIT
- 1AD-6,
- 1AD-6, C/8 "PZR HI PRESS DEV CONTROL" - LIT
- 1AD-6, B/8 "PZR HI PRESS" - LIT
- Pressurizer pressure greater than 2235 PSIG and increasing
- All Pzr heaters - ENERGIZED.
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 AP/1/Al5500/011 2 of 9 2of9 Case I DC~ Rev 22 DCS Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions BOP DOES THIS PAGE IBOP -0 Verify all R~r'iPORV$; .,CLOSED. Perform the following:
- a. Manually close Pzr PORV(s).
- b. IF any Pzr PORV cannot be closed, THEN:
_ 1) Close the affected PORV(s) isolation valve.
- 2) IF the Pzr PORV isolation valve cannot be closed, THEN perform the following:
_ a) IF in Mode 3 with CLAs isolated OR in Mode 4, THEN GO TO AP/1/A155001027 (Shutdown AP/1/Al5500/027 LOCA). _ b) Trip reactor. _ c) WHEN reactor tripped OR SII S/I setpoint reached, THEN ensure SII initiated. S/I _ EP/1/A15000/E-O d) GO TO EP/1/Al5000/E-O (Reactor Trip Or Safety Injection).
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 AP/1/Al5500/011 3 of 9 30f9 Case I Rev 22 DC:: DCl: Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED BOP DOESES THIS PAGE Control r,odsmay withdraW on decreasing NC pressure.
- 2. VerifY Pzr spray valve(s) - CLOSED. Perform the following:
- a. Manually close. *affected spray'valve(s).
b.. IF affected spray valve(s) will not close, THEN perform;the following: 1)IF AT ANY,TIME the Control> Room quperviso(determines that areactor trip is required, THEN: _ a) Trip reactor. _ b) WHEN reactor power less than 5%, THEN stop NCPumps 1A and 18. It is possible that the crew may feel a need to Itrip trip the reactor and SI or it may occur _ c) GO TO EP/1/A15000/E-O automatically if the crew is slow to respond. (Reactor Trip Or Safety Injection}.
- 2) ~1lit~~.~$~I;)!~~f()~~.~:
Select "FAIL CLOSED" for affected
- §lJ~¥~~Kl!l',~~13.A1:~tCfi:;
spray valve(s) mode select switch: _ .'* r:,1;~~~i~!'?~fil'!~~'Stl:W "1 NC-27 PZR SPRAY VLV (~llF;),E,;§IE~m~lijJj, Me>DE SELECT"
* "1 NC-29 PZR SPRAY VLV MODE SELECT".
- 3) iUi;NG~Y,'res,§Iif1&B?i'<Sf:'Staf!jle:\DR IF"NC
_ pressure is stable
" "f:)""""!SMR,.,.."."." ..,,cc OR
.~i:SJ~jJ;jg~TflEN;1C11!l{mB~stgJi)llJji increasing, THEN GO TO Step 3.
(RNO continued on next page)
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 4 of 9 Case I Rev 22 DC~ Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. (Continued) OPP DOES THIS PAGE
- 4) IF NC pressure continues to decrease, THEN:
a) IF in Modes 1 or 2, THEN: _ (1) Trip reactor. _ (2) WHEN reactor power less than 5%, THEN stop NC Pumps 1 A and 1B. 1A _ (3) EP/1/A15000/E-O GO TO EP/1/A15000/E*O (Reactor Trip or Safety Injection). _ b) Stop NC Pumps 1A and 1B. _ c) IF NC pressure continues to decrease, THEN stop additional NC pumps as required. _ d) REFER TO AP/1/A155001004 (Loss of Reactor Coolant Pump).
- 3. Verify all pzrhe~ters-ENERGIZED. _ IF Pzr pressure is less than 2220 PSIG, THEN ensure all Pzr heaters are energized.
4 .EBp$lIj~g!;~NW~Z1~{.N¥~uppIY17(:).P~~AIIjx:
- 4. Ensure 1NV-3ZA (NVSupply To Pzr Au)(
~p~aSi)~**gil.ii~:~J;J.i):;**
Spray) ~. CLpSED~
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A/55001011 AP/1/A/5500/011 50f9 Case I DC~ Rev 22 DCS Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED RO o DOES THIS PAGE PositiYf#Xf##;lQtiYi.ty.*i§~ib\)$rtedd!:1rrrlg*:ar\incr~a$E(jn**NCRr$s~t;l.re\V11JchfI11Cly**cause Positive reactivity isArjserted during an increase in NCpressLlrewhich may cause ayto(Qqiirl$ertioO* auto rod; insertion. 5*"~rifY*NCRr~~~u
- 5. VerifyNC pre$sure':' ..eJ~TAE3I,;~
STABLE.**.o..R OR _ IF pressure continues to decrease, THEN IN.CREASING~ U".cREASINGG REFER TO AP/1/A15500/010 (Reactor Coolant Leak).
- 6. WHEN NC pressure is stable, THEN:
*.§.ltabilizeut\it<:itapp(oRriat~**PQ\V$r*leyeJ.i Stabilize unit at appropriate power level.
- Adjust
.Ad justth$.ftll!tl\Vin9#;l~r$quit$drltl the following as required to mainta in.***'IT;~Y9\Vithirl***1.~
maintain T~vg within 1°F ofT-Ref:
*.IS(:)tT::.FSf#f;
* 'lTurbiOeloaq Turb.ineload Corltrbttbds
- Control rods
*** *BorbncohceritraiiOri.
Boron concentration. 7..IF:aPzrpr~S~I..f~~icballllelf{iU~gfTHEN* 7 IF a Pzrpressure channeUailed, THEN perform following:
- a. Verify "P-11 PZR SII S/I BLOCK a. Ensure compliance with Tech Spec PERMISSIVE" status light (1SI-18) (1 SI-18) in 3.3.2 (Engineered Safety Features required state for unit conditions. Actuation System (ESFAS)
Instrumentation).
- b. Notify IAE to fail following bistables for affected channel per Model WIO W/O
#00874531. Bistables shall be tripped within 72 hours:
- Pzr low pressure SII S/I
- OT Delta T 'IT
- Pzr high pressure Reactor Trip
- Pzr low pressure Reactor Trip.
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/AJ55001011 AP/1/A/5500/011 60f9 6 of9 Case I Rev 22 DC~ Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. Ensure complianc'ewith appro,p'riate Tech Specs:
12K' oW"~
II>'II+i/:J:)1e,~
.3.3.1 (Reactor
*'~J:~{d~,~S;\~**-.:q.~'Yr+~1
...~..<n;'p'£t:fist'~'4,Eilcr:Q'\\
Trip./93./.,*_~W}*::.\~~-;i~j;* System (RTS)
;l~,~ttijm,~ntalibn~
Instrumentation) i~3'~iZ;~ern',
- 3;32 ,\\,=",,9,
_}i~L>, 'irf""te#il:Ssfi@if"2I1eat (Engineered Safety Features
~"l!!*wc"~Xr",q"""""l!'~",
ti'Y6§! Pi~1j~~j@li§~~l¢'tttI~~M:~J Actuation System (ESFAS)
""'d~"mef'fti'@n\'
Ins1';' Instrumentation) "",litfl"'""x,1 _ '~';S,~~iitP~tt~;fJi!i.ij(.i1i'iiiijlj*);."W.,*~~.f~\ 3.3.3 (Post
... *z**. ". ,,~.\~,., Accident Monitoring (PAM)
~.,.~,.v~~~~9~~,~c-,/\.'i"m?,~~WJ~
It;j$~m.t?J~~t;;f)) Instrumentation) TS - 3.4.1 Condition A (based on NC I! pressure at the time) _ ;~* fa:~if)l(~I:~~~f.A1t~;( 3.3.4 (Remote Shutdqwn System) _ I _ .;!a:;:~t;:a[:{ij~Hf~~~~.'1
.3.4.1 (RCS Pressure, Temper<3ture, and I !
fttlJ,~14~JFlrtqtl~"ijllm~*~~<<<UID! Flow Departure From Nucleate Boiling
~;~R~i!AititSs>>
(ONB) Limits) I _ ,iji'~.~S\lt4QQIlS1;~HNU~!l~\i'l'lit1jjl:~~"
- 3A.4:(RCS Loops - MODES 1, and 2)
_if * ;~~_;~t~<tf~~1ii~~~1~ 3.4.5 (RCS Loops - MODE3) I _ t~~4~~~~~j)~~IID
- 3.4.6 (RCS Loops- MODE4)
II
* ':t4i~1,\O~~sm~~~~
_ i,;: 3.4.9 (Pressurizer) _ ~~
- i.~Iifl&r~gr!j~~~~f~Wtf~~ljj!~~~J 3.4.,1,O'(PressurizerSafety Valves)
_:it * ~*,II!!(~~ltt~~.~.~, 3.4.11 (PressurizerPowerOperated
- D'I~~'1:'Q'lffi:m;fLmmtlii)\4i'l!1111, Relief Valves (PORVs>>
- i~~;)~,~;nv:;~~~~x~,,~~m
- 3.4;13(RCSOp~rational Leakage).
- 9. Determine, long term plantstatus.
RETURN TO procedure in effect.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/A15000/E-O 1 of 61 Rev 36 DC~ A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 5/1SII above P-11, valid 5/1 SII below P*11 P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 2 of 61 DC~ Rev 36 DCS B. Symptoms or Entry Conditions
- 1. The following conditions are symptoms that require a Reactor Trip:
- 1 of 2 SIR channels - GREATER THAN 105 CPS WHILE BELOW P-6
- 1 of 2 I/R channels - GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10
- 2 of 4 P/R channels - GREATER THAN 25% FULL POWER WHILE BELOW P-10
- 2 of 4 P/R channels - GREATER THAN 109% FULL POWER
- 2 of 4 P/R channels - +5% FULL POWER IN 2 SECONDS
- 2 of 4 loop ~Ts - GREATER THAN THE OP~T SETPOINT
- 2 of 4 loop ~Ts - GREATER THAN THE OT~T SETPOINT
- 2 of 4 Pzr pressure channels - GREATER THAN 2385 PSIG
- 2 of 4 Pzr pressure channels - LESS THAN 1945 PSIG WHILE ABOVE P-7
- 2 of 3 Pzr level channels - GREATER THAN 92% WHILE ABOVE P-7
- 2 of 4 S/G N/R level channels on 1 of 4 S/Gs - LESS THAN LO-LO SETPOINT
- 2 of 4 NC pump buses - LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7
- 2 of 4 NC pump buses - LESS THAN 56 HERTZ WHILE ABOVE P-7
- 2 of 3 NC flow channels on 2 of 4 NC loops - LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8
- 2 of 3 NC flow channels on 1 of 4 NC loops - LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8
- 4 of 4 turbine stop valves - CLOSED WHILE ABOVE P-9
- 2 of 4 turbine stop valves EHC pressure - LESS THAN 550 PSIG WHILE ABOVE P-9
- 1 of 2 S/I trains - ACTUATED
- 2 of 2 SSPS trains - GENERAL WARNING ALARM.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 30f61 DC~ Rev 36 DeS
- 2. The following are symptoms of a Reactor Trip:
- Any Reactor Trip annunciator - LIT
- Neutron level- RAPIDLY DECREASING
- Rod bottom lights - LIT.
- 3. The following are symptoms that require a Reactor Trip and 511:
- 2 of 4 Pzr pressure channels - LESS THAN 1845 PSIG
- 2 of 3 containment pressure channels - GREATER THAN 1.2 PSIG.
- 4. The following are symptoms of a Reactor Trip and 5/1:
511:
- Any S/I Reactor Trip annunciator - LIT
- NV, NI, and ND pumps - ON
* "SAFETY INJECTION ACTUATED" status light (1SI-13) - LIT
- E/S Load Sequencer Actuated status lights (1SI-14) - LIT.
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- 1. Monitor Enclosure 1 (Foldout Page).
@ Verify Reactor Trip: Perform the following:
- All rod bottom lights - LIT a. Manually trip reactor.
- All reactor trip and bypass breakers - b. IF reactor will not trip, THEN OPEN concurrently:
- IIR amps - DECREASING.
- Implement EP!1!Al5000!F-O EP/1/A/5000/F-O (Critical Safety Function Status Trees) .
- GO TO EP!1!Al5000!FR-S.1 EP/1/A/5000/FR-S.1 (Response To Nuclear Power Generationl TWS).
Generation!AlWS). o Verify Turbine Trip: _
- All turbine stop valves - CLOSED Perform the following:
- a. Manually trip the turbine.
- b. IF turbine will not trip, THEN:
_ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously deprssing depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.
- 3) IF turbine will not runback, THEN close:
- All MSIVs
- All MSIV bypass valves.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/11A15000/E-O 5 of 61 50f61 DC~ Rev 36 DCl: I ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED -0 and 1ETB - ENERGIZED. Verify 1 ETA and Perform the following:
- a. IF 1ETA AND 1ETB are de-energized, OES THIS PAGE THEN GO TO EP/11A15000/ECA-O.O EP/1/A/5000/ECA-O.O (Loss Of All AC Power).
- b. WHEN time allows, THEN attempt to restore power to de-energized switchgear while continuing with this procedure. REFER TO AP/11A15500/007 AP/1/A/55001007 (Loss of Normal Power).
@ Verify 5/1 SII is actuated:
- a. "SAFETY INJECTION ACTUATED" a. Perform the following:
status light (1SI-13) - LIT. 1} Verify conditions requiring S/I: SII: _ .* Pzr pressure - LESS THAN 1845 PSIG OR _ .* Containment pressure - GREATER THAN 1.2 PSIG. _ 2} IF SII is required, THEN manually initiate SII. S/!. 3} IF SII is not required, THEN concurrently: _ .* Implement EP/11A15000/F-O EP/1/A/5000/F-O (Critical Safety Function Status Trees) . Trees). EP/1/A/5000/ES-O.1
- GO TO EP/11A15000/ES-O.1 (Reactor Trip Response).
E/S load sequencer actuated
- b. Both EIS b. Manually initiate SII.
S/!. status lights (1SI-14) - LIT.
- 6. Safety Injection".
Announce "Unit 1 5afety
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 6of61 60f61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. Determine required notifications:
- REFER TO RP/OIAl50001001 RP/O/A/5000/001 (Classification Of Emergency)
- REFER TO RP/O/B/50001013 RP/O/B/5000/013 (NRC Req uirements).
Notification Requirements).
- 8. Verify all Feeclwater Feedwater Isolation status Perform the following:
lights (151-5) - LIT.
- a. Manually initiate Feedwater Isolation.
I~V I b. IF proper status light indication is not obtained, THEN manually close valves. ~wl 9. Verify Phase A Containment Isolation !~ status as follows:
- a. Phase A "RESET" lights - DARK. a. Manually initiate Phase A Isolation.
- b. Monitor Light Panel Group 5 St lights - b. Manually align valves.
LIT.
~ O. Verify proper Phase B actuation as fBop ~ follows:
- a. Containment pressure - HAS a. Perform the following:
REMAINED LESS THAN 3 PSIG. This time may be used later to determine when to align ND Aux spray. _ 1) Record approximate time of reactor trip. _ 2) Verify NS pumps -INDICATING FLOW. _ 3) IF flow is not indicated, THEN manually initiate Phase B Isolation for affected train(s). (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/N5000/E-O 7of61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued)
- 4) Verify Phase B 8 Isolation has actuated as follows:
_ a) Phase B 8 Isolation "RESET" lights - DARK. _ b) IF Phase B 8 Isolation "RESET" lights are lit, THEN manually initiate Phase B 8 Isolation. c) Verify following monitor light panel lights - LIT:
- Group 1 Sp lights
- Group 5 Sp lights
- Group 5 St lights Ll11 and Ll12.
_ d) IF monitor light panel not in correct alignment, THEN ensure correct alignment. e) IF NS pump(s) did not start, THEN perform the following for the affected train(s): _ (1) Reset ECCS. _ (2) DIG load sequencer. Reset D/G _ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a B/O 8/0 SII occurs, THEN restart S/I equipment previously on. _ 5) Stop all NC pumps. _ 6) Maintain seal injection flow. _ 7) Energize H2 igniters. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/N5000/E-0 80f61 DC~ Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued)
- 8) Dispatch operator to perform the following:
_ a) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ b) Place containment H2 analyzers in service. REFER TO OP/1IA/645010 OP/1/N64501010 10 (Containment Hydrogen Control Systems). _ 9) WHEN 9 minutes has elapsed, THEN verify proper VX system operation. REFER TO Enclosure 7 (VX System Operation). _10) GO TO Step 11.
- b. IF AT ANY TIME containment pressure exceeds 3 PSIG while in this procedure, THEN perform Step 10.a.
- 11. Verify proper CA pump status as follows:
- a. Motor driven CA pumps - ON. a. Perform the following for the affected train(s):
_ 1) Reset ECCS. _ 2) Reset DIG load sequencer. _ 3) Manually start affected motor driven CApump. _ 4) IF AT ANY TIME a B/O occurs, THEN restart S/I equipment previously on.
- b. 3 S/G N/R levels - GREATER THAN b. Ensure CA Pump #1 - RUNNING.
11%.
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- 12. Verify all of the following 5/1 SII pumps - ON: Perform the following for affected train(s):
- NV pumps
- ND pumps a. Reset ECCS.
- NI pumps.
- b. Reset DIG load sequencer.
- c. Manually start affected pump.
E?P I d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on.
- 13. Verify all KC pumps - ON. Perform the following for affected train(s):
- a. Reset ECCS.
- b. Reset DIG load sequencer.
- c. Manually start affected pump.
- d. IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on.
- 14. Verify all Unit 1 and Unit 2 RN pumps - Perform the following:
ON.
- a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s).
- b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s):
_ 1) Reset ECCS. _ 2) Reset DIG load sequencer. _ 3) Manually start affected pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart SII equipment previously on.
- 15. Verify proper ventilation systems operation as follows:
- REFER TO Enclosure 2 (Ventilation System Verification).
- Notify Unit 2 operator to perform Enclosure 3 (Opposite Unit Ventilation Verification).
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- 16. Verify all 5/G 51G pressures - GREATER Perform the following:
THAN 775 P5IG.
- a. Verify the following valves - CLOSED:
=.
- All MSIVs
- All MSIV bypass valves
- All SIG PORVs.
- b. IF any valve is open, THEN:
_ 1) Manually initiate Main Steam Isolation. _ 2) IF any valve is still open, THEN manually close valve. Verify proper 5/1 flow as follows:
- a. "NV SII S/I FLOW" -INDICATING FLOW. a. Manually start NV pump(s) and align valves.
- b. NC pressure - LESS THAN 1620 PSIG. b. Perform the following:
_ 1) Ensure NO pump miniflow valve on operating NO pump(s) - OPEN. 1NI-9A and 1NV-10B do not automatically 2) IF NO pump miniflow valve(s) position and the BOP should note and manually cannot be opened, THEN perform the following for affected train(s): open these valves. CRITICAL TASK! _ a) Reset ECCS. _ b) Reset D/GDIG load sequencer. _ c) Stop NO pump. _ d) IF AT ANY TIME a B/O BIO occurs, SII equipment THEN restart S/I previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the NO ND pump. _ 3) GO TO Step 18.
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- 17. (Continued)
- INDICATING FLOW.
- c. NI pumps -INDICATING c. Manually start NI pump(s) and align ltsut'
[~__JI valves.
- d. NC pressure - LESS THAN 285 PSIG. d. Perform the following:
_1) Ensure ND pump miniflow valve on operating ND pump(s) - OPEN.
- 2) IF the ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):
_ a) Reset ECCS. _a) _ b) Reset D/G DIG load sequencer. _ c) Stop ND pump. _c) _ d) IF AT ANY TIME a B/O BIO occurs, SII equipment THEN restart S/I previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18.
- e. ND pumps --INDICATING INDICATING FLOW TO e. Manually start ND pump(s) and align C-LEGS. valves.
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- 18. S/G levels as follows:
Control 5/G
- a. Verify total CA flow - GREATER THAN a. Perform the following:
450 GPM. _ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.
- 2) IF N/R level in all S/Gs is less than 11 11%% (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:
- Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees) .
- GO TO EP/1/A/5000/FR-H.1 EP/1/A/SOOO/FR-H.1 (Response To Loss Of Secondary Heat Sink).
- b. WHEN at least one S/G N/R level is greater than 11% (29% ACC), THEN throttle feed flow to maintain all S/G N/R levels between 11 % (29% ACC) and 50%.
Verify all CA isolation valves - OPEN. _ Manually open valve(s}. Verify 5/1 S/I equipment status based on _ Manually Manua"y align equipment. monitor light panel - IN PROPER ALIGNMENT. Enclosure 4 (NC Temperature Control) shall remain in effect until subsequent procedures provide alternative NC temperature control guidance. Control NC temperature. REFER TO Enclosure 4 (NC Temperature Control).
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- 22. Verify Pzr PORV and Pzr spray valve status as follows:
- a. All Pzr PORVs - CLOSED. a. IF Pzr pressure is less than 2315 PSIG, THEN:
_ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve.
- 3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:
_ a) Energize H2 igniters. b) Dispatch operator to perform the following: _ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO o OP/1/A/6450/010 P/1/Al6450/0 10 (Containment Hydrogen Control Systems). (RNO continued on next page)
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- 22. (Continued) c) IF both the following conditions exist,
- Containment pressure -
GREATER THAN 1 PSIG
- Containment pressure - HAS REMAINED REMAI NED LESS THAN 3PSIG 3 PSIG
_ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently: EP/11A15000/F-0
- Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).
EP/11A15000/E-1
- GO TO EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant).
fBbP1d. I _ _ . Normal Pzr spray valves - CLOSED. b. IF Pzr pressure is less than 2260 PSIG, THEN: _ 1) Manually close spray valve(s).
- 2) IF spray valve(s) cannot be closed, THEN:
_ a) Stop NC pumps 1A 1A and 1B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.
- c. At least one Pzr PORV isolation valve - c. IF power is available, THEN open one OPEN. Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV.
- 23. Verify NC subcooling based on core exit IF any NV OR NI pump is on, THEN:
TICs - GREATER THAN O°F.
- a. Ensure all NC pumps - OFF.
- b. Maintain seal injection flow.
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- 24. Verify main steamlines are intact as IF pressure in any S/G is decreasing in follows: an uncontrolled manner OR any S/G is depressurized, THEN perform the
~~ '------' _
- All S/G pressures - STABLE OR following:
INCREASING
- a. IF both the following conditions exist,
- ALL S/Gs - PRESSURIZED.
- Containment pressure - GREATER THAN 1 PSIG
- Containment pressure - HAS REMAINED LESS THAN 3 PSIG
_ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start).
- b. Concurrently:
EP/1/A15000/F-O (Critical _ . Implement EP/1/A/5000/F-O Safety Function Status Trees). _ . GO TO EP/1/A15000/E-2 EP/1/A/5000/E-2 (Faulted Steam Generator Isolation). Verify S/G tubes are intact as follows: IF any EMF trip 1 light is lit OR any S/G level is increasing in an uncontrolled
- Verify the following EMF trip 1 lights- manner, THEN concurrently:
DARK: EP/1/A15000/F-O (Critical _ . Implement EP/1/A/5000/F-O
- 1EMF-33 (Condenser Air Ejector Safety Function Status Trees).
Exhaust) EP/1/A/5000/E-3 (Steam _ . GO TO EP/1/A15000/E-3
- 1EMF-26 (Steam line 1A)
(Steamline Generator Tube Rupture).
- 1EMF-27 (Steam (Steamline line 1B)
- 1EMF-28 (Steamline 1C)
- 1EMF-29 (Steamline (Steam line 1D).
- All S/G levels - STABLE OR INCREASING IN A CONTROLLED MANNER.
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- 26. Verify NC System is intact as follows:
- a. Verify the following NC pump thermal a. Perform the following:
barrier alarms - DARK:
- 1) Ensure the valve for the affected
- 1AD-6, E/1, "NCP A THERMAL NC pump(s) - CLOSED:
BARRIER KC OUTLET HI/LOHI/La FLOW"
- 1KC-394A (NC Pump 1A Therm Bar Otlt) atIt)
- 1AD-6, E/2, "NCP B THERMAL BARRIER KC OUTLET HI/LOHI/La
- 1KC-364B (NC Pump 1B Therm FLOW" Bar Otlt) atIt)
- 1AD-6, E/3, El3, "NCP C THERMAL
- 1KC-345A (NC Pump 1C Therm BARRIER KC OUTLET HilLaHIILO Bar Otlt)
FLOW"
- 1KC-413B (NC Pump 1D Therm
- 1AD-6, E/4, "NCP D THERMAL Bar Otlt).
BARRIER KC OUTLET HI/LOHI/La FLOW". 2) IF the valve for the affected NC pump will not close, THEN perform the following: _ a) Trip all NC pumps. (RNO continued on next page) (RNa
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- 26. (Continued) b) Perform the following:
_ (1) Dispatch operator with radio to standby at 1KC-425A (NC Pumps Ret Cant Isol) (AB-588, Hdr Cont GG-52, Rm 419) (Ladder needed). _ (2) Close 1KC-425A (NC Pumps Ret Hdr ContCant Isol) from Control Room. _ (3) IF 1KC-425A (NC Pumps Cant Isol) will not Ret Hdr Cont close completely from Control Room, THEN have operator locally close 1KC-425A (NC Pumps Ret Cant Isol) (AB-588, Hdr Cont GG-52, Rm 419). _ (4) WHEN 1KC-425A (NC Pumps Ret Hdr ContCant Isol) has been closed, THEN close 1KC-424B (NC Pumps Ret Hdr ContCant Isol). _ (5) WHEN 1KC-425A (NC Pumps Ret Hdr ContCant Isol) is closed, THEN notify the dispatched operator to return. (6) Close the following valves:
- 1KC-338B (NC Pumps Cant Isol)
Sup Hdr Cont
- 1KC-430A (Rx Bldg Drn Cant Isol)
Hdr Cont
- 1KC-429B (Rx Bldg Drn Iso I).
Cant Isol). Hdr Cont
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- 26. (Continued)
- b. Verify NC System is intact as follows: b. Perform the following:
_ .* Containment pressure - LESS THAN _ 1) Energize H2 igniters. 1 PSIG.
- 2) Dispatch operator to perform the
_ .* IF normal off-site power is available, following: THEN verify containment pressure less than 0.3 PSIG. _ a) Secure all ice condenser air handling units. REFER TO
- Containment high range EMFs - Enclosure 13 (Securing All Ice LESS THAN 3 RlHR: Condenser Air Handling Units).
_ . 1EMF-53A (Containment Trn A) _ b) Place containment H2 analyzers _ . 1EMF-53B (Containment Trn B). in service. REFER TO OP/1IAl645010 OP/1/A/64501010 10 (Containment
- Containment EMF trip 1 lights- Hydrogen Control Systems).
DARK:
- 3) IF both the following conditions
- 1EMF-38 (Containment exist, Particulate)
- 1EMF-39 (Containment Gas) pressure--
- Containment pressure GREATER THAN 1 PSIG
- Containment sump level - STABLE.
- Containment pressure - HAS REMAINED LESS THAN 3 PSIG
_ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start).
- 4) Concurrently:
EP/1/A/5000/F-0
- Implement EP/11A15000/F-0 (Critical Safety Function Status Trees).
EP/1/A/5000/E-1 (Loss
- GO TO EP/11A15000/E-1 Of Reactor Or Secondary Coolant).
- 27. Verify 5/1 termination criteria as follows:
- a. NC subcooling based on core exit TICs a. GO TO Step 28.
- GREATER THAN O°F.
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- 27. (Continued)
- b. Verify secondary heat sink as follows: b. GO TO Step 28.
S/G - N/R level in at least one SIG
- NIR GREATER THAN 11 %
11% OR S/Gs - GREATER
- Total feed flow to SIGs THAN 450 GPM.
- c. NC pressure - STABLE OR c. GO TO Step 28.
INCREASING. level-- GREATER THAN 11
- d. Pzr level %.
11%. d. Perform the following: _ 1) IF NC pressure is increasing AND normal Pzr spray is available, THEN attempt to stabilize NC pressure using normal Pzr spray. _ 2) RETURN TO Step 27.a. S/I - RESET:
- e. Ensure SII
_ 1) ECCS. 1) Perform the following: _ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ b) Concurrently implement Enclosure 8 (ECCS Master Reset) while continuing in this procedure. _ D/G load sequencers.
- 2) DIG 2) Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA)
(AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB)
(AB-560, BB-46, Rm 372). (AB-56Q, _ 3) IF AT ANY TIME a BIO B/O occurs, THEN restart SIIS/I equipment previously on.
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- 27. (Continued)
- f. Ensure only one NV pump - ON.
_ g. Verify NC pressure - STABLE OR g. Perform the following: INCREASING. _ 1) Implement EP/11A15000/F-0 EP/1/A/5000/F-0 (Critical Safety Function Status Trees). _ 2) GO TO EP/1/A/5000/ES-1.2 EP/11A15000/ES-1.2 (Post LOCA Cooldown And Depressurization ).
- h. Verify VI pressure - GREATER THAN h. In subsequent steps, control room 50 PSIG. control is lost for the following valves and local operation will be required:
- 1NV-294 (NV Pmps A&B Disch Flow Ctrl)
- 1NV-309 (Seal Water Injection Flow).
- i. Isolate NV S/I flowpath as follows:
- 1) Verify the following valves - OPEN: 1) Perform the following:
- 1NV-203A (NV Pumps A&B _ a) Open affected valve(s).
Recirc Isol) _ b) IF 1NV-203A AND 1NV-202B
- 1NV-202B (NV Pmps A&B Recirc are open, THEN GO TO Isol). Step 27.i.2.
c) Dispatch operator to open affected valve( valve(s): s):
- 1NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)
- 1NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed).
_ d) Close 1NV-309 (Seal Water Injection Flow). (RNO continued on next page)
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- 27. (Continued) e) IF control of 1NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:
_ (1) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ (2) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps. f) Open the following valves:
- 1NV-312A (Chrg Line Cont Isol)
- 1NV-314B (Chrg Line Cont Isol).
g) IF 1NV-312AOR NV-312A OR 1NV-314B cannot be opened, THEN dispatch operator to open the affected valve(s). Refer to the following enclosure(s) for the affected valve(s):
- Enclosure 10 (Locally Open 1NV-312A)
- Enclosure 12 (Locally Open 1 NV-314B).
_ h) Do not continue in this procedure until 1NV-312A and 1NV-314B are open. _ i) IF NC pressure is greater than 1950 PSIG, THEN throttle 1NV-309 or 1NV-311 to 50% open. (RNO continued on next page)
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- 27. (Continued)
_ j) Open 1NV-294 (NV Pmps A&B Disch Flow Ctrl). k) IF control of 1NV-294 is lost from the control room, THEN: _ (1) Place the controller for 1NV-294 in the 100% demand position. _ (2) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) to control charging flow as required in subsequent steps. I) Close the following valves:
- 1NI-9A (NV Pmp C/l Inj Isol)
- 1NI-10B (NV Pmp C/l Inj Isol).
m) IF 1NI-9A OR 1NI-10B cannot be closed, THEN dispatch operator to close the affected valve(s). Refer to the following enclosure(s) for the affected valve(s):
- Enclosure 9 (locally Close 1NI-9A)
- Enclosure 11 (locally Close 1NI-10B).
1NI-1 OB). n) Throttle charging and seal injection to maintain the following:
- Charging line flow between 60 GPM and 180 GPM
- NC pump seal injection flow.
(RNO continued on next page)
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- 27. (Continued)
_ 0) WHEN 1NV-203A AND 1NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ p) GO TO Step 27.k.
- 2) Close the following valves: 2) Dispatch operator to close the affected valve(s). Refer to the
- 1NI-9A (NV Pmp C/l Inj Isol) following enclosure(s) for the
- 1NI-10B 1NI-1 OB (NV Pmp C/l Inj Isol). affected valve(s):
- Enclosure 9 (locally Close 1NI-9A)
- Enclosure 11 (locally Close 1NI-10B).
1 NI-10B).
- j. Establish charging as follows:
_ 1) Throttle 1NV-294 (NV Pmps A&B 1) Perform the following: Disch Flow Ctrl) for 32 GPM charging line flow. _ a) Place the controller for 1NV-294 in the 100% demand position. _ b) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) for 32 GPM charging line flow. _ c) Throttle 1NV-295 to control charging flow as required in subsequent steps. _ 2) Close 1NV-309 (Seal Water 2) Dispatch operator with radio to Injection Flow). perform the following: _ a) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (ladder needed). _ b) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 24 of 61 DC~ Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- 3) Open the following valves: 3) Dispatch operator to open the affected valve(s). Refer to the
- 1NV-312A (Chrg Line Cont Isol) following enclosure(s) for the
- 1NV-314B (Chrg Line Cont Isol). valve( s):
affected valve(s): _ .* Enclosure 10 (Locally Open 1NV-312A) _ .* Enclosure 12 (Locally Open 1NV-314B). _ 4) Verify 1NV-309 - ABLE TO BE _ 4) GO TO Step 27.j.6. OPERATED FROM THE CONTROL ROOM. _ 5) Place 1NV-309 in auto.
- 6) Perform the following:
- Maintain charging flow less than 180 GPM.
- Maintain 32 GPM seal water flow.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 25 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- k. Control charging as follows:
_ 1) Control charging flow to maintain Pzr level stable. _ 2) Verify Pzr level - STABLE OR 2) IF Pzr level is decreasing. THEN: INCREASING. a) Open the following valves: _ .* 1 NI-9A (NV Pmp C/l Inj Isol) 1NI-9A _ . 1NI-10B (NV Pmp C/l Inj Isol). b) Close the following valves:
- 1NV-312A (Chrg Line Cont Isol)
- 1NV-314B (Chrg Line Cont Isol).
_ c) Implement EP/1/A/5000/F-O EP/11A15000/F-O (Critical Safety Function Status Trees). _ EP/1/A/5000/ES-1.2 d) GO TO EP/11A15000/ES-1.2 (Post lOCA Cooldown And Depressurization ). I. Ensure the following containment isolation signals - RESET:
- Phase A
- Phase B.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/N5000/E-0 26 of 61 260f61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- m. Establish VI to containment as follows: m. Perform the following:
- Ensure 1 VI-77B (VI Cont Isol)-
1VI-77B Isol) - 1) Align N2 to the Pzr PORVs by 1} OPEN. opening the following valves:
- Verify VI pressure - GREATER THAN 1 NI-438A (Emer N2 From CLA A
- 1NI-438A 85 PSIG. To 1NC-34A)
- 1NI-439B (Emer N2 From CLA B To 1NC-32B).
_ 2) IF VI pressure is less than 85 PSIG. 2} PSIG, THEN dispatch operator to ensure proper VI compressor operation.
- n. Concurrently:
EP/1/A/5000/F-0 (Critical
- Implement EP/1/N5000/F-0 Safety Function Status Trees).
EP/1/A/5000/ES-1.1 (Safety
- Monitor EP/1/N5000/ES-1.1 Termination), Enclosure 1 Injection Termination).
(Foldout Page) _ .* GO TO EPI1IN5000/ES-1.1 EP/1/A/5000/ES-1.1 (Safety Termination), Step 12. Injection Termination).
- 28. Implement EP/11A1S000/F-O EP/1/A/5000/F-O (Critical Safety Function Status Trees).
- 29. Control S/G levels as follows:
- a. Verify N/R level in all S/Gs - GREATER a. Maintain total feed flow greater than THAN 11%. 450 GPM until at least one S/G N/R level is greater than 11 %.
- b. Throttle feed flow to maintain all S/G b. IF N/R level in any S/G continues to N/R levels between 11%11 % and 50%. manner, increase in an uncontrolled manner.
EP/1/A/5000/E-3 THEN GO TO EP/1/N5000/E-3 (Steam Generator Tube Rupture).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1 IA/SOOO/E-O EP/1/N5000/E-0 27 of 61 DC~ Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 30. Verify secondary radiation is normal as follows:
- a. Ensure the following signals - RESET:
_ 1) Phase A Containment Isolations _ 2) CA System valve control _ 3) KC NC NI NM St signals.
- b. Align all S/Gs for chemistry sampling.
- c. Perform at least one of the following:
_ . Notify Chemistry to sample all S/Gs for activity. OR _ . Notify RP to frisk all cation columns for activity. lights--
- d. Verify the following EMF trip 1 lights d. GO TO EP/1/N5000/E-3 EP/1/A/SOOO/E-3 (Steam DARK: Generator Tube Rupture).
- 1EMF-33 (Condenser Air Ejector Exhaust)
- 1EMF-26 (Steamline 1A)
- 1EMF-27 (Steamline 18)
- 1EMF-28 (Steamline 1C)
- 1EMF-29 (Steamline 1D).
- e. WHEN activity results are reported, e. Perform the following:
THEN verify all S/Gs indicate no activity. _ 1) Notify station management to evaluate S/G(s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, EP/1/A/SOOO/E-3 THEN GO TO EP/1/N5000/E-3 (Steam Generator Tube Rupture).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-O EP/1/A/5000/E-O 28 of 61 28of61 DC~ Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 31. Verify auxiliary building radiation is Evaluate cause of abnormal conditions normal as follows: as follows:
- EMF-41 (Aux Bldg Ventilation) trip 1 light a. MonitorOAC Monitor OAC EMF alarms, OAC VA
-DARK Graphic, and area monitor EMFs to determine location of activity.
- All area monitor EMF trip 1 lights - DARK
- b. Dispatch operator to locate potential leak.
- c. IF cause of alarm is LOCA outside containment, THEN GO TO EP/1/A/SOOO/ECA-1.2 (LOCA Outside EP/1/A/5000/ECA-1.2 Containment).
- 32. Verify PRT conditions are normal as Evaluate following possible causes of follows: abnormal PRT conditions:
- PRT pressure - LESS THAN 8 PSIG
- Pzr safety temperatures
- Pzr safety relief flow indicated level-- LESS THAN 89%
- PRT level
- Pzr PORVs PzrPORVs
- Rx head vents
- PRT temperature - LESS THAN 130°F.
- NC pump seal return header relief
- Letdown orifice header relief.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 29 of 61 DC~ Rev 36 DCS ACTIONIEXPECTED ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 33. Ensure SII - RESET:
- a. ECCS. a. IF either reactor trip breaker is closed, THEN:
_ 1) Ensure reactor trip breakers - OPEN. _ 2) WHEN trip breakers open, THEN reset ECCS.
- b. D/G DIG load sequencers. b. Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB) (AB-560, Panel1DGLSB)
BB-46, Rm 372).
- c. IF AT ANY TIME a B/O occurs, THEN restart S/I SII equipment previously on.
- 34. Ensure the following containment isolation signals - RESET:
- Phase A
- Phase B.
- 35. Establish VI to containment as follows: Perform the following:
- Ensure 1VI-77B (VI Cont Isol) - OPEN. a. Align N2 to the Pzr PORVs by opening the following valves:
- Verify VI pressure - GREATER THAN 85 PSIG.
- 1NI-438A (Emer N2 From CLA A To 1NC-34A)
- 1NI-439B (Emer N2 From CLA B To 1NC-32B).
- b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 30 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 36. Verify criteria to stop operating NO pumps as follows:
- a. NC pressure - GREATER THAN a. GO TO EP/1/A/5000/E-1 (Loss Of 285 PSIG. Reactor Or Secondary Coolant).
- b. NC pressure - STABLE OR b. GO TO Step 37.
INCREASING.
- c. At least one ND pump - ON. c. GO TO Step 36.e.
- d. Ensure all ND pump(s) with suction aligned to FWST - STOPPED.
- e. IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart ND pumps.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 31 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 37. Verify conditions to stop operating DIGs as follows:
- a. At least one DIG - ON. a. GO TO Step 38.
- b. Verify 1ETA is energized by offsite b. Perform the following:
power as follows: _1}1} Attempt to restore offsite power to
* "DIG 1A BKR TO ETA" - OPEN affected switchgear. REFER TO AP/1/A/55001007 (Loss of Normal
- 11ETA-ETA - ENERGIZED. Power).
_ 2} GO TO Step 37.d.
- c. Dispatch operator to stop 1A DIG and place in standby readiness. REFER TO OP/1/A/63501002 (Diesel Generator Operation).
- d. Verify 1ETB is energized by offsite d. Perform the following:
power as follows: _1}1} Attempt to restore offsite power to
* "DIG 1B BKR TO ETB" - OPEN affected switchgear. REFER TO AP/1/A/55001007 (Loss of Normal
- 1ETB - ENERGIZED. Power).
_ 2} GO TO Step 38.
- e. Dispatch operator to stop 1B DIG and place in standby readiness. REFER TO OP/1/A/63501002 (Diesel Generator Operation).
- 38. RETURN TO Step 21.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/N5000/E-0 32 of 61 Enclosure 1 - Page 1 of 1 DC~ Rev 36 DCS Foldout Page
- 1. IF any S/G(s) suspected ruptured, THEN perform the following:
- WHEN the following conditions met:
- Total CA flow - GREATER THAN 450 GPM AND
- All intact S/G(s) N/R level- GREATER THAN 11%(29% ACC)
THEN throttle feed flow to ruptured S/G(s) to maintain ruptured S/G(s) N/R level between 11 %(29% ACC) and 39%.
- 2. NC Pump Trip Criteria:
- IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:
- At least one NVor NV or NI pump - ON
- NC subcooling based on core exit TICs - LESS THAN OR EQUAL TO O°F.
- 3. CA Suction Source Switchover Criteria:
AP/1/A/55001006 (Loss of S/G
- IF either of the following annunciators are lit, THEN REFER TO AP/1/N55001006 Feedwater):
- 1AD-5, H/4 "CACST LO LEVEL" OR
- 1AD-8, B/1 "UST LO LEVEL".
- 4. Position Criteria for 1NV-202B and 1NV-203A (NV Pumps A&B Recirc IsOI): Isol):
- IF NC pressure is less than 1500 PSIG AND NV S/I flowpath is aligned, THEN close 1NV-202B and 1NV-203A.
- IF NC pressure is greater than 2000 PSIG, THEN open 1NV-202B and 1NV-203A.
- 5. Cold Leg Recirc Switchover Criterion:
- IF FWST level decreases to 37% (1AD-9, 0/8 D/8 "FWST 2/4 LO LEVEL" lit), AND an S/I has occurred, THEN GO TO EP/1/A/5000/ES-1.3 EP/1/N5000/ES-1.3 (Transfer To Cold Leg Recirculation).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 33 of 61 Enclosure 2 - Page 1 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Verify proper VCNC operation as BOP OP DOES THIS ENCLOSURE follows:
- a. Verify one train of the following a. Perform the following:
equipment is in operation: _ 1) Shift operating VCIYC trains. 1}
- YC chiller REFER TO Enclosure 6 (Shifting
- CR AHU-1 Operating VCIYC Train).
- CRAAHU-1
- CRAPFT-1.
eRA PFT-1. 2) 2} IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:
- OP/O/A/6450/011 (Control Room Area Ventilation/Chilled Water System)
- EM/O/A/5200/001 (Troubleshooting Cause For Improper Operation of VCIYC System).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O 34 of 61 Enclosure 2 - Page 2 of 7 DC~ Rev 36 DeS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. (Continued)
- b. Verify the following alarms - DARK: b. IF chlorine odor is detected in the Control Room, THEN perform the
- 1AD-18, N8 "UNIT 1 INTAKE HI following based on the status of given CHLORINE 1A" alarms:
- 1AD-18, B/88/8 "UNIT 1 INTAKE HI 1) IF detectors on both unit intakes are CHLORINE 18" 1B" in alarm, THEN:
- 1AD-18, 0/8 "UNIT 2 INTAKE HI a) Ensure the following VC intake CHLORINE 2A" dampers - CLOSED:
- 1AD-18, E/8 "UNIT 2 INTAKE HI
- 1VC-5B (CRA Filt 1VC-58 Inlet)
CHLORINE 2B".28".
- 1VC-6A (CRA Filt Inlet)
- 2VC-5B (CRA Filt 2VC-58 Inlet)
- 2VC-6A (CRA Filt Inlet).
_ b) GO TO Step 1.d.
- 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN:
a) Ensure the following VC dampers - CLOSED: _ . 1VC-58 1VC-5B (CRA Filt Inlet) _ . 1VC-6A (CRA Filt Inlet). dampers-- b) Ensure the following dampers OPEN: _ 2VC-5B (CRA Filt Inlet)
- 2VC-58
_
- 2VC-6A (CRA Filt Inlet).
_ c) GO TO Step 1.d. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 35 of 61 Enclosure 2 - Page 3 of 7 Rev 36 DC~ Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. (Continued)
- 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN:
a) Ensure the following VC dampers - CLOSED: _
- 2VC-5B (CRA Filt Inlet)
_
- 2VC-6A (CRA Filt Inlet).
b) Ensure the following dampers-dampers - OPEN: _ . 1VC-5B (CRA Filt Inlet) _ . 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d.
- c. Ensure the following VC dampers -
OPEN:
- 1VC-5B (CRA Filt Inlet)
- 1VC-6A (CRA Filt Inlet)
- 2VC-5B (CRA Filt Inlet)
- 2VC-6A (CRA Filt Inlet).
- d. Repeat Step 1 of this enclosure until notified by station management as follows:
_
- At least once every 8 hours OR
_
- Any time VC/yC related annunciators on 1AD-18 actuate.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 EP/1/Al5000/E-0 36 of 61 Enclosure 2 - Page 4 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. Ensure proper VA System operation as follows:
- Ensure the following fans - OFF:
- ABUXF 1A
- ABUXF 1B.
- Ensure VA System filter is in service as follows:
- 1ABF-D-12 & 19 (VA Filter A Bypass Dampers) - CLOSED
- 1ABF-D-5 & 20 (VA Filter B Bypass Dampers) - CLOSED.
- Ensure the following fans - ON:
- ABFXF-1A
- ABFXF 1B.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/Al5000/E-0 37 of 61 Enclosure 2 - Page 5 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. Verify proper VE System operation as follows:
- a. VE fans - ON. a. Manually start fan(s).
- b. Annulus pressure - BETWEEN b. Perform the following:
-1.BIN.
-1.4 IN. WC AND -1.8 IN. WC.
- 1) IF annulus pressure is more positive than -1.4 in. WC, THEN:
a) Verify flow indicated on the following indications:
* "VE 1A1A FLOW TO STACK"
* "VE 1B FLOW TO STACK".
b) IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6": 1AVS-D-2 (VE A Trn Recirc
- 1AVS-D-2 Damp) (AB-603, JJ-51 , Rm 500) - CLOSED
- 1AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-52, Rm 500) - CLOSED
- 1 1AVS-D-3 AVS-D-3 (VE A T Trn rn Exh Damp) (AB-603, JJ-52, Rm 500) - OPEN 1AVS-D-B (VE B Trn
- 1AVS-D-8 T rn Exh Damp) (AB-603, HH-52, Rm 500) - OPEN.
_ c) Consult plant engineering staff _c) and notify IAE/Maintenance to troubleshoot and repair. REFER EM/1/A/52001002 TO EM/1/Al5200/002 (Troubleshooting Cause For VE Hillo Pressure). System Hi/lo _ d) GO TO Step 3.c. _d) (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 EP/11A15000/E-0 38 of 61 38of61 Enclosure 2 - Page 6 of 7 DC~ Rev 36 DeS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued)
- 2) IF annulus pressure is more negative than -1.8 in. WC, THEN:
_ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours, ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/A152001002 EM/11A152001002 (Troubleshooting Cause For VE Hi/Lo Pressure). System Hi/lo
- c. Repeat Step 3.b every 30 minutes until notified by station management.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 39 of 61 Enclosure 2 - Page 7 of 7 Rev 36 DC~ Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. Record time ventilation systems are verified on following table:
TIME SYSTEM INITIALS (VC, VE) (VC.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 EP/1/A/5000/E-0 40 of 61 Enclosure 3 - Page 1 of 1 DC~ Rev 36 DCS Opposite Unit Ventilation Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Ensure proper Unit 2 VA System operation as follows:
- Ensure the following fans - OFF:
- ABUXF-2A
- ABUXF-2B.
- Ensure VA System filter is in service as follows:
- 2ABF-D-12 & & 19 (VA Filter A Bypass Dampers) - CLOSED
- 2ABF-D-5 && 20 (VA Filter B Bypass Dampers) - CLOSED.
- Ensure the following fans - ON:
- ABFXF-2A
- ABFXF-2B.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/A15000/E-O 41 of 61 Enclosure 4 - Page 1 of 4 DCt Rev 36 DC!: NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Verify at least one NC pump - ON. Perform the following:
- a. Use NC T-Colds to determine NC RO DOES THIS ENCLOSURE temperature as required in subsequent steps.
- b. GO TO Step 4.
- 2. T-Avg to determine NC Use NC T-Avg temperature as required in subsequent steps.
- 3. IF AT ANY TIME NC pumps are tripped, THEN use NC T T-Colds
-Colds to determine NC temperature as required in subsequent steps.
- 4. Verify one of the following: GO TO Step 7.
- NC temperature - STABLE AT LESS 55rF.
THAN OR EQUAL TO 557°F. OR 55rF.
- NC temperature - TRENDING TO 557°F.
- 5. Continue to monitor NC temperature.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 42of61 42 of 61 Enclosure 4 - Page 2 of 4 Rev 36 DCSDC~ NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. Do not continue in this enclosure until one of the following occurs:
- NC temperature - GREATER THAN 55rF AND INCREASING IN AN UNCONTROLLED MANNER.
OR
- NC temperature - GREATER THAN 55rF AND STABLE.
OR
- NC temperature - LESS THAN 55rF AND DECREASING IN AN UNCONTROLLED MANNER.
- 7. Verify NC temperature - LESS THAN Perform the following:
557°F AND DECREASING.
- a. IF NC temperature is greater than 55rF AND increasing, THEN stabilize NC temperature at 55rF as follows:
- 1) IF steam dumps are available, THEN use steam dumps.
- 2) IF steam dumps are not available, THEN use S/G PO RVs.
PORVs.
- b. IF the following conditions exist:
- NC temperature is greater than 55rF and stable
- Time and manpower is available, THEN stabilize NC temperature at 55rF as follows:
1)) IF steam dumps are available, 1 THEN use steam dumps.
- 2) IF steam dumps are not available, THEN use S/G PORVs.
- c. GO TO Step 9.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 43 of 61 Enclosure 4 - Page 3 of 4 Rev 36 DC~ NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. cooldown Attempt to stop the NC cool down as follows:
- a. Ensure all steam dumps - CLOSED.
- b. Ensure all S/G PORVs - CLOSED. b. IF any S/G PORV cannot be closed, THEN close its isolation valve.
- c. Ensure S/G blowdown is isolated.
- d. Close the following valves:
- 1SM-77A (S/G 1A Otlt Hdr Bldwn CN)
- 1SM-76B (S/G 1B Otlt Hdr Bldwn CN)
- 1SM-75A (S/G 1C Otlt Hdr Bldwn CN)
- 1SM-74B (S/G 10 Otlt Hdr Bldwn CN).
- e. Depress and hold "SN BEFORE SEAT DRN" "CLOSE" pushbutton (1 MC-3) to close the following valves:
- 1SM-41 (Stop Vlv #1 Before Seat Drn)
- 11SM-44 SM-44 (Stop Vlv #2 Before Seat Drn)
- 11SM-43 SM-43 (Stop Vlv #3 Before Seat Drn) 1SM-42 (Stop Vlv #4 Before Seat
- 1SM-42 Drn).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 EP/1/A/5000/E-O 44 of 61 Enclosure 4 - Page 4 of 4 Rev 36 DCS DCE NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. (Continued)
- f. Verify NC cooldown - STOPPED. f. IF cooldown continues, THEN throttle feed flow as follows:
- 1) IF S/G N/R level is less than 11 %
ACe) in all S/G's, THEN (29% ACC) throttle feed flow to achieve the following:
- Minimize cooldown
- Maintain total feed flow greater than 450 GPM.
- 2) WHEN N/R level is greater than 11 % (29% ACC) in at least one S/G, THEN throttle feed flow further to achieve the following:
- Minimize cooldown
- Maintain at least one S/G N/R level greater than 11 %
(29% ACC).
- 3) IF cooldown continues, THEN close the following valves:
- All MSIVs
- All MSIV bypass valves.
- 9. Continue to perform the actions of this enclosure as required to ensure one of the following:
- NC temperature - STABLE AT LESS THAN OR EQUAL TO 55rF.
OR
- NC temperature - TRENDING TO 55rF.
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 1 of 110 DC~ Rev 34 OCt A. Purpose This procedure provides actions to terminate leakage of reactor coolant into the secondary system following a steam generator tube rupture. B. Symptoms or Entry Conditions This procedure is entered from:
- a. EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection), Step 25, when condenser air ejector radiation, S/G blowdown radiation or steamline radiation is abnormal.
- b. EP/*1/A/5000/E-0 (Reactor Trip Or Safety Injection), Step 30, EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 5, EP/1/A/5000/E-2 (Faulted Steam Generator Isolation), Step 10, EP/1/A/5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 7, and EP/1/A/5000/FR-H.3 (Response To Steam Generator High Level), Step 8, when secondary radiation is abnormal.
- c. EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection), Step 29, EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 4, EP/1/A/5000/ES-1.2 (Post LOCA Cooldown And Depressurization), Step 10, EP/1/A/5000/ES-3.1 (Post - SGTR Cooldown Using Backfill),
Step 6, EP/1/A/5000/ES-3.2 (Post - SGTR Cooldown Using Blowdown), Step 6, EP/1/A/5000/ES-3.3 (Post - SGTR Cooldown Using Steam Dump), Step 8, EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired), Step 12, and EP/1/A/5000/ECA-3.2 (SGTR With Loss Of Reactor Coolant-Saturated Recovery Desired), Step 6, when a S/G N/R level increases in an uncontrolled manner.
- d. Any foldout page that has E-3 transition criteria whenever any S/G level increases in an uncontrolled manner or any S/G has abnormal radiation.
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 EP/1/AJ5000/E-3 2 of 110 Rev 34 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. C. Operator Actions
- 1. Monitor Enclosure 1 (Foldout Page).
- 2. Identify ruptured S/G(s) as follows: Perform the following:
IRO I ** S/G level - INCREASING IN AN a. WHEN ruptured S/G(s) is identified, UNCONTROLLED MANNER. THEN perform Steps 3 through 9. OR b. GO TO Step 10. _ . RP determines ruptured S/G by frisking the cation columns in the CT lab. OR F1 *
- The following EMF trip 1 lights - LIT:
- 1EMF-26 (Steamline 1A)
Crew may ask ROP to frisk CAT ICrew
- 1EMF-27 (Steamline 1B)
COLUMNS to get confirmation of ICOLUMNS
- 1EMF-28 (Steamline 1C) leak. This takes about 5 minutes
!leak.
- 1EMF-29 (Steamline 1D).
OR
- IF S/G Sampling is required to identify ruptured S/G(s), THEN:
- a. Ensure the following signals - I RESET:
_ 1) Phase A Containment Isolations. I _ 2) CA System valve control. _ 3) KC NC NI NM St signals.
- b. Align all S/Gs for Chemistry sampling.
- c. Notify Chemistry to sample all S/Gs for activity.
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A15000/E-3 EP/1/A/5000/E-3 3 of 110 Rev 34 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. Verify at least one intact S/G - Maintain one S/G available for NC AVAILABLE FOR NC SYSTEM System cooldown in subsequent steps.
fRol COOLDOWN. !I I
- 4. Isolate steam flow from ruptured S/G(s}
r::::""'.::::---'1 as follows:
- a. Verify all ruptured S/G(s) PORV- a. WHEN ruptured S/G(s) pressure is less CLOSED. than 1090 PSIG, THEN perform the following:
_ 1) Ensure ruptured S/G(s) PORV-CLOSED. The PORV block valve may already have been isolated _ 2) IF ruptured S/G(s) PORV will not close, THEN manually close If not it will be closed here. ruptured S/G(s) PORV isolation CRITICAL TASK! valve. _ 3) IF ruptured S/G(s) PORV isolation valve will not manually close, THEN dispatch operator to close ruptured S/G(s) PORV isolation valve.
CNS GENERATOR STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 EP/1/A/5000/E-3 4 of 110 40f110 OC~ Rev 34 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
- b. Verify S/G(s) 1B and 1C -INTACT. b. Perform the following:
_ 1) IF both motor driven CA pumps available, THEN close the "CAPT TRIP TN CTRL". _ 2) IF CA Pump #1 is the only source of feedwater, THEN maintain steam flow to the CAPT from at least one S/G.
- 3) IF S/G 1B is ruptured, THEN:
_ a) Dispatch two operators to unlock and close 11SA-1 (1B SA-1 (1 B S/G Main Steam to CAPT Maintenance (OH-624, FF-53, Rm 572) Isol) (DH-624, (Breakaway lock installed). _ b) IF 1SA-1 cannot be closed, THEN dispatch two operators to unlock and close 1SA-3 (1B S/G Main Steam to CAPT Stop
~O-53, Rm Check) (AB-551, DO-53, 217) (Breakaway lock installed).
- 4) IF S/G 1C is ruptured, THEN:
_ a) Dispatch two operators to unlock and close 11SA-4 (1C SA-4 (1 C S/G Main Steam to CAPT Maintenance (OH-624, FF-53, Rm 572) Isol) (DH-624, (Breakaway lock installed). _ b) IF 1SA-4 cannot be closed, THEN dispatch two operators to {1C S/G unlock and close 1SA-6 (1C Main Steam to CAPT Stop Check) (AB-551, DO-53, Rm 217) (Breakaway lock installed) (Ladder needed). _ 5) WHEN the ruptured S/G steam supply to CA Pump #1 is isolated, THEN open the "CAPT TRIP TN CTRL".
CNS GENERATOR STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 EP/1/A/5000/E-3 5 of 110 50f110 Rev 34 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
- c. Isolate blowdown and steam drain on all ruptured S/G(s) as follows:
- S/G 1A:
_ 1) Close 1 SM-77A (S/G 1 1SM-77A 1A A Otlt Hdr _ 1) Dispatch operator to close Bldwn CN). SM-77A (S/G 1 1SM-77A 1 1A A Otlt Hdr Bldwn CN) (DH-583, FF-GG, 43-44, Rm 591).
- 2) Verify the following blowdown isolation valves - CLOSED:
_ a) 1BB-56A (S/G 1A Bldwn Cont _ a) Manually close valve. Isollnsd). _ 1BB-148B (S/G 1A Bldwn b) 1BB-148B b) Perform the following: Cont Isol Byp). _ (1) Manually close valve. (2) IF valve will not close AND 1BB-56A is open, THEN perform the following:
- 1. Ensure "S/G A BLDWN FLOW CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
- 1BB-148B(S/G1A 1BB-148B (S/G 1A Bldwn Cont Isol Byp) (DH-580, EE-FF, 44-45, Rm 591) 1BB-81 (1AS/G
_ .* 1BB-81 (1A S/G Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591).
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- 4. (Continued)
_ 1BB-57B (S/G 1A Bldwn Cont c) 1BB-57B c) Perform the following: I", I IsoIOtsd). _ (1) Manually close valve. (2) IF valve will not close AND 1BB-56A is open, THEN perform the following:
- 1. Ensure "S/G A BLDWN FLOW BLOWN CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
1BB-57B (S/G 1A
- 1BB-57B Bldwn Cont Isol Otsd) (DH-580, EE-FF, 44-45, Rm 591)
- 1BB-81 (1A S/G Blowdown Penetration Valve Test Isol) (DH-583, EE-FF, 44, Rm 591 ).
591).
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- 4. (Continued)
- S/G 1B:
_ 1) Close 1SM-76B (S/G 1B Otlt Hdr _ 1) Dispatch operator to close Bldwn CN). 1SM-76B (S/G 1B Otlt Hdr Bldwn CN) (DH-583, FF-53, Rm 572).
- 2) Verify the following blowdown isolation valves - CLOSED:
_ 1BB-19A(S/G a) 1BB-19A (S/G 1B Bldwn Cont _ a) Manually close valve. Isollnsd). _ 1BB-150B (S/G 1B b) 1BB-150B 1B Bldwn b) Perform the following: Cont Isol Byp). _ (1) Manually close valve. (2) IF valve will not close 1BB-19A is open, AND 1BB-19A THEN perform the following:
- 1. Ensure "S/G B BLDWN FLOW CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
- 1BB-150B (S/G 1B Bldwn Cont Isol Byp) (DH-580, FF, 52-53, Rm 572)
_ .* 1BB-83 1BB-83 (1B (1 B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572).
CNS GENERATOR STEAM GENERA TOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 EP/1/Al5000/E-3 8 of 110 80f110 DC~ Rev 34 DCE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
_ c) 1BB-21 B (S/G 1B Bldwn Cont c} c) Perform the following: c} IsoIOtsd). _ (1) Manually close valve. (2) IF valve will not close 1BB-19A is open, AND 1BB-19A THEN perform the following:
- 1. Ensure "S/G B BLDWN FLOW CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
- 1BB-21B (S/G 1B Bldwn Cont Isol Otsd) (DH-580, FF, 52-53, Rm 572)
_ .* 1BB-83 1 BB-83 (1B S/G Blowdown Penetration Valve Test Isol) (DH-580, FF-53, Rm 572).
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EPI1IA15000/E-3 EP/1/A/5000/E-3 9 of 110 Rev 34 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
- S/G 1C:
_ 1) Close 1SM-75A (S/G 1C Otlt Hdr _ 1) Dispatch operator to close Bldwn CN). 1SM-75A (S/G 1C Otlt Hdr Bldwn CN) (DH-580, GG, 52-53, Rm 572).
- 2) Verify the following blowdown isolation valves - CLOSED:
_ a) 1BB-60A (S/G 1C Bldwn Cont _ a) Manually close valve. Isollnsd). _ 1BB-149B (S/G 1C Bldwn b) 1BB-149B b) Perform the following: Cont Isol Byp). _ (1) Manually close valve. (2) IF valve will not close 1BB-60A is open, AND 1BB-60A THEN perform the following:
- 1. Ensure "S/G C BLDWN FLOW CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
- 1BB-149B (S/G 1C Bldwn Cont Isol Byp) (DH-578, FF-GG, 52, Rm 572)
(1 C S/G 1BB-82 (1C
- 1BB-82 Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572).
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/AJ5000/E-3 EP/1/A/5000/E-3 10 of 110 DC~ Rev 34 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
_ c) 1BB-61 B (S/G 1 1BB-61B C Bldwn Cont 1C c) Perform the following: IsoIOtsd). _ (1) Manually close valve. (2) IF valve will not close AND 1BB-60A is open, THEN perform the following:
- 1. Ensure "S/G C BLDWN FLOW BLOWN CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
1BB-61B (S/G 1C
- 1BB-61B(S/G1C Bldwn Cont Isol Otsd) (DH-578, FF-GG, 52, Rm 572)
- 1BB-82 (1C S/G Blowdown Penetration Valve Test Isol) (DH-583, FF-53, Rm 572).
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 EP/1/A/5000/E-3 110f110 DC~ Rev 34 DC!: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
- S/G 1D:
_ 1) Close 1SM-74B (S/G 1D Otlt Hdr _ 1) Dispatch operator to close Bldwn CN). 1SM-74B (S/G 1D 1SM-74B 1D Otlt Hdr Bldwn CN) (DH-583, FF-GG, 44-45, Rm 591).
- 2) Verify the following blowdown isolation valves - CLOSED:
_ a) 1BB-8A (S/G 1D Bldwn Cont _ a) Manually close valve. Isollnsd). _ b) 1BB-147B (S/G 1D Bldwn b) Perform the following: Cont Isol Byp). _ (1) Manually close valve. (2) IF valve will not close AND 1BB-8A is open, THEN perform the following:
- 1. Ensure "S/G D BLDWN FLOW CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
1BB-147B(S/G1D
- 1BB-147B (S/G 1D Bldwn Cont Isol Byp) (DH-582, EE-FF, 44, Rm 591) 1BB-80 (1D
- 1BB-80 (1 D S/G Blowdown Penetration Valve Test Isol)
(DH-583,EE-FF, 44, Rm 591).
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/11A15000/E-3 EP/1/A/5000/E-3 12 of 110 Rev 34 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. (Continued)
_ 1BB-1 OB (S/G 1D c) 1BB-10B 1D Bldwn Cont c) Perform the following: IsoIOtsd). _ (1) Manually close valve. (2) IF valve will not close AND 1BB-8A is open, THEN perform the following:
- 1. Ensure "S/G D BLDWN FLOW CTRL" - CLOSED.
- 2. Dispatch operators to ensure the following valves - CLOSED:
- 1BB-10B (S/G 1D Bldwn Cont Isol Otsd) (DH-582, EE-FF, 44, Rm 591)
- 1BB-80 (1 D S/G 1BB-80 (1D Blowdown Penetration Valve Test Isol)
(DH-583,EE-FF, 44, Rm 591).
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- 5. Close the following valves on all Perform the following:
EJ RO ruptured S/G(s):
- MSIV
- a. Close the following valves on remaining S/Gs:
- MSIV bypass valve.
=.
- MSIV
_ . MSIV bypass valve.
- b. Place steam dump control in manual and lower controller output to 0%.
- c. Place "STEAM DUMP SELECT" switch in pressure mode.
- d. Transfer turbine steam seal supply to AS as follows:
_ 1) Open 1TL-8 (Aux (Au x Stm To Stm Seal Reg). _ 2) Close 1TL-2 (Main Stm To Stm Seal Reg).
- e. Ensure the following turbine SN before seat drain valves - CLOSED:
- 1SM-41 (Stop Vlv #1 Before Seat Dm)
Drn)
- 1 SM-44 (Stop Vlv #2 Before Seat 1SM-44 Dm)
Drn)
- 1SM-43 (Stop V1vVlv #3 Before Seat Dm)
Drn)
- 1SM-42 (Stop Vlv #4 Before Seat Dm).
Drn).
- f. Close 1AS-1 (SM To AS Inlet).
- g. Ensure the following valves - CLOSED:
- 1HM-1 (MSRH 1A&1B SSRH Stm Source)
- 1HM-2 (MSRH 1C&1D SSRH Stm Source).
(RNO continued on next page)
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- 5. (Continued)
- h. Dispatch operator to isolate steam flow from all ruptured S/G(s). REFER TO Enclosure 2 (Locally Isolating Steam Flow From Ruptured S/G(s)).
S/G(s>>.
- i. WHEN cooldown is initiated in subsequent steps, THEN use intact S/G(s) PORV for steam dump.
_ j. IF at least one intact S/G cannot be isolated from all ruptured S/G(s), THEN EP/1/AI5000/ECA-3.1 (SGTR GO TO EP/1/A15000/ECA-3.1 With Loss Of Reactor Coolant - Subcooled Recovery Desired).
- 6. Control ruptured S/G(s)
S/G(s} level as follows:
- a. Verify ruptured S/G(s) N/R level - a. Perform the following:
GREATER THAN 11% 11 % (29% ACC). _ 1) IF any ruptured S/G is also faulted, THEN do not establish feed flow to the ruptured S/G unless needed for NC System cooldown.
- 2) IF any ruptured S/G(s) is not faulted OR is required for cooldown, THEN:
_ a) Establish and maintain feed flow to affected S/G(s). _ b) WHEN affected S/G(s) N/R level greater than 11 % (29% ACC), ACe), THEN perform Steps 6.b and 6.c. _ 3) GO TO Step 7.
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- 6. (Continued)
Isolate feed flow to all ruptured S/G(s) ISOP I b. IBOP as follows:
- S/G 1A:
_ 1) Close 1CA-62A (CA Pmp A Disch 1) Perform the following: To S/G 1A Isol). _ a) Close 1CA-60 (CA Pump 1A Flow To S/G 1A). _ b) Dispatch operator with 14" valve wrench to close 1 CA-62A (CA Pmp A Disch 1CA-62A To S/G 1A Isol) (DH-587, DD-EE, 44-45, Rm 591). _ 2) Close 1 1CA-66B CA-66B (CA Pmp 1 Disch 2) Perform the following: To S/G 1A Isol). _ 1CA-64 (CA Pump #1 a) Close 1CA-64 Flow To S/G 1A). _ b) Dispatch operator with 14" valve wrench to close 1CA-66B 1 CA-66B (CA Pmp 1 Disch To S/G 1A Isol) (DH-584, DD-EE, 44-45, Rm 591) .
- S/G 1B:
_ 1) Close 1CA-58A (CA Pmp A Disch 1) Perform the following: To S/G 1B Isol). _ a) Close 1CA-56 (CA Pump 1A Flow To S/G 1B). _ b) Dispatch operator with 14" valve wrench to close 1CA-58A 1CA-58A (CA Pmp A Disch To S/G 1B Isol) (DH-586, DD-EE, 52-53, Rm 572).
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- 6. (Continued)
_ 2) Close 1CA-54B 1CA-548 (CA Pmp 1 Disch 2) Perform the following: To S/G 18 1B Isol). _ a) Close 1CA-52 1CA-52 (CA Pump #1 Flow To S/G 18). 1B). _ b) Dispatch operator with 14" valve wrench to close 1CA-54B (CA Pmp 1 Disch To 1CA-548 1B Isol) (DH-584, DD-EE, S/G 18 52-53, Rm 572) .
- S/G 1C:
_ 1CA-46B
- 1) Close 1CA-468 (CA Pmp 8B Disch 1) Perform the following:
To S/G 1C Isol). _ a) Close 1CA-44 (CA Pump 18 1B Flow To S/G 1C). _ b) Dispatch operator with 14" valve wrench to close CA-46B (CA Pmp 8 1CA-468 B Disch To S/G 1C Isol) (DH-586, DD, DO, 53-54, Rm 572). _ 1CA-50A
- 2) Close 1CA-50A (CA Pmp 1 Disch 2) Perform the following:
To S/G 1C Isol). _ a) Close 1 CA-48 (CA Pump #1 1CA-48 Flow To S/G 1C). _ b) Dispatch operator with 14" valve wrench to close 1CA-50A (CA Pmp 1 Disch To S/G 1C Isol) (DH-584, EE-53, Rm 572) .
- S/G 1D:
10: _ 1) Close 1CA-428 CA-42B (CA Pmp 8B Disch 1) Perform the following: To S/G 1 D Isol). 10 _ a) Close 1CA-40 (CA Pump 1B 18 Flow To S/G 1D). _ b) Dispatch operator with 14" valve wrench to close 1CA-42B 1CA-428 (CA Pmp 8 B Disch To S/G 10 1D Isol) (DH-586, DD-EE, 43-44, Rm 591).
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- 6. (Continued)
_ 2) Close 1CA-38A (CA Pmp 1 Disch 2) Perform the following: To S/G 1D Isol). _ a) Close 1 1CA-36 CA-36 (CA Pump #1 Flow To S/G 1D). _ b) Dispatch operator with 14" valve wrench to close 1CA-38A (CA Pmp 1 Disch To S/G 1D Isol) (DH-584, DD-EE, 43-44, Rm 591).
- c. IF AT ANY TIME ruptured S/G(s) N/R 11 % (29% ACC),
level is less than 11% ACe), THEN perform Step 6.
- 7. Verify at least one NC pump - ON.
CAUTION NC T-Cold indication in the ruptured loop may cause an invalid Integrity Status Tree condition. _ Disregard NC T-Cold indication in the ruptured loop, until directed by this EP or until this EP is exited. BOP 8. WHEN "P-11 PZR SII S/I BLOCK PERMISSIVE" status light (1SI-18) (1 SI-18) is lit, THEN:
- a. Depress ECCS steam pressure "BLOCK" push buttons.
- b. Verify main steam isolation blocked status lights (1SI-13) - LIT.
- c. Maintain NC pressure less than 1955 PSIG using one of the following:
_ . Pzr spray OR
- Pzr PORV.
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- NC pump trip criteria based on NC subcooling does not apply after starting a controlled cooldown.
cooldown .
- After the low steamline pressure main steam isolation signal is blocked Main Steam Isolation will occur if the high steam pressure rate setpoint is exceeded.
- 9. Initiate NC System cooldown cool down as follows:
- a. Verify all ruptured S/G(s) pressure - a. GO TO EP/11A15000/ECA-3.1 EP/1/A/5000/ECA-3.1 (SGTR GREATER THAN 320 PSIG. With Loss Of Reactor Coolant -
Subcooled Recovery Desired).
- b. Determine required core exit temperature from the table below:
LOWEST RUPTURED SIGS/G PRESSURE CORE EXIT EX IT TICs (PSIG) (OF) (0 F) EQUAL TO OR GREATER 532 (512 ACC) THAN 1200 llOO - 1199 1100 ll99 520 (501 ACC) 1000 - 1099 507 (489 ACC) 900 - 999 494 (476 ACC) 800 - 899 479 (461 ACC) 700 - 799 462 (445 ACC) 600 - 699 442 (426 ACC) 500 - 599 420 (405 ACC) 400 - 499 392 (379 ACC) 320 - 399 364 (352 ACC)
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- 9. (Continued)
- c. Ensure ruptured S/G(s) isolated as IRO I follows:
, I 1) Verify the following valves on all 1) Ensure the following valves on at ruptured S/G(s) - CLOSED: least one intact S/G - CLOSED:
- MSIV
- MSIV
- MSIV bypass valves. valve..
- MSIV bypass valve
_ 2) Verify S/G PORVon ruptured 2) IF ruptured S/G(s) pressure is less S/G(s) - CLOSED OR ISOLATED. than 1090 PSIG, THEN perform the following: _ a) Ensure S/G PORVPORVon on ruptured S/G(s) - CLOSED OR ISOLATED. b) IF S/G PORV on ruptured S/G(s) not closed or isolated, THEN: _ (1) Ensure operator dispatched to close ruptured S/G(s) PORV isolation valve. (2) Do not continue until affected S/G PORV(s):
- Isolated OR
- Determined to be unisolable.
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- 9. (Continued)
- 3) IF S/G 1B OR 1C ruptured, THEN 3) Perform the following:
verify one of the following CAPT steam supply valves - CLOSED: _ a) Ensure operator dispatched to isolate CAPT steam supply from
* "CAPT TRIP TN CTRL" the ruptured S/G.
OR b) Do not continue until affected CAPT steam supply:
- Manual isolation valve on the affected S/G.
- Isolated OR
- Determined to be unisolable.
- d. Verify the condenser is available as d. GO TO Step 9.g RNO.
follows:
* "C-9 COND AVAILABLE FOR STM DUMP" status light (1SI-18) - LIT
- MSIVon intact S/G(s) - OPEN.
- e. Verify steam dumps - IN PRESSURE e. Place steam dumps in pressure mode MODE. as follows:
_ 1) Place "STM DUMP CTRL" MIA station in manual. _ 2) Manually adjust "STM DUMP CTRL" MIA station output to match "% STM DUMP DEMAND" (1SMP5211). _ 3) WHEN output on the "STM DUMP CTRL" MIA station is equal to the
"% STM DUMP DEMAND" (1SMP5211),
(1 SMP5211), THEN place the steam dumps in pressure mode.
- f. WHEN "P-12 LO-LO TAVG" status light (1SI-18) is lit, THEN place the steam dump interlock bypass switches in "BYP INTLK."
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- 9. (Continued)
_ g. Dump steam to condenser from intact g. Perform the following: S/G(s) at maximum rate while attempting to avoid a Main Steam _ 1) Dump steam from all intact S/G(s) at Isolation. maximum rate with S/G PORV(s). _ 2) IF any intact S/G PORV cannot be opened from the control room, THEN dispatch operator(s) to dump steam at maximum rate from intact S/G(s) PORV. REFER TO Enclosure 3 (Local Operation of S/G PORVs).
- 3) IF operator(s) were dispatched to S/G PORV(s), THEN:
_ a) Obtain sound powered phone from storage box on rear wall of control room. _ b) Connect sound powered phone to jack on 1MC-11. _ c) Monitor sound powered phone for communication from the Doghouse(s).
- 4) IF no intact S/G is available for NC System cooldown, THEN contact station management to determine which of the following to perform:
- Use faulted S/G OR EP/1/A/5000/ECA-3.1
- GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired).
_ 5) GO TO Step 9.h.
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- 9. (Continued)
- h. Verify main steam isolation blocked h. Perform the following:
status lights (1SI-13) - LIT.
- 1) Depressurize NC System to less than 1955 PSIG using one of the following:
_ . Pzr spray OR
- Pzr PORV.
- 2) WHEN "P-11 PZR SII BLOCK PERMISSIVE" status light (1SI-18) is lit, THEN:
_ a) Depress ECCS steam pressure "BLOCK" push buttons. _ b) Verify main steam isolation blocked status lights (1SI-13)- (1SI-13) - LIT. _ 3) Maintain NC pressure less than 1955 PSIG.
- i. WHEN core exit TICs T/Cs are less than required temperature, THEN stabilize core exit TICs T/Cs less than required L-.J temperature.
CNS STEAM GENERATOR TUBE RUPTURE PAGE NO. EP/1/A/5000/E-3 EP/1/N5000/E-3 23 of 110 Rev 34 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. Control intact S/G levels as follows:
- a. Verify N/R level in all intact S/Gs - a. Perform the following:
GREATER THAN 11% 11 % (29% ACC). _ 1) Maintain total feed flow greater than 450 GPM to intact S/Gs until at least one intact S/G N/R level greater than 11 % (29% ACC).
- 2) IF total feed flow greater than 450 GPM cannot be established, THEN contact station management for guidance to establish feed flow from one of the following alternate sources:
** CF CF
** CM CM
_
- Alternate low pressure water source.
- b. Throttle feed flow to maintain all intact b. IF N/R level in any intact S/G continues S/G N/R levels between 16% to increase in an uncontrolled manner, (29% ACC) andand 50%. THEN:
_ 1) Stop NC system cooldown. _ 2) RETURN TO Step 1.
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- 11. Verify Pzr PORV and isolation valve status as follows:
- a. Power to all Pzr PORV isolation valves - a. Dispatch operator to restore power to AVAILABLE. valve(s):
affected Pzr PORV isolation valve( s):
- 1EMXD-F02C (PORV Isol Motor (1 NC31 B))
B>> (AB-560, BB-50, Rm 372)
- 1EMXC-F03C (Pressurizer Power Operated Relief Isol. Valve 1NC33A)
(AB-577, BB-50, Rm 496)
- 1EMXD-F05A (PORV Isol Motor NC35B>> (AB-560, BB-50, Rm 372).
(1 NC35B>>
- b. All Pzr PORVs - CLOSED. b. IF Pzr pressure is less than 2315 PSIG, THEN:
_ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve. _ 3) IF Pzr PORV cannot be closed OR isolated, THEN GO TO EP/11A15000/ECA-3.1 EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired).
- c. At least one Pzr PORV isolation valve - c. Open one Pzr PORV isolation valve OPEN. unless it was closed to isolate an open Pzr PORV.
PORV opens
- d. IF AT ANY TIME a Pzr PORVopens due to high pressure while in this procedure, THEN perform the following:
_ WH EN Pzr pressure decreases to
- 1) WHEN less than 2315 PSIG, THEN ensure the valve closes or is isolated.
_ 2) IF Pzr PORV cannot be closed OR isolated, THEN GO TO EP/11A15000/ECA-3.1 EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired).
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- 12. Ensure 5/1 SII *- RESET:
I op I - aa.. ECCS. ECCS. a. Perform the following: t..,..".,.~..J _ 1} IF either reactor trip breaker is 1) closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2} Concurrently implement Enclosure 2) 12 (ECCS Master Reset) while continuing in this procedure.
- b. DIG D/G load sequencers.
seq uencers. b. Dispatch operator to open the affected sequencer(s} control power breaker: sequencer(s)
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB) (AB-560, BB-46, Rm 372).
- c. IF AT ANY TIME a B/O occurs, THEN restart SII S/I equipment previously on.
- 13. Ensure the following containment sop I signals - RESET:
isolation signals*
- Phase A
- Phase B.
- 14. Establish VI to containment as follows: Perform the following:
II 1-.
,. . . .s. . ,.o-=p. . .
IBOP
- Ensure 1VI-77B (VI (VI Cont Isol) - OPEN. a. Align N2 to the Pzr PORVs by opening the following valves:
- Verify VI pressure - GREATER THAN 85 PSIG. 1NI-438A (Emer N2 From CLA A To
- 1NI-438A 1NC-34A) 1NI-439B (Emer N2 From CLA B To
- 1NI-439B 1NC-32B).
- b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.
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- 15. Verify criteria to stop operating NO FPl pumps as follows:
- a. At least one ND pump - ON. a. GO TO Step 15.e.
ND pump(s}
- b. Verify NO pump(s) suction - ALIGNED b. GO TO Step 16.
TO FWST.
- c. NC pressure - GREATER THAN c. GO TO Step 16.
285 PSIG.
- d. Stop NOND pump(s}
pump(s) with suction aligned to FWST.
- e. IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart NO ND pumps.
- 16. Verify ruptured S/G(s) -IDENTIFIED. _ Do not continue in this procedure until ruptured S/G(s) identified.
- 17. cooldown should be Verify if NC System cooldownshould stopped:
T/Cs - LESS THAN
- a. Verify core exit TICs a. Do not continue in this procedure until REQUIRED TEMPERATURE. T/Cs are less than required core exit TICs temperature.
- b. Stabilize core exit TICs - LESS THAN Crew will hold here until they meet rCrew REQUIRED TEMPERATURE. temperature Item perature requirements.
require ments.
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- 18. S/G{s) pressure is under Verify ruptured S/G(s)
IFlI RO operator control as follows:
- i
- a. All ruptured S/G(s) pressure -
S/G{s) pressure- a. Perform the following: STABLE OR INCREASING. _ 1) Ensure ruptured S/G{s) _1) S/G(s) isolated. REFER TO Steps 3 through 6. _ 2) IF ruptured S/G(s) S/G{s) pressure is less than intact S/G(s) S/G{s) used for cooldown, THEN GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired).
- 3) IF AT ANY TIME D/P DIP between ruptured S/G{s)
S/G(s) and intact S/G{s) S/G(s) used for cooldown is less than 250 PSIG, THEN:
- Maintain total NC System cooldown less than 100°F in an hour
- Dump steam from intact S/Gs to maintain intact S/G pressures 250 PSIG below ruptured S/G{s)
S/G(s) pressure. _ 4) IF intact S/G(s) S/G{s) used for cooldown can not be maintained at least 250 PSIG below the pressure of the S/G(s), THEN GO TO ruptured S/G{s), EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired). _ 5) GO TO Step 19.
- b. IF AT ANY TIME ruptured S/G(s)
S/G(s} pressure is decreasing while in this procedure, THEN perform Step 18. rIRO II
- 19.
RO Verify NC subcooling based on core exit TICs - GREATER THAN 20*F. TICs* 20°F. _ IF NC subcooling cannot be promptly restored to greater than 20°F, THEN GO TO EP/1/A15000/ECA*3.1 EP/1/A/5000/ECA-3.1 (SGTR With I I f Loss Of Reactor Coolant Recovery Desired). Coolant*- Subcooled
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- 20. Depressurize NC System using PZR
~nDl Spray as follows: IBOP!
- a. Verify normal Pzr spray flow - a. GO TO Step 21.
! J AVAILABLE.
- b. Verify Pzr level - LESS THAN 76% b. Observe Caution prior to Step 23 and (73% ACC) GO TO Step 23.
- c. Depressurize NC System with maximum available spray.
- d. IF AT ANY TIME during this step one of This is a judgement call aboLltl IThiS about the following conditions exists:
going II,gOing to step 21. I _
- Spray valves are not effective in I reducing NC pressure I i
I OR _ . Ruptured S/G(s) NR level is approaching 83% (82% ACC).
'-----------------'. I
_ THEN GO TO Step 21.
- e. Do not continue until at least oneofthe one of the following conditions satisfied:
_ .* NC subcooling based on core exit
- T/Cs - LESS THAN OaF TICs O°F OR
- Pzr level-level - GREATER THAN 76%
(73% ACC) OR
- Both of the following:
_ . NC pressure - LESS THAN RUPTURED S/G(s) PRESSURE AND
- Pzr level- GREATER THAN 11%
(20% ACC).
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- 20. (Continued)
- f. Close the following valve(
valve(s): s): _ 1) Pzr spray valves. 1) IF spray valve(s) will not close, THEN: _ a) Stop NC pumps 1A and 1B. 1B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required. _ 2) 1NV-37A NV-37A (NV Supply To Pzr Aux 2) Ensure one of the following valves - Spray). CLOSED: _ . 1NV-312A (Chrg Line Cont Isol) OR
- 1NV-314B (Chrg Line Cont Isol).
_ g. Observe Caution prior to Step 23 and GO TO Step 23.
- 21. Depressurize NC System using Pzr PORVas PORV as follows:
- a. Verify at least one Pzr PORV - a. Establish NV aux spray as follows:
AVAilABLE. AVAILABLE. _ 1) Ensure at least one NI pump - ON. _ 2) Ensure at least one NV pump - ON.
- 3) Ensure the following NV pump miniflow valves - OPEN:
- 1NV-203A (NV Pumps A&B Recirc Isol)
- 1NV-202B (NV Pmps A&B Recirc Isol).
- 4) Close the following valves:
_ . 1NI-9A (NV Pmp C/l Inj Isol) _ . 1NI-10B (NV Pmp C/l Inj Isol). (RNO continued on next page)
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- 21. (Continued)
_ 5) Manually throttle 1NV-294 (NV Pmps A&B Disch Flow Ctrl) for 32 GPM charging line flow. _ 6) Manually close 1NV-309 (Seal Water Injection Flow).
- 7) Open the following valves:
1501) Cant Isol)
- 1NV-312A (Chrg Line Cont
- 1NV-314B 1NV-314B (Chrg Line Cont 1501).
Cant Isol). _ 8) Place 1NV-309 in auto.
- 9) Ensure the following valves -
CLOSED:
- 1NC-27 (pzr Spray Ctrl Frm Loop A)
- 1NC-29 (pzr Spray Ctrl Frm Loop B)
- 1NV-39A (NV Supply To Loop D 1501)
Isol)
- 1NV-32B (NV Supply To Loop A 1501).
Isol). _ 10) Maintain charging flow less than 180 GPM. _ 11) Throttle 1NV-37A NV-37A (NV Supply To Pzr Aux Spray) and charging flow as required. _ 12) RETURN TO Step 20.e.
- b. Verify Pzr level - LESS THAN 76% b. Observe Caution prior to Step 23 and (73% ACC). GO TO Step 23.
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- 21. (Continued)
- c. Open one Pzr PORV. c. Perform the following:
- 1) Align N2 to the Pzr PORVs by opening the following valves:
- 1NI-438A (Emer N2 From CLA A To 1NC-34A)
- 1NI-439B (Emer N2 From CLA B To 1NC-32B).
_ 2) Open one Pzr PORV.
- d. Do not continue until at least one of the following conditions satisfied:
_ . NC subcooling based on core exit TICs - LESS THAN OaF OR
- Pzr level-level - GREATER THAN 76%
(73% ACC) OR
- Both of the following:
_ . NC pressure - LESS THAN RUPTURED S/G(s) PRESSURE AND
- Pzr level - GREATER THAN 11 %
(20% ACC).
- e. Close Pzr PORV. e. Close Pzr PORV isolation valve.
- f. Close Pzr spray valve(s). f. IF spray valve(s) will not close, THEN:
_ 1) Stop NC pumps 1Aand1A and 1B. 1B. _ 2) IF NC pressure continues to decrease, THEN stop third NC pump as required.
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- 22. Verify NC pressure - INCREASING. Perform the following:
- a. Close Pzr PORV isolation valve.
- b. IF pressure continues to decrease, THEN perform the following:
- 1) Monitor the following conditions for indication of leakage from the Pzr PORV:
- PRT pressure
- Pzr Relief Valve Temp.
_ 2) GO TO EP/1/A15000/ECA-3.1 EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired). CAUTION 511 SII must be terminated when termination criteria are satisfied to prevent S/G(s}. overfilling the ruptured S/G(s).
- 23. SII termination criteria as follows:
Verify 5/1
- a. NC subcooling based on core exit TICsT/Cs a. GO TO EP/1/A15000/ECA-3.1 EP/1/A/5000/ECA-3.1 (SGTR
- GREATER THAN O°F. OaF. With Loss Of Reactor Coolant -
Subcooled Recovery Desired).
- b. Verify secondary heat sink as follows: b. GO TO EP/1/A15000/ECA-3.1 EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -
- N/R level in at least one intact S/G - Subcooled Recovery Desired).
GREATER THAN 11 11%% (29% ACC) OR _
- Total feed flow available to S/G(s)-
GREATER THAN 450 GPM.
- c. NC pressure - STABLE OR c. GO TO EP/1/A15000/ECA-3.1 EP/1/A/5000/ECA-3.1 (SGTR INCREASING. With Loss Of Reactor Coolant -
Subcooled Recovery Desired). level - GREATER THAN 11%
- d. Pzr level- 11 % d. RETURN TO Step 7.
(20% ACC).
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- 24. 5/1 pumps as follows:
Stop 511 Isopl a. Stop NI pumps. a. Perform the following: L~-
- 1) IF NI Pump 1A failed to trip, THEN perform the following:
a) Ensure the following valves - OPEN:
- 1NI-115A(NI Pump 1A Miniflow 1501)
- 1 NI-147B (NI Pump Miniflow 1NI-147B Hdr To FWST 1501).
b) WHEN miniflow path aligned, THEN ensure the following valves - CLOSED:
- 1NI-121A (NI Pump 1A To H-Legs B&C)
- 1NI-118A(NI Pump 1AC-Leg Inj 1501).
_ c) Dispatch operator to locally trip 1ETA#11 (1A NI Pump Motor) (AB-577, AA-49, Rm 496). (RNO continued on next page)
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- 24. (Continued)
- 2) IF NI Pump 1B failed to trip, THEN perform the following:
a) Ensure the following valves-valves - OPEN:
- 1NI-144A(NI 1NI-144A (NI Pump 1 1B B
Miniflow Isol)
- 1NI-147B (NI Pump Miniflow Hdr To FWST Isol).
b) WHEN miniflow path aligned, THEN ensure the following valves - CLOSED: 1NI-150B
- 1 NI-150B (NI Pump 1B C-Leg Inj Isol)
- 1NI-152B (NI Pump 1B To H-Legs A&D).
_ c) Dispatch operator to locally trip 1ETB#11 (1B NI Pump Motor) AA-49 , Rm 372). (AB-560, AA-49,
- b. Ensure only one NV pump - ON.
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- 25. Isolate NV 5/1 511 flowpath as follows:
- a. Verify the following valves - OPEN: a. IF NV pump suctions are aligned for Cold Leg Recirc, THEN perform the
- 1NV-252A (NV Pumps Suct Suet From following:
FWST) _ 1) GO TO Enclosure 10 (Establish
- 1NV-253B (NV Pumps Suct From Charging With NV Miniflow FWST). Isolated).
_ 2) GO TO Step 27.
- b. Ensure the following valves - OPEN: b. Perform the following:
1 NV-203A (NV Pumps A&B Recirc
- 1NV-203A 1) Dispatch operator to open affected Isol) 1501) valve(s):
- 1NV-202B (NV Pmps A&B Recirc
- 1NV-203A (NV Pumps A&B Isol). Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)
- 1NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed).
_ 2) GO TO Enclosure 10 (Establish Charging With NV Miniflow Isolated). _ 3) WHEN 1NV-203A AND 1NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ 4) GO TO Step 27.
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- 25. (Continued)
- c. Close the following valves: c. Perform the following:
- 1NI-9A (NV Pmp C/l Inj Isol) 1) Dispatch operator to close the
- 1NI-10B (NV Pmp C/l Inj Isol). affected valve(s). REFER TO the following enclosure(s) for the affected valve(s):
- Enclosure 13 (locally Close 1NI-9A)
'SCENARIO SCENARIO MAY BE TERMINATED
- Enclosure 15 (locally HERER Close 1 1NI-10B).
NI-10B).
- 2) IF NC pump seal cooling is established from KC flow to thermal barrier, THEN perform the following:
_ a) Ensure all NC pumps - OFF. _ b) Stop NV Pumps. _ c) WHEN 1NI-9AAND 1NI-9A AND 1NI-10B are closed, THEN restore NV pump to service. REFER TO Enclosure 9 (NV Pump Restart). d) Ensure the following valves - OPEN: 1NI-115A(NI
- 1NI-115A (NI Pump 1A Miniflow Isol)
- 1NI-144A(NI Pump 1B Miniflow Isol)
- 1 NI-147B (NI Pump Miniflow 1NI-147B Hdr To FWST Isol).
(RNO continued on next page)
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- 25. (Continued) e) Close one of the following valves:
_ . 1NI-118A(NI Pump 1AC-Leg Inj Isol) OR _. 1 1NI-150B NI-150B (NI Pump 11B B C-Leg Inj Isol). _ f) Start NI Pump associated with the closed NI Pump C-Leg injection valve. _ g) Manually align associated NI Pump C-Ieg injection valve as required to maintain Pzr level greater than 11 % (20% ACC). _ h) GO TO Step 32. _ 3) WHEN 1NI-9AAND 1NI-10B are closed, THEN perform Steps 26 through 31. _ 4) GO TO Step 32. NOTE VI pressure less than 50 PSIG will prevent operation of 1NV-294 and 1NV-309 from the control room.
- 26. Establish charging as follows:
- a. Verify VI pressure - GREATER THAN a. GO TO Step 26.b RNO.
50 PSIG.
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- 26. (Continued)
- b. Throttle 1NV-294 (NV Pmps A&B Disch b. Perform the following:
Flow Ctrl) for 32 GPM charging line flow. _ 1) Place the controller for 1NV-294 in the 100% demand position. _ 2) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231) for 32 GPM charging line flow. _ 3) Throttle 1NV-295 to control charging flow as required in subsequent steps. _ 4) IF VI pressure less than 50 PSIG, THEN GO TO Step 26.c RNO.
- c. Close 1NV-309 (Seal Water Injection c. Dispatch operator with radio to perform Flow). the following:
_ 1) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ 2) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps.
- d. Ensure one of the following valves-valves -
OPEN: _ . 1NV-32B (NV Supply To Loop A Isol) OR
- 1NV-39A (NV Supply To Loop D Isol).
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- 26. (Continued)
- e. Open the following valves: e. Dispatch operator to open the affected valve(s). REFER TO the following
- 1NV-312A (Chrg Line Cant Isol) enclosure(s) for affected valve(s):
- 1NV-314B (Chrg Line Cant Isol).
- Enclosure 14 (Locally Open 1NV-312A)
- Enclosure 16 (Locally Open 1 1NV-314B).
NV-314B).
- f. Verify 1NV-309 - ABLE TO BE f. GO TO Step 26.h.
OPERATED FROM THE CONTROL ROOM. _ g. Place 1NV-309 in auto.
- h. Perform the following:
- Maintain charging flow less than 180 GPM
- Maintain 32 GPM seal water flow.
- 27. Control charging flow to maintain Pzr level greater than 11 % (20% ACC).
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- 28. Verify 5/1 flow not required as follows:
- a. NC subcooling based on core exit TICs a. Perform the following:
- GREATER THAN OaF.
_ 1) Manually start S/I SII pumps and align valves as necessary to restore NC subcooling. _ 2) GO TO EP/1/A/5000/ECA-3.1 EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired).
- b. Pzr level level-- GREATER THAN 11 11%
% b. Perform the following:
(20% ACC). _ 1) Control charging flow to restore Pzr level to greater than 11 % (20% ACC).
- 2) IF Pzr level cannot be maintained at greater than 11 % (20% ACC),
THEN: _ a) Manually start S/I pumps and align valves as necessary to restore Pzr level. _ EP/1/A/5000/ECA-3.1 b) GO TO EP/1/N5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant - Subcooled Recovery Desired).
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- 29. Ensure proper operation of VCT Makeup Control System as follows:
- a. Determine the required shutdown boron concentration. REFER TO ROD Book, Section 5.11.
- b. WHEN the required shutdown boron concentration is determined, THEN:
_ 1) Adjust VCT makeup controls for a boron concentration that is greater than or equal to the required shutdown boron concentration. _ 2) Ensure "NC MAKEUP MODE SELECT"-IN SELECT" - IN "AUTO". _ 3) Place the "NC MAKEUP CONTROL" switch momentarily to the "START" position.
- 30. Establish normal letdown as follows:
- a. Verify VI pressure - GREATER THAN a. Perform the following:
35 PSIG. _ 1) WHEN VI pressure is greater than 35 PSIG, THEN perform Steps 30.b through 30.n. _ 2) GO TO Step 31.
- b. Verify Pzr level level-- GREATER THAN 25% b. Perform the following:
(34% ACC). _ 1) WHEN Pzr level increases to greater than 25% (34% ACC), THEN perform Steps 30.c through 30.n. _ 2) GO TO Step 31.
- c. Ensure the following valves - CLOSED:
- 1KC-56A (KC To ND Hx 1A Sup Isol)
- 1KC-81B 1KC-81 B (KC To ND Hx 1B 1B Sup Isol).
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- 30. (Continued) lights -
- d. Verify the following EMF trip 1 lights- d. Perform the following:
DARK: _ 1) Notify station management to EMF-S3A (Containment Trn A)
- 1EMF-53A evaluate restoring normal letdown EMF-S3B (Containment Trn B).
- 1EMF-53B with high NC System activity.
_ 2) Establish excess letdown. REFER TO Enclosure 4 (Establishing Excess Letdown). _ 3) WHEN station management approval to establish normal letdown is obtained, THEN perform Steps 30.e through 30.n. _ 4) GO TO Step 31.
- e. Verify the following valves for the e. Manually open valve(s).
operating KC train(s) - OPEN:
- Train A:
- 1KC-1 A (Aux Bldg Non-Ess Ret Hdr Isol)
KC-SOA (Aux Bldg Non-Ess Hdr
- 1KC-50A Isol).
- Train B:
- 1KC-2B (Aux Bldg Non-Ess Ret Hdr Isol)
KC-S3B (Aux
- 1KC-53B (Au x Bldg Non-Ess Hdr Isol).
- f. Ensure 1NV-849 (Letdn Flow Var Orif Ctrl) valve demand position - 0%.
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- 30. (Continued)
- g. Open the following valves: g. Perform the following:
- 1NV-1A (NC Letdn To Regen Hx Isol) 1) Ensure the following valves -
CLOSED:
- 1NV-2A (NC Letdn To Regen Hx Isol)
- 1NV-1A (NC Letdn To Regen Hx
- 1NV-15B 1 NV-15B (Letdn Cont Isol). Isol)
- 1NV-2A (NC Letdn To Regen Hx Isol)
- 1NV-15B (Letdn Cont Isol).
_ 2) Establish excess letdown. REFER TO Enclosure 4 (Establishing Excess Letdown). _ 3) GO TO Step 31.
- h. While performing the following steps, manually adjust charging flow to maintain letdown subcooled.
- i. Throttle 1NV-148 (Letdn Press Control) to 45% demand.
_ j. Open 1 NV-1 OA (Letdn Orif 1 1NV-10A 1BB Otlt Cont Isol).
- k. Throttle open 1NV-849 (Letdn Flow Var Orif Ctrl) in 1% to 5% increments until one of the following conditions is met:
_ . Letdown flow and letdown pressure increases OR _
- Valve demand position is 60% open.
I. Do not continue until one of the above conditions is met.
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- 30. (Continued)
_ m. Verify letdown flow and letdown m. Perform the following: pressure - HAS INCREASED.
- 1) Close the following valves:
- 1 NV-849 (Letdn Flow Var Orif Ctrl)
- 1 NV-1 OA (Letdn Orif 1B Otlt Cont Isol)
- 1 NV-1A (NC Letdn To Regen Hx Isol)
- 1NV-2A (NC Letdn To Regen Hx Isol).
_ 2) Establish excess letdown. REFER TO Enclosure 4 (Establishing Excess Letdown). _ 3) GO TO Step 31.
- n. Adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure between 150 - 200 PSIG.
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- 30. (Continued)
- o. WHEN 5 minutes have elapsed, THEN perform the following:
_ 1) Adjust 1NV-849 (Letdn Flow Var Orif Ctrl) in 1% increments to desired letdown flow.
- 2) WHEN letdown at desired flow, THEN perform the following:
_ a) Adjust 1NV-148 (Letdn Press Control) to maintain letdown pressure at 350 PSIG. _ b) Ensure 1NV-148 (Letdn Press Control) -IN AUTO. _ 3) IF AT ANY TIME additional letdown flow desired, THEN establish letdown with the 45 or 75 GPM orifice. REFER TO OP/1/A/6200/001 (Chemical and OP/1/Al6200/001 Volume Control System).
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- 31. Align NV pump suction to the VCT as follows:
- a. Verify at least one of the following NV a. Perform the following:
pump suction valves - OPEN: _ 1) Notify station management for _ . 1NV-252A (NV Pumps Suct From guidance to restore NV pump FWST) suction to the VCT. OR _ 2) GO TO Step 32. _ . 1NV-253B (NV Pumps Suct From FWST).
- b. Open the following valves:
_ . 1NV-188A (VCT Otlt Isol) _ . 1NV-189B (VCT Otlt Iso I).
- c. Close the following valves:
- 1NV-252A (NV Pumps Suct From FWST)
- 1NV-253B (NV Pumps Suct From FWST).
- 32. Isolate CLAs as follows:
- a. Verify NC pressure - LESS THAN a. Perform the following:
700 PSIG. _ 1) WHEN NC pressure is less than 700 PSIG, THEN perform Steps 32.b through 32.e. _ 2) Observe Note prior to Step 33 and GO TO Step 33.
- b. Verify the following: b. GO TO EP/1/A/5000/ECA-3.1 (SGTR With Loss Of Reactor Coolant -
- NC subcooling based on core exit Subcooled Recovery Desired).
TICs - GREATER THAN OaF
- Verify Pzr level - GREATER THAN 11% (20% ACC).
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- 32. (Continued)
- c. Dispatch operator to restore power to all CLA discharge isolation valves.
REFER TO Enclosure 11 (Power Alignment for CLA Valves).
- d. Maintain NC pressure greater than CLA pressure until the CLAs are isolated or vented.
- e. WHEN power is aligned, THEN:
- 1) Close all of the following valves: 1) Vent any CLA which cannot be isolated as follows:
1NI-54A (C-Leg Accum A Disch
- 1NI-S4A Isol) _ NI-47A a) Open 1NI-4 7A (C-Leg Accum Cant Isol).
N2 Sup Cont NI-65B (C-Leg Accum B Disch
- 1 NI-6SB Isol) _ 1CB-1 (behind b) Place breaker 1CB-1 1MC-6) (Key #11) to "ON".
- 1NI-76A (C-Leg Accum C Disch Isol) CLA( s) to c) Open the valve for the CLA(s) be vented:
- 1 NI-88B (C-Leg Accum D Disch Isol).
- 1NI-SO NI-50 (C-Leg Accum A N2 Supply Isol)
- 1NI-61 (C-Leg Accum B N2 Supply Isol)
_ .* 1NI-72 1NI-72 (C-Leg Accum C N2 Supply Isol) _ .* 1NI-84 (C-Leg Accum D N2 Supply Isol). _ 1NI-47A (C-Leg Accum d) Close 1NI-47A Cant Isol). N2 Sup Cont _ 1NI-83 (C-Leg Accums N2 e) Open 1NI-83 Vent Ctrl) to depressurize the affected CLA(s). (RNO continued on next page)
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- 32. (Continued) f) WHEN CLA(s) is vented, THEN:
_ (1) Close 1NI-83 (C-Leg Accums N2 Vent Ctrl). (2) Close valve(s) previously opened:
- 1NI-50 (C-Leg Accum A Isol)
N2 Supply 1501)
- 1NI-61 (C-Leg Accum B Isol)
N2 Supply 1501)
- 1NI-72 (C-Leg Accum C Isol)
N2 Supply 1501)
- 1NI-84 (C-Leg Accum 0 D Isol).
N2 Supply 1501). _ (3) Place breaker 1CB-1 (behind 1MC-6) to "OFF". _ 2) Notify dispatched operator to remove power from all CLA isolation valves. REFER TO Enclosure 11 (Power Alignment for CLA Valves). Enclosure 5 (NC Pressure And Makeup Control to Minimize Leakage) shall remain in effect until subsequent procedures provide alternative NC pressure and makeup control guidance.
- 33. Control NC pressure and charging flow to minimize primary to secondary leakage. REFER TO Enclosure 5 (NC Pressure And Makeup Control to Minimize Leakage).
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- 34. Verify at least one NC pump - ON. _ WHEN primary to secondary leakage has been stopped, THEN consider NC T-Cold indication in the ruptured loop to be valid. REFER TO Enclosure 5 (NC Pressure And Makeup Control to Minimize Leakage).
- 35. Verify proper NS pump operation as follows:
- a. At least one NS pump - ON. a. Perform the following:
_ 1) IF AT ANY TIME an NS pump(s) starts while in this procedure, THEN perform Step 35. _ 2) GO TO Step 36.
- b. Verify the following valves - OPEN: b. Perform the following:
- 1FW-27A 1FW-27A (ND(NO Pump 1A Suet Suct From _ 1) IF NS pump(s) have previously FWST) been stopped more than once, THEN GO TO Step 36.
- 1FW-55B (ND (NO Pump 1B Suct From FWST). _ 2) WHEN containment pressure is less than 1 PSIG, THEN perform Steps 35.e through 35.g.
_ 3) GO TO Step 36.
- c. Containment pressure - LESS THAN c. Perform the following:
2.4 PSIG. _ 1) WHEN containment pressure is less than 2.4 PSIG, THEN perform Step 35. _ 2) GO TO Step 36.
- d. Verify operating NS pump(s) - HAVE.
HAVE d. IF NS pump(s) has previously been REMAINED RUNNING SINCE INITIAL stopped, THEN GO TO Step 36. PHASE B SIGNAL.
- e. Reset NS.
- f. Stop NS pumps.
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- 35. {Continued)
- g. Close the following valves:
- 1NS-29A (NS Spray Hdr 1A Cont Isol)
- 1NS-32A (NS Spray Hdr 1A Cont Isol)
- 1NS-15B (NS Spray Hdr 1B Cont Isol)
- 1NS-12B (NS Spray Hdr 1B Cont Isol).
- 36. Verify all AC busses are energized by Perform the following:
offsite power as follows:
- a. WHEN time allows, THEN attempt to
- A Train: restore offsite power while continuing with this procedure. REFER TO
* "FTA B/O NORM FDR FRM ATC" - AP/1/A/55001007 (Loss of Normal CLOSED Power).
* "DIG 1A BKR TO ETA" - OPEN b. Manually start following equipment:
- 1ETA - ENERGIZED .
- Start all available CRD vent fans.
- B Train:
- Dispatch operator to start available VI compressors.
* "FTB B/O NORM FDR FRM ATD" -
CLOSED
* "DIG 1B BKR TO ETB" - OPEN
- 1ETB - ENERGIZED.
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- 37. Verify conditions to stop operating DIGs as follows:
- a. At least one DIG - ON. a. GO TO Step 38.
- b. Verify 1ETA is energized by offsite b. Perform the following:
power as follows: _ 1) 1} Attempt to restore offsite power to
* "DIG 1A BKR TO ETA" - OPEN affected switchgear. REFER TO AP/1/A/55001007 (Loss of Normal
- 1ETA - ENERGIZED. Power).
_ 2) 2} GO TO Step 37.d.
- c. Dispatch operator to stop 1A DIG and place in standby readiness. REFER TO OP/1/A/63501002 (Diesel Generator Operation).
- d. Verify 1ETB is energized by offsite d. Perform the following:
power as follows: _ 1) 1} Attempt to restore offsite power to
* "DIG 1B BKR TO ETB" - OPEN affected switchgear. REFER TO AP/1/A/55001007 (Loss of Normal
- 1ETB - ENERGIZED. Power).
_ 2) 2} GO TO Step 38.
- e. Dispatch operator to stop 1B DIG and place in standby readiness. REFER TO OP/1/A/63501002 (Diesel Generator Operation).
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- 38. Minimize secondary system contamination as follows:
- a. Dispatch operators to perform the following:
_ 1) Inspect aux building and turbine building for leakage. _ 2) Isolate or minimize leakage where possible but do not isolate S/I or charging paths to the NC System. _ 3) Isolate or identify leakage into the turbine building sump. REFER TO PT/1/B/41501001 G (Turbine Building Sump Isolation).
- b. Remove CM polishing demineralizers from service as follows:
_ 1) Ensure "POLSH DEMIN BYP CTRL"
- PLACED IN MANUAL.
_ 2) Ensure "POLSH DEMIN BYP CTRL"
- OPEN.
_ 3) Notify Secondary Chemistry CM polishing demineralizers have been bypassed.
- c. Align auxiliary systems to minimize secondary side contamination. REFER TO Enclosure 6 (Auxiliary System Alignment).
- 39. Operate Pzr heaters as necessary to saturate Pzr water at ruptured S/G(s) pressure.
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- 40. Verify NC pump cooling is aligned as follows:
- a. Verify KC aligned to Reactor Bldg Non a. Perform one of the following based on Essential Header: seal injection status:
- A train _ .* IF NC pump seal injection flow is greater than 6 GPM to each NC
- 1KC-3A (Rx Bldg Non-Ess Ret Hdr pump, THEN manually open the Isol) - OPEN affected valve(s).
- 1KC-230A (Rx Bldg Non-Ess Hdr
- IF NC pump seal injection flow is less Isol) - OPEN than 6 GPM to any NC pump, THEN:
- A train KC pump(s) - ON.
OR NC pump seals will be cooled during NC
- B train System cooldown .
- 1KC-228B (Rx Bldg Non-Ess Hdr _ 1) Maintain NC pump seal injection Isol)-
Isol) - OPEN and thermal barrier cooling isolated to the affected NC
- 1KC-18B (Rx Bldg Non-Ess Ret pump(s).
Hdr Isol) - OPEN _ 2) GO TO Step 41.
- B train KC pump(s) - ON.
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- 40. (Continued)
- b. Verify the following valves - OPEN: b. Perform one of the following based on seal injection status:
- 1KC-394A (NC Pump 1 1A A Therm Bar Otlt)
- IF NC pump seal injection flow is greater than 6 GPM to each NC
- 1KC-364B (NC Pump 1B Therm Bar pump, THEN perform the following:
Otlt) _ 1) Manually open the affected
- 1KC-345A (NC Pump 1C Therm Bar valve(s).
Otlt) _ 2) Monitor KC surge tank levels for
- 1KC-413B (NC Pump 10 1D Therm Bar signs of KC leakage.
Otlt)
- 3) IF AT ANY TIME KC leakage
- 1KC-424B (NC Pumps Ret Hdr Cant suspected, THEN close the Isol) following:
- 1KC-425A (NC Pumps Ret Hdr Cant
- 1KC-424B (NC Pumps Ret Hdr Isol) Cant Isol)
- 1KC-338B (NC Pumps Sup Hdr Cant
- 1KC-425A (NC Pumps Ret Hdr Isol). Cant Isol)
- 1KC-338B (NC Pumps Sup Hdr Cant Isol).
- IF NC pump seal injection flow is less than 6 GPM to any NC pump, THEN:
NC pump seals will be cooled during NC System cooldown. _ 1) Maintain NC pump seal injection and thermal barrier cooling isolated to the affected NC pump(s). _ 2) GO TO Step 41. _2)
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- 40. (Continued)
- c. NC pump seal injection flow - c. Perform one of the following based on GREATER THAN 6 GPM TO EACH NC seal injection status:
PUMP.
- IF seal injection flow exists, THEN throttle 1NV-294 (NV Pmps A&B Disch Flow Ctrl) to maintain 32 GPM seal injection flow.
OR
- IF seal injection flow has been lost, THEN REFER TO AP/11A155001008 (Malfunction of Reactor Coolant Pump), Case ".(Loss of Seal Water Injection).
- 41. Establish NC pump seal return flow as follows:
- a. Verify NC pump seal injection flow - a. Perform the following:
GREATER THAN 6 GPM TO EACH NC PUMP. _ 1) WHEN NC pump seal injection is restored, THEN perform Steps 41.b through 41.g. _ 2) Observe Note prior to Step 42 and GO TO Step 42. D/1 "SEALWATER HX
- b. Verify 1AD-7, 0/1 b. Perform the following:
KC HI/LO FLOW" - DARK. _ 1) Notify station management to evaluate restoring NC pump seal return flow. _ 2) WHEN notified by station management OR 1AD-7, 0/1 D/1 dark, THEN perform Steps 41.c through 41.g. _ 3) Observe Note prior to Step 42 and GO TO Step 42.
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- 41. (Continued)
Iights-
- c. Verify the following EMF trip 1 lights- c. Perform the following:
DARK: _ 1) Notify station management to
- 1EMF-53A (Containment Trn A) evaluate restoring NC pump seal
- 1EMF-53B (Containment Trn B). return with high NC System activity.
_ 2) WHEN station management approval to establish NC pump seal return is obtained, THEN perform Steps 41.d through 41.g. _ 3) Observe Note prior to Step 42 and GO TO Step 42.
- d. Verify NCDT pressure - LESS THAN d. Perform the following:
VCT PRESSURE. _ 1) Consult with station management to establish normal NCDT pressure. REFER TO OP/11A165001014 OP/1/A/6500/014 (Operations Controlled Liquid Waste Systems). _ 2) WHEN NCDT pressure is less than VCT pressure, THEN perform Steps 41.e through 41.g. _ 3) Observe Note prior to Step 42 and GO TO Step 42.
- e. Open the following valves:
- 1NV-89A (NC Pmps Seal Ret Cont Isol)
- 1NV-91 B (NC Pmps Seal Ret Cont Isol).
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- 41. (Continued)
- f. IF AT ANY TIME NCDT pressure is greater than VCT, THEN perform the following:
_ 1) Monitor NC Pump #1 seal LlP. _ 2) Verify excess letdown --ISOLATED. ISOLATED. _ 2) Align 1NV-125B (Excess Letdn Hx Otlt Ctrl) to "NCDT".
- 3) Close the following valves:
- 1NV-89A (NC Pmps Seal Ret Cant Isol)
Cont
- 1NV-91 B (NC Pmps Seal Ret Cont Cant Isol).
_ g. Verify excess letdown -ISOLATED. _ g. Align 1NV-125B (Excess Letdn Hx Otlt Ctrl) to "VCT".
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- Preference should be given to starting 1B NC pump to provide normal Pzr spray capability. If 1B NC pump is not available, then two or three NC pumps may need to be started to provide normal Pzr spray capability.
- If B S/G is the ruptured S/G , then B NC loop may be hotter than the other NC loops. In this case A NC pump should be in operation along with B NC pump for effective spray flow.
- 42. Verify NC pump status as follows:
- a. Verify 1B NC pump - ON. a. Perform the following:
_ 1) IF all NC pumps are off, THEN _1) ensure Natural Circulation. REFER TO Enclosure 8 (Natural Circulation Monitoring Parameters). _ 2) Start NC pumps. REFER TO Enclosure 7 (NC Pump Start).
- 3) IF plant conditions do not allow start of NC pumps, THEN perform the following:
_ a) WHEN NC pump(s) become available, THEN observe Notes prior to Step 42 and perform Step 42. _ b) GO TO Step 43. _ 4) GO TO Step 43.
- b. Stop NC pumps not needed for Pzr spray flow.
- c. Ensure the normal Pzr spray valve associated with secured NC pump -IN MANUAL AND CLOSED.
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- 43. Determine status of NIls Nils as follows:
- a. Verify IIR I/R channels - LESS THAN a. Perform the following:
10-10 AMPS. _ 1) WHEN IIR I/R channels are less than 10- 10 Amps, THEN perform Steps 43.b and 43.c. _ 2) GO TO Step 44.
- b. Verify SIR channels - ENERGIZED. b. Place SIR select switches in "RESET".
- c. Transfer one channel of the "NIS RECORDER" to SIR instrumentation.
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- 44. Shutdown unnecessary plant equipment as follows:
- a. Verify turbine generator megawatt a. Perform the following:
output - LESS THAN OR EQUAL TO ZERO MW. ZEROMW. _ 1} Determine and correct cause of 1) continued turbine generator output. _ 2} WHEN turbine generator megawatt 2) output less than or equal to zero MW, THEN perform Step 44.b and Step 44.c. _ 3} GO TO Step 44.d. 3)
- b. Ensure the following breakers and MODs - OPEN:
MODs-OPEN:
- MOD 1BG and 1BT
- MOD 1AG and 1AT
- 1B.
Generator Breakers 1A and 1B.
"EXCITATION"--
- c. Ensure main generator "EXCITATION" OFF.
- d. Verify "MAN/AUTO REG" select switch d. Transfer to manual mode.
"MAN" mode light - LIT.
- e. Dispatch operator to secure NF chillers and pumps.
- f. Stop excess condensate booster pumps.
_ g. Stop excess hotwell pumps.
- h. Stop C heater drain pumps.
- i. Stop excess RC pumps and cooling tower fans. REFER TO OP/1/B/64001001A (Condenser OP/1/B/6400/001A Circulating Water System).
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- If no NC pump can be run, then using EP/1/A/SOOO/ES-3.1 EP/1/A15000/ES-3.1 (Post-SGTR Cooldown Using Backfill) may result in void formation in the affected loop and inadequate shutdown margin due to poor mixing of unborated S/G water.
- If S/G N/R level has exceeded 92%, then using EP/1/A/SOOO/ES-3.3 EP/1/A15000/ES-3.3 (Post - SGTR Cooldown Using Steam Dump) may result in damage to piping and equipment.
- If the condenser is unavailable, then using EP/1/A/SOOO/ES-3.3 EP/1/A15000/ES-3.3 (Post-(Post -
SGTR Cooldown Using Steam Dump) may result in higher offsite radiological releases.
- 45. Consult with station management to determine appropriate post-SGTR cooldown method:
_ . GO TO EP/1/A/5000/ES-3.1 EP/1/N5000/ES-3.1 (Post-SGTR Cooldown Using Backfill) OR _ . GO TO EP/1/A/5000/ES-3.2 EP/1/N5000/ES-3.2 (Post - SGTR Cooldown Using Blowdown) OR _ .* GO TO EP/1/A/5000/ES-3.3 EP/1/N5000/ES-3.3 (Post - SGTR Cooldown Using Steam Dump).
Scenario 1 Scenario starts at 10-8 amps with a power increase to 1% power. When a positive SUR is evident, the I/R power channel will fail. The reactor should be stabilized and the I/R failure dealt with. The next event is the loss of a CCW pump. Subsequently, a loss of offsite power to B essential bus (lETB) will occur. The DIG will not load and the cooling water valve to the DIG will not open, and the crew will secure the DIG. All power to 1ETB lETB is lost for the remainder of the scenario. A small leak on the reactor coolant system (~25 gpm) will develop requiring charging flow to be increased and letdown to be reduced. Once the leak is quantified, the running feed pump will trip and the aux feed water pump will not start in auto. Based on power < 5%, the reactor should NOT be tripped, however, 1A lA aux feed water pump should be manually started. The major begins with a large steam break on 1A lA SIG outside containment. The 1A lA RHR pump will not start automatically. The recirc valve on one of the running RHR pumps will fail to open and the pump ofthe will be secured. The blowdown isolation valve inside containment on the faulted SIG does not close automatically and the outside valve has no power and is not closed. The outside valve should be locally manually closed. The crew will transition from E-O to E-2 and once the SIG is isolated per E-2, they will terminate SII per ES-1.1. The scenario will be terminated when the high pressure injection isolation valves are closed.
Scenario 2 Scenario starts at 100% power with 1A D/G out of service. Power reduction is required for testing. Boration will be done followed by turbine load decrease. The RN strainer on the running pump will clog requiring another RN pump to be started and the initially running pump to be secured. A condenser dump valve will fail to an intermediate position requiring manual isolation. Reactor power will initially increase and have to be maintained by the crew to prevent exceeding 100%. Once the valve is isolated and stable conditions exist, a loss of vacuum will occur and load will be manually reduced to stabilize and recover vacuum. Finally, the PZR spray valve will open and no manual control is available. The spray valve mode select key switch will be used to fail the spray valve closed. The major event begins with a S/G tube leak on 1A S/G (650 gpm). Feed water will not automatically isolate. The high head injection valves will fail to open on the safety injection. The PORV on the S/G will fail open and require the isolation valve to be closed. Once the NC system is cooled ruptured 5/G down and depressurized where S/I 5/1 can be terminated, the scenario will end when the high head injection valves are closed.
Scenario 3 Starts at 75% power increasing to 100% @ 5%/hr with 1A D/G out of service. PR channel N44 will fail high requiring its removal from service. Then a control rod will drop partially into the core and rods will be placed in manual. Once the rod is addressed, The PZR PORV will open and won't close automatically. The crew will manually attempt to close, but the PORV will stick partially open requiring the block valve to be closed. A loss offeed of feed pump runback will occur but the rods will not respond in auto even if ifthey they are placed back in auto. The major will begin with the loss of ofthe the second running feed pump and will require the crew to trip the reactor. At that time the major accident (lB {LB lOCA) LOCAl will occur. Automatic 5/1 will not occur and be manually initiated. During the swap to ClR CLR after the 1B ND pump is secured due to its sump valve being closed, an "A" train blackout will occur. With no ND aligned to the sump, the crew will send someone to manually open the B sump valve and transition to ECA-1.1. While in ECA-1.1 (loss {loss of recirc), recircL the local operators will manually open the liB" "B" train containment sump valve and the crew will go back to ES-1.3. The scenario will be terminated when proper 5/1 flow is verified per ES-1.3.
Appendix 0 Scenario Outline Form ES-D-1 2009 NRC EXAMINATION Facility: Catawba Nuclear Station Scenario No.: 3-3 Op-Test No.: 20090-1 SNAP 143 Examiners: Operators: Initial Conditions:
- 75% power
- EFPD = 450 days
- Boron Concentration is 208 ppm Turnover:
- 1A DIG was placed in Maintenance Mode and red tagged 2 hours ago for PMs and is expected back in 6 hours.
- Increase power to 100% at 5% an hour per OP/1/A161 00/003 001003 (Controlling Procedure for Unit Operation), Enclosure 4.1, Power Increase Event Malf. No. Event Event No. Type* Description 1 BOP N Dilute for power increase (DCS) 2 RO R Increase power to 100%
3 BOP I P/R N44A failure SRO TS 4 RO C Rod M12 drops partially into the core and sticks SRO TS 5 BOP C PORV open does not fully reclose, can be blocked SRO TS 6 RO C Loss of 1A CF pumpl no auto rod motion 7 ALL M Large Break LOCAl Loss of emergency coolant recirculation Additional Failures Auto S/I train A & B fails to auto actuate 1NI-184B fails closed 1A essential train loss of power 1A
*(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
SIMULATOR SETUP Reset to a 75% power EOL snap Roll Charts Provide a borationldilution plan Clear EHC alarm and any OAC/1.47 OACI 1 .4 7 bypass alarms Sign off OP/11A161 OP/1/A/61 001003 enclosure 4.1 thru step 2.52 (students start at 2.53) MALFUNCTIONS. MALFUNCTIONS, REMOTES. REMOTES, and OVERRIDES Malfunction # Description Value Event Ramp Delay Trigger MAL-ISE002A AUTO SI TRN A FAILS TO ACTUATE MAL-ISE002B AUTO SI TRN B FAILS TO ACTUATE VLV-NI037F NI184B CNMT SUMP LINE 1B 1B 0 ISOL (STEM) FAIL TO POSITION OVR-DG015B DIG 1B MAINT MAl NT MODE PB (11/378) ON INITIATE PB OVR-DG047 *DG-PNL** MAINTENANCE MODE
*DG-PNL ON PB BLACK PB OVR-DG048A *DG-PNL** MODE SEL 2 POS
*DG-PNL ON LOCKOUT RELAY SW TRIP POS MAL-ENB011 G P/R DETECTOR 44A FAILURE MAL-ENB011G 100 3 MAL-IRX006M12 DROPPED ROD M12 STATIONARY 4 Del in 1
MAL-IRX010M12 PERMANENTLY STUCK ROD 4 2 M12-38A MAL-OV0691 B NCDJ5167 NC-34A DEMAND ALARM 5 OPEN fail to NORMAUALARM VLV-NC007F NC34A PZR PORV FAIL TO 1 5 1 POSITION MAL-IRX009 RODS FAIL TO MOVE AUTO 6 OVR-FWP012C CFPT 1A TRIP & RESET TRIP PB ON 6 OVR-FWP015C CFPT 1B TRIP & RESET TRIP PB ON 7 MAL-NC013C NC COLD LEG C LEAK 27.5 8 OVR-EP029D ETA NORM FOR FDR FRM ATC TRIP ON 9 10 PB VLV-NC007F NC34A PZR PORV FAIL TO 0.25 12 1 POSITION MAL-EQB003A LOSS OF DIG 1A SEQUENCER 21 300 CTRLPWR CTRL PWR VLV-NI037F NI184B CNMT SUMP LINE 1B 1B 1 22 300 300 ISOL (STEM) FAIL TO POSITION VLV-NC006C NC33A PZR PORV ISOL VLV 23 300 FAIL PWR LOA-CNT002 H2 ANAL YZERS BOTH 24 600
EVENT TRIGGERS (other than manual) Event Description Trigger 8 Reactor trip either train [ jpplp4(1) I jpplp4(2) ] 9 x11 i357F (TRUE when 1B ND pump is secured) 12 X1 Oi1 03c (TRUE when 1NC-34A is taken to the close position) positionl CRITICAL TASKS (See attached documentation) E-O D - Manually actuate at least one train of SIS-actuated safeguards before any of the following:
- Transition to any E-1 series, E-2 series, or E-3 series procedure or transition to any FRG
- Completion of Step 5.a of ES-0.1 ES-1.3 A - Transfer to cold leg recirculation and establish ECCS recirculation flow that at least meets the assumptions of plant specific LOCA analyses.*
- Per Technical Specification 3.5.2 basis background section:
The EGGS ECCS consists of three separate subsystems: centrifugal charging (high head), safety injection (SI) (intermediate head), and residual heat removal (RHR) (low head). Each subsystem consists of two redundant, 100% capacity trains. The ECCS EGGS accumulators and the RWST are also part of the EGGS, ECCS, but are not considered part of an ECCS EGGS flow path as described by this LCO. LGO. ECCS flow paths consist of piping, valves, heat exchangers, and pumps such that water The EGGS from the RWST can be injected into the RGS RCS following the accidents described in this LGO. LCO. The major components of each subsystem are the centrifugal charging pumps, the RHR pumps, heat exchangers, and the SI pumps. Each of the three subsystems consists of two 100% capacity trains that are interconnected and redundant such that either train is capable of supplying 100% of the flow required to mitigate the accident consequences. This interconnecting and redundant subsystem design provides the operators with the ability to utilize components from opposite trains to achieve the required 100% flow to the core. QUALITATIVE ATTRIBUTES Required Actual Total malfunctions 5-8 8 Malfunctions after EOP entry 1-2 3 Abnormal events 2-4 4 Major transients 1-2 1 EOPs entered/requiring substantive actions 1-2 2 EOP contingencies requiring substantive actions 0-2 1 Critical tasks 2-3 2
REFERENCES OP/1/A/61501009 (Boron Concentration Control) revision 068DCS OP/1/A/61 OP/1 IA/61 001003 (Controlling Procedure for Unit Operation), Enclosure 4.1 revision 106DCS OP/1/B/63001001 (Turbine Generator) revision 091 AP/1/A/55001016 (Malfunction of Nuclear Instrumentation System) revision 023 AP/1 IA/55001014 (Control Rod Misalignment) revision 015 AP/1/A/55001014 AP/1/A/55001011 (Pressurizer Pressure Anomalies) revision 022DCS AP/1/A/55001003 (Load Rejection) revision 036 EP/1/A/5000/E-0 (Reactor Trip or Safety Injection) revision 036DCS EP/1/A/5000/E-1 (Loss of Reactor or Secondary Coolant) revision 023 EP/1/A/5000/ES-1.3 (Transfer to Cold Leg Recirculation) revision 021 EP/1/A/5000/ECA-1.1 (Loss of Emergency Coolant Recirculation) revision 31 DCS OTHER NOTES AND INSTRUCTIONS NOTE: The following steps are GUIDELINES. The NRC lead examiner will direct timing of events unless otherwise noted. NOTE: Any groups or individuals (IAE, RxGrp, RP, SOC, SWM) that are called to IIR a problem or for simple notification of a problem, repeat back the information they provide unless otherwise noted. NOTE: Any operators dispatched should repeat back information provided. Call back items are listed below when necessary for the scenario. Event 1 - Dilute for power increase This event will be entered once the crew has taken turnover and evaluated plant conditions. When the first dilution batch has been completed, the next event can be started. Event 2 - Increase power to 100% This event will be entered once the crew has taken turnover and evaluated plant conditions. When turbine power has increased by 3-5 MW, the next event can be started. Event 3 - P/R N44A failure. SRO Technical Specification Initiating Cues:
- 1AD-2, A/3, A/8, B/8, C/8 E/8 and others When SPOCSP~C is notified to place OTDT/OPDT channel in trip per Step 5, reply:
"Place Channel 4 of OPDT and OTDT in trip condition per Model WIO 00874531." When AP/1/A/55001016 is completed, and the SRO has completed consulting Technical Specifications, the next event can be inserted. TS - 3.3.1 Items 2a, 3, 6, 7, 16b, 16c, 16d, 16e Conditions D, E, R, S
Event 4 - Rod M12 drops partially into the core and sticks Initiating Cues:
- 1AD-2, Df10, Rod Bank ORANGE background on DRPI display 1AD-2, D/10, APf1fAl5500f014 is completed (but before rod retrieval is attempted) and the SRO has When AP/1/Al5500/014 completed consulting Technical Specifications, the next event can be inserted.
TS - 3.1.4 Condition B Event 5 - PORV open does not fully reclose. can be blocked. SRO Technical Specification Initiating Cue:
- 1AD-6 Cf12, 1AD-6 Ef10, F-8 C/12, E/10, APf1fAl5500f011 is complete and the SRO has completed consulting Technical Specifications, When AP/1/Al5500/011 the next event can be inserted.
If an operator is dispatched to remove power from 1NC-33A, insert EVENT 23. When EVENT 23 is activated, state "Power has been removed from 1NC-33A". TS - 3.4.11 Condition B TS - 3.4.1 Condition A (based on NC pressure at the time) Event 6 - Loss of 1A CF pumpl no auto rod motion Initiating Cues:
- 1AD-5, Al1, Al4
- Ff4 1AD-1, F/4 APf1fAl5500f003 is completed, the next event can be inserted. This will begin the major event.
When AP/1/Al5500/003 TS - 3.1.6 Condition A (IF(I F Control Rods are at Lo-Lo insertion lim it) limit) Event 7 - Large Break LOCAl Loss of emergency coolant recirculation This is the major event. NOTE: Depending on student reading speed, they could enter EP/1/A15000/ES-1.3 without ever going to EP/1/A15000/E-1. Additional failures
- Sfl train A & B fails to auto actuate Auto SII
- 1NI-184B fails closed
- 1A essential train loss of power
In E-O, RNO Step 10.a.8).a) and b) when an operator is dispatched to secure ice condenser air handling units and place H2 analyzers in service, insert EVENT 24. Call back when the analyzers are in service and state: "Both Unit 1 H2 Analyzers are in service." NOTE: At kickout from E-O, SUBCRITICALITY is RED due to N44 failure. NC INTEGRITY is RED due to cooldown of loops due to LB LOCA. NC INTEGRITY is VALID and the crew should transition briefly to EP/1/A1S000/FR-P.1 EP/1/A/SOOO/FR-P.1 but kick back out to E-1 due to flow to the NC cold legs. HEAT SINK could also be in RED due to operator action. In E-1 Step 4, if asked to sample S/Gs for activity state "I will sample Unit 1 SIGs s/Gs for activity and report the results back in about an hour." In E-1 Step 4, if asked to frisk cation columns for activity state "I will frisk Unit 1 cation columns for activity and report back the results in a few minutes. Call back in S 5 minutes and state "Unit 1 cation columns indicate no abnormal activity." In ES-1.3 Step 4.b RNO, when dispatched to remove power from 1EDE-F01 EDE-F01F,F, insert EVENT 21. Call back when the breaker is open and state "1EDE*F01F "1 EDE-F01 F is open." In ES-1.3 Step S.a.2).c).(2), RNO when dispatched to manually open 1NI-184B,1NI-184B, insert EVENT 22. Call back when the valve reaches full open and state "1NI-184B "1NI*184B is open." Scenario End Point AFTER VERIFICATION OF PROPER 5/1 511 FLOW PER STEP S.i 5.i of EP/1/5000/Es-1.3. EP/1/S000/ES*1.3.
CREW TURNOVER INFORMATION Initial Conditions:
- 75% power
- EFPD =450 days
- Boron Concentration is 208 ppm Turnover:
- 1A 1A DIG was placed in Maintenance Mode and red tagged 2 hours ago for PMs and is expected back in 6 hours.
- Increase power to 100% at 5% an hour per OP/1/A161 OP/1/A/61 00/003 001003 (Controlling Procedure for Unit Operation), Enclosure 4.1.
Operation). 4.1, Power Increase
Duke Energy Procedure No. Catawba Nuclear Station OP/l!A/6150/009 OP/l/A/61501009 Revision No. Boron Concentration Control Des DCS 068 Electronic Reference No. Continuous Use CNOOSFKT CN005FKT
OP/I/A/6150/009 OP;1/A/61501009 of 4 Page 2 of4 Boron Concentration Control
- 1. Purpose To describe the operation of the Boron Concentration Control System.
- 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can affect core reactivity by changing boron concentration. (R.M.)
2.2 The following Limits and Precautions are Reactivity Management related: (R.M.) 2.2.1 When changing the boron concentration of the NC System, closely monitor the following for expected indication:
- Rod motion
- T-AVG
- Nuclear instrumentation 2.2.2 When performing dilutions at or near 100% power, batch additions to the VCT (instead of continuous dilution at low flow rates) are the preferred C99-0587}
method. {PIP C99-0S87} 2.2.3 If the NC System is filled and vented and the boron concentration is being reduced in the NC System, at least one NC pump shall be in operation, C99-2510} recirculating the NC System. {PIP C99-2S10} 2.2.4 If the boron concentration is being increased in the NC System, at least one Ifthe NC pump or one ND pump shall be in operation, recirculating the NC System. 2.2.5 of the NC System boron concentration of Following an increase or decrease ofthe 2: 50 ppm, pressurizer spray shall be operated to equalize the boron concentration throughout the system. 2.2.6 sub critical and dilution is in progress, ifthe When the reactor is subcritical if the Nuclear Instrumentation increases by a factor of two, secure the operation immediately and evaluate the cause. 2.2.7 If the unit has operated continuously for several months, significant Boron 10 depletion may have occurred. The effective boron concentration ofthe of the NC System may be lower than indicated by Chemistry samples. NC temperature shall be carefully monitored following VCT makeup. 2.3 During continuous dilution operations, sample the NC System H2 concentration every eight hours.
OP/l!A/61501009 OP/l!A161501009 Page 3 of of44 2.4 When manually operating any motor operated valve, minimize the torque applied to the handwheel. 2.5 After manual operation, maintenance or packing adjustment of any motor operated safety related valve, it shall be cycled electrically to ensure reliable automatic operation. 2.6 With the "NC MAKEUP MODE SELECT" switch in the "DILUTE" position, the makeup flow rate is limited by letdown flow, the VCT spray nozzle, and VCT pressure. The maximum expected makeup flow rate is approximately 95 gpm. 2.7 With the "NC MAKEUP MODE SELECT" switch in the "ALTERNATE DILUTE" position, the maximum expected makeup flow rate is approximately 130 gpm. 2.8 With BAT boron concentration greater than or equal to 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is
- .1300 2:.1300 ppm. Automatic or manual makeup can be used when NC System boron concentration is < 1300 ppm. {PIP 03-7305}
2.9 With BAT boron concentration less than 7200 ppm, it is recommended that only manual makeup be performed when the NC System boron concentration is:::: is::: 1250 ppm. Automatic or manual makeup can be used when NC System boron concentration is
< 1250 ppm. {PIP 03-7305}
- 3. Procedure Refer to Section 4 (Enclosures).
- 4. Enclosures 4.1 Automatic Makeup 4.2 Boration 4.3 Dilution 4.4 Alternate Dilution 4.5 Manual Operation Of The Makeup Controls 4.6 Operation Of The Boric Acid Transfer Pumps In Miniflow 4.7 Placing Boric Acid Tank #2 In Service For Unit #1 4.8 Valve Checklist 4.9 Rapid Boration
OP/l!A/61501009 OP/I/A/61501009 Page 4 of4 4.10 Deboration Of The NC System Using A Mixed Bed Demineralizer 4.11 Unit # 1 Boric Acid Tank Cleanup 4.12 Boric Acid Addition To NCP Seals 4.13 Recirculation Of The Boric Acid Tank With The BAT Recirc Pump 4.14 Blend Control Verification
All steps performed by BOP 1 Enclosure 4.3 OPIl!A/61501009 oP/l!A/61501009 Dilution Page 1I of3
- 1. Initial Conditions oD 1.1 1:1 RevlewtheLimiisandPreeauilons.
Review the Limits and Precautions. 1.2 IF11;fMode1.** IFinMode I .* ()r2~.:tin~11f~i[E21i'e;;tctivitY.*.hlal).4gelTIel1tcontrpls*. or 2, ensureR2:reactivity management controls esti;(PIi.shedpefSPMP established perSOMP 01-02 6Rea~ti-vitYMail~gemeilt);:'(R'.M;) (Reactivity Management) . (RM. ) oD L3 VerifY the NV . Systetnis Ved~XbeNV in operation per OP/1/A/62001001 (Chemical and "¥olPI)1e System is bOOpPetatipIlPe~OP/I1A/6200/00~(~1i~roicaland Control Volume,Control System). oD .*1.4V§~i~ 1.4 suffj,¢i~ilt~:~Ty-()lume;isayai14bleto*recei-V§theveactop:qpplanfdispl~6eddUv[ngthe VerifY sufficientRHT volume is available to receivethe reactor coolant displaced during the Pl~fiiJ'ed.<l11\ttipi1~pefatH?p. planned dilution operation, o 15 VerifYthe NBSystem isin,operation per OP/1IA162001012(Reactor.MaK~uP Water). o 1.6 Ensure a"minimum of one NC pump remains in operation throughout the 'evolution.
- 2. Procedure N@I'E:
NO'fE: 'l\hl$eil~l~s\tre~~l.:¥tffect:te~QtivitY()fthec()re.*.*ai1diis:~herefp~ei.de$~:~ilatediI)1ppPt~nt; This enclosure will affect reactivity of the core and is thereforedesignatedimportantto to Reactivity Management per. the'guidelines Re¥tqt~-vitYM~il!l.gementper the:/~i<le1ines*.ofN8D'.SQft:(Re@ti¥itY.Mana~emeil1)*j ofNSD 304 (Reactivity Management)., '(R.M.) (!t.ryL) o 2.1 Ensure valves are aligned per Enclosure 4.8 (Valve Checklist). 2.2 IF the blender is set .* for IRthel}let!<lerisset automatic makeup per Enclosure 4.1, Automatic Mak¢up,l;ecord fot!l.lltpmlitlQ'I)1~eupperEnQ1Q$J.Jre4.1,.~\tt9matic Makeup,r:ecord the stitp0[nt:pp setpointon INMj242~i(RMWS'l\iWb:a/A,:e.len<lerGttl)i~ INV-242A (RMWST To B/A Blender Ctrl): gpm 2.3 Ensure the Jollowing valve control switches in "AUTO": oDlNV'J.242A,:.iCRMWSW**T INV-242A (RMWST ToBIA o :a!A,Hlel).detCtrl) Blender Ctrl) o D (B/A BlenderOtlt 1.'0 VCT) INV'jl~~A *.CITA,:alel1<ler~iJtT~V~W) INV:-18IA o 2.4 EnsureflNV-Q42A(RMWSTToB/ABlender Cttl) controll,erin auto. o 2.5 Ensure at1east one reactor makeup w:ater pump is in "AUTO" or' "ON". o D 2.2.66 A,.<ljJ.J$t1h§tot~t\l11al<,et1pfjat~h~9xmtettothede$i~e<lY~IJ.JI)1e9'f8reactprroakeu.p*watefto* Adjust the total makeup batch counter to the desired volume qfreactor makeup water to be b.e
¥td<le<l,'*~R;M*)
added.'(R.MJ, o 2.7 PlacetQ..e "NCiMAKEUPMODESELECT" switch to the "PILUTE" position. N@iEE:1'41gplet<l~W'fl9",~ates NOTE: High letdown flow rates .**:re*$!!ltiI}iI}~re~§e<lQ@kpre~$J.Jre9il~hele~<l()Wt1:1ine.*,*.*I'f81etQ,()t\iilfl9~: result in increased backpressute onthe letdown line. IOetdown flow: i~~~§gp~~lt~fljbedes~~~l~l()*~~~~~~~heidi~J.J~~~~f19~~~~etd~QIgpm*JQaY9iQ,lll*emq~! is ~ 90 gpm, it may be desirable to reduce the dilution flow rate to 80 gpm to avoid the Total Mal<,e!!p, l:j'.tl:)'N~tiy-ia.t!(ma~fltl1'lfl!1Q,iifl~~l:)9iflte.Q,flu.tQmflti9'a9til:)lJ.§) M~keup .*flow peviCltion alarm and"a:ssociated automatic actions~ o 2.8 Adjllstthesetpoinlfor INY-242ACRM,WST To B/ABlend¢,r Ctrl)'Jo the desired flow:.
Enclosure 4.3 OPfl!Af6150f009 OP/l!A/6150/009 Dilution Page 2 of3 2.9 IF AT ANY TIME it is desired to divert letdown to the RHT manually operate INV-I72A TFATA.:NYTIME.it (3-Way Divert To VCT-RHT) as follows: (3-WayDivert aT DESIRED OT -"1 D 2.9.1 Place the control switch for INV-l72A INV-I72A (3-Way Divert To VCT-RHT) to the "RHT" position. D 2.9.2 Ensure VCT level is monitored continuously while diverting to the RHT. D 2.9.3 WHEN desired VCT level is reached return INV-I72A INV-l72A (3-Way Divert To VCT-RHT) to "AUTO". NOTE: If necessary, dilution can be manually secured at any time by placing the "NC MAKEUP Ifnecessary, CONTROL" switch to the "STOP" position. D 2.10 PlaCe the NC MAKEUP CONTROL" switch in the "START" position. (R.M.) 2.11 VerifY the following valves open: D INVW~4'~A(~W~rn*'l1QB/~:I31eild~rCtrl) D INV-242A (RMWST To BfA Blender Ctrl) D INV ":'~'81~.(:I3/~:I31'¢rluet01iltrn9VC'l1) INV-I81A (BfA Blender 011tTo VCT) 2.12 IF in "AUTO", verifY the reactorI11akeup water pump starts. 2.13 WHENti:Qy(j,~§iredV91):l.111¢,<of!'¢.Mt9ri:111ak~):I.l>iwat~t WHEN the de,sired volume of reactor makeup water **is is .teM:Q~(j,Oil~heJQtal\tnakeupga~~:Q reached on the total makeup batch c()l1nt~r,~il,Sl,ii:~'th~'*.f6nQW:Jng'¥~I'¥¢~icJ'9~e*i(:(tLN!li) counter, ensure the following valvesblose ... (R.M.) D INV~~4~W(~W~TTdB/~:I31¢nu~r(}trl) INV..;242A (RMWST To BfA Blender Ctrl) D l~M..;'I~l~~B/A, INV-18IA (BfA *. :I3Jyi1(j,erqtltrnQVGrn) Blender 011t To VCT) 2.14 IF automatic makeupis desired, perform one ofthe following: 2.14.1 IF it is desired uesireu to change the blender blenuer outlet boron concentration, refer to Enclosure 4.1 (Automatic Makeup). OR 2.14.2 IRlllakellpat the previous concentration is acceptabl~.AND;the system Wa,$ 2.14 .2IFW111~¢):I.I>~t,theRP¢'¥ig):l.§'g9QC¢ijt~~tJgp,i§6!Gc¢IW\QI¢"WND~t:Qe,S&st~nl was Rfe\llQ!t'slya~igi1eURy!,Ei)clq'sute'i.Fl(~Y(9iji~ti8~~¢l.lP)~***.p¢~(9rQlthe.foUq\\l~i1g: previously aligned per Enclosure4.I(Automatic Makeup), perform the following: D 2;14.2.1 ~i)'siifet:Q¢~di11:rqll¢tf&rl~~~~:<t6~ Ensure the controller for INV-242A. (~WS'l1'l1g.:I3/A:I31~il9¢fGtfl) (RMWSTTo BfA Blender Ctrl) i's,Set1:o1::Q¢.:\lall.l~Jt¢c9r9¢g1il*.~t¢P~~6tJ(R,~.} is set to the value recorded in Step 2.2. (R.M.) D 2.14.2.2 Placethe"NC MAKEUP MODE SEL.ECTn'swit~ffjn "AUTO". D 2.14.23 'l?la~e.thei'~G~]§UPG~NTBr~l]i~!'sW:itchtq'the!'STWRi'l\!l Place the NC MAKEUP CONTRQL" sWitCh to the "START" position. (R:,NI;) I>gsitilQl!;" (R.M.)
Enclosure 4.3 OP/ll A/61501009 OP!l/A/61501009 Dilution Page 3 of3 2.15 Do NOT file this enclosure in the Control Copy folder of this procedure.
Duke Energy Procedure No. Catawba Nuclear Station OP/l!A/61 001003 OP/I/A/61 00/003 Revision No. Controlling Procedure For Unit Operation 106 DCS lO6DCS Electronic Reference No. Continuous Use CNOO5FK5
OPIl!A/61 OPIl!AI61 001003 Page 2 of4 Controlling Procedure For Unit Operation
- 1. Purpose To describe the operation of the unit between approximately 15% and 100% full power.
- 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can effect core reactivity by the following: (R.M.)
- Control rod movement
- Turbine load changes
- Feedwater manipulations
- Reactor power changes 2.2 The following Limits and Precautions are Reactivity Management related: (R.M.)
2.2.1 2.2.l Before returning reactor control to automatic, T -AVG shall be within +/- 1°F of T-AVG T-REF. 2.2.2 Do NOT exceed rod insertion limits or temporary rod withdrawal limits. 2.2.3 Automatic control rod withdrawal is blocked when Control Bank D z ~ 200 steps withdrawn. 2.2.4 The difference in boron concentration between the PZR and NC System is desired to be maintained within +/- 50 ppm. 2.2.5 Axial Flux Difference (AFD) shall be maintained within the allowable limits as defined in the ROD manual at all power levels above 50% reactor power. (Tech Spec 3.2.3) 2.2.6 During a power change, other indications of reactor power shall be observed along with power range and secondary thermal power indications to aid in determining the reactor power level. Using indications like turbine impulse pressure, CF flow rate, NC loop .1Ts, LlTs, and others may help in detecting the miscalibration of a nuclear instrument. 2.3 In the event of an inadvertent power reduction, it is recommended that the power level NOT be increased until an investigation has been conducted and corrective action taken.
OP/l!A/6lO0/003 OP/l!A/6100/003 Page 3 of4 2.4 lfreactor control is in manual, maintain T-AVG within +/- 2°F ofT-REF to prevent receiving "T-REF/T-AUCT HIILO" alarm. 2.5 Whenever there is a thermal power change greater than or equal to 15% rated thermal power within a one hour period: (OAC point CIL4790 C1L4790 in alarm)
- NotifY Chemistry to take an isotopic analysis for iodine within 2 to 6 hours following the last power change that is greater than or equal to 15% rated thermal power within a one hour period. (T.S. SR 3.4.16.2)
- When thermal power has stabilized, notifY notify Radiation Protection to sample and analyze gaseous effluents. (S.L.C.
(S.L.e. 16.11-6) 2.6 S/G blowdown flowrate shall NOT exceed a maximum of200 GPM per S/G. 2.7 After a thermal power change when plant conditions stabilize, 1EMF-39 lEMF-39 setpoints shall be adjusted so the Trip 2 setpoint is set at three times the containment activity and Trip 1 setpoint is set at 70% of Trip 2 setpoint. 2.8 lfthe RC System condenser inlet temperature drops to less than or equal to 60°F when the Rx is shutdown or less than or equal to 55°F when the Rx is critical, the system shall be configured as follows:
- One RC pump running (throttled).
- One tower inlet isolated.
- All three riser bypasses open.
2.9 OAC point C1K0628 CIK0628 (CF Flow Venturi Correction Factor) shall be reset to 1.0 when ofthe either of the following conditions are met:
- A step load change such as a load rejection greater than 10% rated thermal power,
- A ramp load change of greater than 15% rated thermal power in a one hour period.
2.lO 2.10 When the unit is engaged in a power maneuver resulting in a mismatch between OAC point CIP1385 (Reactor Thermal Power, Best) and anyexcore any excore power channel in excess of2% refer to Tech Spec Basis for SR 3.3.1.2. 2.11 The insertion of Control Bank D will affect mismatch between OAC point CIP1385 C1P1385 (Reactor Thermal Power, Best) and the excore power range channels. This is ofthe due to shielding of the power range detectors by Control Bank D. Therefore, refer to Tech Spec Basis for SR 3.3.1.2 when mismatch between Reactor Thermal Power (Best Estimate) and the excore power range channels shall be observed to be exceeding 2%. 2.12 The Reactor Engineering Group normally provides information for planned power maneuvers. The OAC xenon predict program can be used to help anticipate dilution and boration requirements. {PIP C99-0587}
OP/l!A/6 1001003 OP/l!A/61 Page 4 of4 2.13 The Steam line N-16 Radiation Monitors (EMF-71, 72, 73, 74) become inaccurate at power levels below 40% due to inaccuracies in the algorithm used to calculate the output of these monitors. {PIP 99-3980} ofthese 2.14 It is recommended that Primary Chemistry be notified prior to all significant boric acid additions or dilutions to the NC System such that proper pH control may be maintained. Normal boric acid additions and dilutions should be communicated at the Control Room shift briefing. {PIP C-01-665} 2.15 In accordance with INPO best practices when personnel are accessing areas that could experience significant dose rate changes resulting from increasing power, Operations shall maintain Reactor power steady or decreasing.
- 3. Procedure Refer to Section 4 (Enclosures).
- 4. Enclosures 4.1 Power Increase 4.2 Power Decrease 4.3 Unit Operation Between 85% and 100% Power 4.4 T-AVG Coastdown 4.4.1 T-AVG Coastdown Data 4.4.2 Adjustment OfDCS ACCEPTED VALUE For T AVG A VG 4.4.3 T-AVG Coastdown Tracking Data (Phase 1 and Phase 2) 4.5 Power Escalation Guideline
Enclosure 4.1 OP/l!A/6100/003 Power Increase Page 15 of 15 - - 2.50 IF required due to Generator/Automatic Voltage Regulator (AVR) testing at approximately 75% turbine power (~885 MWe), perform the following: 2.50.1 IF performing Generator/Automatic Voltage Regulator (AVR) (A VR) testing, HOLD until Generator/ A VR personnel are ready for Operations to continue with Unit 1 Generator/AVR power increase. o 2.50.2 Once notified by A VR personnel that AVR testing is complete, at this power, begin power increase. Person making notification, notification_ _ _ _ _ _ _ __ CAUTION: Alternate indications of reactor power shall be monitored to verify reactor power level and help prevent NI miscalibration. 2.51 At 75% reactor power, compare OAC heat balance point CIP1385 (Reactor Thermal Power, Best) to nuclear instrumentation. - - 2.52 IF required, notify IAE to adjust nuclear instrumentation per Model W/O #00874628. Person notified CAUTION: Failure to perform the following step as written may result in lifting the AS Header relief valve. NOTE: OAC Graphics CF Pump Details, CFPMPIA and CFPMPIB, shall be referred to while swapping steam supplies for CFPTs. - - 2.53 2.5 3 **~~*:¥tppio~lm¥tt~~~6~~tul'!;)J:tt(1pOW~1'(~Q~ftMWl~~;:peif9rmiJl:i¢**fol~owingwhile.*.¢l:is].lrillg Atapproximat~ly 85% turbine power (1024 MWe); perform the following while ensllring
~f1p1ll11I?:$p~~di$:;m:~iqt~jl'l,¢g; CFpump speedis.mainta:ined:
pss to to here here complete. complete. No No steps steps signed signed off off h here ... o 2.53.1 Slowly open ISP-3 I SP-3 (SC To CFPT lA & IB) (TB-640, 1IG-24). G-24). o 2.53.2 Adjust setpoint of lAS-2 IAS-2 (Main Stm To Aux Stm) to 125 psig. o 2.53.3 IAS-I2 (AS To CFPT Isol). Slowly close lAS-12 o 2.53.4 IF Unit 1 and Unit 2 AS headers are cross-tied, adjust setpoint of2AS-2 (Main Stm To Aux Stm) to maintain the desired AS header pressure. 2.54 IF a temporary PC was installed at the local MSR Panel for placing the MSR's in service, remove the PC. 2.55 IF desired to increase turbine power to greater than 85%, go to Enclosure 4.3 (Unit Operation Between 85% and 100% Power). 2.56 File this enclosure in the Control Copy folder of this procedure.
Duke Energy Procedure No. Catawba Nuclear Station oP/I/B/6300/001 Turbine Generator Revision No. 091 Electronic Reference No. CN005F07 CNOOSF07 Multiple Use PERFORMANCE I
- UNCONTROLLEDFORPRrnT**********
(ISSUED) - PDF Format
OP/l/B/63 00/00 1 OP/l!B/6300/001 Page 2 of5 Turbine Generator
- 1. Purpose To describe the proper method for operating the Turbine-Generator.
- 2. Limits and Precautions 2.1 This procedure is Reactivity Management related because it controls activities that can effect reactivity. (R.M.)
2.2 Low load operation limits: 2.2.1 The unit can be operated continuously at low loads when exhaust hood 17SoP. The load shall, however, be increased slowly until temperature is < 175°F. the temperature decreases below 125°F 12SoP before increasing load at normal rate (Multipoint Recorder on 1MC3). IMC3). 2.2.2 Limit turbine/generator operation below 5% load to 1 hour to prevent moisture erosion unless directed by the Turbine Engineer for testing 2.2.3 Motoring of the unit is to be avoided. 2.2.4 Excessive use of the exhaust hood sprays shall be avoided to prevent accelerated blade erosion. 2.3 Journal bearings shall NOT be operated with metal temperatures above 250°F 250 0 P (OAC Turbine Bearings graphic (TGBRG)). 2.4 Lube oil cooler discharge temperatures shall be lOO°F lOOoP to 120°F 120 0 P when at rated speed. 2.S 2.5 The lube oil temperature rise shall NOT exceed 50°F SOop on the main bearings and 4SoP45°F on the thrust bearing. 2.6 Under no conditions shall the thrust bearing be operated above 190°F 190 0 P metal temperature (OAC Turbine Bearings graphic (TGBRG)). 2.7 Never allow a hot rotor to stand without rolling. If and when a hot rotor was allowed to stand still, when possible rotate the shaft 180° and allow to stand still again for one-half the time it first stood still, and then put the turbine on turning gear. 2.8 The minimum allowed cold gas temperature is 86°P 86°F for operation. The maximum cold gas temperature is 122°F. (OAC points CIA0522C1A0522 (Cold Gas from Hydrogen Cooler Turbine End) and CIA0528 C1AOS28 (Cold Gas from Hydrogen Cooler Exciter End), Main Generator graphic (MAINGEN)). (MAlNGEN)).
OP!lIB/63 00100 1 OP/l/B/6300/001 Page 3 of5 2.9 Do NOT exceed the load, hydrogen pressure, and power factor limits per the Unit One Revised Data Book Figure 43. 2.10 If the limits of the Unit One Revised Data Book Figure 43 (Generator Capability Curves) are exceeded, the Turbine Generator shall be tripped. 2.11 The generator shall NOT be operated without excitation. If the generator is operated without field, the unit shall be immediately tripped off the line and shutdown for inspection. 2.12 Following a trip-out due to differential phase relays, both the armature and field windings shall be meggered and inspected before attempting to resynchronize. 2.13 Do NOT allow turbine generator speed to exceed 2000 rpm on overspeed tests. 2.14 The turbine shall NOT be operated with condenser vacuum less than 24.3 inches Hg. 2.15 The maximum differential pressure between adjacent LP shell pressures shall NOT exceed 2.0 inches Hg. (main condenser vacuum gauges on 1MC13, IMCI3, OAC points C1P1669 (DIP between A & CIPl669 & B Condensers) and CIPl670 C1P1670 (DIP between B & &C Condensers) or Main Condenser graphic (CMCOND)). 2.16 Do NOT hold the turbine at speeds < 800 rpm for more than 5 minutes. 2.17 When steam seals are on the turbine, the steam packing exhauster shall be operating, and the turbine shall be on turning gear. The turbine may be taken off gear with steam seals established with concurrence from the Turbine Engineer. 2.18 When a condition arises that is serious enough to make a reduction in speed necessary, it shall be initiated by selecting "MANUAL" and "CONTROL VALVE LOWER" or by tripping the turbine. 2.19 Temperature of the LH System reservoir shall be 2: 90°F prior to turbine start (OAC point C1A0188 CIAOl88 (LH TEMP)). 2.20 A sudden downward trend on an LP turbine's lower extraction temperature shall be investigated as a possible indication of water induction into the turbine. This is indicated on the recorder on the rear of 1MC8 IMC8 labeled "TURBINE WATER DETECTION", using any of the LP 8th stage lower temperatures. 2.21 The time the turbine generator is on turning gear shall be kept to a minimum to prevent the buildup of copper dust in the generator coil slots. 2.22 When system is in "EMERG MANUAL" runbacks and limit circuits may NOT be available. 2.23 Control rods shall NOT exceed rod withdrawal limits. Prior to changing power, refer to Reactor Operating Data Book, Temporary Control Rod Withdrawal Limits.
op!l IB/63 00100 1 OP/l/B/63 Page 4 of5 of 5 2.24 A "LOAD RATE" > "6.2 MW/MIN"MWIMIN" shall NOT be used during normal load changes. 2.25 The main turbine oil temperature limit of 80 to 90°F shall be maintained when the turbine is on the turning gear. 2.26 Differential temperature between adjacent exhaust hoods shall NOT exceed 30°F unless evaluated and approved by the responsible engineer (Turbine Generator System Expert). (OAC points CIP1667 (A & B Exhaust Hoods Metal Delta Temp) and CIP1668 (B & C Exhaust Hoods Metal Delta Temp) or Main Condenser graphic (CMCOND>>.(CMCOND)). 2.27 During turbine acceleration, the heat up rate of the first fIrst stage bowl inner surface (OAC Point CIP1283 (First Stage Metal Temp Rate>>Rate)) shall be < 150°Fihr. 150°FIhr. 2.28 During turbine acceleration, the rate of change of the reheat steam temperature (OAC points CIP1287 to CIP1292 (CIV No.1 (to 6) Inlet Temp Rate) or Turbine Generator (TG>> shall be < 12soFIhr. graphic (TG)) 125°Fihr. 2.29 Any deviations from this procedure that could affect steam admission rates shall require an engineering evaluation to be performed which specifically addresses partial arc admission. 2.30 The 6.9KV Switchgear Automatic Fast Transfer Switches are placed in the ENABLE position whenever the generator breakers are closed and in the DEFEAT position whenever the generator breakers are open. If an auto swap of the tie breaker occurs when autoswap in the DEFEAT position, equipment being supplied by the 6.9KV Switchgear is more likely to trip than when the switch in ENABLE. {PIP 98-4093, PIP 98-3589} 2.31 Feedback loops shall NOT be taken in/out of service during turbine control valve movement. Following turbine control valve movement, DEHC shall be allowed to stabilize prior to placing feedback loops inlout of service to prevent unexpected load changes. (PIP 03-5660) 2.32 The Main Turbine OlD OIU Work Station has the capability to perform control functions for the Main Turbine, including tripping and resetting of the turbine. If a control function window is inadvertently selected while manipulating the Main Turbine OIU Work Station, the window shall be closed to prevent actuation of the control function. 2.33 The Main Turbine shall NOT be run more than 3 hours at 1800 RPM, no load, unless directed by the Turbine Engineer for testing. 2.34 The Excitation System can affect the functioning of heart pacemakers. Personnel with pacemaker devices shall NOT enter the A VR enclosure/building enclosurelbuilding during operation or testing. If the A VR enclosurelbuilding is NOT installed, personnel with pacemaker AVR devices shall remain at least 20 feet away from the A VR during operation or testing. 2.35 Failure to confirm steam isolation to the turbine prior to opening the generator breaker may result in destructive overspeed of the steam turbine power train. {PIP C-08-5018}
00/00 1 OP/1/B/63001001 OP/l!B/63 Page 5 of5
- 3. Procedure Refer to Section 4 (Enclosures).
- 4. Enclosures 4.1 Turbine Generator Startup 4.2 Load Changing 4.3 Transfer Turbine From Auto Control To Manual Control And Transfer Turbine From Manual Control To Auto Control 4.4 Turbine Generator Shutdown 4.5 Placing (Removing) Core Monitor And Pyrolysate Collector In (From) Service 4.6 Valve Checklist 4.7 Generator Operating Limits 4.8 Turbine Generator Roll Computer Points 4.9 Lamp Verification 4.10 Operation of Turbine TSI Panel 4.11 Reboot of the Main Turbine OIV OIU Computer 4.12 Transfer ofthe of the Main Turbine OIU OID Computer Alarm Switch That Drives the "ERC Fault Annunciator" 4.13 Voltage Regulator Operation From Control Room 4.14 Voltage Regulator Operation From VI U1 Gen Voltage Reg Local Control Panel
Enclosure 4.2 OP!l/B/6300/001 OP/l/B/6300/o01 Load Changing Page 1 of4 1. o o o D o D
Enclosure 4.2 op;1 IB/63 00100 1 OP!l/B/63001001 Load Changing Page 2 of4 o 2.1.1.6
*I}{\~
I
- ,. :Di.~*-".~~+;zJ;J Steps in Green will willi - -
be signed off already. i~ttlf8' o CAUTION: 1. Unti1 it is recognized that the first stage~h¢ll metal temperatutechange rate stays be16~ the allowable limit{,iSO°FIhr), thefollowing?16ading :r~te shall NOT be, excdeded:
- 1/2%/min : First Sta:~e Inner ShelV'I,(~inperature(1MC3 orOAC point CIAl140 (Turbine Lower Inner Sh6U'Temp)}S3'50°F 4t 1%/mmsFfrstStage Inner* Sheil Temperature (lMC30r OAC point CIA1140 Critrbine LowerInner Shell Temp)) > 350°F 2.' Normal steady-state load changes shall be made without exceedingtbe limits shown on Enclosure 4.7 (Generator Operating Limits) and inthe Unit One OACDatabook flRecommended Startup arid Loading Curves".
- 3. J!nit OrieRe:actorOperating Data, Section 2.4 shall be referred to for allowable ramp rates.A"LOADRATE" > 6.2 MW/MIN shall NOT be used duringnormalload changes.
2.1.2 Increase turbine generator loacl:by performing tIle following: o 2.1:2.t D';2;:IS~. ;§I ** Select ll~jj.tl*~;~p'~~till~;~t~it~~\;
"LOAD RATE" and verify it illuminates.
o 11~::~~t 02.1:2.2 1b1g~tl IllPutthe*de~ired
*~~;~~~1_
load rate. o .~¥li' 2.1.2.3 .~~tl~8_~~"~~'~~~~tl~¥~i * *~:_~9.~~i~ Select '!ENtER" or uON:ii;'a'nd ve+ffy:~',L()AD1~ATE" goes dark oO 1%1~2~4,. 2.1:2.4
'6~:**',.. ,': '~'d~:,~','
~.¢lect "TARGElT"*and verify it;H1uminates~
o :4d.2.5 D'~" Input the desired load target. oO ~i~Yi4r 2.1:2.6
~;~'}W' Select "E:NJER" and verify " TARGET" goes::~ark.
Enclosure 4.2 OP/liB/63001001 OP/l!B/63001001 Load Changing Page 3 of4 o D 2.1.2.7 Verify new load target appeafson Target Display. o 2.1.2.8 Select "00" and verify it illuminates to start load increase. o 2.1.2.9 S,,(g'plgwqbWncu~rigeSC$lJ.all:pei9bb1j9in~tea**with' S/G blowdown changes shall be coordinated with .*Seico1t9aty Secondary Cu\%1;i1:1s~ty. Chemistry. CAUTION :'iI]belg~~;{lJ.~~lggenp~~Sstij~:and*.p()w~1j,~actdl[iW.ltsp~rthetJnit CAUTION: Rlew~edData~dq~ The load? hydrogen pressure and power factor limits per the Unit One Revised Data Book
~igun~*:%t~:l~n~l1'NOT~~e~9~eded, Figure 43 spall NOT be exceeded.
2.2 IF decreasing turbine generator load, perform the following: 2.2.1 Decrease turbine generator load within the following limitations: o 2.2.1.1 D Rate of change of First-Stage Bowl Inner Surface Temperature shall NOT exceed 150°F/hr (OAC point C1P1283 (First Stage Metal Temp Rate)). o D 2.2.1.2 OAC point C1Al140 C1A1140 (Turbine Lower Inner Shell Temp) vs. Percent Steam Flow (OAC point C1P1588 (Design Total Main Steam Flow, Measured (%)) shall be maintained above and to the left of curve in the Unit One OAC Databook "Load-Changing Recommendations". o D 2.2.1.3 Control valve casing difference, OAC point C1A0961 (Turb Valve Chest Inner Surface Metal Temp) minus C1A0967 (Turb Valve Chest Outer Surface Metal Temp), shall NOT exceed curve "Allowable Temp Difference on Control Valve Casing" in the Unit 1 OAC Databook. o D 2.2.1.4 S/G b10wdown blowdown flowrates shall be adjusted to obtain maximum blowdown b10wdown for the appropriate load. 2.2.1.5 IF CV4 fully closes (92% of full load, 1109 MWE), verify 1SM-33 (Ctrl Vlv V1v #4 Stm Lead Dm) opens. 2.2.1.6 IF CV3 fully closes (65% of full load, 783 MWE), verify 1SM-25 (Ctrl Vlv V1v #3 Stm Lead Dm) opens.
Enclosure 4.2 op;1/B/63 00/00 1 OP!l/B/63001001 Load Changing Page 4 of4 CAUTION: 1. Nonnal steady-state load change shall be made without exceeding limits shown on Enclosure 4.7 (Generator Operating Limits) and in the Unit One OAC Databook "Recommended Starting and Loading Curves".
- 2. Unit One Reactor Operating Data, Section 2.4 shall be referred to for allowable ramp rates.
2.2.2 Decrease turbine generator load by perfonning the following: D 2.2.2.1 Select "LOAD RATE" and verify it illuminates. D 2.2.2.2 Input the desired load rate. D 2.2.2.3 Select "ENTER" and verify" LOAD RATE" goes dark D 2.2.2.4 Select "TARGET" and verify it illuminates. D 2.2.2.5 Input the desired load target. D 2.2.2.6 Select "ENTER" and verify" TARGET" goes dark. D 2.2.2.7 Verify new load target appears on Target Display. D 2.2.2.8 Select "GO" and verify it illuminates to start load decrease. D 2.2.2.9 S/G blowdown changes shall be coordinated with Secondary Chemistry. 2.3 Do NOT file this enclosure in the Control Copy folder of this procedure.
Initiating Cues:
- 1AD-2, N3, Al3, N8, Al8, 8/8, C/8 E/8 and others
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 AP/1/N55001016 1 of 14 DC~ Rev 24 DCS A. Purpose
- To verify the proper response in the event of a nuclear instrumentation malfunction.
B. Symptoms Case I. Source Range Malfunction
- Indication lost or erratic
- 1AD-2, D/1 "SIR HI VOLTAGE FAILURE" - LIT
- 1AD-2, D/3 "SIR HI FLUX LEVEL AT SHUTDOWN" - LIT
- 1AD-2, D/4 "SIR HI FLUX LEVEL AT SHUTDOWN" - LIT.
Case II. Audio Count Rate Malfunction
- Audible count rate lost.
Case III. Intermediate Range Malfunction
- Indication lost or erratic
- 1AD-2, C/1 "I/R HI VOLTAGE FAILURE" - LIT
- 1AD-2, C/2 "I/R COMPENSATING VOLTAGE FAILURE" - LIT
- 1AD-2, C/3 "I/R HI FLUX LEVEL ROD STOP" - LIT
- SIR failure to re-energize during shutdown.
Ca'se IV. Power Range Malfunction
- Indication lost or erratic
- 1AD-2, Al1 "P/R HI NEUTRON FLUX RATE ALERT" - LIT
- 1AD-2, Al2 "P/R HI NEUTRON FLUX LO SETPOINT ALERT" - LIT
- 1AD-2, Al3 "P/R HI NEUTRON FLUX HI SETPOINT ALERT" - LIT
- 1AD-2, 8/3 "COMPARATOR P/R CHANNEL DEVIATION" - LIT
- 1AD-2, 8/5 "P/R HI VOLTAGE FAILURE" - LIT
- 1AD-2, E/8 "OVER POWER ROD STOP" - LIT
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/Al5500/016 AP/1/A155001016 2 of 14 Case I DC~ Rev 24 DCS Source Range Malfunctions ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Verify at least one of the following SIR Perform the following:
Channels - OPERABLE:
- a. IF in Mode 2 below P-6, THEN perform
- N-31 the following:
OR _ 1) Manually trip reactor.
- N-32. _ 2) GO TO EP/1/A15000/E-O EP/1/Al5000/E-O (Reactor Trip or Safety Injection).
- b. IF in Mode, 3, 4, or 5 AND the following conditions exist:
- Reactor Trip Breakers - CLOSED
- Rod control system capable of rod withdrawal.
THEN perform the following: _ 1) Manually trip reactor. _ 2) IF any control rods were withdrawn AND Pzr Pressure greater than 1955 PSIG, THEN GO TO EP/1/A15000/E-O (Reactor Trip or Safety Injection). _ 3) IF any control rods were withdrawn AND Pzr Pressure less than 1955 PSIG, THEN REFER TO AP/1/A155001005 AP/1/A15500/005 (Reactor Trip or Inadvertent S/I Below P-11).
- c. GO TO Step 5.
- 2. Verify unit --IN IN MODE 2 BELOW P-6. _ GO TO Step 5.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/5500/016 3 of 14 Case I DC~ Rev 24 DCE Source Range Malfunctions ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Limited boron concentration changes associated with NC inventory control or limited plant temperature changes are allowed.
- 3. Stop operations involving positive reactivity additions.
- 4. GO TO Step 7.
- 5. Verify unit - IN MODE 6. _ GO TO Step 7.
BDMS (Gamma Metrics) automatic actuations and alarm not required for operability during refueling operations.
- 6. Verify at least two of the following Perform the following:
neutron flux monitors - OPERABLE:
- a. Notify fuel handling operators to
- N-31 perform the following:
- N-32 _ 1) Place components being handled in a safe position.
- A Train BDMS
_ 2) Suspend Core Alterations.
- B Train BDMS.
- b. Suspend operations that would cause introduction of coolant into the NC system with boron concentration less than limit specified in the COLR.
- c. IF no neutron flux monitors operable, THEN immediately initiate actions to restore one neutron flux monitor to operable status.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 AP/1/A155001016 4 of 14 Case I Rev 24 DCSDC~ Source Range Malfunctions ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. Identify the affected SIR channel(s):
- N31 OR
- N32.
- 8. Verify the following alarms - DARK: Perform the following:
- 1AD-2, D/3 "SIR HI FLUX LEVEL AT a. Depress "OFF" for the containment SHUTDOWN" evacuation alarm.
- 1AD-2, D/4 "SIR HI FLUX LEVEL AT b. Notify plant personnel to disregard the SHUTDOWN". containment evacuation alarm.
- 9. Verify affected SIR channel control Perform the following:
power available:
- a. Notify OSM that due to loss of control
_ . Control power fuse --ILLUMINATED ILLUMINATED power SIR LEVEL TRIP cannot be bypassed. Reactor power reduction to OR below P-6 SIR BLOCK PERMISSIVE will result in Reactor Trip due to "Nil Hi
- Control Power ON - LIT Flux SR RX Trip".
- b. GO TO Step 14.
1AD-2, C/4 "NIl "Nil SYS SIR & IIR TRIP BYPASS" will actuate in the following step.
- 10. At the affected SIR drawer, perform the following:
- a. Place the "LEVEL TRIP" switch for the affected channel in "BYPASS".
- b. Verify the "LEVEL TRIP BYPASS" light for the affected channel - LIT.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 5 of 14 Case I Rev 24 DC~ Source Range Malfunctions ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 11. Verify the affected SIR channel trip bypass status light (1SI-19)
(151-19) - LIT.
- 12. Verify 1AD-2, C/4 "Nil SYS SIR & IIR TRIP BYPASS" - LIT.
- 13. Block the high flux at shutdown function as follows:
- a. At the affected SIR drawer, place the "HIGH FLUX AT SHUTDOWN" switch for the affected channel in "BLOCK".
- b. Verify 1AD-2, 0/2 "SIR HI SHUTDOWN FLUX ALM BLOCKED" - LIT.
- 14. Ensure the following components -
ALIGNED TO THE OPERABLE SIR CHANNEL:
* "CHANNEL SELECTOR" switch on the Audio Count Rate Channel panel
* "NIS RECORDER".
- 15. Determine and correct cause of SIR malfunction.
- 16. Ensure compliance with appropriate Tech Specs:
- 3.3.1 (Reactor Trip System (RTS)
Instru mentation)
- 3.9.2 (Nuclear Instrumentation)
- 3.3.9 (Boron Dilution Mitigation System(BDMS>>.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/11A155001016 AP/1/A/55001016 6 of 14 Case I Rev 24 DC~ DC!: Source Range Malfunctions ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 17. Determine required notifications:
- REFER TO RP/0IAl50001001 RP/O/A/50001001 (Classification Of Emergency)
- REFER TO RP/0/B/50001013 RP/O/S/50001013 (NRC Notification Requirements).
- 18. Notify Reactor Group Engineer of occurrence.
- 19. WHEN the affected SIR channel is repaired, THEN ensure IAE returns the channel to service.
- 20. Determine long term plant status.
RETURN TO procedure in effect.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 AP/1/A/5500/016 7 of 14 Case" Rev 24 DC~ Audio Count Rate Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Verify the unit - IN MODE 6. Perform the following:
- a. Stop any positive reactivity additions until audible count rate indication is restored or station management approval is obtained.
- b. GO TO Step 3.
- 2. Verify audio count rate signal - AUDIBLE IF the count rate is audible in the control IN CONTAINMENT. - room, THEN shift the "AMPLIFIER SELECTOR" switch (inside and at the back of the Audio Count Rate Drawer) to the "A1" position (Key #18).
- 3. Verify SIR channels operable as follows: IF a single SIR channel has failed, THEN:
- N ON SCALE a. At the Audio Count Rate panel, place
- N ON SCALE. the "CHANNEL SELECTOR" switch to the operable SIR channel position.
- b. GO TO Case I (Source Range Malfunctions).
Malfunctions ).
- 4. Determine and correct cause of audio count rate malfunction.
- 5. RETURN TO procedure in effect.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 AP/1/N55001016 8 of 14 Case III DC~ Rev 24 DC::: Intermediate Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Verify reactor power - GREATER THAN _ Stop any power increase.
10%.
- 2. Verify 1AD-2, Cf3 C/3 "I/R "lfR HI FLUX LEVEL _ Adjust turbine load to maintain T-Avg at ROD STOP" - DARK. T-Ref.
- 3. Identify affected IIR I/R channel:
- N-35 OR
- N-36.
1AD-2, C/4 "NIl "Nil SYS SIR & & I/R TRIP BYPASS" will actuate in the following step.
- 4. At the affected I/R IfR drawer, perform the following:
- a. Place the "LEVEL TRIP" switch for affected channel in "BYPASS".
- b. Verify the "LEVEL TRIP BYPASS" light on the affected I/R drawer - LIT.
- 5. Verify the affected IIR I/R channel trip (1SI-19) - LIT.
bypass status light (151-19)
- 6. Verify 1AD-2, C/4 Cf4 "NIl SYS SIR & IfR TRIP BYPASS" - LIT.
- 7. Ensure the "NIS RECORDER" - ALIGNED TO THE OPERABLE IIR I/R CHANNEL.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/SSOOI016 AP/1/A15500/016 9 of 14 Case III DC~ Rev 24 DCS Intermediate Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. WHEN the operable IIR I/R channel is less than 10-10 Amps, THEN ensure SIR channels are reset.
- 9. Determine and correct cause of IIR I/R malfunction.
- 10. Ensure compliance with Tech Spec 3.3.1 (Reactor Trip System (RTS)
Instrumentation).
- 11. Determine required notifications:
- REFER TO RP/O/Al5000/001 RP/O/A/SOOOI001 (Classification Of Emergency)
- REFER TO RP/O/B/5000/013 RP/O/S/SOOOI013 (NRC Notification Requirements).
- 12. Notify Reactor Group Engineer of occurrence.
CAUTION Installing IIR fuses with any P/R channel inoperable or in a tripped condition, may result in a reactor trip on P/R rate trip due to voltage spikes.
- 13. WHEN the affected IIR I/R channel is repaired, THEN ensure IAE returns the channel to service.
- 14. Determine long term plant status.
RETURN TO procedure in effect.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 AP/1/Al5500/016 10 of 14 Case IV Rev 24 DC~ Power Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions ROo DOES THIS PAGE -0 Verify all rod motion - STOPPI;O. _ IF unwarranted rod motion is occurring, THEN place "CRD BANK SELECT" to manual.
- 2. V~rify 1 AD"2~ Et8 "OVER,'POWER ROD _ Adjust Turbine load to maintain T-Avg at STQP".;, DARK. T-Ref.
3.
- 3. II:IMmHi1lfiio'i'IIfi'ifI%P/Rh"':"P Identify failed P/R ch~nnel:
L"~'J>>,'!.JpJ,~~_,,.9 a,.mi\~Jj'
- N-41 OR
- N-42 OR
- N-43 OR
- N-44.
- 4. I;nsure unaffec.t~d channels;"
OPERABLE.
- 5. Request IAE to place th~~following bi~tab,J~s in the trippedconditiori.
REFER'TOMode.1 W/O #OQ874531:
- OT DELTA T
- OP DELTA T;
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 AP/1/A/5500/016 11 of 14 Case IV Rev 24 DC~ Power Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. Perform the followingaction~ at the e.E!tlI'p.~mtli~fpllowing.apti()/'1§iMtl1E!
l\(1ispglJ~ngotisiQontrptAnd]nmQatiprl Miscellaneous Control Andlhd!cation IBOP DOES THIS PAGE Panel: I!
- a. Plac~
PI~~~it~e.".*gpprQP~I~te*.*"RQ(l}§IOp tl:1e appropriate "ROD STOP BYP~SS'~. switcl1** BYPASS" switchto *.Jo***tpe*** the affe.~teg affected
¢paOOel.***.P(;jsitl(;jo*;
channel position.
'0grify*llJe*gffg¢tedf1~.¢I~pr*.*Ove~p(;jWefj
- b. Verify the affected nuclear overp,ower f(;jo*i.s1gpolJantiel*.*bypasseO*.statl;Js.ligpt
~pdstop channel bypassed status light (181;'19) - LIT.
(~*§I~'9t:'.f"IT. PIl1\~e~!PQWoBMI$MAIc;.lTIiByp~SS1l
- c. Place "POWER MISMATCHBYPASS" sWi~¢IJ*t()toe switch to the affected affecledehl1\ti.rlel**.PQsi~i(;jti;**
channel position.
- 7. eetll'Q~rotl1efpU()win;gactioo~i~ttlJ(e Perform the following actions at the
[)etE!Qt()t'QtJttetttQ()l)1parat()~R~f1:E![; Dete¢Jor Current Comparator panel:
- a. PJaee.f!UlPPERSEc;TIOt'll'ehantiel a.; Place "UPPER SECTION" channel defe?t defeat * $Witcpt().toe.
switch to the affeetegelJanneli affected channel. b: VePify.itl3e**"@I:1~t'lt\lEL[)8rEAm'rl
- b. Verifythe "CHANNEL DEFEAT" light i~jh~
fQrtl3.e IJPPetisec:~i(;jn****;.**.***LIT.. for the. *. upper section - LIT. c:
- c. Place PI$ce "LOWERSEECTIOt'lcParl);iel "LOWER SECTION" channel defealsWitc:o*lo.tbeaffectedehannel, defeat switch to the affected channel.
V~Fify.*.the"@rJ,.xt'lt\lEL;(l}EI7~m"****.ligjht
- d. Verify the "CHANNEL DEFEAT" light
.fotthe.IQWg!"Y$ectiQrl~*****LII:
for the lower section -LIT.
- 8. At theComparator.~nd Rate pan~l, place At.itl1e*Q()mB~~~t()~.~l'1d,*RatE!iBariE!I;'BI~QE!
the "COMPARATOR CHANNEL *. DEFEAT" the**!'Gf>>MBARAjf~R*GHANNEL* [)ElmEAjf~; s'!li.t.Qlitp::i.tl1e:aff~Qtef,l*QI1~tlnE!l:pp§jti()tli sWitch t()Jheaffected channel position.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/1/A/55001016 AP/1/A/5500/016 12 of 14 Case IV DC~ Rev 24 OCE Power Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
'BOP P DOES THIS PAGEl N@TB m~§f~illo~If';lg~nh.unclatQti§~ill,89tuat§(,in;It1~'.*fQI1Q~if';l9~t§mi The following annunciators will actuate in the fbllQwing step: EPT LAST STEP i CEPT 1AO-2, A/1 "PJR HI NEUTRON 1'~1il4~iA/{t!:m!/Rifll* NEgmR~N'5L:g);({~mp&L*pIRm" I5LUXRi\TE ALERT" A/3. n P/R HI NEUTRON F.LUX HI. S.ET POINT ALERT" 1A'1il~2;.wag'HMRfll*'f\J.Egm80N***IjEL:giKfllI:~pmRQ1NlA'LER]"
1AD-2, 1.~[JJ2,** . BJ5"P/R 1AO-2, HI VOLTAGE FAILURE' B/~IJ1'R/Rihi*I'YOlSmA'Gp'P"A'I.L:lgR~!* {.~~1il-2,E/~.ll'<g'\l'ERP~VJlpRR~Q"'.~W~PIf; 1AO-2, E/8"OVER POWER ROO STOP", 9."pe~eilie~gi~e.ilfie~lectedi¢fi~.nilie!~~
,9. De-energizlftheaffectedchannei as follows:
a*RernoV~III~~~IHQf';llr()l.mQ~~*[fU$~§~t
- a. Remove the control poWer fuses at m!Q~~n'IR~'Q9~'A'11'9ra\}len; Power Ra(lge A drawer.
N@TB ofthe affected P/R control power fuses .* ~IJ;l~IJ*1'l9tQ9qurV!(ith*out R§pJaQ§,!1!ij§Qt()f'(Ii§~ff§Gt§9g/RIC()r1trolim()wenlfu$~~ Replacemerit shall' notoccur without al:Jth()ri?i~ti'or:l' .*qfitn*e~Qm~rinten9.~m~9fQmeta.tiqr:l$or authoriz.ation oftheSuperintendent of Operations or his J;lj$(jesig[fjee: desigriee~ R~g!-le$t*. the
- b. Request th~Q~M.torQfllr1~aintli§ OSM to mailltain the 9or1~tolpQW~(fl:J~~suf';ld§t*.*hi$9Qr1troL control power fuses underhis control.
Verifythe~ffected Power Range c.'\l'§rifyl~§.i~ffe9t§(j*'*.Pow~tRa.nge
- c. c. Remove the instrument power fuses at C~l:>im§t'$bp~$>r1Q*PnY$i¢l:.lI$lg.n$
cabinetshpws no* physical signs *bf of Power Range B drawer. damage. 9~lTIag~; 1O.
- 10. er1~t:!te~le¢le9¢fi~t1t1~lbi~t~ble~~teit1 Ensure affected channel bistables are in tlie**.l'eggrted~t~leP)RBI7BRT@;eili¢IQ~gt~
the required state. REFER TO Enclosure 1:;1{6I~RJ;Jist~b.le§;\rnn~li;Mg§1*J;Je 1i{P/R Bistables:rhat;:MustJ;3e rntippe9}* Tripped).
- 11. et1~t:!teil~I~;{Ree(l:JR~E;R;:;~Se1+ee]eQ Ensure "NIS::R,ECOR,OER~'- SELECTED TO AN QPERABJ,.,;E:P/R:.CHANNEL...
m.~~N@.6I.eRl¥J;JJ41e:P/R'el;l~~N.el:S
- 12. A'dJg$1*¢Qt1.tfol.,tQ9~tQ~Q'iait1t~It1:lrnrA'~e**~t Adjust controlr(jds tolrnaintci.in T -Ave~at _ 117 rods will not move in manual, THBN IF THEN
,[,"Ref~
T-Ref. adjust turbine load to maintain T -Ave at T-Ref.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/11A155001016 AP/1/Al5500/016 13 of 14 Case IV DC~ Rev 24 DC!: Power Range Malfunction ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 13. WHEN T-ave withirt 1;~F of T-Ref, AND a4(0 rod control desir~d, THEN r:~turn control rods to auto.
- 14. Determine and correct cause of P/R r:nalfunction.
- 15. Ensure compliance with appropriate T8 3.3.1 Items 2a, 3, 6, 7, 16b, iTS Tech Specs: 16d, 16e Conditions D,E,R,8 D,E,R,S
- 3.2.4 {Quadrar'ltPower Tilt Ratio (QPTR})
- 3.3.1 (Reactor Trip Systeni{RTS)
Instrumentation }.
- 16. .gl~i,!ijlitf~fteqftt~t:lNpmjfJ.V.n~~.
Determine required notifications: _ .:~~~;§~~~~lOJ~~_'Q~,
- REFER TO RP/O/Al50qO/001
*t.~le'~jt£iW~iSnO~Iifi!i'l:;o'm~nc:
(passificcltion u~!ij",,!y! .. ~1.:~, Of
....*..*..Emergency) "~.
dJ,'lR~,.,JI('" _ ",']
* ;B6RREFER __ TO\~,~{~Z,~li,('tt!."i:~
RP/O/B/50001013 (NRC
;K<1tJf~llllitEi.tJlf1I!lfl~l$J Notification Requirements}.
- 17. Ngti,fy;:Reactqr Group3Engineer Of occurrence, 18" WHEN the affected P/R cl;1annel is repair~d, THEN ens4r:~ I~E returns .tl;1'e chaJ'lneltos,er:vice,
- 19. Determine long term plantstatus.
RETURN TO prC:ic.edutein e,ffect.
CNS MALFUNCTION OF NUCLEAR INSTRUMENTATION SYSTEM PAGE NO. AP/11A155001016 14 of 14 Enclosure 1 - Page 1 of 1 Rev 24 DC~ P/R Bistables That Must Be Tripped 11.* '~.' **"i;WiKiJlli.'eL'£~nillm.*.**. Ensure the folloWing ":'l!i~'J1.HBi+~'F~il**,
~~~~W\\~.* ",.[?J!i!I"I1"tt~~~~lllMl'§Y'reacfQttrip system interlocks in requiredstafe (1SI~18) for existing
'.' feF'~'?*te[l6'~ifi*re..,tJitetl~+e:*(!I'SI:SlA'lfo.liWa'~*s*
.JfliKUll ........ ~~~".".. .. ..... ' ...., .. ~'%.~+".,. t'ln'~\
..... S;~4, ... ~f£"L...... 'l!J!
*g:Ii:l[W.l\tl)li~t~'filifl'*n'Am unit conditionswitl;lih 1 hour;
- P-z JI;"Yr
~*.p~a
~f¢;Bt9;
.' P-9
_ Jl;flfJlfJI
- P-10.
- 2. Ensure the following bistables for the,affected channel are placed in the~li;ippedcondition within 72 hours,';
- NC loop OTDT~reactor trip status light(1SI-7} -lilT
- NC loop OPDTreactor trip status Iight.(1SI-7) - LIT.
Th~tfollqwing bistable's can only be as~ured to stay,;in the tripped condition by the re'mOval 'of the?ffected changel's control power fus$s.
- 3. Ensure the folloWing bistables for the.~ffected chaimel are in the trippedcopditiQI1 within 72 hours:
- P/Rhigh,flux low setppJntstat4s,t1jght(tSI-3):-UT
- P/R highflllx hi9i:l s~tpoint st~Jusiilight (1.SI:-3)- LIT
- PIRhigh flux r.ate'status IigtW(1SI-3) - LIT.
Duke Power Company Procedure No. Catawba Nuclear Station API l/A/5500/014 l/A/SSOO/014 Revision No. 015 Control Rod Misalignment Electronic Reference No. CN005CEI CNOOSCEI Continuous Use PERFORMANCE I
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
(ISSUED) - PDF Format Iinitiating Initiating Cues: I-* 1AO-2, 0/10, Rod Bank ORANGE background on ORPI display
CNS CONTROL ROD MISALIGNMENT PAGE NO. AP/1/A15500/014 AP/1/A/55001014 1 of 7 1of? Revision 15 A. Purpose
- To verify proper operator response in the event one or more control rods are found to be stuck, misaligned or dropped.
B. Symptoms Case I Control Rod Misalignment
- f9,ll(Il_tlIIJ~¥(~illrl'O Nil indication of flux tilt
* <<atl(.fl(.if,:gY.1(fif~.~'!.i~.~l'II~Jk1lDim Ind'ividual rod(s) greater than 12 steps from bank po-sition
* '11IlB:lI'fltMl?~_tl.lRIJjIJ:&fj_llfll~'lJ 1AD-2, B/3 "COMPARATORP/R CHANNEL DEVIATION" - LIT
....* 1AD-2, B/1 "P/R LOWER DET HI FLUX DEV*
;~iA,~'~.l:BJ,~~i*tl§t11t;lll{lttil OR* 1I'1;_~f~lII?
AUTO DEFEAT" - LIT
- .~,
- tll;~1Il?*'~Rl~.,p~R~Qe.J'~f2*1ll~.tla~ltlflt;Jt<<ail~lt*')~;:f211f 1AD-2, B/2 "P/R UPPER DET HI FLUX DEV OR AUTO DEFEAT"- LIT.
Case II Dropped Control Rod
- 1AD-2, A14 Al4 "T-REFIT-AUCT HI/LO" HIILO" - LIT
- Sudden decrease in T -Avg
- Turbine Load - DECREASING
- Rod bottom Iight(s) light(s) - LIT
- 1AD-2, D/9 "RPI AT BOTTOM ROD DROP" - LIT 1AD-2,
- 1AD-2, E/9 "RPI TWO OR MORE RODS AT BOTTOM" - LIT
- NIl indication of flux tilt Nil
- 1AD-2, B/3 "COMPARATOR PIR P/R CHANNEL DEVIATION" - LIT
- 1AD-6, F/8 "PZR LO PRESS CONTROL" - LIT
- Unexpected Rod Withdrawal.
CNS CONTROL ROD MISALIGNMENT PAGE NO. AP/1/A155001014 AP/1/A/55001014 2 of? Case I Revision 15 Control Rod Misalignment ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions DOES THIS PAGE -GD Verify~dhly'onero&~MISALIGNED. IF two or more rods are misaligned by greater than 24 steps, THEN:
- a. Manually trip Reactor.
- b. GO TO EP/1/A15000/E-O EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).
- 2. Ensure "CRD BANK SELECT" switch -IN MANUAL.
- 3. Verify affected rod bottom light($)- _ IF rod is dropped, THEN GO TO Case"Case II DARK. (Dropped Control Rod).
- 4. StopanyJutbinelQad changes in progress.;:
- 5. Adjust turbine load to maintain T ~Avg within 1°F ofT-Ref.
Weithet)'Data A F~ilurelfor "Data B Failure" is indicated, and the "No Urgent Alarm" block is green, then the affected individual rod. ppsitioniJ:\oicationswiII be in the "Half Accuracy" mode proyiping12 step increrneptposiW'>n indication instead of 6. Individual rod positi9,6;:iQdication'may~jffer by as much as 10 steps from grQup step counter indicatiljJn!
- 6. Verify any of the following DRPI _ GOTOStep 11>
indications -IN ALARM:
- Data A Failure OR No DRPI alarms.
- Data B Failure.
CNS CONTROL ROD MISALIGNMENT PAGE NO. AP/11A155001014 AP/1/A155001014 3 of? 30f7 Case I Revision 15 eqolrql!R~~;Mjsaii9omeQt C()ntrol Rod Misalignment ACTION/ExeECTED RESPONSE RESPONSE NOT OBTAINED
?7. Determine affected rod(s) by at least one of the following:
- Individual rod display is yellow or red
- Rod Bottom light - LIT.
- 8. Request IAE to investigate and correct cause of DRPI malfunction. REFER TO AM/1/A151 AM/1/A15100/003 00/003 (Troubleshooting Cause For Invalid DRPI Indication).
DRPllndication).
- 9. WHEN rod position indication has been restored, THEN:
- a. Verify all rods - ALIGNED. a. GO TO Step 11.
- b. GO TO Step 15.
- 10. GO TO Step 15.
11.Eg~~~~.f°rij~*II~gq~Y(i~haRllrQpriat~
- 11. Ensure,complii:mce with appropriate TS 3.1.4 Condition B
- Y:ggt1i~p~.c~:
TechiSpecs: I
***.. :a1.1;.1($h~t~qYvfu.N1gtgin.(~~.N1)
_ . ..3.1:1 (Shutdown Margin (SDM>> _ ~i
.**~i1**.4.*(Roq~~Q~~~1 igl")fu:l~Fi.tl4.ir:hitS) 3.1.4 (Rod GroupAlignn1tmtLimits)
* ~~:;l;$*l~~(itdQYvhaaFiI<\I.(:i~~*rtfOn.t:;ir:hit}
3.1 5 (Shutddwn Bank Insertion I..,imit) I
- 3.1.6 (Gontrol Ban~* *.*lnl?~~iq£lJLimit~}
*.$11*6(.Qq(;jtnql~1;I(:i~ Insertion limits)
* ?1 *. f[.{f{qqeq§{t!~hlfu~r~liqO*)
3.1.7 (RodP9sition Indication)
* <~*:~*;$~~lal**.RI~~i.~itt~rgO~~(~RQ.})
3.2:3 (Axial Flux DiffereQce (AFD>>
*******~:1~.~*(Qp~af!~otpClw~r[lit*R~ti()*
3.g,4 (Quad rant Power TilfRatio' (~~T~)} (QPTR>>
- SLC 16.7-.11' {position Indication System
- Shutdown).
- 12. ***eaclq~~[a~Rl;QgiQ~~r**o~
Nc)jllY.ReactorGroup Engin~er of occifrrence. nce:
CNS CONTROL ROD MISALIGNMENT PAGE NO. AP/1/A155001014 AP/1/A/5500/014 4 of? Case I Revision 15 Control Rod Misalignment ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 13. D~termine and 13.Det rlctcorrecfcausedftdi:f correct cause of rod misalignment. I'm
- 14. Me Verify the affected rod(s) are operable as foil follows:
- a. Verify1AD~2,8f&1*1:qIl!~@W**.*<k@tiJ7rRG)L, A/10 "ROD CONTROL a. GO TO AP/1/A/5500/015 AP/1/A155001015 (Rod Control All"lag~n*. -~iWAR~:
URGENT FAILURE" DARK. Malfunctions), Case I (Failure Of Rods To Move). b.ffl.~~1
- b. ~t~d.J'()~,
Realign'affected '!~.EER.ro rod. .*.REFER TO GI?! @Z@OB(R~gQ~ntr~U; OPJ1JAl6150J008 (Rod Control). They will not be allowed to retrieve the rod.
- 15. Determine required notifications:
- REFER .TORPJOJAl50001001 (ClassifiCation OfEmergency)
** REFER TO RP/O/B/50001013 (NRC Notification Requirem'¢hts). ~I6; 16; Det~rinine,lor1g Q~~~lJ)"Ii*O~:I~~.~*.te term plantstatus.
RErURN RETURN .*mO TO * *Pfoce procedure in effect.
CNS CONTROL ROD MISALIGNMENT PAGE NO. AP/1/A/5500/014 5 of? Case II Revision 15 Dropped Control Rod ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions -0. Verify only one rod - DROPPED OR MISALIGNED. IF two or more rods are dropped OR misaligned by greater than 24 steps, THEN:
- a. Manually trip Reactor.
- b. GO TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).
- 2. Ensure "CRD BANK SELECT" switch -IN MANUAL.
- 3. Adjust turbine load to maintain T-Avg within 1°F of T-Ref.
- 4. Verify 1AD-2, Al10 "ROD CONTROL Perform the following:
URGENTF~LURE"-DARK URGENT FAILURE" - DARK.
- a. Do not move control rods.
- b. IF AT ANY TIME reactor power must be reduced, THEN use boron to reduce reactor power.
- c. Dispatch operator to Rod Control System cabinets to determine location of failure.
- d. Request IAE to perform the following:
_ 1) Determine and correct cause of dropped rod. _ 2) Reset alarm.
- e. WHEN the "ROD CONTROL URGENT FAILURE" alarm is reset, THEN control rods and boron may be used for power changes.
CNS CONTROL ROD MISALIGNMENT PAGE NO. AP/1/N5500/014 AP/1/A/5500/014 6of7 Case II Revision 15 Dropped Control Rod ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Excore nuclear instrumentation may be skewed by dropped rod.
- 5. Use OAC point C1 P1385 (Reactor _ Use delta temperature indication to Thermal Power, Best) to determine estimate reactor power.
reactor power in subsequent steps.
- 6. Verify the following - WITHIN TECH SPEC Reduce reactor power as required by LIMITS: Tech Specs per one of the following:
- AFD (Tech Spec 3.2.3) _
- OP/1/N61 OP/1/A/61 00/003 (Controlling Procedure For Unit Operation)
- QPTR (Tech Spec 3.2.4).
OR
- AP/1/A/5500/009 AP/1/N5500/009 (Rapid Downpower).
- 7. Ensure compliance with appropriate Tech Specs:
- 3.1.1 (Shutdown Margin (SDM>>
- 3.1.4 (Rod Group Alignment Limits)
- 3.1.5 (Shutdown Bank Insertion Limit)
- 3.1.6 (Control Bank Insertion Limits)
- 3.1.7 (Rod Position Indication)
- 3.2.3 (Axial Flux Difference (AFD>>
- 3.2.4 (Quadrant Power Tilt Ratio (QPTR>>
- SLC 16.7-11 (Position Indication System
- Shutdown).
- 8. Notify Reactor Group Engineer of occurrence.
- 9. Request IAE to investigate and correct cause of dropped rod.
CNS CONTROL ROD MISALIGNMENT PAGE NO. AP/1/N55001014 ? of? Case" Revision 15 Dropped Control Rod ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. Determine required notifications:
- REFER TO RP/OIN50001001 (Classification Of Emergency)
- REFER TO RP/O/B/50001013 (NRC Notification Requirements).
- 11. Verify reactor power - GREATER Perform the following:
THAN OR EQUAL TO 5%. A shutdown is performed to avoid the risk of mode change while recovering the dropped rod.
- a. IF any control bank is withdrawn, THEN begin unit shutdown to be in Mode 3 within 6 hours. REFER TO OP/1/N61 001003 (Controlling Procedure For Unit Operation).
- b. IF dropped rod is in shutdown bank, THEN insert shutdown banks after control banks have been inserted.
- 12. Do not continue until any required power reductions are complete.
- 13. WHEN the following conditions are met, THEN retrieve dropped rod. REFER TO OP/1/A16150/008 (Rod Control):
- Steady state plant conditions
- Rod control problem repaired.
- 14. Determine long term plant status.
RETURN TO procedure in effect.
Initiating Cue:
-1AD-6 C/12, E/10, F-8 le1AD-6 NC Pressure decreasing INC I
I I I I I ~----~--~------~~------------~----------------~
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 1 of 9 DC~ Rev 22 DCl: A. Purpose To ensure proper response in the event of abnormal Pressurizer pressure, assess plant conditions, and identify the appropriate steps for the following cases: Case I Pressurizer Pressure Decreasing Case II Pressurizer Pressure Increasing. B. Symptoms Cas~, I. pressurizer Pressure Decreasing:
.1;/;f.ID:';Q;)E:/10***IfB4~PO~'VIDJSGH*.*****f'fJi*TEMP:'.+rl.:.t:r
- 1f\D-6;E/10 "PZR PORV DISCH HI TEMP" -LIT
- 1AD-6iE/11 1.*lAS';Qi.'::E/1.*.1.,,**IIB4~iSAf360]¥IJ')ISGIHARGE.*IH[TE:MB'!":,*,*Llo]
"PZR SAFETY DISCHARGE HI TEMP" - LIT 1/;f.SP*Q;r/13"pZRI.;(i)'PRE:S8G.a~TR0L" ." 1AD-6, F/8 "PZR LO PRESS CONTROL" - LIT
- 1AD-:-6,
)llAS"Q,/AlS "PZR HI1"*PRE:8SAI.;E:RT~!*
AlB "PL:Rf'f PRESS ALERT" '*~1:.;1:r
- LIT
- An:BZlnh.$~ter$-E:NIEHGIL:EID}
.". All Pzr h~aters - ENERGIZED 1/;f.ID7.Q';.?:D/1411B4RI.:.0\.BRE$S"B0R'ilNG3J4.**'E3.1.;0C~EDIf
- 1AD7S';:D/11 "PZR LO PRESSPORV NC34 BLOCKED" .... - 1.:.17]'
LIT"
- 1AD,.6, 0/10 "PZRLO
.1AID4Q\IDI10* "B4~L.0 *.*BRE:8S* .B0R'ilNG~~'>~I~6**.E3I.;OGl<lE:ID~'+LI:r PRESS .*PQRV NC32'& 36 BLOCKED" - LIT
- Pre.ssurizer pressure less than 2235 PSIGand decreasihg Case II. Pressurizer Pressure Increasing:
- 1AD-6, 1AD~6, D/8 "PZR LO PRESS ALERT" -~ LIT 1AD~6, C/8 "PZR HI PRESS DEV CONTROL" -~ LIT
- 1AD-6, 1AD~6, B/8 "PZR HI PRESS" -~ LIT
- 1AD-6,
- Pressurizer pressure greater than 2235 PSIG and increasing
- All Pzr heaters -~ ENERGIZED.
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 AP/1/A/5500/011 2of9 Case I DC~ Rev 22 DCS Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. C. Operator Actions fBBP---l BOP -0 Verify all Pzr PORVs - CL~SED. ' Perform the following: Manuall~AIO$e~~r:80RV(s):
- a. Manually close Pzr PORV(s).
b..IRaijy~~('~ORMQgnn~t.beCld~eq, b IF any Pzr PORV cannot be cldsed, PORV will stick before it gets rpORV THEN: l'HEN: full closed. _ CIQ§~iffje:~ffeQt~qP~RV{~)
- 1) Close the affected PORV(s) isolation valve.
isolettlonvalve.
- 2) IR IF the Pzr PORV isolation valve cannot be closed, l'HEN THEN perform the following:
_ IR in Mode 3 with CLAs isolated a) IF OR in Mode 4, l'HEN THEN GO 1'0 TO AP/1/A155001027 (Shutdown AP/1/A/5500/027 LOCA). _ b) l'rip Trip reactor. _ c) WHEN reactor tripped OR S/I SII setpoint reached, l'HEN THEN ensure S/I SII initiated. _ d) GO 1'0 EP/1/A15000/E-O TO EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 AP/1/A/5500/011 30f9 Case I Rev 22 DC~ Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Control rods mawwithdraw on*decreaSing NCpressure.
- 2. Vei;ify Pzr;;sp(ayvalve(s) - CLOSED. Perform the following:
- a. Manually close affected spray valve(s).
- b. IF affected spray valve(s) will not close, THEN perform the following:
- 1) IF AT ANY TIME the Control Room Supervisor determines that a reactor trip is required, THEN:
_ a) Trip reactor. _ b) WHEN reactor power less than 5%, THEN stop NC Pumps 1A and 1B. _ c) GO TO EP/1/A15000/E-O EP/1/A/5000/E-O (Reactor Trip Or Safety Injection).
- 2) Select "FAIL CLOSED" for affected spray valve(s) mode select switch:
* "1 NC-27 PZR SPRAY VLV MODE SELECT"
* "1 NC-29 PZR SPRAY VL V VLV MODE SELECT".
_ 3) IF NC pressure is stable OR increasing, THEN GO TO Step 3. (RNO continued on next page)
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/11A155001011 AP/1/A/5500/011 4 of 9 Case I Rev 22 DC~ Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. (Continued)
- 4) IF NC pressure continues to decrease, THEN:
a) IF in Modes 1 or 2, THEN: _ (1) Trip reactor. _ (2) WHEN reactor power less than 5%, THEN stop NC 1A and 1 Pumps 1Aand B. 18. _ (3) EP/11A15000/E-O GO TO EP/1/A/5000/E-O (Reactor Trip or Safety Injection). _ b) Stop NC Pumps 1A and 1 B. 18. _ c) IF NC pressure continues to decrease, THEN stop additional NC pumps as required. _ d) REFER TO AP/1/A/5500/004 AP/11A155001004 (Loss of Reactor Coolant Pump).
- 3. Verify.all Pzr heaters - ENERGIZED. _ IF Pzr pressure is less than 2220 PSIG, THEN ensure all Pzr heaters are energized.
BOP
- 4. EnslJr~ 1NY-:37A (NV Supply Topzr * ~gX
**elj~gt@~N.yt~'!,.7f!.(N\y§gllll.!Y:]Q.R~t.* Aux
.§p*t~Y;);~
§pray),;* Cl#~a.l!al; CLOSED~
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/A155001011 AP/1/AJ5500/011 5 of 9 50f9 Case I Rev 22 DC~ Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Positive reactivity is inserted during an increase in NC pressure which may cause auto rod insertion.
- 5. Verify NC pre$5ure" STAB.LE OR _ IF pressure continues to decrease, THEN INCREASING., REFER TO AP/1/Al5500/010 AP/1/A15500/010 (Reactor Coolant Leak).
BOP
- 6. WHENiNC pressure is stablejTHEN:
- Stabilize;junilatappr()'priatepQwer level.
- Adjust the following as requiredto rnaintain T~Avgwithin 1°FbfT-Ref:
- Turbine load
- Control rods
- Boron concentration.
- 7. jl.~1tj~t~i&nti)lO~JA11fl~1!I"'&N' IF a Pzr pressure channel failed, THEN perform following:
"P~11 PZR SII BLOCK
- a. Verify "P-11 a. Ensure compliance with Tech Spec PERMISSIVE" status light (1SI-18) in 3.3.2 (Engineered Safety Features required state for unit conditions. Actuation System (ESFAS)
Instrumentation ).
- b. Notify IAE to fail following bistables for affected channel per Model W/O
#00874531. Bistables shall be tripped within 72 hours:
- Pzr low pressure SII
- OT Delta T
- Pzr high pressure Reactor Trip
- Pzr low pressure Reactor Trip.
CNS PRESSURIZER PRESSURE ANOMALIES PAGE NO. AP/1/Al5500/011 AP/1/A/5500/011 Case I 6of9 6 of 9 Rev 22 DC~ Pressurizer Pressure Decreasing ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. ef1sqr~~9mpli~Q~ewith'appr9priat~
EnsOrecompliance with appropriate Tectl}Specs: Tech Specs: 3A.11 Condition B TS 3..4.11 T8 3.3r1{gE¥gct&r1iftl/,1§ystem~g'f$)
- 3.3.1 (Reactor Trip System (RTS)
TS 3.4.1 T8 3..4.1 Condition A (based on NC dstf:~ffl'E¥'hl?ti&riJ Instru mentation) pressure at the time)
- 3i~3.2i{eng.ih~e(ed$?f~tYI7.~atures
.3.3.2 (Engineered Safety Features ActU?~i(')D$ysfepl{E$FJXi.$)
Actuation System (ESFAS) lri§tt~,ffleot?tidl')) Instrumentation)
*.3:~;~'{IrQ§tJXi.ccj(.'f§n~'M9rlltQftrrig~IrAN1J 3;3:3 (Post Accident MonitQi'ing (PAM) n$tr~th§ri~atiQI')
IInstrumentation)
- 3.3."4 (Remote Shutdown Sysferr\)
- 3.4.;n:{gSJ?fte§§~rE¥(
3A.1(RCS Pressure, Teffl'pE¥t?t~t§jq:rJt:l Temperatur~,and FloW:i:)E¥/,1a[tu(eF[Qrl1' FlawDeparture From *.*NuclE¥atE¥lio.iJjrng Nucleate Boiling (~t}JIi)eiti1its) (DNB) Limits)
- 3'4.4.{g(3$j'L..()op$.Ht)?10DES1iadd~~
3.4.4 (RCSLoops ... MODES 1 and 2)
- 3.4;5(gGS.l;:d&p~:5N1Q~E*.*
3.4.5 (RCS Loops- MODE 3)
*.3j.4.q~g(3$L..o&Ps""t)?100E4.>
3.4.6 (RCS Loops -MODE4)
- 3;4.i;9(P('§$Sl.!tiz~r) 3A.9 (Pressurizer) 3A;1Qi'<lrftE¥$~~rtzE¥r$afltY*
- 3.4.10 (Pressurizer Safety Valves) Vah(E¥$~}
3.4.11. ,~**.****(lrr~$$~ri:ZEiUi)pC;>Wlr~peuatet:l**
- 3:411' (Pressurizer power Operated ReliE¥fVa!¥E¥$~,~IrQg~§))
Relief Valves (POR\ts>>
*.3;4r13{gG$~p~r?~ional***
3A:13 (Rep Operational
- Leakage). Le?!g?gE¥).
9.
- g. ~,eteJjmif1~19ng:i!erm/,1Jal'lt*$!alY§:
Determine longtel1l1plant status, RETURN 'TaPr9Q~tlyr@In~ff~~!~ TO procedure in effect.
~--~--"--. ------------------~--"'-- Initiating Cues:
*e 1AD-5, 1AO-5, Af1, Af4
- 1AO-1, F/4 1e1AD-1, Turbine load decreasing ITurbine I
CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 AP/1/Al5500/003 1 of 36 DC~ Rev 36 DCE A. Purpose CA~E I S;iNitchyard Available:
- To verify proper response in the event of a Load Rejection with Unit Tie Switchyard PCBs closed and the switchyard is available.
CASE II Switchyard Not Available:
- To verify proper response in the event of a Load Rejection with all Unit Tie Switchyard PCBs open and/or the switchyard is not available, with the Unit carrying it's in-house loads.
CNS LOAD REJECTION PAGE NO. AP/11A155001003 AP/1/A/55001003 2 of 36 Rev 36 DC~ B. Sympt(jms B; 'Symptoms CASE t CAs*e*., §witgfjYijtt:!~vaU,aBI.e: Switchyard AvaiJable: SWitGhyard energized .AND any Switchyard. ::*,tJMi"mie,*.F"Q,E;}@I,psedAN:D:
~W,i,qby~~a:emergi~ei:l,r~N.J),*.'*a,f1Yf?WitchYal"a UniLTie PCBc.iosed AND:
- 1AO-1, F/4 "TURB.RUNBACK INITIATED"- LIT
- Turbine GeneratOr megawattoutput -.RAPIDL Y DECREASING "e21:'AI..Qf?~,QFL;Q'A~,I.f:'J.m.l..f<iQQrsJ~I)UM~l!?tatcr~lig!;l1~@~1"'1~),-.Llm
* "C-7A LOSSQF LQAD INTLK CONDDUMP" status light(1SI-18)-LlT
* '!e7:z!l3l.QSS*'.QF'.':I..Q~~'
"C-7B LOSSOF LOAD
- INTLK ATMOS * *'.DtJt0,F"r*,!;)tl:ltcr~l,ig!;lt~~*SI-1
[rsJml..15.AJ"t00S DUMP" status light (1SI-18) * ~)*-'Ll.m
- LIT *Copd,el"lseI"6t.atthp~P;!;lerip$t(:)ath:"'.Oqmp\Ja'Ve~;***QE:!;r~J
- Condenser or atmospheric steam dump valves - OPEN
*** Any load rejection. occurring Or;isireq
'Af1Y:lp~i:lrejec.tiQf1i"pccl.ir~iMg, uirei:l or is required
'. Control rods - STEPPING IN.
CAse CASE II Switchyard Switch AvailaBle: yard Not Available: Switchyara Switch yard not available AND:
- 1AD-1, F/4 "TURB RUNBACK INITIATED" - LIT
- Turbine Generator megawatt output - RAPIDLY DECREASING
* "C-7A LOSS OF LOAD INTLK COND DUMP" status light (1SI-18) - LIT * "C-7B LOSS OF LOAD INTLK ATMOS DUMP" status light (1SI-18) (1 SI-18) - LIT
- Condenser Conaenser or atmospheric steam dump aump valves - OPEN
- Control rodsroas - STEPPING IN.
CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 3 of 36 30f36 Case I Rev 36 DC~ Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. C. Operator Actions EO RO DOES DOES THIS THIS PAGE PAGE _0Ve~ifY!I.Jf't:JiQQ:IP~c:f~PJ;~REA~ING _ t7). Verify: turbine load - DECREASING IN Perform the following: V AUTOMATIC.
- a. Select "MANUAL" on turbine control panel.
- b. Depress "CONTROL VALVES LOWER" pushbutton and reduce turbine load as required.
o 0"erifY pt'pp'Q:ri:fjQ:agtPr:.fjQ:~ppn~Q:: Verify . proper reactor response: ControLrods-IN.'~AUTO"
- C.QrltrQbtQc:fSL;-.i l N;'IJiXU:J!01'ANID AND
_ J17m~AVg"'.*i.~ IFT-Avgis. greate*fj!Jjan1.5':!17 higl:lC~r greater than 1.soF .*nighQ:r than T-Ref, THEN manually insert c:ontrol ttlaQ,'.T";RQ:fiTHENman*lIa!JY*iosefjt'c;qntrol tpc:fsa~t~Cjuiredt()maifltain'" rods as required to maintain T7 AV9 cWitnin T-Avgwithin SmEPpIN~iIN STEPPING IN 1~EofT~Ref. 1"F ofT-Ref.
.: P/R neutron flux - DECREASING, IRods Rods fail to work in AUTO l
- 3. V~fjifYipr:pp~tst~a!fi.(lqmp.:qP~f'ati()na~
Verify,propersteamdump operation as follows:
- a. Verify V~rifY'i':-;IHI3~f*.*iJ1lWuitj~J1t~~iQJ1i~.
T.,Hef instrumentation- a. IF117 T-Avg Coastdown is in progress, AVJiXIL:.A:I3L AVAILABLE;. E:; THEN determine T-Reffrom T -Ref from table. REFER REmER TO Enclosure 4 (T -Ref Value Following Runback/Power Reduction). 17ollowing "C..,*Q*C0NiIDJiXV;JiXliL:.A:I3I:.i.E.F013:'SmM
- b. "0*9 CQNE) AVAILABLE FORSTM b. Perform the following:
DLJMpH:*,st.Ei!4S)IJg*h;tt!:1:iSI~1.*~);~l2lm.; DUMP":statuslight (jSI.,18)7L1T; _ 1) Manually operate S/G PORVs as necessary to maintain T -Avg at T-Avg T-Ref. _ 2) GO TO Step 4.
CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 AP/1/A15500/003 40f36 Case I Rev 36 DC~ Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued) E?
RO DOES THIS PAGE_ _~~ DO_E_S_T_H_IS_P_A_G_E c*~gj~~m'mt~f~iO'mt
- c. Verifythe'followilig,: c. IF steam dump valves are closed AND T-Avg is 3°F greater than T-Ref, THEN:
_ * *;~~YJ~;,I!:~."&;~CJ~~~{mM~~~m~[)~
"C.:7ALOSS OF LOAD INTL:J<,~OND
.O.WMPl!l; DUMP" light (1SI-18)
~\F;!M"M?;Ka!ih]!i, A.YI., J 3 -LIT
*1fi"+l!ji!80l"*"*Ii>+:;:(JS1~'ilHY;i,'t::l}T:'1;
".'" ....
- status k.' _ 1) Place "STM DUMP CTRL" in manual.
_ 'i':~r*a:'1'Ql;'Cli~i\"i8IW'8i"'1",:l\'Ali'1Inlli:lL:ATJII~"
* *?h,~",*.!~',hh."..?~J:11'~;i;W~&'i\?f~"v;;-I.Y)R..Jp;..;.,,,.~,.*,>*
Steam dump valves - MODULATING. ,'- . ,/~",,~t'; _ 2) Adjust "STM DUMP CTRL" to 0% demand. _ 3) Place the steam dumps in pressure mode. _ 4) Manually operate condenser steam dump valves to maintain T-Avg at T-Ref. _ 5) IF steam dump valves fail to operate, THEN dump steam as necessary from available S/G PORVs to maintain T-Avg at T-Ref.
- d. T*Avg - DECREASING TO T.. REF. d. Perform the following:
_ 1) Place "STM DUMP CTRL" in manual. _ 2) Adjust "STM DUMP CTRL" to 0% demand. _ 3) Place the steam dumps in pressure mode. _ 4) Manually operate condenser steam dump valves to maintain T-Avg at T-Ref. _ 5) IF steam dump valves fail to operate, THEN dump steam as necessary from available S/G PORVs to maintain T-Avg at T-Ref.
CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 AP/1/A155001003 5 of 36 50f36 Case I Rev 36 DC~ Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. V~rify PzrPORV'clrid Pzr spray valve V&rrI'yB~t:Bi~R\I,'1iriCfR~t".*.~praY**Xl:llv~ OP DOES THIS PAGE
$tatusas***.fol*lowS*:
status as follows: a, All Pzr PORVs - CLOSED. a.lE!T'~rI?t~.~suflels
- a. IF PZf pressure is less than 23t9P~lg.
lesslhan 231'5 PSIG, THEN: THSNl _ Manually close Pzr PORV{s).
- 1) M?nU?II.Y¢losePzll*PG>HV{s}:
_ :~)
- 2) *IE'?Qym~t:)e~i,,!!:¢l3l'1nofpe.pl(jse~i IF'aDY PirPORV cannot be closed, THEN close its isolation valve.
TIlISNcloseiitsIsol'ation.VaIVe;
- 3) IFIE Pzr PORV isolation valve cannot be closed, THEN:
TIlISN: _ a) Trip reactor. _ EP/1/A15000IE-0 b) GO TO EP/1/A/5000/E-0 (Reactor Trip Or Safety Injection).
- b. Normal Pzrspray valves -, CLOSED. IE Pzr pressure is less than 2260 PSIG,
- b. IF THEN:
TIlISN: _ 1) Manually close the affected spray valve(s). _ 2) REFER AP/1/A155001011 RSESR TO AP/1/A/55001011 (Pressurizer (pressurizer Pressure Anomalies). 5*W~tify*
- 5. PtQP~t*.QM:*§Y$l~Q1.QP&J:1ition:*1is Vf¥tify . prop.erCIYI~yst~moperation as follows;'
follows:' _ ~.>>>VIlISN.
<1. WHEN reactorij;!a~t~ij~~iM~ll.isl~sS power is less .t/:}l3fliJ9%,
than 75%, mllllt*N.~@*~.(;it~pot/:}~ll/:}ftat9ii)pqj;ri~~.,," J:HEN e!lsure both C-htr drainpumps-
~I::'I:::
- OFF.
b .,,!!~"i~Y>r~~<llJ~r\P~iM~r"'
- b. gi~~JB§.i1:TH~~*
Verify; reactor power,.. * *GREATERTHAN b. GO TO Step 6. 56% PRIOR TO THE: EVENT. 9.6%!T'.il:~1R,.JB~:T.RI~EE;"!!Et-JJB; c."!!eti~y.:*stafl~t:iY/:}9~~I!pl.nnp{s~:,,,:~:,.*.ONi
- c. Verify standbyhotwell pump(s) -ON. c. Manually start standby hotwell pump(s) as necessary.
d .,,!!erify:s~aDCfoy~~nCf~!1~atep~(jster
- d. Verify st13ndbycc>nden~ate booster d. Manually start standby condensate pump(s)~ ON.
PQj;ri~<sJeQ}N~ booster pump(s) as necessary.
CNS LOAD REJECTION PAGE NO. AP/1/A155001003 AP/1/A/55001003 6of36 60f36 Case I DC~ Rev 36 DCS Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. Verify the following generator alarms - _ Ensure turbine generator load -
DARK: REDUCED TO APPROXIMATELY 48% AND THE ALARM CLEARS. _ * ;lAO"~;~J~~1,W1~1iNi~~~RMI;@ 1AD-11,C/t liGEN BKR,tA OVER
~~RRE~y?'
CURRENT" _ *.~{Q'~1'1~'~lTI:t~~~~~~:~~~~., 1AD-11, F/1"GEN BKR B OVER
~"1Jm.m;z4t CURRENT".
IRol 7. Verify SIG leve,lsare adequate as follows: Perform the following:
- a. Ensure feedwater regulating valves -
__ ** 'BIJi;il~;~tWA~~~I.~~~m~~'.? All S/G low leveLalert alarms (1AD-4)- MODULATING TO CONTROL S/G
~'~JllIi DARK LEVELS AT PROGRAM SETPOINT.
_
- 4i111lIY~@~.J~;RfI~mfj~C~,UMs,;;
All S/G low CF flow alarms (1AD-4)- b. IF any S/G(s) N/R level is decreasing in
.~lIk' DARK. an uncontrolled manner, THEN:
_ 1) Trip reactor. _ EP/1/A15000/E-O (Reactor
- 2) GO TO EP/1/A/5000/E-O Trip Or Safety Injection).
CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 7 of 36 Case I Rev 36 DC~ Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. M~JifY:teaot()rtp()WE!t;::~Gge~'lieg:'lifi~N Verify reactor power"'GREATER THAN Perform the following:
20%.
- a. Place "CRD BANK SELECT" switch - IN MANUAL.
- b. Maintain control rods above insertion limits.
- c. Operate control rods to stabilize reactor power between 6%-10%.
- d. IF AT ANY TIME reactor power is less than or equal to 5%, THEN perform the following:
_ 1) Ensure turbine - TRIPPED. _ 2) Concurrently insert control rods to shutdown the reactor. REFER TO OP/1/A/6150/008 (Rod Control). _ 3) GO TO AP/1/A/5500/002 (Turbine Generator Trip).
- e. GO TO Step 10.
9 9..IFIF AmAN;V:i)FIMEtE!~§t§tpQvtE!ti$IE!$s AT ANY TIME rea~tor power is less ttl@l1or.~qyaI1§:~9~J~)FH*EN?p~r:I'()*!!Iitj.** than or equal to.20~, THEN perform
~teJ.l8igNCi).:
Step 8 RNO.
- 10. M~dfY:*~§:.tI~;:i~~r;ptE!$sure?Gge~meR Verify AS h~a~erpressure - GREATER _ Adjust 1 1AS-2 AS-2 (Main Stm To Aux Steam) mHAN~g;le~.UJ4I.:.JID~~
THAN OR:I:Q~AL;;r() 140 4.9fP~IG; PSIG. as required to maintain AS header IBOpl pressure between 140 PSIG and 150 PSIG.
- 11. ~djY$t"~'liY~A(~trn§E!~I'R~g'~MP)~§ Adl lJ st1TL-4 (StmSealReg Byp) as I1~QE!§§@~t().I1i.@il1t@II1***st~@I1i§e@r necessary to maintain steam seal ptE!ssut~il:)~tW~E!n*AlP~IG**4'*6P§.I.G*~.
piessure.between 4.PSIG -'6 PSIG. Calculating boron for this is an ADMIN JPM on this exam. If they start to do it, then the next event should begin and the
- 12. MonitorEnclo~lire'3(~()~
MgQ!t9tfel1¢[()§:YtE!~;:(~Q~:ln$E!rti9n Insertion TS can be reviewed during foliowup. followup. j;;.imit;~Qt@tiQI1JJ LimW.Boration). IBOpi
CNS LOAD REJECTION PAGE NO. AP/1/AJ55001003 AP/1/AJ5500/003 8 of 36 Case I Rev 36 DC:: Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 13. V~rify reactor power - LESS THAN 30%~ !'?*~ITQrmlt1gfQllQWing; Perform the following:
- a. IF the. ry r:l bacK target *. IQ§.d, a~IF.lh.E}.,r~~.~§pklc:rrg~t' IO<;lQ * *.is'.*lesstflan is less than
~~!Y();i'THEN:
30%, THEN: _ 1) WHEN time and personnel permit, THEN perform applicable steps of OP/1/AJ61 001003 00/003 (Controlling Procedure For Unit Operation). _ 2) Do not continue in this procedure until reactor power is less than 30%. _ 3) WHEN reactor power is less than 30%, THEN GO TO Step 14. WHEN
- b. WH EN',.~he the. *appropri§tetul!)~acklal!get appropriate runback target.
load is reached, THEN: Igadis'feachE}QrTHEN: _ .1I~tabiliz:E}unjtatc!-l(fE}rit.*power
- 1) Stabilize unit at current power * *I~veL level.
_~) _ 2) Maintain control rods *.**abbve Mairntain+eenttolrods above iinsertfonlimfts: nsettlon.:litxlifsi
~)
- 3) Adj~sttflE}fglloWi)jgi'§sreqqired Adjust the following as required to maintain mqltlU,li T~Avg within 1°Fof T -Ref:
nflf&.t\vg$'ithin1(?pof*T
.TClttllneload
- Turbine load
.Confreirods
- Control rods
- Boron concentration.
*"6oton'1.cbnGentratiol.l.
- c. GO TO$tep15.
- 14. Verify the "RESET" light on "AM SAC Perform the following:
FOR CF VALVES" switch - DARK.
- a. IF turbine impulse pressure is less than 190 PSIG, THEN notify IAE to correct the cause of the AMSAC failure to deactivate.
- b. Depress the "BYPASS" pushbutton on "AM SAC FOR CF VALVES" switch.
- c. WHEN 2 minutes has elapsed, THEN verify "RESET" light on "AM "AMSAC SAC FOR CF VALVES" switch has remained dark.
CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 9 of 36 Case I DC~ Rev 36 DCS Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 15. Verify the following PCBs - C.LOSED:
fBOPl
- r.7*.~I)l~ratot~t~ak~t)~*1f" Generator breaker 1A When separated from the grid
*.r.7~tjera~b.rbr~akel"{~>a Generator breaker 1B the turbine reverts to speed iiPCB14
- PCB 14 . control.
- PGlB1 PCB 15 E5
- PCBPCB1:zi17 Perform the following:
*PGlB18;
- PCB 1.8.
- a. IF both generator PCBs are open, THEN ensure main turbine speed -
MAINTAINED BETWEEN 1792 AND 1807 RPM.
- b. IF the turbine generator is separated from the grid, THEN:
_ 1) Ensure main turbine speed - 1} MAINTAINED BETWEEN 1792 AND 1807 RPM. _ 2} Ensure main generator voltage - 2) MAINTAINED BETWEEN 20.9 KV AND 23.1 KV.
- c. IF load rejection caused by loss of main busline 1A or 1B, THEN:
- 1) Notify Transmission Control Center 1}
(TCC), using one of the following methods, to investigate and repair cause of the loss of busline:
- 704-382-9403
- 704-382-9404
- 704-399-9744
- 704-382-4413 (System Operating Center).
_ 2) WHEN notified by TCC that the 2} affected busline is ready to be re energized, THEN restore power to the affected busline. REFER TO Enclosure 1 (Offsite Power Restoration Resto ratio n). Adjust power fa~tor as necessary. 16 .~t:jJI1lj;;tR(::iw~r1c,l'~t(::irt!j;;:>tl~:~~j;;j;;c,lI¥~ 16.
**RE~I:~tT(.)1.ftlit*;;1~eMjj;;eCliii'mata:!e(::i(::i1t REFER TO Unif f Revised. Data Book Rj§UrEJ:~$:
Figure 43. '
CNS LOAD REJECTION PAGE NO. AP/1/AJ5500/003 AP/1/A155001003 10 of 36 Case I Rev 36 DC~ Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 17*W8'.IIm'lBDm'l.ltfrlUnJ~f~,itg~tl
- 17. WHEN the appropriate runback target IROI 1load
"":D1'ITho~~iii;;."""V'mLlGN!ii' is reached, THEN:
"J),,,",,qN",\,!0{~S~"J~~)'t~,
_ :';'$:t_.Q'fm;;at;~:~t:.r1~~,tmml1!t:l~~~
- StabiliZe' unit atappropriate power leveL ii* 'Matt\l1't~jO.Q'ltrQhtoj~j(,'h~ve:i]"'6~'1;,tl'Hl Maintain'Gontrol rod~'above,
" .." , , " " " " " , v " " " " . ' '.' insertion
.",iSNl;JP.J?,* .. ")i1~,5(I.'!o,,.,iJ!l:
l.ili'llt~~';: limits.
* ?~tJ*usJElhetfQlf(llrAiii;;as.~ajr:et1f1fe,
'it' .Adjust the..,*.,.,.".!l'h,g
,.J.L....,};(.,., following "as required
"."",j,lil" to
;flli~~in{~A{~ithif;):f~'~tQf';J";;R~l~)
maintain T-Avg withitt1°F ofT-Ref:
*i%*fi'\.I,tli:,OJ~
- Turbine load
- ~I<!n,
- Control rods
- Boron concentration.
- 18. Notify System Operating\'Center(SOG) using thered dispatcher telephone of current unit status.
- 19. Determine'and correct cause of load rejection. Load rejection caused by loss of CF pump.
CNS LOAD REJECTION PAGE NO. AP/1/AJ55001003 AP/1/A/55001003 11 of 36 Case I DC~ Rev 36 DC::: Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 20. ~t1l.1t'g()\Yt1uij(lQc~~§ary:pJ~(lJeql.lipoi~gJ Sh!Jtdown unnecessary,pJantequipment as'follows:
as follows:
- a. Restore CM and CF as follows:
_ 1) Verify C,*htrdrain pumps - ON. _ WHENtiOO'J;i~l1dm~npowet'p~l"tnit,
- 1) WHEN time and manpower permit, TF'lENcqmplete,the THEN complete the . §lJutdoWtlQfthe shutdown of the
@7IJtfo(a.
C-htr draini.o*.***PllfrJPS:'**REFER* pumps. REFER .* TO Of1>t~/e/qg$Oloq~****.(Fe~(jvv~ter OP/1/B/62501004 (Feedwater hle~terMeqts;Ol"aJns~ndElleeo Heater Vents, Drains and Bleed SYstem); System). IRai __ 22))M~tifY;QQtlJlill~Ft=?li/11PS?fJN VerifYQothCF Pumps - IN _ g) 'GOI"TOr$tep.4ot~;
'---' SE~\zICE.
SERVICE. _ 3) Shutdown one CF pump as necessary. REFER TO OP/1/A/62501001 OP/1/AJ62501001 (Condensate and Feedwater System). _ 4) Shutdown excess Condensate Booster Pumps. REFER TO OP/1/AJ62501001 (Condensate and OP/1/A/62501001 Feedwater System). _ 5) Shutdown excess Hotwellhlotwell Pumps. OP/1/AJ62501001 REFER TO OP/1/A/62501001 (Condensate and Feedwater System). R@p(.Jrnp(s}~qg9QQIJqQ!(jWerfan§:
- b. RC pump(s) Cln(:j cooling tower fans.
RERERTO;'~f1>I~/e/6400tOO~ REFER TO;OP/1 IB/6400/001 A (~l:lden§er'~lr~ul~tlijgW~Jel"§~stern)* (Condenser Circulating Water System). IRol 21. R~§et§t~~I'P.:'gqmp"y~:lyg§~§*::f()U()W$: Resetsteam dumpv~lves as,'folloWs: a*Merif~*'*rea:CtQI"FpQwer::$+~eb;e:
- a. Verify reactprpower - STABLE. a. Perform the following:
_ WF'lEN reactor power is stable,
- 1) WHEN TF'lEN perform Steps 21.b THEN through 21.g.
_ 2) GO TO Step 22.
CNS LOAD REJECTION PAGE NO. AP/1/A/5500/003 12 of 36 Case I DC~ Rev 36 DCt Switchyard Switch yard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 21. (Continued) RO o does this pag page _
\f~'~ifyJste~t;ncjul'Tlpv~lv~s4IN
- b. Verify steam dump valves - IN b. Perform the following:
1~]j;A\fG"MODE "T-AVG" MODE.
- 1) IF using S/G POR\fs, PORVs, THEN:
_ a) WHEN T-Avg is within 1°F of T-Ref AND stable, THEN close S/G PORVs. POR\fs. _ b) GO TO Step 21.d.
- 2) WHEN T-Avg T-Avg is within 1°F of T -Ref T-Ref AND stable, THEN:
_ a) Ensure steam dumps - CLOSED. _ b) Perform Steps 21.d through 21.g. _ 3) GO TO Step 22.
- c. ,verify steam dump valves - CLOSED. c. Perform the following:
_ 1) WHEN steam dump valves are closed, THEN perform Steps 21.d through 21.g. _ 2) GO TO Step 22.
- d. Resetsteam dump valves.
~. Verify
- e. ~~ITifytn~ f()JI()wing'st(:m.J~IIgnt~
the following status lights (1~171{U~~A.RIX: (1SI:'18) - DARK:
*.*****.I'~ . 7JA.:t.;,~~$'<=lF.*t.;,<=l.A.IJINmt.;,~*
"C-7A/LOSS OF LOAD INTLK COND ~~NP 1J\;lty1~:'
DLJMP"
* *J*'~77J.~j:t.;,~$$'OfT,t.;,<=lA.p:INmt.;,~
"C-7S5LOSS OF LOApJNTLK ATMOS A.].ty1 .*<=l$:P.ll.IM.ITI",t DUMP".
- f. IFl'l:-A.~~sl'l1()dEj. ()IOR~rati.()Ijj~'
IF"J-AVG"modeof operation is
~v~il~f§I~jirrHEN,*
gv~Hable,THEN~nsure . ~i;l~l1tt~\st~~iltIdJ)iltI*p.**
.steam dump val.vesii"i)j:;"r valves in~!T .-AVG" .A\f~"'rnoaejmode~
_ g*~~tify!;:'~mM"PLJMf;?,!;~mRt.;,i::i~mljtfll
- g. Verify;!;~'pTM DUMpCTRLH.>JN _ g. IF steam dumps are in "T-AVG" "T-A\fG" mode, A.ll.I!TI@.
AUTO.: THEN place "STM DUMP CTRL" in auto.
CNS LOAD REJECTION PAGE NO. AP/11A155001003 AP/1 IAl55001003 13 of 36 Ca~e . ,I.I
,mi:is~e.'
a~,,>, DeS Rev 36 DC!:
'~WJt~I1_~~vtilJI~tIl~;;
$witchY8Ycl Available .
ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. ~~rify reactor power
- GREATER THAN Transfer feed flow to CA nozzles.
15%. . REFER TO Enclosure 2 (Transferring Feed Flow From CF To CA Nozzles).
- 23. Verify CA pumps - OFF. Perform the following:
- a. WHEN CA is no longer needed to feed S/G(s), THEN shutdown the CA System S/G(s},
following the automatic start and return CA System to standby readiness. OP/11A162501002 (Auxiliary REFER TO OP/1/A162501002 Feedwater System).
- b. Re-establish S/G blowdown. REFER TO OP/11A162501008 OP/1/A162501008 (Steam Generator Slowdown).
Blowdown).
- 24. Verify re'~~torpoYl~J change ':G,J3;E;ATERi _ GO TO Step 26.
TMAN OR:EQUAL":lP 15% IN A 1HOUR fROl PERIOD. Depending on how far they
- 25. Notify the following sections to take reduce power, this step may appropriate samples: apply and they will do step 25.
- Radiation Protection to sample and analyze gaseous effluents. REFER TO Selected Licensee Commitments Manual, Section 16.11-6.
- Primary Chemistry to sample for isotopic analysis of iodine. REFER TO Tech Specs 3.4.16 (Sample must be taken between 2 hours and 6 hours following last power change greater than or equal to 15% rated thermal power within a 1 hour period).
TS 3.1.6 Condition A (if rods are below LoLo insertion limits.)
- 26. EQsu~~t:com~nar:tce with apprc>,priate Tech Specs:
- 3.1.1 (Shutdown Margin(SDM))
_ Ii * ~::l~{)jl~~titttll.§!~~;\!(;l~flifj)tl'i~lr:m. 3.1.Q/{Control 8ank;lnsertion:Limits) _ ~Y
- t~li!r~l!~m~J{f.1
- 3:8:~::;(AO$purc~s ':*iOperating).
CNS LOAD REJECTION PAGE NO. AP/1/A/55001003 14 of 36 Case I DC~ Rev 36 DCS Switchyard Available ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 27..~QtlfY~~actotGrogpai1§iQ~~rot 27 NQtify Reactor Group Engineer of occurrence. octiJrrehce. 28. 28t m~t~troi.rJeIQng'lt~trn.pl~QJ)!;t~t!l.$i Determine long term pla.,tstatus. RI3lJ::l:JRN)TOc).R/1)Z~6tpP1QPa RETURN TO OP/11A16100/003 (Controlling;Procedure For *.l!Iflit (eQQtfiQlljQ9;RrQ¢e.Ct9fi~J7Qr Unit C)p@r~tiofl)f Operation).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O EP/1/A/5000/E-O 1 of 61 Rev 36 DC~ A. Purpose This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of all Reactor Trips and 511 above P-11, valid 5/1 below P-11 and to assess plant conditions, and to identify the appropriate recovery procedure.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP11 IA/5000/E-0 20f61 DC~ Rev 36 DCS B. Symptoms or Entry Conditions
- 1. The following conditions are symptoms that require a Reactor Trip:
- 1 of 2 SIR channels - GREATER THAN 105 CPS WHILE BELOW P-6
- 1 of 2 I/R channels - GREATER THAN 25% FULL POWER AMPS EQUIVALENT WHILE BELOW P-10
- 2 of 4 P/R channels - GREATER THAN 25% FULL POWER WHILE BELOW P-10
- 2 of 4 P/R channels - GREATER THAN 109% FULL POWER
- 2 of 4 P/R channels - +5% FULL POWER IN 2 SECONDS
- 2 of 4 loop ATs - GREATER THAN THE OPAT SETPOINT
- 2 of 4 loop ATs - GREATER THAN THE OTAT SETPOINT
- 2 of 4 Pzr pressure channels - GREATER THAN 2385 PSIG
- 2 of 4 Pzr pressure channels - LESS THAN 1945 PSIG WHILE ABOVE P-7
- 2 of 3 Pzr level channels - GREATER THAN 92% WHILE ABOVE P-7
- 2 of 4 S/G N/R level channels on 1 of 4 S/Gs - LESS THAN LO-LO SETPOINT
- 2 of 4 NC pump buses - LESS THAN 77% OF NORMAL VOLTAGE (5082 VOLTS) WHILE ABOVE P-7
- 2 of 4 NC pump buses - LESS THAN 56 HERTZ WHILE ABOVE P-7
- 2 of 3 NC flow channels on 2 of 4 NC loops - LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-7 AND BELOW P-8
- 2 of 3 NC flow channels on 1 of 4 NC loops - LESS THAN 90% OF LOOP MINIMUM MEASURED FLOW WHILE ABOVE P-8
- 4 of 4 turbine stop valves - CLOSED WHILE ABOVE P-9
- 2 of 4 turbine stop valves EHC pressure - LESS THAN 550 PSIG WHILE ABOVE P-9
- 1 of 2 S/I trains - ACTUATED
- 2 of 2 SSPS trains - GENERAL WARNING ALARM.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EPf1fAl5000fE-O 30f61 Rev 36 DCS DCE
- 2. The following are symptoms of a Reactor Trip:
- Any Reactor Trip annunciator - LIT
- Neutron level- RAPIDLY DECREASING
- Rod bottom lights - LIT.
- 3. 51/:
The following are symptoms that require a Reactor Trip and 5":
- 2 of 4 Pzr pressure channels - LESS THAN 1845 PSIG
- 2 of 3 containment pressure channels - GREATER THAN 1.2 PSIG.
- 4. The following are symptoms of a Reactor Trip and 5/1:
Sfl Reactor Trip annunciator - LIT
- Any SII
- NV, NI, and ND pumps - ON
* "SAFETY INJECTION ACTUATED" status light (1SI-13) - LIT
- EfS EIS Load Sequencer Actuated status lights (1SI-14) - LIT.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 40f61 4of61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- c. Operator Actions RO DOES THIS PAGE
- 1. Monitor Enclosure 1 (Foldout Page).
@ Verify Reactor Trip: Perform the following:
_
- All rod bottom lights - LIT a. Manually trip reactor.
_
- All reactor trip and bypass breakers - b. IF reactor will not trip, THEN OPEN concurrently:
- I/R amps - DECREASING.
- Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees) .
- GO TO EP/1/A/5000/FR-S.1 (Response To Nuclear Power GenerationlATWS).
oG) Verify Turbine Trip:
- All turbine stop valves - CLOSED Perform the following:
- a. Manually trip the turbine.
- b. IF turbine will not trip, THEN:
_ 1) Depress the "MANUAL" pushbutton on the turbine control panel. _ 2) Rapidly unload turbine by simultaneously depressing the "CONTROL VALVE LOWER" and "FAST RATE" pushbuttons.
- 3) IF turbine will not runback, THEN close:
- All MSIVs
- All MSIV bypass valves.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O 50f61 5 of 61 Rev 36 DC~ DCE I ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED -0 Verify 1ETA and 1ETB - ENERGIZED. Perform the following:
- a. IF 1ETA AND 1ETB are de-energized, OP DOES BOP THEN GO TO EP/1/N5000/ECA-O.O (Loss Of All AC Power).
THIS PAGE
- b. WHEN time allows, THEN attempt to restore power to de-energized switchgear while continuing with this procedure. REFER TO AP/1/N55001007 (Loss of Normal Power).
oG) Verify SII is actuated:
- a. "SAFETY INJECTION ACTUATED" a. Perform the following:
status light (1SI-13) - LIT. 1) 1} Verify conditions requiring S/I: _ . Pzr pressure - LESS THAN 1845 PSIG Auto SII is blocked on both channels. Manual initiation OR required. CRITICAL TASK! _
- Containment pressure -
GREATER THAN 1.2 PSIG. _ 2) 2} IF S/I is required, THEN manually initiate S/I. 3} IF S/I is not required, THEN 3) concurrently:
- Implement EP/1/N5000/F-O (Critical Safety Function Status Trees) .
- GO TO EP/1/N5000/ES-O.1 (Reactor Trip Response).
- b. Both E/S load sequencer actuated b. Manually initiate S/I.
status lights (1SI-14) - LIT.
- 6. Announce "Unit 1 Safety Injection".
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/11A15000/E-O 60f61 6 of 61 Rev 36 DCSDC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. Determine required notifications:
- REFER TO RP/OIAl50001001 RP/O/A/50001001 (Classification Of Emergency)
RP/O/B/50001013 (NRC
- REFER TO RP/O/B/5000/013 Notification Requirements).
- 8. Verify all Feedwater Isolation status Perform the following:
lights (151-5) - LIT.
- a. Manually initiate Feedwater Isolation.
- b. IF proper status light indication is not obtained, THEN manually close valves.
- 9. Verify Phase A Containment Isolation status as follows:
- a. Phase A "RESET" lights - DARK. a. Manually initiate Phase A Isolation.
- b. Monitor Light Panel Group 5 St lights - b. Manually align valves.
LIT.
- 10. Verify proper Phase B actuation as follows:
- a. Containment pressure - HAS a. Perform the following:
REMAINED LESS THAN 3 PSIG. This time may be used later to determine when to align ND Aux spray. _ 1) Record approximate time of reactor trip. _ 2) Verify NS pumps -INDICATING FLOW. _ 3) IF flow is not indicated, THEN manually initiate Phase B Isolation for affected train{s). train(s). (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/A15000/E-O 7of61 Rev 36 DC~ ACTIONIEXPECTED ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued)
- 4) Verify Phase B Isolation has actuated as follows:
_ a) Phase B Isolation "RESET" lights - DARK. _ b) IF Phase B Isolation "RESET" lights are lit, THEN manually initiate Phase B Isolation. c) Verify following monitor light panel lights - LIT:
- Group 1 Sp lights
- Group 5 Sp lights
- Group 5 St lights Ll11 and Ll12.
_ d) IF monitor light panel not in correct alignment, THEN ensure correct alignment. e) IF NS pump(s) did not start, THEN perform the following for the affected train(s): _ (1) Reset ECCS. _ (2) Reset DIG load sequencer. _ (3) Manually start affected NS pump. _ (4) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. _ 5) Stop all NC pumps. _ 6) Maintain seal injection flow. _ 7) Energize H2 igniters. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 8of61 DC~ Rev 36 DCE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued)
- 8) Dispatch operator to perform the following:
_ a) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ b) Place containment H2 analyzers in service. REFER TO OP/1/A/6450/010 (Containment Hydrogen Control Systems). _ 9) WHEN 9 minutes has elapsed, THEN verify proper VX system operation. REFER TO Enclosure 7 (VX System Operation). _10) GO TO Step 11.
- b. IF AT ANY TIME containment pressure exceeds 3 PSIG while in this procedure, THEN perform Step 10.a.
11. !BOpI11. Verify proper CA pump status as follows:
- a. Motor driven CA pumps - ON. a. Perform the following for the affected train(s):
_ 1) Reset ECCS. _ 2) Reset D/G load sequencer. _ 3) Manually start affected motor driven CApump. CA pump. _ 4) IF AT ANY TIME a B/O occurs, THEN restart S/I equipment previously on.
- b. 3 S/G N/R levels - GREATER THAN b. Ensure CA Pump #1 - RUNNING.
11%.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/11A15000/E-O 90f61 Rev 36 DC~ ACTIONIEXPECTED RESPONSE RESPONSE NOT OBTAINED
- 12. Verify all of the following 5/1 pumps - ON: Perform the following for affected train(s):
NV pumps
- NVpumps
- ND pumps BOP DOES a. Reset ECCS.
- NI pumps. THIS PAGE
- b. Reset DIG load sequencer.
- c. Manually start affected pump.
- d. IF AT ANY TIME a BIO occurs, THEN restart SII S/I equipment previously on.
- 13. Verify all KCpumps KC pumps - ON. Perform the following for affected train(s):
- a. Reset ECCS.
- b. Reset DIG load sequencer.
- c. Manually start affected pump.
- d. IF AT ANY TIME a BIO occurs, THEN restart SII S/I equipment previously on.
- 14. Verify all Unit 1 and Unit 2 RN pumps- Perform the following:
ON.
- a. IF any Unit 2 RN pump is off, THEN manually start affected pump(s).
- b. IF any Unit 1 RN pump is off, THEN perform the following for affected train(s):
_ 1) Reset ECCS. _ 2) Reset DIG load sequencer. _ 3) Manually start affected pump. _ 4) IF AT ANY TIME a BIO occurs, THEN restart S/I SII equipment previously on.
- 15. Verify proper ventilation systems operation as follows:
- REFER TO Enclosure Enclosure 2 (Ventilation System Verification).
- Notify Unit 2 operator to perform Enclosure 3 (Opposite Unit Ventilation Verification).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 EP/1/N5000/E*0 10 of 61 DC~ Rev 36 DCE ACTIONIEXPECTED ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 16. 5/G pressures - GREATER Verify all SIG Perform the following:
THAN 775 PSIG. P5IG.
- a. Verify the following valves*
valves - CLOSED:
- All MSIVs
_ .* All MSIV bypass valves
- All SIG S/G PORVs.
- b. IF any valve is open, THEN:
_ 1) Manually initiate Main Steam Isolation. _ 2) IF any valve is still open, THEN manually close valve.
- 17. Verify proper 5/1 511 flow as follows:
S/I FLOW" *-INDICATING
- a. "NV SII INDICATING FLOW. a. Manually start NV pump(s) and align valves.
- b. NC pressure*
pressure - LESS THAN 1620 PSIG. b. Perform the following: _ 1) Ensure ND pump miniflow valve on operating ND pump(s) *- OPEN.
- 2) IF ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):
_ a) Reset ECCS. _ b) Reset DIG load sequencer. _ c) Stop ND pump. _ d) IF AT ANY TIME a 8/0 B/O occurs, S/I equipment THEN restart SII previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 11 of 61 Rev 36 DCS DC::: ACTIONIEXPECTED RESPONSE ACTION/EXPECTED RESPONSE NOT OBTAINED
- 17. (Continued)
IBOP I c. NI pumps -INDICATING FLOW. c. Manually start NI pump(s) and align valves.
- d. NC pressure - LESS THAN 285 PSIG. d. Perform the following:
_ 1) Ensure ND pump miniflow valve on operating ND pump(s) - OPEN.
- 2) IF the ND pump miniflow valve(s) cannot be opened, THEN perform the following for affected train(s):
_ a) Reset ECCS. _ b) Reset DIG D/G load sequencer. _ c) Stop ND pump. _ d) IF AT ANY TIME a B/O BIO occurs, THEN restart SII S/I equipment previously on. _ e) IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart the ND pump. _ 3) GO TO Step 18.
/BOP IBOP I e. ND pumps -INDICATING FLOW TO e. Manually start ND pump(s) and align C-LEGS. valves.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1 IA/5000/E-0 EP/1/A/5000/E-0 12 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 18. Control 51G S/G levels as follows:
- a. Verify total CA flow - GREATER THAN a. Perform the following:
450 GPM. _ 1) IF N/R level in all S/Gs is less than 11 % (29% ACC), THEN manually start CA pumps and ensure correct valve alignment.
- 2) IF N/R level in all S/Gs is less than 11 % (29% ACC) AND feed flow greater than 450 GPM cannot be established, THEN concurrently:
- Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees) .
- GO TO EP/1/A/5000/FR-H.1 (Response To Loss Of Secondary Heat Sink).
- b. WHEN at least one S/G N/R level is greater than 11 % (29% ACC), THEN throttle feed flow to maintain all S/G N/R levels between 11 % (29% ACC) and 50%.
Isop Verify all CA isolation valves - OPEN. _ Manually open valve(s).
- 20. Verify 5/1 SII equipment status based on _ Manually align equipment.
monitor light panel - IN PROPER ALIGNMENT. Enclosure 4 (NC Temperature Control) shall remain in effect until subsequent procedures provide alternative NC temperature control guidance. Control NC temperature. REFER TO Enclosure 4 (NC Temperature Control).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/AJ5000/E-O EP/11A15000/E-O 13 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. Verify Pzr PORV and Pzr spray valve status as follows:
[BOP
- a. All Pzr PORVs - CLOSED. a. IF Pzr pressure is less than 2315 PSIG, THEN:
_ 1) Manually close Pzr PORV(s). _ 2) IF any Pzr PORV cannot be closed, THEN close its isolation valve.
- 3) IF any Pzr PORV cannot be closed OR isolated, THEN perform the following:
_ a) Energize H2 igniters. b) Dispatch operator to perform the following: _ (1) Secure all ice condenser air handling units. REFER TO Enclosure 13 (Securing All Ice Condenser Air Handling Units). _ (2) Place containment H2 analyzers in service. REFER TO OP/1/AJ64501010 OP/11A164501010 (Containment Hydrogen Control Systems). (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 14 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 22. (Continued) c) IF both the following conditions exist,
- Containment pressure -
GREATER THAN 1 PSIG
- Containment pressure - HAS REMAI NED LESS THAN REMAINED 3PSIG
_ THEN start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). d) Concurrently:
- Implement EP/11A15000/F-0 (Critical Safety Function Status Trees).
- GO TO EP/11A15000/E-1 (Loss Of Reactor Or Secondary Coolant).
- b. Normal Pzr spray valves - CLOSED. b. IF Pzr pressure is less than 2260 PSIG, THEN:
_ 1) Manually close spray valve(s).
- 2) IF spray valve(s) cannot be closed, THEN:
_ a) Stop NC pumps 1Aand1A and 1 B. 1B. _ b) IF NC pressure continues to decrease, THEN stop third NC pump as required.
- c. At least one Pzr PORV isolation valve- c. IF power is available, THEN open one OPEN. Pzr PORV isolation valve unless it was closed to isolate an open Pzr PORV.
fRCCl
- 23. Verify NC subcooling based on core exit IF any NV OR NI pump is on, THEN:
TICs - GREATER THAN O°F.ODF.
- a. Ensure all NC pumps - OFF.
- b. Maintain seal injection flow.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/11Al5000/E-O 15 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 24. Verify main steamlines are intact as IF pressure in any S/G is decreasing in rr------, follows: an uncontrolled manner OR any S/G is l~~J depressurized, THEN perform the
_
- All S/G pressures - STABLE OR following:
INCREASING
- a. IF both the following conditions exist,
- ALL S/Gs - PRESSURIZED.
- Containment pressure - GREATER THAN 1 PSIG
- Containment pressure - HAS REMAINED LESS THAN 3 PSIG
_ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start).
- b. Concurrently:
EP/11A15000/F-O (Critical _ . Implement EP/1/A/5000/F-O Safety Function Status Trees). _ . GO TO EP/1/A/5000/E-2 EP/11A15000/E-2 (Faulted Steam Generator Isolation).
- 25. Verify S/G tubes are intact as follows: IF any EMF trip 1 light is lit OR any S/G level is increasing in an uncontrolled
- Verify the following EMF trip 1 lights-lights - manner, THEN concurrently:
DARK: EP/11A15000/F-O (Critical _ . Implement EP/1/A/5000/F-O
- 1EMF-33 (Condenser Air Ejector Safety Function Status Trees).
Exhaust) _
- GO TO EP/1/A/5000/E-3 EP/11A15000/E-3 (Steam
- 1EMF-26 (Steamline 1A) Generator Tube Rupture).
- 1EMF-27 (Steam line 1B)
(Steamline
- 1EMF-28 (Steamline 1C)
- 1EMF-29 (Steamline 1D).
- All S/G levels - STABLE OR INCREASING IN A CONTROLLED MANNER.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 16 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 26. Verify NC System is intact as follows:
IBOP J a. Verify the following NC pump thermal a. Perform the following: barrier alarms - DARK:
- 1) Ensure the valve for the affected
- 1AD-6, E/1, "NCP A THERMAL NC pump(s) - CLOSED:
BARRIER KC OUTLET HilLaHI/LO FLOW"
- 1KC-394A (NC Pump 1A Therm Bar Otlt) atIt)
- 1AD-6, E/2, "NCP B THERMAL BARRIER KC OUTLET HIlLaHI/LO
- 1KC-364B (NC Pump 1B Therm FLOW" Bar Otlt) atIt)
- 1AD-6, E/3, "NCP C THERMAL
- 1KC-345A (NC Pump 1C Therm BARRIER KC OUTLET HIlLaHI/LO Bar Otlt)
FLOW"
- 1KC-413B (NC Pump 1D Therm
- 1AD-6, 1AD-6, E/4, "NCP D THERMAL Bar Otlt).
BARRIER KC OUTLET HilLaHI/LO FLOW". 2) IF the valve for the affected NC pump will not close, THEN perform the following: _ a) Trip all NC pumps. (RNa (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 17 of 61 DC~ Rev 36 DeS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 26. (Continued) b) Perform the following:
_ (1) Dispatch operator with radio to standby at 1KC-425A (NC Pumps Ret Hdr Cont Isol) (AB-588, GG-52, Rm 419) (Ladder needed). _ (2) Close 1KC-425A (NC Pumps Ret Hdr Cont Isol) from Control Room. _ (3) IF 1KC-425A (NC Pumps Ret Hdr Cont Isol) will not close completely from Control Room, THEN have operator locally close 1KC-425A (NC Pumps Ret Hdr Cont Isol) (AB-588, GG-52, Rm 419). _ (4) WHEN 1KC-425A (NC Pumps Ret Hdr Cont Isol) has been closed, THEN close 1KC-424B (NC Pumps Ret Hdr Cont Isol). _ (5) WHEN 1KC-425A (NC Pumps Ret Hdr Cont Isol) is closed, THEN notify the dispatched operator to return. (6) Close the following valves:
- 1KC-338B (NC Pumps Sup Hdr Cont Isol)
- 1KC-430A (Rx Bldg Drn Hdr Cont Isol)
- 1KC-429B (Rx Bldg Drn Hdr Cont Isol).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 18 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 26. (Continued)
- b. Verify NC System is intact as follows: b. Perform the following:
- Containment pressure - LESS THAN _ 1} Energize H2 igniters.
1) 1 PSIG. 2} Dispatch operator to perform the 2)
- IF normal off-site power is available, following:
THEN verify containment pressure less than 0.3 PSIG. _ a} a) Secure all ice condenser air handling units. REFER TO
- Containment high range EMFs - Enclosure 13 (Securing All Ice LESS THAN 3 RlHR: Condenser Air Handling Units).
_ . 1EMF-53A (Containment Trn A) _ b} Place containment H2 analyzers b) 1EMF-53B (Containment Trn B). _ . 1EMF-53B in service. REFER TO OP/1/A/64501010 OP/1/A/6450/010 (Containment
- Containment EMF trip 1 lights- Hydrogen Control Systems).
DARK:
- 3) IF both the following conditions 3}
- 1EMF-38 (Containment exist, Particulate)
- 1EMF-39 (Containment Gas)
- Containment pressure -
GREATER THAN 1 PSIG
- Containment sump level-level - STABLE.
- Containment pressure - HAS REMAINED LESS THAN 3 PSIG
_ THEN manually start one VX fan. REFER TO Enclosure 5 (VX Fan Manual Start). 4} Concurrently: 4)
- Implement EP/1/A/5000/F-0 (Critical Safety Function Status Trees).
- GO TO EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant).
- 27. Verify 511 SII termination criteria as follows:
- a. NC subcooling based on core exit TICs T/Cs a. GO TO Step 28.
- GREATER THAN O°F.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 19 of 61 DC~ Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- b. Verify secondary heat sink as follows: b. GO TO Step 28.
- NIR level in at least one SIG -
GREATER THAN 11% 11 % OR
- Total feed flow to SIGs - GREATER THAN 450 GPM.
- c. NC pressure - STABLE OR c. GO TO Step 28.
INCREASING.
- d. Pzr level- GREATER THAN 11%. d. Perform the following:
_ 1) IF NC pressure is increasing AND normal Pzr spray is available, THEN attempt to stabilize NC pressure using normal Pzr spray. _ 2) RETURN TO Step 27.a.
- e. Ensure SII - RESET:
_ 1) ECCS. 1) Perform the following: _ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ b) Concurrently implement Enclosure 8 (ECCS Master Reset) while continuing in this procedure. _ 2) DIG load sequencers. 2) Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA)
(AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB)
(AB-560, BB-46, Rm 372). _ 3) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 EP/1/A/5000/E-0 20 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- f. Ensure only one NV pump - ON.
_ g. Verify NC pressure - STABLE OR g. Perform the following: INCREASING. _ 1) Implement EP/1/A1S000/F-0 EP/1/A/5000/F-0 (Critical Safety Function Status Trees). _ 2) GO TO EP/1/A/5000/ES-1.2 EP/1/A15000/E5-1.2 (Post LOCA Cooldown And Depressurization ).
- h. Verify VI pressure - GREATER THAN h. In subsequent steps, control room 50 PSIG. control is lost for the following valves and local operation will be required:
- 1NV-294 (NV Pmps A&B Disch Flow Ctrl)
- 1NV-309 (Seal Water Injection Flow).
- i. Isolate NV 5/1S/I flowpath as follows:
- 1) Verify the following valves - OPEN: 1) Perform the following:
- 1NV-203A (NV Pumps A&B _ a) Open affected valve(s).
Recirc Isol) _ b) IF 1NV-203A AND 1NV-202B
- 1NV-202B (NV Pmps A&B Recirc are open, THEN GO TO Isol). Step 27.i.2.
c) Dispatch operator to open affected valve(s):
- 1NV-203A (NV Pumps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed)
- 1NV-202B (NV Pmps A&B Recirc Isol) (AB-554, HH-JJ, 54-55, Rm 231) (Ladder needed).
_ d) Close 1NV-309 (Seal Water Injection Flow). (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 EP/1/A/5000/E-0 21 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued) e) IF control of 1NV-309 is lost from the control room, THEN dispatch operator with radio to perform the following:
_ (1) Close 1NV-308 (Seal Wtr Inj Flow Ctrllsol) Ctrl Isol) (AB-554, JJ-54, Rm 233) (Ladder needed). _ (2) Throttle 1 NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps. f) Open the following valves:
- 1 NV-312A (Chrg Line Cont Isol)
- 1NV-314B (Chrg Line Cont Isol).
g) IF 1NV-312AOR 1NV-314B cannot be opened, THEN dispatch operator to open the affected valve(s). Refer to the following enclosure(s) for the affected valve(s):
- Enclosure 10 (Locally Open 1NV-312A)
- Enclosure 12 (Locally Open 1NV-314B).
_ h) Do not continue in this procedure until 1NV-312A and 1NV-314B are open. _ i) IF NC pressure is greater than 1950 PSIG, THEN throttle 1 NV-309 or 1 NV-311 to 50% open. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/11A15000/E-0 22 of 61 DC~ Rev 36 DCE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
_ j) Open 1NV-294 (NV Pmps A&B Disch Flow Ctrl). k) IF control of 1NV-294 is lost from the control room, THEN: _ (1) Place the controller for 1NV-294 in the 100% demand position. _ (2) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrl Isol) (AB-551, JJ-55, Rm 231) to control charging flow as required in subsequent steps. I) Close the following valves:
- 1NI-9A (NV Pmp C/l Inj Isol)
- 1NI-10B (NV Pmp C/l Inj Isol).
m) IF 1NI-9AOR 1 NI-9A OR 1NI-10B 1NI-1 OB cannot be closed, THEN dispatch operator to close the affected valve(s). Refer to the following enclosure(s) for the affected valve(s):
- Enclosure 9 (locally Close 1NI-9A)
- Enclosure 11 (locally Close 1NI-10B).
n) Throttle charging and seal injection to maintain the following:
- Charging line flow between 60 GPM and 180 GPM
- NC pump seal injection flow.
(RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 EP/1/A/5000/E-0 23 of 61 DC~ Rev 36 DC!: ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
_ 0) WHEN 1NV-203A AND 1NV-202B are opened, THEN charging flow may be reduced below 60 GPM. _ p) GO TO Step 27.k.
- 2) Close the following valves: 2) Dispatch operator to close the affected valve(s). Refer to the
- 1NI-9A (NV Pmp C/l Inj Isol) following enclosure(s) for the 1NI-1 OB (NV Pmp C/l Inj Isol).
- 1NI-10B affected valve(s):
- Enclosure 9 (locally Close 1NI-9A)
- Enclosure 11 (locally Close 1NI-10B).
- j. Establish charging as follows:
_ 1) Throttle 1NV-294 (NV Pmps A&B 1) Perform the following: Disch Flow Ctrl) for 32 GPM charging line flow. _ a) Place the controller for 1NV-294 in the 100% demand position. _ b) Dispatch operator with a radio to throttle 1NV-295 (NV Pmps A & B Disch Ctrllsol) (AB-551, JJ-55, Rm 231) for 32 GPM charging line flow. _ c) Throttle 1NV-295 to control charging flow as required in subsequent steps. _ 2) Close 1NV-309 (Seal Water 2) Dispatch operator with radio to Injection Flow). perform the following: _ a) Close 1NV-308 (Seal Wtr Inj Flow Ctrl Isol) (AB-554, JJ-54, Rm 233) (ladder needed). _ b) Throttle 1NV-311 (Seal Wtr Inj Flow Ctrl Byp) (AB-555, JJ-54, Rm 233) to maintain 32 GPM seal water flow in subsequent steps.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 24 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- 3) Open the following valves: 3) Dispatch operator to open the affected valve(s). Refer to the
- 1NV-312A (Chrg Line Cont Isol) following enclosure(s) for the
- 1NV-314B (Chrg Line Cont Isol). affected valve(s):
- Enclosure 10 (Locally Open 1NV-312A)
- Enclosure 12 (Locally Open 1NV-314B).
_ 4) Verify 1NV-309 - ABLE TO BE _ 4) GO TO Step 27.j.6. OPERATED FROM THE CONTROL ROOM. _ 5) Place 1NV-309 in auto.
- 6) Perform the following:
- Maintain charging flow less than 180 GPM.
- Maintain 32 GPM seal water flow.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O EP/1/A/5000/E-O 25 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- k. Control charging as follows:
_ 1) Control charging flow to maintain Pzr level stable. _ 2) Verify Pzr level - STABLE OR 2) IF Pzr level is decreasing. decreasing, THEN: INCREASING. a) Open the following valves:
- 1 NI-9A (NV Pmp C/l Inj Isol) 1NI-9A
_ . 1NI-10B (NV Pmp C/l Inj Isol). b) Close the following valves:
- 1NV-312A (Chrg Line Cont Isol)
- 1NV-314B (Chrg Line Cont Isol).
_ EP/1/A15000/F-O c) Implement EP/1/A/5000/F-O (Critical Safety Function Status Trees). _ d) GO TO EP/1/A15000/ES-1.2 EP/1/A/5000/ES-1.2 (Post lOCA Cooldown And Depressurization Depressurization). ). I. Ensure the following containment isolation signals - RESET:
- Phase A
- Phase B.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/SOOO/E-0 EP/1/A/5000/E-O 26 of 61 DC~ Rev 36 DCt ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 27. (Continued)
- m. Establish VI to containment as follows: m. Perform the following:
- Ensure 1 VI-77B (VI Cont Isol) -
1VI-77B 1) 1} Align N2 to the Pzr PORVs by OPEN. opening the following valves:
- Verify VI pressure - GREATER THAN
- 1NI-438A (Emer N2 From CLA A 85 8S PSIG. To 1NC-34A)
- 1NI-439B (Emer N2 From CLA B To 1NC-32B).
_ 2} IF VI pressure is less than 85
- 2) 8S PSIG, THEN dispatch operator to ensure proper VI compressor operation.
- n. Concurrently:
EP/1/A/SOOO/F-0 (Critical
- Implement EP/1/A/5000/F-0 Safety Function Status Trees).
EP/1/A/SOOO/ES-1.1 (Safety
- Monitor EP/1/A/5000/ES-1.1 Injection Termination), Enclosure 1 (Foldout Page)
EP/1/A/SOOO/ES-1.1 (Safety _ .* GO TO EP/1/A/5000/ES-1.1 Injection Termination), Step 12.
- 28. Implement EP/1/A15000/F-O (Critical Safety Function Status Trees).
- 29. Control S/G levels as follows:
- a. Verify N/R level in all S/Gs - GREATER a. Maintain total feed flow greater than THAN 11%. 450 4S0 GPM until at least one S/G N/R level is greater than 11 %.
- b. Throttle feed flow to maintain all S/G b. IF N/R level in any S/G continues to N/R levels between 11 % and 50%.SO%. increase in an uncontrolled manner, EP/1/A/SOOO/E-3 THEN GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-0 EP/1/Al5000/E-0 27 of 61 DC~ Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 30. Verify secondary radiation is normal as follows:
- a. Ensure the following signals - RESET:
_ 1) Phase A Containment Isolations _ 2) CA System valve control _ 3) KC NC NI NM St signals.
- b. Align all S/Gs for chemistry sampling.
- c. Perform at least one of the following:
_ . Notify Chemistry to sample all S/Gs for activity. OR _ . Notify RP to frisk all cation columns for activity.
- d. Verify the following EMF trip 1 lights- EP/1/A15000/E-3 (Steam
- d. GO TO EP/1/Al5000/E-3 DARK: Generator Tube Rupture).
- 1EMF-33 (Condenser Air Ejector Exhaust)
- 1EMF-26 (Steamline 1A)
- 1EMF-27 (Steamline 1B)
- 1EMF-28 (Steamline 1C)
(Steamline
- 1EMF-29 (Steam line 1D).
- e. WHEN activity results are reported, e. Perform the following:
THEN verify all S/Gs indicate no activity. _ 1) Notify station management to evaluate S/G(s) activity results. _ 2) IF S/G(s) activity indicate a SGTR, THEN GO TO EP/1/A15000/E-3 EP/1/Al5000/E-3 (Steam Generator Tube Rupture).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-O EP/1/AlSOOO/E-O 28 of 61 280f61 Rev 36 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 31. Verify auxiliary building radiation is Evaluate cause of abnormal conditions normal as follows: as follows:
(Au x Bldg Ventilation) trip 1 light
- EMF-41 (Aux a. Monitor OAC EMF alarms, OAC VA
-DARK Graphic, and area monitor EMFs to determine location of activity.
- All area monitor EMF trip 1 lights - DARK
- b. Dispatch operator to locate potential leak.
- c. IF cause of alarm is LOCA outside containment, THEN GO TO EP/1/N5000/ECA-1.2 (LOCA Outside EP/1/AlSOOO/ECA-1.2 Containment).
- 32. Verify PRT conditions are normal as Evaluate following possible causes of follows: abnormal PRT conditions:
- PRT pressure - LESS THAN 8 PSIG
- Pzr safety temperatures
- Pzr safety relief flow indicated
- PRT level - LESS THAN 89%
- Pzr PORVs PzrPORVs
- Rx head vents
- PRT temperature - LESS THAN 130°F.
- NC pump seal return header relief
- Letdown orifice header relief.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 29 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 33. Ensure 5/1 - RESET:
- a. ECCS. a. IF either reactor trip breaker is closed, THEN:
_ 1) 1} Ensure reactor trip breakers - OPEN. _ 2} WHEN trip breakers open, THEN 2) reset ECCS.
- b. DIG load sequencers. b. Dispatch operator to open the affected sequencer(s) control power breaker:
sequencer(s}
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB) (AB-560, BB-46, Rm 372).
- c. IF AT ANY TIME a B/O occurs, THEN restart SII S/I equipment previously on.
- 34. Ensure the following containment isolation signals - RESET:
- Phase A
- Phase B.
- 35. Establish VI to containment as follows: Perform the following:
- Ensure 1VI-77B (VI Cont Isol) - OPEN. a. Align N2 to the Pzr PORVs by opening the following valves:
- Verify VI pressure - GREATER THAN 85 PSIG.
- 1NI-438A (Emer N2 From CLA A To 1NC-34A)
- 1NI-439B (Emer N2 From CLA B To 1 NC-32B).
- b. IF VI pressure is less than 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/N5000/E-0 EP/1/A/5000/E-0 30 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 36. Verify criteria to stop operating NO pumps as follows:
- a. NC pressure - GREATER THAN a. GO TO EP/1/N5000/E-1 EP/1/A/5000/E-1 (Loss Of 285 PSIG. Reactor Or Secondary Coolant).
- b. NC pressure - STABLE OR b. GO TO Step 37.
INCREASING.
- c. At least one ND pump - ON. c. GO TO Step 36.e.
- d. Ensure all ND pump(s) with suction aligned to FWST - STOPPED.
- e. IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart ND pumps.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O EP/11A15000/E-O 31 of 61 Rev 36 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 37. Verify conditions to stop operating DIGs as follows:
- a. At least one DIG - ON. a. GO TO Step 38.
- b. Verify 1ETA is energized by offsite b. Perform the following:
power as follows: _ 1) Attempt to restore offsite power to 1}
* "DIG 1A BKR TO ETA" - OPEN affected switchgear. REFER TO AP/1/A155001007 (Loss of Normal AP/11A155001007
- 1ETA - ENERGIZED. Power).
_ 2) 2} GO TO Step 37.d.
- c. Dispatch operator to stop 1A DIG and place in standby readiness. REFER OP/11A163501002 (Diesel Generator TO OP/1/A163501002 Operation).
- d. Verify 1ETB is energized by offsite d. Perform the following:
power as follows: _ 1) 1} Attempt to restore offsite power to
* "DIG 1B BKR TO ETB" - OPEN affected switchgear. REFER TO AP/1/A155001007 (Loss of Normal AP/11A155001007
- 1ETB - ENERGIZED. Power).
_ 2) 2} GO TO Step 38.
- e. Dispatch operator to stop 1 B DIG and place in standby readiness. REFER TO OP/1/A163501002 OP/11A163501002 (Diesel Generator Operation).
- 38. RETURN TO Step 21.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A1S000/E-0 EP/1/A/5000/E-0 320f61 32 of 61 Enclosure 1 - Page 1 of 1 Rev 36 DC~ Foldout Page
- 1. IF any S/G(s) suspected ruptured, THEN perform the following:
- WHEN the following conditions met:
- Total CA flow - GREATER THAN 4S0 450 GPM AND
- All intact S/G(s) N/R level-level - GREATER THAN 11 11%(29%
%(29% ACC)
THEN throttle feed flow to ruptured S/G(s) to maintain ruptured S/G(s) N/R level between 11 %(29% ACC) and 39%.
- 2. NC Pump Trip Criteria:
- IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:
- At least one NV NVor or NI pump - ON
- NC subcooling based on core exit TICs - LESS THAN OR EQUAL TO O°F.
- 3. CA Suction Source Switchover Switch over Criteria:
- IF either of the following annunciators are lit, THEN REFER TO AP/1/A1SS001006 AP/1/A/55001006 (Loss of S/G Feedwater):
1AD-5, H/4 "CACST LO LEVEL"
- 1AD-S, OR
- 1AD-8, B/1 "UST LO LEVEL".
- 4. Position Criteria for 1 NV-202B and 1NV-203A (NV Pumps A&B Recirc 1501): Isol):
- IF NC pressure is less than 1S001500 PSIG AND NV S/I f10wpath flowpath is aligned, THEN close 1NV-202B and 1NV-203A.
- IF NC pressure is greater than 2000 PSIG, THEN open 1NV-202B and 1NV-203A.
5. S. Cold Leg Recirc Switchover Criterion:
- IF FWST level decreases to 37% (1AD-9, D/8 "FWST 2/4 LO LEVEL" lit), AND an S/I SII has occurred, THEN GO TO EP/1/A1S000/ES-1.3 EP/1/A/5000/ES-1.3 (Transfer To Cold Leg Recirculation).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O 33 of 61 Enclosure 2 - Page 1 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Verify proper VCIYC operation as OP DOES THIS ENCLOSUR follows:
- a. Verify one train of the following a. Perform the following:
equipment is in operation: _ 1) Shift operating VCIYC trains.
- YC chiller REFER TO Enclosure 6 (Shifting
- CR AHU-1 CRAHU-1 Operating VCIYC Train).
- CRAAHU-1
- CRA PFT-1. 2) IF no train can be properly aligned, THEN dispatch operator and IAE/Maintenance to restore at least one train of VCIYC. REFER TO the following:
- OP/O/Al6450/011 (Control Room Area Ventilation/Chilled Water System)
- EM/O/Al5200/001 (Troubleshooting Cause For Improper Operation of VCIYC System).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/A15000/E-O 34 of 61 Enclosure 2 - Page 2 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE ACTIONIEXPECTED RESPONSE NOT OBTAINED
- 1. (Continued)
- b. Verify the following alarms - DARK: b. IF chlorine odor is detected in the Control Room, THEN perform the
- 1AD-18, A/8Al8 "UNIT 1 INTAKE HI following based on the status of given CHLORINE 1A" alarms:
- 1AD-18, 8/8B/8 "UNIT 1 INTAKE HI 1) IF detectors on both unit intakes are 1)
CHLORINE 18" 1B" in alarm, THEN:
- 1AD-18, D/8 "UNIT 2 INTAKE HI a) Ensure the following VC intake CHLORINE 2A" dampers - CLOSED:
- 1AD-18, E/8 "UNIT 2 INTAKE HI
- 1VC-5B 1VC-58 (CRA Filt Inlet)
CHLORINE 2B".28".
- 1VC-6A (CRA Filt Inlet)
- 2VC-5B 2VC-58 (CRA Filt Inlet)
- 2VC-6A (CRA Filt Inlet).
_ b) GO TO Step 1.d.
- 2) IF Unit 1 intake HI chlorine detector(s) in alarm, THEN:
a) Ensure the following VC dampers - CLOSED: _ . 1VC-5B 1VC-58 (CRA Filt Inlet) _ . 1VC-6A (CRA Filt Inlet). b) Ensure the following dampers-dampers - OPEN: _
- 2VC-5B 2VC-58 (CRA Filt Inlet)
_
- 2VC-6A (CRA Filt Inlet).
_ c) GO TO Step 1.d. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 35 of 61 Enclosure 2 - Page 3 of 7 Rev 36 DC~ Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. (Continued)
- 3) IF Unit 2 intake Hi chlorine detector(s) in alarm, THEN:
a) Ensure the following VC dampers - CLOSED: _
- 2VC-5B (CRA Filt Inlet)
_ .* 2VC-6A (CRA Filt Inlet). b) Ensure the following dampers - OPEN: _ . 1VC-5B (CRA Filt Inlet) _ . 1VC-6A (CRA Filt Inlet). _ c) GO TO Step 1.d.
- c. Ensure the following VC dampers -
OPEN: _ .* 1VC-5B (CRA Filt Inlet) _ .* 1VC-6A (CRA Filtlnlet) Filt Inlet) _
- 2VC-5B (CRA Filt Inlet)
_
- 2VC-6A (CRA Filt Inlet).
- d. Repeat Step 1 of this enclosure until notified by station management as follows:
_
- At least once every 8 hours OR
_
- Any time VCIYC related annunciators 1AD-18 actuate.
on 1AD-18
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-0 EP/1/N5000/E-0 36 of 61 Enclosure 2 - Page 4 of 7 Rev 36 DC~ Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. Ensure proper VA System operation as follows:
- Ensure the following fans - OFF:
- ABUXF 1A
- ABUXF 1B.
- Ensure VA System filter is in service as follows:
- 1ABF-D-12 & 19 (VA Filter A Bypass Dampers) - CLOSED 1ABF-D;.5 & 20 (VA Filter B Bypass
- 1ABF-D-5 Dampers) - CLOSED.
- Ensure the following fans - ON:
- ABFXF-1A
- ABFXF 1B.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/A15000/E-0 37 of 61 Enclosure 2 - Page 5 of 7 DC~ Rev 36 DC:::: Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. Verify proper VE System operation as follows:
- a. VE fans - ON. a. Manually start fan(s).
- b. Annulus pressure - BETWEEN b. Perform the following:
-1.4 IN. WC AND -1.8 IN. WC.
- 1) IF annulus pressure is more positive than -1.4 in. WC, THEN:
a) Verify flow indicated on the following indications:
* "VE 1A FLOW TO STACK"
* "VE 1 B FLOW TO STACK".
1B b) IF flow is not indicated, THEN dispatch operator to verify status of the following dampers based on their local indication or their operating piston rods being extended 4" to 6":
- 1AVS-D-2 (VE A Trn Recirc Damp) (AB-603, JJ-51 , Rm 500) - CLOSED
- 1AVS-D-7 (VE B Trn Recirc Damp) (AB-603, HH-52, Rm 500) - CLOSED
- 1AVS-D-3 (VE A Trn Exh Damp) (AB-603, JJ-52, Rm 500) - OPEN
- 1AVS-D-8 (VE B Trn Exh Damp) (AB-603, HH-52, Rm 500) - OPEN.
_ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER EM/1/A/52001002 TO EM/1/A15200/002 (Troubleshooting Cause For VE System Hi/lo Hi/Lo Pressure). _ d) GO TO Step 3.c. (RNO continued on next page)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-0 EP/1/N5000/E-0 38 of 61 Enclosure 2 - Page 6 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued)
- 2) IF annulus pressure is more negative than -1.8 in. WC, THEN:
_ a) Determine which VE train indicates highest discharge flow to stack. _ b) Within 2 hours, ensure VE train that indicates highest discharge flow to stack is secured. _ c) Consult plant engineering staff and notify IAE/Maintenance to troubleshoot and repair. REFER TO EM/1/N5200/002 EM/1/A/5200/002 (Troubleshooting Cause For VE Hi/Lo Pressure). System Hi/lo
- c. Repeat Step 3.b every 30 minutes until notified by station management.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/Al5000/E-O EP/1/A/5000/E-O 39 of 61 Enclosure 2 - Page 7 of 7 DC~ Rev 36 DCS Ventilation System Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. Record time ventilation systems are verified on following table:
TIME SYSTEM INITIALS (Ve, VE)
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-0 EP/1/A/5000/E-0 400f61 40 of 61 Enclosure 3 - Page 1 of 1 Rev 36 DC~ Opposite Unit Ventilation Verification ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Ensure proper Unit 2 VA System operation as follows:
- Ensure the following fans - OFF:
- ABUXF-2A
- ABUXF-2B.
- Ensure VA System filter is in service as follows:
- 2ABF-D-12 & & 19 (VA Filter A Bypass Dampers) - CLOSED
- 2ABF-D-5 & & 20 (VA Filter B Bypass Dampers) - CLOSED.
- Ensure the following fans - ON:
- ABFXF-2A
- ABFXF-2B.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A15000/E-O 41 of 61 Enclosure 4 - Page 1 of 4 Rev 36 DC~ DC:: NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. Verify at least one NC pump - ON. Perform the following:
- a. Use NC T-Colds to determine NC RO DOES THIS ENCLOSURE IRO temperature as required in subsequent steps.
- b. GO TO Step 4.
- 2. Use NC T-Avg to determine NC temperature as required in subsequent steps.
- 3. IF AT ANY TIME NC pumps are tripped, THEN use NC T T-Colds
-Colds to determine NC temperature as required in subsequent steps.
- 4. Verify one of the following: GO TO Step 7.
- NC temperature - STABLE AT LESS THAN OR EQUAL TO 55rF.
OR
- NC temperature - TRENDING TO 55rF.
- 5. Continue to monitor NC temperature.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/11A15000/E-O EP/1/A/5000/E-O 42 of 61 Enclosure 4 - Page 2 of 4 Rev 36 DC~ NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. Do not continue in this enclosure until one of the following occurs:
- NC temperature - GREATER THAN 55rF 557°F AND INCREASING IN AN UNCONTROLLED MANNER.
OR
- NC temperature - GREATER THAN 55rF 557°F AND STABLE.
OR
- NC temperature - LESS THAN 55rF AND DECREASING IN AN UNCONTROLLED MANNER.
- 7. Verify NC temperature - LESS THAN Perform the following:
557°F AND DECREASING.
- a. IF NC temperature is greater than 557°F AND increasing, THEN stabilize 55rF NC temperature at 55rF as follows:
- 1) IF steam dumps are available, THEN use steam dumps.
- 2) IF steam dumps are not available, THEN use S/G PORVs.
- b. IF the following conditions exist:
- NC temperature is greater than 55rF 557°F and stable
- Time and manpower is available, THEN stabilize NC temperature at 55rF 557°F as follows:
- 1) IF steam dumps are available, THEN use steam dumps.
- 2) IF steam dumps are not available, THEN use S/G PORVs.
- c. GO TO Step 9.
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O EP/1/N5000/E-O 43 of 61 Enclosure 4 - Page 3 of 4 Rev 36 DC~ NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. cool down as Attempt to stop the NC cooldown follows:
- a. Ensure all steam dumps - CLOSED.
- b. Ensure all S/G PORVs - CLOSED. b. IF any S/G PORV cannot be closed, THEN close its isolation valve.
- c. Ensure S/G blowdown is isolated.
- d. Close the following valves:
- 1SM-77A (S/G 1A Otlt Hdr Bldwn CN)
- 1SM-76B (S/G 1B Otlt Hdr Bldwn CN)
- 1SM-75A 1SM-75A (S/G 1 C Otlt Hdr Bldwn 1C CN)
- 1SM-74B (S/G 1D Otlt Hdr Bldwn CN).
- e. Depress and hold "SN BEFORE SEAT DRN" "CLOSE" pushbutton (1 MC-3) to close the following valves:
- 1SM-41 (Stop Vlv #1 Before Seat Drn)
- 1SM-44 (Stop Vlv #2 Before Seat Drn)
- 1SM-43 (Stop Vlv #3 Before Seat Drn) 1SM-42 (Stop Vlv #4 Before Seat
- 1SM-42 Drn).
CNS REACTOR TRIP OR SAFETY INJECTION PAGE NO. EP/1/A/5000/E-O 440f61 44 of 61 Enclosure 4 - Page 4 of 4 Rev 36 DCS DC!:: NC Temperature Control ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. (Continued)
- f. Verify NC cooldown - STOPPED. f. IF cool down continues, THEN throttle cooldown feed flow as follows:
- 1) IF S/G N/R level is less than 11%
(29% ACC) in all S/G's, THEN throttle feed flow to achieve the following:
- Minimize cooldown
- Maintain total feed flow greater than 450 GPM.
- 2) WHEN N/R level is greater than 11 % (29% ACC) in at least one S/G, THEN throttle feed flow further to achieve the following:
- Minimize cooldown cool down
- Maintain at least one S/G N/R level greater than 11 %
(29% ACC).
- 3) IF cooldown continues, THEN close the following valves:
- All MSIVs
- All MSIV bypass valves.
- 9. Continue to perform the actions of this enclosure as required to ensure one of the following:
- NC temperature - STABLE AT LESS THAN OR EQUAL TO 557°F.
55rF. OR
- NC temperature - TRENDING TO 55rF.
557°F.
I I I I
Duke Energy Procedure No. Catawba Nuclear Station EP/I/Alsooo/E-l EP/I/A/SOOO/E-l Loss of Reactor or Secondary Coolant Revision No. 023 Electronic Reference No. CP0094CP Continuous Use PERFORMANCE I
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
(ISSUED) - PDF Format [At f t some point in this procedure, FWST level will drop to 37% and they will transition to ES-1.3 Iwill I
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 EP/1/A/SOOO/E-1 1 of 29 Revision 23 A. Purpose This procedure provides actions to recover from a loss 1055 of reactor or secondary coolant. B. Symptoms or Entry Conditions This procedure is entered from:
- a. EP/1/A15000/E-O EP/1/A/SOOO/E-O (Reactor Trip Or Safety Injection), Step 22, and EP/1/A15000/FR-H.1 EP/1/A/SOOO/FR-H.1 EP/1/A/SOOO/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 41 and EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 43 when a Pzr PORV is stuck open and its isolation valve cannot be closed.
EP/1/A/SOOO/E-O (Reactor Trip Or Safety Injection), Step 26, with any of the following
- b. EP/1/A15000/E-O symptoms: high containment radiation, high containment pressure, or high containment recirculation sump level.
- c. EP/1/A15000/E-O EP/1/A/SOOO/E-O (Reactor Trip Or Safety Injection), Step 36, EP/1/A15000/ECA-2.1 EP/1/A/SOOO/ECA-2.1 EP/1/A/SOOO/FR-H.1 (Uncontrolled Depressurization Of All Steam Generators), Step 8 and EP/1/A15000/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 46, when NC pressure is less than the shutoff head pressure of the NOND pumps.
- d. EP/1/A15000/ES-1.1 EP/1/A/SOOO/ES-1.1 (Safety Injection Termination), Step 14 and EP/1/A15000/ES-1.1 EP/1/A/SOOO/ES-1.1 (Safety Injection Termination), Step 33, and EP/1/A15000/FR-1.2 EP/1/A/SOOO/FR-1.2 (Response To Low S/I has to be reinitiated.
Pressurizer Level), Step 8, if SII
- e. EP/1/A15000/E-2 EP/1/A/SOOO/E-2 (Faulted Steam Generator Isolation), Step 12, after identification and isolation of a faulted S/G.
- f. EP/1/A/SOOO/ECA-0.2 (Loss Of All AC Power Recovery With SII Required), Step 15, EP/1/A15000/ECA-O.2 1S, after normal injection mode conditions are established.
EP/1/A/SOOO/ECA-1.2 (LOCA Outside Containment), Step 3, when a LOCA outside
- g. EP/1/A15000/ECA-1.2 containment is isolated.
- h. EP/1/A15000/FR-C.1 EP/1/A/SOOO/FR-C.1 (Response To Inadequate Core Cooling), Step 21 and EP/1/A/SOOO/FR-C.1 (Response To Inadequate Core Cooling), Step 31, and EP/1/A15000/FR-C.1 EP/1/A15000/FR-C.2 EP/1/A/SOOO/FR-C.2 (Response To Degraded Core Cooling), Step 24, after core cooling has been established.
- i. EP/1/A/SOOO/FR-H.1 (Response To Loss Of Secondary Heat Sink), Step 39, after EP/1/A15000/FR-H.1 secondary heat sink has been re-established and all Pzr PORVs are closed.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/Al5000/E-1 EP/1/A/5000/E-1 2of29 20f29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Monitor Enclosure 1 (FoldO'ut Page).
2.;'f)~
- 2. VerifY mainsteamlines are intact as IF pressure in any S/G is decreasing in foil follows: an uncontrolled manner OR any S/G is depressurized, THEN:
_ **fill~~.~.t?m~~l.Ire~;'~TA~4E<J51R AHS/G pressures - STABLE oR. INCREASING a. IF any faulted S/G(s) feedlines OR steamlines are not isolated, THEN:
- All S/Gs - PRESSURIZE8.
_ 1) IF EP/1/A/5000/E-2 EP/1/Al5000/E-2 (Faulted Steam Generator Isolation) has been performed for the affected S/G, THEN GO TO Step 2 RNO b. _ 2) GO TO EP/1/A/5000/E-2 EP/1/Al5000/E-2 (Faulted Steam Generator Isolation).
- b. IF the affected S/G(s) is faulted outside containment, THEN request RP to perform the following:
_ 1) Monitor the area of the steam fault for radiation. _ 2) Notify the control room of any abnormal radiation conditions. 3.*c~Rlto[iRtact*SI@ileM~i~*~$;*1f~O*d.~$:
- 3. CodtroUntact S/G >Ievels as'10110'l/s:
'8I\~.rifYN{RI~.V~.!iq~II.I'.
- a. Verify N/R level in aU intact S/Gs - a. Maintain total feed flow greater than GREATER THAN 11% {29% ACC).
GIRBATBRTHAN11Wo 450 GPM until at least one intact S/G N/R level is greater than 11 % (29% ACC).
- b. TAr()ttI~ feed floW t()l11aintaira'lIi.ntact b. IF N/R level any S/G continues to
'f3IG N/R levels betWtren '11% increase in an uncontrolled manner, (29%ACC) and 50%. THEN GO TO EP/1/A/5000/E-3 EP/1/Al5000/E-3 (Steam Generator Tube Rupture).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/11A15000/E-1 EP/1/A/5000/E-1 30f29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4 V~rity* *secondaryradiatioh 4..~~~i,~ ~*~.cotl.qary'rl(ldi(ltiQ:pi§,,*p'QJl"ij~r~§ is normal as f()II()Ws!. follows: a;a. .* )1:28§pre** Ensure the tb~Jqn~Wi following ng*.***~I!;}.Q(3I§ifR~$Eftr:} signals - RESET: _ 1) t)Rhase*A*Cont(3inmebt Phase A Containmellt
- i'soIatibns Isolations
_ 2'~f.$Y'§(e[J)*vaIYecq!'i{rqr _ 2) CA System valveconfrol _ .3) _ ~.~. {~G.t\fO'.~.INM., KCNC NINM * .St $t~ignaf~i signals. fj:**~II~!'i.'iall., b: Align all * '$!r::,.~(:ftironerniSt/j&"~'act1~IIr:1~ S/Gsfor Chemistry sampling.. c:{3eil~rrnatJ~a~t c.Perform atleastone*. one(jt'1heJ~Ilq~!i6g: of the following: _ . . Notify f'l!.~.~if>"9h~rnistry.tti$am~I~(all/$Z(3$ Chemistry to .sampleall S/Gs for activity. fqraotivitY'.* OR _."~~1ify~PtqfriSkall.* _ . Notify RP to frisk all cation daHbneoltlmo~ columns f~r(3otivitY'; for activity. d.verify,the fol/owing EMF trip J lights c. d. GO TO EP/11A15000/E-3 EP/1/A/5000/E-3 (Steam DARK: Generator Tube Rupture).
*.1R~F+3~'*(Condens!r'f.ir§jeGt¢r 1EMF-33 (Condenser Air Ejector E~!:Jatfst)
Exhaust)
.... 1EM~;:26($!~CiI[J)nr1e)jf.)
.1 EMFC:26 (Steamline:]A)
- 1EMF-27 .(stea.rm.
*1S'ME'"Zt i (Steamlineli i'\e\Jl?)
1B)
*.1EMF:*28 Ste(jlrt1lin! t~)
1'i1:2MFi28 {(Steamline 1C)
- '.ij.I:EK.\1~i~9{st~amli 1EMFL29 (Steamline1 O.ei;:1!lP.J:
D).
- e. WHEN activity reSLilts areieport~d. e. Perform the following:
THEN verify all S/Gs indicate'iio activity.* . _ 1) Notify NotifY' station management to evaluate S/G(s) activity activitY' results. _ activitY' indicate a SGTR.
- 2) IF S/G(s) activity SGTR, EP/11A15000/E-3 THEN GO TO EP/1/A/5000/E-3 (Steam Generator Tube Rupture).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/N5000/E-1 40f29 4 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED IsoP! 5*"~rifY~~r:~gR,,¥,.*cln(l.*J$oI~tion~fJ!v~
- 5. Verify Pzr PQRV.andisolation valve L~ I status *a$.fQIrQWs:
S\fJtIJS asfoIrows:
~*~w~ijt9al!11zr*.B>R\lisolatioh\,ialve$L
- a. PQwer to all Pzt PORV isolation valves - a. Dispatch operator to restore power to AXI,Ai.IHABHE.
AVAILABLE. affected Pzr PORV isolation valve(s):
- 1EMXD-F02C (PORV Isol Motor (1 NC31 B>>
B)) (AB-560, BB-50, Rm 372)
- 1EMXC-F03C (Pressurizer Power Operated Relief Isol. Valve 1NC33A)
(AB-577, BB-50, Rm 496)
- 1EMXD-F05A (PORV Isol Motor NC35B)) (AB-560, BB-50, Rm 372).
(1 NC35B>>
- b. All Pzr PORVs - CLOSED. b.IFF?trprEt$$l.;I~Etisl~$$than.231.5PSt(3,
- b. IF Pzr pressure is less than 2315 PSfG, ZEHENl THEN:
_t) tv1~ng~ll~iCIQ$~::R~rPORV{
- 1) Manually closepzr PORV(s). $~.
_.~)IF.~:@Y~~r.:~(:)R~carlrl~t~~***ctosed, _ 2) IF ariyPzr PORV cannot be closed, ZEHEN.**.cIQseits* THEN close its.*.*.isolation'l,(alve, isolation valve.
- c. Mleastone'PzrJ:;)*ORV.
At least one Pzr PORV isolation isolation valve .-- c. Open one Pzr PORV isolation valve OP6N: OPEN. unless it was closed to isolate an open Pzr PORV.
- d. IF AT ANYTIME aPzr PORVopens
- d. ~R\{rq~:~I'1~
due to high pressure, THEN, afterBzr after Pzr pre~ pressure decreases to less than han 2~~:*~*.'i.* 231.5 . . (b;*el'l~l.;ItEjtl"le:val.6Iosesot PSIG, enswe the valve closes or is.tsolated; is isolated.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 EP/1/A/SOOO/E-1 50f29 S of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 6. Verify SIIJerrninatiohc;riteria as follows:
- a. NQs NtCsubcoolingc.;lnt"l99~§~gc.;ln**pore~gjtl'rp~
based on core ekitT/Cs a. GO TO Step 6.f.
-GIR
-'GREATER THAN O°F.
RmIHANGA81 bb..V~("ify secondary *lie;:!t~in~*asf0I1QWs: Verify .s§¥qQoti;:!ry heat sink as follows: b. GO TO Step 6.f. 6.f.
~¥~J:ii~tali~~~tpt1ejrlt~~:t~J
- N/R leve.lin.at least one intact S/G-iATE;'~,:rH~~:**:1**1%.*{~9 GREATER THAN 11% (29% ACC)
OR
- TotalfeedJIQw to,all11. intact j~':l;!i?:t§IGs S/Gs- ...
GREATER THAN 450 SO GPM: GPM.
.~~i?:i$:rJXE5LE.*OR
- c. NC pressure::'STABLE OR c.GO TOStep6.f~
INCREASING. ISIG:. d.~zrJevel~.GR5AT5RmHAN1*1%
- d. pzrlevel- GREATER THAN 11% d. Perform tlie the following:
(20% ACC). _ 1) IF NC pressure is increasing AND normal Pzr spray is available, THEN attempt to stabilize NC pressure using normal Pzr spray. _ 2) GO TO Step 6.f.
- e. GO TO EP/1/A/SOOO/ES-1.1 EP/1/A/5000/ES-1.1 (Safety Injection mermination).
Termination).
- f. ~1It~r91ir1~t(p~~dteIi~)(GEIf6R MonitorS/ltermination criteria. REFER I()syr~*. :2. . (~~I.l'errojllati()111 TO Encloslire2 (S/iTermination Crjt~ria).
JI _ g. IF AT ANY miME TIME S/I termination criteria is met while wliile in this tliis procedure, THEN GETURN TO Step 6. RETURN
- 7. '.N(:;~
Verify proper NS pump. *operation prqp~J'* *~§Pi.ltJlP qp¢r~(iqt!~s as ISOfj .fol .8: folloW's:
- a. Atleas,t,6ne NS.pump"- ON. a. Perform tlie the following:
_ Am ANY TIME an NS pump(s)
- 1) IF AT while in tliis starts wliile this procedure, THEN perform Step 7.
_ 2) GO TO Step 8.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 EP/1/Al5000/E-1 6of29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued) b.\l~ri{Y*tb*efoHg&ving\t19Iye§***:"*~p'c;N!
- b. Verify the following valves - OPEN: b. Perform the following:
_ ..til7:}iY'+~?';§(&tDPurnp~A':Su&tFtgm _ 1FW.:.27A(ND Pump 1A Suct From _ 1) IF NS pump(s) have previously FWSTJ 5*W§'1i) been stopped more than once, THEN GO TO Step 8. _ '~li:~I7W".$$E3}~&P'~lJrnI?1B§ucti:Eroqi*** _ .{'1FW-:-55B (NDPump1B SuctFrom FWST). 5W§'1i)'* _ 2) WHEN containment pressure is less than 1 PSIG, THEN perform Steps 7.e through 7.h. _ 3) GO TO Step 8. i[jlJn~btf~ueS$~re"*.*.;ll;.c;SS*.T8;A;t\J
- c. C:ontainment pressure -LESS THAN c.Fil~ffc;>rqi:~hef01:I<>Wing:
- c. Perform the following:
BIG; 2.4PSIG. _ 1) *V'{J"I!N~()ntainrn~rltl?r WHEN containment pressure is less reisless th~~~.4p>BIG, than 2.4 PSIG, THEN P rm perform
§tfilp7; Step 7.
_ 2) _ ~)'GOq;OStep8; GO TO Step 8.
- d. Verify operating NS pump(s) - HAVE d. IF NS pump(s) has previously been REMAINED RUNNING SINCE INITIAL stopped, THEN GO TO Step 8.
PHASE B SIGNAL.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A1S000/E-1 EP/1/A/5000/E-1 70f29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. (Continued)
- e. Ensure SIIS/I - RESET:
_ 1) ECCS. 1) Perform the following: _ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ b) WHEN trip breakers open, THEN reset ECCS. _ 2) DIG load sequencers. 2) Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA)
(AB-S77, BB-46, Rm 496) (AB-577,
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB)
(AB-S60, BB-46, Rm 372). (AB-560, _ 3) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on.
- f. Reset NS.
_ g. Stop NS pumps.
- h. Close the following valves:
- 1NS-29A (NS Spray Hdr 1A Cont Isol)
- 1NS-32A (NS Spray Hdr 1 1A A Cont Isol)
- 1NS-15B 1NS-1SB (NS Spray Hdr 1B Cont Isol)
- 1NS-12B (NS Spray Hdr 1B Cont Isol).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 EP/1/Al5000/E-1 8of29 80f29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. ti,c:(t9:~t9P Verify criteria op~rating~p to stop operating ND fblloWs!
pumpsasfonows:
~~,~r~s~~te***';i!s~~~1;:SRJH~f\J
- a. N,C,pressure - GREATER THAN a. GO TO Step 10.
285,)=)8JG; 285PSIG.
- b. NC pressure - STABLE OR b. GO TO Step 9.
INCREASING.
- c. At least one ND pump - ON. c. GO TO Step 8.h.
- d. ND pumps suction - ALIGNED TO d. GO TO Step 9.
FWST.
- e. Verify FWST level-level - GREATER THAN e. Perform the following:
45%.
- 1) IF AT ANY TIME the following conditions exist:
_
- Any ND pump(s) operating with flow - LESS THAN 1000 GPM TO THE LOOPS AND
- KC to the associated ND HX -
ISOLATED, _ THEN stop the affected ND pump(s) within 3 hours. _ 2) GO TO Step 9.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 EP/1/A/5000/E-1 90f29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. (Continued)
- f. Ensure S/I - RESET:
_ 1) ECCS. 1) Perform the following: _ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ b) WHEN trip breakers open, THEN reset ECCS. _ 2) DIG load sequencers. 2) Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA)
(AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB)
(AB-560, BB-46, Rm 372). _ 3) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on. _ g. Stop ND pumps.
- h. IF AT ANY TIME NC pressure decreases to less than 285 PSIG in an uncontrolled manner, THEN restart ND pumps.
- 9. Verify NC and S/G pressures as follows:
- a. All SIG pressures - STABLE OR a. IF SIG pressure is decreasing due to a INCREASING. S/G, THEN RETURN TO Step 1.
faulted SIG,
- b. NC pressure - STABLE OR b. RETURN TO Step 1.
DECREASING.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 10 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 1O. ¥~ri'()(jn?iti()rlS**tost()P.***()p~r~til1g'lJ'lS$ Verify conditions to stop operating DIGs asfoJloWs; as follows:
- a. At least one DIG -ON. a. GO TO Step 11.
- b. Verify1i::TA 's*1~e9~~g.i.teCJ*,.byoff§i.te is energized by offsite b. Perform the following:
allOWs: power as*foliows: _ 1} Attempt to restore offsite power to
* "D/G1ABKRTO ETA" - OPEN. affected switchgear. REFER TO AP/1/A155001007 (Loss of Normal
- 1ETA..: ENERGIZED. Power).
_ 2} GO TO Step 10.d.
- c. WHEN.S/I is reset, THEN dispatch operafor.hstop 1A DIG and place in standby readiness. REFER TO OP/11JY63501002 {Diesel Generator Operation} ;
d .\t'~tifY~I3T.
- d. n@rgi~edby,,6ff$ite Verify 1ETBisenergized by offsite d. Perform the following:
power as follows: POWepasfti.) s: _ 1} Attempt to restore offsite power to I~D/1BiBIXRrraETB'r.:aPlEN
* "DIG tBBKR TO ETB" - OPEN affected switchgear. REFER TO AP/1/A155001007 (Loss of Normal
- 11BTB::S,:BNlER(1SIZBD.
ETB '- ENERGIZED. Power). _ 2} IF 1ETA is energized from offsite power, THEN GO TO Step 10.f.10J. _ 3} GO TO Step 11.
- e. WHEN S/lisreset, THEN dispatch operator to stop 1Bt>~(3andplace in standby readines$:REFERTO OP/1/A163501002 (Diesel Generator Operation);
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 EP/1/Al5000/E-1 11 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. (Continued) f.f.EnsUre~ll+
EnsureS/1 - RE$El: RESET: _ 1) ECCS. 1) Perform the following: _ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ b) WHEN trip breakers open, THEN reset ECCS. _ 2) DIG load 'sequencers; 2) Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA)
(AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB)
(AB-560, BB-46, Rm 372). _ 3) IF AT ANY TIME a B/O occurs, THEN restart*S/I equipment previously on. Depending on reader speed, FWST may be at 37% by this point. If not they will continue in this procedure until then and transition per Enclosure 1.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/11A15000/E-1 EP/1/A/5000/E-1 12 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 1. 92t~iilfgl'ltai*nm~ntiH2.**con.c~ntratiO'n Obtain containment H2 concentration as follows, as?fQlloWs:
- a. Eb?ureoperator.hasb~en dispatched to.'secure all ice condenser air handling units. REFER TO EnClosure 3 (Securing All Ice Condenser Air Handling Units).
- b. Verify containment Hz analyzers- IN b. Perform the following:
SERVICE. _ 1} Dispatch operator to place containment HzH2 analyzers in service. REFER TO OP/11A164501010 OP/1/A/6450/010 (Containment Hydrogen Control System). _ 2} WHEN Hz H2 analyzers are in service, THEN perform Steps 11.c through 11.e. _ 3} GO TO Step 12. c*'Y~rifyc()lJt~iimflJgtif**H2.CQj;ii~entratiQ0-
- c. Verify containment Hz concentration - c. Perform the following:
l..aSSTHAN<6%. LESS THAN 6%. _ 1} Obtain recommendation from station management for method to reduce Hz H2 concentration. _ 2} GO TO Step 12. qt~1~m)g9t{H2~00CentratiQh
- d. Verify containment Hz concentration .~.- d. Dispatch operator to place H2 Hz LE$S THAN A'NO;5~16:
0.5%. recombiners in service. REFER TO OP/11A164501010 OP/1/A/6450/010 (Containment Hydrogen Control System).
- e. WHEN the ice condenser air handling units are off AND H2 concentration is less than 60/0;,THEN energize theRz igniters (1 MC.;7).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/SOOO/E-1 E P111A/SOOO/E-1 13 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 12.ltlJti.atee~~!g~tiQl1pfPI~OfstatU~~$
- 12. Initiate evaluation of plant status as follows:
fQUpws:
- a. Verify SII systems yst~rm~4:~p!~NED~QR
-ALIGNED FOR a. GO TO Step 12.c.
INJECTION MOIDEl MODE. b.VerifYOQI~pegRe~ik~::~pM~ilI~y~$
- b. Verify Cold,Leg Recirc capability as follows:
_ 1) AtJeast one NO pump - _ 1) GO TO EP/1/A/SOOO/ECA-1.1 AVAILA8LE. (Loss Of Emergency Coolant Recirculation)).. Recirculation 811 ofthe following
- 2) Verify power to..?llqffhefQllqwlng 2) Perform the following:
valves ':'AVAILABLE: BbE;
- IF power cannot be verified to
*.1:ffV\f~~7~(f'fJ~1i2Urpp 1FW'-;27A (NO Pump 1 A$uct 1A Suct minimum number of valves FWST)
From FWST) required to perform the following:
.*1
- 1NI-t8SA (NO ~f?~rpp1~Cont Pump 1ACont Sump Suct)
- Transfer one train of NO to the
** 1N[)~28A(ND~upply ToNV &1A containment sump 1'Nli=>mps)
- \11/
1ffl~F~;~:*R~rt1p
*.1Ifvy~55B (~p;Pump 1 tBSl.lct B Suct
- Establish NO flow from fr<?rnF~\j\JS1)
From FWST) containment sump to one train 1:t-I'7~:~f1,I?~I':\I[).f?~mi1>
- 1NI-184B (NO Pump .1BOont 1B Cont of NV and NI pumps.
SlilmJ?'t~ SumpSuct)
.1N140
- 1NI-332A (1'(NI :\11 Rurpp*$l.l9 Pump Suctf ",'-'e;¥ef X-Over _ THEN GO TO F
From NO) EP/1/A/SOOO/ECA-1.1 (Loss Of
** 1 1NI-333B (NI, Pump SucfFrom Emergency Coolant NQ) ..... Recirculation).
- 1NI-3;34B (NIPump Suct X-Over Frorr(NO)
** 1NI-t36B (NO SliP ply To NI Pump 1B).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 EP/11A15000/E-1 14 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 12. (Continued) 3} Verify power to all ofthe following
- 3) 3} IF power cannot be verified to 3) valves - AVAILABLE: minimum number of valves required to isolate NI pump miniflow, THEN
** 1NI-115A (NI Pump 1A Miniflow perform the following:
Isol)
- 1NI-144A 4~{fi;!IIPlltftR~l:3iMlniflow (NFPump 18 Miniflow
- Attempt to restore power to Isol) miniflow isolation valve(s) valve(s}
- 1NH!]ip:N4.i.mifloWHdr 1NJ-140!3 (N!i'F>ump Miniflow Hdr ToR To FWST Isql).
- Have operator standing by to locally close the required valve:
- 1NI-147B (NI Miniflow Hdr To FWST Isol) (AB-548, HH-JJ, 53-54, Rm 234)
- 11NI-115A(NI NI-115A (NI Pump 1A Isol) (AB-549, GG-HH, Miniflow Isol}
53-54, Rm 235)
- 11NI-144A NI-144A (NI Pump 1B 1B Miniflow Isol) (AB-548, HH-JJ, 53-54, Rm 234).
4}
- 4) Verify the"ENAB~E" .Iights for the _ 4}
- 4) WHEN criteria for establishing Cold following switches - L.IT: Leg Recirc are met, THEN manual alignment to containment sump will
* "G . .LEGRECIR "C-LEG RECIR FWST TO CONT be required.
SUMRSWA,PT SUMP SWAP TRN A"
<?..bR~j:~F
** 1'"C-LEG RECIRFWST TOCONT SUMP+:SVV SUMP SWAP TRNB".
- c. Verify auxiliary building radiation is c. Evaluate cause of abnormal conditions normal as follows: as follows:
- EMF-41 (Au x Bldg Ventilation) trip 1 _ 1} Monitor OAC EMF alarms, OAC VA 1) light - DARK Graphic, and area monitor EMFs to determine location of activity.
- All area monitor EMF trip 1 lights- lights -
DARK. _ 2}
- 2) Dispatch operator to locate potential leak.
_ 3} IF cause of alarm is LOCA outside 3) containment, THEN GO TO EP/1/A/5000/ECA-1.2 EP/11A15000/ECA-1.2 (LOCA Outside Containment).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 EP/1/Al5000/E-1 15 of 29 150f29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 12. (Continued)
- d. WHEN the TSC is activated AND staffed, THEN:
_ 1) Notify the Reactor Engineer to assess core damage. REFER TO RP/O/A/5000/015 (Core Damage RP/O/AlSOOO/015 Assessment). _ 2) Notify Chemistry to obtain current NC boron concentration. _ 3) WHEN NO ND is aligned for Cold Leg Recirc, THEN notify Chemistry to obtain current containment sump boron concentration.
- 4) Notify Operating Engineer of the following:
_ a) VA is required to be aligned to normal within 72 hours of the event. _ b) Evaluate aligning VA to normal mode. REFER TO OP/O/A/6450/003 (Auxiliary OP/O/Al6450/003 Building Ventilation System).
- e. Notify station management to evaluate starting additional plant equipment to assist in recovery.
- 13. Verify NC System cool down and depressurization is required as follows:
- a. NC pressure - GREATER THAN ND flow to C-Legs is greater than
- a. IF NO 285 PSIG. 675 GPM, THEN GO TO Step 14.
EP/1/A/5000/ES-1.2 (Post
- b. GO TO EP/1/Al5000/ES-1.2 LOCA Cooldown And Depressurization ).
Depressurization).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 16 of 29 Revision 23 ACTIONIEXPECTED RESPONSE ACTION/EXPECTED RESPONSE NOT OBTAINED
- 14. Verify transfer to Cold Leg Recirc as follows:
- a. FWST level-level - LESS THAN 37% (1AD-9, a. RETURN TO Step 11.
D/8 "FWST 2/4 LO LEVEL" - LIT).
- b. SII systems - ALIGNED FOR COLD EP/1/A/5000/ES-1.3 (Transfer
- b. GO TO EP/1/A/5000IES-1.3 LEG RECIRC. To Cold Leg Recirculation).
- 15. Isolate CLAs as follows:
- a. Verify at least two NC T-Hots - LESS a. Perform the following:
THAN 328°F. _ 1) WHEN at least two NC T-Hots less than 328°F, THEN perform Steps 15.b through 15.d. _ 2) GO TO Step 16.
- b. Dispatch operator to restore power to all CLA discharge isolation valves.
REFER TO Enclosure 4 (Power Alignment for CLA Valves).
- c. Ensure SII - RESET:
_ 1) ECCS. 1) Perform the following: _ a) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ b) WHEN trip breakers open, THEN reset ECCS. _ 2) DIG load sequencers. 2) Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA)
(AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB)
(AB-560, BB-46, Rm 372).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 EP/1/A/5000/E-1 17 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 15. (Continued)
_ 3) IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on.
- d. WHEN power is aligned, THEN:
- 1) Close all of the following valves: 1) Perform the following:
- 1NI-54A (C-Leg Accum A Disch a) Ensure containment isolation Isol) signals - RESET:
- 1 1NI-65B NI-65B (C-Leg Accum B Disch
- Phase A Isol)
- Phase B.
- 1NI-76A (C-Leg Accum C Disch _ b) Ensure 1VI-77B (VI Cont Isol)-
Isol) OPEN.
- 1NI-88B 1NI-88B (C-Leg Accum D Disch _ c) IF VI pressure is less than Isol). 85 PSIG, THEN dispatch operator to ensure proper VI compressor operation.
(RNO continued on next page)
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/N5000/E-1 18 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 15. (Continued) d) Vent any CLA which cannot be isolated as follows:
_ (1) Open 1NI-47A(C-Leg 1NI-47A (C-Leg Accum N2 Sup Cant Isol). _ (2) Place breaker 1CB-1 (behind 1MC-6) (Key #11 ) to "ON". (3) Open the valve for CLA(s) to be vented:
- 1NI-50 (C-Leg Accum A N2 Supply Isol)
- 1NI-61 (C-Leg Accum B N2 Supply Isol)
- 1NI-72 (C-Leg Accum C N2 Supply Isol)
- 1NI-84 (C-Leg Accum D N2 Supply Isol).
_ (4) Close 1NI-47A. 1NI-47A. _ (5) Open 1NI-83 (C-Leg Accums N2 Vent Ctrl) to depressurize the affected CLA(s). (RNO continued on next page)
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 E P111A/5000/E-1 19 of 29 190f29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 15. (Continued)
(6) WHEN CLA(s) is vented, THEN:
- 1. Close 1 NI-83.
- 2. Close valve(s) previously opened:
_ .* 1NI-50 (C-Leg Accum A N2 Supply 1501) Isol)
- 1NI-61 (C-Leg Accum Isol)
B N2 Supply 1501) 1NI-72 (C-Leg Accum
- 1NI-72 Isol)
C N2 Supply 1501)
- 1NI-84 (C-Leg Accum Isol).
D N2 Supply 1501).
- 3. Place breaker 1CB-1 1CB-1 (behind 1MC-6) to "OFF".
_ 2) Notify dispatched operator to remove power from all CLA isolation valves. REFER TO Enclosure 4 (Power Alignment for CLA Valves).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 EP/1/A/5000/E-1 20 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 16. Determine S/G depressurization requirements as follows:
- a. Verify NC pressure - LESS THAN a. GO TO Step 18.
INTACT S/G(s) PRESSURE.
- b. Notify Chemistry to sample all S/Gs for activity levels.
- c. WHEN S/G sample results are known, THEN:
_ 1) Request RP to perform a dose projection on steaming S/Gs.
- 2) WHEN the dose projection is complete, THEN:
_ a) Verify the dose projection for _ a) Do not dump steam from any each S/G - ACCEPTABLE. S/G with an unacceptable dose projection. _ b) Perform Step 17 for all intact S/Gs.
- d. GO TO Step 18.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A15000/E-1 21 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 17. Depressurize intact S/G(s) to NC pressure as follows:
- a. Verify "C-9 COND AVAILABLE FOR a. Perform the following:
STM DUMP" status light (1SI-18) - LIT. _ 1) Dump steam from all intact S/G(s) PORV until S/G pressure is less than NC pressure. _ 2) GO TO Step 18.
- b. Depress ECCS steam pressure "BLOCK" push buttons.
- c. Verify MSIVs on all intact S/Gs - OPEN. c. Perform the following:
_ 1) Dump steam from all intact S/G(s) PORV until S/G pressure is less than NC pressure. _ 2) GO TO Step 18.
- d. WHEN "P-12 LO-LO TAVG" status light (1SI-18) is lit, THEN place the steam dump interlock bypass switches in "BYP INTLK."
- e. Verify steam dumps - IN PRESSURE e. Place steam dumps in pressure mode MODE. as follows:
_ 1) Place "STM DUMP CTRL" MIA station in manual. _ 2) Manually adjust "STM DUMP CTRL" MIA station output to match "% STM DUMP DEMAND" (1 SMP5211). _ 3) WHEN output on the "STM DUMP CTRL" MIA station is equal to the
"% STM DUMP DEMAND" (1 SMP5211), THEN place the steam dumps in pressure mode.
- f. Dump steam to condenser until S/G f. Dump steam from all intact S/G(s) pressure is less than NC pressure. PORV until S/G pressure is less than NC pressure.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/11A15000/E-1 EP/1/A/5000/E-1 22 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 18. Consult with station management to determine whether reactor vessel head should be vented.
- 19. WHEN 4 hours after event initiation has elapsed, THEN verify power available to the following valves required for Hot Leg Recirc:
1 NI-121A (NI Pump 1A To H-Legs
- a. 1NI-121A a. Dispatch operator to ensure B&C). 1EMXA-R07C (Safety Inj. Pump 1A Hot 1N1121A)
Leg Inj. Header Isol. Valve 1N1121A) (AB-577, FF-54, Rm 478) - CLOSED.
- b. 1NI-162A 1NI-162A (NI To C-Legs Inj Hdr Isol). b. Dispatch operator to ensure 1EMXA-R05A (Safety Inj. Pumps Cold Leg Inj. Hdr. Isol. Valve 1N1162A)
(AB-577, FF-54, Rm 478) - CLOSED.
- c. 1NI-152B (NI Pump 1B To H-Legs c. Dispatch operator to ensure A&D). 1EMXJ-R06D (Safety Inj. Pump 1B Hot 1N1152B)
Leg Header Isol. Valve 1N1152B) (AB-560, GG-56, Rm 330) - CLOSED.
- d. 1 NI-173A (ND Hdr 1A To Cold Legs d. Dispatch operator to ensure C&D). 1EMXA-R07D (ND Header 1A To NC 1EMXA-R07D 1N1173A)
Cold Leg Loops C & D Valve 1N1173A) (AB-577, FF-54, Rm 478) - CLOSED.
- e. 1NI-178B (ND Hdr 1B To Cold Legs e. Dispatch operator to ensure A&B). 1EMXJ-R04A (ND Header 1B 1EMXJ-R04A 1B To NC Cold Leg Loops A & B Valve 1N1178B)
(AB-560, GG-56, Rm 330) - CLOSED.
- f. 1NI-183B (ND Hdr A&B Hot Leg Inj 1NI-183B f. Dispatch operator to ensure Isol). 1EMXB-F01 D (ND Header A&B Hot 1N1183B)
Leg Injection Isol Valve 1N1183B) (AB-560, FF-56, Rm 330) - CLOSED.
- 20. WHEN 6 hours after event initiation has elapsed, THEN GO TO EP/1/A15000/ES-1.4 (Transfer To Hot EP/11A15000/ES*1.4 Leg Recirculation).
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/A/5000/E-1 EP/1/Al5000/E-1 23 of 29 Revision 23 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 21. Consult with station management to evaluate long term plant status.
CNS LOSS OF REACTOR OR SECONDARY COOLANT PAGE NO. EP/1/N5000/E-1 24 of 29 Enclosure 1 - Page 1 of 2 Revision 23 Foldout Page
- 1. NC Pump Trip Criteria:
- IF the following conditions are satisfied, THEN trip all NC pumps while maintaining seal injection flow:
- At least one NV or NI pump - ON
- NC subcooling based on core exit TICs - LESS THAN OR EQUAL TO OaF.
- 2. 5/1 Reinitiation Criteria:
- IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start SII S/I pumps and align valves as required to restore subcooling and Pzr level.
- 3. Secondary Integrity Criteria:
un isolated SIG
- IF pressure in any unisolated S/G is decreasing in an uncontrolled manner OR any un isolated S/G is completely depressurized, THEN GO TO EP/1/N5000/E-2 (Faulted Steam Generator SIG Isolation).
- 4. SGTR Transition Criteria:
- IF level in any SIG S/G is increasing in an uncontrolled manner OR any SIG S/G has abnormal radiation, THEN:
- a. Manually start S/I SII pumps and align valves.
- b. GO TO EP/1/N5000/E-3 (Steam Generator Tube Rupture).
- 5. Colcf.~~9 Recife Switchover Criterion:
- IFFWSTI~vel decreasesto 37% (1AD i 9, D/S FWST2/4 LOl£VEL"lit), THEN GO ii TO EP/1/N5000/ES,,1.3 (Transfer To Cold Leg Recirculation).
I II I I
Duke Energy Procedure No. Catawba Nuclear Station EP/I/A/5000/ES-1.3 EP/1/A/5000IES-1.3 Transfer to Cold Leg Recirculation Revision No. 021 Electronic Reference No. CP0094CV Continuous Use PERFORMANCE I
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
(ISSUED) - PDF Format
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/SOOO/ES-1.3 1 of 38 Revision 21 A. Purpose This procedure provides the necessary instructions for transferring the safety injection system and containment spray system to the recirculation mode. B. Symptoms or Entry Conditions This procedure is entered from: EP/1/A15000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 14, on low FWST level.
- a. EP/1/A/SOOO/E-1 EP/1/A15000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 10,
- b. EP/1/A/SOOO/ECA-2.1 on low FWST level.
- c. Other procedures whenever FWST level reaches the switch over setpoint.
switchover
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/SOOO/ES-1.3 20f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. Monitor Enclosure 1 (Foldout Page).
.d~tJj1t10N**:§t'ir:e¢i cAillTIONS/1 recirculation flow to NC *. §Y~f~m!miJ§tl>~)m~iht~*j*Q~d*.~t!:alltime~;
..cUl~1ipn**.fl.C:)Yttp:Np System 'must be maintained ,at all times.
N0We NO-IE;i .*$t~p~:?thrq~gn.*.8.**$f')qLJIClt~~petfqfm~q
- St~p~ 2 through 8shouldb~ performedwithouLdelay. *. ~j~hqutqe.lay;
- CSFshould not be implemented
- until p~~$flqUld:i!,\c:)t.*be.i81plerper:lted.** untilair~ll}f~qby.*tnis****pfqyed4r directed by this procedure. e.
- 2. t;I~.~~.~.;~i:l~)~{tbe VeriN.atle.astone ,of the ;'follpwifiQ following Perform the following:
annunciators iat<:>.rs;.,LIT;
- LIT:
- a. Ensure SII - RESET:
_ ***.* 1*~D,,?Q;(~i3"CON'F
.1,40-20, B/3"CONT..* SUMP $l)f'l11J?l;;EVEL;>$l$(
LEVEL >3.3 ft'; fill _ 1) ECCS. OR _ 2) DIG load sequencers.
** 1AO-21 ,813 "CONT. SUMP LEVEL >3.3 _ 3) IF AT ANY TIME a 8/0B/O occurs, fi". THEN restart SII equipment previously on.
- b. Ensure the following valves - CLOSED:
- 1FW-27A (NO Pump 1A Suct From FWST)
- 1FW-SS8 FW-SSB (NO Pump 1 18 B Suct From FWST).
(RNO continued on next page)
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 EP/1/N5000/ES-1.3 30f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. (Continued)
- c. IF valve(s) will not close, THEN:
_ 1) Stop associated ND NO pump(s).
- 2) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):
* "C-LEG RECIR FWST TO CONT SUMP SWAP TRN A"
* "C-LEG RECIR FWST TO CONT SUMP SWAP TRN B". 8".
_ 3) Close the associated ND NO pump(s) containment sump suction valve(s).
- d. IF FWST level less than 37% due to FWST puncture, THEN RETURN TO procedure and step in effect.
- e. IF both NS pumps are off, THEN GO TO Step 2 RNO g.
- f. IF either of the following annunciators are lit:
_ . 1AD-20, B/2 8/2 "CO NT. SUMP LEVEL
>2.5 ft" OR
_ .* 1AD-21, B/2 8/2 "CONT. SUMP LEVEL
>2.5 ft",
_ THEN GO TO Step 3. (RNO continued on next page)
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 EP/1/A/SOOO/ES-1.3 4of38 4 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. (Continued)
- g. IF all of the following conditions met:
- FWST level - LESS THAN 8%
- NC temperature - GREATER THAN 200°F
- Containment Spray - PREVIOUSLY IN SERVICE
- Indicated containment sump level -
GREATER THAN O.S 0.5 FT. _ THEN GO TO Step 3.
- h. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect.
- i. IF both "CO NT. SUMP LEVEL >3.3 ft" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump.
_ j. GO TO EP/1/A/5000/ECA-1.1 EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation) Recirculation)..
- 3. Verify .***~~***t!q~ij KC flow.toND O?hea~~i<cl'1aoge.rs.9 heat exchangers- _ Establish KC flow to affected NO Hx(s).
GREATER:reR:rtl~ THAN 5000OOGRM. GPM.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 5 of 38 50f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 4. E:nsureSII - RESET:
J
- a. ECCS. a. Perform the following:
_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) WHEN trip breakers open, THEN reset ECCS.
- b. DIG load sequencers. b. Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB) (AB-560, BB-46, Rm 372).
c.IF ATANY TIME a SlOoc611rs; THEN c. rest<:irt 8/1 equipment previously on.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 6 of 38 6of38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 5.$Iriif;S(Q~lili.l~lfillJ_41t~~
- 5. AligrlS/isystem f9r recirc"as follows:
- a. *~~~itY:lr9J_\l~ti~~lfj.Nt; Verify folloWlhg valves;- OREN; a. Perform>the following:
* ~NI*m85A (NO ;ijJjltl~;Jtlllit.JjJltti; Pump1AContSump _ 1) Manuallyopen affected valve(s).
$uct)
- 2) II~Valve(s) will not open, THEN:
- tNI-1.B4B (NO Pump 1B Cont Sump S,u~t). _ a) Stop the NO pump(s} a$socia~ed with a closed containment sump suction Valve(s).
b) Close the associatectNb
!11NI-184B NI-184B will NOT be open. 10 seconds pump(s) s.uctionvalve from the after they secure the pump, there will be a lafter FWST:
loss of all essential power to A train. "A"
!Ioss train power to essential equipment will not (Itrain 1FW-27A (NO Pump 1ASuct
- 1FW-27A(ND 1A Suct be restored for the remainder of the
,be From FWST) scenario.
Iscenario.
** 1FW-55B (NO Pump 1B Swct L-______________________
From FWST). (RNO continued on next page)
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/11A15000/ES-1.3 EP/1/A/5000/ES-1.3 70f38 7of38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued)
~c)~,!~N.th~)~D.purnP(§~~\;lcti(??
c) WHEN the NO pump(s):!?uction
¥§[v:~*from**.tQ7F~ST.ig<<12seq; varve from the FWST is closed, mHEN** p~rfo.rm***tl1e.f()lr()Wing:
THEN** . perform the following: (1))Att.~li1pf~8.rnaM~1 (1 Attempt to manually open t*Q~.~m~ct~~*.* the 82n.t~i affected . containment surnP*$ucti()n.valv:~ sump suctidnvalve(s).
- 1NI-185A (NO (ND Pump 1A Cont Sump Suct)
*.1NI~184B(N 1NI-184B (NO D~1.1/'l"lP1E3i PUmP 1B ContFSump C00t Su mpSOct).
Suct). (2) IFIFa:ff~Cl~dcontaiQrn~t"l~ affected containment
~.urnH*.gUCtl()[l**.Xal~~'4'ilt~9t sump suction valve will not openiTHENdisp~tch 2pe(lj*.*~!'I.E~.qiSp§lch**.W() two operators
- 0. o.rsJo qR~nthe to open the affected a valve(s):
ed.valve{$)::
.1NI-185A(NOPump1A
- 1NI-185A (ND Pump 1A Cont Sump Suct)
(AB-545, EE-FF, 52-53, Rm 217)
- 1t>J1~181E3(~*[).PumpfE3 1NI~1841;3(NO Pump 1B IOnce they call,, it will take 10 minutes to to. g Cont .*~* ~.mp.~u~t)
@()nt. SumpSuct) n, 5 toto. get there and 5 to to. 0 ep (.t\~7~~5, . . FF-GG, (AB-545, FF~GJ~j52"53, 52-53, RrgigtZl:
Rm 217). .
- 3) IF both containment sump suction valves are closed, THEN:
Beth Both valves are NOT clesed. closed. 1NI-185A is epen open _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO GOTO EP/11A15000/ECA-1.1 TO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation Recirculation). ).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/SOOO/ES-1.3 8of38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- s. (Continued)
S. IBOP I \;t~rifYT91IbWl~g'la"(es-Ci1,Q$ED:
- b. Verify following valves - CLOSED: b. Perform the following:
.1FcV':j:"2'lA.(t'!{PgQ[if;ljA§llctFrom
- 1FW-27A(ND Pump 1ASuct From _ 1) Manually close affected valve(s).
FWS[) FWST)
- 2) IF valve(s) will not close, THEN:
*.1~VV.,~.~*l3<t9DI?;~r:np1:'il3,::~'ucrFr9m'*
1FW-SS8(ND PUfJ1p 16 SucfFrom FV':jS[)! FWST). _ a) Stop associated ND pump(s). b) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):
* "C-LEG RECIR FWST TO CONT SUMP SWAP TRN A"
* "C-LEG RECIR FWST TO CO CONTNT SUMP SWAP TRN 8".
_ c) Close the associated ND pump(s) containment sump suction valve(s). d) IF both containment sump suction valves are closed, THEN: _ (1) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ (2) GOTO EP/1/ EP/1 I A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/AJ5000/ES-1.3 EP/1/A15000/ES-1.3 90f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued)
- c. Verify NO pumps - ON. c. Perform the';following:
_ 1) Start NO pump(s)with suction aligned to an open containment sump suction valve. There should be no valid RED paths and the crew should go to 2) ,IF no NO pump can be started OR ECA-1.1 no NO train can be aligned for, recirc, THEN: _ a);,IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/AJ5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
- d. Isolate NI pump miniflow as follows:
_ 1) Verify NC pressure - LESS THAN 1) Perform the following: 1620 PSIG. _ a) Stop NI pumps. _ b) WHEN pressure is less than 1620 PSIG, THEN start NI pumps.
- 2) Close the following valves:
- 11NI-115A NI-115A (NI Pump 1A Miniflow Isol)
- 11NI-144A(NI NI-144A (NI Pump 1B1B Miniflow Isol).
_ 3) Place "PWR DISCONOISCON FOR 1NI-147B" switch in "ENABLE". _ 4) Close 1 NI-147B (NI Pump Miniflow 1NI-147B Hdr To FWST Isol).
CNS TRANSFER TO COLDCOLO lEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 EP/1/A/SOOO/ES-1.3 10 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- s. (Continued) 5.
- e. Close the following valves:
- 1NO-32A (NO Train 1A Hot leg Inj Isol)
- 1NO-65B NO-6SB (NO Train 1B Hot leg Inj Isol).
- f. Verify at least one of the following NV f. Perform the following:
pumps miniflow valves - ClOSEO: CLOSED: _ 1) IF 1NI-9A (NV Pmp C/l Inj Isol) _ . 1NV-203A (NV Pumps A&B Recirc AND 1 NI-1 OB (NV Pmp C/l Inj Isol) 1NI-10B Isol) are closed, THEN maintain charging flow greater than 60 GPM. OR
- 2) Close the following valves:
- 1NV-202B (NV Pmps A&B Recirc Isol).
- 1NV-203A (NV Pumps A&B Recirc Isol)
- 1NV-202B (NV Pmps A&B Recirc Isol).
- g. Align NO train discharges to NI and NV pump suctions as follows:
- 1) Open the following valves:
- 1NI-332A (NI Pump Suct X-Over From NO)
- 1NI-333B (NI Pump Suct From NO).
_ 2) Ensure 1NI-334B (NI Pump Suct X-Over From NO) - OPEN.
- 3) Open the following valves:
- 1NO-28A (NO Supply To NV & 1A NI Pmps)
- 1NI-136B (NO Supply To NI Pump 1B).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 11 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued)
- h. Isolate FWST from NVand NV and NI pumps as follows:
_ 1) Place "PWR DISCON FOR 1NI-100B" 1 NI-100B" switch in "ENABLE". _ 2) Close 1NI-100B 1NI-1 OOB (NI Pmps Suct _ 2) Dispatch operator to close 1 1NI-100B NI-1 OOB From FWST). (NI Pmps Suct From FWST) (AB-552, HH-JJ, 53-54, Rm 234).
- 3) Close the following valves: 3) Perform the following:
- 1NV-252A (NV Pumps Suct From a) IF 1NV-252A (NV Pumps Suct FWST) From FWST) cannot be closed, THEN dispatch operator to
- 1NV-253B (NV Pumps Suct From perform the following:
FWST). _ (1) Open 1EMXA-R04A (NV Pump Suction From FWST Motor (1 NV252A>> (AB-577, FF-54, Rm 478). _ (2) Close 1NV-252A (NV Pumps Suct From FWST) (AB-554, HH-53, Rm 234) (Ladder needed). b) IF 1NV-253B (NV Pumps Suct From FWST) cannot be closed, THEN dispatch operator to perform the following: _ (1) Open 1EMXJ-R03A (NV Pump Suction From FWST Motor (1 NV253B>> (AB-560, GG-56, Rm 330). _ (2) Close 1NV-253B (NV Pumps Suct Suet From FWST) (AB-554, HH-JJ, 53-54, Rm 234) (Ladder needed).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/5000/ES-1.3 12 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued)
- i. Verify proper recirc flow as follows: i. IF any S/I pump on without a suction flowpath, THEN stop the affected
* "NV S/I S/J FLOW"-INDICATING FLOW pump(s).
- NI pumps --INDICATING INDICATING FLOW
- ND pumps -INDICATING FLOW.
- 6. WHEN FWST level decreases to 11 %
(1AD-9, Et8 E/8 "FWST LO-LO LEVEL" alarm lit), THEN perform the following:
- a. Stop NS Pumps.
- b. Align NS for recirc. REFER TO Enclosure 2 (Aligning NS for Recirculation ).
Recirculation).
- 7. IF any NS pump in service with suction aligned to FWST, THEN perform the following:
- a. Ensure appropriate operator is in possession of Enclosure 2 (Aligning NS for Recirculation).
- b. Designate operator to ensure NS pumps immediately secured when FWST level decreases to 11 % OR 1AD-9, E/8 "FWST LO-LO LEVEL" alarm lit.
- c. IF time and manpower permit, THEN notify designated operator to review Enclosure 2 (Aligning NS for Recirculation) for current plant conditions.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 EP/11A15000/ES-1.3 13 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. Verify criteria for initiation of NO aux containment spray:
- a. Containment pressure - GREATER a. Perform the following:
THAN 3 PSIG. _ 1) IF AT ANY TIME containment pressure exceeds 3 PSIG, THEN perform Step 8. _ 2) Observe Caution prior to Step 9 and GO TO Step 9.
- b. Time since reactor trip - GREATER b. Perform the following:
THAN 50 MIN. _ 1) Designate someone to notify Control Room Supervisor when 50 min from reactor trip has elapsed. _ 2) WHEN the time since reactor trip is greater than 50 min, THEN perform Step 8. _ 3) Observe Caution prior to Step 9 and GO TO Step 9.
- c. Verify the following valves - CLOSED: c. Observe Caution prior to Step 9 and GO TO Step 9 .
- 1NS-43A (NO Pmp 1A To Cont Spray Hdr)
- 1NS-38B (NO Pmp 1B To Cont Spray Hdr).
CNS TRANSFER TO COLD lEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 14 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. (Continued)
- d. Verify core cooling can be maintained d. Perform the following:
with minimum SII S/I flow as follows: _ 1) IF both NO trains are aligned AND
* "NV SII FLOW" - INDICATING FLOW operating in Cold leg Recirc, THEN GO TO Step 8.e.
_
- At least one NI pump -INDICATING
- INDICATING FLOW. 2) IF one NV AND one NI pump are available, THEN:
_ a) IF NC pressure is greater than 285 PSIG, THEN GO TO Step 8.e. _ b) Ensure one NV pump - ON. _ c) Ensure one NI pump - ON. d) Open the following valves:
- 1NI-9A (NV Pmp C/l Inj Isol)
- 1NI-10B (NV Pmp C/l Inj Isol).
e) Close the following valves:
- 1NV-312A (Chrg Line Cant Isol)
- 1NV-314B (Chrg Line Cant Isol).
_ f) IF "NV SII FLOW" AND NI pump flow is indicated, THEN GO TO Step 8.e. _ 3) Observe Caution prior to Step 9 and GO TO Step 9.
CNS TRANSFER TO COLD COLO LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 EPf1fA/5000fES-1.3 15 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 8. (Continued)
- e. Align one ND NO train to provide aux containment spray as follows:
- Train A:
_1) 1) Place "PWR DISCON OISCON FOR 1NI-173A" switch in "ENABLE". _2) 2) Close 1NI-173A (ND Hdr 1A To 1 NI-173A (NO C&O). Cold Legs C&D). _3) 3) Open 1NS-43A (ND (NO Pmp 1A To Cont Spray Hdr). OR
- Train B:
_ 1) Place "PWR DISCON _1) OISCON FOR 1NI-178B" 1NI-178B" switch in "ENABLE". _2) 2) Close 1NI-178B 1 NI-178B (ND (NO Hdr 1B 1 B To Cold Legs A&B). _3) 3) Open 1NS-38B (ND (NO Pmp 1B To Cont Spray Hdr).
- f. WHEN containment pressure is less than 1 PSIG, THEN secure ND NO Aux Spray. REFER TO Enclosure 4 (Securing NDNO Aux Spray).
CAUTION Bl0 occurs, NVINI If a BIO NV/NI pump(s) may sequence on or be left in service without adequate suction, It is critical to ensure ECCS pumps are not operated without adequate pump suction.
- 9. IF AT ANY TIME a Bl0 BIO occurs, THEN perform the following:
- a. Ensure NV/NI NVfNI pumps taking suction from de-energized ND NO pump(s) - OFF.
- b. Restart S/I Sfl equipment previously on.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/Al5000/ES-1.3 EP/1/A/5000/ES-1.3 16 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 10. EP/1/A15000/F*O (Critical Safety EP/1/A15000/F-O Function Status Trees) may now be implemented.
- 11. Verify proper recirc flow as follows: Perform the following:
* "NV S/I FLOW" - INDICATING FLOW a. IF at least one flow path cannot be established from the containment sump
- NI pumps --INDICATING INDICATING FLOW to the NC System, THEN:
- NO pumps - INDICATING FLOW. _ 1) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect.
_ 2) GO TO EP/1/Al5000/ECA-1.1 EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation). Recirculation ).
- b. WHEN time and manpower permit, THEN continue attempts to establish maximum Cold Leg Recirc capability.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 17 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Monitoring for signs of containment sump blockage must be performed as long as ECCS pumps are aligned to sump.
- 12. IF AT ANY TIME ECC5 ECCS or N5NS pumps indicate signs of cavitation, OR loss of 5/1 SII recirc flow to NC system occurs, THEN perform the following:
If adequate sump level exists and pumps cavitate, sump blockage should be suspected, unless other cause is known.
- a. IF at least one train of Cold Leg Recirc cannot be maintained, THEN perform one of the following:
- IF sump blockage is suspected, THEN GO TO EP/1/A/5000/ECA-1.3 (Containment Sump Blockage).
OR
- IF loss of emergency coolant recirc is known to be caused by failure other than sump blockage, THEN GO TO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/AJ5000/ES-1.3 18 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 13. Verify ND NO & NS rooms sump pump interlock status as follows:
- a. Verify "ON" is released on the following a. Depress "LCL" on the affected switch(s) switches: to release the "ON" button.
* "NO & NS ROOM SMP PMP 1A"
* "NO & NS ROOM SMP PMP 1B" S"
* "NO & NS ROOM SMP PMP 2A" (2MC11 )
(2MC11)
* "NO & NS ROOM SMP PMP 2B" 2S" (2MC11).
- b. Verify "RESET" lights dark. b. Dispatch operator to place the local control switch for the affected pump(s)
* "NO & NS ROOM SMP PMP 1A" "STDSY" on 1ELCP0243 to "STDBY" 1ELCP0243 (AB-54?,
(AS-54?,
* "NO & NS ROOM SMP PMP 1B" S" MM-53, Rm 212).
* "NO & NS ROOM SMP PMP 2A" (2MC11 )
(2MC11)
* "NO & NS ROOM SMP PMP 2B" 2S" (2MC11 ).
(2MC11).
- c. Place protective shrouds over the following control switches to prevent inadvertent reset:
* "NO & NS ROOM SMP PMP 1A"
* "NO & NS ROOM SMP PMP 1B" S"
* "NO & NS ROOM SMP PMP 2A" (2MC11 )
(2MC11)
* "NO & NS ROOM SMP PMP 2B" 2S" (2MC11 ).
(2MC11).
- d. Consult station management for recommendation and concurrence prior to resetting the interlocks.
- 14. Determine if station management needs to evaluate transfer to hot leg recirc:
- Verify procedure entered from _ .* Consult station management to evaluate EP/1/A15000/E-1 EP/1/AJ5000/E-1 (Loss Of Reactor Or the potential need for transfer to hot leg Secondary Coolant). recirc.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 19 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 15. Initiate makeup to FWST as follows:
- a. Verify the following valves - CLOSED: a. Perform the following:
- 1NV-252A (NV Pumps Suct Suet From _ 1) WHEN all valves are closed, THEN FWST) perform Step 15.
- 1NV-253B (NV Pumps Suct From _ 2) GO TO Step 16.
FWST) 1FW-27A (ND
- 1FW-27A (NO Pump 1A Suct From FWST)
- 1FW-55B (ND(NO Pump 1 B Suct From 1B FWST)
- 1 NI-1 OOB (NI Pmps Suct From 1NI-100B FWST)
- 1NS-20A (NS Pump 1A Suct From FWST)
- 1NS-3B (NS Pump 1B Suct From FWST).
CAUTION
- Makeup to FWST greater than 50,000 gallons may violate containment flooding assumptions.
- Makeup to FWST at concentrations other than the minimum Tech Spec value may violate containment sump chemistry assumptions.
- b. Initiate makeup of 50,000 gallons to FWST at minimum Tech Spec boron concentration. REFER TO Enclosure 3 (FWST Makeup).
- 16. RETURN TO procedure and step in effect.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 EP/1/A/SOOO/ES-1.3 20 of 38 Enclosure 1 - Page 1 of 1 Revision 21 Foldout Page
- 1. 5/1 511 Reinitiation Criteria:
- IF NC subcooling based on core exit TICs is less than OaF OR Pzr level cannot be maintained greater than 11 % (20% ACC), THEN manually start S/ISII pumps and align valves as required to restore subcooling and Pzr level.
- 2. Loss Of Emergency Coolant Recirculation:
- IF Step S 5 has been completed AND recirc flow is subsequently lost, THEN perform the following:
- a. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect.
- b. GO TO EP/1/A/5000/ECA-1.1 EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
- 3. Loss Of FWST Supply To ECCS Pumps:
- IF FWST level decreases to less than 11 %, THEN stop NS pumps taking suction from the FWST.
- IF FWST level decreases to less than S%,
5%, THEN stop all pumps taking suction from the FWST.
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 1 of 83 Rev 31-DC~ A. Purpose This procedure provides actions to restore emergency coolant recirculation capability, to delay depletion of the FWST by adding makeup and reducing outflow, and to depressurize the NC System to minimize break flow. B. Symptoms or Entry Conditions This procedure is entered from:
- a. EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant),
Coolant). Step 12. 12, when Cold Leg Recirc capability cannot be verified.
- b. EP/1/A/5000/ES-1.2 (Post LOCA Cooldown And Depressurization), 5, when Cold Depressurization). Step 5.
Leg Recirc capability cannot be verified.
- c. EP/1/A/5000/ES-1.3 (Transfer To Cold Leg Recirculation).
Recirculation), Step 5,
- 5. when at least one flowpath from the sump cannot be established or maintained.
- d. EP/1/A/5000/ECA-1.2 (LOCA Outside Containment),
Containment). Step 3. 3, when a LOCA outside containment cannot be isolated.
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 EP/11A15000/ECA-1.1 2 of 83 Rev 31 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED C. Operator Actions
- 1. IF loss of Emergency Coolant Recirculation is due to sump blockage, EP/1/A/5000/ECA-1.3 THEN GO TO EP/11A15000/ECA-1.3 (Containment Sump Blockage).
- 2. Monitor Enclosure 1 (Foldout Page).
- 3. Restore recirc capability as follows:
- a. Verify all of the following pumps-pumps - a. IF power is available to the affected AVAILABLE TO BE OPERATED FROM essential buses),
bus(s), THEN dispatch THE CONTROL ROOM: operator and maintenance to determine and correct cause of pump failure.
=.
_ .* NO ND pumps _ . NVpumps _ . NI pumps. EM/1/A/52001005 REFER TO EM/11A15200/005 (Troubleshooting Cause For ND, NV Pump(s) Failing to Start). Start}. NO, NI, or
- b. Verify the following valves - b. Perform the following:
AVAILABLE TO BE OPERATED FROM THE CONTROL ROOM: 1)
- 1) IF power is not available, THEN dispatch operator to ensure the
- 1NI-185A 1NI-185A (NO(ND Pump 1A Cont Sump following breakers are closed:
Suct)
- 1EMXA-R08D 1EMXA-R08D (NO(ND Pump 1A
- 1NI-184B 1NI-184B (NO(ND Pump 1BContSump 1B Cont Sump Suction From Containment Sump Suct). Valve 1N1185A) 1N1185A) (AB-577, FF-54, Rm 478) 1VfciY"not May not do this since the power loss
- 1 EMXB-F01 C (NO 1EMXB-F01C (ND Pump 1 1BB Suction From Containment Sump is beyond just those 1N1184B) (AB-560, FF-56, Valve 1N1184B) breakers. Rm 330).
(RNO continued on next page)
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A15000/ECA-1.1 EP/1/A/5000/ECA-1.1 3 of 83 DC~ Rev 31 DCE ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued)
- 2) IF power cannot be restored to at least one valve OR valve cannot be operated from the control room, THEN:
_ a) IF NO Pump 1A is available, THEN dispatch two operators to standby to open 1NI-185A (NO Pump 1A1A Cont Sump Suct) (AB-545, EE-FF, 52-53, Rm 217). IThis This should already have been _ b) IF NO Pump 1B is available, done in ES-1.3 THEN dispatch two operators to standby to open 1NI-184B 1NI-184B (NO Pump 1B Cont Sump Suet) Suct) (AB-545, FF-GG, 52-53, Rm 217). c) WHEN at least one of the following - LIT:
- 1AO-20, B/2 "CO NT. SUMP "CONT.
- LEVEL >2.5 fi"ft" OR
- 1 AO-21, B/2 "CO 1AO-21, "CONT.
NT. SUMP
- LEVEL >2.5 fi"ft"
_ THEN have dispatched operator open affected valve(s).
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 EP/1/A1S000/ECA-1.1 40f83 4 of 83 Rev 31 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued)
B c. Verify containment sump level c. IF NC inventory lost outside adequate as follows: containment, THEN GO TO Step 4.
- 1AD-20, B/2 "CO "CONT.
NT. SUMP LEVEL
- >2.5 ft"
>2.S fi" - LIT OR
- 1AD-21, B/2 "CO NT. SUMP LEVEL "CONT.
- >2.S ft"
>2.5 fi" - LIT OR
- All of the following:
- FWST level - LESS THAN 8%
- NC temperature - GREATER THAN 200°F
- Containment Spray -
PREVIOUSLY IN SERVICE
- Indicated containment sump level -
GREATER THAN O.S 0.5 FT.
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A1S000/ECA-1.1 EP/1/A/5000/ECA-1.1 S 5 of 83 Rev 31 DCS ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 3. (Continued)
- d. Verify Cold Leg Recirc capability - d. Perform the following:
RESTORED.
- 1) Continue attempts to restore recirc capability as follows:
=.
- Power restoration
- Local valve operation
- Obtain maintenance assistance as required. REFER TO EM/11AlS200/006 EM/1/A/5200/006 (Troubleshooting Cause For FW, NO, NI, or NV Valves(s) Failing to Operate).
- Other actions as specified by station management.
- 2) WHEN emergency coolant recirc capability is restored during this procedure, THEN:
a) IF transfer to Cold Leg Recirc is required, THEN perform the following: (1) Ensure the following valves
-OPEN:
- 1NS-29A (NS Spray Hdr 1A 1A Cont Isol)
- 1NS-32A (NS Spray Hdr 1A 1A Cont Isol) 1NS-15B (NS
- 1NS-1SB Spray Hdr 1B Cont Isol)
- 1NS-12B 1NS-12B (NS Spray Hdr 1B Cont Isol).
_ (2) GOTO EP/1/A1S000/ES-1.3 EP/1/A/5000/ES-1.3 (Transfer To Cold Leg Recirculation). _ b) RETURN TO procedure and step in effect. _ 3) GO TO Step 4.
- e. RETURN TO procedure and step in effect.
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 EP/1/N5000/ECA-1.1 60f83 6 of 83 DC~ Rev 31 DCS ACTION/EXPECTED RESPONSE ACTIONIEXPECTED RESPONSE NOT OBTAINED =-:=~ 4. Ensure S/I 5/1 - RESET:
- a. ECCS. a. Perform the following:
_1)1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) WHEN trip breakers open, THEN reset ECCS.
- b. DIG load sequencers. b. Dispatch operator to open the affected sequencer(s) control power breaker:
_ .* 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496) _ .* 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB) (AB-560, BB-46, Rm 372).
- c. IF AT ANY TIME a B/O occurs, THEN restart SII equipment previously on.
- 5. Depress the "DEFEAT" pushbuttons push buttons on the following switches:
* "C-LEG RECIR FWST TO CONT SUMP SWAPTRN A" SWAPTRNA"
* "C-LEG RECIR FWST TO CONT SUMP SWAPTRN B".
- 6. Verify adequate FWST level as follows:
- a. FWST level - GREATER THAN 5%. a. GO TO Step 33.
- b. IF AT ANY TIME FWST level is less than 5%, THEN GO TO Step 33.
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/Al5000/ECA-1.1 EP/1/A/5000/ECA-1.1 7 of 83 Rev 31 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 7. Determine NS requirements as follows:
- a. Verify following NS pump suction valves a. GO TO Step 10.
-OPEN:
- OPEN:
- 1NS-20A (NS Pump 1A Suct Suet From FWST)
NS-3B (NS Pump 18
- 1NS-38 1B Suct From FWST).
- b. Determine number of NS pumps required from the following table:
FWST LEVEL CONTAINMENT PRESSURE (PSIG) REQU I RED NS PUMPS REQUIRED GREATER THAN 15 2 GREATER THAN BETWEEN 10 AND 15 1 5% LESS THAN 10 0 LESS THAN 5% N/A 0
- c. Verify the number of NS pumps on - _ c. Manually operate NS pumps as EQUAL TO NUM8ER NUMBER REQUIRED. required by table above.
Will secure the 1 B NS pump. 18
- 8. Verify criteria to align NS for recirc as follows:
- a. Any NS pump - ON. a. GO TO Step 9.
- b. Verify at least one of the following*
following b. Perform the following: annunciators - LIT: _ 1) WHEN at least one "CONT. SUMP _ . 1AD-20, B/3 8/3 "CONT.
"CO NT. SUMP LEVEL LEVEL >3.3 fi" annunciator is LIT,
>3.3 fi" THEN GO TO Step 8.c.
OR _ 2) GO TO Step 9. _ .* 1AD-21, B/3 8/3 "CONT.
"CO NT. SUMP LEVEL
- >3.3fi".
>3.3 fi".
- c. Align NS for recirc. REFER TO Enclosure 3 (Aligning NS for Recirculation).
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A15000/ECA-1.1 EP/1/A/5000/ECA-1.1 80f83 8 of 83 Rev 31 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED Align NS spray valves as follows:
- a. Verify NS Pump 1A - ON. a. Perform the following:
_ 1) Ensure NS Train A - RESET.
- 2) Close the following valves:
- 1NS-29A (NS Spray Hdr 1 A Cant 1A Cont Isol)
- 1NS-32A (NS Spray Hdr 1A CantCont Isol).
- b. Verify NS Pump 18 1B - ON. b. Perform the following:
_ 1) Ensure NS Train B 8 - RESET.
- 2) Close the following valves:
- 1NS-15B.(NS 1NS-158 (NS Spray Hdr 18 1B Cont Cant Isol) 1NS-128 (NS Spray Hdr 18
- 1NS-12B 1B Cant Cont Isol).
- c. IF AT ANY TIME NS pumps are stopped or started, THEN:
Depending on reader speed 1NI-184B
- Ensure associated NS Train -
should be open by this time and the RESET. crew would go back to ES-1.3 per _
- Close associated spray valves after enclosure 1 guidance.
securing a pump. _
- Open associated spray valves prior to starting a pump.
- 10. Initiate makeup to FWST. REFER TO OP/1/A16200/014 (Refueling Water System).
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A/5000/ECA-1.1 90f83 Rev 31 DC~ ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 11. Control intact S/G levels as follows:
- a. Verify N/R level in all intact S/Gs - a. Maintain total feed flow greater than GREATER THAN 11% (29% ACC). 450 GPM until at least one intact S/G N/R level is greater than 11 %
(29% ACC).
- b. Throttle feed flow to maintain all intact b. IF N/R level in any S/G continues to S/G N/R levels between 11 % increase in an uncontrolled manner, (29% ACC) and 50%. THEN stop feed flow to that S/G.
- 12. Monitor shutdown margin during cool down as follows:
- a. Notify station management to monitor shutdown margin during NC System cooldown.
- b. Request periodic NC boron samples from Primary Chemistry.
Sample results are not required prior to initiating cooldown in subsequent steps.
- c. WHEN each NC boron sample obtained, THEN:
_ 1) Perform shutdown margin calculation. REFER TO OP/O/A/61001006 (Reactivity Balance Calculation). _ 2) Verify NC boron concentration - 2) Perform the following: GREATER THAN OR EQUAL TO REQUIRED BORON
- Borate as required to restore CONCENTRATION. shutdown margin.
- Notify Station Management.
CNS LOSS OF EMERGENCY COOLANT RECIRCULATION PAGE NO. EP/1/A15000/ECA-1.1 EP/1/A/5000/ECA-1.1 52 of 83 Enclosure 1 - Page 1 of 1 DC~ Rev 31 DC:: Foldout Page
- 1. Emergency Coolant Recirc Capability Restoration:
- WHEN!emergency coolant recirc capability is restored daring this procedure, THEN:
- a. IF transfer to Cold Leg Recirc is required, THEN perform thefollowirig:
;IDi
- 1) ',IB:.J:'!t![~~fII.jJ9,&~~I~lili.~fII Ensure the fallowing valves::-OPEN:
-=
_ :~r-'~~!!t~'~~~'.~
- 1NS~?f},A(NStSpr~y tidrlA Cont IsOI)
- 1",~~._.~AlIllllG:~ll.
,gg 1NS;'32A(NSiSpraYhl9~'1'A
'it' ;IB~_MS";§"
Cont Isol) _ _ CQ!1t IsOI)
- 1I':JS-1SB'(NSSpraYHqr1B
* (lii\_.~iji;ij('J::4iiii\~.w Jf(
zfRi!l~l_ 1NS-12B {NS Spray'HCfr' 1B (J;.<1rt Isol); _ 2Ji-lI~lm1Wl<ll~~~,Q(j}t~~.ll'ill,"I.~j:t~::t;,E1lfi~~i:~q_m~*
- 2) GOtTO EP/1/A/5000/ES-1.3 (Transfer To~old Leg Recirculation).
_ b. RETURN TO procedure and step in effect.
- 2. ECCS Suction Source Monitoring Criteria:
_ .* IF the suction source is lost to any ECCS OR NS pump, THEN stop the affected pump. _ .* IF FWST level decreases to less than 5%, THEN stop all pumps taking suction from the FWST. _ .* IF both "CO NT. SUMP LEVEL >2.5 ft" fi" annunciators on 1AD-20 and 1AD-21 dark, THEN stop all pumps taking suction from the containment sump.
- 3. CA Suction Source Switchover Criteria:
- IF either of the following annunciators are lit, THEN REFER TO AP/1/A155001006 AP/1/A/55001006 (Loss of S/G Feedwater):
1AD-5, H/4 "CACST LO LEVEL" _ . 1AD-5, OR
- 1AD-8, B/1 "UST LO LEVEL".
Duke Energy Procedure No. Catawba Nuclear Station EP/I/A/5000IES-1.3 Transfer to Cold Leg Recirculation Revision No. 021 Electronic Reference No. CP0094CV Continuous Use PERFORMANCE I
- * * * * * * * *
- UNCONTROLLED FOR PRINT * * * * * * * * * *
- UNCONTROLLEDFORPruNT**********
(ISSUED) - PDF Format
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/5000/ES-1.3 1 of 38 Revision 21 A. Purpose This procedure provides the necessary instructions for transferring the safety injection system and containment spray system to the recirculation mode. B. Symptoms or Entry Conditions This procedure is entered from:
- a. EP/1/A15000/E-1 EP/1/A/5000/E-1 (Loss Of Reactor Or Secondary Coolant), Step 14, on low FWST level.
- b. EP/1/A15000/ECA-2.1 EP/1/A/5000/ECA-2.1 (Uncontrolled Depressurization Of All Steam Generators), Step 10, on low FWST level.
- c. Other procedures whenever FWST level reaches the switch over setpoint.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/SOOO/ES-1.3 2of38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED c. C. Operator Actions OPP DOES ALL THESE ACTIONS
- 1. Mol)itor EnciosOre1(Foldout Page).
.",.'N CAUTIONS/I::l:e,circulationflowtoNC Syst~m must be maintained ilt',aJI times. *fllm
- St~ps 2 through 8 should beperform~9 with()ut qelay.
~NOTE :~ ::: ~ ;
- CSF should not<b~implemented until directed by this procea,LJre.
- 2. Verify at le:a~f one oflhe following Perform the following:
annunciators - LIT:
- a. Ensure SIIS/I - RESET:
- 1~b-20, 8/3 "CO NT. SUMPLEVEL >3.3,<'
- W ' _
_1) 1) ECCS. OR _ 2) DIG load sequencers.
** 1AD-21, 8/3 "CONT. SUMP LEVEL >3.3 _ 3) IF AT ANY TIME a 8/0 occurs, ftn ~ THEN restart SII S/I equipment previously on.
- b. Ensure the following valves - CLOSED:
- 1FW-27A (NO (ND Pump 1A Suct From FWST)
FW-SS8 (ND
- 1FW-558 (NO Pump 18 Suct From FWST).
(RNO continued on next page)
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/5000/ES-1.3 30f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. (Continued)
- c. IF valve(s) will not close, THEN:
_ 1) Stop associated ND NO pump(s).
- 2) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):
* "C-LEG RECI R FWST TO CONT SUMP SWAP TRN A"
* "C-LEG RECI R FWST TO CO NT SUMP SWAP TRN B". 8".
_ 3) Close the associated ND pump(s) containment sump suction valve(s).
- d. IF FWST level less than 37% due to FWST puncture, THEN RETURN TO procedure and step in effect.
- e. IF both NS pumps are off, THEN GO TO Step 2 RNO g.
- f. IF either of the following annunciators are lit:
_ . 1AD-20, B/2 8/2 "CO NT. SUMP LEVEL
>2.5 ft" OR
- 1AD-21, B/2 8/2 "CONT. SUMP LEVEL
>2.5 ft",
_ THEN GO TO Step 3. (RNO continued on next page)
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A/5000/ES-1.3 4of38 4 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 2. (Continued)
- g. IF a" all of the following conditions met:
- FWST level - LESS THAN 8%
- NC temperature - GREATER THAN 200°F
- Containment Spray - PREVIOUSLY IN SERVICE
- Indicated containment sump level -
GREATER THAN 0.5 FT. _ THEN GO TO Step 3.
- h. IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect.
- i. IF both "CO NT. SUMP LEVEL >3.3 fi" ft" annunciators on 1AD-20 and 1AD-21 dark, THEN stop a" all pumps taking suction from the containment sump.
_ j. GO TO EP/1/A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
- 3. Verify KC flowto NO hec,lt exchangers -~ _ Establish KC flow to affected NO Hx(s).
GREATER THAN 5000 GPM.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/N5000/ES-1.3 EP/1/A/5000/ES-1.3 5 of 38 50f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED 4.;.h~lf~i.ili'I.It~)i
- 4. Ensure SII- RESET:
- a. i~~~~l ECCS. a. Perform the following:
_ 1) IF either reactor trip breaker is closed, THEN dispatch operator to open Unit 1 reactor trip breakers. _ 2) WHEN trip br.eakers open, THEN reset ECCS.
- b. BIG 'load sequencers,' b. Dispatch operator to open the affected sequencer(s) control power breaker:
- 1EDE-F01 F (Diesel Generator Load Sequencer Panel 1DGLSA) (AB-577, BB-46, Rm 496)
- 1EDF-F01 F (Diesel Generator Load Sequencer Panel 1DGLSB) (AB-560, BB-46, Rm 372).
- c. IFAT'ANYTIME:?I3/O occurs, THEN restart 811 equipme'nlpreviouslyon.
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/SOOO/ES-1.3 6 of 38 60f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED S. ;A'~4.lll~";;~rA>#>**>>\****;~ti":*$;-~lduar*;Zf;> Align SII syst~m for recirc as follows:
- 5. ~M:U".~, ,,,,*.,"'~iJDi1,~Il,(:~. . , . !1~_s . *"""f/fl§1l a~*
- a."V~rify jD"w** f~!~;P~f!§~i*
follClWing valves - OPEN: a. Perform the following:
** j;~A~_lK~*:G()ntSi\!mJ 1J)JI-18SA(NO Pump 1A ContSdmp _ 1) Manually open affected valve(s).
Suct)
- 2) IF valve(s) will not open, THEN:
- 1NI-184B{NO PUrTlp18 Cont Sump Suct). _ a) Stop the NOND pump{s) pump(s) associated with a closed containment sump suction valve(s).
b) Close the associated ND NO pump(s) suction valve from the FWST:
- 1 FW-27A (NO Pump 1ASuct 1FW-27A(ND 1A Suct From FWST)
FW-SS8 (NO
- 1FW-558 (ND Pump 18 Suct From FWST).
(RNO continued on next page)
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/5000/ES-1.3 70f38 7 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued) c) WHEN the NO pump(s) suction valve from the FWST is closed, THEN perform the following:
(1) Attempt to manually open the affected containment sump suction valve(s).
- 1NI-185A (NO Pump 1A Cont Sump Suct)
*.1NI-184B(NOPump1B 1NI-184B (NO Pump 1B Cont Sump Suct).
(2) IF affected containment sump suction valve will not open, THEN dispatch two operators to open the affected valve(s):
- 1NI-185A 1NI-185A(NO(NO Pump 1A Cont Sump Suct)
(AB-545, EE-FF, 52-53, Rm 217)
- 1NI-184B (NO Pump 1B Cont Sump Suct)
(AB-545, FF-GG, 52-53, Rm 217).
- 3) IF both containment sump suction valves are closed, THEN:
_ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ b) GO TO EP/1/A15000/ECA-1.1 EP111 A/5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/NSOOO/ES-1.3 EP/1/N5000/ES-1.3 88of38 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued)
S.
- b. Ve.f(tJ:19,'~lji~;~f&~~
VerifY following valves - CLOSED: b. Perform the following:
- ** i~~[I*i.<'*Af.* .....""Pump
. . ::. .,.'~:'."1ASuct i:1RW"21~lm>liIrmYI~~i$i!r(jfr;~m' 1FW-27A,(ND FWST)
,',;,::' '.From
/;,;./.". _ 1) Manually close affected aff-ected valve(s).
- 2) IF valve(s) will not close, THEN:
** 1FW-558,(ND~pmp 18 Suct From FWST). _ a) Stop associated ND NO pump(s).
b) Depress the following "DEFEAT" pushbutton(s) for the affected train(s):
* "C-LEG RECIR FWST TO CONT SUMP SWAP TRN A"
* "C-LEG RECIR FWST TO CONT SUMP SWAP TRN B". 8".
_ c) Close the associated N NOD pump(s) containment sump suction valve(s). d) IF both containment sump suction valves are closed, THEN: _ (1) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ (2) GO TO GOTO EP/1/NSOOO/ECA-1.1 EP/1 I N5000/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/SOOO/ES-1.3 90f38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued) c.\tit~(f~.~
- c. Verify NO pumps- ON. c. ~~.rmf,itlfltfi"~~
- c. Perform thef6l1qwing:
_ 1) .Start ND pump(s) with suction
- aligned to an open containment Should start 1B ND pump at this IShould sump suction valve.
time. CRITICAL TASK! 2) IF no ND pump can be started OR no ND train can be aligned for recirc, THEN: _ a) IF a valid red OR orange path procedure is in effect, THEN RETURN TO procedure in effect. _ EP/1/A15000/ECA-1.1 b) GO TO EP/1/A/SOOO/ECA-1.1 (Loss Of Emergency Coolant Recirculation).
- d. Isolate NI pump miniflowasfollows:
_1) _ 1) Verify NC pressure -LESS THAN 1) Perform the following: 1620 PSIG. _ a) Stop NI pumps. _ b) WHEN pressure is less than 1620 PSIG, THEN start NI pumps.. pumps
- 2) Clo!;)ethe followingValve$;
* "1!~1~115A(NI Pump:1AMiniflow Isol)
** 1NI-144A (NI Pump 1BMiniflow
.Isol);
_ 3) Plaqe"PWR OISCQNFQR tN.I~147B"switch' ill "ENj\BLE". _ 4)' Close 1 NiL:147B (NI Pump Miniflow Hdr To FVVST Iso I).
CNS TRANSFER TO COLD lEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/5000/ES-1.3 10 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued) e.(_A,t~'W~il\i&Alirf~*"t;:
- e. Close the following v?lves:
".,.",~~,,,~~v~,y**Y*;./.-**.9?OCa~~
** 1ND-32A (NO Train1A Hot Leg loj Isol)
- 1ND-658 (NO Train 1B Hot Leg Inj Isol).
f: Verify at least one of the following NV f. Perform the following: pumps miniflpwyalves - CLOSED: _ 1) IF 1NI-9A (NV Pmp C/l Inj Isol) _ .* 1NV-203A(NV PumpsA&B Recirc AND 1 NI-1 OB (NV Pmp C/l Inj Isol) 1NI-10B Isol) are closed, THEN maintain charging flow greater than 60 GPM. OR
- 2) Close the following valves:
- *.1:.t:4\l~2o~.lJiOlp$:,*A~erRfl~kc
;tillit' .. .
1NV..202B (NV Pmps A&B . Recirc "p". ",' . ' . ' " '" Isol).
- 1NV-203A (NV Pumps A&B Recirc Isol)
- 1NV-202B (NV Pmps A&B Recirc Isol).
- g. Align NO train discharges to NI and NV pump suctions as follows:
- 1) Open the followi'ng valves:
- 1NI-392A (NI Pump Suct X-Over From NO)
* .. 1Nl-~33B(NI :pump SuctFrqrn NO).
_ 2) Ensure 1NI-334B (NIPump Suct X-OverFrom NP)- OPEN.
- 3) Open the*followIngvalves:
- 1N@-:-2aA(~p .~:upply TON\1&1A NI Prnps) .
- 1NI-136B (NO Supply To NI Pump 1B).
CNS TRANSFER TOT.o C.oLD COLD LEG RECIRCULATION RECIRCULATI.oN PAGE NO.N.o. EP/1/N5000/ES-1.3 EP/1/A/5000/ES-1.3 11 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued)
- h. Isolate FWST from NV c3rip Nlpumps as follows:
_ 1) Place "PWR DISC.oN FOR 1 NI-100B" switch in "ENABLE". _ 2) Close tNIHOOB (NI Pmps Suct _ 2) Dispatch operator to close 1 1NI-100B NI-1 OOB FromEVV~JT (NI Pmps Suct From FWST) (AB-552, HH-JJ, 53-54, Rm 234).
- 3) Clpseith, following valves: 3) Perform the following:
** lt1jV::252A(NV Pumps Suct From a) IF 1NV-252A (NV Pumps Suct FWST) From FWST) cannot be closed, THEN dispatch operator to
- 1 NV~2.5'3B (NV Pumps Suct From perform the following:
FWSr). _ (1) Open
.open 1EMXA-R04A (NV Pump Suction From FWST Motor (1 NV252A)) (AB-577, FF-54, Rm 478).
_ (2) Close 1NV-252A (NV Pumps Suet Suct From FWST) (AB-554, HH-53, Rm 234) (Ladder needed). b) IF 1NV-253B (NV Pumps Suct From FWST) cannot be closed, THEN dispatch operator to perform the following: _ (1) Open
.open 1EMXJ-R03A (NV Pump Suetion Suction From FWST Motor (1 NV253B)) (AB-560, GG-56, Rm 330).
_ (2) Close 1NV-253B (NV Pumps Suct Suet From FWST) (AB-554, HH-JJ, 53-54, Rm 234) (Ladder needed).
CNS TRANSFER TO COLD LEG RECIRCULATION PAGE NO. EP/1/A15000/ES-1.3 EP/1/A/5000/ES-1.3 12 of 38 Revision 21 ACTION/EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 5. (Continued) i.i.r~.Bif§J.~!'~mal!1lI~.
Verify properrecirc flow as follows: i. IF any S/I SII pump on without a suction flowpath, THEN stop the affected tJa'tjlh'mJiiiSl4i"ilittl1\'i'~,jW~la'AW'j[fm'M$~{!li'i
":J2~:v~~}!>)1~\Wt,;~*~:~01~t~~,~~~b~~>~~~j~~~:'
* "NV SIIFL0W" -INDICATING FLOW pump(s).
*,ttfjtJ7mp~';.iIN~'lRfIII~
- NJ'pumps - INDfqATfNG FLOW THE SCENARIO CAN BE
** ;mIf>:IlJll;~;~NWI'l~Tj._i ND'pumps -INDICAl'rNC3 FLQW. TERMINATED AT THIS POINT.
- 6. WHEN FWST level decreases to 11 11%%
(1AD-9. El8 (1AD-9, Et8 "FWST LO-LO LEVEL" alarm lit), THEN perform the following: lit).
- a. Stop NS Pumps.
- b. Align NS for recirc. REFER TO Enclosure 2 (Aligning NS for Recirculation).
- 7. IF any NS pump in service with suction aligned to FWST. FWST, THEN perform the following:
- a. Ensure appropriate operator is in possession of Enclosure 2 (Aligning NS for Recirculation).
- b. Designate operator to ensure NS pumps immediately secured when FWST level decreases to 11 % OR 1AD-9, E/8 "FWST LO-LO LEVEL" alarm lit.
- c. IF time and manpower permit, THEN notify designated operator to review Enclosure 2 (Aligning NS for Recirculation) for current plant conditions.}}