ML20247H458
| ML20247H458 | |
| Person / Time | |
|---|---|
| Site: | Millstone  |
| Issue date: | 04/09/1998 |
| From: | NORTHEAST NUCLEAR ENERGY CO. |
| To: | |
| Shared Package | |
| ML20247H439 | List: |
| References | |
| EOP-35-E, EOP-35-E-0, NUDOCS 9805210171 | |
| Download: ML20247H458 (17) | |
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EOP Review and Approval Form / 3.
.fl (Sheet I of 1) .
DOCUMENT NO.
EOP 35 E-0 3
TITLE REV. NO.
Reactor Trip or Safety injection 19 PREPARED BY DEPARTMENT Operations, U3 DOCUMENT REVIEW Review Type Sign and Date Print # I comm%ts Den ent L a w ason J{ Atne 03 cf5 oth. c ALML Ah / - * *s Cn<nece b.1, '
do,- 4 IR / 0 ~4 (Fh Safety Evaluation Attached?
YES @ NO Environmental Review YES NO PORC APPROVAL APPROVAL DATE 9 ' O_. MEETING NUMBER .3 -9 b - I 8 Z-i
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EFFECTIVE DATE Verified Revisionfe//'/#
initia!_Mg D'.ie_YJ-ff Printed: 03-25-98 03:55 pm OP 3265, Att 5 Rev. 6 (08-19-97) 9805210171 980507 Staton Admin Procedures Group OSCAR Report PDR ADOCK 05000423 P PDR
n REACTOR TRIP OR EOP 35 E-0 Page1 SAFETYINJECTION Rev.19 ~ .$
g es.u Section !!
Eff. Rev 9 Procedure Page 1-27 19 ?
Attachment A," Containment Isolation Phase A Valves" 19
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kEACTOR TRIP OR EOP 35 E-0 Page 2 3 SAFETY INJECTION Rev.19 L e
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e A. PURPOSE This procedure provides actions to verify proper response of the automatic protection systems following manual or automatic actuation of a reactor trip or safety injection. It is also used to assess plant conditions and identify the appropriate recovery procedure. i B. ENTRY CONDITIONS This procedure is applicable in Modes 1,2, and 3 when SI is not blocked.
Using this procedure in any other Mode requires a step by step evaluation to i determine if a specified action is still applicable in the current plant condition.
SYMPTOMS
- 1. Symptoms requiring a reactor trip if one has not occurred:
SIGNAL SETPOINT
= PR Flux High 109 % (2/4)
- PR Flux High (low) 25% (2/4)
- PR Flux Rate High +5% / 2 seconds (2/4)
IR Flux High 25% (1/2)
( 5
= SR Flux High 10 cps (1/2)
- OTAT 120% ipenalties (2/4)
- OPAT 109% - penalties (2/4)
PZR Level High 89% (2/3)
PZR Press High 2385 psia (2/4) !
- PZR Press Lo 1900 psia (2/4)
= SG Level Low-Low 18.1% (2/4)
One Loop Flow Low 90% (2/3)
Two Loop Flow Low 90% (2/3)
. Turbine Trip > P9 Turb Stop Valves Closed (4/4)
ETS Press.<500 psig (2/3)
=
SSPS Gen Warning Train A and B l
RCP Low Shaft Speed 95.8% (2/4)
=
SI Actuated N/A V
liEACTOR TRIP OR EOP 35 E Page 3 SAFETYINJECTION Rev.19 ;
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- 2. Symptoms requiring a reactor trip and safety injection, if one has not occurred.
SIGNAL SETPOINT
- PZR Press Low 1892 psia (2/4)
- Ctmt Press High 17.7 psia (2/3)
- Steam Line Press Low 658.6 psig (2/3) l
- 3. Symptoms of a reactor trip
= Any reactor trip annunciator lit.
- Rapid decrease in neutron level indicated by nuclear instrumentation.
- All shutdown and control rods fully inserted (rod bottom lights lit). i
- 4. Symptoms of a reactor trip and safety injection
- Any SI annunciator lit.
i,
- SI pumps running
- Group 2 ESF Status lamps lit.
ENTRY CONDITIONS
- 1. Any at power manual reactor trip required by an operating procedure as a result of plant conditions.
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f liEACTOR TRIP OR EOP 35 E-0 Itge4 SAFETY INJECTION Rev.19 h
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STEF ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED I
NOTE
- Foldout page must be open.
- ADVERSE CTMT is defined as GREATER THAN 180 F or GREATER THAN 105R/hr in containment.
- The reactor can be interpreted as " tripped" when any two of the three bulleted substeps of step 1.* are satisfied.
I.* Verify Reactor'IYip TRIP the reactor
. Check reactor trip and bypass E reactor will NOT trip, breakers - OPEN THEN
- Check rod bottom lights - a. TRIP Bus 32B and 32N.
LIT b. Dis 3atch an operator to locally
(. TRlP the reactor trip and
- Check neutron flux - bypass breakers' DECREASING
- c. E reactor trip can NOT be verified, THEN Go to FR-S.1, Response to Nuclear Power Generation /ATWS, step 2.
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REACTOR TRIP OR EOP 35 E-0 Page 5 (
SAFETYINJECTION Rev.19 e 4.
STEF ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED -
l Verify'Ibrbine 'Irip 2.*-
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- a. Check all turbine stop a. TRIP the turbine.
valves - CLOSED LE the turbine will NOT trip, THEN Runback the turbine to close the control valves.
i IE the turbine can NOT be i runback, THEN CLOSE the MSIVs and i MSIV bypass valves.
3.* Verify Power To AC Emergency I Busses
- a. Check busses 34C and 34D - a. Try to Restore power to at AT LEAST ONE least one AC emergency bus.
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ENERGIZED LE power can NOT be restored l to at least one AC emergency bus, THEN Go to ECA-0.0, Loss of All AC Power, step 3.
- b. Check busses 34C and 34D - b. Try to Restore power to BOTH ENERGIZED de-energized AC cmergency bus.
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REACTOR TRIP OR EOP 35 E-0 Page 6 9 SAFETY INJECTION Rev.19 h STEF ACTION / EXPECTED RESPONSE- RESPONSE NOT OBTAINED g 4.* Check If SI Is Actuated Check if SIis required: q
- a. Verify Safety Injection
- CTMT pressure -
Actuation annunciator - LIT GREATER THAN 18 psia l
M
- PZR pressure LESS THAN 1890 psia M
+ PZR level LESS THAN 16%
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- RCS subcooling LESS THAN 32 F M
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i' SG pressure LESS THAN 660 psig IE SI is required, THEN Initiate SI.
IE SI is NOT required, i THEN l Initiate monitoring of CSF Status Trees and Go to ES-0.1, Reactor Trip l Response.
- 5. Verify Service Water Pumps - START pump (s).
AT LEAST ONE PER TRAIN RUNNING l
ONE PER TRAIN RUNNING THEN l START pump (s).
REACTOR TRIP OR EOP 35 E-0 Page 7 (
SAFETYINJECTION Rev.19 i
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h.. STEF ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED I
= IE ECCS pumps c'o NOT start, l Check RUNNIS]IG"mps - THEN START pump (s).
- Check RHR pumps -
RUNNING
= Check two charging pumps -
RUNNING
- 8. Verify AFW Pumps Running
- a. Check MD pumps - a. START pump (s).
RUNNING
- b. Check turbine-driven b. OPEN steam supply valves. I pump -
RUNNING, IF NECESSARY l
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AEACTOR TRIP OR EOP 35 E-0 Pagm 8
- SAFETY INJECTION Rev.19 i
(, ' STEP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED
- 9. Verify FW Isolation as necessary Align component for minimum safety (s) function.
- Check SG feed regulating valves - CLOSED Check SG feed regulating bypass valves - CLOSED Check FW isolation trip valves - CLOSED Check MD FW pump - l STOPPED
+ Check TD FW pumps -
TRIPPED Check SG blowdown isolation valves - CLOSED Check SG blowdown sample t isolation valves - CLOSED Check SG chemical feed isolation valves - CLOSED
- 10. Check If Main Steam Lines Should lle Isolated
- a. Check Ctmt pressure a. Proceed to step 11.
GREATER THAN 18 psia OR any SG aressure LESS T}IAN 660 psig
- b. Verify MSIVs and b. Initiate MSI.
MSIV bypass valves -
CLOSED IE MSI will NOT actuate, THEN CLOSE the MSIVs and MSIV bypass valves.
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REACTOR TRIP OR EOP 35 E-0 Page 9 1 SAFE"IY INJECTION Rev.19 i i w
(ll' STEF ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED g i
- 11. Check If CDA Required I
- a. Check Ctmt pressure is a. Proceed to step 12.
GREATER THAN 23 psia
.QR Ctmt spray is initiated !
- b. Verify CDA
- 1) Quench sprayinitiated 1) Initiate CDA. !
IE CDA will NOT actuate, l THEN a) START quench spray ,
pumps.
b) OPEN(3uench spray l Pump discharge valves I
( (3OSS*MOV34A and 3OSS*MOV34B).
- 2) RPCCW Ctmt su 3 ply and 2) CLOSE valves.
return header iso.ations -
CLOSED
- 3) RPCCW aumps - 3) STOP RPCCW pumps.
STOPPED
- c. STOP ali RCPs
- d. STOP all main circulating water pumps
- c. Proceed to step 13.
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R'EACTOR TRIP OR EOP 35 E-0 Itge 10 i SAFE 1YINJECTION Rev.19 6 4
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STEF ACTION / EXPECTED RESPONSE- RESPONSE NOT OBTAINED -g
- 12. Verify CAR Fans Operating In s Emen;ency Mode
- CAR fans A and B -
RUNNING
- CAR fan C - STOPPED
- b. Verify RPCCW Ctmt supply b. OPEN valves.
and return header isolations - OPEN
- c. Verify Train A and B RPCCW c. OPEN valves.
supply and return to chill water valves - OPEN I
- 13. Verify CIA
( a. Check ESF Group 2 status a. Initiate CIA AND Verify ,
columns 2 throug h 10 - LIT minimum safety function is '
met.
IE CIA will NOT actuate, i THEN !
Reposition valves as necessary for minimum safety function using Attachment A.
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REACTOR TRIP OR EOP 35 E-0 Page 11 SAFETY INJECTION Rev.19 RESPO;JSE NOT OBTAINED h:
STEP ACTION / EXPECTED RESPONSE
- 14. Verify Proper ESF Status Panel as necessary .
Indication Align component for minimum safety (s) function.
. Verify ESF Group 1 lights -
OFF
= Verify ESF Group 2 lights -
LIT IE Main Steam Line Isolation has occurred, THEN Verify ESF Group 3 lights - LIT
- IE CDA has occurred, THEN Verify ESF Group 4 lights - LIT
- Ctmt temperature GREATER THAN 180 F DE
- Ctmt radiation GREATER THAN 105R/g l
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REACTOR TRIP OR EOP 35 E-0 Page 12 SAFETY INJECTION Rev.19 r y (J S1EP ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED k
C AUTIO N
- To provide adequate ECCS 110w, RCS subcooling and PZR level should be monitored to ensure that the charging pump is manually restarted if RCS subcooling based on core exit TCs 1 decreases to LESS THAN 32"F (115*F ADVERSE CTMT) or j I
PZR level decreases to LESS THAN 16% (50% ADVERSE CTMT).
=
If offsite power is lost after SI reset, manual action to restart safeguards equipment may be required.
- DO NOT reset CDA if recirculation spray pumps are required and have not automatically started.
- 16. Verify ECCS Flow
- a. Check charging pump flow a. START pumps and Align indicator - valves.
( FLOW INDICATED
- b. Check RCS pressure - b. Proceed to step 16.i.
GREATER THAN 1650 psia sia ADVERSE
- c. Check PORV block valves - c. OPEN energized block valves.
OPEN i
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REACTOR TRIP OR EOP 35 E-0 Page 13 SAFETY INJECTION Rev.19 s
,^ STEF ACTION / EXPECTED RESPONSE- RESPONSE NOT OBTAINED ti
- d. VERIFY the following: d. Proceed to step 17.
1) hagngumps - TWO
GREATERTHAN 32 F (115*F ADVERSE CTMT).
- 3) Secondary heat sink:
- NR levelin at least one
( SG - GREATER THAN8%
42% ADVERSE MT)
- 5) PZR level - GREATER TIIAN 16%
(50% ADVERSE CTMT) 1
- c. RESET SI
- f. RESET CDA,ifrequired
- g. STOP all but one charging '
l pump and Place in AUTO l
- h. Proceed to step 17. .
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REACTOR TRIP OR EOP 35 E-0 Page 14 '
SAFETY INJECTION Rev.19 h
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. STEF ACTION / EXPECTED RESPONSE RESPONSE NOT OBTAINED -
- i. Check SI pump flow i. START indicators - valves. pumps and Align FLOW INDICATED
- j. Check RCS pressure - j. Proceed to step 17.
LESS THAN 300 psia (500 psia ADVERSE CMT)
- k. Check RHR pump flow k. START pumps and Align indicators - valves.
FLOW INDICATED
- 17. Verify Adequate Heat Sink
- a. Check NR level in at least one a. Proceed to step 17.d SG -
GREATERTHAN 8%
(42% ADVERSE GMT)
- b. Control feed flow to maintain
( NR level -
BETWEEN 8% and 50%
(42% and 50% ADVERSE CTMT) <
- c. Proceed to step 18. l
- d. Verify Total AFW Flow - d. START pumps and Align I 1
GREATER THAN 530 gpm valves as necessary.
IE AFW Flow GREATER THAN 530 gpm can NOT be established, THEN Initiate monitoring of CSF Status Trees and Go to FR-H.1, Response to Loss of Secondary Heat Sink.
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, STARTUP ISSUE Review Only Copy
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UNRESOLVED ITEM REPORT SUBJECT FOR RESOLUTION UNIT Oper: tor action times assumed in the Chapter 15 analyses. 3 UIR LOG NUMBER 1068 ORIGINATOR DATE DEPT SYSTEM 0343 10/28/96 FSAR3 -
SOURCE DOCUMENT Primnry l Secondary l Reference FSAR CHAP 15 l
DESCRIPTION OF UNRESOLVED ITEM For two transients, questions are being raised regarding the operator action times assumed in the analysis.
DISCUSSION DETAILS:
Specifically,1). in the inadvertent St, the analysis assumed that the operator terminates the injectior. flow to avoid an overfill ofthe system (i.e., solid pressurizer). However, the operator experience at the simulator may not support this assumption in all cases. 2). Following a LOCA, it is assumed that the operator can line up the charging and the HPSI pumps for the containment recirculation within 10 min. of receiving low low level alarm in the RWST. The simulator experience suggests that in some cases, it may take longer than 10 mins. to complete the change in the line-up.
RECOMMENDED DISPOSITION DETAILI The following plan is recommended: a). Collect data based on the simulator experience to establish if there is discrepancy in the anlaysis a:sumption and operator actions. b). If a discrepancy is established for the inadvertent Si, we may need to revise the EOPs or change the emphesis in the operator training regarding the action related to Si termination. There seems to be no analysis relief (Other Westinghouse plants ne clio dealing with issue). c). For the LOCA issue, an engineering analysis is needed to establish the maximu time available for the change in line-up of the charging and HPSI pumps before the pumps start to cavitate, Once this analysis is complete, then potential EOP changes, if any, can be inv1stigated. Safety analysis branch would work with Engineering, Operation and Training to resolve these issues.
DISPOSITION BY DATE SUPERVISOR DATE NOTIFIED 10/28/96 1/7/97 FINAL DISPOSITION AR to Safety Analysis c3 ranch to perform the Dispositioned Actions of UIR 1068
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CATEGORY 13 - FSAR COMPLETION MILESTONE reg START .UP MODEO OTHER PRIOR,lTY 2 ,
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EP/ PVRT APPROVAL DATE UPM APPROVAL DATE Yes 1/13/97 Yes 1/24/97
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FINAL DISPOSTION DOCUMENT DOCUMENT NUMBER CCMMENTS AR 97002499 SAB ACR M3-96-0245 FINAL ROUTING DISTRIBUTION: lOnginator lNo l System Engineer: lNo l Project File. lNo VIR REVIEWED I CLOSED (Original) DATE ATTACHMENTS For UIR No.1068 Pt 14/rev 2 Page 1
l A n /
e 9/30/97 \.97-53s Form Approved by 7 f Tr/3-Q Effective Date SORC Mtg. No.
CR Forni CR No:
Initiation M3 '/53 '7 RK0J5 dis MEMcMUWefSJDJEGM.IEOams BMWptMK40. 2iHDId f) . : Jt '.' S O - "
V L"j Organization identifying condition: Discovery date: 12/10/97 System #: 3301 Affected Unit (s):
Safety Analysis Branch Discovery time:
1.
10 20 30 Co Condition description (including how condition was discovered, organization creating condition, what activity was in progress when event was discovered):
UIR 1068 identified the issue that based upon simulator data, the operators cannot meet the response time assumed for the Inadvertent SI event in Chapter 15 of the FSAR. The feasibility of a new approach for the Inadvertent SI event (FSAR Section 15.5.1) is being investigated, to provide a longer operator response time to mitigate the event Analysis is in progress to show that the PORV is qualified for water relief for at least one hour. Preliminary results indicated that the analysis will be successful. This will provide a significant increase in opemtor response time over the current analysis time of 13 minutes. However, in order to credit the new analysis, at least one PORV must be operable to provide RCS pressure relief so that the pressurizer safety valves would not relieve water since they would not be evaluated for this condition. This requires a modification to Technical Specification 3.4.4 to assure that at least one PORV would be operable to provide automatic pressure control. Since this TS change is needed to implement a new approach, there are no associated operability or deportability issues for the TS change. Resolution of UIR 1068 is needed prior to entry into Mode 3.
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Component Identification Number- 3RCS*PCV455 AND 456,3RCS*MOV 8000A A,ND D .
Method of Discovery: Management
- 2. Continuation Sheet O Immediate corrective action taken Nuclear Licensing e and Engineering have been informed about the need for a TS change.
TR# AWO# Eng. Disp.#
- 3. Continuation Sheet O Recommended corrective action Initiate a TS change to assure that at least one PORV would be operable for automatic pressure control.
4 Initiator Name: Continuation Sheet O Time: 1300 Phone No.:
_ Initiator's Signature: , Date: 8 Cost Control Center: - -
Initiator Requests Follow.up: YES . -
Supervisor Name:
, , Time: .2,.J o p W/. . gg .g.
Supervisor Signature: Date:
_/c2[/o[C)J Phone No:
181MtiClikiaill@tewnsilElitillfsgoRer41?ilirif)feirirEi_li_iliMSE.feEiBireiiEMR6 1.
Does CR have an actual or potential effect on plant or personnel safety, operability, Notes:
deportability, (e.g., NGP 2.25, EPlP 4400) or plant operation?
9okeNcd NP 0 O Yes or Don't Know (Section 3 required to be completed.)
_ J No Ifcontinuation sheets (IU' C1. l' age 7) are required. identify the section being continued by section number.
Form RP4-1 Rev.5 Page I of 7
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