ML080940462
| ML080940462 | |
| Person / Time | |
|---|---|
| Site: | Nine Mile Point  |
| Issue date: | 03/31/2008 |
| From: | - No Known Affiliation |
| To: | D'Antonio J Operations Branch I |
| Hansell S | |
| Shared Package | |
| ML073040288 | List: |
| References | |
| ES-D-1 | |
| Download: ML080940462 (129) | |
Text
Appendix D Scenario 0 ut I i n e Form ES-D-1 Facility: Nine Mile Point 2 Examiners:
Operators:
Initial Conditions: Simulator IC-241
- 1. Reactor Power 90%
Turnover:
- 1. All equipment operable.
- 2. Swap Service Water Pumps from the 2SWP*P1 B to the 2SWP*P1 F for normal equipment rotation. Pre-start checks have been completed and an A 0 is standing by at the F pump Scenario No.: NRC-01 Op-Test No.: March 2008 Event No.
6 8
9 Event DescriDtion I N (SROI I N2-OP-77 Service Water RR30,31 TS (SRO)
N2-SOP-6, Feedwater Failures N2-SOP-29. Sudden Reduction in Core Flow PSP exceeded, RPV blowdown required (CT)
EOP-C2 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NRC Scenario 1 March 2008
Facilitv: Nine Mile Point 2 Scenario No.: NRC-01 OD-Test No.: March 2008 TARGET QUANTITATIVE ATTRIBUTES
[PER SCENARIO: SEE SECTION D.5.d)
- 1. Total malfunctions (5-8)
Events 2.3.4.5.6.8
- 2. Malfunctions after EOP entry (1-2)
Events 8
- 3. Abnormal events (2-4)
Event 2 SOP-I 3 Event 3 SOP-34, Event 4 SOP-6,29 Event 5 SOP-8
- 4. Major transients (1-2)
Event 7
- 5. EOPs enteredkequiring substantive actions (1-2)
- 6. EOP contingencies requiring substantive actions (0-2)
Event 9 EOP-C2
- 7. Critical tasks (2-3)
CRITICAL TASK DESCRIPTIONS:
CT-1.O Initiate DW spray to control containment CT-2.0 Initiate RPV Blowdown when PSP is exceeded pressure and DW spray established ACTUAL ATTRIBUTES 6
1 4
1 2
1 2
NRC Scenario 1 March 2008
NMP SIMULATOR SCENARIO NRC Scenario I REV. 00 No. of Pages: 22 APRM UPSCALE/RBCLCW PUMP TRIP/ADS SRV OPENS/CONTROL ROD DRIFT/REACTOR SCRAM-MODE SWITCH FAILURE/STEAM LEAK IN DRYWELL PREPARER S. Dennis DATE VALIDATED DATE GEN SUPERVISOR OPS TRAINING R. Brown DATE 1/23/08 0 PE RAT IO N S MANAGER NA Exam Security DATE CON FIG U RAT1 ON CONTROL NA Exam Security DATE SCENARIO
SUMMARY
Length: 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Initial Power Level: 90%
The scenario begins at 90% power. The BOP will be required to swap from the 2SWP*Pl B to the 2SWP*P1 F for normal equipment rotation. After completion of the pump swap, one of the running RBCLCW pumps will trip and the standby pump will fail to auto start. The standby pump can be manually started by the operators.
An ADS SRV will then go open but can be closed by pulling the SRV solenoid fuses.
When this occurs, a Drywell vacuum breaker pair will fail open. The crew will enter the SOP for Stuck Open SRV and the SRO will review Technical Specifications (TS) in regard to the vacuum breakers.
Once TS are addressed a trip will occur on one Feedwater Pump and only a partial Recirc Runback will occur. SOPS must be entered to control feedwater level and address the reduction in power. Cram rods will need to be inserted and TS must be addressed due to loop flow mismatch.
When plant conditions stabilize, one control rod will drift out requiring an entry into the SOP for Unplanned Power Changes. The SOP will require that power be lowered and the RO will reduce recirculation flow IAW procedures. After power is lowered, another control rod will drift out requiring a reactor scram.
When the reactor scrams a steam leak will occur inside the drywell. LPCS and RHR A will fail to initiate and RHR B will trip when Drywell pressure exceeds 1.68 psig.
However, both LPCS and RHR A can be started manually. RHR A must then be placed NRC 2008 Scenario 1 March 2008
in Suppression Chamber sprays per EOP-PC. When Suppression Chamber pressure exceeds 10 psig, the crew will attempt to spray the Drywell with RHR A, but RHS*MOV15A will not open. Spraying the Drywell must be accomplished with Service Water (Critical Task). Once DW sprays are in service and PSP is evaluated, it will be recognized that RPV Blowdown is required once above the PSP (Critical Task). The crew will blowdown the reactor and continue to control Containment pressure.
The scenario ends with the blowdown complete and containment pressure lowering.
Major Procedures Exercised:
EOP-RPV, PC, C2. SOP-8,34 EAL Classification:
Alert 3.1.I - Primary Containment cannot be maintained below 1.68 psig due to coolant leakage.
Termination Criteria:
RPV Blowdown is complete and containment pressure lowering NRC 2008 Scenario 1 March 2008
I. SIMULATOR SET UP A. IC Number: IC-I 7. (Operation Above 100% Rod Line)
B. Presets/Function Key Assignments
- 1. Malfunctions:
- a. RH14A ECCS FAILS TO INITIATE (DIVI)
- b. CW16C CCP-PI C FAILS TO AUTOSTART
- c. CW02B RBCLCW PUMP TRIP PIB
- d. PCIOB DW/WW VACUUM BKR PAIR FAILED OPEN (21SC*RV34 AB) -DELAY 20 SECONDS
- f.
FW03A Feedwater Pump Trip (PIA)
- g. RR30 HPU B PMP#I FAILURE
- e. RD05-18-31 CONTROL ROD FAILURE DRIFT OUT
- f. RD05-42-39 CONTROL ROD FAILURE DRIFT OUT
- g. MS04 STEAM LINE RUPTURE INSIDE PRIMARY CONTAINMENT (DELAY 3 MINUTES)
- h. RHOIB RHR PUMP TRIP (PIB)
PRESET PRESET TRG 1 TRG 2 TRG 3 TRG 3 TRG 3 TRG 4 TRG 6 TRG 7 TRG 8
- 2. Remotes:
- a.
RD08-18-31 HCU ISOLATION FOR INSERTED ROD TRG 5
- c.
RH47 2RHS*MOV 25A EOP JMPR TRG 9 (RHS*MOVI 5A 33 CONTACT)
- 3. Overrides:
- b. OVR-03A2S14D1142815 ON MODE SWITCH (SD)
PRESET C.
OVR-03A2S14D114290 ON MODE SWITCH (REFUEL)
PRESET
- b. OVR-03A2S14D114291 ON MODE SWITCH (SU)
PRESET
- b. OVR-03A2S14D114292 ON MODE SWITCH (RUN)
PRESET
- 4. Annunciators:
- a. None NRC 2008 Scenario 1 March 2008
C. Equipment Out of Service
- 1. None D. Support Documentation E. Miscellaneous NRC 2008 Scenario 1 March 2008
II.
SHIFT TURNOVER INFORMATION TITLE SRO ATC RO PART I:
shift.
To be performed by the oncoming Operator before assuming the NAME TITLE NAME 0
Control Panel Walkdown (all panels) (SM, CRS, STA, CRO, CRE)
PART II:
To be reviewed by the oncoming Operator before assuming the shift.
Shift Supervisor Log (SM, CRS, STA) 0 CRO Log (CRO) 0 LCO Status (SM, CRS, STA)
Lit Control Room Annunciators Computer Alarm Summary (CRO) 0 Shift Turnover Checklist (ALL)
Evol u t ions/Gene ral I n fo rmatio n/Eq u i pmen t Status :
0 Reactor Power = 90%
Loadline = >loo%
0 None
~
PART 111:
RemarkslPlanned Evolutions:
Swap Service Water Pumps from the 2SWP*P1 B to the 2SWP*P1 F for normal pump Rotation.
PART IV:
To be reviewed/accomplished shortly after assuming the shift:
0 Review new Clearances (SM)
Test Control Annunciators (CRE) 0 Shift Crew Composition (SM/CRS)
BOP RO NRC 2008 Scenario 1 March 2008
1 Scenario ID#
INSTRUCTOR COMMENTS (Strenaths. Areas for Immovement. ODen Items etc.)
What Happened?
What we did?
Why? (Goals) 0 the r 0 pt io n s?
NRC 2008 Scenario 1 March 2008
Ill.
PERFORMANCE OBJECTIVES A. Critical Tasks:
CT-1.O CT-2.0 Spray the Drywell with Service Water when RHR is unavailable.
Blowdown the RPV when PSP is exceeded.
B. Performance Objectives:
PO-I.o PO-2.0 PO-3.0 PO-4.0 PO-5.0 PO-6.0 PO-7.0 PO-8.0 PO-9.0 Given the plant with direction to swap Service Water Pumps, the crew will remove the 2SWP*P1 B pump from service and place the 2SWP*P1 F pump in service for equipment rotation IAW N2-OP-11.
Given the trip of a RBCLCW pump and the failure of the standby pump to auto start, the crew will manually start the standby pump IAW SOP-13.
Given the plant or plant system in a condition requiring Technical Specification action, identify the deviation and any required actionshotifications in accordance with all applicable ad mi n ist rat ive, emergency, and technical p roced u res.
Given a pair of failed open Drywell Vacuum Breakers the crew will diagnose the failure and enter Technical Specifications.
Given a stuck open SRV the crew will diagnose the failure enter and execute N2-SOP-34 to close the by pulling the SRV solenoid fuses.
Given a single Feedwater Pump trip, with only a partial Recirc Runback, the crew will enter and execute SOPS 6, 101 D, and 29, to control feedwater level, reduce power and maintain NMP 2 in service.
Given a control rod drift, the crew will execute N2-SOP-8 to fully insert and disarm the control rod.
Given the plant operating and a steam leak inside the drywell the crew will diagnose the leak Given a second control rod drift the crew will recognize the requirement to scram the reactor and will perform a reactor scram.
NRC 2008 Scenario 1 March 2008
PO-I 0.0 Given drywell pressure above 1.68, the crew will verify automatic ECCS initiations and recognize the failure of LPCS and RHR A to start.
PO-I 1.O Given suppression chamber pressure above 10 psig, the crew will spray the drywell using Service Water through RHR B loop prior to exceeding the Primary Containment Pressure Limit.
PO-I 2.0 Given suppression chamber pressure above the Pressure Suppression Pressure with drywell sprays in operation, the crew will blowdown the reactor prior to exceeding the Primary Containment Pressure Limit NRC 2008 Scenario 1 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 1 Swap Service Water Pumps from the 2SWP*P1 B to the 2SWP*P1 F for normal equipment rotation IAW N2-OP-11.
EVENT 1 -SRO Actions EVENT 1 -BOP Actions Role Play: As AO, wait two minutes and report that Service Water Pump P I F prestart checks are complete.
Cue: If asked report that SWP strainer and casing venting are complete.
S RO/Crew Crew conducts a pre-brief, walks down the panels, and tests annunciators.
SRO Directs the BOP to start Service Water Pump I F and secure Service Water Pump I B per N2-OP-I 1.
Conducts a pre-evolution brief.
BOP PO-?.o Reviews N2-OP-11, Section E.2.0 and G.1.O Verifies Precautions and Limitations are met.
Dispatches A 0 to perform prestart check of PID.
Starts Service Water Pump, P I F and secures Service Water Pump, P I B.
NRC 2008 Scenario 1 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 2 RBCLCW Pump P I B trips. Standby Pump fails to auto-start and must be started manually SIM Booth: Activate Trigger # I when cued.
EVENT 2 -SRO Actions EVENT 2 -BOP Actions EVENT 2 -RO Actions ZREW PO-2.0 B
Responds to RBCLCW Pump PIB trip.
Recognizes the PIA pump fails to start.
B jR0 B
Directs ROs to respond to annunciators and enter SOP-I 3 B
May contact the Work Execution Center (W EC) for maintenance followup.
BOP Recognizes failure of standby RBCLCW pump to auto start.
References annunciator response for pump trip.
0 Refers to SOP-I3 and starts the standby pump.
0 Place B Pump in Pull-To-Lock Monitors reactor power, pressure and level.
0 May announce on plant page entry to SOP-I3 NRC 2008 Scenario 1
-1 0-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 3 -ADS SRV Opens/ Drywell vacuum breaker fails open SIM Booth: Activate Trigger #2 when cued EVENT 3 SRO Actions CREW, SRO PO-4.0 and PO-5.0 SRO PO-3.0 Enters into N2-SOP-34 Directs Power Reduction to approx. 85%
Declares PSVl34 ADS valve inoperable.
Refers to Tech Specs 3.5.1. With one ADS valve inoperable no actions is required. Currently the minimum number of REQUIRED ADS valves is still met with one valve inoperable.
When informed Report that a pair of DW vacuum breakers are open determines that DW and SC pressures are equal, therefore the vacuum breakers should not be open.
Refers to Tech Spec 3.6.1.7.2.C for SP to DW vacuum breakers (2hours) and recognizes requirement to perform N2-OSP-ISC-M@002 within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.
NRC 2008 Scenario 1
-1 1-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 3 SRO Actions (Cont.)
EVENT 3 RO actions May direct one loop of RHS placed in Suppression Pool Cooling.
IF RHS is placed in Suppression Pool Cooling, declares RHS inoperable for LPCl mode and enters Tech Spec 3.5.1 CONDITION A REQUIRED ACTION A.l with 7 day COMPLETION TIME.
IF Suppression Pool Temperature exceeds 90°F, enters EOP-PC.
Notifies Operations and Plant Management.
Contacts WEC SRO for assistance and work planning.
Conducts post event brief.
0 Reports one or both of the following :
o P601556 Drywell Vacuum Brkr Inboard Disc Open o P601557 Drywell Vacuum Brkr Outboard Disc Open.
Informs the CRS that 34A and B vacuum breakers indicate open on Panel 2CEC*PNL628 NRC 2008 Scenario 1
-1 2-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 3 RO actions (Cont.)
EVENT 3 BOP Actions Reduces power to approximately 85% per N2-SOP-101 D.
IF Average Suppression Pool temperature is approaching I
10°F...... THEN Scram the reactor per N2-SOP-101 C and continue here.
Monitors parameters to assist in determining SRV position.
Monitors and control RPV water level in directed band in manual.
Make page announcement regarding plant status.
BOP Reports annunciators Enters and executes N2-SOP-34 0
Identify which SRV is open.
( PSVl2 1 )
Place the keylock switch for PSV21 to the OFF position.
0 Did the SRV close? NO (Detail 1)
Use one or more of following indications to verify SRV status:
-SPDS Computer
-ERF Computer Points
-MSSZCI 11; MSSZCl28 NRC 2008 Scenario 1
-1 3-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 3 BOP actions (CONT)
PSVl34 closes afterpulling F81, F82 F13A, F14A. At P601 position indicating (red and green) lights for PSVl34 are now deenergized.
Role Play: Acknowledge as Rad Protection in regard to placing SW rad monitor in service when RHR is placed service
-Reactor Power Change
-Generator Output Change
-Steam Flow/Feed Flow Mismatch
-Acoustic Mon itor Proceeds to back panel P628 with fuse pullers and protective safety equipment (PPE). Using Detail 2, remove the fuses for the affected SRV in the following order until the SRV closes:
C,A,B Solenoid fuse Did SRV close? YES for A solenoid Detail 1 Use one or more of following indications to verify SRV status:
SPDS Computer ERF Computer Points MSSZCI 11 MSSZC128 Reactor Power Change Generator Output Change Steam Flow/Feed Flow Mismatch Acoustic Monitor Exits SOP-34 and informs SRO SRV is closed.
If directed starts RHS in NRC 2008 Scenario 1
-1 4-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 4 - Feedwater Pump Trip, Partial Recirc Runback Sim Booth: Activate Trigger #3 when cued EVENT 4 SRO Actions EVENT 4 RO Actions Suppression Pool Cooling.
Crew PO-6.0 0
Recognizes and responds to trip of PIA feedwater pump trip.
0 Recognizes and responds to partial Recirc Runback Directs crew response IAW the following:
o SOP-6. Feedwater Failures o SOP-I01 D, Power Reduction o SOP-29, Sudden Reduction in Core Flow.
Refers to TS 3.4.1.B. for Recirc Loop Flow Mismatch (2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />)
Direct inserting Cram Rods per SOP-6 0
Recognizes trip of PIA Feedwater Pump.
0 Refers to SOP-6, Feedwater Failures Inserts 4 Cram Rods as required NRC 2008 Scenario 1
-1 5-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 4 BOP Actions SIM Booth Operator: Insert the next malfunction (TRG 4) for control rod drift PRIOR to resetting the runback.
EVENT 5 - Control Rod Drift EVENT 5 SRO Actions I
I by SOP-6 IAW SOP-6, Closes LVlO for tripped feedwater pump PIA.
0 Recognizes Partial Recirc Runback 0
Inserts Cram Rods as directed per SOP-6 BOP Refers to SOP-29 Attachment 1 to address Recirc loop Flow Mismatch Begins recovery actions to reset runback IAW Att.1.
Crew PO-7.0 0
Identifies and reports control rod drift on 18-31 SRO 0
Recognizes entry and directs entry to SOP-8, Unplanned Power Changes 0
Declares control rod 18-31 inoperable per Tech. Spec. 3.1.3 condition C actions C.l and C.2 NRC 2008 Scenario 1 I
-1 6-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPE RATOR ACT1 ONS Sim Booth Operator: When requested to valve out the HCU, Insert TRG 5 after approximately 3 minutes.
EVENT 5 RO Actions (fully insert and disarm)
(4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> to disarm).
Recognizes and identifies Control Rod 18-31 drifting out.
Selects rod for display.
Refers to SOP-8 and inserts drifting control rod 18-31 Releases insert pushbutton and observe rod position.
Recognizes rod continues to drift out Drives the rod full-in and holds insert pushbutton until HCU is disarmed.
When rod 18-1 5 is full-in, directs field operator to close RDS*VI 03
& RDS*V105.
Dispatch Auxiliary Operator to isolate HCU by closing RDS*VI 03 and VI05 in accordance with SOP-
- 08.
NRC 2008 Scenario 1
-1 7-March 2008
I NSTRUCTO R ACT ION SI PLANT RESPONSE OPERATOR ACTIONS EVENT 6, Second Control Rod Drift Sim Booth: Activate Trigger #6 when cued EVENT 6 SRO Actions EVENT 6 RO Actions Crew PO-9.0 Identifies and reports second control rod drift of control rod 42-39 SRO Direct mode switch be placed in shutdown Places mode switch to shutdown.
Provides scram report:
o Mode Switch in Shutdown o APRMs downscale o RPV Water Level o RPV Pressure o All Rods In o FW and MSlV status Maintains RPV level 160-200 inches Monitors RPV pressure 800-1 000 psig and lowering.
NRC 2008 Scenario 1
-1 8-March 2008
INSTRUCTOR ACTIONS!
PLANT RESPONSE OPERATOR ACTIONS EVENTS 7 & 8, Steam Leak Inside Drywell.
LPCS and RHR A Fail to Automatically Initiate and RHR B Trips Sim Booth: Activate Trigger #7 and Trigger #8 activated at 1.68 psig in drywell EVENTS 7 & 8 SRO Actions PO-8.0 Identifies steam leak and ECCS failures.
RO PO-2.
Directs RO to start LPCS and RHR A pumps.
Directs RHR A placed in Suppression Chamber sprays.
Declares an Alert based on EAL 3.1.1 and EPMP-EPP-0102 review.
Directs the crew to monitor and report when Suppression Chamber pressure exceeds 10 psig.
When told that Suppression Chamber pressure exceeds 10 psig Directs the following:
o Drywell Unit Coolers tripped.
o Recirc. Pumps tripped Verifies within Drywell Spray Initiation Limit Curve Directs spraying the Drywell using RHR A and defeating the DW NRC 2008 Scenario 1
-1 9-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 9 Note to Evaluator: It is important that the evaluation to blowdown when above PSP be made only after Drywell sprays are initiated or it is determined that the Drywell cannot be sprayed. It is incorrect EOP implementation to continue to RPV Blowdown with having attempted to spray the Drywell.
EVENT 7 & 8 RO Actions S
Booth: Insert Trigger #9 for Rt MOVI 5A failure NRC 2008 Scenario 1 S
RO Spray interlocks per EOP-6, Att. 22 Determines Suppression Chamber pressure above the Pressure Suppression Pressure curve limit.
Directs spraying the Drywell using Service Water via RHR B using EOP-6 Att. 5.
CT-1.O Verifies that Containment pressure is above PSP with Drywell Sprays in service.
Directs RPV Blowdown per EOP-C2, based on being above PSP with Drywell Sprays in service.
CT-2.0 Directs placing RHR A in Suppression Pool Cooling.
PO-I 0.0 0
Reports DW pressure above 1.68 psig.
0 Recognizes and reports failure of LPCS and RHR A pumps to start.
0 Recognizes and reports failure of DIV I EDG.
Recognizes and reports trip of RHR B pump.
D Places RHR A in Suppression 0
I N STRUCTOR ACT1 ONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 7,8 & 9 BOP Actions EVENT 9 - RPV Blowdown Chamber sprays and does not establish Suppression Pool cooling.
Defeats the DW Spray interlocks per EOP-6, Att. 22 Recognizes and reports that RHS*MOV15A has lost power on overload and is not open.
Sprays the Drywell using Service Water via RHR B using EOP-6 Att. 5.
CT-1.O Places RHR A in Suppression Pool Cooling.
BOP PO-I 1.o Reports Suppression Chamber pressure above 10 psig.
0 Verifies DW unit coolers tripped.
0 Trips Recirc pumps.
Initiates ADS Division 1 using the pushbuttons on P601 CT-2.0 Verifies that 7 ADS valves open.
0 Verifies that RPV pressure is lowering NRC 2008 Scenario 1 March 2008
V.
POST SCENARIO CRITIQUE A. NA, NRC Exam VI. REFERENCE EVENTS AND COMMITMENTS A. Reference Events 1.O During performance of Surveillance (N2-OSP-ADS-R001), when the 8th SRV was opened Suppression Chamber pressure became great enough to open a pair of vacuum breakers. The vacuum breakers stayed open for almost 30 minutes until DW and SC pressure equalized.
B. Commitments
- 1. None VII. LESSONS LEARNED NRC 2008 Scenario 1 March 2008
EVALUATED SCENARIO CHECKLIST X
X
- 1.
Additional Information about these checks:
Realism/Credibility Event Sequencing For continuing training, can be found in NUREG 1021, ES 604 and Appendix D.
For initial training, can be found in NlJREG 1021, ES 301 and Appendix D.
- 3.
I X
I Simulator Modeling I
I x
I Evaluating Crew Competencies Quantitative Attributes 6
2 1
2 Total Mal f u nctions Malfunctions after EOP Entry Abnormal Events Major Transients EOPs Used EOP Contingency Procedures Used I
Simulator Run Time EOP Run Time Crew Critical Tasks (if applicable per Attachment 6.)
- 4.
Developmental Checks:
Does every event have either a Critical Task(s) or Performance Objective?
Is Criteria given for sequencing to subsequent events?
Is termination criteria clear and unambiguous?
Does termination criteria allow verification that all CT, PO standards are met?
N2-SOP113 - LOSS OR DEGRADED CCP SYSTEM A siandby CCP pump failed io atiio start, An RHS pump is operating, Attempt to manually start the pump.
Shift seal cooling to SWP per N2-OF-13, H.7.0.
EVENT DESCRIPTION NOTE: Trip of WCS pumps may NOT be irnrnediatoly required if the station is in Mode 4/5 IF THEN wcs must
- 1. Throttle WCS'MOV200 be removed until the filters are in hold.
\\tr"" service,
- 2. Trip WCS pump(s). J r
11 IF THEN 1 AI1 CCP pumps have tripped &Q none can be I
I I
re-started, SCRAM the Reactor per N2-SOP-101 C.
'Trip BOTH Recirc pumps m e n t e r N2-SOP-29.
'Trip WCS pumps if required.
\\that systems loads will NOT have adequate &ling, I
I r
IF THEN 1
until 1 main &Q 1 booster pump t
Perform Attachment 2 to restart pumps.
Detail A. Major System Loads WCS System Recirc Pump Cooling Drywell Cooling SFCHXs IAS Mini Loop HXs Equipment Drain Cooling RDS Pump Cooling Sample System Cooling t
Monitor system loads Secure loads as required.
(Detail A).
t Perfom any of the following as required to stabilize the CCP system:
Place standby mainlbooster pump in service per N2-OP-13, F.2.01F.4.0.
Place standby heat exchanger in service per N2-OP-13, F.7.0.
Place CCP-TIKlO8, RBCLC HEAT EXCHANGER TEMP CONTROLLER in MANUAL AND maintain CCP temperature 80 - 85°F.
Take local control of CCP-TV108 per N2-OP-13, H.3.0 Verify system operating per N2-Verify CCP-TIK108, RBCLC HEAT OP-13. F.1.0.
EXCHANGER TEMP CONTROLLER to AUTO.
Verify CCP-TWO8 local control restored to Auto Der N2-OP-13, H.3.0 NINE MILE POINT NUCLEAR STATION UNIT 2 I
SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-13
I N2-SOP STUCK OPEN SRV EVENT DESCRIPTION See Sectioii 1.O.
Identify which SRV is open. ___
affected SRV to the OFF position.
Did SRV close?
(Detail 1)
Exit this procedure 85% per N2-SOP-IOlD.
I f
IF I
THEN 1
Y2-SOP-iO1C while continuing.
temperature is approaching Using Detail 2. remove the fuses for the affected SRV in the following order until the SRV closes:
- 1. C Solenoid fuse
- 2. A Solenoid fuse
- 3. B Solenoid fuse Detail 1 Use one or more of following indications to verify SRV status:
. ERF Compu:er Points MSSZClll Reactor Power Change Generator Output Change Steam FlowiFeed Flow Mismatch Accoustic Monitor SPDS Computer
- MSSZClZE:
Did SRV close?
NZ-SOP-lO1C m e x i t this procedure.
Detail 2 1
SCRAM the Reactor per I N r n :
Average Suppression Pool temperature will contlnue to rise after SRV (c2) closure due to convective mixing of localized heated water
. With Suppression Pool average temperature 290°F and <11O"F AND RTP is > 1 % Suppression Pool average temperature must be verified to be 11O"F and <120"F, Suppression Pool average temperature must be verlfied to be 420'F once every 30 minutes (Tech Spec 3 6 2 1, Condition 0)
N2-OSP-ISC-M@002 must be performed within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after an SRV has cycled (Tech Spec 3 6 1 7 2)
NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE
N2-SOP FEEDWATER FAILURES f
EVENT DESCRIPTION
~~
~
Feedwater failure requires a power reduction.
Level 3 (159.3) is anticipated, Level 8 (202.3) is anticipated, A feed flow malfunctioning, The narrow ranoe A(B) instrument is malfunctioning, FWS-LVIO is NQI responding, s ! e m Row ins!rilmen! is L
I Reduce power per N2-SOP-101 D.
SCRAM the Reactor per N2-SOP-IOIC exit this procedure.
Change to single Element Control per N2-OP-3. F 8.0 AND r e t m FWLC to auto.
Change to narrow range B(A) instrument per N2-OP-3, F 8.0 AND return FWLC to auto.
Enter LVlO Failure Flowchart WHILE continuing this flowchart.
Immediate Actions S h a d o w e d See Section 1.O.
IF THEN I
FWLC IS NOS reSDOndlnQ correctlv, I Take manual control of FWLC.
THEN IF I
Yes Feedpump shutdown Perform Concurrently Reduce Power to approximately 65% per N2-SOP-1OID I
1 Shutdown affected pump. I Verify level stable between 178.3 @Q 187.3.
4 0 Venfy 2FWL-P2A(B,C) auto starts.
0 Close 2FWS-LVlOA(B.C).
U IF required, close 2FWS-MOV47A(B.C).
0 Locally place 2FWL-P2A(B,C) control switch in Start 1
being placed Remove Condensate Demineralizers from service i
Lowering RPV level high feedwater Row with 2FWSMOV21NB.
Determine cause for risino level.
valve indicates 0%.
Place 2FWS-LV55 in manual close.
+
IF required, close 2FWS-MOV47A( B,C).
Determine cause for lowering level. --
I CRS, exit this I E$ER NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-06
IMMEDIATE AND SUBSEQUENT ACTIONS N2-SOP SUDDEN REDUCTION IN CORE FLOW Immediate Actions Shadowed I - - - - - - - - - - -
I 1 ANY OF THE FOLLOWING:
I Any APRM peak-to-peak value I
I I
I I
I exceeds 10%.
I IM I
I noise from random to regular 1 seconds.
I IQB I
I A change in the character of the I WITH a period of about two r --
ANY LPRM peak-to-peak value exceeds three times the baseline I value established for that LPRM, If I available (ref. CRC book).
I I Periodic LPRM upscale OR I
I1B I
downscale alarms.
I in service?
f switch in RUN QE flow to left I
APKMiLPRM noise levels demonstrate a worsening trend I
I toward the above limits.
SCRAM the reactor per Recover per N2-SOP-101 C I
4 t
.f I
I Core flow power within the CRAM rods.
1 Insert the first 4 CRAM rods.
I NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE
~
~~
PROCEDURE NUMBER N2-SOP-29
N2-SOP UNPLANNED POWER CHANGES 11 Immediate Actions Shadowed c
IF Cause due to Control Rod Drift Cause due to Loss of Feedwater Heating, Cause due to Recirc FCV Failure, Cause due to Control Rod Drop, Cause due to Single Control Rod Scram, Cause is Unknown, b
(
EVENT DESCRIPTION 11 THEN Continue at IQ Perform Attachment 2.
Perform Attachment 3.
Perform Attachment 4.
Perform Attachment 5.
J Depress "HYDRAULIC PRESSURE UNIT SHUTDOWN" pushbutton at ZCEC'PNL602.
Yes Close "LOOP A(B)
.HYDR FLU!D OUTSIDE ISOL."
NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-08
N2-SOP CONTROL ROD DRIFT lden!ify -hick cw!ro! rod is driting 2.d i? what direction CR IN /OUT NOTE:
Specific r e c o m m e n d a t i o n s from the on call Rx Eng. m a y override directions for plant power reductions.
Using INSERT pushbutton, !ully insert drif!ed conto1 rod.
Bypass the RWM if necessary Recuce Rx power to No
+ approximately 85% per N2-SOP-IOID QR as recommended by Rx Eng.
b w e r should have l/
Insert the face adjacent control rod identified in the I
CRC book for the drifted control rod m a s recommended by Rx Eng.
Depress and hold INSERT pushbutton to maintain control rod fullv inserted.
i When control rod is
. HCU for the drifting control rod.
2RDSV103 2RDSV105 Release INSERT Reduce core flow to NZ-SOP-IOID as Rx Enn approximately 65 mlbmlhr per N2-SOP-1OlD E as recommended by Rx Eng.
Isolate stuck N2-OP-30. Section mechanically bound/
stuck?
I F.8.2.
I the drifted rod is inserted, THEN NORM-TEST-SRI toggle switches to opening the following valves:
!&j.@ directed by the SM, exit this procedure.
2RDSV105 Refer to TS 3.1.5, Control Rod Scram Accumulator Operability.
Refer to TS 3.1.3, Control Rod Operability.
Contact Maintenance for troubleshootlrepair plan as required.
SCRAM the drifted control rod by placing toggle switches to TEST, mas recommended by Rx Eng.
NORM-TEST-SRI NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEOllRE NUMBER N2-SOP-OB
N2-SOP-101 D = RAPID POWER REDUCTION execnting !his procedure, Core flow is <54 mlbmlhr.
EVENT DESCRIPTION Immediate Actions Shadowed See Section 1.O.
-c f
IF THEN MFLCPR is greater than 0.95, power is lowered to c 75%. begin to inserting the first four CRAM rods further Recirc flow reduction.
IF THEN Further power reductions are required WHILE Re-enter at this point Enter N2-SOP-29. Sudden Reduction in Core Flow, and perform concurrently 1
Lower Reactor power by using Recirc flow CRAM rods.
I Determine Reac?or Rod!ine &Q monitor core thermal limits.
1 No Verify clean steam reboiler auto transfer to AUX Steam.
Verify HVH steam supply auto transfer to Aux Steam.
Verify sufficient Cond Demins in service per N2-OP-5.
Place HDL pumps in recirc per N2-OP-8, G.I.0.
ME: If cram rods cannot be inserted due to equipment failures but power reduction below 75% is required, then attempt to maintain 112% (17 MWth) per minute power reduction, if possible, and immediately notify Rx Eng.
As required, continue with N2-OP-lOlC(1O1D.lOlA).
NOTE:
The following actions are typically performed for down power evolutions:
0 Update rodline notice at panel 2CECPNL603.
U Notify Central Regional Control (315-460-2421).
Notify Constellation dispatcher (410) 468-3750.
I NINE MILE POINT NUCLEAR STATION UNIT2 SPECIAL OPEMTING PROCEDURE P R 0 C E D U R E PAGE RWISION I NUMBER N7.SOP-101 D I NUMBER 03 I NUMBER 03
f EVENT DESCRIPTION N2-SOP-lOlC -
WHILE continuing, peiform the foilowing as time permits:
See Section 1.O.
I Continue with "Pressure Control*
IMMEDIATE AND
\\-GENERAL ACTIONS f
IF THEN Automatic Scram is anticipated time
- permits, Mode switch is NOT in REFUEL position, Reduce Recirc Flow to 55 mlbmihr per NZ-SOP-lO1D.
P!ace MODE Switch !o SHUTDOWN position.
r _ _ _ - - - - - - - - - - - -
I 0 All rods full in I 0 Rx power lowering (c1) I 0 Turbine trippediTSVs & TCVs shut I 0 Generator tripped and house loads I
I I
I 4
transferred I
I U SDV V&D valves closed 1 U RCS pumps downshift I U RPV pressure on TBVs OF: SRVs I 0 FWLC controlling level > 159.3" Verify automatic responses.
IF THEN All feedwater pumps have tripped.
Place "manual" and verify the valves are ?ill closed.
2FWS-LVlO and LV55 controllers to I Reset the scram as follows:
I 1. Notify radwaste to operate all pumps for 2DER-TKZA.
I I
I I
- 4
- 1 I
I I
I I 2. Place all four SDV high level bypass switches I I
I I 4. Using scram reset switches, reset the scram, I I
I i 5. Reseat rods if necessary by applying insert I
IF THEN I
to BYPASS.
I 4 3. IF intiated, reset ARI per N2-OP-36B, H.3.0.
The Reactor scram can be promptly reset (and remain reset),
Reset the scram.
Close 2RDS-V28 if directed by the SSSICRS.
0 verify all 8 pilot solenoid lights lit.
e Reactor scram CANNOT be reset.
I signal.
I
__I-Shift ManagerlEmergeiicy Director to review EPIP-EPP-02 for classification of an emergency.
I 6 Verify SDV vent and drain valves open I
_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ d Perform Concurrently L
f P
I
\\
f Continue with "Level Control" 1
i U Energize 2WCS-MOV107 (2NHSMCCOO8-2E).
I 0 If required, secure makeup to the Cooling Tower 0 At 2CEC-PNL842, shutdown HWC 7
IF
~~
WCS IS in one pump three filter lineup, Outside temperature is ~ 5 0
- degrees, THEN Throttle close ZWCSMOV200 (m if required, throttle open ZWCS-MOVllO) to obtain approximately 225 gpm WCS flow.
- 1. If required, Isolate the Reactor Building by placing 2HVR'AODlA (m 'AODl 6) to close verify the following:
Rsactor Building ventilation isolates GTSstarts
- 2. Perform N2-OP-52 actions for Reactor Building isolation (Sections H.l.O, H.5.0).
NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE I
PROCEDURE NUMBER N2-SOP-1O1C
N2-SOP-IOIC - LEVEL CONTROL Close & MSiVs AND open the following to maintain level ~ 2 5 5 "
U MSS'MOV207 U MSS'MOV111 U MSS'MOVI 12 12EHSMCC102-7A 240' NAB)
Stabilize and control level at 178 - 183" (or as directed by EOPs) with feedwater in auto (preferred) or manual.
Feed pump restart is required, Restart feed piimp per Detail 1 Level CANNOT be maintained <250",
Start feedwater pump as follows
- 1. Confirm suction pressure > 500 psi.
- 2. Verify aux oil pump running.
- 3. Place pump switch lo red flag.
- 4. WHENPFWS-FVPNBIC - 15% open, confirm pump starl.
- 5. Confirm flow - 8000 gpm.
- 6. Inject with 2FWS-LV55NB (open ZFWS-V103NB if required)
OR verify open 2FWSMOV47AIBIC &Q inject with FWS-LVIONBIC as required.
- 7. IF required, reset setpoint setdown per N2-OP-3, H.1.0.
- 8. For automatic control, refer lo N2-OP-3, H.9.12
- 9. Verify aux oil pump stops.
H.9.13.
~~~~~~~~~~~~
NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-lO1C I
Level control IS lost, I Ke-enter al 9 I
I r
U RClC As required, periorm the foilowing io establish ordered level band:
0 Ciose 2FWS-LVlONBIC.
U IF 2 feedpumps are running, trip one feedpump ("C" preferred).
U As required, close the following valves:
- 2FWS-MOV47NBIC
- 2ZIP-V10/11 0 Establish WCS reject per N2-OP-37.
0 Reset Reactor scram per General Actions flowchart I
continue.
IF required, place FWLC in single element.
1
- 1. Place FWLC in manual.
As required, perform the following:
U Reset setpoint setdown w r Detail 2.
- 2. Place 1 ElemnV3 Element control switch in 1 Element.
- 3. If required, restore FWLC to auto.
U Reset PAM recorders.
0 Continue with N2-OP-lOIC, Section G.3.0.
I I
I I
I I
I I
I I
I I
I I
I I
I I
I I
I I
I I
1 I
- - - - FWS Pump Restart Detail 1 I I
I I
I I
I Is at least Condensate and running?
is unavailable.
1 condensate pump Feedwater injection YeS Verify the following:
U Out of service condensate, booster and feedpumps in PTL.
U 5 2 condensate pumps running.
U L 2 booster pumps running.
U 2FWR-FV2s closed.
0 The following controllers in manual with 0%
output:
- 2FWS-HlC1010~
- 2FWS-HICIGOO 3 IF required, resel Level 8 pushbuttons I Detail 2 I
I Reset Setpoint Setdown I
I I 1. Verify Rx level stable above I
I I
Level 3 [159.3").
I 2. Null FWS Master Controller by I I
rotating the thumbwheel until I I
the red process pointer is in I
I the green band.
I
' 3. Depress the SETPOINT I
I SETDOWN RESET I
I pushbutton AND confirm I
I amber light is extinguished.
I i 4. Verify proper automatic control I in the desired band.
I L _ _ _ _ _ _ _ _ _ _ J I
I I
I I
I I
I I
I I
I I
I I
I
N2-SOP-IOIC - PRESSURE CONTROL Pressure controlled within prescribed band.
Cooldown rate <lo0 degrees per hour (RPV pressure >420 psig for first hour).
f IF THEN
~
Pressure control is lost MSlVs are closed AND the Main WHEN desired, re-open the MSIVs per I
1 Main Condenser to control pressure. I Perform Concurrently l------
Control pressure (cooldown rate) within !he ordered band using any of the following:
Main Condenser using TBVs o Use EHC pressure set OR bypass valve opening jack Initiate condenser neck spray by opening 2CNM-MOV126 o
SRVs RClC Steam Condensing As required to control cooldown rate, perform.
the following:
Close 2MSS-ACV87NBICID and AOVBWB.
E time permits, swap gland seal to main steam per N2-CP-25, Section F.2.0 OR H.3.0.
Close 2ASS-MOV152.
rn Start ZARC-PlA(B) as follows:
- 1. Confirm no fuel damage.
- 2. Close 2ARC-AOV104.
- 3. Place in AUTO 2ARC-ACV105.
- 4. Open 2SWP-HV98A(B).
- 5. Starl ZARC-PlA(B).
- 6. Verify proper operation per N2-OP-9, Section F.1:
Close 2ASS-AOV148.
I Fast close outboard MSIVs. (C3,4,5,6.9)
Continue with pressure control actions per NZ-OP-lOIC, G.3.0.
NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-IOlC
Appendix D Scenario Outline Form ES-D-1 Facility: Nine Mile Point 2 Examiners:
Operators:
Initial Conditions: Simulator IC-I 7 or equivalent
- 1. Reactor Power 100%
Turnover:
- 1. All equipment operable.
- 2. Perform RHR Pump Operability Test IAW N2-OSP-RHS-QOO6 Scenario No.: NRC-02 Op-Test No.: March 2008 N2-SOP-19, Loss of Instrument Air Power decrease to 85% due to EHC oscillation problem N2-SOP-23, EHC Press Reg Failure
] C(SR0)
(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NRC Scenario 2 March 2008
Facility: Nine Mile Point 2 Scenario TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO; SEE SECTION D.5.d)
- 1. Total malfunctions (5-8)
Events 2,3,4,5,6,8,9
- 2. Malfunctions after EOP entry (1-2)
Events 8,9
- 3. Abnormal events (2-4)
Event 2 -SOP-19, Event 3SOP-101 D, SOP-23 Event 5 - SOP-6, Event 6 SOP-8
- 4. Major transients (1-2)
Event 7
- 5. EOPs enteredlrequiring substantive actions (1-2)
- 6. EOP contingencies requiring substantive actions (0-2)
Event 7,8,9 EOP-C5,
- 7. Critical tasks (2-3)
CRITICAL TASK DESCRIPTIONS:
CT-1.0 Place ADS inhibit switches to ON to prevent CT-2.0 restore & maintain RPV level above the injection under ATWS conditions MSCWL precluding the need to perform a RPV Blowdown.
CT-3.0 Inject SLC before exceeding HCTL CT-4.0 RO inserts all control rods 0.1 NRC-02 ACTUAL ATTRIBUTES 7
2 4
1 2
1 4
Op-Test No.: March 2008 NRC Scenario 2 March 2008
NMP SIMULATOR SCENARIO NRC Scenario 2 REV. 00 No. of Pages: I 9 RHS WATER LEG PUMP TRIP/IA COMPRESSOR TRIP/EHC PRESSURE REGULATOR OSCILLATIONS/HPCS SPURIOUS START/FEEDWATER MASTER CTRLR FAILURE/RECIRC FCV VALVE OPENS/ATWS/LOSS OF HIGH PRESSURE FEED PREPARER S.Dennis DATE VALIDATED DATE GEN SUPERVISOR OPS TRAINING R. Brown DATE 1/23/08 0 P E RAT1 0 N S MANAGER NA Exam Security DATE CON F I G U RAT1 ON CONTROL NA Exam Security DATE SCENARIO
SUMMARY
Length: 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Initial Power Level: 100%
The scenario begins at 100% power. The RO will perform the surveillance test for the C RHR Pump, N2-OSP-RHS Q006. While the pump is running, the breaker will trip for the RHS B/C Water Leg Pump RHS*P2 requiring a TS entry by the SRO (TS 3.5.1.C - 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />). Once TS are addressed, the in service Instrument Air Compressor will trip requiring operator action to manually start the C standby compressor. The B compressor will not start.
Oscillations of the in service EHC pressure regulator will occur and require actions to swap to the alternate regulator and lower reactor pressure. Additionally, the RO will be required to lower reactor power to 85% IAW the SOP-23.
Once conditions stabilize, a HPCS spurious start will occur requiring operator action to terminate the initiation. The SRO will address TS for HPCS inoperability and 2 other ECCS pumps inoperable (3.0.3). After addressing TS, the Feedwater Master Controller will then fail as-is. The crew will enter SOP-6 and control feedwater in manual.
Additionally, a failure of the Recirculation FCV will cause the FCV to open. Operator action will be required to control the FCV and reactor level. Cram rods may be inserted or Recirc flow lowered to lower reactor power to pre-transient levels.
The backup EHC pressure regulator will fail and result in a rapid RPV pressure rise.
The reactor will automatically scrams, however, all control rods will not fully insert and NRC 2008 Scenario 2 March 2008
A and B reactor feed pumps will trip. EOPs RPV, EOP-Failure-To-Scram will be entered. The RO must inhibit ADS to prevent injection during the ATWS (CT).
The RClC turbine can be manually controlled after a controller malfunction. SLC pumps will fail to auto-start and must be manually started prior to exceeding the HCTL (CT). RPV level must be restored with C FW pump, RClC (or Condensate Booster Pumps with RPV pressure lowered) precluding the need to perform a RPV Blowdown (CT). The RO will implement actions to insert control rods until all rods are inserted (CT).
Major Procedures Exercised:
EOP-RPV, PC, C2. SOP-8, 34 EAL Classification:
SAE 2.2.2 - ReactodReactivity Control-ATWS Termination Criteria:
rod insertion is in progress.
RPV level is being controlled in the required band and control NRC 2008 Scenario 2 March 2008
I. SIMULATOR SET UP A. IC Number: IC-I 7 or equivalent. (Operation Above 100% Rod Line)
B. Presets/Function Key Assignments
- 1. Malfunctions:
- a. RH20 RHS*P2TRlP TRG 10
IA02B 21AS-C3B THERMAL OVERLOAD TRIP PRESET
- d.
IA04A IAS COMPRESSOR LAG AUTO-START FAILURE PRESET
- e. IA04B IAS COMPRESSOR B/U AUTO-START FAILURE PRESET
- f.
TC03A EHC SYS PRESS REG FAILURE-OSCILLATION TRG 2
- g.
CSOl B HPCS INADVERTENT INITIATION TRG 4
- i.
TC02B EHC SYS PRESS REG FAILURE-LOW (B)
TRG 6
- j.
TC02A EHC SYS PRESS REG FAILURE-LOW (A)
TRG 6
- k.
TRG 7 I.
TRG 8
- m. RC07 RClC FLOW TRANSMITTER FAILURE-HI TRG 9
- n. RP02 RPS-FAILURE TO SCRAM-AUTOMATIC TRG 22
TRG 23
TRG 23 FW03A FW PUMP TRIP (PIA) - DELAY 45 SECS FW03B FW PUMP TRIP (PIB) - DELAY 45 SECS
- q.
RH08 GRP 5 ISOLATION FAILURE-RHS*MOV122/113 TRG 25
- r.
an603109 RPS A DIS VOL HI LVL TRIP TRG 26
- s.
an603409 RPS B DIS VOL HI LVL TRIP TRG 26
- t.
RP08A RRCS 98 SEC TIMER FAILURE (DIV 1)
PRESET
- u. RPO8B RRCS 98 SEC TIMER FAILURE (DIV II)
PRESET RD17A PARTIAL INSERTION OF RODS UDER SCRAM(L1) PRESET RD17B PARTIAL INSERTION OF RODS UDER SCRAM(L2) PRESET RD17C PARTIAL INSERTION OF RODS UDER SCRAM(L3) PRESET RD17E PARTIAL INSERTION OF RODS UDER SCRAM(L5) PRESET RD17F PARTIAL INSERTION OF RODS UDER SCRAM(L6) PRESET RD17G PARTIAL INSERTION OF RODS UDER SCRAM(L7) PRESET RD17H PARTIAL INSERTION OF RODS UDER SCRAM(L8) PRESET RD171 PARTIAL INSERTION OF RODS UDER SCRAM(L9) PRESET NRC 2008 Scenario 2 March 2008
RD17J PARTIAL INSERTION OF RODS UDER SCRAM(L1O) PRESET RD17K PARTIAL INSERTION OF RODS UDER SCRAM(L11) PRESET RD17L PARTIAL INSERTION OF RODS UDER SCRAM(L12) PRESET RD17M PARTIAL INSERTION OF RODS UDER SCRAM(L13) PRESET RD17N PARTIAL INSERTION OF RODS UDER SCRAM(L14) PRESET Remotes:
- a.
RH52 RHRB FILL AND VENT TRG 24
- b. TC02 PRESSURE REG BIAS A 0-+10 B (PSIG)
TRG 3
- c.
RRIOA FCV A DRIFT (DELAY 3 SECONDS)
TRG 5
- d.
RR12A FCV A DRIFT POSITION (0-100%)
TRG5
- e.
DEFEAT RCIC/MT TRIP INTLK (EOP-6 ATT 2)
TRG 20
- f.
TRG 21
- g.
TRG 21
- h.
TRG 21
- i.
TRG 21 MSOGA DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148A)
MSOGB DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148B)
MSOGC DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148C)
MSOGD DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148D)
- 3. Overrides:
- 4. Annunciators:
- a. None C. Equipment Out of Service
- 1. None D. Support Documentation E. Miscellaneous NRC 2008 Scenario 2 March 2008
II.
SHIFT TURNOVER INFORMATION TITLE SRO PART I:
shift.
To be performed by the oncoming Operator before assuming the NAME TITLE 0
Control Panel Walkdown (all panels) (SM, CRS, STA, CRO, CRE) 1 PART II:
To be reviewed by the oncoming Operator before assuming the shift.
ATC RO BOPRO Shift Supervisor Log (SM, CRS, STA) 0 CRO Log (CRO) 0 LCO Status (SM, CRS, STA)
Lit Control Room Annunciators 0
Computer Alarm Summary (CRO) 0 Shift Turnover Checklist (ALL)
Evolution s/Gene ral I n fo rmation/Eq u i pment Status :
0 Reactor Power = 100%
0 Loadline = >loo%
None PART 111:
RemarkdPlanned Evolutions:
Perform N2-OSP-RHS-QOOOG RHR Svstem Loop C Pump and Valve Operabilitv Test and Svstem Integrity Test PART IV:
To be reviewed/accomplished shortly after assuming the shift:
0 Review new Clearances (SM) 0 Test Control Annunciators (CRE) 0 Shift Crew Composition (SM/CRS)
NRC 2008 Scenario 2 March 2008
Scenario ID#
INSTRUCTOR COMMENTS (Strengths, Areas for Improvement, Open Items etc.)
What Happened?
What we did?
Why? (Goals)
Other 0 ptions?
NRC 2008 Scenario 2 March 2008
Ill.
PERFORMANCE OBJECTIVES A. Critical Tasks:
CT-1.O CT-2.0 CT-3.0 Inhibit ADS to prevent injection during the ATWS.
Manually start SLC prior to exceeding the HCTL.
RPV level must be restored to preclude the need to perform a RPV Blowdown Following the ATWS implement actions to insert control rods CT-4.0
- 6. Performance Objectives:
PO-I.o PO-2.0 PO-3.0 PO-4.0 PO-5.0 PO-6.0 PO-7.0 PO-8.0 Given the plant or plant system in a condition requiring Technical Specification action, identify the deviation and any required actionshotifications.
Given RHS B/C Water Leg Pump breaker tripping, the crew will secure from the surveillance, declare the pump inoperable and restore the valve lineup.
Given the plant operating at power with an instrument air compressor failure, the operating crew will restore IA header pressure to normal prior to 60 psig IA header pressure.
Given the plant operating with a malfunction of the EHC pressure regulator the crew will take action in accordance with N2-SOP-23 to reduce power below 85% and place the l'6" pressure regulator in service.
Given the plant with a spurious HPCS initiation, the crew will take actions to terminate the injection.
Given an operating reactor with a Recirc flow control valve failed open and a FWLC failure the crew will tale the appropriate actions to restore and maintain RPV water level.
Given the plant operating at power with RPV pressure lowering due to an EHC failure, the crew will verify the MSlVs close and the Reactor SCRAMS in accordance with SOP-I 01 C.
Given a loss of Normal Feedwater the crew will stabilize RPV level using RClC in manual.
NRC 2008 Scenario 2 March 2008
PO-9.0 Given entry conditions to EOPs RPV, PC and C-5, the crew will execute the following actions to mitigate the event:
Preventing HPCS Injection Inhibiting ADS initiation.
Terminating and preventing RPV injection in accordance with EOP Basis and as directed by EOP-CS.
Verifying SLS injection prior to Suppression Pool temperature 1.
11 0°F.
Operating Suppression Pool Cooling to minimize suppression pool heatup.
Insert Control Rods per EOP-6, Att. 14.
NRC 2008 Scenario 2 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 1 RHR Pump Operability Test with RHS BIC Water Leg Pump breaker trip EVENT 1 -SRO Actions EVENT 1 -BOP Actions Role Play: When directed to open test connections, report that the test connections are open.
NRC 2008 Scenario 2
-9.
Crew Crew conducts a pre-brief, walks down the panels, and tests annunciators.
SRO PO-I.o Perform pre-job brief with RO assigned to performance of su rvei Ha nce Authorizes/directs performance of surveillance N2-OSP-RHS-W@006 for RHS C loop BOP Reviews surveillance, and com mences.
Makes plant announcement starting RHS*PI C Positions RHS*PI C control switch to start.
Notes and reports to CRS, annunciator 601 540 did not alarm Directs test connection for suction opened.
Throttle open RHS*FV38C to 7450 gpm March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS Sim Booth OPERATOR After pump flow is established at 7450 gpm, activate malfunction by depressing FIO key:
RHS*P2 TRIP TRG 10 Annunciator 601648: RHR B SYS VALVES/WATER LEG PMP MOT OVERLOAD EVENT 1 -BOP Actions SIM BOOTH NOTE: After 5 minutes, Call Control room and report that the BKR for the RHS Water Leg Pump was bumped accidentally by Electrical Maintenance.
Electrical Maintenance has seen no breaker problems and advises retarting the pump.
EVENT 1 - SRO Actions EVENT 2 Instrument Air CompreSsor A Trips, B will not start, C must be placed in service manually.
0 Observe RHS*MOV4C closed 0
Directs test connection for discharge opened.
PO-2.0 BOP Diagnoses RHS B/C Water Leg Reference Pump breaker trip 0
Notifies SRO SRO 0
Determines the Loss of RHS*P2, RHS B/C WTR LEG PMP, will render RHS B AND C inoperable.
0 Refers to Technical Specification 3.5.1.
NRC 2008 Scenario 2
-1 0-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS SIM Booth: Insert Trigger #2 when cued EVENT 2 -BOP Actions When single loop conditions are stabilized and when directed by lead instructor insert malfunction :
IA02A Inst. Air Compressor A Trip
- Instrument Air header pressure lowers
- AN 851228 INSTR AIR CPSR 3A/3B/3C AUTO TRIP/FAIL TO START EVENT 3 - Power decrease to 85% due to EHC oscillation problem Sim Booth: Activate trigger #2 when directed RPV Pressure starts to oscillate Annunciator for 6 Regulator in Control Alarms Fuel failure starts ramping EVENT 3 -SRO Actions 3op PO-3.0 D
Reports Annunciator B
Enters SOP-I9 B
Reports Instrument air header pressure lowering B
Recognizes Lag IAS Compressor B fails to start B
Manually starts IAS Compressor C.
SRO Acknowledges reports Directs SOP 19 entered Directs manual starting of standby IAS compressors Crew PO-4.0 0
Reports alarms 0
Reports pressure / power oscillations SRO Direct entry into SOP-23 0
Direct power reduced below 85%
IAW SOP-I01 D NRC 2008 Scenario 2
-1 1-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 3 -RO Actions EVENT 3 -BOP Actions When requested to adjust EHC Controls to place EHC B pressure regulator in activate Trigger #3, this dials remote function TC02 to 10 PSlG to place the B EHC pressure regulator in control.
EVENTS 4 HPCS spurious start Sim Booth: Insert CSOl B, HPCS Inadvertent Initiation, Trigger #4 when cued HPCS auto starts Div 111 D/G starts.
HPCS injects into the vessel.
Reactor level increases as HPCS injects.
0 Verify thermal limits are acceptable per OP-23 section for operation with 1 pressure regulator out of service 0
Enter SOP-23 0
Perform power reduction below 85%
BOP 0
Direct personnel to relay room to place B EHC regulator in control per SOP-23 NRC 2008 Scenario 2
-1 2-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE 0 PE RATOR ACT1 ONS EVENTS 4 - SRO Actions EVENTS 4 SRO Actions (Cont.)
EVENTS 4 RO Actions PO-5.0 RO B
B B
D D
8 8
8 8
a Determines HPCS initiation not required.
May direct HPCS pump be placed in pull-to-lock if still running.
Directs SOP-06 entry.
Review Tech Spec 3.5.1 required actions 6.1 and B.2, declares HPCS INOP and enters 14 day LCO.
Review Tech Spec 3.3.5.1, required actions A.l and 6.3.1.
Review Tech Spec 3.6.1.3 for HPCS injection valve.
Contacts Work Week Manager.
Identifies need for notifications per 10CFR50.72 (b) (3) (v) and 10CFR50.73 (a) (2) (v).
May direct HPCS injection valve to be closed.
Conducts transient brief.
As time permits, verifies HPCS injection not required.
If directed, places HPCS in pull-to-lock.
If directed, closes HPCS injection valve.
Dispatches operator to verify proper operation of Div Ill D/G.
NRC 2008 Scenario 2
-1 3-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS Role Play: If called to check the Div Ill Switchgear or HPCS pump, report overcurrent flags on breaker and HPCS pump appears normal.
Role Play: IF called for a report on HPCS report you are still investigating EVENTS 5 & 6 - Feedwater master controller fails as-is requiring manual control.,
Recirculation FCV failure causes FCV to open.
Sim Booth: Insert Trigger #5 when cued EVENTS 5 & 6 -SRO Actions EVENTS 5 & 6 -RO & BOP Actions NRC 2008 Scenario 2
-1 f
CREW PO-6.0 IdentifiedReports power rise.
Responds to Annunciator for RX Water Level Hi/Lo.
SRO Directs entry to SOP-6, Feedwater Failures Directs Manual Control of Feedwater Directs entry to SOP -8, Unplanned power changes Directs lowering power by insertion of Cram Rods or Lowering Recirc on Loop A Enters SOP 6 & 8 as directed Lowers power with Cram Rods or using B Recirc FCV Reports Recirc flow mismatch Monitors FW system response and March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 7 - EHC Regulator failure cause Reactor High Pressure, ATWS, Loss of Feedwater Sim Booth: Initiate Triggers 6,7,8,9,22,23,25,26 when cued RPV Press rises rapidly.
0 Rx may Scram on High Pressure or Neutron Flux.
0 RPV level lowers.
0 All control rods fail to fully insert.
0 A loss of Feedwater occurs EVENT 7 SRO Actions takes manual control as required to maintain normal level band D
Reviews power to flow map.
Crew PO-7.0, PO-8.0 & PO-9.0 0
Recognize and report EHC failure, loss of feedwater, Reactor SCRAM and failure of SCRAM.
SRO 0
Directs mode switch placed in shutdown.
0 Acknowledges scram report.
Enters EOP-RPV Control.
Exits RPV Control and enters EOP-C5 Failure to Scram.
NRC 2008 Scenario 2
-1 5-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 7 RO Actions Directs ADS logic inhibit to on and verification that HPCS is in pull-to-lock.
Directs RRCS initiated.
Directs a RPV water level band.
Directs a RPV pressure band with a target of 500 - 600 psig to establish injection with Booster pumps.
Directs a loop of RHR be placed in Suppression Pool Cooling.
Directs control rods inserted using EOP-6, Attachment 14.
Directs RO to prevent MSlV closure per EOP-6, Attachment I O.
Acknowledges trip of RClC turbine.
May direct LPCS and LPCl injection prevented. (Not preferred source of injection.)
Enter EOP-PC, executes all legs simultaneously.
May direct drywell cooling restored in accordance with EOP-6, 4.
Place reactor mode switch in shutdown.
Provides scram report.
NRC 2008 Scenario 2
INSTRUCTOR ACTIONS/
PLANT RESPONSE 0 PERATOR ACT1 ON S SIM Booth: At the examiner cue, once scram is reset, clear all RD17 malfunctions and SDV Hi LVL annunciator malfunctions (an603109, an603409 RPS A,B DIS VOL HI LVL TRIP) on Trigger 26. This will allow rod insertion when an additional scram is initiated.
EVENT 7 BOP Actions Sim Booth: If requested by control room activate TRG 21 for the following MSlV Inserts Control Rods in accordance with EOP-6 4 CT-4.0 Restores Drywell Cooling (EOP-6 Att 24):
Lowers RPV pressure using SRVs and establishes injection with condensate booster pumps.
Using condensate system, restore and maintain RPV level above the MSCWL.
CT-3.0 BOP Takes appropriate action to maintain RPV water level within the directed band.
B Verifies HPCS in pull to lock.
B Takes appropriate action using SRVs or bypass valves to maintain RPV pressure within the directed band.
Places ADS inhibit switches to ON.
B CT-1.O Installs jumpers to defeat MSlV closure isolation per EOP-6, NRC 2008 Scenario 2
-1 7-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS Defeats:
MSOGA DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148A)
MSOGB DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148B)
MSOGC DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148C)
MSOGD DEFEAT LVL 1 ISOL OF MSIVS (JMPR K148D)
EVENT 8 RClC Controller Failure EVENT 8 BOP Actions EVENT 9 - SLC FAILURE TO AUTO START Termination Criteria:
RPV water level being controlled in directed band and control rod insertion in progress.
Attachment I O.
D Places RHR A(B) in suppression pool cooling.
D Notifies the SM to declare RHR A(B) LPCl mode inoperable.
3op D
Identify and report to CRS, RClC failure in automatic.
Take manual control of RClC speed controller and raise turbine speed to inject with RCIC, if directed.
B BOP B
Identifies Failure of SLC to auto start on initiation signal.
B Manually places SLC in service prior to exceeding the HCTL CT -2.0 NRC 2008 Scenario 2
-1 8-March 2008
V.
POST SCENARIO CRITIQUE A. NA, NRC Exam VI.
REFERENCE EVENTS AND COMMITMENTS A. Reference Events None B. Commitments
- 1. None VII. LESSONS LEARNED NRC 2008 Scenario 2
-1 9-March 2008
1 X
X EVALUATED SCENARIO CHECKLIST Event Sequencing Simulator Modeling Additional Information about these checks:
6 2
2 1
2 2
For continuing training, can be found in NUREG 1021, ES 604 and Appendix D.
Total Malfunctions Malfunctions after EOP Entry Abnormal Events Major Transients EOPsUsed EOP Contingency Procedures Used Simulator Run Time For initial training, can be found in NUREG 1021, ES 301 and Appendix D.
4
- 2.
Qualitative Attributes EOP Run Time Crew Critical Tasks (if applicable per Attachment 6.)
I X
I ReaIism/CredibiIity I
I X
1 Evaluating Crew Competencies
- 3.
Quantitative Attributes
~~~
~~~
~
- 4.
Developmental Checks:
Does every event have either a Critical Task(s) or Performance Objective?
Is Criteria given for sequencing to subsequent events?
Is termination criteria clear and unambiguous?
Does termination criteria allow verification that all CT, PO standards are met?
N2-SOP-I9 - LOSS OF INSTRUMENT AIR EVENT DESCRIPTION 1
See Sectim 1.O.
I lowers to < 85 psig, an Operator to monitor 2RDS-PI133 &
SCRAM the Reactor per N2-SOP-101C &PQ 2RDS-PI133 fRB el 261') scram air header I pressure, lowers to < 60 psig.
ZIAS-PI101 (P851) Instrument air Dressure.
SCRAM the Reactor Der NZ-SOP-lO1C ewers to < 70 psig, IF Annunciator 851218 (Inst Air Rcvr Tk3 Press Low) alarms, Annunciator 603306 (CRD Scram Air Hdr Press Low) alarms, Air compressor is tripped AND isolation 01 compressorlreceiver is required THEN Dispatch an Operator t monitor 21AS-PI194 (RB el. 261').
Perform Attach. 3.
Close 21AS-V102(V20:
V302). 21AS-TKlA(TKIB, TKlC) outlet isolation 1
= Ncl 0 trippedldegraded?
Determine cause of I lowerina air pressure.
I Yes N2-OP-19, Section H.3.0.
lowering air pressure.
I are withdrawn Scram required if control rod(s)
Perform Attach. 2.
I If required, Start i VerQ auto started Instrument air ComDressors:
Manual start:
1 Select 21AS-C3A(C3B,C3C) as LEAD on the Instrument Air Compressor Selector Swltch for the compressor to be started 2 Place 21ASC3A(C3B.C3C) control swltch to Auto start; NORMAL-AFTER-START 100 psig. Lag air compressor Correct cause of compressor failure.
1 Perform Attach. 1 compressor local fault(s) restored to air NINE MILE P O l M NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE BcIL, enter N2-OP-19, PROCEDURE REVISION
N2-SOP EHC PRESS REGULATOR FAILURE EVENT DESCRIPTION See Section 1.O.
than 500 psig due to the malfunction, regulators shifting control, Lower power to approx. 85% per N2-SOP-1OID.
Adjust Pressure Regulator Bias to place the backup pressure regulator in control per Detail A.
lNo No Verify Backup Pressure Regulator in control.
/\\
L Verify Backup Pressure Regulator in control.
Verify Reactor pressure 5 1020 psig.
Verify throttle pressure NOTES: The following guidance should be reviewed is out of service, refer to N2-OP-23. Section H.5.0.
after the plant has been stabilized:
N2-OP-1O1D Precaution D.10.2 for Equipment Out of Service Analysis Tech Spec Section 3.2.2, MCPR and Core Opera!ing Limits Report Tech Spec 3.2.3, LHGR and Core Operating Limits Report pressure is stable or as directed, exit this procedure.
Detail A I
I r - - - - - - - - - - - - - - - - - - - - - - -
I 1. Dispatch an operator with key (tag# 16) to panel P843 in Relay Room.
I 2. At P843, Bay A, dissngage potentiometer locking mechanism AND I
slowly rotate the PRESSLlRE SETPOINT BIAS potentiometer to I
achieve the desired setting:
I 4.46 to place the B Regulator in control.
i 2.80 to place the A Regulator in control.
I 3. Engage potentiometer locking mechanism.
I 4. At P843 P851, check " A IN CONTROL QB "B' IN CONTROL.
i 5. Check annunciator 851 148 &N.D comp pt TMBBCOS alarm (B Reg in I
control) QB clear (A Reg in control).
I I
I I
I I
I I
I I
I... " '.
I 6. Use the INCREASE Q& DECREASE pushbuttons at PRESSURE I
I SETPOINT SELECTOR at P851 to establish 4020 psig Reactor Steam 1 1
Dome pressure. Do exceed 988 psig Turbine Throttle pressure.
I L - - - - - - - - - - - - - - - - - - - - - - -
NOTES:
A setting of approx. 3.63 on the PRESSURE SETPOINT BIAS potentiometer is the control crossover point between Adjustment of bias settings greater than 4 46 or less than 2.80 may be required depending on the severity of NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE REVISION PROCEDURE
N2-SOP-I 01 D = RAPID POWER REDUCTION r
IF MFLCPR is greater than 0.95, EVENT DESCRIPTION Immediate Actions Shadowed See Sec:ion 1.O.
1 THEN BFFORF power is lowered to < 75%, begin inserting the first four CRAM rods eBlQB to further Recirc flow reduction.
IF THEN Further power reductions are required WHILE executing !his procedure.
Core flow is c54 mlbmlhr.
1 Re-enter at this p i n t Enter N2-SOP-29, Sudden Reduction in Core Flow, and perform concurrently I
Lower Reactor power by using Eecirc flow CRAM rods.
I Determine Reactor Rcdline Bw1 mon!tcr core thermal limits.
1 4 m: If cram rods cannot be inserted due to equipment failures but power reduction below 75% is required, then attempt to maintain 1/2% (17 MWth) per minute power reduction, if possible, and immediately notify Rx Eng.
Verify clean steam reboiler auto iransfer to Aux Steam.
Verify HVH steam supply adto transfer to Aux Steam.
Verify sufficient Cond Demins in service per N2-OP-5.
Place HCL pumps ir, recirc per N2-OP-8, G.l.O.
As required, continue with N2-OP-101 C( 101 D. 101 A).
NOTE:
The following actions are typically performed for down power evolutions:
U Update rodline notice at panel 2CEVPNL603.
0 Notify Central Regional Control (315-460-2421).
0 Notify Constellation dispatcher (410) 468-3750.
NINE MILE POINT NUCLEAR STATION UNIT 2 I
SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-lOID
~~
~
~~~~
~~
N2-SOP FEEDWATER FAILURES 1
EVENT DESCRIPTION See Section 1 0 Immediate Actions Shadowed IF THEN FWLC IS NX responding correctly, Take manual control of FWLC
+
f IF THEN Feedwater failure requires a power reduction, Level 3 (159.3") is anticipated, Level 8 (202.3") is anticipated, A feed flow OR steam flow ihstrmen! is malfunctioning, The narrow range A(B) instrument is malfunctioning, FWS-LV10 is responding, Enter LVlO Failure Flowchart WHILE Reduce power per N2-SOp-101 D.
SCRAM the Reactor per NZ-SOP-IO1 C exit this procedure.
Change to single Element Control per N2-OP-3, F.8.0 AND re!urn FWLC to auto.
Change to narrow range B(A) instrument per N2-OP-3, F.8.0 AND return FWLC to auto.
continuing this flowchart.
Yes FeedpumFi shutdown f
Shutdown affected pump
+
4 Venfy level stable between 1 7 a r ~ ~ ~ i 8 7 3 "
U Venfy PFWL-PLA(B C) auto starts U Close 2FWS-LVIOA(B.C) 0 IF required, close 2FWS-MOV47A(B,C) 0 Locally place 2FWL-PZA(B.C) control switch in Start 1
Open 2FWS-V25A(B,C).
L Demineralizers from service IF required, throttle feedwa!er flow with i ZFWS'MOV21 NB.
Fast close LVlO until valve indicates 0%.
Place ZFWS-LV55 in manual &Q close.
Determine cause for IF required, close lowering level.
2FWS-MOV47A(B.C).
As directed by SMI CRS. exit this prowdure.
I :EBER NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-06
N2-SOP FEEDWATER FAILURES IF required, Make 2FWS-LVlO FAILURE MOV47A(B,C) throttleable per Attachrnent 2.
Throttle 2FWSMOV21A w/B B B l o w e r reactor power to stabilize level per N2-SOP-1O1D IF required, take manual handwheel control of LVlOs per Detail A feedpump Perform prestarts on another Swap feed pumps.
2NHSMCC003-7C 2NHS-MCC003-21 B 2NHS-MCC003-14A '..
ZFWS-PNLlOA(B.C) 1.
CB m
I IF THEN Take manual handwheel control per Detail A.
02 Lower power per N2-SOP-1O1D NQ remove the pump from service.
The locked up valve is drifting AND pump limits are challenged,
. G a c h. 1. Step 1.1.4.a
!I Attach. 1. Step 1.1.3 1
i" Is the control power fuse blown?
Replace fuse AND restore per Attach. 1.
Step 1.1.4.b.
No r
Attach. 1, Step 1.3.
1 E
a 5
pian to remove affected pump from service.
Detail A 1. Establish communications between I
I PNL603~ZFWS-PNLlOA(B.C)
I I
Open the applicable breaker($
I Lvlos are reverse I
Comm jack 9(5,4).
I I
2NHS-MCC003-7C (LVIOA)
I... ' ' acting, cw to CCW to close FMiER NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE i
2NHS-MCC003-21B (LVlOB)
' c I
I 2NHS-MCC003-14A (LVIOC)
I I
Open dose 2FWS-LVIOA (B,C)
I I
using the local handwheel.
I PROCEDURE NUMBER N2-SOP-06 Take local electric control per Attach. 1 Step 2.0.
known and corrected, return to automatic control per Attach. 1,
N2-SOP UNPLANNED POWER CHANGES No Immediate Actions Shadowed Reduce Reactor power to approximately 85% per N2-SOP-101D.
EVENT DESCRIPTION 11 bo scrammed OR drifted, N2-SOP-101 C.
Cause due to Control Rod Drift, Cause due to Loss of Feedwater Heating, f
IF THEN More than one control rod has SCRAM the reactor per scrammed OR drifted, N2-SOP-101 C.
Core flow enters the Heightened Enter N2-SOP-29, Sudden Continue at IQ Core flow enters the Heightened Awareness Zone OR Exit Region, Enter N2-SOP-29, Sudden Reduction in Core Flow.
Cause due lo Recirc FCV Failure, Cause due to Control Rod Drop, Depress "HYDRAULIC PRESSURE UNIT SHUTDOWN" pushbutton at 2CEC'PNL602.
Perform Attachment 2.
Perform Attachment 3.
rn Cause due to Single Control Rod Scram, Perform Attachment 4.
Monitor Ofgas AND Main Steam Line Radiation Monitors for evidence of Fuel Element Failure.
~ Cause is Unknown, IF THEN Perform Attachment 5.
SPECIAL OPERATING PROCEDURE
N2-SOP CONTROL ROD DRIFT Iden!ify which control rod is driftino and in what direction m: Specific recommendations from the on call Rx Eng. may override directions for plant power reductions.
IN I OUT HCU for the drifting control rod.
2RDSV103 2RDSV105 Perform initial entry flowchart.
Has the Yes
. Using INSERT pushbutton. fully insert drif!ed control rod.
Bypass the RWM if necessary Reduce Rx power to No approximately 85% per NP-SOP-lO1D m a s recornmended by Rx Eng.
inserted?
Yes E w e r should have I
7 Insert the face adjacent control roil identified in the CRC book for the drifted control rod B a s recommended by Rx Eng Contact Rx Eng. for additional Did the Release INSERT Reduce core flow to N2-SOP-101 D Q1! as Restore hydraulics by i opening the following already been lowered to approximately 85%.
t L
inserted?
Reduce core flow to approximately 65 mlbmlhr per NZ-SOP-IOlD as recommended by Rx Eng.
Isolate stuck N2-OP-30, Section F.8.2.
I No control rod by placing BOTH NORM-TEST-SRI G s w i t c h e s 10 TEST the dnfted rod IS inserted, THEN NORM-TEST-SRI E
required, disarm the control rod per N2-OP-30 Refer to TS 3.1.3. Control Rod Operability.
valves:
W d i r e c t e d by the SM, exit this procedure.
Refer to TS 3.1.5, Control Rod Scram Accumulator Operability.
Contact Maintenance for trotibleshooffrepair plan as required.
- ZRDSV105 j l
2RDSV103 NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-08
N2-SOP108 - LOSS OF FEEDWATER HEATING 7 -
Adjust Reactor power per NZ-SOP-1OID to maintain t i e following Reactor power 5 3467 MWt (Use OD-3 or manual Heat Balance)
FW temperature (NSSTA101, 102,103, 104, OR FWS-TIWA, TIWB) in the'GOOD area of Figure 1 HDL-PIA (B C) flows < 3800 gpm AND current < 190 amps Exit this procedure 1
I 2FWS-MOV102 is stuck open I
Commence a Plant Shutdown per Pressure Heater String lost NZ-OP-101D AND N2-OP-1O1C 2CNM AOV101 is stuck open One High Pressure Heater AND one Low Pressur Heater String lost (can be different HTR Strings) J i"l Perform Attachment 1 Figure 1: FEEDWATER TEMPERATUREnHERMAL POIF!ER LIMIl Allow feedwater heater system sufficient time to stabilize before initiating further power reductions I
NINE MILE PO!NT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE
Appendix D Scenario Outline Form ES-D-1 Facility: Nine Mile Point 2 Examiners:
Operators:
Scenario No.: NRC-03 Op-Test No.: March 2008 Initial Conditions: Simulator IC-244
- 1. Plant startup is in progress IAW N2-OPIOIA @ Step 2.45.
- 3. Reactor Pressure is at approximately 900 psig.
- 4. One Bypass Valve is approximately 15%
- 5. Other operators will be performing SJAE startup later today.
Turnover:
- 1. Continue Power Increase to get one bypass valve open approximately 25%
- 2. Transfer Reboiler Steam Supply to Main Steam IAW N2-OP-25, Section 5.0, then continue startup Event I Malf. No.
No.
I Event DescriDtion I
I R (SRO)
I N2-OP-IOIA I
I N (SRO)
I N2-OP-25 I EOP-C4 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NRC Scenario 3 March 2008
Op-Test No.: March 2008 =
TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO SEE SECTION D.5.d)
- 1. Total malfunctions (5-8)
Events 3,4,5,6,8,9 Events 8,9
- 2. Malfunctions after EOP entry (1-2)
- 3. Abnormal events (2-4)
ACTUAL ATTRIBUTES 6
2 3
- 4. Major transients (1-2)
I Event7 I
1
' 5. EOPs enteredlrequiring substantive actions (1-2)
- 6. EOP contingencies requiring substantive actions (0-2)
Event 10 EOP-C4
- 7. Critical tasks (2-3)
CRITICAL TASK DESCRIPTIONS:
CT-1.O initiate an RPV blowdown when level indication is lost or if the PSP is exceeded.
CT-2.0 flood the RPV to the elevation of the main steam lines IAW RPV flooding.
2 1
2 NRC Scenario 3 March 2008
NMP SIMULATOR SCENARIO NRC Scenario 3 REV. 00 No. of Pages:
19 PREPARER S. Dennis VAL1 DATED GEN SUPERVISOR OPS TRAINING R. Brown OPERATIONS MANAGER NA Exam Security CON FIG U RAT1 0 N CONTROL NA Exam Security DATE DATE DATE 1/23/08 DATE DATE SCENARIO
SUMMARY
Length: 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Initial Power Level: 1 % Startup with RPV Pressure at 900 psig The scenario begins with a plant startup in progress and reactor pressure at 900 psig.
Control rods will be withdrawn until one bypass valve is open 25%. When that occurs, the operators will transfer the Reboiler Steam Supply to Main Steam. After that occurs, the plant startup will continue with control rod withdrawal.
While increasing power an inop trip will occur on IRM channel A. The operators will bypass the affected IRM and reset the half scram. TS (TS 3.3.1.I) will be referred to by the SRO.
Next, a loss of offsite power to Div I Switchgear occurs when breaker 16-2 fails open, the crew will take action per N2-SOP-03 to stabilize plant parameters and adjust Service Water flow. The SRO will be required to address TS (TS 3.8.1.A - 1 Hr for surveillance - 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> SD LCO). When plant conditions are stabilized IRM G will have an upscale trip requiring a TS entry by the SRO.
A seismic event will then occur causing a Condensate pump to trip and the standby pump must be started. A service water pump will also trip requiring entry to TS 3.7.1.E.
-72 hours). N2-SOP-90 will be entered to address the seismic event.
Once conditions are stabilized, a seismic aftershock will occur causing a rupture of the recirculation loop suction line. Initially drywell pressure rise slowly and the operators will manually scram the plant. The leak will get larger and entry into EOP-RPV and EOP-PC will be required. The event is complicated by a failure of Division 2 ECCS to initiate automatically. Operator action will be required to manually initiate Division 2 ECCS.
NRC 2008 Scenario 3 March 2008
The crew must initiate an RPV blowdown when level indication is lost or if the PSP is exceeded (CT). Only 5 SRVs will initially open requiring operator action to open additional SRVs. The crew must flood the RPV to the elevation of the main steam lines in accordance with RPV flooding EOP-C4 (CT). Once RPV is flooded, containment parameters can be addressed.
Major Procedures Exercised:
EOP-RPV, PC, C4 EAL Classification:
Alert 8.4.4 - Seismic Event, SAE - 2.1.2 -RPV Flooding Required Termination Criteria:
acoustic monitors, RPV pressure rising, or tailpipe temperatures lowering.
Level recovered to the main steam lines as indicated by NRC 2008 Scenario 3 March 2008
I. SIMULATOR SET UP A. IC Number: IC-244, Ensure RWM is functional when IC is snapped.
B. Presets/Function Key Assignments
- 1. Malfunctions:
- a. RH14B ECCS FAILS TO INITIATE (DIV II)
PRESET
PRESET
PRESET
- d.
NMOSA IRM CHANNEL FAILURE - INOP (A)
TRG 1
- e. ED04F 4.16 KV NORMAL BUS FAULT (SWG16)
TRG 2
- f.
NMO6G IRM CHANNEL FAILURE-UPSCALE (G)
TRG 3
- g.
MTOI SEISMIC ACCELERATION TRG 4
- h. FWOIB CONDENSATE PUMP TRIP (PIB)
TRG 4
- i.
TRG 4
- j.
RR20 RR LOOP RUPTURE -DBA LOCA (5 minute Ramp) TRG 5 K.
CWOl F SERVICE WATER PUMP TRIP (PI F)
RPV LEVEL INSTRUMENTS ALL FAIL UPSCALE (3 Minute Delay)
TRG 6 Remotes:
- 3. Overrides:
- a. None
- 4. Annunciators:
- a. None C. Equipment Out of Service
- 1. None D. Support Documentation E. Miscellaneous - ENSURE THE FOLLOWING PROCEDURES ARE OUT IN THE CONTROL ROOM SIGNED OFF AS INDICATED BELOW N2-OP signed off thru step 3.3.32 N2-OP-IOIA - step 2.46.3 completed N2-OP-101A - step 2.45 in progress NRC 2008 Scenario 3 March 2008
II.
SHIFT TURNOVER INFORMATION PART I:
shift.
To be performed by the oncoming Operator before assuming the Control Panel Walkdown (all panels) (SM, CRS, STA, CRO, CRE)
PART II:
To be reviewed by the oncoming Operator before assuming the shift.
Shift Supervisor Log (SM, CRS, STA) 0 CRO Log (CRO) 0 LCO Status (SM, CRS, STA)
Lit Control Room Annunciators 0
Computer Alarm Summary (CRO) 0 Shift Turnover Checklist (ALL)
Evol u t ions/Gene ral I nfo rmat ion/Equ i pmen t Status :
0 Reactor Power = Startup @ 900 psig 0
Currently at step 2.45 of N2-OP-IOIA 0
BPV # I is approximately 15% open Other operators will be performing SJAE startup later today.
PART 111:
RemarkdPlanned Evolutions:
Applicable Procedures In Progress N2-OP signed off thru step 3.3.32 N2-OP-101A - step 2.46.3 completed N2-OP-101A - step 2.45 in progress
- Additional Applicable Startup procedures are being monitored and performed by other operators. No actions from any applicable procedure will taken without notifying the control room.
Continue to raise power to get BPV # I 25% open Transfer the Reboiler Steam Supply to Main Steam IAW N2-0P-25, Section 5.0.
PART IV:
To be reviewedlaccomplished shortly after assuming the shift:
0 Review new Clearances (SM) 0 Test Control Annunciators (CRE) 0 Shift Crew Composition (SM/CRS)
NRC 2008 Scenario 3 March 2008
TITLE NAME TITLE SRO ATC RO BOP RO NRC 2008 Scenario 3 NAME March 2008
Scenario ID#
I INSTRUCTOR COMMENTS (Strenaths. Areas for Imtxovement. ODen Items etc.)
What Happened?
What we did?
Why? (Goals)
Other 0 pt io n s?
NRC 2008 Scenario 3 March 2008
Ill.
PERFORMANCE OBJECTIVES A. Critical Tasks:
CT-1.O The crew must initiate an RPV blowdown when level indication is lost or if the PSP is exceeded The crew must flood the RPV to the elevation of the main steam lines IAW RPV flooding EOP-C4 CT-2.0 B. Performance Objectives:
PO-I.o PO-2.0 PO-3.0 PO-4.0 PO-5.0 PO-6.0 PO-7.0 PO-8.0 Given the plant or plant system in a condition requiring Technical Specification action, identify the deviation and any required actionshotifications.
Given the plant with a reactor startup in progress, the crew will identify and take actions for a failed IRM detector in accordance with N2-OP-92.
Given the reactor plant operating at full power when service water pump trips, the crew will take action to stabilize service water in accordance with the ARP and N2-OP-11.
Given a large LOCA inside the primary containment, the operating crew will operate the containment sprays to stabilize containment pressure < I.68 psig.
Given EOP-RPV, monitor and control Reactor Water Level and Reactor Pressure.
Given the plant shutdown following a large break LOCA and RPV level indication not usable, the crew will perform RPV flooding in accordance with EOP-C4.
With RPV level instrumentation unavailable for use the crew will open 7 ADS valves in accordance with EOP-C4.
With RPV level instrumentation unavailable, 7 ADS valves open and control rods not inserted, the crew will inject with all systems necessary to achieve and maintain greater than 165 psig RPV pressure in accordance with EOP-C4.
NRC 2008 Scenario 3 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 1 Continue Startup EVENT 1 -RO Actions EVENT 1 -BOP Actions CREW Crew conducts a pre-brief, walks down the panels, and tests annunciators.
SRO B
Direct the RO to continue withdrawing control rods until RPV pressure is 925 psig and BPV #I is 20% open.
Withdraws control rods IAW sequence.
Monitors RPV, CRD and Nuclear Instruments Establish a stable positive period greater than 60 seconds using control rods as required.
Maintain IRM indications between 25 AND 75 on 125% scale by ranging IRM range switches as required.
BOP e Maintain Reactor Water Level between 178.3 AND 187.3 NRC 2008 Scenario 3 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE 0 PE RATOR ACT1 ONS EVENT 2 Transfer Reboiler Steam Supply to Main Steam EVENT 2 -SRO Actions EVENT 2 -BOP Actions NRC 2008 Scenario 3 SRO Directs the BOP to change the Reboiler Steam supply to the Main Steam supply provided that Reactor pressure control is established with a Turbine Bypass Valve open 20% or greater.
Verifies an operator is stationed at the Auxiliary Boilers.
Manually open 2ASS-MOV148, MAIN STM TO AUX STM ISOL VLV Close 2ASS-AOV145, AUX BLR STM INLET VLV, Place the Reboiler 2ASS-STVI 12 and 2ESS-STVI 04 control switches in the AUTO Direct the local operator to depress the RESET PUSHBUTTONS on the 2CES-IPNL204 Open 2CNA-HV34A(B)
Monitor for proper reboiler operation March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 3 IRM A lnop Trip SIM BOOTH: Activate Trigger 1 EVENT 3 SRO Actions EVENT 3 RO Actions SRO PO-1.o e
Direct actions for IRM failure consult ITS 3.3.1.I.
Reports to SRO.
Bypass IRM A per N2-OP-92, H.3.0.
Resets half scam per N2-OP-97, Sect H.2.0 At 2CEC*PNL603, reset SCRAM signals by momentarily placing applicable switches to RESET as follows:
o REACTOR SCRAM RESET LOGIC A o REACTOR SCRAM RESET LOGIC C o Verify PILOT SCRAM VALVE SOLENOID white lights A, C, E AND G are lit.
NRC 2008 Scenario 3
-1 0-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPE RATOR ACT1 0 NS EVENT 4 Loss of power to Div I switchgear.
(TS) Restore non-essential Service Water, Drywell Cooling.
SIM BOOTH: Activate Trigger 2 0
Loss of power to Div 1/111 Switchgear.
0 Div I and 111 EDGs start and pick up their respective buses.
0 S WP non-essential headers isolate.
Crew PO-3.0 Recognize loss of power from SWGOIG.
0 Enter SOP-3 and perform immediate actions to stabilize SWP and restore pneumatics.
SRO PO-I.o 0
Monitor crew actions and implementation of SOP-3.
0 Evaluate Tech Specs for the loss of power to SWGOIG. T.S. 3.8.1 AC Sources Operating.
0 Enters T. S. 3.8.1 Condition A, restore in 24 hrs.
0 Enters T.S. 3.7.1 Condition C, restore in 72 hrs.
BOP 0
Perform supplemental actions of SOP-3 for a loss of power with EDGs on the bus.
0 Verify Div 1/111 EDGs start.
0 Verify SWP non-essential headers isolate.
NRC 2008 Scenario 3
-1 1-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 5 IRM G Fails Upscale SIM BOOTH: Activate Trigger 3 for IRM G Upscale EVENT 5 SRO Actions EVENT 5 RO Actions NOTE: This will result in a half scram which cannot be reset. IRM G can not be bypassed due to the previous IRM A inop condition EVENT 6 Small Seismic Event, Condensate pump trip, Service Water Pump trip Activate Malfunctions on Trigger 4 MTOI SEISMIC ACCELERATION FWOI B CONDENSATE PUMP TRIP (PIB)
CWOl F SERVICE WTR PP TRIP (PI F)
Annunciator:
842 12 1 Seismic Acceleration Exceeded Verify Div I SWP pump restarts.
0 Restore flow to SWP non-essential headers.
Start 3rd SWP pump in Div II.
0 Restore pneumatics.
SRO PO-2.0 0
Direct actions for IRM failure consult ITS 3.3.1.I.
RO 0
Recognize IRM G failure.
0 Reports to SRO.
Crew PO-3.0 0
Report alarms 0
Monitor plant conditions 0
Recognize trip of SWP*Pl F.
0 Recognizes trip of B Condensate PP NRC 2008 Scenario 3
-1 2-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE 0 PE RATOR ACT1 ON S EVENT 6 SRO ACTIONS EVENT 6 BOP Actions Role Play: If directed, as Auxiliary Operator to perform pre-start checks on the SWP pump wait 2-3 minutes then report they are complete.
Role Play: If directed to inspect the F SWP, wait 4 minutes, then report that there is an acrid odor in the vicinity of that pump.
Role Plav: If directed to inspect the F SWP breaker, wait 2 minutes, then report that the 0
Responds to Seismic alarm SRO Monitor crew response Directs SOP-90 entry for seismic event Directs a SWP pump in DIV I1 started.
Direct the standby Condensate Pump started.
Recognizes entry into T.S. 3.7.1, Cond. E, required Act. E.l, restore required pump within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.
Reviews OP-78, Attachment 11 and enters action #2.
Exits T.S. 3.7.1 action E.l after SWP*Pl F is started.
BOP 0
Refers to ARPs.
Places SWP*Pl F in pull-to-lock.
0 Throttles flows on remaining running 0
SWP Pumps to maintain flows I 10,000 gpm.
0 Starts SWP.
NRC 2008 Scenario 3
-1 3-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPE RATOR ACT1 ON S breaker indicates instantaneous overcurrent trip. (50/51 relays, 86 device is tripped).
EVENT 6 RO Actions Role Plav: If directed, as Auxiliary Operator to perform pre-start checks on the condensate pump wait 2-3 minutes then report they are com ple te.
Role Plav: If directed to inspect the B Condensate Pump, wait 4 minutes, then report that there is an acrid odor in the vicinity of that pump.
Role Plav: If directed to inspect the B Condensate Pump breaker, wait 2 minutes, then report that the breaker indicates instantaneous overcurrent trip. (50/51 relays, 86 device is tripped).
EVENT 7 Large Seismic Event, Recirc Loop suction line break When directed by lead instructor:
Re-activate MTOI - Seismic Acceleration AND Trigger 5 for RR20, Recirc loop rupture 0
Reactor scrams due to large break LOCA 0
Drywell pressure rises rapidly 0
RPV water level lowers rapidly RO 0
Refers to ARPs.
0 Places Condensate Pump 8 in pull-to-lock.
0 Starts Standby Condensate Pump Crew PO-4.0 0
Recognize / report reactor scram and LOCA NRC 2008 Scenario 3
-1 4-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 7 SRO Actions SRO a
a a
a a
a a
Monitor plant response Acknowledge scram report Announces entry into EOP-RPV and executes all legs simultaneously.
Directs operators to control water level between the Post Scram low level and 200 inches and to restore RPV level to between 160 and 200 inches.
Enters EOP-PC Directs operator to establish SC sprays before pressure reaches 10 EOP-6, Att. 22 Enters EOP-C4 for RPV flooding Directs 7 ADS valves open Directs RPV injection with available systems Directs slowly raising injection u si ng feed wate r/cond en sate, RCIC, CRD, and/or RHS through shutdown cooling to achieve 2 or more SRVs open AND RPV pressure above 165 psig but as low as possible.
Directs MSlVs shut.
Psig NRC 2008 Scenario 3
-1 5-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 7 RO Actions NRC 2008 Scenario 3
-1 6-RC I C/S team Condensing Isolations shut.
Main Steam line drains isolated.
Monitor crew actions response Acknowledge only 5 ADS SRVs open.
Directs additional SRVs opened Verify ECCS injecting Monitor contain men t response Directs crew to monitor for indications of core damage IAW EOP-C4 Directs RHR cooling maximized Directs pneumatics restored Directs Div 1/11 H2/02 monitors placed in service per EOP-PC Mode switch to shutdown and scram report Restores level (as directed).
When directed to start RPV Flooding Slowly commences injection to the RPV to achieve 165 psig or greater using feedwatedcondensate, RCIC, CRD, and/or RHS through shutdown cooling.
Shuts all MSIVs.
March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPE RATOR ACT1 0 NS EVENT BOP Actions EVENT 8 - Failure of Div I1 ECCS to initiate EVENT 9 & I O - Loss of RPV level indication, RPV Flooding RPV water level goes below the fuel zone indication and crew recognizes that RPV level is unknown.
SIM BOOTH: As Directed, activate Trigger 6 for RPV Level Instrument Flashing After ECCS has had time to re-flood the RPV to the jet pumps, water level will be indicated on the fuel zone but due to the reference leg flashing malfunction will begin to be erratic on all available instruments.
Verifies shut RCIC/Steam Condensing Isolation valves, 21CS*MOV121 & 21CS*MOV128.
Shuts Main Steam Lines drain valves.
Takes action to manually initiate Div I1 ECCS As directed Injects with LP ECCS As Directed Injects with available FWS/Cond PO-5.0, PO-6.0, PO-7.0, PO-8.0 CREW Report RPV level indication is unknown SRO Enters EOP-C4 - RPV Flooding Monitors for Core damage Directs blowdown by opening 7 ADS valves CT-1.O Directs Continued Injection until the main steam lines are flooded as indicated by:
o Increasing Reactor pressure.
o SRV Red Light Indication on P601 -acoustic monitor NRC 2008 Scenario 3
-1 7-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS Event 9 & I O : BOP Actions (cont)
Event 9 & I O : RO Actions Termination Criteria:
Indication of Mean Steam Lines Flooded is determined by crew NRC 2008 Scenario 3 noise.
o Decreasing SRV tailpipe temperature.
CT-2.0 BOP 0
Initiates blowdown by opening 7 ADS valves 0
0 Open additional SRVs 0
Establishes 7 SRVs open CT-1.0 0
Continues feeding vessel with available systems as directed.
0 Monitors for indications of main steam lines flooded.
0 Continues feeding vessel with available systems as directed.
0 Monitors for indications of main steam lines flooded.
-1 8-March 2008
V.
POST SCENARIO CRITIQUE A. NA, NRC Exam VI.
REFERENCE EVENTS AND COMMITMENTS A. Reference Events None B. Commitments
- 1. None
- 2.
VII. LESSONS LEARNED NRC 2008 Scenario 3
-1 9-March 2008
EVALUATED SCENARIO CHECKLIST X
X X
X 1
Realism/Credibility Event Sequencing Simulator Modeling Evaluating Crew Competencies Additional Information about these checks:
6 2
2 1
2 For continuing training, can be found in NUREG 1021, ES 604 and Appendix D.
Total Malfunctions Malfunctions after EOP Entry Abnormal Events Major Transients EOPsUsed For initial training, can be found in NUREG 1021, ES 301 and Appendix D.
2
- 2.
Qualitative Attributes EOP Contingency Procedures Used Simulator Run Time
- 3.
I I
I Quantitative Attributes I I EOP Run Time I
4 I Crew Critical Tasks (if applicable per Attachment 6.)
- 4.
Developmental Checks:
Does every event have either a Critical Task(s) or Performance Objective?
Is Criteria given for sequencing to subsequent events?
Is termination criteria clear and unambiguous?
Does termination criteria allow verification that all CT, PO standards are met?
Appendix D Scena ria 0 u tline Form ES-D-1 Facility: Nine Mile Point 2 Examiners:
Operators:
Initial Conditions: Simulator IC-1 7
- 1. Reactor Power 100%
Turnover:
- 1.
- 2.
Scenario No.: NRC-04 Op-Test No.: March 2008 Reduce power to 90% per LD for a rod line adjustment which will take place on the next shift.
Perform N2-OSP-RMC-S@001 Control Rod Movement and Position Verification Surveillance Test Position Verification Surveillance Test 3
RD18 C(R0)
CRD PIA suction filter clog causes pump trip.
C (SRO)
N2-SOP-30, CRD Failures I
- I 5
overrides C (BOP)
Control roorr AC unit trips (TS 3.7.2.A - 7 days, TS 3.7.3.A - 30 TS (SRO) days.
6 EGOGA C(B0P)
Stator water pump trip, failure of standby to auto start, Generator C (SRO)
RB. Power reduction may be required.
N2-SOP-68. Loss of Stator Coolina OP-3, Loss of AC Power, N2-SOP-97 RPS Failures OP-13, Degraded CCP System, N2-SOP-60, Loss of DW 9
I ED02A,B I M (ALL)
I Loss of Offsite Power with EDG auto-start failures (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NRC Scenario 4 March 2008
Facilitv: Nine Mile Point 2 Scenario No.: NRC-04 TARGET QUANTITATIVE ATTRIBUTES (PER SCENARIO: SEE SECTION D.5.d)
- 1. Total malfunctions (5-8)
Events 3,5,6,7,8,10
- 2. Malfunctions after EOP entry (1-2)
Events 10
- 3. Abnormal events (2-4)
Event 3-SOP-30, Event 6-SOP-68. Event 7-3.1 3.60.97,
- 4. Major transients (1-2)
Event 9
- 5. EOPs enteredlrequiring substantive actions (1-2)
- 6. EOP contingencies requiring substantive actions (0-2)
EOP-Failure to Scram,
- 7. Critical tasks (2-3)
EOP-RPV, EOP-PC CRITICAL TASK DESCRIPTIONS:
CT 1.O - Upon Mode Switch and RPS PB Failure, Scram is accomplished with RRCS.
CT 2.0 - On EDG Auto-start failure, start the EDGs from the control room IAW SOP-03.
CT 3.0 - drywell spray is initiated prior to exceeding the PSP.
ACTUAL ATTRIBUTES 6
1 3
1 2
1 3
OD-Test No.: March 2008 NRC Scenario 4 March 2008
NMP SIMULATOR SCENARIO NRC Scenario 4 REV. 00 No. of Pages:
26 PREPARER S. Dennis VAL1 DATED GEN SUPERVISOR OPS TRAINING R. Brown 0 PE RAT1 0 N S MANAGER NA Exam Security CON FIG U RAT1 ON CONTROL NA Exam Security DATE DATE DATE 1/23/08 DATE DATE SCENARIO
SUMMARY
Length: 1.5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Initial Power Level: 100%
The scenario begins with the crew performing a power maneuver power will be lowered to 90% for a rod line adjustment which will take place on the next shift. The crew will perform surveillance N2-OSP-RMC-W@001 Control Rod Movement and Position Verification. Following the third rod tested, a trip of the running CRD pump will occur due to a clogged suction strainer. Actions must be taken to start the standby pump.
Once the standby pump is started, position indication for a control rod will be lost requiring the SRO to address Technical Specifications (TS 3.1.3.C.1 and 2).
One of the Control Room AC units will trip and the standby unit will fail to auto-start.
The SRO will enter TS 3.7.3.A. The running Stator Water Cooling pump then trips and the standby pump fails to start but can be manually started. If a bypass valve opens due to the pump trip and generator runback a power reduction will be required. When conditions stabilize, a loss of Switchgear 15 will occur which affects RPS and requires operator action to transfer RPS to its alternate supply. Additionally, Switchgear 15 may be re-powered.
Once conditions are stabilized, a small leak will develop in the drywell requiring a manual scram of the reactor. A failure of the mode switch and RPS manual scram pushbuttons will occur requiring the use of RRCS to insert control rods (CT). The SRO will enter EOPs and EOP contingencies.
Once the rods are inserted, a Loss of Offsite Power will occur. Additionally, the EDGs will fail to auto start. The operators will take actions to start the EDGs in the control room IAW SOP-O3(CT). The containment leak will get worse. RHR pump PIA will trip when placed in service and Suppression Chamber Spray must continue with RHR NRC 2008 Scenario 4 March 2008
pump P I 6. The operators will be expected to control containment pressure with Drywell Spray prior to exceeding the Pressure Suppression Pressure (CT).
Major Procedures Exercised:
EOP-RPV, PC, C6. SOP-I,3,11,30,68 EAL Classification:
Alert - 6.1.3 - AC Power loss for > I 5 minutes on one bus Alert - 3.1. I - Primary Containment Pressure cannot be maintained < I.68 psig Alert - 2.1. I - auto scram failed Termination Criteria:
pressure are being controlled.
Containment pressure is decreasing and RPV level and NRC 2008 Scenario 4 March 2008
I. SIMULATOR SET UP A. IC Number: IC-I7 B. PresetdFunction Key Assignments
- 1. Malfunctions:
- b. RDI 1 30-59 CONTROL ROD FAILURE RPlS (ANY)
TRG 2 (DELAY 2 SECONDS)
- c.
EGO6A MAIN GEN STATOR CLG PMP TRIP TRG 4
- e.
RP03 RPS FAILURE TO SCRAM PRESET
- f.
TRG 8
- g.
TRG 8
- i.
DGOIC DG #3 FAILURE TO START TRG 8
- j.
ED14 UPS FAULT 2VBB-UPSIG TRG 9
- k.
TRG 15 I.
MS04 STM LINE RUPTURE IN PRI CONT (RAMP 8 MINS) TRG 13 ED02A LOSS OF OFFSITE 115KV LINE 5 (DLY 5 SECS)
ED02B LOSS OF OFFSITE 115KV LINE 6 (DLY 5 SECS)
RHOIA RHR PUMP TRIP (PIA) (DLY 10 SECS)
- m. AN603443 Control Rod Drift
- 2. Remotes:
- a.
RP02 RPSMGZEPA
- b. RC02 RClC LVL 8 TRIP DEFEAT
- c.
DGOI LOCKOUT RELAY DGI (DELAY 8 MINS)
- d. DG03 LOCKOUT RELAY DG3 (DELAY 4 MINS)
- e.
SB05 2VBS-PNLA102 BKRS 1,2
- f.
SB06 2VBS-PNLB102 BKR 3 (DLY 10 SECS)
- g.
SB07 2VBS-PNLA104 BKR 3 (DLY 20 SECS)
- h. SB08 2VBS-PNLB103 BKR 7 (DLY 30 SECS)
- i.
SBOI 2VBS-PNLA101 BKRS 6,7,9,11,12,13,19,20,36,37 (DLY 1 MIN)
- j.
SB02 2VBS-PNLB101 BKR 5,6,7,8,9,12,13,14,15 (DLY IMIN 10 SECS)
- k.
SB03 2VBS-PNLB104 BKR 3 (DLY 1 MIN 20 SECS)
I.
SB04 2VBS-PNLA103 BKR 3 (DLY 1 MIN 45 SECS)
- m. SBI 1 2VBS-PNLA101 BKR 35 NRC 2008 Scenario 4 TRG 2 TRG 6 TRG 14 TRG 11 TRG 12 TRG 20 TRG 20 TRG 20 TRG 20 TRG 20 TRG 20 TRG 20 TRG 20 TRG 21 March 2008
- n. SB12 2VBS-PNLB101 BKR 23 (DLY 10 SECS)
TRG 21
- 0. SB09 2VBS-PNLIOIA BKRS 3,11,13,20 (DLY 20 SECS)
TRG 21
- p. SB13 2BYS-PNL201A BKRS 11,18,19,20 (DLY 30 SECS)
TRG 21
- q. SB15 2BYS-PNL202A BKRS 1,2,3,4,5,6 (DLY 1 MIN TRG 21
- r.
SB14 2BYS-PNL201B BKRS 18,21 (DLY 1 MIN 10 SECS) TRG 21
- s.
SBIO 2VBS*PNL301B BKRS 12,13,17,20 TRG 21 (DLY 1 MIN 20 SECS) 2BYS*PNL202B BKRS 1,2,3,4 (DLY 1 MIN 45 SECS) TRG 21
- t.
SB16
- 3. Overrides:
- a.
OVR-20A2S065D12438 PTL CNTL RM A/C FAN ACU 1A SW TRG 3
- b.
OVR-04A2S022D16126 GEN STR COOL PMP 2GMC PIB PRESET C.
OVR-05A2S101 D17235 STP NORM INCOMING TRG 5 13.8KV NORM BUS FD
- d.
OVR-18A3S095Dll357 STP CONTROL ROOM A/C FAN*ACUl B PRESET OFF (GRN)
OVR-18A3S095Dll358 NAP CONTROL ROOM A/C FAN*ACUI B PRESET OFF (GRN)
- e.
- 4. An nu nciators:
- a. None C. Equipment Out of Service
- 1. None D. Support Documentation E. Miscellaneous
- 1.
Provide RMR for Power reduction NRC 2008 Scenario 4 March 2008
II.
SHIFT TURNOVER INFORMATION TITLE SRO ATC RO BOP RO PART I:
shift.
To be performed by the oncoming Operator before assuming the NAME TITLE NAME 0
Control Panel Walkdown (all panels) (SM, CRS, STA, CRO, CRE)
PART II:
To be reviewed by the oncoming Operator before assuming the shift.
Shift Supervisor Log (SM, CRS, STA) 0 CRO Log (CRO) 0 LCO Status (SM, CRS, STA)
Lit Control Room Annunciators 0
Computer Alarm Summary (CRO) 0 Shift Turnover Checklist (ALL)
Evolution s/Gene ral I n fo rma tion/Eq u i pmen t Status :
0 Reactor Power = 100%
0 Loadline = >loo%
0 None PART I I I :
Remarks/Plan ned Evol ut ions :
Lower Reactor power per RMR to 90% to support rod line adjustment next shift.
Perform N2-OSP-RMC-S@001 Control Rod Movement and Position Verification.
PART IV:
To be reviewed/accomplished shortly after assuming the shift:
0 Review new Clearances (SM) 0 Test Control Annunciators (CRE) 0 Shift Crew Composition (SM/CRS)
NRC 2008 Scenario 4 March 2008
Scenario ID#
INSTRUCTOR COMMENTS (Strenaths. Areas for Imtxovement. ODen Items etc.)
What Happened?
What we did?
Why? (Goals)
Other 0 pt ions?
NRC 2008 Scenario 4 March 2008
Ill.
PERFORMANCE OBJECTIVES A. Critical Tasks:
CT-1.O Given a failure of RPS the crew will use of RRCS to insert control rods.
Given a Loss of Off-Site Power with a failure of the EDGs the operators will take actions to start the EDGs in the control room Given a small leak in the drywell the crew will initiate Drywell Spray prior to exceeding the Pressure Suppression Pressure CT-2.0 IAW SOP-03 CT-3.0
- 6. Performance Objectives:
PO-I.o PO-2.0 PO-3.0 PO-4.0 PO-5.0 PO-6.0 PO-7.0 Given the plant at rated power, the crew will lower power to 90%
using recirc flow control following the guidance of the provided RMR and N2-OP-101 D.
Given the plant at 90% power, the crew will perform surveillance N2-OSP-RMC-W @OOl Given a loss of the a running CRD pump, the crew will start the Standby CRD pump before receiving any accumulator alarms, IAW N2-SOP-30.
Given the failure of control rod position indication for a control rod Refer to N2-OP-96, Section H and restore RPIS.
Given the plant or plant system in a condition requiring Technical Specification action, identify the deviation and any required actionshotifications.
Given a loss of the operating stator water cooling pump and the failure of the standby pump to auto start the operating crew will take action to manually start the standby pump IAW N2-SOP-21, N2-SOP-68 and N2-SOP-101 C.
Given a loss of the Control Room AC Unit and the failure of the standby AC unit to auto start the operating crew will take action to manually start the standby AC unit IAW N2-OP-53A.
NRC 2008 Scenario 4 March 2008
PO-8.0 With an electrical fault on NNS-SWGOI 5, the crew will electrically isolate NNS-SWGOI 5 and investigate the cause per N2-SOP-03.
With B RPS de-energized due to loss of NNS-SWGOI 5, the crew will re-energize B RPS from its alternate supply per N2-SOP-97.
PO-I 0.0 With DW Cooling fans de-energized due to loss of NNS-SWGOI 5, the crew will start DRS-UC3A per N2-OP-60.
PO-I 1.O With the plant operating at power the crew will respond to LOCA in the drywell PO-12.0 Given the plant operating at full power when a station blackout occurs, the crew will respond to the station blackout in accordance with N2-SOP-1 and N2-SOP-03.
PO-9.0 NRC 2008 Scenario 4 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 1 - Power reduction to 90%
EVENT 1 -SRO Actions EVENT 1 -RO Actions Core Flow lowers, Power lowers EVENT 1 -BOP Actions NRC 2008 Scenario 4 ZREW B
Crew conducts a pre-brief, walks down the panels, and tests annunciators.
SRO PO-1.o D
If not previously performed, conducts Shift and Reactivity Briefs.
Directs power lowered to 90% per RMR and OP-101 D B
RO Lowers power to 90 YO by reducing core flow Moves RCS*HYVI 7A&B individually in the close direction, maintaining loop flow differential at a minimal value by alternating between the two valves.
Monitors Nls and rate of power change.
BOP Monitors plant parameters to verify proper operations.
March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 2 - Perform N2-OSP-RMC-W@001 Control Rod Movement and Position Verification Surveillance Test EVENT 2 -SRO Actions EVENT 2 -RO Actions EVENT 3 CRD PIA suction filter clog causes pump trip.
Sim Booth: Activate Trigger 1 as directed RDS-PIA trips on low suction pressure.
AN 603318 CRD Pmp Sucf Fltr Diff Press High AN 603315 CRD Pmp IB Sucf Press Low AN 603309 CRD Pmp ?A Suct Press Low AN 603308 CRD Pmp IA/IB Auto Trip RDS-PIA trips AN 603341 Rod Drive Accum Trbl EVENT 3 SRO Actions SRO B
Auth riz PO-2.0 s/directs performance of surveillance N2-OSP-RMC-W@OOl RO B
Commences surveillance B
Exercises first control rod Exercises the second rod CREW PO-3.0 0
Recognize/Report the loss of RDS-PIA SRO Directs RO to halt surveillance test.
NRC 2008 Scenario 4
-1 0-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS NOTE: If Required, prompt SRO to continue with surveillance test when CRD suction Filters are swapped EVENT 3 -RO Actions Role Play:
As an Operator dispatched to Swap CRD Suction Filters, wait 5 min. or as directed by lead instructor, clear Malfunction RD18 and report Suction Filters swapped.
Examiner Note: The following annunciator may alarm during the CRD suction Filter swap.
AN 603316, CONTROL ROD HIGH TEMPERATURE alarms.
0 Directs RO to enter and execute SOP-30 0
When suction filter has been swapped directs the resumption of Control Rod Movement surveillance test.
RO 0
Enters and executes SOP-30 Places RDS Flow Controller to MAN Closes RDS Flow Control Valve Directs A 0 to shift RDS Suction Filters Throttles closed WCS*MOV200 until F/Ds are in HOLD Trips WCS Pumps Acknowledge CRD Suction Filter Swap.
Restart a CRD pump per N2-SOP-30.
Report CRD Flow restored.
CREW 0
Recognizes/Reports control rod high temperature alarm and takes the actions of ARP.
0 Dispatches Aux Operator to monitor CRD temperatures.
NRC 2008 Scenario 4
-1 1-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS Role Plav:
to monitor CRD temperatures, report that highest temperature is on rod 18-43 (report 265°F if alarm is in, report 240°F if alarm is clear).
As the Aux Operator dispatched EVENT 4 - Rod Position Indication Lost Booth Operator: Insert malfunction RDI 1 (Trigger 2) after rod 30-59 is returned to position 48.
AN603443 Control Rod Drift A N603303, Rod Drive Control System Inoperable AN603304, Rod Position Indicating Sys Inoperable AN 603305, Control Rod Display noperable EVENT 4 SRO Actions Role Play:
As the Reactor Engineer direct a halt to all further rod movement and direct the SRO to determine the control rod movement and notify Reactor Engineering if any control rod movement occurs.
Role Play:
As the I & C Supervisor ask for CREW PO-4.0 & 5.0 0
Resumes NZ-OSP-RMC-W@OOI Control Rod Movement and Posit ion Verification.
0 Recognize Rod Out Block 0
Diagnose loss of RPlS for 30-59 SRO Suspend all attempts to move control rods.
0 Direct entry into N2-0P-96, Section H.
0 Refer to Technical Specification 3.1.3 0
Determines a control rod whose NRC 2008 Scenario 4
-1 2-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS all the current control room annunciators and state you will send an I & C Tech to determine the cause of the problem.
EVENT 4 RO Actions position cannot be determined be declared inoperable and fully inserted within 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> and disarmed within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.
Notify the Reactor Engineer AND Contact the I&C Department to troubleshoot AND repair.
0 NRC 2008 Scenario 4
-1 3-Respond to Rod Out Block Suspend all attempts to move control rods.
Enter ARP for 603304 RPlS INOP Push AND hold the RDCS STATUS Inoperative Reset pushbutton for five seconds Refer to N2-OP-96, Section H.
Verify the Rod Display fans are operating in P603 panel, depress "Test High Temp" and "Test Low Temp" orange push button to verify fan operation.
Record the lit LEDs in 2CEC-PNL615.
Attempt to determine the position of 30-59 by checking:
The Full-In (or Full-out) indication on the R&DD.
Demand an 00-7 printout from March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 5 - Control Room AC unit trips Sim Booth: Activate Trigger 3 as directed EVENT 5 SRO Actions EVENT 5 RO Actions the process computer.
When I & C reports the RPlS is repaired and the RPlS system is verified operable reset the control rod drift and block.
CREW PO-7.0 0
Recognizes and diagnoses the loss of Control Room AC and the standby unit failure to auto-start.
SRO 0
Directs manual start of CNTL RM A/C FAN ACU 1B 0
Enters procedure N2-OP-53A 0
Enters TS 3.7.2.A - 7 days, TS 3.7.3.A - 30 days.
0 Monitors Reactor Power, Pressure
& Level NRC 2008 Scenario 4
-1 4-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 5 BOP Actions EVENT 6 Stator water pump trip, failure of standby to auto start, Generator RB. Power reduction may be required.
Sim Booth: Activate Trigger 4 as directed GMC-PIA trips on motor electric fault.
AN851135, STTR CLG WTR Pump IA/IB Auto Trip/Fail to Start GMC-PI B fails to start automatically or manually.
Loadset begins to runback Turbine bypass valves begin to open.
EVENT 6 SRO Actions 3op Manually starts CNTL RM A/C FAN ACU IA.
Verifies system conditions IAW Enters procedure N2-OP-53A Verifies CR HVAC operates correctly Crew PO-8.0 0
Recognizesheports loss of GMC-PIA.
0 Recognizes failure of standby GMC pump to start automatically.
SRO 0
Enter SOP-68 0
Enters ITS 3.7.2.A - 7 days, TS 3.7.3.A - 30 days NRC 2008 Scenario 4
-1 5-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 6 RO Actions EVENT 6 BOP Actions Role Play:
As the A 0 sent to Stator Water skid that all conditions are normal. If sent to the breaker for GMC-PIA report that the breaker front is warm.
Report that the breaker for GMC-PI B appears normal.
EVENT 7 Loss of Switchgear 15 Plant response will include loss of:
CCS-PI B RDS-PI B WCS-PIB 1/2 of DW Cool Fans RPM - MGIB Sim Booth: Activate Trigger CUE: After being dispatched by control room, 0
Enters SOP-68 0
If a runback occurs, initiate a power reduction IAW N2-SOP-101 D as necessary to maintain the BPV closed BOP 0
Enters SOP-68 0
manually starts GMC-PI B 0
Reports start of standby GMC Pump 0
Dispatched personnel to the local GMC skid to check for probable causes.
CREW PO-8.0, 9.0, 10.0 0
Recognize trip of RPS and loss of SWGOI 5.
0 Enter SOP-3 for loss of SWGOI 5.
0 Enter SOP-97 to re-energize B RPS.
NRC 2008 Scenario 4
-1 6-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS report as Electrical Maintenance that Switchgear 15 has no problems and it appears a problem occurred with BKR 15-3.
EVENT 7 SRO Actions Sim Booth: When asked to reset the EPAs for RPS, INSERT TRG 6.
Role Play: After being dispatched by control room, report as Electrical Maintenance that Switchgear 15 has no problems and it appears a problem occurred with BKR 15-3.
Sim Booth: Activate Trigger 5 as requested Role Play:
report:
0 RPM*ACBIB tripped 0
RPM*ACB2B tripped 0
RPM-MGIB not running RPM-MG1 B Generator Output switch closed As A 0 dispatched for SOP-97, 0
NHS-MCCOO9-4EL breaker closed SRO Enter SOP-3 and isolate SWGOI 5.
Enter SOP-97 and to re-energize B RPS.
Direct an operator to place RPS Alternate power switch to ALT and reset the EPAs Enters ITS 3.4.7 Directs a plant shutdown per N2-OP-I 01 C due to the significantly reduced CCP capacity.
NRC 2008 Scenario 4
-1 7-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 7 RO Actions EVENT 7 BOP Actions Role Play:
reset the EPAs report:
As A 0 dispatched for SOP-97 to 0
EPA relay trip flags reset 0
EPA breaker reset When 9 RPS has been re-energized per SOP-97 and as directed by the Lead Instructor, insert malfunction Trigger 7 (MS03) for Steam Leak RO 0
Check control rod positions for drifting control rods Enter ARPs for AN60221 8 and 602224.
When the EPA breakers are reset, reset half scram and isolations.
0 BOP Start DRS-UC3A per N2-OP-60.
Start CCP-PI C Dispatch operators to EHS*MCC103 (CB261) and RB 261to override and open MOVs to RCS Pumps.
Direct throttling open WCS*MOVI 10 When directed place RPS Alternate power switch to ALT.
Direct an operator to reset the EPAs.
NRC 2008 Scenario 4
-1 8-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 8 Steam Leak in containment, Failure to Scram 603140 Drywell Pressure HIGH/LOW EVENT 8 SRO Actions CREW PO-I 1.o Recognizes and responds to annunciator.
Identifies and reports changing contain ment parameters.
SRO Directs mode switch to shutdown.
Enters RPV Control.
Directs EOP-RPV, enters C-5 Failure to SCRAM.
Directs ADS logic inhibited.
Directs CSH placed in pull-to-lock.
inches Directs a RPV water level band 159-200 inches.
Directs a RPV pressure band with a target of 800-1000 psig.
Directs RRCS initiated.
CT-1.O Directs EOP-6, Attachment 13.
May direct EOP-6 Attachment I O.
NRC 2008 Scenario 4
-1 9-March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 8 RO Actions EVENT 8 BOP Actions PO-4.0 Place reactor mode switch in shutdown and provides scram rep0 rts.
e Recognizes and Reports all control rods did not insert Inhibits ADS.
Initiates RRCS IAW EOP-6, 3 CT-1.O Takes appropriate action to maintain RPV water level within the directed band of 159 -200 inches.
BOP NRC 2008 Scenario 4 Takes appropriate action to maintain RPV pressure within the directed band.
As directed places HPCS in PTL Restores drywell Cooling (EOP-6 att 24):
o Determines drywell temperature <25OoF o Overrides drywell unit cooler water LOCA isolation interlocks with keylock switches.
o Verifies closed drywell unit cooler in let valves March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS Sim Booth Operator: After exiting EOP-Failure to Scram and re-entering EOP-RPV control AND a level and pressure band has been established - Initiate TRG 8 for the next event Station Blackout.
EVENT 9 4% 10 - Loss of Offsite Power with EDG Auto start failures, increasing drywell leak, Trip of B RHR pump Loss of NPS-SWGOOI and 003.
Loss of all Feed Recirc pumps trip CRD pump trips Circ Water pumps trip Loss of all AC except Div 111 Diesel 0
Restores CCP to drywell by opening containment isolation valves.
o Restores CCP to drywell unit coolers by opening drywell unit cooler inlet valves.
o Overrides drywell unit cooler fan interlocks with keylock switches.
o Restarts drywell Unit cooler Fans (all).
CREW PO-I 2.0 0
Recognizes and reports Loss of Power.
Recognizes SOP and EOP-entry Conditions.
NRC 2008 Scenario 4 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 9 & 10 SRO Actions EVENT 9 & 10 SRO Actions (cont)
EVENT 9 BOP Actions EVENT 9 & 10 BOP Actions (cont)
Sim Booth: Once the EDGs are started and Directs Entry to SOP-3 for Loss of AC Directs start attempt of the EDGs from the control room CT-2.0 Updates crew on EOP-RPV entry.
Directs level control using RCIC.
Directs pressure control using S RVs Directs entry into EOP-PC as appropriate.
Directs suppression chamber spray be initiated before exceeding 10 psig suppression chamber pressure.
BOP 8
NRC 2008 Scenario 4 Attempts to start the EDGs 1 and 111 as per SOP-3 Detail A instructions:
Checks listed annunciators Places EDG control switch to Start Verifies voltage and frequency Places Synch Switch to ON Closes output breaker Verifies bus voltage of 41 60V Places Synch Switch to Off March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS the safety buses powered up, activate Trigger 13. This will increase the severity of the drywell leak o Informs SRO of successful start and load of EDGs CT-2.0 Once EDGs are started, Controls RPV pressure with SRVs - 800 -
1000 psig Places RHR A(B) in suppression chamber sprays as follows.
Opens SWP*MOVSOA(B) -
may be delayed until after spray are in service as follows:
Verifies RHR pump A(B) running.
Verifies RHS*MOV24A(B) overridden closed.
Opens RHS*MOV33B to establish SC spray flow.
Opens RHS*FV38A(B) and establish approximately 7450 gpm-if suppression pool cooling is required.
Throttles open SWP*MOV33A(B) to establish flow not to exceed 7400 gpm.
May be required to start dhservice Water pump (post-LOCA).
Closes RHS*MOV8A(B) - after 10 minute time delay from ECCS initiation signal.
NRC 2008 Scenario 4 March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS EVENT 10 - Drywell Spray required, RHR pump A trip EVENT 10 - RO/ BOP actions Sim Booth: When operator places A RHR in Drywell Spray, initiate Trigger 15 to trip RHR pump A NOTE: The Ay RHR pump will trip requiring B RHR pump and loop to be placed in Drywell Spray NRC 2008 Scenario 4 o Directs RP to place SWP*RE23A(B) in service.
SRO Directs DW spray when SP Pressure is > I O psig Verifies DW spray conditions are met.
Directs RCS Pumps tripped.
Direct DRS Unit Coolers tripped.
Directs DW Spray IAW EOP-6, 2 prior to exceeding the PSP limit.
CT-3.0 RO/BOP When directed to place DW spray in service o Tripdverifies tripped RCS Pumps.
o Trips DRS Unit Coolers.
Places RHR in Drywell Spray prior to exceeding the Pressure Suppression pressure limit as follows:
CT-3.0 o Verifies an initiation signal present.
o Opens SWP*MOVSOA(B) -
May be delayed until after sprays are in service.
March 2008
INSTRUCTOR ACTIONS/
PLANT RESPONSE OPERATOR ACTIONS Termination Cue:
Containment pressure is decreasing and RPV level and pressure are being controlled.
0 0
0 0
0 0
0 0
0 0
0 Verifies RHR pump running.
Determines the A RHR pump tripped requiring B RHR pump and loop to be placed in Drywell Spray Verifies closed RHS*FV38 (B).
Verifies open RHS*MOV4 (B).
Opens RHSMOV25 (B).
Opens RHS*MOV15 (B).
Verifies RHS*MOV4 (B) closes.
Verifies approximately 7450 gpm on drywell spray header.
Closes RHS*MOV8 (B) after 10 minute time delay from receipt of initiation signal.
Contacts RP to start SWP*RE23A(B).
Throttles open SWP*MOV33 (B) to establish flow not to exceed 7400 gpm - may be required to start gfh service water pump (post LOCA).
0 Monitors for improving contain men t para meters NRC 2008 Scenario 4 March 2008
V.
POST SCENARIO CRITIQUE A. NA, NRC Exam VI.
REFERENCE EVENTS AND COMMITMENTS A. Reference Events None B. Commitments
- 1. None VII. LESSONS LEARNED NRC 2008 Scenario 4 March 2008
EVALUATED SCENARIO CHECKLIST X
X X
X
- 1.
Additional Information about these checks:
Realism/Credibility Event Sequencing Simulator Modeling Evaluating Crew Competencies
- 2.
7 2
For continuing training, can be found in NUREG 1021, ES 604 and Appendix D.
Total Malfunctions Malfunctions after EOP Entry For initial training, can be found in NUREG 1021, ES 301 and Appendix D.
5 1
2 Abnormal Events Major Transients EOPsUsed
- 3.
Quantitative Attributes 1
EOP Contingency Procedures Used Simulator Run Time 2
EOP Run Time Crew Critical Tasks (if applicable per Attachment 6.)
- 4.
Developmental Checks:
Does every event have either a Critical Task@) or Performance Objective?
Is Criteria given for sequencing to subsequent events?
Is termination criteria clear and unambiguous?
Does termination criteria allow verification that all CT, PO standards are met?
N2-SOP CONTROL ROD DRIVE FAILURES
. RPV pressure is 2900 psig NQ Two or more accumulators for withdrawn control rods are inoperable AND Charging water header pressure e940 psig for 20 minutes, RPV pressure IS e900 psig AND Any withdrawn control rod has an inoperable accumulator NQ Charging Water Header Pressure < 946 psig.
h EVENT DESCRIPTION See Section 1.0.
SCRAM the reactor per N2-SOP-IOIC IF Annunciator 602324, RWCU PUMP CLG WTR TEMP HIGH, is received.
An RDS pump can NOT be restored to service within 15 minutes ox indications of system breech exist.
c THEN Remove WCS from service as follows.
- 1. Throt?le WCS'MOV200 until in service filters on hold.
- 2. Trip WCS pumps.
Isolate RDS backfill by closing 2RDS-V20 (preferred) OR 2RDS-VZ058.
r operating?
Shift 2RDS-FC107 (RDS flow controller) to Manual.
- C!ose FCV tc minimum position.
Perform any or all of the following as required to restore charging water pressure:
Place standby pump in service per N2-OP-30, Section F.2.0.
Place standby discharge filter in service per N2-OP-30, Section F.3.0.
Place standby suction Riter in service per N2-OP-30, Section F.1.O.
Verify charging header integrity Verifv open ZRDS'V28.
valves are located on RB El.
215' in the RDS pump area.
2RDS-V20 is in the overhead between the RDS pumps 2RDS-V2058 is above the I
WHEN charging water header pressure has been restored above 940 psig, exit this procedure.
- 2. Place 2RDS-FC107 in Auto.
- 3. E WCS RPV backfill was removed from NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-30
N2-SOP LOSS OF STATOR WATER COOLING A Generator Runback is in progress, Reactor power has been reduced to minimum EVENT DESCRIPTION See Sec:ion 1.O.
m: Runback may be indicated by the following:
. Load set motor lowering TBVsopen Genera!or Auxiliaries Troub!e (851 112)
Cornp Pt GMCBC07. GEN PROT CKT ENERGIZED A
F Y
Reduce power per N2-SOP-1O1D to maintain TurSine Bypass Valves c!osed.
Start the standby GMC pump.
Lower Generator VARS to approx. 0.
IF Turbine has tripped.
c THEN Exit this SOP &Q recover GMC per N2-OP-26.
m: Turbine Trip occurs:
. 2 minutes after the runback is (Recirc flow approx. 55 mlbm) has NOT cleared, the runback I Trip the Turbine per N2-SOP-21 Dispatch personnel lo GMC skid to check local indications for possible cause.
A complete loss of GMC system has occurred.
I y
stcp?
Continue power redudion per NZ-SOP-101 D VNTlL ALL Ttirbine Bypass Valves are closed.
Verify proper operation of GMC system per N2-OP-26, Section F 1 0.
Determine cause 0: the iuGback the cause of the Generator Runback has been corrected:
Press the INCREASE pushbtitton on the LOAD SELECTOR approx. 1350 MWe is indicated on the LOAD SET METER.
Exit this procedure.
I NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMEER N2-SOP-68
N2-SOP LOSS OF AC POWER IF LOSS OF 2NPS-SWGOOl(OO3) AND/OR NNS-SWGOl4(015)
THEN f
EVENT DESCRIPTION
\\
A CRD pump was lost, A Recirc. pump was lost, A MSOP pump was lost, An IAS compressor was lost, A half scram occurred, I
See Section 1.0.
I Enter N2-SOP-30.
Enter N2-SOP-29.
Enter N2-SOP-68.
Enter N2-SOP-19.
Enter N2-SOP-97.
A total loss of condensate flow occurred, Close all 2CND-V13'AND 2CND-V18' valves.
Perform Attachment 1 Section 1.6 NINE MILE POINT NUCLE4R STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-03
N2-SOP LOSS OF AC POWER f
Notify the Shift Manager/Emergency Director to review EPIP-EPP-02 for classification of an emergency (See EALS.l) ti!axS:
bus that originally lost power has not See Secticln 1.O.
LOSS OF 2ENS*SWG101 AND/OR 2ENS*SWGl03 commencing re-opening.
- 2. Voltage - 4160V Frequency - 60 hz Yes No Attempt Div 1 and/or Div 2 Diesel remote start & load per N2-OP-100A Section F.4.0 4
SPECIAL OPERATING PROCEDURE Refer to Attachment 1, Additional Actions IF Div 3 diesel is running, shut it down (emergency SD PB at pnl 8152) either Div 1 y~ Div 1
Enter N2-SOP-01, Station Blackout I
No A
r 7
energized promptly Scram the reactor I
SWP:
division non-essentials closing/
f When DG on bus, verify:
Affected Div non-essentials close
. 1SWPpumpin affected Div starts 7
When SWP pump
- tarts
b Open all non-t Throttle 74's as essentials (Note 1) required 40kgpm I
If required. start a 3rd SWP pump in unaffected Div.
No SMED review EPIP-EPP-02 for emergency classification (See EAL 6.1) one division's non-essentials, and the other division's MOV 50, will not close.
IF headers are intact, these valves are not 74's. 50's and non-essentials are closing
. SWP valves to diesels 1SWPpump per Div starts
. Diesels have adequate SWP per SOP-101C Trip the following:
Main Turbine Recirc pumps WCS pumps
+
Dispatch an operator to the failed Diesel(s).
Perform N2-OP-100A Section H.13.0. Local Start and Loading Verify open MOV5OA & B If required, establish flow through unaffected div RHR HX Start an Start an additional Div 1 additional Div SWP pump 2 SWP pump 11 case of a LOCA OR Diesel failure:
Maintain system flow as required, and secure pumps until 1 pump is running in each Div powered from a diesel.
Throttle 74's to maintain <lOkgpm. Close non-essentials Start additional SWP pumps in unaffected Div Close MOVBOA & B
ATTACHMENT 9: ENERGIZING 2NNS-SWG015 (STUB BUS)
NOTE: The following steps are performed at Panel 852 UNLESS otherwise noted.
9.1 Prerequisites 9.1.1 PRIOR to executing the following steps, power must be available from one of the following sources:
0 2NPS-SWG003 (Attachment 7) 0 2ENS*SWG103 (Division I I Emergency Switchgear) (Attachment 8) 9.1.2 Section 1.6 Fault Identification and Isolation is complete.
9.1.3 Upon completion of Attachment 9, retum to Attachment 1 Section 1.7 as appropriate to restore power to the plant.
9.1.4 At Panel 804 (CB 288'), verify reset 86-2NNSY15 (4.16KV BUS NNS-015 PROTECTION LOCKOUT RELAY) 9.2 Enerqizinq 2NNS-SWG015 (Stub Bus) from 2NPS-SWG003 NIA, 2NNS-SWG015 will NOT be energized from 2NPS-SWG003
(-)
9.2.1 Verify closed 3-6.
9.2.2 Close 15-3.
9.2.3 Return to Attachment 1 Section 1.6.
9.3 Enerqizinq 2NNS-SWG015 (Stub Bus) from 2ENFSWG103 NIA, 2NNS-SWG015 will NOT be energized from 2ENS-SWG003
(-1 CAUTION Energizing 2NNS-SWG015 from 2ENS*SWG103 WHEN the Div II Diesel is supplying the bus is NOT permitted during a LOCA.
9.3.1 Place 15-3 in Pull-to-Lock.
Page 66 N2-SOP-03 Rev 07
ATTACHMENT 9: (Cont)
NOTE: The following 5 ?p requires a PA 2235 Key loc;,>d in the CSO's desk.
IF 2NNS-SWGO15 is needed for SBO recovery, THEN at Panel 852, place the Div I 1 LOCA SIGNAL BYPASS switch to ON.
Do NOT exceed the emergency diesel generator rating, 4400 KW (4840 KW 2 hour2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> limit)
WHEN re-energizing STUB Bus 2NNS-SWG015.
At 2ENS*SWG103 (CB 261'), verify reset 86-2ENSY12. (Breaker 103-8) 9.3.2 9.3.3 9.3.4 9.3.5 Close 103-8.
9.3.6 Close 15-8.
9.3.7 Return to Attachment 1 Section 1.6.
Page 67 N2-SOP-03 Rev 07
N2-SOP-I3 - LOSS OR DEGRADED CCP SYSTEM m:
Trip of WCS pumps may NOT be immediately required if the station is in Mode 4/5.
See Section 1.a.
IF THEN All CCP pumps have tripped N none can be re-started, SCRAM the Reactor per NZ-SOP-IOIC.
Trip BOTH Recirc pumps &Q enter N2-SOP-29.
Trip WCS pumps if required
\\that sy&ms loads will have adequate doling, I
+
until 1 main N 1 booster pump Perform Attachment 2 to restarl pumps.
Detail A - Major System Loads 9
WCS System Recirc Pump Cooling Drywell Cooling SFCHXs IAS Mini Loop HXs
. Equipment Drain Cooling RDS Pump Cooling Sam& Svstem Coolina f
I'"
Monitor system loads Secure loads as required, (Detail A)
A f IF THEN wcs must
- 1. Throttle WCS'MOVPOO be removed m service.
urtil the filters are in hold.
- 2. Trip WCS pump(s).
I--
Verify system operating per N2-Verify CCP-TIKlO8, RBCLC HEAT OP-13, F.I.O.
EXCHANGER TEMP CONTROLLER to AUTO Verify CCP-TVIOH local control restored to Auto per N2-OP-13, H.3.0.
I 1
7 Perform any of the following as required to stabilize the CCP system:
Place standby mainlbooster pump in service per N2-OP-13.
F.2.01F.4.0.
Place standby heat exchanger in service per N2-OP-13, F.7.0.
Place CCP-TIK108, RBCLC HEAT EXCHANGER TEMP CONTROLLER in MANUAL AND maintain CCP temperature 80 - 85°F.
Take local control of CCP-I W108 per N2-OP-13, H.3.0.
I NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-13
N2-SOP LOSS OF DRYWELL COOLING IF The Drywell Cooling Isolation lveS can be opened, See Section 1.0
\\I 11 L
Continue in Fans Only leg.
7 1I v
/
THEN Enter the Restore Cooling leg at becomes available, Monitor Drywell temperature.
- 1. Place W the following switches in OVERRIDE as necessarv to re-ooen isolated valves r
IF Drywell cooling can W be restored,
, Drywell pressure IS expected to exceed 1.68 psig, THEN Attempt to maintain drywell pressure per N2-OP-61A.
Evaluate Tech Spec 3.6.1.5, Drywell Temperature.
IF required, commence a normal plant shutdown.
Enter N2-SOP-1OIC. Reactor Scram.
This step defeats containment isolation signals. TS 3.3.6 1 &Q For 2CCP*MOV265/2CCP'MOV124 -
DRYWELL UNIT COOLER WTR DIV I LOCA OVERRIDE For 2CCP'MOV273/2CCP'MOV122 -
DRYWELL UNIT COOLER WTR DIV II LOCA OVERRIDE
- 2. Verify closed the CCP inlet isolation valves for ALL
- 3. As required, verify open the following:
Drywell Unit Coolers.
- 2CCPMOV265
- 2CCPMOV273
- 2CCPMOV122
- ZCCP'MOV124
- 4. Verify open the following:
- 2CCP-MOV3A B MOV3B
- 5. Verify DRS Unit Cooler Fans operating:
- 2DRS-UCIB 2DRS-UCIC
- ZDRS-UCID 2DRS-UC2A
- 2DRS-UC2B 2DRS-UC2C
- 1. Place the following in OVERRIDE as required:
- UNIT COOLER FANS GRI LOCA OVERRIDE
- UNIT COOLER FANS GR2 LOCA OVERRIDE
- 2. Verify DRS Unit Cooler Fans operating:
- 2DRS-UCIC 2DRS-UCID
- 2DRS-UC2A 2DRS-UC2B
- 2DRS-UC3A B UC3B conditions are corrected, verify the following:
- 1. DRS operating per N2-OP-60.
I 2. i?ll OVERRIDE switches have been restored.
I NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERAllNG PROCEDURE
'ROCEDURE IUMBER N2-SOP-60
N2-SOP-11 LOSS OR DEGRADED SWP SYSTEM IF Intake Bay level is LESS THAN 238 ft, Intake Bay level is
<ESS THAN 234 ft.
Trip of WCS pumps may be EVENT DESCRIPTION See Section 1.0.
immediately required if the station is in Mode 4/5.
THEN Verity open SWP"MOV30NB.
Verify open SWPMOV77AIB. J Lu!ILs:
EALs to Evaluate 8.4.3. Intake level
< 237 ft 8.4.7. Intake level
< 233 ft Evaluate Tech Spec 3.7 1 for Service Water and Ultimate Heat Sink.
IF THEN All SWP pumps have tripped A N none can be I
re-started.
SWP Non-Essential Headers are isolated AND can I be restored, SWP intake can NOT be restored above 233 ft.
maintained SCRAM the Reactor per NZ-SOP-101C.
Trip the Turbine per N2-SOP-21.
Trip BOTH Recirc pumps &Q enter N2-SOP-29.
Trip WCS pumps, if required.
1 IF THEN All 5\\12,? pumps have been tripped h r APPROX.
1 minute or less SWP pump flow is GREATER THAN 10,000 gpm, a pump is available, Additional SWP flow is required, Pump flow can NOT be maintained above low flow Start the available SWP pump.
Throttle SWP'MOV74s as required to maintain pump flow LESS THAN 10,000 gpm.
Start additional SWP pumps.
Throttle SWP flow through an RHR HX as required.
f f
IF I
THEN The SWP non-essential header iso!a!ion valves pump is available 1
I
- 1. Verify at least one SWP pump operating per division.
- 2. Verify open:
SWP'MOV50A SWP*MOV50B 3 Open Non-Essential Header iso!a!!on valve(s).
I 4. Start additional SWP pumps as required.
I 2SWP'MOV74A(C,E) 2SWP'MOV74B(D.F) 2EHS*MCC101-2B(2D.3B) 2EHSUCC301-2B(2D.3B) -
f IF THEN t is suspected that the
/stem is W longer full,
~~~~~~r I
E.l.O I Restore SWP flow as lollows:
- 1. Verify pumpistrainer are full by obseiving
- 2. De-energize SWP'MOW4 for the pump to
- 3. Verify the non-essential headers are
- 4. E restoring both divisions of SWP.
- 5. Station an operator to manually open
- 6. Start the SWP pump.
- 7. Throttle open SWP'MOV74 lo establish
- 8. Energize SWP'MOV74.
- 9. Start additional pumps per N2-OP-11.
strainer dp of 0.25 :o 0.5 psid.
be started.
isolated.
open SWP'MOV5CNB.
SWF"MOV74 for the pump to be started.
> 2000 gpm.
E.2.0.
Isolate the Turbine Bldg. SWP Header.
until intake level has been restored above c, 238 n.
~
NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE I
I Re-enter at e lo restore pumpslheaders.
'ROCEOURE IrMEER o2 lREVlSlON IUMBER NZ-SOP-11 NUMBER 02 I
N2-SOP-I 01 D = RAPID POWER REDUCTION EVENT DESCRIPTION Immediate Actions Shadowed See Section 1 0 1
f IF THEN MFLCPR is greater than 0.95, BFFORF power is lowered to < 75%, begin inserting the first four CRAM rods eBLaB to Flow, and perform concurrently 1
C Lower Reactor power by using liecirc flow CRAM rods.
I J
Determine Reac?or Rodline /QQ moni!o! core !herma! limits. '
As required, continue with N2-OP-l01C:(101 D,lOlA).
NOTE:
The following actions are typically performed for down power evolutions:
0 Update rodline notice a! panel ZCEC'PNL603.
0 Notify Central Regional Control (315-460-2421).
0 Notify Constellation dispatcher (410) 468-3750.
WE: If cram rods cannot be inseited due to equipment failures but power reduction below 75% is required, then attempt to maintain 112% (17 MWth) per minute power reduction, if possible, and immediately notify Rx Eng Verify clean steam reboiler auto transfer to Aux Steam.
Verify HVH steam supply auto transfer to Aux Steam.
Verify sufficient Cond D e m m In service per N2-OP-5.
P!ae HDL pumps in recirc per N2-OP-8, G.1.O.
NINE MILE POINT NUCLEAR STATION UNIT 2 I
SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER NZ-SOP-101 D
EVENT DESCRIPTION N2-SOP-IOIC -
(
See Section 1 0 IMMEDIATE AND The Reactor scram can be promptly reset (and remain reset),
Reset the scram.
i GENERAL ACTIONS IF THEN i T h e Reactor scram CANNOT be reset, Immediate Actions Shadowed Automatic Scram is anticipated PJQ time Mode switch is NOT in REFUEL position, Reduce Recirc Flow to 55 mlbrnihr per Place MODE Switcb to SHUTDOWN position.
- permits, NZ-SOP-lO1D.
Close ZRDS-VZE if directed by the SSSICRS. J Arm AND depress BOTH Manual Scram pushbuttons on either side of ZCEC'PNL603.
1 0 All rods full in I 0 Rx power lowering (c1) 1 U Turbine trippedlTSVs & TCVs shut I U Generator tripped and house loads 1
transferred I
, I U SDV V&D valves closed I
1 U RCS pumps downshift I 0 RPV pressure on TBVs C@ SRVs I U FWLC controlling level > 159.3" I
I I
I Verify automatic responses.
I I
I 1
r IF THEN All feedwater pumps have tripped, Place U 2FWS-LVlO and LV55 controllers to "manual" and varify the valves are full closed.
I I Reset the scram as follows:
' 1. Notify radwaste to operate all pumps for I
I 2. Place all four SDV high level bypass switches I 4 3. IF intiated, reset ARI per 112-0P-36B, H.3.0. I I
' 4. Using scram reset switches, reset the scram; I I 5. Reseat rods if necessary by applying insert I
I 6 Verify SDV vent and drair. valves open.
I I
I I
to BYPASS.
I I
verify all 8 pilot solenoid lights lit.
I i
signal.
I 1
Notify the Shift ManagedEnergency Director to review r--
EPIP-EPP-02 for classification of an emergency.
Continue with "Level Control" WHILE continuing, perform the following as time permits.
0 Fully insert IRMs @&I SRMs U Energize 2WCS-MOV107 (2NHSMCC008-2E) 0 If required, secure makeup t3 the Cooling Tower U At 2CEC-PNL842, shutdowr HWC r
IF WCS is in one pump three filter lineup, Outside temperature is 4 0 degrees, Continue with
'Pressure Control" THEN Throttle close ZWCS'MOVZOO (m if required, throttle open ZWCS-MOV110) to obtain approximately 225 gpm WCS flow.
- 1. If required, isolate the Reactor Building by placing ZHVR'AODlA (m
'AODlB) to close &Q verify the following:
Reactor Biiilding ventilation isolates GTSstarts
- 2. Perform N2-OP-52 actions for Reactor Building isolation (Sections H.l.O, H.5.0).
I NINE MILE WINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE REVISION INUMBER N2-SOP-1O1C l E % E R 02 INUMBER 03
N2-SOP-I 01 C - LEVEL CONTROL f
IF Feed pump restart is required.
Level CANNOT be maintained <250",
Level control is lost, I feedwater in auto (preferred) or manual.
I I
THEN Restart feed pump per Detail 1 Close ALL MSlVs AND open the following to maintain level ~255":
0 MSS'MOV207 U MSSMOVIII 0 MSS'MOVI 12 (2EHSMCC102-7A, 240 NAB)
Re-enteral As required, perform the following:
U Reset setpoint setdown per Detail 2.
U Reset PAM recorders.
0 Continue with NZ-OP-IOIC, Section G.3.0.
I I
I Reset Setpint Setdown I 1. Verify Rx level stable above I
I I
Level 3 (159.3").
- 12. Null FWS Master Controller by I I
rotating the thumbwheel until I I
the red process pointer is in I
IF required, place FWLC in single element.
- 1. Place FWLC in manual.
) 2. Place 1 ElemenV3 Element control swilch
- 3. If required, restore FWLC to auto.
in 1 Element.
Stabilize RPV level using of the following:
U Feed and Condensate 0 RCIC 0 CRD U HPCS thumbwheel tape setting has no effect until setpoint As required, per?orm the following io estabiish ordered ievel band:
U IF 2 feedpumps are running, trip one feedpump ("C preferred).
U As required, close the following valves:
n Close ZFWS-LVIONBIC.
- ZFWS-MOV47NBIC
. ZFWS-LV55NB
- ZFWS-V103AIB
- ZCNM-LV137
- 2ZIP-V10111 0 Establish WCS reject per N2-OP-37.
U Rese! Reactor scram per General Actions flowchart.
I r - - - - - - - _ - - - - - - - - - - _ _ - - - -
w FWS Pump Restart Detail 1 I I
I I
I I
running?
is unavailable.
I Is at least Condensate and 1 condensate pump
'3. Depress the SETPOINT I
I SETDOWN RESET I
I pushbutton AND confirm I
I amber light is extinguished.
1 i 4. Verify proper automatic control I I
in the desired band.
I 1
Venfy Ihe following:
0 Out of service condensate, boosler and feedpumps in PTL U 2 2 condensate pumps running.
0 2 2 booster pumps running U 2FWR-FV2s closed.
U The following controllers in manual with 0%
output.
. 2FWS-HlC1010~
~ 2FWS-HIC1600 3 IF required. reset Level 8 pushbuttons.
Star! feedwater pump as follows:
- 1. Confirm suction pressure > 500 psi.
- 2. Verify aux oil pump running.
- 3. Place pump switch lo red flag.
- 4. WHENZFWS-FVZAIBIC - 15% open, confirm pump start.
- 5. Confirm flow - 8000 gpm.
- 6. Inject with 2FWS-LV55NB (open ZFWS-VIO3NB if required)
I I
I I
I I
I I
I I
I I
- 8. For automatic control, refer to N2-OP-3. H.9.12 H.9.13.
I I
- 9. Verify aux oil pump stops.
I OR verify open 2WS-MOV47AIBK ZFWS-LVlONB/C as required.
inject with
- 7. IF required, reset setpoint setdown per N2-OP-3, H.1.0.
NINE MILE POINT NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-1OlC
N2-SOP-101C - PRESSURE CONTROL IF Pressure control is lost, MSlVs are closed &Q the Main Condenser is available,
\\
!I THEN 3
Re-enteral 9 N2-OP-1, Section H.4.0 &Q use the Main Condenser to control pressure.
desired, re-open the MSlVs per L
Control pressure (cooldown rate) within the ordered band using any of the following:
Main Condenser using TBVs o Use EHC pressure set 4E1 bypass valve opening jack.
Initiate condenser neck spray by opening 2CNM-MOV126.
o SRVs RClC Steam Condensing.
1s required to control cooldown rate, perform le following:
Close ZMSS-P,OV87AIB/C/O and AOV88NB.
rn E time permits, swap gland sea to main steam per N2-OP-25, Section F 2 0 OR H.3.0.
Close 2ASS-MOV152.
v Start ZARC-PlA(B) as follows:
- 1. Confirm no fuel damage.
- 2. Close 2ARC-AOV104.
- 3. Place in AUTO 2ARC-AOV105.
- 4. Open 2SWP-HV98A(B).
- 5. Start ZARC-PlA(B).
- 6. Veri$j proper operation per N2-OP-9.
Section F.1.1.
Close ZASS-AOV148.
Fast close outboard MSIVs. (C3,4,5,6,9)
Y t
pressure control is stable 4E1 appropriate cooldown rate has been established, IH&J continue.
control actions per N2-OP-IClC, G.3.0.
NINE MILE P O l M NUCLEAR STATION UNIT 2 SPECIAL OPERATING PROCEDURE PROCEDURE NUMBER N2-SOP-1O1C