ML041070251
| ML041070251 | |
| Person / Time | |
|---|---|
| Site: | Surry  |
| Issue date: | 02/19/2004 |
| From: | NRC/RGN-II |
| To: | |
| References | |
| 50-280/04-301, 50-281/04-301 | |
| Download: ML041070251 (91) | |
See also: IR 05000281/2004301
Text
Final Su
SURRY EXAM
50-280, 50-281E2004-301
-
FEBRUARY 24 MARCH 2
& MARCH 4,2004 (WRITTEN)
IS ES-
Appendix 13 Required Operator Actions Form ES-ID-2
Op-Test No.: 2004-301 Scenario No.: 1 Page 2 of 23
EvcntNo.: 1
Event Description: Loss of Component Cooling Water to NRHX requiring letdown to be
secured.
I
j BOP I Verifies letdown diverted.
I
- Closes 1-CH-LCV-1460A.
- Closes 1-CK-LCV-144OB.
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2084-301 Scenario No.: 1 Page 3 of 23
Event No.: 2
Event Description: Place Excess Iztdown in service.
I 1 BOP Opens 1-CH-HGV-1201 Excess Letdown HX Isolation. (Step
15.1.15)
I
I I
BOP Records charging flow. (Step 5.1.16)
I I
BOP Places 1-CH-HCV-1389 to VCT position. (Step 5.1.21)
Appendix D Required Operator Actions
Op-Test NO.: 2004-301 Scenario No.: 1
EventNo.: 3
Event Description: Median Selcct Tave fails high.
-
Time Position Applicant's Actions or Behavior
BOP Acknowledges annunciator 1H-IZ7, STM BUMP VV TRIP OPEN.
~~
BOP Acknowledges annunciator 1H-A4, Tave - Tref BEVIATIOK.
RO Acknowledges annunciator 1C-D8, PRZR LO LVL.
RQ Places rod control in MANUAL to stop rod motion.
RO Verifies Charging Flow Control in MANUAL and zero demand
from previous event.
RO/BOP Reviews annunciators.
~~~~ ~
SRO Reviews Tech Specs and identifies no applicable limiting actions.
SWO Notifies E&C of failure.
SRO Notifies OMOC of failures and unit conditions.
TEAM Discusses plant operation with Steam Dumps with trip open
demand, MFRVs with no trip close criteria at 554 "F, and operation
with rods and charging flow control in MANUAL.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 1 Page 5 of 23
EventNo.: 4
Event Description: 1A Steam Generator Level Transmitter fails low. Ramped to allow
adequate operator response to gain control of S 6 level prior to trip on steam / feed
mismatch.
1 feedwater flow, and FW heater oscillations.
Reviews ARPs.
Action 20, and 3.7.3#3 Operator Action 20. 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> to place
I
SRO Notifies QMOC.
Appendix D Required Operator Actions Fsrm ES-D-2
Op-Test No.: 2004-301 Scenario No.: 1 Page 6 of 23
Event No.: 5
Event Description: Pressurizer Pressure Controller (PC-4444 / Channel 1) fails high.
Ramped to allow adequate operator response to gain control of pressure. Failure of
PRZR MSTR Controller in AUTO.
Time Position Applicant's Actions or Behavior
RQ Diagnose high failure of either PZR Pressure Transmitter PT-444 or
Master Controller.
Alarms:
- IC-Ag, P U R PRESS CONTR HI OLTPUT
- lC-B8, PRZR LO PRESS
- ID-H4, PRZR STY VV PWR RELIEF VV OPEN
- IC-DS, PRZW PWR RELIEF LIhJ HT TEMP
- IC-FT, PRZW RELIEF TANK HI PRESS
Indications:
- MCB meter for PT-444 reads maximum pressure
- PRZR Master Controller goes to maximum output
- PRZR Spray valvcs go full open
- PORV 1455C opens
- Actual RCS pressure as indicated by MCB for ET-445
loweri11g rapidly
RQ Takcs actions IAW ARP 1C-AS (Note: actions taken for any other
ARP will delay actions necessary to avoid a Rx Trip or SI).
- Attempts to place M a t e r Controller in MANUAL.
- Identifies Master Controller will not transfer to MANUAL.
- Verify closed or close 1-RC-PCV-1455C.
- Places PRZR spray valve controllers in MANUAL.
- Closes both PRZR spray valves.
SRO Directs WO to control pressure IAW 1-AP-31.OO. Should note that
1-WC-PCV-1455Cis inoperable while control is in manual. SRO
should review TS 3.1.6. (TS 3.1.6.a states that with a PQRV
inoperable but capable of k i n g manually cycled, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />
either restore to operable or close the block valve and maintain
power to the block valve.) SIP0 should review TS 3.12.F if PRZR
pressure decreases < 2205 psig. (TS 3.12.F states restore the
parameter to within its limits within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.)
Appendix La Required Operator Actions Form ES-D-2
@-Test NQ.: 2004-301 Scenario No.: B Page 7 QP 23
7
Time Position Applicants Actions or Behavior
Maintains RCS pressure IAW I-AP-3 1 .OO
Check RCS pressure lowering
Attempts to place 1-CH-PC-14445in MANUAL.
Identifies that 1-CH-PC-14445will not transfer out of
I
AUTO.
Close or verify closed PRZR PORVs
Close Block Valve to isolate a PORV that will not close.
Turn on pressurizer heaters.
Close or verify closed 1-CH-HCV-1311, Aux Spray
Isolation.
Check AUXSpray Line for leakage. (None should be
detected.)
Place spray valve controllers in MANUAL and adjust
demand to zero.
Check Turbine load stable.
Provide notifications co OMQC, STA, and Shift Supervisor.
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 SCeIfdriQNo.: 1 Page S of 23
Event No.: 6
Event Description: 16=Steam Generator tube leak with failure of Condenser Air Ejector
Rad Monitor auto actions. Slowly ramp leak until Condenser Air Ejector Monitor
alarms.
Time Position Applicant's Actions or Behavior
BOP Diagnose IC Steam Generator Tube I ~ a as k evidenced by
Condenser Air Ejector alarm.
Alarms:
- 1A-A3, N l 6 HIGH
- lA-B3, N16 ALERT
- IC-BS, PIPZR LO PRESS
- 1-RM-G8, CONDENSER AIR EJECTOR
.L\LERT/FAILURE
- 1-RM-HS, 1-SV-RI-111 KIGH
Indications:
- Upscale on 1-SV-RI-111
- UgscaIe on 1-RM-RR-15QBPen 4
I IJnit2 Verifies alarm reading greater than background or radiation level
has trended up by reading 1-SV-RI-111 or 1-RM-RR-150B Pen 4.
Checks PCS points using Group 80 Review:
- RlRM20SC, MS-RI-124
- RlRM2056, MS-RI-I25
- R1RM206C, MS-RI-I26
Unit 2 Monitor SG Blowdown Monitors:
- 1-SS-RI-112
- 1-SS-RI-113
Directs verification of automatic actions associated with Condenser
Air Ejector alarm.
AP-16.00, Excessive RCS Leakage
Directs compensatory aceions or physical positioning of TV-SV-
102 and TV-SV-103 per AWP 1-RM-NS.
Reposition TV-SV-102 and TV-SV-103 per .4RP I-RM-WE;.
Appendix D Kepired Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: 1 Page 9 of 23
.- - Time Position Applicants Actions or Behavior
PRZR level lowering (slight)
Annunciator 1B-E5, CHG FP TO REGEN H3Dc HI-LO FLOW
A discernable negative change in VCT level trend has developed.
Note: At this point, these indications will be inconclusive due to
small magnitude of leak.
SR8 Directs the following:
- Performance of 0-OSP-RC-002, Steam Generator Primluy
to Secondary Leakage Monitoring.
- Pedommse of I-OPT-RC-IO.Q,Reacror Coolant Leakage
- Computer Calculated.
- AP-ltiMI Step 3: Verify closed or close normal and excess
letdown isolations:
1-CH-LCV-1460A
1-CH-LCV- 1460B
1-RC-HCV-1557A
- 1-RC-HCV-B557B
- I-RC-HCV-1557C
. - - 1-RH-HCV-1142
- AP-16.00 Step 4: Verify PRZR level, PRZR pressure, and
RCS subcooling stable or rising. (Ideally they will be stable
or rising, but if they are not applicants may choose to
manually trip reactor and proceed to E-0 at this point).
- AP-16.00 Step 6: Verify adequate makeup being supplied
by blender and Leak Rate 9 50 gpm. (VCT level w ~ lbe l
going down and Leak Rate will be 9 50 gpm. This is
another criteria for Rx Trip).
- AP-16.00 Step 7: Aiign Charging Pump Suction to the
RWST:
- Open 1-CH-MOV-1115B
- Open 1 -CN-MOV- 1 115B
Close 1-CW-MBV-1115C
Close 1-CH-MOV-1115E
- Manual Reactor Trip. Proceed to E-Q.
Appendix D Required Operator Actions Form ES-D-2
Bp-Test No.: 2804-301 Scenario No.: B Page BO of 23
Event No.: 7 &k8
Event Description: 1C Steam Generator tube rupture coincident with Loss of Offsite
Power. #I EDG fails to auto start, requiring manual start from the Control Room.
Time Position Applicants Actions or Behavior
All Diagnose requirements to trip Reactor. (Also see the previous
event, which will Iead into this Event.)
AlarNiS:
- ID-E5, CHG PP TO REGEN HX HI-LO FLOW
Indications (Pretrip):
- PRZR pressure and level lowering
- Tavg stable
- Charging line flow rising
indications (Post-trip):
- Rx trips on OIFBT or Low PRZR Pressure
- Turbine trip by Rx Trip
- Rx trip and bypass breakers open
- Rod bottom lights are lit
- Generator trip 30 seconds after Rx trip
- All AFW pumps start
- WP & LP Heater Drain Pumps trip
- Safety Injection on bw PRZR pressure
- Phase 1 isolation
All Diagnose Loss of Offsite Power. This malfunction should be
kiggered by Reactor Trip.
Alms:
- 1K-H4,4 KV EMERG BUS TIE STUB BUS BKR TRIP
- 1K-G6,4 KV RES BUS SUP BKR OPEN
- 1K-E7, CC PPS DISCH HDR LO PRESS
- O-VSP-A3, DIESEL FIRE PUMP .4UTO START
Indications:
- Breakers 15A1,15B1. 15CI, 15B1, 15EB, 15FI, 15A2,
15B2, and 15C2 all open.
- EDG 3 auto starts and energizes the emergency bus.
- Emergency stub bus breakers open
- All station service loads are de-energized
- RCPstrip
- cc Pumps trip
Appendix D Required Operator Actions Form ES-D-2
Qp-Test No.: 2QO4-301 Scenario No.: 1 Page 11 of23
Time Position Applicant's Actions or Behavior
RO Verify Reactor Trip (Ea, Step 1 - Immediate Action Step)
- Manually trip Keactor
- Check all rod bottom lights lit
- Check Reactor Trip and Bypass Breakers open
- Check neutron flux lowering
BOP Verify Turbine Trip ( E O , Step 2 - Immediate Action Step)
- Manually trip Turbine
- Verify all Turtpine Stop Valves closed
- Close MSR S t e m Supply I-MS-SOV-104
- Verify Generator Output Breaker Open (30 sec time
delay)
BOP Verify both Emergency AC Buses energized (E-0, Step 3 -
Immediate Action Step)
SRQ EDG #3 did not auto start. EDG must be manually started from
the Control Room. SRO should direct 1-AP-10.07. Loss of Unit 1
Power, to restore power to the AC Emergency Bus.
BOP/SRO Verify both 4160 V Emergency Buses energized. (1-AP-10.07,
Step 2 ) - J Bus will not be energized. RNO directs operators to
Att. 1.
BOWSRO If any EDG has failed to start, then: (1-AP-10.07, Att. 1. Step 2 )
Put EDG #3 in EXERCISE
Start EDG #3
Place EDG #3 in AUTO
If EDG fails to load, then check status of annunciator IK-
G4,4KV EMERG BUS EMEKG SUP BKR AUTO TRP.
Identifies 1K-G4 is NOT lit and manually load EDG ~
Turn SYNC-ACB-1533 key switch to ON.
Verify or establish generator voltage by momentarily
depressing the E m K G GEN NO 3 Field Plash
pushbutton.
Raise INCOMING voltage to 120 volts using EMERG
GEN NO 3 VOLT AB5 control switch.
Identifies EhEERG SUP Breaker 1533 did not close.
Verify open NORM SUP Breaker 1558.
Closes EMERG S U P Breaker 15J3.
Identifies 1J EMERG Bus re-energizes.
Turn the SYNC Key Switch for 1SJ3 to OFF.
BOP/SKO If either Emergency Bus energizes and both of the following
damners are not open. then initiate Att. 10: (1-AP-10.07. SteD 6)
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2003-301 Scenario No.: 1 Page 12 of 23
i me Position Applicants Actions or Behavior
- l-VS-MOD-103B
- 1-VS-MQD-103D
Aft. 10 contains instructions for battery room ventilation. Local
actions to open slide dampers, Battery Room 1A door, and
estabtish a fire watch.
SRQ Return to procedure step in effect. (I-AP-10.07. Att. 1, Step 8 )
SRO Check if SI initiated. (E-Q.Step 4 - Immediate Action Step)
Directs manual initiation of SI after Reactor Trip. Expect SWO
brief.
ROBQP Manually initiates SI and verifies 1A-F3 and IA-F4 annunciators
lit. (E-Q.Step 4 - Immediate Action Step)
BQP Venfy Feedwater isolation. (E-0, Step 5)
- Feed Pump Discharge MOVs closed (l-W-MOV-150A
closed & B is de-energized open)
- M W Pumps tripped
- Feed Reg Valves closed
- SG FW bypass flow demand at zero
- SG Blowdown TVs closed
RO Verify CTMT Isolation Phase I. (E-0, Step 6)
- Phase I TVs closed
- 1-CH-MOV-1381 closed
- B-SV-TV-102A closed
- PAM isolation 1-DA-TV-103A closed
- PAM isolation B-DA-TV-IO3B closed
BOP Verify MW pumps running. (E-0, Step 7)
- MD AFW Pumps (time delayed) A running & B de-
energized
- T D AFW Pump (if necessary)
May discuss isolating APW to 1C SG with SRO at this time.
RQ Verify SI Pumps running. (E-0, Step 8)
- CHG Pumps running (A lockout, Cmnning & B
de-energized with breaker closed)
- LHSI Pumps running (A running & 73 de-energized
with breaker closed)
RO Check Charging Pump Auxiliaries. (E-e), Step 9)
- CHG Pump CC Pump (X running & B de-enerpized)
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: I Page 13 of 23
Position Applicants Actions or Behavior
- GHG Pump SW Pump (A running & B de-energized)
BOP Check Intake Canal level > 24 feet and being not being
maintained by CW Pumps. (E-0, Step 10)
- Initiate 0-AP-12.01, Loss of Intake Canal Level
- Direct Unit 2 to initiate AP-12.01
BOP Check Main Steam Line Isolation required. (E-0. Step B 1)
- Check if any s f the following annunciators have been lit.
E-F-IO, KI STEAM FLOW SI - (should be off)
B-C-4, HI HI CLS TRAIN A - (should be off)
B-C-5, HI HI CLS TRAIN B - (should be Off)
Check if CTMT Spray required (E-14, Step 12)
(CTMT Pressure should be near pre-event lev& - RNO directs
operators to Step 13)
Verify SH flow: (E-@Step 13)
- EEISI to Cold L C ~>S 0 gpm:
- 1-SI-E-1961
1-SI-H-1962
- 1-SI-Fa-2963
- 1-SI-FT-1943 or 1943A
- Check one or two CHG Pumps running
- Check RCS pressure > 185 psig (should be > 185 psig)
- Reset SI
- Stop one LHSI Pump and place in AUTO (if two are
mnning)
Verify total AFW flow > 350 gpm (E-8, Step 14)
Check A N MOVs open (IC SG may require manual alignment)
(E-14, Step 15)
- Identifies J ENIERG Bus MOVs de-energized.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: I Page 14 of 23
RO/SRO Verify SI Valve Alignment LAWr Att. 2 (E-0, Step 16)
- Verify open or open CHG Pump Suction from RWST
MOVS
1-CH-MOV- 1115B
1-CH-MQV-1115D (de-energized closed)
- Verify closed or close CHG Pump Suction from VCT
1-CH-MOV-1115c
- 1-CH-MOV-l I15E (de-energized opened)
- Verify closed or close CHG Line Isolation MOVs
1-CH-MOV-1289A
1-CH-MOV- 1289B (de-energized opened)
- Verify closed or close Letdown orifice isolation valvcs
1-CH-HCV- 1200A
B -@PI-HCV-1200B
1-CH-HCV- 1200C
- Verify open or open EMS1 to cold legs MOVs
- 1-SI-MOV- 1867C
1-SI-MBV-1867D (de-energized closed)
- Verify open or open LHSH suction from RWST MOVs
1-SI-MBV- 1862A
- 1-SI-MOV-1862B (de-energized opened)
- Verify open or open LHSI BO cold legs MOVs
1-SI-MOV-1864A
- 1-SI-MOV-18643 (de-energized opened)
BOP Verify ventilation alignment and A@ power alignment IAW
Attachment 3 (E-0, Step 17) (E-(9,Att. 3 is attached)
- Only one switch to be manipulated on the Ventilation Panel)
WO/SRO Zheck RCS Avg Temp stable or trending toward 547 v. (E-(9,
Step 18)
[f < 547 OF, then stop dumping steam and reduce AFW flow if SG
Levels permit (SG Levels > 12% in ab least one SG). If soaldown
- ontinues, then close MSTVs.
[f > 547 OF, then dump steam via Atmosphe.rics (LOSP -
- ondenser not available)
Appendix I) Required Operator Actions Form ES-D-2
RO/SRO Check PRZR PORVs and Spray Valves: (E-0, Step 19)
- PRZR PQRVs closed
- PRZR Spray controls at zero demand (Spray valves
closed)
A4tIeast one PORV Block Valve open.
RQ/SRQ Check RCP Trip and Miniflow Recirc Criteria (E-0, Step 20)
- HHSI flow to Cold Legs > 0 gpm
- RCS Subcooling < 30 ?;
- RGS pressure e 1275 psig
- If RCS Pressure e 1275 psig then close GHG Pump
miniflow recirc valves (I-CH-MOV-1275A & B & C>
BQP/SRQ Check SG Not Faulted: (E-0, Step 21)
- Pressure in all SGs stable or rising
- Pressure in all SGs > 100 psig
BQP/SRQ Check SG Tubes ruptured: (E-e), Step 22)
- Condenser air ejector radiation =. normal
- SG Blowdown Radiation > noma1
- SG MS Radiation > normal
- TD AFW Pump exhaust noma1
- 16 SG level increasing in an uncontrolled manner
SWO Directs transition to E-3, Steam Generator Tube Rupture. (E-Q,
Step 22)
RO/SRO Check RCP Trip and Miniflow Recarc Criteria (E-3, Step 1)
- HHSI Wow to Cold Legs > 0 gpm
- RCS Subcooling e 30 T
- RCS pressure e 1275 psig
- If RCS Pressure e 1275 psig then close CHG Pump
miniflow recirc valves (I-CH-MBV-1275.4 & B & C)
TEAM Identifies ruptured IC SG (E-3, Step 2)
- Level rise
- SG Main Steam Line Monitor high
- SG Blowdown monitor high
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario KO.: 1 Page 14 of 23
. . . . .. . . . . .... . . . .... . . .. . . . .
Isolate IC SG (E-3, Step 3 - Clr;ii$#d
- Adjust 16 SG PORV controller to 1035 psig
- Verify IC SG Blowdown TVs closed
- Directs local closure of 1-MS-158 (1C supply to TD Al3V
Pump)
- Close 1C SG MSTV
[solation of IC SG prior to exiting E-3 is a critical task.
Check ruptured SG Level 9 12% ( 5 3 , Step 4)
FIow to IC SG must be maintained until level 9 12%.
When level > 1276, A W flow to IC SG shall be stopped.
Check PZRZ PORVs and Block Valves (E-3, Step 5 )
- Check power available to Block Valves
- Check PRZR PORVs closed
- Ensure at least otic PRZR PORV Block Valve open
Check if SG not faulted. (E-3, Step 6)
- Check pressure stable or rising in all SGs
- Check pressure 9 100 psig in all SGs
Check IA & 1B (intact) SG levels (E-3, Step 7)
- Any NR SG Level 912%
- Check emergency buses both energized (RNO should not
need to be performed if bus was restored by manually
starting #3 EDG earlier in scenario. However, local
isolation of A m header on J Bus may be necessary if J
Bus not energized. 1-FW-140 / 155 / 170)
- Control AFW flow to maintain 22 to SO% in IA & 1B
SGS
Reset both trains of SI (E-3, Step 8)
BOP Verify Instrument Air Available (E-3. Step 10)
- Check Annunciator IB-E6 lit.
- Initiate Attachment 2 to restore 1 .4
- Check no C T W Instrument Air Compressor mnnings.
- Locally crosstie to turbine BIdg IA
- Verify I-IA-TV-100 close and manually align valves.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 1 Page 17 of 23
Align Condenser Air Ejector to CTMT (E-3, Step 11)
- Venfy 1-SV-TV-102 open
- Verify 1-SV-TV-103clssed
- Open I-SV-TV-102A
Verify alE AC buses energized by offsite power. (This will not be
the case. EDGs will be powering buses). (E-3, Step 12)
Direct implementation of I-AP-10.09, Loss of Unit 1 Power (if
not already implemented). (E-3, Step 12)
Check if LHSI Pumps should be stopped. (E-3, Step 13)
- Check RCS pressure > 258 psig
- Stop LHSI Pumps and place in AUTO.
BOP Check IC SG isolated from 1B and 1A SGs (E-3, Step 14)
- Check IC SG pressure > 350 pig.
BOP/SRO Initiate RCS Cooldown (E-3, Step IS)
- Determine required core exit temperature (ONE T M ) :
- Lowest Ruptured SG P (psig) CETG (F)
1001 - 1085 495
902 - 1000 485
801 - 900 470
701 - 800 455
601 - 700 440
501 - 600 420
401 - 500 400
350 - 400 385
- Place Steam Dump Mode Select Switch in Steam Pressure
Mode.
- Cooldown at maximum rate using Steam Dumps (if
condenser vacuum available or use A & BBSG
PQRVs.
- Do not manually open 6SG PORV (Critical Task).
- Check CETCs less than required temperature
- Stop cooldown
- Maintain CETCs less than required temperature
rhis step should be completed prior to depressurizing.
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: 1 Page 18 of 23
BQPlSRQ Check ruptured SG pressure stablc or rising (E-3. Step 16)
WO Check RCS subcooling based on CETCs 9 50 "F
RO Depressurize RCS to minimize break flow and refill PRZR (E-3
Step 18)
- Check normal spray available and RCPs -4& C running
(normal sprays will not be available and RCPs will be of0
- RNQ directs to Step 19
SCENARIO C O M P E T E ONCE RCS IS DEPRESSmEZEW.
RQ Depressurize WCS using PMZW PORV to minimize break flow
and refill PRZR. E-'3.Step 19)
- Check at least one PRZR PORV available
- Qpcn one PRZR PORV until any of the following
conditions exist:
PRZR Level > 69%
- RCS Subcooling based on GIETCs < 30 "n;
- PRZR Level 9 22% & WCS P < IC SG P
- Close P U R PQRV
Appendix D Required Operator Actions Farm ES-D-2
Qp-Test No.: 2004-301 Scenario No.: 1 Page 19 of 23
Simulator Setup
Initial Conditions:
e Recall IC for 75% Rx Power.
1. Enter the following MALFUNCTIONS:
2. Enter the following OVEIPRDES:
3. On MONITOR, recall PRIMARY2 variables
4. Verify the following control room setup: NOPE
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2804-,301 Scenario No.: 1 Page 20 of 23
SWIFT TURNOVER
Initial Conditions:
- '75% Re3ctor Power.
- Known Heakage of 1 gpd in IA S t e m Generator.
- Thunderstoms are approaching from the West.
Turnover:
Shift orders are to maintain power at 75%.
ondenser Vacuum
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: B Page 21 of 23
Session Conduct
0 Ensure conditions in Simulator Setup arc established.
Event No.: 1
Initiate Trigger #I to insert Malfunction CC-04, Loss of CG to NRHX. Role play the
following:
0 If the team dispatches the Auxiliary Bldg Operator, wait 18 minutes and inform the team
that 1-CC-TCV-103 is closed and air signal to open on TCV diaphragm if demand is
present from controller.
0 If the team informs I & C Maintenance, role-playing gathering procedures and prints to
formulate a Troubleshooting Plan.
0 If SRO notifies Shift Manager, role-play as necessary to allow SRQ to perform a plant
status update following the event.
Event No.: 2
Role-play as necessary to assist the team in placing Excess Letdown in service IAW l a p -
Event No.: 3
Initiate Trigger #3 to insert Malfunction RC-08, Median Select Tave fails high. Role play
the following:
If the team informs I & C Maintenance, role-playing gathering procedures and prints to
formulate a Troubleshooting Pian.
0 If SRQ notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
status update following the event.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2084-301 Scenario No.: 1 Page 22 of 23
Event No.: 4
Initiate Trigger #4 to insert Malfunction FW-13, A SG Level Transmittcr fails low. Role
piay the following:
0 If the team informs I & C Maintenance, role-playing gathenng procedures and prints to
fornulabe a Troubleshooting Plan.
a If SRO notifies Shift Manager, role-play as necessary to allow SRQ to perfom a plant
status update following the event.
Event No.: 5
Initiate Trigger #S to insert Malfunction RC-15, PRZR Pressure Controller fails high. Role
play the following:
0 If the team informs I&C Maintenance, role-playing gathering procedures and prints to
formulate a Troubleshooting Plan.
a If SRQ notifies Shift Manager, robplay as necessary to allow SRQ to perform a plant
status update following the event.
Event No.: 6
Initiate Trigger #6 to insert Malfunction Rc-24, c SG Tube Rupture with a failure of
Condenser Air Ejector RM automatic actions. Role play the f~llowing:
0 If the team informs I&C Maintenance, role-playing gathering procedures and prints to
formulate a Troubleshooting Plan.
If SRQ notifies Shift Manager: role-play as necessary to allow SRO to perform a plant
status update following the event.
0 If SRO notifies HB Supervisor, role-play as necessary to allow SRQ to pe.rfom a plant
status update following the event.
0 If team directs the Service Bldg Operator, role play to isolate C SS IAW procedure
using P&ID or MOhqTOR variables as dkcted by team members.
Appendix D Required Operator Actions Farm ES-D-2
Op-Test No-: 2004-301 Scenario No.: 1 23 Qf 23
Event No.: 7
Trigger #7 will activate on the Rx Trip and insert Malfunction EL-Oi. Loss of Off-Site
Power (LOOP) with a failure of #3 #EBG to automat~callystart requiring local actions.
Role play the following:
0 If team notifies Unit 2 Reactor Ohperator, role-play as necessary to identify #3 EDG is
not loaded on 25 Emergency Bus and Unit 2 is responding to Rx Trip with LOOP with
only 2H Emergency Bus energized.
If team directs local actions in response to the SGTR with LQOP, perform directcd
actions by utilizing P&HD and MONlTOR variables with appropriate time delays.
status update following the event.
If SRO notifies HP Supervisor, role-play as necessary to allow SRO to perfom a plant
status update following the event.
0 If team directs the Service Bldg Operator, role play to isdate c SG L4W procedure
using P&IQ or MOhVOR variables as directed by team members.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 2 Page 2 of 21
Event No.: 1
Description: Bearing Cooling Water Pump trips and standby pump fails to auto start.
Time I Position Applicant's Actions or Behavior
I Acknowledges 1B-G2, BC HDR LO Pressure.
Acknowledges 1K-D4,4KV BKR ALTO TRIP.
Identifies loss of 1-BC-P-1B and failure of 1-BC-P-1A to automatically start
on low system pressure.
Manually starts I-BC-P-1A.
Verifies running amps on 1-BC-P-1A and BC system low pressure alarm
clears.
Performs focus brief on the failure and actions in progress.
Directs BOP to dispatch Service BLDG operator to 1-BC-P-1B's breaker
B5C8.
Directs RO to dispatch Turbine BLDG operator to locally investigate
conditions rat BC pumps.
Place control switch for 1-BG-B-1B in PTL position.
Direct Electracal Maintenance to investigate breaker 15C8.
Notifies Shift Manager and direct initiation of Work Order.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 2 Page 3 of 21
Event No.: 2
Event Deseription: Letdown Divert Valve fails open
Time Position Applicants Actions or Behavior
RO Identifies normal make-up in progress to VCT.
RO Identifies 1-CH-LCV-ll1SA diverted to PDT.
RO Identifies I-CH-LCV-11 1SA controller demand at 100% for unknown
reason.
RO May utilize ARP 1D-GI, VCT HI-LO LVL for guidance based on normal
make-up flow ability to maintain VCT level.
Direct RO to place I-CH-LCV-1115A controller in Manual and reduce
demand to align l-CK-LCV-1115A to VCT position or place control switch
for I-CH-LCV-11158 in NORM position.
RO Perfoms the directed action to align 1-CH-LCV-11154 back to VCT.
SWO Performs a focus brief on the failure and actions in progress.
SRO Directs I Csr C Maintenance to investigate the failure of 1-CH-LCV-I 11SA
controller.
SRO Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form E5-D-2
Op-Test No.: 2804-301 Scenario No.: 2 Page 4 of 21
Event No.: 3
Event Description: Selected 1 Stage Turbine Pressure Transmitter fails low
Position 4pplicant's Actions or Behavior
BOP Acknowledges annunciator 1H-A4, Tavg > Tref DEVIATION.
BOP Acknowledges annunciator BH-H7, STM D W VV TRIP OPEN.
BOP Identifies control rods are stepping due to 1 Stage Turbine Pressure
Channel 3 Transmitter failure low.
SRO Directs RO to place control rods in Manual.
RO/ROP PIaces control rods in Manual to stop the rod motion.
BOP Identifies Main FXVs are reducing SG levels to the no load setpoint based
on Channel 3 failure.
Reviews annunciator response procedures for remaining dams.
SRO Reviews Tech Specs Section 3.7 and identifies TS Table 3.7-1 items 20 b RL
20c requiring Operator Action #13, one-hour clock to verify permissives
status. In addition, identifies TS Table 3.7-2 item l e and TS Table 3.7-3
item 2a requiring Operator Action #20,72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> clock to place channel in
trip.
SWO Performs focus brief on failure and actions in progress. Discuss plant
impact with Stm Dump trip open signal and Main FRVs due to failure.
SRO Notifies H & C Maintenance to place channel in trip.
SRO Directs RQ to perfom 1-OPT-RP-001, CHECK OF PERMISSIVE
STATUS LICGTS P-6, P-7, P-8, AND P-IO, to verify permissive status
lights are correctly illuminated. (Only P-7 must be completed to comply
with TS.)
RO Perfoms l-OPT-RP-QOI, CHECK OF PERAISSIVESTATUS EIGHTS P-
6, P-7, P-8, AND P-10 and reports results of completed OPT to SRO.
(Only P-7 must be completed to comply with TS.)
Appendix D Required Operator Actions Form ES-D-2
Bg-Test No.: 2004-301 Scenario Nu.: 2 Page 5 of 21
Event No.: 3
Event Description: Selected Ist Stage Turbine Pressure Transmitter fails low
RP-OOI, ALIGNING CQNTROL SYSTEM FOR PERFORMANCE OF
CHANNEL I, II, IIl,AND EV PROCESS AND PROTEGTlQN TESTING.
this procedure will not be completed before proceeding to next event.
Appendix r) Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Sceaario No.: 2 Page 6 of 21
Event NO.: 4
Event Description: Pressurizer Level Controller fails low
Applicants Actions or Behavior
Acknowledges annuciator 1C-D8, PKkR LO LVL.
Identifies CHG flow reduction.
Identifies CHG flow controller output demand at 0%.
Directs RO to take manual control of CHG f l and~ return CHC flow to
normal.
Takes CXG flow controller to MANUAL and increases CHG flow to
normal.
Notifies h&C Maintenance to investigate the failure.
Perfom focus brief on failure and actions in progress.
Kotifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form E?-D-2
Op-Test No.: 200.4-301 Scenario No.: 2 Page 7 of 21
Event No.: 5
nit f d s low
Applicants Actions or Behavior
Identifies failure of Median Select Tavg low.
Reviews annunciators.
Notifies IRrC Maintenance to investigate the failure.
Notifies Shift Manager and STA of faillure.
Perform focus brief on failure and actions in progress.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004301 Scenario No.: 2 Page 8 of 21
Event No.: 6
Event Description: Seiected 1B Steam Generator Steam Flow Transmitter fails high
Position Applicants Actions or Behavior
BOP Acknowledges annunciators associated with the SG levels and high
feedwater Kow.
TEAM Identifies B SG Steam Flow channel failed high (1-MS-FI-1484).
SRO Direct BOP to place B Main FRV in Manual and restore B SG level.
BOP Takes manual control of 3 Main FRV and reduces feedwater flow to
restore level.
TEAM Performs focus brief on failure and actions in progress.
SRO Reviews Tech Specs Section 3.49 and identifies TS Table 3.7-1 items 17
requiring Operator Action #6; identifies TS Table 3.7-2 item l e and TS
Table 3.7-3 item 2a requiring Qperator Action #20, 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> clock to place
channel in trip.
SRO Notifies 1& C Maintenance to place channel in trip.
TEAM May elect to swap controlling Steam Flow channel to I\ for B SG in
accordance with lH-G6, STM GEN 1B LVL ERROR
- Return level to program
- Select redundant channel
- When level retirrned to normal, then place FRV in AUTO.
SRO Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Kequirecl Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 2 Page 9 of 21
Event No.: 7
Event Description: Turbine Governor Valve fails closed. Ramp in slow enough for
BOP to detect and respond.
OR AUTO DEFEAT < 50%.
OR AUTO DEFEAT < 50%jii.
Appendix D Required [)perator Actions Form &IS-D-2
Qp-Test No.: 2004-301 Scenario No.: 2 Page 10 of 21
Event No.: 8,9, 10, & 11
Event Description: LBLOCA - Auto Reactor Trip, Turbine fails to trip, Generator
Output breakers fail to open, and both trains of Safety Injection fail to automatically
actuate. Manual actuation from the control room is necessary.
Position Applicants Actions QE=Behavior
RO Acknowledges annunciators.
RO Identifies decreasing RCS Pressure.
..............................................................................................................._ .................
RO Identifies aiitoimxic Rcactor Trip and iriitiatcs I-E-0 Immediate Actiims.
SRO Directs performance of 1-E-0 lnmmediate Actions.
BOP Acknowledges annunciators while R 8 perfoms I-E-0 Immediate Actions.
RWSRO Verifies Reactor Trip (E-0, Step 1 - Immedaate Action Step)
- Manually trip Reactor
- Check all Rods On Bottom Light lit
- Check Reactor Trip and Bypass Breakers open
- Check Neutron flux lowering
Verify Turbine Trip (E-0, Step 2 - hmediate Action Step)
RO/SRO - Identify that Turbine failed to automatically trip
(Event 9 - Manually trip the turbine by pressing both Trip Pushbuttons
& 10) - Identify all Turbine Stop Valves close
- Close MSR Steam Supply 1-MS-SOV-104
- Identifies that Generator Output Breaker Failed to open after 30
second time delay.
- Manually open output breakers and place Excitation control switch
in om.
- ~~~~ ~
RO/SRO Verify both Emergency AC Buses energized (E-Q,Step 3 - Immediate
Action Step)
-
RO/SRO Check if SI is actuated. (E-0, Step 4 - Immediate Action Step)
..... (Event 11) - Identify that SI faiied to automatic
- Manually actuate both trains of SI
- Verify LHSI pumps rirnning
- Verify SI annunciators lit
I A-F-3
- A-F-4
Appendix D Required Operator Actions Form ES-D-2
@-Test No.: 2004-301 Scenario No.: 2 Page 11 of 21
Position 4pplicant's Actions or Behavior
BQP/SRO Verify F W Isolation. (E-0, Step 5)
- Feed pump discharge MQVs closed (1-H;W-MOV-lSOA & B)
- MiW pumps tripped
- Feed Reg valves closed
- SG F W &pass Wow demand at zero
ROISRO Verify CTMT Isolation Phase 1. (E-0, Step 6 )
- Phase I TVs closed
- 1-CH-MOV-1381 closed
- 1-SV-TV-102A c l o ~ d
- PAM Isolation valves 1-BA-TV-103A closed
- PAM Isolation valves 1-DA-TV-103A closed
BQPISRQ Verify AFW pumps Running. (E-0, Step 7)
- MD AFW Pumps running (time delayed)
- TD Pump running (time delayed)
RQ//SRQ Verify SI Pumps Running. (5-0, Step 8)
- CHG Pumps running
- LHSI Pumps running
WO/SRO Verify CHG Pump Auxiliaries. (E-0, Step 9)
- CHG Pump CC Pump running
- CHG Pump SW Pump running
WBISRQ Zheck Intake Canal. (E-0. Step 10)
- Level > 24 m
- Level being maintained by CW Pumps
BQWSRO 2heck if Main Steamlines should be isolated. (E-0, Step 1I)
- Check if any of the following annunciators have been lit.
- E-F-IO, HI STEAM FLOW SI - (should be off)
- B-C-4, HI Ht CLS TRAIN A - (should be on)
- B-C-5, HI HI CLS TRAm B - (should be on)
- Check MSTVs closed
- Check either of the following actuated
- HI Steam flow SI - (should be no)
- Header to line SI - (should be yes)
- Verify RWST crosstie valves open
- 1-SI-TV-I02A & E9 open
- 2-SI-TV-202A & Eo open
- Check RCS pressure < 185 PSIG - (should be yes)
Appendix D Required Operator Actions Form ES-D-2
Op-Test NQ.: 2004-301 Scenario No.: 2 Page 12 O f 21
Position Applicants Actions or Behavior
RQ/SRO Check if CTMT Spray Required. (E-0, Step 12)
- CTMT pressure has exceeded 23 psia
- Manually initiate Hi Hi CLS
- TripaliRCPs
- Verify CS pumps running
- Check ISRS pumps running (Time Belayed)
- Check OSRS pumps running (Time Belayed)
- Initiate Attachment 1, CL.5 Gomponent Verification
SRORO Low PRZR pressure SI signal should be blocked when PRZR pressure
5ecreases < 2000 psig
- Blocks Low P U R pressure SI signal by using block switches
High steam flow SI signal should be blocked when Tave decreases <
543°F
- Blocks High stcam flow SI signal by using the block switches
33.3 pumps should be r u m in the foliowing order of priority: C , B, A
RO/SRO Verify SI F ~ w( 5. 0 , Step 1 3 )
- HHSI to cold legs flow indicated
- H -SI-R-1961
- 1-SI-F;%-1962
- 1-SI-FI- 1963
- I-SI-Fi-1943 or 19438
- Check three CHG Pumps running
- Reset SI
- Stop one CHG Pump and place in AUTO
- Check RCS pressure < 185 psig (should be < 185 p i g )
- Identify LHSI flow indicatcd.
BOP/SWO Verify Total AFW flow 9 350 gpm [450 gpm]. (E-0, Step 14)
BQP/SRO Check AFW MOVs open. (E-0: Step 15)
RO/SRQ Verify SI VaBve Aiignment IAW Att. 2. (E-@,Step 16)
- Verify open CHG Pumps Suction from RWST MOVs
- 1 -CH-MOV-1115B
- l-CH-MOV-1115D
- Verify closed CNG Pump Suction from VCT MOVs
- I-CH-MQV- 1 115C
- 1-CH-MOV-I 115E
- Verify closed CHG Line Isolation MQVs
- 1-CH-MOV-1289A
- 1-CH-MOV-1289B
Appendix n Required Operator Actions Form ES-D-2
Op-Test No.: 2804301 Scenario No.: 2 Page 13 of 21
Position Applicant's Actions or Behavior
. .
RO/SRB Verify SI Valve Alignment IAW Att. 2. (E-0, Step 16) CONTINUED
- Verify open HHSI to cold legs MOVs
- l-SI-MOV-1867C
- 1-SI-MOV-1867B
- Verify open EHSI suction from WWST MOVs
- I-SI-MOV-IX62A
- 1-SI-MOV- 1862B
- Verify open LHSI to cold legs MOVs
- 1-SI-MQV-1864A
- 1-SI-MOV-1864B
Unit 2 Verify ventilation alignment and AC power alignment IAW Attachment 3
OPR (E-0, Step 17) (E-0, Att. 3 is attached)
(Only one switch to be manipulated on the Ventilation Panel)
RO/SRQ Check RCS Avg Temp stable or trending towards 547°F. (E-0, Step 18)
- Identify < 549°F
- Identify not dumping steam and control total feed flow. Maintain >
350 gpm [450 gpm] until NR level > 12% [ 18%]in at least one SG.
- Identify MSTVs closed
RO/SRO Check PRZW PORVs and Spray Valves: (E-0, Step 19)
- PRZR PORVs closed
.. - ..
- PRZR Spray controls at zero demand (Spray valves closed)
- At least one PBWV Block Valve open
RQ/SRO Check RCP Tnp and Miniflow Recirc Criteria. ( E a , Step 2Q)
- "SI flow to Cold legs indicated
- RCS Subcooling < 30°F [WF]
- Stop all RCPS
- Identify RCS pressure < 1275psig j1475 p i g ]
- Close CHG Pump miniflow m i r e valves (l-CH-MOV-l275A, 3, & C)
BOP//SRO Check SG Kot Faulted. (E-0, Step 21)
- Pressures in all SGs stable for plant conditions
- Pressures in all SGs > 100 psig
BOP//SRQ Check SG Tube ruptured. ( E O , Step 22)
- Condenser air ejector radiation - normal
I SG Blowdown radiation - normal
- SG MS radiation - normal
- TD AEW Pump exhaust - normal
Appendix D Required Qperator Actions Form ES-I)-2
Op-Test No.: 2004-301 Scenario No.: 2 Page 14 of 21
Time Position Appticant's Actions or Behavior
ROISRQ Check RCS Intact Inside CTMT. (E-0, Step 23)
- CTMT radiation > normal
- CTMT pressure > noma[
SRO Directs transition to E-1, Loss of Rcactor or Secondary Coolant
STA Identify Red Path on CSF Status F-4 Integrity requiring transition to EX-
P. 1
SRO Directs transition to FR-P. 1 Response to Immincnt Pressurized Thermal
~
Shock
ROiSRO Check RCS Pressure > 1x5 psig [250 psig]. (FR-P~l,Step 1)
- Identify RCS Pressure < 185 psig [250 psig]
- Identify LHSI pump Wow > 1000 gpm
- RETLXN TO procedure and step in effect.
SRQ Directs transition to E- 1, Loss of Reactor or Secondary Coolant
ROiSRO Check RCP Trip and Miniflow Recirc Criteria. (El, Step 1)
- "SI flow to Cold legs indicated
- RCS Subcooling < 30°F [8S°F]
.. .
- Identify all RCPs stopped
- Identify RCS pressure < 127Spsig [I475 p i g ]
- Identify CHG Pump miniflow recirc valves (1-CH-MOV-l275A, B, &
C) closed
Check SG Not Faulted. (E-1, Step 2 )
- Pressures in all SCs stable for plant conditions
- Pressures in all SGs > 180 psig
Check Intact SG Levels. ( 5 1 , Step 3)
- NR Bevel > 12% [IS%]
- Check emergency buses both energized
- Control feed flow to maintain NR level between 22% and 50%
Check SG Tube ruptured. (E- 1, Step 4)
- Condenser air ejector radiation - normal
- SG Blowdown radiation - normal
- SG MS radiation - normal
- ID A m Pump exhaust - normal
- SG NR level not increasing in an uncontrolled manner
Appendix I) Required Operator Actions Form ES-D-2
Op-TC?StNO.: 200.1-301 Scenario No.: 2 Page 15 of 21
Position Applicant's Actions or Behavior
WO/SRO If any PWZR PORV opens because of high PRZR pressure, the PORV
must-be verified close2 or isolated after pressure &creases to less than
2335 psig. (E-1, Caution prior to Step 5)
ROISRO Check PRZR PORVs and Block Valves. (E-I, Step 5)
- Power to PRZR PORV block valves available
- PRZR PORVs closed
- PRZR PORV block valve at least one open
KOiSRO Check If SI Flow should be reduced. (E-1, Step 6)
- RCS Subcooling based on CETCs < 30°F [85"F]
- GOTOStep7
RO/SRO Check If Hi Hi C U Initiated. ( E l . Step 7)
- Identify RS Pumps running
- Identify Hi Hi CLS annunciators lit
RO/SRO Verify Service Water Available. ( E l , Step 8)
- Check Intake Canal level k i n g maintained by CW Pumps
- GOTOStep 12
RO/SRO Check If CTMT Depressurization Equipment can be stopped. (E-8, Step
12)
- CTMT pressure < 12 psia
- Reset both trains of CLS
- Stop OSRS Purnp(s) and put in AUTO
- Stop CS Pump(s) and put in AUTO
- Close CS Discharge valves
- I-CS-MOV-lO1A
- I -CS-MOV-10113
- 1-CS-MBV-1016
- 1-CS-MOV-1O1B
- Close CHEM ADD TK OUTLT valves
- 1-CS-MBV-102A
- 1-CS-MBV-IO2B
- Operate ISRS Pumps with SW aligned to maintain CTMT pressure
between 10 psia and 13 psia
~
SCENARIO CQMPLETES ONCE CS PUMPS SECURED.
Op-Test No.: 2004-301 Scenario No.: 2 Page 16 of 21
Sirnulatapr Setup
Initial Conditions:
0 Recall IC for 3% Rx Power.
1. Enter the following MALWCTIONS:
....
1
...ii...-..i.-.-.-.....~-.. j..i.L..
1
2
3
4
5 0 1 -I
6
7
2. Enter the following OVERRIDES:
..............................
Op-Test No.: 2004-301 Scenario No.: 2 Page 17 of21
3. On MONITOR, recall PRIMARY2 variables and verify 'IDLY29 and TDLYSO are
-..
both set to X O ~ o .
4. Verify the following control room setup: Piace 1-EH-P-MP2 in PTL and a red
magnetic above the control switch.
Op-Test No.: 2004-301 Scenario No.: 2 Page 18 of 21
SHIFT TLXNOVER
Initial Condithns:
0 5Q%Reactor Power.
0 Known leakage of 1 gpd in A Steam Generator.
0 Thunderstorms a e approaching from the West.
0 I-EH-P-MP-2 ( E X Pump) is tagged out of service for thermal overbad replacement
Turnover:
Shift orders are to maintin power at 50%.
Qg-l'est NO.: 2004-301 Scenario NO.: 2 Page 19 of21
Session Conduct
- Ensure conditions in Simulator Setup are established.
Event No.: 1
Initiate Trigger #1 to insert Malfunction BC-01, BC Pump trips on overcurrent. Role play
the following:
- If the team dispatches the Turbine Bldg Operator, wait 5 minutes and inform the team
that 1-BC-P-1.4 running normally and no indications why 1-BC-P-IB tripped.
- If the team dispatches the Service Bldg Operator, w i t a couple of minutes then inform
the team that breaker for 1-BC-P-1B tripped on overcurrent on "A" phase (15CX).
- If the team informs Eiectricai Maintenance, role-play to investigate the breaker then
return to the shop to formulate a Troubleshooting Plan.
status update following the event.
Event No.: 2
Initiate Trigger #2 to insert Malfunction CK-19, Letdown Dsvert Valve fails open. Role
play the foilowing:
- If the team dispatches the Auxiliary Bldg Operator, wait 10 minutes and inform the team
that no indications locally why letdown diverted.
- If the team informs I Clr C Maintenance, role-play to investigate the controller and
formulate a Troubleshooting Plan.
status update following the event.
Event No.: 3
Initiate Trigger #3 to insert Malfunction MS-14, Selected 1 Stage Turbine Pressure
Transmitter fails low. Role play the following:
- If the team informs I & C Maintenance, role-play gathering procedures to place the
channcl in trip and to formulate a Troubleshooting Plan.
Qp-Test No.: 2004301 Scenario No.: 2 Page SO of 2 I
0 If SRQ notifies Shift Manager, role-play as necessary to allow SKO to perfom a plant
status update foliowing the event.
Event No.: 4
Initiate Trigger #4 to insert Malfunction RC-17, PFZK Level Controller fails low. Role
play the following:
0 If the team informs I B C Maintenance, role-play gathering procedures and pijnts to
investigate the failure and to formulate a Troubleshooting Plan.
If sKo notifies Shift Manager, role-play as necess,uy to d o w SRO to perform a plant
status update following the event.
Event No.: 5
If Control Rods are in AUTO, then initiate Trigger #5 to insert Malfiinction RC-(48, Tavg
Taylor Math Unit fails high. Role play the following:
0 If the team informs I&G Maintenance, roie-play gathering procedures and prints to
formulate a Troubleshooting Plan.
0 If SRQ notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
status update following the event.
Event NO.:6
Initiate Trigger #6 to insert Malfunction MS-08, "E!" SG Steam Plow Transmitter fails high.
Role play the following:
0 If the team informs I & C Maintenance, role-play gathering prcwxhres to place the
channel in trip and formulating a Troubleshooting Plan.
0 If SRQ notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
status update following the event.
@-Test No.: 2004-301 Scenario No.: 2 Page 21 of 21
Event NO.: 7
Initiate Trigger #7 to insert Malfunction TU-03, Turbine Governor Valve fails close. Role
play the following:
0 If the team dispatches Turbine Bldg Operator to investigate wait about 5 minutes and
inform that there are no nndications why the GV #I failed closed.
0 If' the team informs IgiC Maintenance, role-play gathering procedures and prints to
investigate and formulate a Troubleshooting Plan.
0 If SRO notifies Shift Manager, role-play as necessary to allow SRO to perform a pkant
status update following the event.
Event NO.: 8
Initiate Trigger #8 to insert Malfunction RC-01, LBLQCA with a failure of turbine to
automatically trip, generator output breakers fail to open, and both SI trains fail to actuate.
Role play the foIlowing:
0 If team notifies Unit 2 Reactor Operator, role-play as necessary to initiate AP-S0.00 and
acknowledges the wR.g alarms.
0 If team directs local actions in response to the LBLOCA. perfom directed actions by
utilizing P&D and MONITOR variables with appropriate time delays.
0 If SRO notifies Shift Manager, role-play as necessary to alIow SRO to perform a plant
status update following the event.
0 If SRO notifies HP Supervisor, roie-play as necessary to allow SRO to perform a plant
status update following the event.
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: 3 Pag@2 of 24
Event No.: 1
Event Description: Raise power. (Rods initially sho~ildbe positioned to prompt
dilution. as opposed to rod pull)
Position Applicants Actions or Behavior
TEAM Conduct brief for raising powcr in accordance with l-OP-TM-OOS, Unit
Ramping Operations
TEAM Review I-OP-TM-OOS, Section 5.3, Preparations for Turbine Ramp Up.
- Identifies that last shift completed Section 5.3
TEAM Review I-OP-TM-005, Section 5.4, Power Increase Between SO% and
100% Reactor Power.
- Identifies that last shift completed Section 5.4 up to step 5.4.12
- Continue the power escalation to 90 to 91 percent power.
SRO/BcBP Commence the power increase at the ramp rate spccified by Shift Manager
- Recall the Shift Manager directed setting of 6 on the Load Rate
Thumbwheel.
- Using the Load Rate c/o per Min thumbwheel, rotate until setting of 6
is displayed.
- Initiate power increase by depressing the GO pushbutton
SRORO Initiate dilution and use control rods as required to maintain A 0 in band.
- Observe the expected response on
- FR-1-113,BA-PRI WTR Flow
- YlC-1148, PRI WTR SUP BATCH Integrator
SRO/RO Identify that A 0 is high in the band, so dilution would be preferred prior to
outward rod motion.
RO Initiate dilution
Appendix D Required Operator Actions Form E$-D-2
Op-Test No.: 2004-381 Scenario No.: 3 Page 3 of 24
Event No.: 2
Event Description: FT-CH-B 114, Primary Water Flow XMTR hails low.
Applicants Actions or Behavior
Identifies normal dilution to YCT stops and investigates why no PG flow
indicated.
Acknowledges annunciator 1D-A4, PRI WTR TO BLEND DEVIATIOh
FLOW
Directs BOP to stop; the ramp to stabilize plant conditions based on the
failure.
Stop the turbine ramp by deprcssing the KQLD pushbutton.
Rcviews annunciator alarm response 1D-A4, PRI WTR TO BLEND
DEVIATION FLOW.
May rcset the blender controls back to AUTO.
Performs a focus brief on the failure and actions in progress.
Directs 1 & C Maintenance to investigate the failwe.
Notifies Shift Manager and STA of failure and actions in progress.
.
Appendix D Required Operator Actions Form DS-D-2
Op-Test No.: 2004-301 Scenario No.: 3 Page 4 of 24
Event No.: 3
Event Description: 1-CN-P-1.4, Condensate Pump Performance Degradation ramped in
to require timely operator response. Failure of standby pump auto starl. Manual start
required.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-381 Scenario No.: 3 Page 5 of 24
Event No.: 4
. .
Event Description: Selected 1A Steam Generator h4F.V Flow Transmitter fails Iow
Time Position Applicants Actions or Behavior
BOP Acknowledges annunciators associated with the SG levels and feedwater
flow.
TEAM Identifies A SG Steam Cxnerator MFW channel f i l e d low (1-FW-FF-
1477).
SRO Direct BOP to place 6A49Main FWV in Manual and restore A SG levei.
BOP Takes manual control of A Main FRV and reduces feedwater flow to
restore level.
TEAM Performs focus brief on failure and actions in progress.
SRO Reviews Tech Specs Section 3.7 and identifies TS Table 3.9-1 item 17
requiring Operator Action #6 to place the channel in trip in 7 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
SRO Notifies I & C Maintenance to place channel in trip.
TEAM May elect to swap controlling MFW Flow channel to IV for A SG in
accordance with 1H-GS, STM GEN 1A LVL ERROR
- Return level to program
- Select redundant channel
- When levei returned to normal, then place FXV in AUTO.
SRO Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form ES-D-2
Qp-Te~tNO.: 2004-301 Scenario No.: 3 Page 6 of 24
Event No.: 5
Event Description: 1A SG PORV Controller fails high
Applicants Actions or Behavior
Informs control room of steam blowing from top of Unit 1 Safeguards.
Identifies A SG PORV is open and controller output is at IcBO%.
Directs BOP to take manual control of A SG PQRV.
Takes A SG PORV controller to MANCAL and closes the valve.
Wotifies HP that a steam release occurred from the A SG with known
primary to secondary leakage of B gpd.
Notifies I&C Maintenance to investigate the f d u r e .
Perform focus brief on failure and actions in progress.
Kotifies Shift Manager and STA of failure and actions in progress.
. .
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 3 Page 7 of 24
Event No.: 6
Event Description: Isolable letdown line leak in containment.
- Position
Time Applicants Actions or Behavior
RQ Acknowledges annunciator IB-A3. CTMT S U M P HI LEVEE.
RO Identifies increasing CTMT Sump level with CTMT Sump pump running
in auto.
TEAM Implements AP-16.00, EXCESSIVE RCS LEAUGE.
Rcp Identifies LTDN flow at zero.
SRO If SI Accumulators are isolated. I-AP-16.81, SHIJTDQWN LQCA should
be used for guidance. RCS average temperature has a direct impact on
pressurizer level. (M16.00. Notes prior to Step 1)
Increase CHG flow using 1-CH-FCV-1122in manual to maintain PRZR
level at program setpoint, as necessary. (AP-16.00. Step 1)
- Identifies PRZR level at setpoint
SRORO Check WCS leak rate. (AP-16.00. Step 2)
- PRZR level decreasing (should not be)
- Annunciator D-3-5 lit (should not be)
- GOTOStep 12
SRORO Check WCS leak rate 10 gpm. (AP-16.00, Step 12)
- Initiate unit shutdown IAW GOP (Unless leak previously isohted).
- Control CHG flow and seal injection to maintain PRZR level
- Evaluate E P P applicability
SRORQ Check IJnit Conditions stable. CAP-16.00, Step 13)
- PRZR level (should be)
- PRZR pressure (should be)
- Tave (should be)
Check Letdown leak indicated. (AP-16.00, Step 14)
- Identifies annunciator 1B-A3, C T W Sump Hi Lvl lit
Appendix Id Required Operator Actions Form ES-D-2
Op-Test NO.: 2804-301 Scenario No.: 3 Page 8 of 24
Applicants Actions or Behavior
Verify Closed or close Letdown Isolations. (AP-16.00, Step 15)
- 1-CH-LCV- 146QA
- I-CH-LCV-1460B
- 1-WC-WCV-l557A, B, & C
- I-RH-HCV-1142
TEAM Perfom focus brief on failure and actions in progress.
SRORO Check RCS leak rate with letdown secured reduced. (AP-16.00, Step 16)
- Identifies letdown leak stopped following securing letdown isolations
SROiRO Place intact Letdown System in service IAW Shift Supervisor direction.
(AP-16.00, Step 17)
- Place Excess letdown IAW 1-OP-CH-006
- Revicws precautions and limitations
- Verify all of the following Loop Drain header isolation valves are
closed.
- 1-RC-HCV-1557A, 3, & C (shodd be)
- Verify I-CH-HCV-1201, Excess LDTN HX ISQL valve is
closed (should be)
- Verify 1-CH-HIC-I 137, Excess LDTN Flow setpoint is zero
(should be)
- Verify I-CH-HCV-1389, Exccss LBTW Divert is in the VCT
(should be)
- Verify open 1-CH-MBV-1381, RCP Seal Return (should be)
- Verify running at least one CC Pump (should be)
- Verify ET-CC-109, EXCESS LDTN HX Outlet CC Flow is
indicating 148 gpm (should be)
- Notes the reset switch located on the RHR flats must be held in
the open position until 1-CC-HCV-108 opens fully.
- Verify TI-CC-188, EXCESS LDTN HX Outlet CC temp is
indicating ambient. (should be)
- Verify 1-CM-PI-1138, Excess LDTN HX Outlet pressure is
indicating = 50 pisg (should be)
- Verify I-CH-TI-B139, Excess LDTN HX Outlet temp is
indicating ambient. (should be)
- Notes the first 50 galluns of Excess LDTN flow should be
directed to the PDTT so that the Excess LDTN flow is not
returned to the RCS.
- Places 1-CH-HCV-1389Excess LDTN Divert valve to the PDTT
position to flush the Excess LDTN HX
Appendix I) Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: 3 Page 9 of 24
Position Applicant's Actions or Behavior
SROwiO Place Excess letdown IAW 1-OP-CH-006(Continued)
- Verify 1-CH-PI-1138, Excess LDTN HX Outlet pressure
indicates = BO psig (should be)
- Open 1-CH-HCV-1201, Excess LDTN HX Is01
- Verify l-CH-I;I-l122A, CHG Line flow is stable and record the
flow (should be zero)
- Reviews caution about potential leak points downstream of the
loop drain valves
- Review caution about only one loop drain valve may he open
above 200"F, to prevent the possibility of bypassing SI flow to
the two intact loops in a DBA, due to Eoop cross-connect through
the drain header.
- Open one Loop Drain header isolation valve 1-RC-HCV-1557A
or B or C
- Notes Excess LDTN flow rate can be calculated by using I-DG-
LI-103, PDTT level (2.5% level changes is 15 gallons
- Notes Attachment 1 may be used to lower PRZW level if required
- Slowly open 1-CH-HCV-1137,Excess LI9TN Flow using 1-CH-
MC-I137 until = 15 gpm flow is established to the PDTT
- Verify TI-CC-108, EXCESS I D T N HX Qutlet CC temp
indicates < 150°F
- Verify 1-CH-TI-1139, Excess kDTN HX Outlet temp indicates <
195°F
- When the PBTT level has increased at least 10% as indicated on
I -D@-L1-107,then transfer flow from the PDTT to the VCT by
placing l-CW-HCV-I380 to the VCT position.
- Verify that there is no change in the recorded RCP Controlled
Leak Off flow by checking 1-CH-FR-1190
- Verify 1-CH-PI-1138 indicates 65 psig
50 TO Step 31 (AP-16.00, Step 18)
Check WCS leak rate. (AP-16.00, Step 31)
- Unidentified leakage iess than I gpm (should he)
- Stabilize unit conditions
Perform RCS Icak rate
Evaluate SOUKC of leakage. Unit operation may C Q R t I n U e if none of the
Foliowing exists. (AP-16.00, Step 3'2)
- A non-isolable fault in an RCS component body, pipe well, vessel wail,
or pipe weld
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 3 Page 10 of 24
Applicants Actions or Behavior
Reviews Tech Spec 3.1.C, identifies RCS leakage > 1 gpm unidentified
requiring identification within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> of leak detection or the reactor shall
be brought to WSD within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> (TS clock exited when letdown
isolated).
Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 3 Page 11 of 24
Event No.: 7, 8,9, & 10
Event Description: Main Steam Line Break in Containment in 1A Steam Generator.
A~to and Manual Reactor Trips fails along with faiiure of AMSAC. FruIure of one Hi
CLS Train fails to activate. Failure of 1-CC-TV-10% (CCW return from RCP 1A) to
close ora Phase JJI Isolation.
Position Applicants Actions or Behavior
KO Acknowledges amunicators.
RO Identifies decreasing RCS Pressure and Temperature with control rods
stepping out.
TEAM Identifies abnormal indications on A SG and inside C T W
RO Identifies failure of automatic Reactor Trip and initiates 1 -E-O I~nmediatc
Actions.
SRO Dieects perfonnance of 1-E0 Immediate Actions.
BOP Acknowledges annunciators while R 8 performs Immediate Actions.
SRORO Verifies Reactor Trip (E-0, Stcp 1 - Immediate Action Step)
- Attempts to manually trip Keactor
- Identifies failure of both Reactor Trip Pushbuttons
- Informs the TEAM
sa0 Directs performance of 1-FK-S.I Immediate Actions.
SROIROI Verify Reactor T15p. (FR-S.-l, Step 1)
BOP - Manually insert control rods or trip Turbine to automatically insert
......-.......-....-..............................
- After Turbine tripped return the control rods to automatic
SROIRO Verify Turbine Trip (FR-S.l, Step 2 )
- Verify all turbine stop valves closed (should not be)
- Manually trip the turbine
SROtBOP Verify AFW Pumps Running. JFR-S.1, Step 3 )
- Identifies MD AFW Pumps running (should be)
- Identifies TD AFW Pump running (should be)
Initiate Emergency Boration of RCS. (FR-S. I. Step 4)
- Verify CHG flow > 75 gpm (should not be}
- Identifies SI in service, so CKG Pump suction align to RWST
- Verify PRZK pressure < 2335 psig (should be)
Appendix D Required Operator Actions Form ES-D-2
Op-Te~tNO.: 2004-301 Scenario No.: 3 Page 12 of 24
Time
- Position Applicants Actions or Behavior
...
TEAM If an SI signal exists or occurs, Attachment 1 should be performed while
continuing with this procedure. (FR-S.I1 Caution prior to Step 5 )
TEAM Identifies SI occurred due to Hi CLS
sao/Ro Directs performance of Attachment I , Verifying Steps 1 through 13 of 1-E-
0.
- Verify Reactor Trip - dispatch an operator to perform local trip
- Verify Turbine Trip - isolate reheaters by closing 1-MS-SOV-104
- Verify both AC Emergency Buses energized (should be)
- Identifies SI initiated - nianually initiate SI
- Verify F W Isolation (should be)
- Verify CTlkST Isolation Phase I (should be)
- Verify A W Pumps running (should be)
- Verify SI Pumps running (should be)
- Check CHG Pump Auxiliaries running (should be)
- Check Intake Canal 9 24 F T and level being maintained by CW Pumps
- Check if Main Steamlines should be isolated (should be)
- Check if CS Required > 23 p i a
- Manually initiate Hi Hi CLS
- TripailRCPs
- hitiate Attachment 2, CLS Component Verification
, ...
- Manually close I-RM-TV-10OC (Hi CLS Train failure)
- Manually close 1-RM-TV-lOOA (Hi CLS Train failure)
- Manually close I-CC-TV-IOSA (Component failure)
- Blocks Low PRZR pressure and High Steam F ~ Q SI W signals
- Verify SI flow (should be)
- Reset both trains of SI
- Stops A CHG Pump and put in AUTO
- Identifies RCS pressure > 185 psig
- Stops one LHSI Pump and put in AUTO
SRO/BOP Check if the following trips have occurred (EX-SI, Step 5)
- ReactorTrip
- Direct Sewice BLDG operator to open Unit 1 Reactor Trip
Breakers or Rod Drive MG set output breakers
- Turbine Trip (should be)
SROBOP Alternate water sources for A W Pumps will be necessary if ECST level
Secreases < 20%. (R-S.1, Caution prior to Step 6)
- Identifies ECST level > 20%)
Appendix I) Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: 3 Page 13 of 24
Position Applicants Actions or Behavior
SWOBOP Check SG Levels. (Et-S.1, Step 6)
- Check NR level in at least one SG > 12%)(should not be)
- Verify total k e d flow > 700 gpm
- Control feed flow to maintain NR level between 22% and 50%
SRO/BOP Verify all dilution paths isolated. (FR-S.1, Step 7 )
- Put PG Pump control switches to OFF
- Close PG to Blender Flow Control Valve, 1-CH-FCV-1114A
- Verify PRT p6 outside TV, I-RC-TV-1519A closed (should be)
- Initiate Attachment 3, PG Isolation
- Directs Auxiliary BLDG operator to complete Atb. 3
SRO/BOP Check for Reactivity Insertion from uncontrolled RCS Cooldown. (FK-
s.l,Step 8)
- RCS temperatures decreasing in an uncontrolled manner (should be)
- A SG pressure decreasing in an uncontrolled manner (should be)
- Identifies ASG faulted inside CTMT
SRO/BOP Check MSTVs closed. (FR-S.1, Step 9)
- Identifies MSTVs closed on Hi Hi CLS
SROiBOP Identify Faulted SG(s). (FR-SI. Step IO)
- Check pressures in all SGs
- Identifies A SG pressure decreasing in an uncontrolled manner
~
At least one SG must be maintained available for RCS cooldown. If all
SSs are faulted, at least 60 @in [IO0 gpm] feed flow should be maintained
to each SG. If the TB AFW Pump is the only source of feed flow, steam
supply to the TD AFW Pump must be maintained from at least one SG.
(EX-S.1, Cautions prior to Step 11)
....
SROBQP Isolate Faulted %G(s).(I7R-S.1, Step 11)
..,... . - Isolate MFW line
- Close A SG Ew isolation MOV, I-FW-MOV-154.4
- Locally close feed REG bypass valve manual isolation valve, 1-
m-26
- Locally close steam supply valve to TD A W Pump, 1-MS-87
- Close or verify c l ~ s e d
- Close QT verify closed SG blowdown TVs (should be)
SRO/BOP Check CETCs < 1200°F (FR-S.1, Step 12) (should be)
-.
Appendix D Required Operator Actions E;hrm E;S-D-2
Op-Test No.: 2004-301 Scenario No.: 3 Page 14 of 24
Time
- Position Applicant's Actions or Behavior
SROIBOP If adverse CTA,MTconditions have been exceeded, the Gamma-Metrics
Excore Neutron Monitor system (Source and Wide Ranges) should be used
to monitor neutron flux for the duration of the event. (FR-S. 1. Note prior
to Step 13)
SRO/BOP Verify Reactor Subcritical. (FR-S.1, Step 13)
- Check power range channels < 5% [Gamma-Metrics Wide Range
Power] < 5% (should be)
- Check the fotlowing
- Intermediate range channels negative startup rate [Gamma-
Metrics Wide Range Power decreasing]
- Or
- Shutdown margin IAb7 1-0P-RX-002, SHUTDOWN MARGIN
(CALCULATED AT ZERO POWER) 9 1.44%
Boration should be continued fo obtain adequate shutdown margin dunng
subsequent actions. (FR-S. 1, Caution prior Step141
SRO Return to procedure and step in effect.
SRO Transitions to I-E-0, Step 1
TEAM Perform transient brief on failures and actions in progress.
SRORO Verifies Reactor Trip (E-0. Step I - Immediate Action Step)
- Check all Rods On Bottom Light lit
- Check Reactor Trip and Bypass Breakers open locally
- Check Neutron flux Iowering
SROIBOP Verify Turbine Trip (E-Q, Step 2 -Immediate Action Step)
- Manually tripped the turbine by pressing both Trip Pushbuttons
- Idcntify all Turbine Stop Valves closed
- CIose MSR Steam Supply 1-MS-SOV-104
- Verify Generator Output Breaker open (30 second time delay)
SROiRO Verify both Emergency AC Buses energized (E-0, Step 3 - Immediate
Action Step)
Appendix D Required Operator Actions Form ES-11-2
Op-Test No.: 20004-301 Scenario No.: 3 P2lge 15 Qf24
Applicants Actions or Behavior
Check if SI is actuated. ( E O , Step 4 - hmediate Action Step)
- Manually actuated both t&ns of SI
- Verify LHSI pumps running
- Verify SI annunciators lit
- A-F-3
- A-P-4
Verify T;w Isolation. [E-0, Step 5)
- Feed pump discharge MOVs closed (1-FW-MOV-1SOA & B)
- NZFW pumps tripped
- F e d Reg valves closed
- SG F W bypass flow demand at zero
Verify CTMT Isolation Phase I. ( E O , Step 6 )
- Phase I TVs closed
- 1-CH-MOV-1381 closed
- 1-SV-TV-102A closed
- PAM Isolation valves 1-DA-TV-183A closed
- PAM Isolation valves l-DA-TV-103B closed
Verify AFW pumps Running. (E-0, Step 7)
- MD AFW Pumps running (time delayed)
- TE) A m Pump ninning (time delayed)
verify SI Pumps Running. (E-0, Step 8)
- CHG Pumps running
- LHSI Pumps running
Verify GHG Pimp Auxiliaries. (E-8, Step 9)
- CHG Pump CC Pump running
- CHG Pump SW Pump running
- heck Intake Canal. (E-0, Step 10)
- Level >24m
- Level k i n g maintained by CW Pumps
Appendix D Required Operator Actions Form ES-13-2
Op-Test No.: 26)04-381 Scenario No.: 3 Page 16 of 24
Time Position 4pplicant's Actions or Behavior
SRQEO Zheck if Main Stearnlines should be isolated. (E-0, Step 11)
- Check if any of the following annunciators have been lit.
I E-P-IO, HI STEAM FLOW SI - (should be off)
- B-C-4, HI HI CLS TRAIN A - (should be OBI)
- B-6-5, HI HJ CLS TRACIJ B - (should be on)
- Check MSTVs closed
- Check either of the following actuated
- Hi Steam flow SI - (should be no)
- Header tu line SI - (should be yes)
- Verify RWST crosstie valves open
- 1-SI-TV-102A & B open
- 2-SI-TV-202A & B opera
Check RCS pressure < 185 PSIG - (should be no)
SRO/RQ Zhcck if CTMT Spray Required. (E-0, Step 12)
- CTMT pressure has exceeded 23 psia
- Manually initiate Hi H i CLS
- TnpallRCPs
- Verify CS pumps running
- Check ISRS pumps running (Time Delayed)
- Check QSRS pumps running (Time Delayed)
- Initiate Attachment I , CLS Component Verification
SRO/RO Low PRZR pressure SI signal should be blocked when PRZR pressure
decreases 6 2000 psig
- Blocks Low PRZR pressure SI signal by using block switches
High steam flow SI signal should be blocked when Tave decreases <
543°F
- Blocks High steam flow SI signal by using the block switches
CHG pumps should be run in the following order of prionty: C, B, A
RQ/SRQ Verify SI Flow. (E-0, Step 13)
- HHSI to cold legs flow indicated
- 1-SI-H-1961
- 1-SI-H- I962
- 1-SI-ET-1963
- 1-SI-HI-1943 or 1943-4
- Check three CHG Pumps running
.. Reset SI
- Stop one CHG Pump and place in AUTO
- Check RCS pressure < 185 p i g (should not be)
BOF/SRQ Verify Tota! AFW flow > 350 gpm [450 gprn]. (E-0, Step 14)
Appendix B Required Operator Actions Form FS-D-2
@-Test KO.: 2004-301 Scenario No.: 3 Page 17 of 24
]rime
- Position Applicants Actions or Behavior
BOPISRO Check AFW MOVs open. (E-Q, Seep 15)
RQiSRO Venfy SI Valve Alignment IAW Att. 2. (E-Q,Step 16)
- Verify open CHG Pumps Suction from RWST MBVs
- 1-CH-MOV- B 115R
- H -CH-MOV- 1115D
- Verify closed CHG Pump Suction from VCT MQVs
- I-CH-MQV-1115C
- B -CH-MOV- 1115E
- Verify closed CHG Line IsoIation MOVs
- 1-CH-MOV-1289A
- 1-CH-MOV-I-1289B
- Verify open msl to cold legs MOVs
- 1-SI-MOV- 1867C
- I-SI-MOV-1867D
- Verify open LHSI suction from RWST MOVs
- 1-SI-MOV-1862A
- 1-SI-MOV-l862B
- Verify open LHSI to cold legs MQVs
- 1-SI-MOV-1864A
- 1-SI-MOV-1864B
BOP Verify ventilation alignment and AC power alignment IAW Attachment 3
( E O , Step 17) (E-0, Att. 3 is attached)
(Only one switch to be manipulated on the Ventilation Panel)
Check WCS Avg Temp stable or trending towards 547%. (E-O*Step 18)
- Identify < 547°F
- Identify not dumping steam and control total feed flow. Maintain 9
350 gpm [450gpm] until NR level > 12% [lS%] in at least one SG.
- Identify MSTVs closed
RO/SRO Check PRZR PORVs and Spray Valves: (E-Q,Step 19)
- PRZR PORVs closed
- PRZR Spray controls at zero demand (Spray valves closed)
- At least one PORV Block Valve open
RO/SRO Check RCP Trip and Miniflow Recirc Criteria. (E-0, Step 20)
- HCISI flow to Cold legs indicated
- WCS Subcooling > 30°F [8S0F]
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 204-301 Scenario No.: 3 Page 18 of 24
- Pressures in all SGs stable for plant conditions (should not be)
- Pressures in all SGs > 100 psig (should not be)
.............________
1
I
SCEKARIO
-............ .(...:..o
...m ......ONCE rR4NsrrIm
.. i , E ..r...m .......... Io..E-2.
......................__
Scenario No.: 3
Simulator S e t u ~
TnitiaE Conditions:
0 Recall IC for 75% Rx Power.
1. Enter the foilowing M m W C R O N S :
2. Enter the following OVERRIDES:
Bp-Test NO.: 2004301 Scenario No.: 3 Page 20 of 24
3. On n?lONITBR, recall PRlh/li\RY2 variables
4. Verify the following control room setup: NONE
Scenario No.: 3 Page 21 of 24
SHIFT TURNOVER
Initial Conditions:
- 75% Reactor Power.
- Known leakage of 1 &pdin 1A Steam Generator.
- Thunderstorms are approaching from the West.
Turnover:
Shift orders are to raise power immediately following turnover. The previous shift
ramped the unit from 60% to 75% following B MFW Pump maintenance.
e 1-OP-gM-005has been completed up to step 5.4.12.
@-Test NO.: 2004-301 Scenario No.: 3 Page 22 of 24
Session Conduct
0 Ensure conditions in Simulator Setup are established.
Event No.: 1
Role-play as necessary to assist the team in ramp the unit L4W 1-OP-TM-005.
Event No.: 2
Initiate Trigger #2 to insert Malfunction CH-27, FT-CH-I 114, Primary Water Flow XMTR
fails low. Role play the following:
0 If the team dispatches the Auxiliary Bldg Operator, wait 16)minutes and inform the team
that there are no local indications why there is a blender problem.
0 If the team informs I & C Maintenance, role-play that YOU are gathering procedures and
prints to fornulate a Troubleshooting Plan.
0 If SRO notifies Shift Manager, roie-play as necessary to allow SWO to perfom a plant
status update following the event.
Event No.: 3
Initiate Trigger #3 to insert Malfunction CN-06, A CN Pump Performance Degradation.
Role play the following:
0 If the team dispatches the Turbine Bldg Operator, role play that the A CN Pump has
no discharge pressure and is making abnomal noises from the impeller casing. In
addition, no indication why the (7 CN Pump failed to auto start.
0 If the team informs Mechanical Maintenance, role-play that the A CN Pump needs to
be shutdown and tagged out for investigation and repair.
0 If the team informs the CN Polishing BLdg, to place 1-CP-AOV-122 in manual and fully
open the AOV, while the team closes 1-CP-MOV-100 use override to simulate placing
the AOV in manual and open, t k n remove ovemde when MOV closed.
0 If SRO notifies Shift Manager, role-play as necessary to allow, SRO to perform a plant
status update. following the event.
OP-Test NO.: 2004-301 Scenario No.: 3 Page 23 of 24
Event No.: 4
Initiate Trigger #4 to insert Malfunction FAT-18,ASG MEW How Transmitter fails low.
Role play the following:
0 If the team informs I & C Maintenance, role-play that YOU are gathering procedures to
place the channel En trip then will formulate a Troubleshooting Plan.
0 If SRO notifies Shift Manager, role-play as necessay to allow SRO to perfam a plant
status update following the event.
Event No.: 5
Initiate Trigger #5 to insert Malfunction MS-15, A SG POWV Controller fails high. Role
play the following:
0 If team does not notice that the SC PORV is open, as Security, call the MCR and report
steam is corning out of a pipe on top of safeguards.
0 If the team informs I&C Maintenance, role-play that you are gathering procedures and
prints to formulate a Troubleshooting Plan.
0 If SRO notifies Shift Manager, role-play as necessary to allow SIP0 to perform a plant
status update following the event.
e If team directs the Service BIdg Operator, role play to isolate A SG PORV using
P & D or MONlTOR variables as directed by team members.
Event No.: 6
Initiate Trigger ##6to insert Malfunction CN-01. Isolablc Letdown Line Break inside CTMT.
Role play the following:
If Sa0 notifies HP Supervisor, role-play as nccessary to allow SRO to perform a plant
status update following the event.
If SRO notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
status update following the event.
Cdp-Test NO.: 2004-301 Scenario No.: 3 Page 24 of 24
Event No.: 7
-- -
Initiate Trigger #7 to insert Malfunction MS-03, MS Line Break in CThTT on A SG with
a failure of RPS tu automatically and manually trip the reactor. In addition, f d u r e of .4
Ha C u train to actuate and failure of 1-CC-TV-1OSA to automatica!ly close.
Role play the following:
If team notifies Unit 2 Reactor Qperator, role-play as necessary to implement AP-50.00.
If team directs local actions in response to the ATWS, perfom directed actions by
utilizing $&ID and MONlTBR variables with appropriate time delays.
If team directs local actiuns in response to the MSLB, perform directed actions by
utilizing P&D and MONITOR variables with appropriate time delays.
If SRO notifies Shift Manager, role-play as necessary tu allow SRO to perfom a plane
status update following the event.
If SRO notifies W Supervisor, roleplay as necessary to allow SRO to perform a plant
status update following the event.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: Spare Page 2 of 26
Event No.: 1
Event Description: Conduct Rod Movement Testing (1-OPT-RX-005)
Time
~
Position Applicants Actions or Behavior
TEAM Conduct a brief of I-OPT-RX-005, CONTROL ROD ASSEMBLY
PARTIAL M O m m W
Review initial conditions of 1-OPT-RX-MIS. (OPT-RX-005, Section 3.6))
SRO/RO Review precautions and limitations of 1-OPT-RX-005. (OPT-WX-005,
Section 4.0)
SRO/RO Identifies that the Service BIDG operator will need a key to the Rod Control
Logic Cabinet. (OPT-RX-805, Section 5.0)
SROiRO Identifies that a full test is to be done and the PCS Computer is operable.
(OPT-WX-005, Section 6.1)
SRO/RO Bank Overlap Verification and Documentation. (OPT-RX-005, Section 6.2)
- Record the step counter DEMAND POSTN for control banks A, 3, and
L.
- Direct an operator to record and report the bank overlap thumbwheel
settings.
- Direct an operator to record and report the bank overlap counter (BOC)
number and RO records the step counter DEMAND POSTN for conerot
bank B.
- Determine the difference between BOC and control bank B.
- Identifies the difference is 384.
Control Bank D (OPT-RX-005, Section 6.3)
- Turn the ROD CONI MODE SEL switch to CBD.
- Record the baseline rod position on the Withdrawn line in Attachment 1,
Table 1, Control Bank D.
- Insert Control Bank D 12 steps.
- Complete the Inserted line in Attachment 1, Table 1
- Withdraw Control Bank D 12 steps
- Calculate in Attachment 1, Tabble 1 the Control Bank D Insertion and
compare with the Reference.
Appendix I) Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: Spare Page 3 of 26
Time Position Applicant's Actions or Behavior
SRO/RO Control Bank C (OPT-RX-005, Section 6.4)
- Turn the ROD C O W MODE SEL switch to CBC.
- Record the baseline rod position on the Withdrawn line in Attachment I ,
Tabie. 2, Control Bank C .
- Insert Control Bank C 12 steps.
- Complete the Inserted line in Attachment I , Table 2
- Yerify 1G-B5, CQNLPU PRWTOLT RQD CONTR SYS is lit.
- Verify 1G-B7, ROD BANK C LO LIMIT is lit.
- Notes that in the event the Group I and Group 2 Step Counters are not
the same after the next Step, they must be made the same by stepping out
only to prevent a Rod Croup Sequence Error. This will leave rods at 230
steps and prevent rod grsup misalignment.
- Withdraw Control Bank C to 235 steps as indicated by the Group Step
Demand Counters.
- Pulse the Group Group Step Demand Counters down to 230 steps using
Attachment 2 for guidance.
- Calculate in Attachment 1 Table 2 the Control Bank C Insertion and
compare with the Reference.
- Verify a l m s IG-B5 and IG-B7 are not lib.
Control Bank B (OPT-RX-005, Section 6.5)
- Turn the ROD CQNT MODE SEE switch to CBB.
- Record the baseline rod position on the Withdrawn line in Attachment I:
Table 3, Control Bank B.
- Insert Control Bank B 12 steps.
- Complete the Inserted line. in Attachment 1, Table 3
- Verify IG-B5, CQMPU PRLNTOm ROB CONTR SYS is lit.
- Verify BG-B6, ROD BANK B LO UMlT is lit.
- Notes that in the event the Group 1 and Group 2 Step Counters are not
the same after the next Step, they must be made the same by stepping out
only to prevent a Rod Croup Sequence Error. This will leave rods at 230
steps and prevent rod group misalignment.
- Withdraw Control Bank B to 235 steps as indicated by the Group Step
Demand Counters.
- Pulse the Group Group Step Demand Counters down to 230 steps using
Attachment 2 for guidance.
- CalcuEate in Attachment 1, Table 3 the Control Bank B Insertion and
compare with the Reference..
- Verify dams 1GB5 and 16-BG are not lit.
Appendix D Required Operator Actions
Op-Test NO.: 2004-30 1 Scenario No.: Spare
Position
SRO/RO Control Bank A (OPT-RX-005, Section 6.6)
- Turn the ROD CONT MODE SEL switch to CBA.
- Record the baseline rod position on the Withdrawn line in Attachment I ,
Table 4,Control Bank A.
- Insert Control Bank A 12 steps.
- Complete the Inserted line in Attachment E , Table 4
- Verify 1G-B5, COMPU PRINTOUT ROD CONTR SYS is lit.
- Ve~ify1G-I35, ROD BANK A LO LlMK is lit.
- Notes that in the event the Group 1 and Group 2 Step Counters are not
the same after the next Step, they must be made the same by stepping out
only to prevent a Rod Croup Sequence Error. This will leave rods at 230
steps and prevent rod group misalignment.
- Withdraw Control Bank A to 235 steps as indicated by the Group Step
Demand Counters.
- Pulse the Group Group Step Demand Counters down to 230 steps using
Attachment 2 for guidance.
- Calculate in Attachment 1, Table 4 the Control Bank A Insertion and
compare with the Reference.
- Verify a l m s 1GBS and 1G-B5 are not lit.
SRO/RO Shutdown Bank B (OPT-RX-005, Section 6.4)
- Turn the ROD CONT MODE SEL switch to SBW.
- Record the baseline rod psition on the Withdmwn line in Attachment I ,
Table 5, Shutdown Bank B.
- Insert Shutdown Bank B 12 steps.
- Complete the Inserted line in Attachme.nt I , Table 5
- Verify 16-55, COMPU P R m Q t I T ROD CONTR SYS is lit.
- Notes that in the event the Group 1 and Group 2 Step Counters are not
the same after the next Step, they must be made the same by stepping out
only to prevent a Rod Croup Sequence Error. This will leave rods at 230
steps and prevent rad group misalignment.
- Withdraw Shutdown Bank I3 to 235 steps as indicated by the Group Step
Demand Counters.
- Pulse the Group Group Step Demand Counters down to 230 steps using
Attachment 2 for guidance.
- Calculate in Attachment 1, Table 5 the Shutdown Bank B Insertion and
compare with the Reference.
- Verify a l m 1G-B5 is not lit.
AppeRdlX D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario NQ.: Spare Page 5 of 26
Time Position Applicant's Actions or Behavior
SROiRO Shutdown Bank A (QPT-RX-005, Section 6.8)
- Turn the ROD C O W MODE SEI, switch to SBA.
- Record the baseline rod position on the Withdrawn line in Attachment 1,
Table 6, Shutdown Bank A.
- Insert Shutdown Bank A 12 steps.
- Complete the Inserted line in Attachment 1, Table 6
- Verify 1G-135, CQMPU PRZNTOLT ROD CONTW SYS is lit.
- Notes that in the event the Group 1 and Group 2 Step Counters are not
the same after the next Step, they must be made the same by stepping out
only to prevent a Rod Croup Sequence Error. This will leave rods at 230
steps and prevent rod group misalignment.
- Withdraw Shutdown Bank A to 235 steps as indicated by the Group Step
Demand Counters.
- Pulse the Group Group Step Demand Counters down to 230 steps using
Attachment 2 for guidance.
- Calculate in Attachment 1. Table 6 the Shutdown Bank A Insertion and
compare with the Reference.
Verify alarm 1G-B5 is not lit.
SRORQ Rods in Auromatic, and Bank Overlap Verification and Documentation.
(OPT-RX-005, Section 6.9)
- After verifying that Tavg is within 2 1 "Fof Tref, then put ROD CONT
MODE SEL switch in AUTO.
- Record the step counter DEMAND POSTN for control banks A, B, and
C.
- Direct an operator to record and report the bank overlap thumbwhecl
settings.
- Direct an operator to record and report the bank overlap counter (BOC)
number and RQ records the step counter DEMAND PQSTN for contra!
bank D.
- Determine the difference between BOC and control bank D.
- Identifies the difference is 384.
SRQiWO Follow-On. (OFT-RX-005, Section 7.0)
- Evaluate the test results by reviewing the Acceptance Criteria.
- Identifies when the rods are inserted 12 steps, the GP1 and GP2
step counter Insertion is 12.
- Identifies when the rods are inserted 12 steps. the IRPI Insertion is
12 & 6.
- Identifies the difference between Bank Overlap Counter and
Control Bank D is 384.
- Identifies the thumbwheel settings are corrected based on criteria.
. ..
Appendix D Required Operator Actions Form ES-D-2
@-Test No.: 2004-301 Scenario No.: Spare Page 6 of 26
Event No.: 2
Event Description: PRZR pressure transmitter fails high (1-RC-PT-1445).
Applicamt's Actions or Behavior
Acknowledges annunciators IC-FS, PRZR HI PRESS and 1D-H4, PRZR
Identifies PRZR pressure transmitter failed high.
Closes PRZR PORV that opened due to instrumentation failure.
Verifies PRZR pressure recovering following the opening of PRZR PORV.
Perfoms a focus brief on the failure and actions in progress.
Reviews annunciator response procedures.
sRO Evaluates Tech Specs sections 3.I.A.6, 3.l.G, and 3.12.F. Declare PRZR
PORV, 1-RC-PGV-14% inoperable and close PRZR PORV block valve, 1-
RC-MOV-1535 within one-hour. If PRZR pressure decreased < 2205 psig
then identify a two-hour to restore PRZR pressure.
Directs I & C Maintenance to investigate the failure of 1-RC-$T-1445,
PRZR Pressure control channel.
Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form ES-D-2
Qp-Test No.: 2004-301 Scenario No.: Spare Page 7 of 26
Event NO.: 3
Event Description: PRZR PORV Leakage (l-RC-PCV-IJSSC)
-
rime Position Applicant's Actions or Behavior
RO Acknowledges annunciator lC-F7, PRZR REKEF TK I-w PRESS.
RO Identifies PRZR pressure decreasing and reviews annunciator response
procedures.
RO Acknowledges annunciator IC-Ld7, PRZR PWR RELIEF LINE HI TEMP.
SRO Direct implementation of AP-3 1.00, INCREASING OR DECREASING
RCS PRESSURE.
SRBWOP Check Turbine b a d stable. (AP-31.00, Step 1)
SROBO Check RCS pressure decreasing. (AP-3 1 .00, Step 2)
- Identifies RCS pressure is slowly decreasing.
SRQIROI Decreasing RCS pressure will cause the OTAT setpoint to decrease. (AP-
BOP 3 1.00, Caution prior to Step 3)
- Monitor OTAT setpoint.
SRQRO PZR PORV I-RC-PCV-14SSC should be declared inoperable when the
Master Controller is placed in Manual. (AP-31.00, Note prior to Step 3)
Stop Pressure Decrease. (AP-31.00, Step 3 )
- Place 1-CH-PC-l444J, PRZR PRESS MASTER CNTRL in
MANUAL.
- Decrease demand on PRZR PRESS MASTER CNTHPL to raise RCS
pressure.
- Declare PRZR PORV inoperable.
SRORO Check RCS pressure still decreasing. (AP-31.00, Step 4)
- Identifies RCS pressure is stili decreasing.
SRO/RO Verify no pressure loss through the PRZR PORVs. (AP-31.00, Step 5)
- Close or verify close PRZR EQRVs
- Close Block M 6 V to isolate any PORV, which will not close or is
leaking.
- Identifies when the remaining Block MOV closes RCS pressure starts
increasing.
Appendix D Required Operator Actions FOITIIES-D-2
Op-Te~tNO.: 2004-301 Scenario No.: Spare Page 8 of 26
Event No.: 3
Event Description:
AppHcant*sActions or Behavior
Turn on all PRZR heaters. (AP-31.00, Step 6) (should be)
Verify closed or close 1-CH-HCV-1311, AIJX Spray Isolation. (AP-31.00,
step 7) (should be)
Check AUX Spray line leakage suspected. (AP-31.08, Step 8) (should not
be)
- GO TO Step 10
Place Spray valve controllers in Manual and adjust demand to zero. (AP-
31.00, Step 10)
- Places both spray valves controllers in Manual.
- Verifies demand at zero
Check either of the following conditions. (AP-31.863, Step 11)
- Identifies both spray valves closed.
- Identifies spray valves not leaking due to abnormal PRT conditions.
- GOTOStep13
Check RCS Pressure stabilizing or increasing. (AP-3 1.00, Step 13)
- Identifies RGS pressure increasing following closing last PRZR PQRV
block valve.
- GQTOStep 17
Return PRZR PRESS MASTER CNTRL and PWZR Spray Valve
controllers back to AUTO.
Evaluates Tech Specs sections 3.I.A.6,3.1.6, and 3.12.F. Declare PRZR
PQRV, B -RC-PCV-1456 inoperable and close PRZR PQRV block valve, 1-
Re-MOV-1535 within one-hour. If PRZR pressure decreased < 2205 psig
then identify a two-hour to restore PRZR pressure. Determine RCS leak
rate after stabilizing plant conditions.
~~
Notifies Shift Manager and STA of failure and actions in progress.
Appendix I9 Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: Spare Page 9 of 26
Event No.: 4
Event Description: Unit Load Reduction (AP-23.08)
Position Applicants Actions or Behavior
BOP Acknowledges annunciator lG-E5, GEN L E A D S CLG TRBL
Direct the Turbine BEDC operator to local annunciator panel to investigate
cause of alarm.
Reviews annunciator response procedure while awaiting field report.
Perform ARP 1G-E5, GBN LEADS CLG TRBL.
- Turbine BLDG operator reports Low Air Flow due to a loss of A
Isophase Bus Duct Cooling (BDC) Fan.
- Reviews cautions:
- If one or more fan is inoperable, a unit ramp down to the self
cooled eating of 14,250 amps should be initiated immediately.
- Power should be reduced at the rate of 1% power per minute to
78% power. Power reduction should continue from 78% to
14.250 amps at normal rate of 15s MWelWR.
- Reviews note in accorddnce with OPAP-0006, Shift Operating
Practices, at the discretion of the Shift Supervisor, the thermal overload
devices may be reset only once.
- Attempt to restart Fan
- Dispatch operator to check circuit breaker MCC lA2-2-1B, GEN
LEADSCLR PH A Fan
- Report from field is the breaker is tripped.
- Initiate a ramp down to reduce generator amps to 14.250 amps in
accordance with 0-AP-23.00. RAPW) LOAD REDUCTION
- GO TO Step 8 to initiate work request to repair IBBC fan.
SRQ Notify Electrical Maintenance to investigate failure of the rSDC Fan.
SRQ Notifies Shift Manager and STA of failure and actions in progress.
swo Directs AP-23.00, Rapid Load Reduction based on loss of BDG Fan.
TEAM Zonservative decision-making must he maintained during rapid load
reductions. If uncertain or degrading conditions arise which could
idversely affect the safety of the plant, or if any criteria in Attachment 1 is
- xceeded, the load reduction should be terminated by tripping the Re.actor
ar the turbine, or both, depending on power levei. (AP-23.00, Caution
?nor to Step 1)
Appendix D Required Operator Actions Form ES-D-2
Oy-Test No.: 2004-381 Scenario No.: Spare Page 10 of 26
Time Position Aualicants Actions or Behavior
1 1 -
TEAM Reviews notes. (AP-23.sO, Notes prior to Step 1)
Actions that can be conapleted independently of preceding steps may ke
performed out of sequence as directed by the SRO.
I If at any time plant conditions no longer require rapid load reduction,
actions should continue at Step 25.
- RCS Tave must be manntained 5577°F and RCS pressurc > 2205 p i g .
Tech Spec 3.12.F.1 should be reviewed if either parameter is exceeded.
- I&C sboiiid be contacted to provide assistance with adjusting HwPIs.
TEAM Initiate Plant Load Reduction at l%/MINUTE or less. (AP-23.00, Step 1)
- Verify turbine valve position not on limiter. (should not be)
- Insert control rods in AUTO or MANUAL as necessary to maintain
Tave and Tref matched.
- Verify or place Turbine in IMP IN.
- Adjust LOAD RATE %MTNthumbwheel to 1%MHN ramp rate.
- Initiate Turbine load reduction using OPERATOR AUTO.
- Perform emergency boration for 30 to 40 seconds IAW the following:
- Verify or raise CHG flow to > 75 gpm
- Transfer the in-service BATP to FAST
- Open 1-CH-MOV-1350
- Monitor EMER BORATE FLOW
- After required emergency boration, perform the foIlowing :
- Close I-CH-MQV-1350
- Transfer the in-service BATP to AUTO
- Restore CHC flow control bo normal
Establish a continuous 10 gpm normal borntion to maintain control rod
position above the LO-LO- insertion limits.
Check all PRZR heaters energized.
Control ramp rate to maintain RCS pressure > 2205 p i g .
Monitor steam dumps for proper operation.
Reduce Turbine valve position limiter as load decreases.
SRO If a ramp rate > 1%/min (not to exceed SWrnin) is desired, emergency
borate to maintain Tref and Tave matchcd, hFlrux in band, and control rod
position above the LO-LO insertion limit. (AP-23.00, Note prior to Step 2)
SRO/BOP Notify the following: (AP-23.00. Step 2)
- System Operator
- Polishing BLDG
- Chemistry
- OMOC
Appendix I4 Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: Spare Page 11 of 26
- Until > 15% in one hour, GO TO Step 6
Appendix D Required Operator Actions FOIIIIES-D-2
Op-Test No.: 2004381 Scenario No.: Spare Page 12 of 26
Event No.: 5
Event Descriptiorn: 1A Steam Generator Level Transmitter fails low (l-W-L7--1476)
Time Position Applicants Actions or Behavior
BOP Acknowledges annunciators associated with the SG levels and high
feedwater flow.
TEAM Identifies A SG channel 3 f d e d low (1-FW-LT-1476).
SRO Direct BOP to place AMain FRV in Manual and restore A SG level.
BOP Takes manual control of A Main PRV and reduces feedwater flow to
restore level.
TEAM Perfurns focus brief on failure and actions in progress.
SRO Reviews Tech Specs Section 3.7 and identifies TS Table 3.7-1 items 12 & 17
requiring Operator Action #6; identifies TS Table 3.7-2 item 3a and IPS
Table 3.3-3 item 3a requiring Operator Action #20,72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> clock to place
channel in trip.
SRO Notifies I & C Maintenance to place channel in trip.
SRO Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: Spare Page 13 of 26
Event No.: 6
--
Event Description: 1B SG FQRV fails open (l-MS-RV-I(B1B)
Applicants Actions or Behavior
Infoornns control room of steam blowing from top of Unit 1 Safeguarcls.
Identifies B SG PQRV is open and controller output is at 100%.
Directs BOP to take manual control of B SG PQRV and close the valve.
Takes 3 SG FQRV controller to MANUAL and closes the valve.
Notifies I&C Maintenance to investigate the failure.
Perform ~ Q C U Sbrief on failure and actions in progress.
Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: Spare Page 14 of 26
Event NQ.: 7, 8,9: Id), & 11
Event Description: Main Steam Line Break at header. B Charging Pump Trips and
A and C Fail to auto start. Motor Driven and Steam Driven AFW pumps trip.
MSTVs fail to close (1-MS-TV-lOlA, 3. & e).B & C ,Main Steam NRVs fail to
close.
Position Applicants Actions or Behavior
RBIElOP Acknowledges annunciators.
RQiBOP Identifies decreasing SG and RCS Pressure, along with RCS temperatures.
RQ Identifies automatic Reactor Trip and initiates 1-E-0 Irnrnediate Actions.
SIP0 Directs perf&rmance of 1-E-0 Immediate Actions.
BOP Acknowledges annunciators while RQ performs 1-E-0 Immediate Actions.
SRO/RO Verifies Reactor Trip (E-0; Step 1 - Immediate Action Step)
- Manually trip Reactor
- Check all Rods On Bottom Light lit
- Check Reactor Trip and 5ypass Breakers open
- Check Neutron flux lowering
SROIRO Verify Turbine Trip (E-0, Step 2 - Immediate Action Step)
- Manually trip the turbine by pressing both Trip Pushbuttons
- Identify all Turbine Stop Valves close
- Close MSR Steam Supply I-MS-SOV-104
- Verify Generator Output J3reake.r open (30 second time delay)
SRQ/RO Verify both Emergency AC Buses energized (E-0, Step 3 - Immediate
Action Step)
SROIRO Check if SI is actuated. ( E O , Step 4 - Immediate Action Step)
- Manually actuate both trains of SI
- Verify LHSI pumps running
- Verify SI annunciators lit
- A-F-3
- A-F-4
SROIBOP May take actions to isolate the steam break by:
[Event 10) - Attempting to close MSTVs using control switches and App R
Emergency closure switch (Vertical Board 2)
- Closes A MS KRV and attempts to close B & c MS NRVs
Appendix D Required Operator Actions Form ES-D-2
Qp-Test NO.: 2004-301 Scenario NO.: Spare Page 15 of 26
Position Applicants Actions OF Behavior
SROBQP Verify F W Isolation. (E-0, Step 5 )
- Feed pump discharge MOVs closed (l-FW-MOV-150A & B)
- NZFW pumps tripped
- Feed Reg valves closed
- SG F W bypass flow demand at zero
Venfy CTMT Isolation Phase I. (E-0, Step 6)
- Phase I TVs closed
~ 1-CH-MOV-1381 closed
- 1-SV-TV-102A closed
- PAM Isolation valves 1-DA-TV-103A closed
- PAM Isolation valves I-DA-TV-103B closed
SROBBP Verify AFW pumps Running. (E-0, Ste.p7)
(Event 9) - Identifies MD A F V Pumps not running
- Lockout annunciators lit for both MD AFT4 Pumps
- Identifies TD A W Pump not running
- Identifies no exhaust steam flow indicated for TD AFW Pump
SRO Direct Unit 2 Operator to crosstie AFW and supply Unit 1 IAW AP-
50.00.
ROiSRO Verify SI Pumps Running. (E-0, Step 8)
(Event 8) - Identifies B CXG Pump tripped
- Identifies K and C GHG Pumps not running
- Identifies no lockout annunciators lit
- Manually start A and C CHG Pumps
- LHSI Pumps running
RO/SRO Verify CHG Pump Auxiliaries. (E-0, Step 9)
- CHG Pump CC Pump running
- CHG Pump SW Pump running
RO/SRO Check Intake Canal. (E-0, Step 10)
- Level924FT
- Level being maintained by CWI Pumps
Appendix D Required Opemtor Actions Form ES-D-2
Op-Test NO.: 3004-301 Scenario No.: Spare Page 16 of 26
Time Position Applicants Actions or Behavior
SROlBOP Check if Main Steamlanes shsuld be isolated. (E-0, Step 11)
(Event 10) - Check if any of the following annunciators have been lit.
- E-F-10, M STEAM FLOW SI (should be on)
- B-C-4, J3I HI CLS TRAIN A (should be off)
- B-G-5, HI PII CLS TRAIN B (should be off)
- Attempt to close MSTVs using control switches and App R Emergency
closure switch (Vertical Board 2 )
- Closes A MS KRV and attempts to close E $r 6MS NRVs
- If annunciator E-H-IO (Header to line SI) (should be yes)
- Venfy RWST crosstie valves open
- 1-SI-TV-102A
- I-SI-TV-102B
- 2-SI-TV-202A
- 2-SI-TV-202B
~
Check RCS pressure < 185 psig (should not be)
SRO/RQ Zheck if GTMT Spray Required. (E-0, Step 12)
- CTMT pressure has exceeded 23 psia (should not be)
I
If CTMT pressure has exceeded 17.7 psia (should not be)
- GOTOStep 13
. .
Review notes. (E-0, Notes prior to Step 13)
I Low PRZR pressure SI signal should be blocked when PRZR pressure
decreases < 2000 psig
- Blocks t o w PRZR pressure SI signal by using block switches
- High steam flow SI signal should be blocked when Tave decreases
543°F
- Blocks High steam Blow SI signal by using the block switches
- CHG pumps should be run in the following order of priority: C, B, A
Venfy SI Flow. (E-& Step 13)
- SI to cold legs flow Indicated
- I-SI-FH-1941
- I-SI-H-1962
- 1-SI-FI-1963
- 1-SI-FI-I933 or 1943A
I
Check three CHlG Pumps running
- Reset SI
- Stop one CHG Pump and place in AUTO
- Check RCS pressure < 18.5 psig (should be > 18.5psng)
~
Appendix 11 Required Operator Actions Fomi ES-D-2
Op-Test No.: 2004301 Scenario No.: Spare Page k7 O f 26
Event No.: 12
--
Evemt Description: RCS Bleed and Wed
Time
- Position Applicant's Acaions or Behavior
SRQiBOP Verify Total AFW flow > 350 gpm [4SO gpm]. (E-0, Step 14)
- Identifies no AFW Pumps running
- AFW flaw < 350 gpm
GO TO FR-H. 1
SRO Transitions to E%-H. 1
SROBOP Reviews Cautions. (FR-H. 1, Cautions prior to Step 1)
- If total feed flow < 350 gpm [45Qgpm] due to operator action, this
procedure should not be performed.
- Feed flow should not be reestablished to any faulted SG if a non-
faulted SG is available.
TEAM Check if Seconelary heat sink is required: (FR-H.1, Step I)
- RCS pressure > any non-faulted SG pressure (shoukl be)
- RCS hot leg temperature > 350°F (should not be)
- Try to put RHR system in service while continuing this procedure.
Refer to 1-OP-RN-001,RHR OPERATIONS. If adequate cooling with
RgFR is established, then RETURN TO procedure and step in effect.
TEAM Review caution. (FK-H.1 , Caution prior to Step 2)
- If wide range level in any 2 SGs < 7% [22%] or PRZR pressure 2335
psig due to loss of secondary heat sink, RCPs should be tripped and
Steps EO through 17 should be immediately initiated for bleed and feed.
TEAM Identifies that 2 SGs < 7% [22%] on wide range level indication and
actions required by the Caution OH the Continuous Action Page.
SRO/RB Stops all RCPs.
TEAM Reviews caution. (FR-H.1, Caution prior to Step 10)
- Steps I0 through 17 must be performed quickly in order to establish
RCS heat removal by RCS bleed and feed.
SROiRO Verify stopped or stop all RCPs (I%-H. B Seep 10)
I
- Identifies all RCPs stopped.
Appendix I9 Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: Spare Page 18 of 26
rime Position Applicant's Actions or Behavior
. .%*
........ SROrnO Initiate SI. (FR-H.1, St
- Manually initiate SI
- Identifies SI was a1
SRO/RO Verify RCS Feed Path: (IT-H.1, Step 12)
- Check CHG Pumps at least one running (should be two)
- Verify SI valve emergency alignment:
- C H S Pump suction from RWST MOVs opened (should be)
- 1-CH-MOV-1I15B Sr I)
- CHG Pump suction from VCT MOVs closed (should be)
- 1-CH-MOV-1IlSC & E
- HHSI to cold leg opened (should be)
- 1-SI-MOV-1867C & B
- Verify "SI flow to cold legs (should be)
SRB/RO Reviews note. (FR-H.1, Note prior to Step 13)
If an SI signal is actuated after completion of Step 13, the SI signal should
be reset.
SRO/RO Reset both trains of SI (time delay). (FR-H.l, Step 13)
- Depress both trains of SI Reset Pushbuttons after waiting one minute
for reset permissive.
SRO/RB Check if CLS can be reset; (FR-H. 1 Step 84)
~
- CTMT pressure < 14 psia (should be)
- Reset both trains of CLS, if necessary (should not be)
SRO/RO Verify Instrument Air available: (FR-W. 1, Step 15)
- Check annunciator B-E-6 not lit (should not be)
- Check at least one CTMT IA compressor running (should be)
- Verify I-IA-TV-180 open (should be)
Critical SRO/RO Establish RCS Bleed Path: (FR-H.1, Step 16)
Task - Verify power to PRZR PORV block valves available (should be)
- Verify PRZR PORV bloc t be)
- Open both PRZR PORV blo
- Open both PRZR PORVs
SROrnO Verify adequate RCS Bleed Path: (FR-H.1, Step 17)
- PRZR PORVs both open (should be)
- PRZR PORV block vaIves both open (should be)
Appendix D Required Operator Actions Form ES-D-2
Op-Test NQ.: 2004-301 Scenaris No.: Spare Page 19 of 26
Time Position Applicants Actions or Behavior
SWOIRO Initiate Attachment 4 while continuing with this procedure. (FR-HI, Step
18)
- Verify Reactor Trip (should be)
- Verify Turbine Trip (should be)
- Verify both AC Emergency Buses energized (should be)
- Identifies SI actuated
- Verify F W Isolation (should be)
- Verify CTMT Isolation Phase H (should be)
- Ve.rify AFW Pumps running (should not be)
- Verify SI Pumps running (should be two)
- Check CHG Pump Auxiliaries running (should be)
- Check Intake Canal > 24 E T and level be.ing maintained by CW Pumps
- Check if Main Steamlines should he isolated (should be only AS 6 )
- Check if CS Rquire.d 9 23 psia (should not he)
- Blocks Low PRZR pressure and High Steam Flow SI signals
- Verify SI flow (should be)
- Reset both trains of SI (should be)
- Identifies RCS pressure 9 185 psig
Stops one LHSI Pump and put in AUTO
SIIWRO Maintain RCS Heat Removal: (FR-H.1, Step 19)
- Maintain SI flow
- Maintain RCS vent paths open
SRQ/RO Reviews caution. (FR-N. 1, Caution prior to Step 20)
If containment pressure increases to > 23 psia, containment spray should
be verified.
Check if CS should be stopped. (FR-H.1, Step 20)
- Identifies Spray Pumps not running
Continue attempts to establish secondary heat sink in at least one SG using
high pressure makeup. (FR-H. 1, Step 21)
- M V flow (TAW Step 2)
- h/fFw flow (IAW Step 3)
- Condensate ROW ( U W Step 7 )
Appendix I) Required Operator Actions Form ES-D-2
Bp-Test No.: 2004-301 Scenario No.: Spare Page 20 of 26
rime Position Applicants Actions or Behavior
SRO/BOP Try to establish AFW flow to at least cane SG: (FR-H. 1, Step 2)
- Check SG blowdown TVs closed (should be)
- Verify AFW MOVs open (should be)
- Identities that 3 and C SG faulted and isolate AFW MQVs to both
SGS.
- Check ECST available (should bc)
- Check A W available
- Identifies can not start A W Pumps and GCUTI~S out RNO
- Identifies minimum feed flow not established, then do the
following:
- StopRCPs
- Have BJnnit 2 operator close Unit 2 AFW MOVs
- Wave Unit 2 operator open MOV-W-160A & B
- Have Unit 2 operator start both MD AFW Pumps (TB
AFW Pump 08s initial conditions)
- Control AFW flow to maintain total flow to SG > 350
gpm [4508pmI.
- Identifies AFW flow establish to A SG via Unit 2 AFW
crosstie.
SROBOP Check for adequate Secondary Heat Sink: (PR-H. 1, Step 22)
- NR level in at least one SG > 12% [18%1
- Identifies NR level in A SG increasing
- RETURN to Step 21
..... .............. ...........- ...........- ...........
SCENARIO
-. ........ COMPLETED
.............. ONCE FLOW ......... FEED ........F;STABLISIED.
.- ........................ .-
...
@+Test NO.: 2004-301 Scenario No.: Spare Page 21 of 26
Simuiator Setup
Initial Conditions:
0 Recall IC for IQO% Rx Power.
1. Enter the foollo~ingNIALFaTNCTIIONS:
Op-Test No.: 2004-301 Scenario No.: Spare Page 22 of 25
2. Enter the following OVERRIDES:
...................
................. .................
..
OFF
om
AUTO-ENABLE
AUTO-ENABLE
AUTO-ENABLE AUTO-DIS ABLE
AUTO-ENABLE AUTODISABLE
a. On MONITOR, recall P R M m Y 2 variables.
4. Verify the following control room setup:
e Place l-EH-P-MP2 in PTL with il red magnet above the control switch.
Place an orange magnet above the control switch for I-RC-HCV-1557A.
Op-Test No.: 2804-381 Scenario No.: Spare
SHIFT TURNOVER
Initial Conditions:
0 100% Reactor Power.
0 Known leakage of lgpd in IA Stem Generator.
9 Thunderstoms are approaching from the West.
1-EH-P-MP-2 (EPump) is tagged out for thermal overload replacement.
0 1-RC-HCV-15578 (Loop aDrain) is isolated.
0 h i t 2 is at 100% power with 2-EW-P-2 (TDAFW Pump) tagged out for governor
replacement.
Turmover:
0 Shift orders are to conduct a Partial Rod Movement Test IAW 1-OPT-RX-005
I I I I
..
Op-Test No.: 2004-,U)I Scenario No.: Spare Page 24 of 26
0 Ensure conditions in Simulator Setup are established.
Event No.: 1
Role-play as necessary to allow the team to perform l-OPT-RX-QOS,
Control Rod Assembly Partial Movement.
The Service Bldg Operator will be stationed in the Unit 1s Normal SWGR to
perfom local actions as directed by the team.
Event No.: 2
Initiate Trigger #2 to insert Malfunction RC-48, PRZR Pressure Transmitter fails high.
Role-play the following:
e If the team informs I & C Maintenance, role-play gathering procedures and prints to
formulate a Troubleshooting Plan.
0 If SRO notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
status update following the event.
Event No.: 3
Initiate Trigger #3 to insert Malfunction, RC40. PRZR PORV leakage (I-RC-PCV-1455C).
Role-play the following:
0 If SWO notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
status update following the event.
Event No.: 4
Initiate Trigger #4 to insert Ovemde, V2GE5, GEN LEADS C I S FRBL. Role play the
following:
0 If team dispatches Turbine Bldg Operator to investigate, infom the team after a couple
of minutes that a low air flow drop is in and A Isophase Bus Duct Cooling Fan
breaker (MCC 1A2-2-IB) is tripped.
Op-Test No.: 2004-301 Scenario No.: Spare Page 25 of 26
0 If the tcam informs Electrical Maintenance, role-play as necessary to investigate and
fomulatjng a troubleshooting and repair plan.
0 E SRO notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
status update following the event.
0 Role-play as necessary to allow the team to perform AP-23.00, Rapid b a d Reduction.
Event No.: 5
Initiate Trigger #5 to insert Malfunction FW-13, A SG Level Transmitter fails low. Role
play the following:
e If the team informs I Br C Maintenance, role-play gathering procedures to place the
channel in trip and formulating a troublcshooting and repair plan.
If SRQ notifies Shift Manager, role-play as necessary to allow SRO to perform a plant
shtus update following the event.
Event No.: 6
Initiate Trigger #6 to insert Malfunction MS-15, SG PBRV (1-MS-RV-lOlB) fairails open.
Wait for cue from lead examiner BO inf0mn the team as Security that steam is blowing from
the top of safeguards.
Role-pia), the foollowing:
0 If the team informs I&C Maintenance, role-play gathering procedures and prints to
formulate a troubleshooting plan.
If SRQ notifies Shift Manager, role-play as necessary to allow SRQ to perform a plant
status update following the event.
Event No.: 7
Initiate Trigger #7 to insert Malfunction MS-01, MSLB at Header. In addition, B CHG
pump trips with auto start failure of A & C CHG Pumps; all AEw Pumps trip; the
MSTVs fail to close; and B Br C MS M V fail to close.
Role play the following:
0 If the team dispatches the Service Bldg Qpcrator to check MD Ana: Pump breakcrs,
-- inform the team that the breakers have ovcrcurrent drops on all phases.
0 If the team informs Electrical Maintenance, role-play invcstigating the cause and
forniulating a repair plan.
0 If SRO notifies Shift Manager, role-play as necessary to allow SRO to perfom a plant
status update following the event.
0 If SRO notifies HP Supervisor, role-play as necessary to allow SRO tQ petfonn a plant
status update foilowing the event.