ML041070244
| ML041070244 | |
| Person / Time | |
|---|---|
| Site: | Surry  |
| Issue date: | 02/19/2004 |
| From: | NRC/RGN-II |
| To: | |
| References | |
| 50-280/04-301, 50-281/04-301 | |
| Download: ML041070244 (80) | |
See also: IR 05000281/2004301
Text
raft
SURRY EXAM
50-280, 50-28112004-301
-
FEBRUARY 24 MARCH 2
& MARCH 4,2004 (WRITTEN)
Appendix D Scenario Outline Form ES-D-1
Examiners: Operators:
Initial Conditions:
75% Reactor Power
Known leakage in 1A Steam Generator
Thunderstorms are approaching from t h e West
Turnover:
Shift orders are to maintain power at 100%.
- Event
-1
NO.
2
3
4
Transmitter Bails low. Ramped to allow adequate operator
response to gain control of SG level prior to trip OR steam /
5
6
a
8
- (M)0rfll (R)eactivity, (I)nstrument, (C)omponent, (Mlajjar
Appendix D Required Operator Actions Fom ES-D-2
Scenario No.: I Page 1 of 14
EventNo.: 1
Event Description: l a s s of Component Coaling Water to NRHX requiring letdown to
be secured.
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2084-301 Scenario No.: 1 Page 2 of 14
EventNo.: 2
Event Description: Place Excess Letdown in service.
Applicant%Actions or Behavior
Obtains copy of OP-CH--006.
Reviews Precautions and Limitations.
Places 1-@H-HCV-1389to the PDTT position. (Step 5.1.13)
Opens -CW-HCV-1201Excess Letdown HX Isolation. (Step
5.1.15)
Records charging flow. (Step 5.1.16)
Opens 1Loop drain isolation valve l-RC-HGV-I557A, B, or 6
(Step 5.1.17)
Opens I-GH-HCV-I 137 to establish 15 gaLlons per minute flow.
(Step 5.1.18)
Places 1-CH-HCV-1389to VCT position. (Step 5.1.21)
Verifies or places 1-CN-PCV-1145 in MANUAL. (Step 5.1.27.a)
Verifies or closes 1-CH-LCV-1460A and B. (Step 5.1.27.b)
Verifies or closes 1-CH-FCV-1122. (Step 5.1.27.d)
Verifies or closes 1-CN-HCV-1200A, B, and @(Step5.1.27.0
Fully opens I-GH-PGV-I 45. (Step 5.1.27.g)
Appendix D Required Operator Actions Form ES-B-2
@-Test No.: 2084-301 scenario No.: I Page 3 of 14
EventNo.: 3
Event Description: Median Select Tave fails high.
Apgllsant's
... Actions
... ...._...__. or .Behavior
_. ..-. ..-. __
... . ....-. ...-. .. ....-
Acknow!edge.s annunciator 1 H-H7, S W DUMP VV T R P OPEN.
Acknowledges annunciator cH-A4, Tave - Tref%VIATION.
Places rod control in MANUAL to stop rod motion.
Places Charging Flow Contml in MANUAL and lowers demand to
stop Pressurizer level rise.
Reviews annunciators.
Reviews Tech Specs and identifies no applicable limiting actions.
Notifies I&C of failure.
Notifies OMOC of failures and unit conditions.
Discusses plant operation with Steam Dumps with trip open
demand, B V s with RQ trip close criteria at 554 T7and operation
with rods and charging flow control in M A N A L .
Appendix B Required Operator Actions
Op-Test No.: 2004-301 scenario No.: 1
EventNo.: 4
Event Description: l A Steam Generator Level Transmitter fails low. Ramped to allow
adequate operator response to gain control of SG level prior to trip on s t e m / feed
mismatch.
fedwater, and F W heater oscillations.
channel 3 in trip.
Appendix D Required Operator Actions Form E§-B-2
Qp-T'est NO.: 2804-301 Scenario No.: 1 Page 5 Qf14
EventNs.: 5
Event Description: Pressurizer Pressure Controller (PC-444A / Channel 1) fails high.
Rmped to allow adequate operator response to gain control of pressure.
Position Applicant's Actions or Behavior
WO Diagnose high failure of either PZR Pressure Transmitter p T p - 4 4 or
Master Controller.
- 1C-A$, PRZR PRESS CONTR IllI BUTPUT
- 1C-?38, P Z R LO PRESS
~
1D-H4, PRZR SITY VV PWR FGLDZF VV QPEN
- BC-D7, PRZt PWR RELIEF LINE HI TEMP
- I C W , PRZR RELIEF TANK PRESS
- 1G-F3 & W 0VTE;MP DELTA T TURB R W M & ROD
STOP
Indications:
- MCB meter for pTp-444 reads maximum pressure
- PRZR Master Controller goes to maximum output
- P E R Spray valves go full open
- P o R v 1455c QPnS
- Actual RCS pressure as indicated by MCB for FT-445
lowering rapidly
RO rakes actions IAW Am BC-A$ (Note: actions taken for any other
ARP will delay actions necessary to avoid a Rx Trip OH SI).
- Place Master Controller in MANUAL. and lower output.
- Verify closed or close 1-RC-PCV-1455C.
- Verify closed or close PWZR spray valves.
SRO Directs RO to control pressure U W 1-AP-3 1 .OO. Should note that
6-WC-PCV-1455C is inoperable while control is in manual. SRO
hould review TS 3.1.6. (TS 3.1.6.3 states that with ti PORV
noperable but capable of being manually cycled, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />
- ither restore to operable or close the block valve and maintain
lower to the block valve.)
Appendix D Required Operator Actions Form ES-D-2
@-Test NO.: 2004-301 Scenario No.: 1 pa@?6 of 14
Position Applicants Actions QP Behavior
a0 Maintains RCS pressure JAW 1-AP-31.00
Check RCS pressure lowering
Place I-CH-PC-1444J in MANUN-.
Decrease demand on PRZR Press Master Controller to raise
acs pressure.
Close or verify closed P m R PORvs
Close Block Valve to isolate a PORV that will not close.
Turn QB]pressurizer heaters.
Close or verify closed 1-CH-HCV-1311, Aux Spray
Isolation.
Check Aux Spray Line for leakage. (None should be
detected.)
Place spray valve controllers in MANUAL and adjust
demand to zero.
Zheck Turbine load stable.
Provide notifications to OMOC, STA, and Shift Supervis~r.
Appendix D Required Operator Actions Fom E§-D-2
Qp-Test NO.: 2004-301 Scenario KO.: 1 h@? 9 of 14
EventNo.: 6
Event Description: IC Steam Generator tube le& with failure of Condenser Air Ejector
Rad Monitor auto actions. slowly ramp leak until Condenser Air Ejector Monitor
alarms.
Position Applicant's Actions or Behavior
BOP Diagnose IC Steam Generator Tube Leak as evidenced by
Condenser Air Ejector alarm.
Alms:
- 16-BB, P m LO PRESS
~ 1@-D8,PWZR LU LEVEL
~ 1-RM-GS, C0NH)ENSER Aw EJECTOR
'UER'PIFAEURE
Indications:
- Upscale om 1-SV-N-111
- Upscale on 1-RM-RR- 15QBPen 4
BOP Verifies alarm reading greater than background or radiation level
has trended up by reading 1-SV-IPI-111 or 1-RM-RR-150B Pen 4.
BOP Checks EWCS points using Group 80 Review:
- RlRM204C, MS-RI-124
- W1M205C, MS-WI-125
- W1Rh1[206C9MS-WZ-126
BOP Monitor SG BIowdown Monitors:
- I-SS-RI-112
- I-SS-w-183
SRO Directs verification of automatic actions associated with Condenser
Air Ejector a l m .
AP-16.00, Excessive WCS Leakage
SRU Directs compensatory actions or physical positioning of TV-SV-
102 and TV-SV-103 per ARP I-WM-GE: Attachment 1.
Reposition TV-SV-102 and TV-SV-103 per ARP 1-RM-G8
4tFachrnent 1.
____~ -
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 1 Page 8 of 14
Position Applicant%Actions or Behavior
PRZW level lowering (slight)
Annunciator IlDB5, CHG PP TO REGEN FIX HI-LQ m W
A discemable negative change in VCT level trend has developed.
Note: At this point, these indications will be inconclusive due to
small magnitude of leak.
Directs the following:
Performance of Q-BSP-RC-002,Steam Generator Primary
to Secondary Leakage Monitoring.
Performance of 1-OPT-RC-10.0, Reactor Coolant Leakage
- Computer Calculated.
AP-16.00 Step 3: Verify closed or close normal and excess
letdown isolations:
~ 1-CH-LCV-146OA
1-CH-LCV-146QB
- 1-RC-HCV-1S57A
- 1-RC-WCV-I 557B
- 1-WC-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 FQ
manually trip reactor and proceed to E-Qat this point).
AP-16.00 Step 3: Verify adequate makeup being supplied
by blender and Leak Rate > 50 gpm. (VCT level will be
going down and Leak Rate will be > 50 gpm. This is
another criteria for Rx Trip).
AH-16.00Step 7: Align Charging Pump Suction to the
RWST:
- Open 1-CHI-MOV-1I15B
- Open 1-6H-MOV- 1115D
- Close I-CH-MOV-1115C
Close I-CW-MOV-H 11%
Manual Reactor Trip. Proceed to E-0.
_ _ ~
Appendix D Required Operator Actions Fom ES-D-2
Op-Test XO.: 2004-301 Scenario No.: 1 Page 9 of 14
Event No.: 7 & 8
Event Description: BC Steam Generator tube rupture coincident with Loss of Offsite
Power. #1 EDG fails to auto start, requiring manual start from the Cont~~ol
Room.
Pssitior Applicant%Actions or Behavior
AH Diagnose requirements to trip Reactor. (Also see the previous
event, which will lead into this Event.)
Alms:
- lC-D8, Pam LO LEVEL
- 1D-E5, CHG PP TO REGEN HX HI-LO FLOW
Indications (Pre-trip):
- PRZR pressure and level lowering
- Tavgstable
- Charging line flow rising
- Lowefing feed flow to 1A SG
Indications (POSt-trip):
- Rx trips on QTDT or ]Low PRZR Pressure
- Turbine trip by RXTrip
- Rx trip and bypass breakers open
- Rod bottom lights ape lit
- Generator trip 30 seconds after Rx trip
- AH1 rn pumps S t a t
- HP & LB Heater Drain Pumps trip
- Safety Injection on &ow PKiX pressure
- Phase 1 isolation
AB1 Diagnose Loss of Offsite Power. This malfunction should he
triggered by Reactor Trip.
Alms:
~
1K-H4,4 KV Ei"vERG BUS TIE STUB BUS BKR T R P
- 1K-G6,4 KV RES BUS S U P BKR OPEN
- 1K-E7, CC PPS DBCH HDR LO PRESS
- 0-VSP-A3, DIESEL FzEgE PUMP AUTO START
ndications:
- Breakers lSA1,15B1, 3SC31,15D1, 15E1, 15F1,15A2,
15B2, and 1.322all open.
- EDG 3 auto starts and energizes the emergency bus.
- Emergency stub bus breakers open
- AI1 station service loads are de-energized
- RCPstrip
Appendix B Required Operator Actions
Bp-Test NO.: 2004-301 Scenario No.: 1
Position Applicants Actions OF Behavior
- CCPumpstrip
RO Verify Reactor Trip (E-0, Step 1 - Immediate Action Step)
- Manually trip Reactor
- Check all rod bottom lights lit
Check Reactor Trip and Bypass Breakers open
- Check neutron flux lowering
BOP Verify Turbine Trip (E-& Step 2 - Immediate Action Step)
- Manually trip Turbine
- Verify all Turbine Stop Valves closed
- Close MSR Steam Supply 1-MS-SOV-104
- Verify Generator Output Breaker Open (30 see time
delay)
BOP Verify both Emergency AC Buses energized (E-Q,Step 3 -
hmeciiate Action Step)
EBG #I &id not auto start. EDG must be manually started from
the Control Room. SRO should direct 1-M-10.07,Loss of Unit I
Power, to restore power to the AC Emergency Bus.
Verify both 4160 V Emergency Buses energized. (1-AP-10.07,
Step 2 ) - H Bus will not be energized. RNO directs operators to
Att. 1.
[f any EDG has failed to start, then: (I-A?-10.07, Att. E , Step 2 )
- Put ED6 #1 in EXERCISE
- St&tDG#1
- Place EDG #1 in AUTO
- If ED6 loads, then go to Step 6
f either Emergency Bus energizes and both of the fd8owm.g
iarnpers are not open, then initiate Att. 10: (1-AP-10.07, Step 6)
- I-VS-MOD-103B
- B-VS-MOD-103D
4tt. 10 centins instructions for battery room ventilation. Local
.ctions to open slide dampers, Battery Room 1A door, and
stabhh a fire watch.
SRB Leturn to procedure step in effect. (1-M-10.07, Att. I, Step 8)
SRO :heck if SI initiated. (E-0, Step 4 - bmediate Action Step)
- ~~~~
Appendix D Required Operator Actions Form ES-D-2
@-Test No.. 2004301 Scenario No.: 1 Page 11 of 14
rime Position Applicamt's Actions 01- Behavior
Directs manual initiation of SI after Reactor Trip. Expect SRO
brief.
RQ/BOP Manually initiates SI and verifies 1A-F3 and 1A-W annunciators
lit. (E-Q, Step 4 - Immediate Action Step)
BOP Verify Peedwater isolation. (E-0, Step 5)
- Feed Pump Discharge MOVs closed (l-FW-MOV-1SOA
%6 B)
- MFW Bumps tripped
- Feed Reg Valves closed
- SG F W bypass Wow demand at z e r ~
- SG Blowdown TVs closed
RO Verify CTMT Isolation Phase I. (E-0, Step 6)
- Phase I TVs closed
- 1-CH-MOV-1381 closed
- l-SV-TV-102A closed
- PAM isolation l-DA-TV-183A closed
- PAM isolation 1-DA-TV-103B closed
BOP Verify AFW pumps running. (E-Q,Step 7)
- MD A@w Pumps (time delayed)
- "El AFW Pump (if necessary)
May discuss isolating AI;'w to IC SG with SRO at this time.
WO Verify SI Pumps running. (E-0, Step 8)
- CHG Pumps running
- LIISI Pumps running
a0 :heck Charging Pump Auxiliaries. (50,Step 9)
- CHG Pump CC Pump
- CHG Pump SW Pump
BOP Sheck Intake Canal level > 24 feet and being maintained. (E-0,
,tep 10)
BOP :heck Main Steam Line Isolation required. @-(I, Step B I)
- Check if any of the following annunciators have been lit.
~
E-F-10, HI STEAM FLOW SI - (should he off)
- B-C-4, HI HI CLS TRAIN A - (should be off)
- i HI CLS TWAIN B - (should he off)
B-C-5, H
dlheck if CTMT Spray required (E-0, Step 12)
Appendix B Required Operator Actions Form ES-D-2
Bp-Test No.: 2004-301 Ssenario No.: 1 Page 12 of 14
Applicant's Actions or Behavior
( C T W Pressure should be near pre-event levels - RNO directs
operators to Step 13)
Verify SI flow: (E-0, Step 13)
- "SI to Cold Legs > 0 p m :
- I -SI-F?-1961
- 1 -SI-R-1962
- 1-SI-R-1963
- I -SI-R-1943 or 19434
- Check three CHG Bumps running
- Reset SI
- Stop one CHG Pump and place in AUTO
- Check RCS pressure > 185 psig (should be > 185 psi@
- Verify SI reset
- Stop one LHSI Pump and place in AUTO
Verify total AFW flow > 358 gpm (E-0, Step 14)
Check AFW MOVs open (IC SG may require manual alignment)
(E-0, Step 15)
Verify SI Valve Alignment IAW Att. 2 (BO,Step 14)
- Verify open or open CWG Pump Suction from RWST
- 1-CH-MOV-1115B
- I-CH-MOV-1115D
- Verify closed or close CHG Pump Suction from VCT
- 1-CH-MOV-1I15C
- l-CH-MOV-1115E
- Verify closed or close CHG Line Isolation MOVs
- I-CH-MOV- 12898
- I-CH-MOV-1289B
- Verify closed or close Letdown orifice isolation valves
- I-CH-HCV- 12008
- l-CH-HCV-120B
- I -CH-HCV- 1200C
- Verify open or open HHSI to cold legs MOVs
- I-SI-MOV-1867C
- 1-SI-MOV-1867D
- Verify open or open LHSI suction from WWST MOVs
- I-SI-MOV-I 8628
- 1-SI-MOV-B862B
- Verify open or open LHSI to cold legs MOVs
Appendix D Required Operator Actions Form ES-B-2
Op-Test NO.: 2004-301 Scenario No.: 1 Page 13 of 14
Time Applicant's Actions or Behavior
I-SI-MBV-I 8698
I -SI-MBV- 18443
Verify ventilation alignment and AC power alignment MaW
Attachment 3 (E-0, Step 17) (E-0, An. 3 is attached)
(Only one switch to be manipulated on the Ventilation Panel)
Check RCS Avg Temp stable OH trending toward 547 9. (E-0,
Step 18)
If e 547 'P, then stop dumping steam and reduce MW flow if SS
Levels permit (SG Levels > 12% in at least one SG). If cooldown
continues, then close MSTVs.
If > 547 OF, then dump s t e m via Atmospherics (LOSP -
condenser not available)
Check PFZR PQWVs and Spray Valves: (E-0, Step 19)
- PRZR PORVs closed
- PWZR Spray controls at zero demand (Spray valves
closed)
- At least one PORV Block Valve open.
Check RCP Trip and Miniflow Recirc Criteria (E-0, Step 20)
- HHSI flow to Cold Legs > 0 g~ppn
- RCS Subcooling < 30 F
- WCS pressure < 1275 psig
If RCS Pressure < 1275 psig then close CHG Pump miniflow
recirc valves (1-CM-MOV-1275A Cpr B & C)
Check SG Not Faulted: @-Q Step 21)
- Pressure in all SGs stable or rising
- Pressure in all SGs > 100 psig
Check SG Tubes ruptured: [E-0, Step 22)
- Condenser air ejector radiation > normai
- SG Blowdown Radiation > normal
- SG MS Radiation > normal
- TD AFW Pinnap exhaust > normal
- l A SG level increasing in an uncontrolled manner
Directs transition to E-3, Steam Generator Tube Rupture. (E-0,
Step 22)
Check RCP Trip and Miniflow Recirc Criteria (E-3, Step I )
- " SI flbw to Cold kegs > 0 gpm
Appendix D Required Operator Actions Form ES-B-2
Op-Test NO.: 2004-301 Scenario No.: 1 Page 14 of 14
If RCS Pressure < 1245 psig then close CHG Pump miniflow
recirc valves (1-CH-MOV-1275A 8r B B C)
- Level rise
- SC Main Steam Line Monitor high
- SG Blowdown monitor high
Isolate IC SG (E-3, Step 3 - Critical Task)
- Adjust 16: SG POWV controller to 1035 p i g
- Verify IC! SG Blowdown TVs closed
- Directs local closure of 1-MS-158 (161 supply to TD AFN
Pump)
- Close I C SG MSTV
Isolation o f 1C SG prior to exsting E-3 is a critical task.
Check ruptured SG Level > 12% (E-3, Step 4)
Flow to 116 SG must be maintained until level > 12%.
When level > I%%,AFW flow to IC S B shall be stopped.
Zheck P%RZPORVs and Block Valves (E-3, Step 5)
- Check power available to Block Valves
Check PRZR PORVs closed
- Ensure at least one P E R PORV Block Valve open
- heck if SG not faulted. @-39Step 6 )
Check pressure stable or rising in all SGs
- Check pressure > B O psig in all 3 0 s
- Any A R SG Level >12%
- Check emergency buses both energized (RNO should p 1 ~ 1
need to be. performed if bus was restored by manually
starting #I EDG earlier in scenario. However, local
isolation of AFW header on H Bus may be necessary if H
Bus not energized. 1-Ew-141/ 156 / 171)
- Control AFW flow to maintain 22 to 50% in I A 63c 1B
beset both trains of SI (E-3. Steo 8)
Appendix D Required Operator Actions Form ES-B-2
Op-Tesli NO.: 2084-301 Scenario No.: 1 Page 15 of 15
Appiicants Actions OF Behavior
BOP Verify Instrument Air Available (E-3, Step 10)
- Check Annunciator W E 6 not lit.
- Check at Least one CThlT Instrument Air Compressor
running.
- Verify 1-IA-TV-108 open.
BOP Align Condenser Air Ejector to CT,W (E-3- Step 11)
- Verify 1-SV-TV-182 open
- Verify 1-SV-TV-103 closed
- Open 1-SV-TV-102A
BQPIRO Verify all AC buses energized by offsite power. (This will not be
the case. EDGs will be powering buses). @-3>Step 12)
SRQ 3irect implementation of 1-AP-10.07. Loss of Unit 1 Power (if
lot already implemented). (E-3, step 12)
RO :heck if LHSI Pumps should be stopped. (E-3, Step 13)
- Check RCS pressure > 250 psig
- Stop LHSI Pumps and piace in AUTO.
BOP :heck IC SG isolated from 1B and la SGs @-3, Step 14)
- Check 1@SO MSTV or NRV closed.
- Check 1C SG pressure > 358 psig.
nitiate RGS Cooldown (E-3. Step 15)
- Determine required core exit temperature (SW TIME):
- Lowest Ruptured SG P Qpsig) GET (OF)
1001 - 1085 495
901 - 1008 485
~ 801 - 900 470
- 701 - 800 455
601 - 700 440
- 501 - 608 420
401 - 500 400
~ 350 - 400 385
- Place Steam Dump Mode Select Switch in Steam Pressure
Mode.
- C O ~ ~ ~ atOmaximum
- Check CETs Iess than required temperature
- Stop COOldow~
- Maintain CETs less than required temperature
Appendix B Required Opemtor Actions Form ES-D-2
Op-Test No.: 2004-381 Scenario No.: B Page 16 of 16
'ime Applicant's actions or Behavior
This step should be completed prior to depressurizing.
Check ruptured SC pressure stable or rising (E-3, Step 14)
RO Check R c S subcooling based on CETs > 50 F
RO Depressurize RCS to minimize break flow and refill PRZR (E-3
Step 18)
- Check n o m d spray available and WCPs A & C running
(normal sprays will not be available and RCPs will be off)
- RNO directs to Step 19
ritiC&l E
] a0 Depressurize RCS using PRZR PORV to minimize break flow
and refiSl PRZR (53, Step 19 - Critical Task)
- Check at least one PRZR PORV available
~
Open one PRZR PORV until any of the foliowing
conditions edst:
- P U R Level > 49%
RCS Subcooling based on CETs < 30 "F
~
PWZR Level > 22% & RCS P < 1c SG P
...- ....-. .....-
SCENARIO CQh.TPI,ETE ONCE RCS I S TSEPRESSIIRLZED. ...-. ..-. ...__
Appendix D Scenario Outline Farrn ,ES-D-1
e
Facility: Surry
Examiners: Operators:
&gTAMbbiCb
2
. he3
Initial Conditions: dA3LB as+-cce&cd/p 7-3
50% Reactor Power 1 - 1.Sh-3
Known leakage in 1A Steam Generator
Thunderstorms are approaching from the West
1-EH-P-MP2 (EHC Pump) is Tagged Out of Service for Thermal O ~ e r l ~ aReplacement
d
TUtT?QVer:
Shift orders are to maintain power at 50%.
Description
p.,
actuate. Manuai actuation from the control room is
Appendix H) Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: 2 Page 1 of 16
EventNo.: 1
Event Description: Bearing Cooling Water Pump trips and standby pump fails to auto
start.
Applicants Actions or Behavior
Acknowledges 1B-G2,BC HElR LO Pressure.
I
f BOP Acknowledges 1K-D2,4KV BKR AUTO TRUP.
Identifies loss of I-BC-P-1B and failure of I-BC-P-IA to automatically start
on low system pressure.
Manually starts 1-BC-P-la.
Verifies running amps on 1-BC-P-IA 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-TBs breaker
1568.
Directs RO to dispatch Turbine BLDG operator to locally investigate
conditions at BC pumps.
Place control switch for 1-BC-P-1B in PTL position
Direct Electrical 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 2 of 16
Event No.: 2
Event Description: Letdown Divert Valve fails open
Applicants Actions or Behavior
Identifies normal make-up in progress to VCT.
~~
Identifies 1-CH-LCV-1115A diverted to PDT.
Identifies L -CH-LCV-l115A controller demand at 100% for unknown
reason
May utilize A W lD-Gl, VCT HI-LO L W for guidance based on normal
make-up flow ability to maintain VCT level.
Direct RO to place 1-CK-LCV-I B 15A controller in Manual rend reduce
demand to align 1-@N-LCV-11 15A to VCT position or place controi switch
for 1-CH-LCV-I 115A in N O M position.
Performs the directed action to align 1-CH-LCV-1I 1 514 back to VCT.
Performs a focus briefon the failure and actions in progress.
-.....-..... .... ...-. ...-
Directs I & C: Maintenance te investigate the faiiure of 1-CI-I-1.W-11I5A
contrsller.
Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions
Op-Test No.: 2004-301 Scenario No.: 2
Event No.: 3
Event Description: Selected 1' Stage Turbine Pressure Transmitter fails low
Applicant's Actions or Behavior
Acknowiedges annunciator 1 H-A4, Tavg > < T r d DEVIATION.
-..-. . ..__ .._. .__ .-. .. ..- ..- ._ ...-
Acknow!edges annunciator I H-H?, S l M I N J 3 W T W OPEN
Identifies control rods are stepping due to Stage Turbine Pressure
Channel 3 Transmitter failure low.
Directs RO to place control rods in Manual.
Piaces control rods in Manual to stop the rod motion.
Identifies Main FRVs are reducing SG levels to the no load setpoint based
on Channel 3 failure.
Reviews annunciator response procedures for remaining of alarms
Reviews Tech Specs Section 3 7 and identifies TS Table 3 7-1 items 20 b 6t
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 4-3
item 2a requiring Operator .4ctiOn #20, 72 hour8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> dock to place channel in
trip
Performs focus brief on failure and actions in progress Discuss plant
impact with Stm Dump trip open signal and Main FRVs due to falure
I
SRQ Notifies I & C Maintenance to place channel in trip.
Directs RQ to perform I-QPT-KP-O0I, CHECK OF IT3%h4ISSIVE
STATUS LIGHTS P-6, P-'3, P-8, AND P-10, to verify permissive status
lights are correctly illuminated.
Pedorms 1-QPT-RP-O0I, CHECK OF PERMISSIVE. STATUS LIGHTS P-
6, P-7, P-8, AND P-10 and reports results of completed OPT to SRO.
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004301 Scenario KO,:2 Page 4 of 16
Event No.: 3
Event Description: Selected 1' Stage Turbine Pressure Transmitter fails low
Applicant's Actions or Behavior
Directs BOP to swap instrumentation channels in accordance with perform
I -0P-RP-001, ALIGNING CONTROL SYSTEM FOR PEwFORhgANCE
OF CN.4". I, II,IlI, AND IV PROCESS AND PROTECTION
TESTING.
Performs 1- 0 P - a - 0 0 1 to swap instrumentation channels. Should note that
this procedure ndi not be completed before proceeding to next event
~
Notifies Shift Manager and ST.4 of failure and actions in progress.
I I
Appendix D Required Operator Actions Form ES-B-2
Op-Test NQ.: 2004-301 Scenario No.: 2 Page 5 of 16
Event N o . : H b
Event Description: Selected 1B Steam Generator Steam Flow Transmitter fails high
Identifies B SG Steam Flow channel failed high (1-MS-LT-lXXX).
Direst BOP to place B Main FRV in Mamual and restore B SG level.
Takes manual control of B Main FRV and reduces feedwater flow to
restore Ievel.
Reviews AM%.
Performs focus brief on failure and actions in progress.
Reviews Tech Specs Section 3.7 and identifies TS Table 3.7-1 items 17
requiring Operator Action #6; identifies TS Table 3.7-2 item le 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.
Notifies I & C Maintenance to place channel in trip
May elect to swap controlling Steam Plow channel to IV for B SG in
accordance with 1H-%, STM GEN IB LVL ERROR
- Return Ievel to program
- Select redundant channel
- When level returned to normal, then place FRV in AUTO.
Notifies Shift Manager and STA of failure and actions in progress.
Appendix 19 Required Operator Actions Form ES-D-2
Bp-Te~tNO.: 2004-301 Scenario No.: 2 Page 6 of 16
Event No.: 5
Event Description: Pressurizer Level Controller fails low
0fde~ /A/$%aY&b
Applicants Actions or Behavior
Acknowledges annuciator lC-BS, P W R LO LVL.
Identifies CHG flow reduction.
Identifies CMG flow controller output demand at 0%.
Directs RO to take manual control of CHG flow and return CHG flow to
normal.
Takes CWG flow controller tu MWAk amd increases CEIG flow to
normal.
Notifies IRrC Maintenanw to investigate the failure.
Perform foms brief on failure and actions in progress.
Notifies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions FOITTI
Op-Test No.: 2004-301 Scenario NQ.: 2 Page 7 of 16
Event No.: 6
Event Description: Tavg Taylor Math Unit fails low
Appendix D Required Operator Actions FOP^ ES-B-2
Op-Test No.: 2004-301 Scenario No.: 2 Page 8 of 16
Event No.: 7
Event Description: Turbine Governor Valve fails closed. R a m p in slow enough for
BOP to detect and respond.
Time
I
Appendix D Required Operator Actions F o ES-D-2
~
Qp-Test No.: 2004-301 Scenario No.: 2 Page 9 of 16
Event No.: 8,9, Br 10
Event Description: LBLOCA - Auto Reactor Trip, Turbine fails to trip, and both trains
of Safety Injection fail to automatically actuate. Manual actuation from the control room
is *&&N 0 u r p o r &L& dL .p Ot-4
Time AppBicsnts Actions or Behavior
Acknowledges annunicators.
Identifies decreasing RCS Pressure
RO Identifies automatic Reactor Trip and initiates 1-E-0 Immediate Actions.
SRO Directs performance of 143-0 Immediate Actions.
BOP Acknowledges annunciators while RO performs I-E-0 Immediate Actions.
RO/SRO Verifies Reactor Trip ( E O > Step 1 - Immediate Action Step)
- Manually trip Reactor
- Check ail Rods On Bottom Light lit
- Check Reactor Trip and Bypass Breakers open
- Check Neutron flux lowering
RQ/SRO Verify Turbine Trip (E-0, Step 2 - Immediate Action Step)
(Event 9) - Identify that Turbine failed to automatically trip
- Manually trip the turbine by pressing both Trip Pushbuttons
- Identify all Turbine Stup Valves dose
- Close MSR Steam Supply 1-MS-SOV-I04
- Verify Generator Output Breaker open (39 second time delay)
ROISRB Verify both Emergency A@Buses energized (E-0, Step 3 - Immediate
Action Step)
RO/SRQ Check if SI is actuated. (E-0, Step 4 - Immediate Action Step)
Event 10) - Identify that ST failed to automatically actuate.
-
e hlanualiy actuate both trains of SI d~~~~~~~ d e w h e 53
- Verify LHSI pumps running
- Verify SI annunciators lit
- A-F-3
- A-F-4
Appendix 6) Required Operator Actions Form ES-D-2
Bp-Test No.: 2004301 Scenario No.: 2 Page 10 of 16
AipBicants Actions or Behavior
Verify FW Isolation. @-a, Step 5)
- Feed pump discharge MQVs closed (l-PW-MBV-lSOA & B)
- MFW pumps tripped
- Peed Reg valves closed
- SG FW bypass flow demand at zero
Verify CTMT Isolation Phase T (E-0, Step 6)
- Phase I TVs closed
- 1-CH-MQV-1381 closed
- I-SV-TV-102A OS&
- PAM Isolation vaives 1-BA-TV-103A closed
- PAM Isolation valves I-DA-TV-IO3A closed
Verify AFW pumps Running (EO, Step 7 )
- MD AFW Pumps running (time delayed)
- TD AFW Pump running (time delayed)
Verify SI Pumps Running (E-0, Step 8)
- CHG Pumps running
- LHSH Pumps running
Verify CHG Pump Auxiliaries (E-0, Step 9)
- CHG Pump CG Pump running
- CHG Pump SW Pump running
Check Intake Canal. (E-07Step 10)
- Leve1.24FT
- Levef being maintained by CW Pumps
heck if Main Stearnlines should be isolated (,E-(&Step I I )
- Check if any ofthe following annunciabars have been lit
- I S T E M FLOW SI - (should be of%)
E-F-10, H
- B-@-4,HI HI CLS TRAIN A - (should be on)
- B-C-5, HI M CLS T W N B - (should be on)
- Check MSTVs closed
- Check either ofthe following actuated
- Hi Steam flow SI - (should be no)
- Header to line SI - (should be yes)
- Verify RWST crosstie valves open
- 1-SI-TV-102A & B open
- 2-SE-TV-262A & B open
- Check RCS pressure < 185 PSIG - (should be yes)
Appendix D Required Operator Actions F o ES-B-2
~
Qp-Test NO.: 2004-301 Scenario No.: 2 Page 11 of 16
Applicants Actions OF Behavior
Check if CTMT Spray Required. (E-0, Step 12)
- CTMT pressure has exceeded 23 &a
- Manually initiate Hi Hi CLS
- TripallRCPs
- Verify 63s pumps running
- Check HSRS pumps running (Time Delayed)
- Check OSRS pumps running (Time Delayed)
- Initiate Attachment I, CLS Component Verification
Low PRZR pressure SI signal should be blocked when P M K pressure
decreases < 2000 psig
- Blocks Low P U R pressure SI signal by using bIsck switches
High steam flow SI signal should be blocked when T a w decreases <
543°F
- B l ~ c k High
s steam flow SI signal by using the block switches
CHG pumps should be mn in the following order of priority: CIB, A
Verify SI Flow. (E-0, Step 13)
- HHSI to cold legs flow indicated
- 1 -SI-FI-1961
- 1-SI-FI-1962
- 1-SH-FH- 1963
- 1-SI-BP- 1943 or I943A
- Check three CHG Pumps running
- Reset SI
- Stop one GHG Pump and place in AUTO
- Check WCS pressure 185 psig (should be < 185 psig)
- Identie LHSI flow indicated.
Verify Total AFW flow 350 gpm [450 gpm]. (E-0, Step 14)
Check AFW MOVs open. (E-0, Step 15)
Veri@ SI Valve Alignment IAW Att. 2 (E-Q, Seep 16)
- Verify open GHG Pumps Suction from RWST MBVs
- l-CM-MQV-1115B
- 1-CH-MBV- 1I 15D
Verify closed CHG Pump Suction from VCT MOVs
- 1-CH-MOV- I I 156
- 1-CH-MOV- 1115E
Verify closed CHG Line Isolation MQVs
- 1 -@H-MOV-l289A
- 1-@H-MOV-1289B
Appendix B Required Operator Actions Form E§-D-2
Scenario No.: 2 Page 12 of 16
Position Appk?ant's Actions or ]Behavior
RO/SWC Verify SI Valve alignment IAW Att. 2. (50, Step 14) CQNTINLED
- Verify open HHSI to cold legs h/lBVs
- l-SI-MBV-1867C
- I-Si-MQV-I867D
- Verify open LHST suction from RWST MOVs
- I-SI-MOV-1862A
- I-SB-MQV-1862B
- Verify open LHSI to cold legs MaVs
- 1-SZ-MOV-1864A
- I-SI-MMBV-1864B
Unit 2 Verify ventilation alignment and AC power alignment IAW Attachment 3
OPR (E-0, Step 17) @-Q Att. 3 is attached)
(Qnly 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 547'F
- Identifgr not dumping steam and control total feed flow. Maintain >
450 gpm [450gpm] until NW IeveE > 12% [18%1] in at least one SG.
- Identify MSTVs closed
ROiSRQ Check PRZR PORVs and Spray Valves: (E-0, Step 19)
- PRZR PORVs closed
- P U R Spray controls at zero demand (Spray valves closed)
- At Ieast One PORV Block Valve open
- heck RCP Trip and Miniflow Recirc Criteria. (E-0, Step 20)
HHSI flow to Cold legs indicated
RCS Subcooling e 3 0 T [85"F]
Stop ail RCPs
Identify RCS pressure 1275psig [I475 psiel
Close CHG Pump miniflow recirc valves (l-CH-MOV-l275A, W, Br C)
- heck SG Not Faulted. @-Q>Step 2 1)
Pressures in all SGs stable for plant conditions
Pressures in all SGs 100 p i g
- heck SG Tube ruptured. (E-0, Step 22)
Condenser air ejector radiation - normal
SG Blowdown radiation - normal
SG hlS radiation - normal
TB M W Pump exhaust - normal
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 2 Page 13 of 16
Position Applicant's Actions or Behavior
RO/SRO Check RCS Intact Inside CTMT. @-0? Step 23)
- CTMT radiation normal
- CTMT pressure > normal
SKO Directs transition to E-l, Loss ofReactor or Secondary Coolant
STA Identify Red Path on CSF Status F-4 Integrity requiring transition to FR-
P. 1
SRO Directs transition to FR-P. 1, Response to Imminent Pressurized Thermal
Shock
Check RCS Pressure > 185 psig [250 psig] (FR-P.l, Step 1)
- Identify RCS Pressure < 185 psig [a50 p i g ]
- Identifsr LHSI pump flow > 1000 gpm
- E T U R N $0 procedure and step in effect.
Directs transition to E-1, Loss of Reactor or Secondary Coolant
Check RCP Trip and Miniflow Recirc Criteria. @-I; Step 1)
- HE-ISI f l to ~Cold~legs indicated
- RCS Subcooling < 30'F [85"F]
- Identify all RCPs stopped
- Identify RCS pressure 1275psig 61475 psig]
- Identify CHG Pump miniflow recirc valves (l-CH-MQV-l295A, B, B
C) closed
Check SG Not Faulted. (El, Step 2)
- Pressures in all SGs stable far plant conditions
- Pressures in ali S a 100 psig
Zheck Intact SG Levels. (E-1, Step 3)
- NR level > 12% [I8%]
- Check emergency buses both energized
- Control feed flow to maintain NR level between 22% and 58%
BOF!SRO :heck SG Tube mptured. (E-1, Step 4)
- Condenser air ejector radiation - normal
. SG Blowdown radiation - normal
. §G MS radiation - normal
Ti3 AFW Pump exhaust - normal
SG NR level not increasimg in an uncontrolled manner
Appendix D Required Operator Actions Form ES-D-2
Op-Tst No.: 2004-301 Scenario No.: 2 Page 14 of 16
Time Position AppIicant's Actions or Behavior
ROiSRO If any P W R PORV opens because of high F U R pressure, the PORV
must be verified closed or isolated afkr pressure decreases to less than
2435 pig. (E-1, Caution prior to Step 5)
RO/SRQ Cheek PRZR PORVs and Block Valves. (E- 1, Step 5)
- Power to PRZR PORV block valves available
- PKZR PORVs closed
- P U R PORV block valve at least one open
RQ/SRO Check If SI Flow should be reduced @-I? Step 6)
- RCS Subcooling based on CETCs 30°F [85"H]
- (30 TO Step7
WO/SRO Check If Hi Hi CLS Initiated. (E-1, Step 4 )
- Identify RS Pumps running
- Idcnti@ Hi Hi CLS annunciators lit
RO/SRO Verify Service Water Available. @-I>Step 8)
- Check Intake Canal level being maintained by CW Pumps
- GOT012
Check If CTMT Depressurization Equipment can be stopped. @-I9 Step
1 a>
- CTMT pressure < 12 psia
- Reset both trains of CLS
- Stop OSRS Pump(s) and put in AUTQ
- Stop CS Pump(s) and put in AUTO
- Close CS Discharge valves
- 1-CS-MBV- 101A
- l-@S-MOV-IOlB
- 1-CS-MOV- 101e
- I-CS-MOV-lO1D
Close CHEM ADD TK OUTLT valves
- 1-cs-haoV-102A
- I -CS-MBV- I02B
. Operate ISRS Pumps with SW aligned to maintain CTMT pressure
CCS Pressure should be monitored. TfRCS Pressure decreases in an
ncontrolled manner to < 250 psig [400 pig], on LHSI pump must
ianually restarted to supply water to RCS. @-I> Caution prior to Step 13)
Appendix D Required Operator Actions Form ES-D-2
Qp-Test NO.: 2004-301 Scenario No.: 2 Page 15 of 16
Time
___ Position Applicants Astions or Behavior
RBISRO Check IfLHSI Pumps should be stopped. (E-1, Step 13)
- Check RCS pressure 250 psig [400 psig]
- GO TO Step 15
__
ROISRO Check IfEBGs can be stopped. (E-1, Step 15)
- Veri@ AC ernergency buses energized by ofissite power.
- Reset both trains of SI, ifnecessary (should not be)
- Stop any unloaded EDGs IAW Attachment 1, Stopping Unloaded
EDGS
- WO direct the Sewice BLBG operator to secure EDGs ZAW Att. 1
ROISRO Verify Instrument Air Available (23-1, Step 16)
- Check annunciator B B - 6 not lit (should not be)
- Check at least one CTMT fA compressor running (should be one)
- Verify both trains of CLS reset (should be reset)
- Manually open 1-1A-TV- 100
ROISRB Initiate Evaluation of Plant Status. (E- 1: Step 17)
- Verify cold leg recirculatisn capability
- Power to LHSI Pumps available
- Power to the following SI valves avairable
- 1-SI-MQV-1863A & 3
- 1-SI-MOV-18858 $t B
- l-SI-MOV-1885B & C
- l-SI-MBV-I860A & B
- I-SZ-MQV-I862A &B
- I-SI-MOV-1115B & D
- Check auxiliary building radiation - normal
- Kaman vent-vent monitors - normal
- Auxiliary Building Control area monitor -normal
~
Consult with TSC on need ta obtain any ofthe folIowing samples
- RCS
- Boron
- Activity
- CTMTSump
- Boron
- Pl-H
- Activity
- CTMT Atmosphere
-m
- Activity
Appendix D Required Operator Actions Form ES-D-2
Qp-Test NO.: 2004-301 Scenario Ne.: 2 Page 16 of 16
- SGS
- Activity
- Sodium
- PH
- Conductivity
- Boron
- Initiate evaluation of plant equipment
- Electrical Distribution
- Safeguards
- WatedGaseous supply and storage
- Radiation Monitoring
- %cleat Instrumentation
- CVCS
- Ventillation
- Past-Accident Monitoring
- Instrument Air System
Appendix D Scenario Outline Form ES-D-I
f
Facility: Surry
initial Conditions:
Reactor Power is 75%
a m f P
Known ieakage in 1A Steam Generator
Thunderstorms are approaching from the West
Turnover:
Shift orders are to raise power immediately following turnover.
Description
I I I
I I
(Njorrnal, (W)eactivity, (I)nstrurnent, (C)ornponent,
Appendix D Required Operator Actions Form ES-D-2
Qp-Tesb No.: 2004-301 S~enarioNo.: 3 Page I of21
Event No.: 1
Event De$CPiptiQn:Raise power. (Rods initially should be positioned to prompt
dilution, as opposed
~
Time Position
TEAM Conduct brief for raising _ power
_ in accordance with 1-QP-TM-005. Unit
Ramping Operations
TEAM Review I-OP-TM-OQS: Section 5.3, Preparations for Turbine Ramp Up.
- Identifies that last shift completed Section 5.3
TEAM Review 1-OP-TM-005, Section 5.4, Power Increase Between 50% 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.
SROIBOP Commence the power increase at the ramp rat iced by Shift Manager
- Recall the Shift Manager directed setting the Load Rate
Thumbwheel. -w ISS-md/Av
- Using the Load Rate % per %finthumbwheel, rotate until setting of 8
is displayed.
- Initiate power increase by depressing the GO pushbutton
Initiate dilution and use control rods as required to maintain A B in band.
- Observe the expected response on
- FR- 1- 113, BA-PRO WTR Fhw
- d86-114A, PWI WTR SUP BATCH Integrator
-
SROXO Identi@ that b 0 is high in the band, SO dilution would be preferred prior to
outward rod motion.
RO [nitiate dilution
Appendix D Required Operator Actions
Bg-Test No.: 2004-301 Scenario No.: 3
Event No.: 2
Event Description: FT-CH-1114, Primary Water Flow XMTR fails low
AppBicants Actions Behavior
Identifies normal dilution to VCT stops and investigates why no PG flow
indicated.
Acknowledges annunciator 1D-A4,
Directs BOP to stop the ramp to stabilize plant conditions based on the
fai lure.
Stop the turbine ramp by depressing the HOLD pushbutton.
Reviews annunciator alarm response 1D-A4.
Reset the blendes controls back to AUTO.
Performs a focus brief the failure and actions in progress
Directs I & C Maintenance to investigate the failure.
Notifies Shifi Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions F O HES-D-2
~
Scenario KO.: 3 Page 3 of21
Event No.: 3
Event Description: I-CN-P-l A, Condensate Pump Performance Degradation ramped in
to require timely operator response. Failure of standby pump auto stant. Manual start
required
J
Appendix D Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scenario No.: 3 Page 4 of21
Event No.: 4
Event Description: Selected 1.4 Steam Generator MFW Flow Transmitter fails low
- Return level to program
- Select redundant channel
hifi Manager and STA of failure and actions in progress
Appendix D Required Operator Actions Form E§-D-2
Bp-Test No.: 2604301 Scenario No.: 3 Page 5 of 21
Event No.: 5
Event Description: 1A SG PORV Controller fails high
Appendix D Required Operator Actions Form ES-D-2
OB-Test No.: 2004-301 Scenario No.: 3 Page 6 OF 21
Event No.: 6
Event Description: IsaIable letdown line leak in containment
Applicant's Actions QP Behavior
Acknowledges annunciator 1B-A3, CTMT SURP HI LEVEL
~
Identifies increasing CYhtT Sump level with CTMT Sump pump running
in auto.
Acknowtedges annunciator 1D-A4, PRI WTR TO BLEND DEVIATION
FLOW
Implements AP-16.Q0, EXCESSIVE RCS LEAKAGE.
~~~
Identifies LTDW flow at zero
If SI Accumulators are isolated I-@- 16 0 1, SHUTDOWN LOCA should
be used or guidance RCS average temperature has a direct impact on
pressurizer level (APB6 00, Notes prior to Step 1)
Increase CWG flow using I-CH-FCV-1122 in manual to maintain P U R
level at program setpoint, as necessary (AP-16 00, Step 1)
- Identifies PWR level at setpoint
Check RGS leak rate (AI?-16 00, Step 2 )
- PRZR !eve$decreasing (should not be)
- Annunciator D-3-5 lit (should not be)
- Go TO Step 12
Check a@% leak rate < 10 gpm (AP-16 80, Step 12)
- Initiate unit shutdown IAW W P
- Control CHG flow and seal injection to maintain P U R level
- Evaluate E P P applicability
Check Unit Conditions stable (-4P-1600, Step 13)
- P U R level (should be)
- PRZR pressure (should be)
- Taw (should be)
Check Letdown Ieak indicated (AP-16 00. Step 14)
- Identifies annunciator lB-M, CTMT Sump Hi Lvl lit
Appendix D Required Operator Actions Form ES-D-2
Bp-Test No.: 2004-301 Scenario No.: 3 Page 7 of 21
- 1-CM-LCV- 1 4 6 0 ~
- I-RC-HCV-l557A, 14, & c
- 1-M-HCV- 1142
Perform focus briefon failure and actions in progress.
Chec.k RCS leak rate with letdown secured reduced. (AP-16.00, Step 16)
- Identifies letdown leak st0ppe.d following securing letdown isolations
Place intact Letdown System in service IAW Shift Supervisor direction.
ce Excess letdown IAW 1-OP-CH-886
eviews precautions and limitations
erify all of the following Loop Drain header isolation valves are
I-RC-HCV-1557A7B, SZ C (should be)
H-HPCV- 1201, Excess LDTN HX ISOL valve is
dosed Iqhould be)
- Verify 1- H-HK-1137, Excess LDTN Flow setpoint is zero
(shouldh be
!
- Verify 1-Cd\FCV-i389, Excess LDTN Divert is in the VCT
(should be) \.,
- Verify open 1-C@-MO\r- 13 8 1 RPCP Seal Return (should be)
~
- Verify running at'lqast one cc ~ u m (should p be)
- Verify FI-CC-109; b T N HX Outlet Flow is indicating =: 140
gpm (should be) '\,\
- Notes the reset switch lbcated on the RFW flats must be held in
the open position until I-~C-HCV-IOS opens h11y.
- Verify TI-CC-108, LDTNNX Outlet temp is indicating ambient.
'\
(should be) '\
- Veri5 1-CH-FZ-I 138, Excess CQT" FIX Outlet pressure is
indicating Z= 50 pisg (should be) '~,\
- Verify 1-CH-TI-I 139, Excess L D h HX Outlet temp is
indicating ambient. (should be) "\
- Notes the first 50 gallons of Excess L D W flow should be
directed to the PDTT so that the Excess kDTN flow is not
returned to the RCS. \
- Places 1-CH-HCV-I389 Excess LDTN Divertualve to the PDTT
position to flush the Excess LBTN pwi
Appendix D Required Operator Actions Form BS-D-2
Qp-Test No.: 2004-301 Scenario No.: 3 Page Iof 21
AppBicmts Actions or Behavior
Place Excess letdown MW I-OP-CH-OD6 (Continued)
- Verify I-CH-Pi-1138, Excess LDTN MX Outlet pressure
indicates = 10 psig (should be)
Open 1-CH-HCV-1201, Excess LDTN HX HSQI
Veri@ 1-CH-FI-1 122A, GHG Line flow is stable and record the
\flow (should be zero)
iews caution about potential leak points downstream of the
caution about only one loop drain valve may be open
0 0 T , to prevent the possibility of bypassing SI flow to
ct loops in a DSA, due tQ h o p cross-connect through
Drain header isolation valve 1-RC-HCV-I 557A
rate can be calculated by using 1-D@-
level changes is = 1S gallons
- Notes Attachment ed to lower P U R level if required
- Slowly open 1-CH ,Excess LBTN Flow using 1-CHI-
HC-1137 until zz 15 s established to the PDTT
- Verify TI-GC-108, L tlet temp indicates I50F
- Veri@ I-CH-TI-I 139, Excess E X Outlet temp indicates c:
195OF
- When the PDTT level has increa 10% as indicated on
\
GO TO 31 (AP-16.00, Step 18)
Check RCS leak rate. (Ap-16.00, Step 3 1)
- Unidentified leakage less than 1 gpm (should be)
- Stabilize unit conditions
Perform RCS leak sate
Evaluate source of leakage unit operation may contain if none of the
following exists. (M-16.00, Step 3 2 )
- A non-isolable fault in an RCS component body, pipe well, vessel wall,
or pipe weld
END OF AI-16.00
Appendix D Required Operator Actions Form ES-D-2
Qp-Te~tNO.: 2004-301 Scenario No.: 3 Page 9 of 21
be brought to HSD within 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />.
Appendix D Required Operator Actions Form BS-D-2
Bp-Test No.: 2004-301 Scenario No.: 3 Page 10 of 21
Event No.: 7
Everf' ~escription:Loss of Semi-vital Bus. Bus will not be recoverable
~
Applicant's Actions or Behavior
Acknowledges numerous annunciators
Identifies loss of Semi-Vital Bus by observing zero voltage on indicator.
Reviews annunciators.
9
- Identifies condenser vacuum decreasing
- Directs placing condenser hoggers in service
- Identified GS System in service
Condenser
- 1-VP-4
- 1-VP-4
__ -.
I
--
Appendix D Required Operator Actions Form ES-D-2
io1 S@C!DaB.iQ NQ.: 3 Page 11 of21
Applicants Actions or Behavior
- 1-VP-19
- 1-VP-20
- Open Nogger steam supply valves
- 1-as-19
- 1-AS-20
- Open Hogger suction valves
- I-VP-I
- 1-w-2
- Make entry in Narrative Logs that Hoggers are in service
- Notify IIP Count Room that Hoggers are in service
Power tu the Steam Header Pressure MitnuallAuto station has been lost,
h the associated controller in Auto-Hold with fixed output demand. The
minutes. The PORVS will continue to control in
setpoint set on the MCR ManuaUAuto station
- ontrolier to shift to Relay rack at last setpoint which faiied low.
nually close 1-MS-86.
Or
9. WHEN fault corrected then
ause.
Appendix D Required Qperator Actions Form E§-D-2
Bp-Test NO.: 2004-301 Scenario Yo.: 3 Page 12 Of21
Applicants Adorns or Behavior
Perform focus brief on failure and actions in progress.
Breaker 15 for Unit I and Breaker I S on Unit 2 Semi-vital Bus should be
opened before performing the following step. (AP-I 0.05, Note prior to
Step 9)
Directs the Electrical Department to swap the Gai-tronics power supply to
unit 2 semi-vital bus (Junction Box in Unit 1 ESGR). (AP=10.05, Step 9)
~ alternate steam release will be required to keep the Main Stean
es from lifting. (AP10.05, Caution prior to Step 10)
- I-CV-P-lA&
- 1-BA-P-4A & B,
- 1 -DG-P- 1A & B, Pri ain zXFER Pumps
Locally Transfer NRC Supply as necessary.
[AP-10.05, Step 12)
- Direct Service
necessary (should be
no)
Secure the following as necessary
- BR-P-SA & B, Stripper Circ Pumps (S~SU~C! b
- BR-P-4A & B, PRT DRW TK PP
- Check LW and BR Panels for failed indications and c
Appendix D Required Operator Actions Form E§-D-2
Op-Test NO.: 2004-301 Scenario No.: 3 Page 13 of 21
AppBicants Actions or Behavior
Monitor the following components which have failed indications. (Ae-
10.05, Step 14)
- RCPS
- Instrument and Service Air
- rnWPumps
autoiatically shifted to unit 2. (m-1
- SROBO Direct Service BLDG op check power supply
alignment
Appendix D Required Operator Actions Form E§-D-2
Op-Test No.: 2004-301 Scenario No.: 3 Page 14 of21
Event No.: 8, 9, 10, & 11
Event Description: Main Steam Line Break in Containment in 1A Steam Generator.
Auto and Manual Reactor Trips fail. Failure of one Hi CLS Train fails to activate.
Failure of B -CC-TV- 1 OSA (CCW return from RCP 1A) to close an Phase ID Isolation
Time Position Applicants Actions or Behavior
RO Acknowledges annunicators.
RQ Identifies decreasing RCS Pressure and Temperature with control rods
stepping out .
TEAM Identifies abnormal indications on K 9SG and inside CTMT
KQ Identifies failure automatic Reactor Trip and initiates 1 - E 4 Immediate
Actions.
SRO Directs performance of 1-E-0 Immediate Actions.
Acknowledges annunciators while RO performs Immediate Actions.
Verifies Reactor Trip @-0, Step 1 -Immediate Action Step)
- Attempts to manually trip Reactor
- Identifies failure of both Reactor Trip Pushbuttons
- Informs the TEAM
Directs performance of I -FK-S. 1 Immediate Actions.
Verify Reactor Trip. (FR-S.-l, Step 1)
- Manually insert control rods
- Afler Turbine tripped return the control rods to automatic
Verify Turbine Trip (PR-S.l, Step 2)
- Verify ail turbine stop valves closed (should not be)
- Manually trip the turbine
Verify AE;W Pumps Running. (FR-S.1, Step 3)
- Identifies MD AFW Pumps running (should be)
- Identifies TD AFW Pump running (should be)
Initiate Emergency Boration ofRCS. (FR-S. 1, Step 4)
- Verify CHG flow > 75 gpm (should not be)
- Identifies SI in service, so CHG Pump suction align to RWST
- Verify P U R pressure 2335 psig (should be)
Appendix D Required Operator Actions FOITIIES-El-2
OpTest No.: 2004-301 Scenario No.: 3 Page 15 Of 21
Position Applicants Actions or Behavior
TEN If an SI signal exists or occurs, Attachment I should be performed while
continuing with this procedure. (FR-S.1, Caution prior to Step 5)
TEAM Identifies SI occurred due to Hi CLS
TEN Hdentifies AMSAC initiated a Reactor Trip by opening MG set breakers.
SROiRO Directs performance of Attachment 1, Verifying Steps 1 through 13 of I-E-
0.
- Verify Reactor Trip - dispatch an operator to perform local trip
- Verify Turbine Trip - isolate reheaters by closing 1-MS-SQV-104
- Verify both AC Emergency Buses energized (should be)
- Identifies SI initiated - manually initiate SI
- Verify FW Isolation (should be)
- Verify CTMT Isolation Phase 1 (should be)
- Veri@ M W Pumps mnning (should be)
- Verify SI Pumps running (should be)
- Check CHG Pump Auxiliaries running (should be)
- Check Intake Canal > 24 FT and level being maintained by CW Pumps
- Check ifMain Steamlines should be isolated (should be)
- Cheek if CS Required > 23 psia
- Manually initiate Hi Hi CLS
- Trip aH1RCPs
- Initiate Attachment 2, CLS Component Verification
- Manually close 1-RM-TV-lOOC (HI CLS Train failure)
a - Manually close 1-Kh.I-TV-IOOA (Hi CLS Train fdure)
- Manually close 1-CC-TV-IOSA (Component failure)
- Blocks Low PRZR pressure and High Steam Flow SI signals
- Verify SI flow (should be)
- Reset both trains of SI
- Stops A CHG Pump and put in AUTO
- Identifies RCS pressure I85 psig
- Stops one LHSl Pump and put in AUTO
SROWOP :heck if the following trips have occurred (FR-S. 1, Step 5)
Reactor Trip (depends on ASMSAC)
- Direct Service BLDG operator to open Unit 1 Reactor Trip
Breakers
Turbine Trip (should be)
Uternate water sources for AFW Pumps will be necessary if ECST leveh
fecreases 20%. (FR-S. 1, Caution prior to Step 6 )
Identifies ECST level 9 20%
Appendix D Required Operator Actions Form ES-I3-2
Position Applicants Actions or Behavior
SWQ/BgPP Check SG Levels. (FIX-S. 1, Step 6)
- Check NR level in at least one SG 12% (should not be)
- Verify total feed flow > 708 gpm
- Control feed flow to maintain NR level between 22% and 50%
Verify all dilution paths isolated. (FR-S. 1, Step 7)
- Put PG PUMPcontrol switches to OFF
- Close PG to Blender Flow Control Valve, l-CH-FCV-1114A
- Veri@ PRT PG outside TV, I-RC-TV-1519A dosed (should be)
- Initiate Attachment 3, PG Isolation
- Directs Auxiliary BLDG operator to complete Att. 3
Check for Reactivity Insertion from uncontrolied RCS Cooldown @It-
s 1, Step 8)
- RCS temperatures decreasing in an uncontrolled manner (should be)
- A SG pressure decreasing in an uncontrolled manner (should be)
- Identifies A SG faulted inside CTMT
Check MSTVs closed. (FR-S 1, Step 9)
- Identifies MSTVs closed on Hi Hi CLS
- 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 Hf all
SGs are faulted, at least 60 gpm El00 gpm] feed flow should be maintained
to each SG. Ifthe TD AFW Pump must be maintained from at least one
SG (EX-S.I, Cautions prior to Step B I)
Isolate FauIted SG(s). (FR-S. 1, Step 11)
- Isolate W W line
- Close A SG PW isolation MOV, l-FW-MOV-154A
- Locaily close feed REG bypass valve manual isolation valve, 1-
FW-26
- Locally close steam supply valve to TB AI;W Pump, 1-MS-87
- Close or verify closed SG PORV (should be)
- Close or verify closed SG b1owdown TVs (should be)
- heck CETCs 1200°F (FR=S.l, Step 12) (sho~ldbe)
Appendix D Required Operator Actions Form ES-B-2
Op-Test No.: 2004-301 Scenario No.: 4 Page 13 of 21
Time
s _
Applicants Actions or Behavior
If adverse CTMT conditions have been exceeded, the Gamma-Metrics
Excore Neutron Monitor system (Source and Wide Ranges) should be used
t~ monitor neutron flux for the duration ofthe event. (FR-S. 1, Note prior
to Step 13)
Verify Reactor Subcritical. (FR-S.1, Step 13)
- Check power range channels < 5% [Gamma-Metries Wide Range
Power] 5% (should be)
- Check the following
- Intermediate range channels negative startup rate [Gamma-
Metrics Wide Range Power decreasing]
- or
- Shutdown margin IAW 1-OF-RX-002, SHUTDOWN MARGIN
(CALCULATED AT ZERO PQWR) > 1.73%
Boration s h ~ u kbe
i continued to obtain adequate shutdown margin during
subsequent actions. (FR-S.1, Caution prior Step141
Return to procedure and step in effect.
Transitions to I-E-0, Step 1
Perform transient brief on failures and actions in progress.
Verifies Reactor Trip (E-0, Step 1 - Immediate Action Step)
- Identifies Reactor was tripped by AMSAC
- Check all Rods On Bottom Light lit
- Check Reactor Trip and Bypass Breakers open Iocally
- Check Neutron flux lowering
Verify Turbine Trip (93, Step 2 - Immediate Action Step)
- Manually tripped the turbine by pressing both Trip Pushbuttons
- Identify all Turbine Stop Valves close
- Close MSR Steam Supply I-MS-SOV-IO4
- Verifi Generator Output Breaker open (30 second time delay)
Verify both Emergency AC Buses energized (E-0, Step 3 - Immediate
kction Step)
Appendix D Required Operator Actions F o m ES-D-2
Qp-Test No.: 2004-301 Scenario No.: 3 Page I8 of21
- veri@ ~ H Spumps
I running
- Veri@ SI annunciators lit
- A-F-3
- A-F-4
30P/SRO Verify FW Isolation. @-Ox Step 5)
- Feed pump discharge MQVs closed (1-FW-MOV-150A & B)
- MFW pumps tripped
- Feed Reg valves closed
- SG FW bypass flow demand at zero
WO/SRO Veri& CTMT Isolation Phase I. (E-0, Step 0)
- Phase I TVs closed
- 1-CH-MBV-1381 closed
- 1-SV-TV-1028 C ~ S S ~
- P A M Isolation valves l-DA-TV-lO3A closed
- PAM Isolation valves 1-DA-TV-103A closed
- CHG Pumps running
- LHSI Pumps running
- Level being maintained by CW Pumps
Appendix D Required Qperator Actions Form ES-D-2
Bp-Test NO.: 2004-361 Scenario No.: 3 Page 19 of 21
Applicant's Actions or Behavior
Check $Main Steamlines should be isolated. (33, Step 11)
- Check if any ofthe following annunciators have been lit.
- E-F- 10, HT S T E M FLOW SI - (should be OB^)
- B-@-4,HI HI CLS TRAIN A - (should be on)
- B-C-5, HI HI CLS T W B - (should be on)
- Check MSTVs closed
- Check either ofthe following actuated
- Hi S t e m flow SI - (should be no)
- Header to line SI - (should be yes)
- Verify KWST crosstie valves open
- I-SI-TV-102A $r B open
- 2-SI-TV-202A & B open
Check RCS pressure < 185 PSIG - (should be no)
=heck if CTMT Spray Required (E-0, Step 12)
- CTMT pressure has exceeded 23 psia
- Manually initiate Hi Hi CLS
- Trip all RCPs
- Veri@ CS pumps running
- Check ISRS pumps running (Time Belayed)
- Check QSRS pumps running (Time BeIayed)
- Initiate Attachment 1, CLS Component Verification
,ow PRZR pressure SI signal should be blocked when P U R pressure
lecreases < 2800 psig
BEocks LSW PR%R pressure SI signal by using block switches
ligh steam flow SI signal should be blocked when Tave decreases <
i43'F
Blocks High steam Bow SI signal by using the block switches
- HG pumps should be run in the following order of priority. C, B, A
Jerify SI Flow. (E-0, Step 13)
- HHSI to cold legs flow indicated
- 1-SI-PI- 1961
- 1-SI-PI- 1962
- 1-SI-FI-1963
- 1-SI-FI-1943 or 19438
- Check t h e e CHG Pumps running
- Reset SI
- Stop one 6 H S Pump and place in AUTO
- Check RCS pressure 185 psig (should not be)
rerify Total AFW flow > 350 gpm [450 gpm]. @-Q Step 14)
Appendix E) Required Operator Actions Form ES-D-2
Op-Test No.: 2004-301 Scemario Ne.: 3 Page 20 of 21
~
Time Position Applicant's Actions or B e h a ~ i ~ r
BQP/SRC Check AFW MOVs open. (E-0, Step 15)
Verify SI Valve Alignment IAW Att. 2. (E-0, Step 16)
- Verify open CHG Pumps Suction from RWST MOVs
- 1-CH-MOV- 1115B
- 1-CH-MBV- 1115D
- Verify closed CHG Pump Suction from VCT MOVs
- I-CH-MOV- 11 15C
- 1 -CH-MOV-l115E
- Verify closed CHG Line Isolation h?lBVs
- l-CH-MOV-1289A
- 1-CH-MQV- 1289B
- Verify open NHSI to cold legs MOVs
- l-§I-MOV- 1867C
- l-SI-LWQV-I86919
- Verify open LHSI suction from RWST MOVs
- 1-SI-MOV-18628
- 1-SI-MOV-1862B
- Verify open LHSI to cold legs MQVs
- I-SI-MQV-1864A
- I-SI-MBV- 18643
Verify ventilation alignment and AC power alignment IAW Attachment 3
)3-0,Step 17) (54, Att. 3 is attached)
- Only one switch to be manipulated on the Ventilation Panel)
?heck RCS Avg Temp stable or trending towards 547°F.(E-0, Step IS}
- Identify 547°F
. Identi6 not dumping steam and control total feed flow. Maintain >
350 gpm [450 gpm] until WR level > 12% [IS%] in at least one SC.
. Identify MSTVs closed
- heck PRZR PQRVs and Spray Valves: (E-0, Step 19)
P U R PQRVs closed
PRZR Spray controls at zero demand (Spray valves closed)
Ai least one PORV Block Valve open
- heck RCP Trip and Miniflow Recirc Criteria. (E-0, Step 20)
HHSI flow to C d d legs indicated
RCS Subcooling > 30CF[ W F ]
Appendix D Required Operator Actions PQrIIIES-D-2
Scenario No.: 3 Page 21 of21
- Pressures in all SGs > 108
Appendix D Scenario Outline Form ES-D-1
Examiners: Operators:
Initial Conditions:
700% Reactor Power
Preparing to conduct partial rod movement testing.
Turnover: Off normal conditions for Unit 1: 1-KC-HCV-1557A (Excess Letdown) is isolated
due to Ieakby, 1-EH-P-MP2 (EH6 Pump) is tagged out for thermal overload replacement.
Unit 2 is at 100% power with 2-FW-P-2 (TDAFW Pump) tagged out for governor replacement.
9
I I
M 1 (ALL) Main Steam bine Break at header ( 5 0 ,E-2)
t I I
12 M (ALL) RCS bleed and feed
i
(M)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor
Appendix D Required Operator Actions Form ES-D-2
Op-Test N O .: 2004-301 Scenario No.: Spare Page 1 of22
Event No.: I
Event Description: Conduct Rod Movement Testing (1-OPT-RX-005)
PARTIAL MOVEMENT
(OPT-RX-005, Section 6 1)
Bank Overlap Verification and Documentation (OPT-KX-005, Section 5 2 )
- Record the step counter DEMAND POSTN for control banks A, R, and
c
- Direct an uperator 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 BEMAhD POSTN for control
bank D
- Determine the diEerence between BOG and control bank B
- Identifies the difference is 384
SRORO Control Bank D COPT-RX-005, Section 6 3)
- Turn the ROD CQNT -MODE §EL switch to CBD
- Record the baseline rod position on the Withdrawn line in Attachment 1,
Table 1, Control Bank I3
- Insert Control Bank D 12 steps
- Complete the Inserted line in Attachment I, Table 1
- Withdraw Control Bank B 12 steps
- Calculate in Attachment 1, Table I the Control Bank D Insertion and
compare with the Reference
I I I
Appendix D Required Operator Actions Porn1 ES-D-2
Qp-Test No.: 2004-301 Scenario No.: Spare Page 2 of22
Position A p p h m t ' s A c t h s or Behavior
SRO/KQ Control Bank C (OPT-RX-005, Section 6.4)
- Turn the ROD CON" MODE SBL switch to CBC
- Record the baseline rod position on the Withdrawn line in Attachment 1,
Table 2, Control Bank C
- Insert Control Bank C 12 steps
- Complete the Inserted line in Attachment I, Table 2
- Verify 1G-B5, COMPU PRINTOUT ROD CONTR SYS is lit
- Verify 16437, ROD BANK C LO L M T 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 Enor This will leave rods at 230
steps and prevent rod group 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
- Caiculate in Attachment 1, Table 2 the Control Bank 6 Insertion and
compare with the Reference.
- Veri@ alarms 1G-B5 and 1G-B7 are not lit
SRO/RO Control Bank 3 (OPT-RX-005, Section 6 . 5 )
- Turn the ROB CONT MODE SEL switch to CBB.
- Record the baseline rod position on the Withdrawn line in Attachment 1,
Table 3, Control Bank B
- Insert Control Bank B 12 steps
- Complete the Inserted line in Attachment 1, Table 3
- Verify 16-B5, COMPU PRINTOUT ROD CONTR SYS is lit
- Verify 16436, ROD BANK B LO L M T is lit.
- Notes that in the event the Group 1 and Group 2 Step Counters ape 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.
- Calculate in Attachment 1, Table 3 the Control Bank B Insertion and
compare with the Reference
- veri^ alarms BGB5 and 1G-B6 are not lit.
Appendix D Required Operator Actions Form ES-D-2
Qp-Test NO.: 2004-301 Scenario No.: Spare Pa@! 3 Qf22
Time Position
SIPOBO
1 - Turn the ROD COXT MODE SEL switch to CBA.
- Record the baseline rod position on the Withdrawn line in Attachment 1,
Table 4, Control Bank A.
- Insert Control Bank A 12 steps.
- Complete the Inserted line in &4ttachment1, Table 4
- Verify lG-B5, COMPU PRHNTOUT ROD CONTR SYS is lit.
- Verify 16-B5, ROD BANK A LO LLMT is lit.
- Notes that in the event the Group I and Group 2 Step Counters are mot
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.
- Calc.ulate in Attachment 1, Table 4 the Control Rank A Insertion and
compare with the Reference.
- Verify alarms 1'3435 and 1GB5 are not lit.
Shutdown Bank B (OPT-RX-005, Section 6.4)
- Turn the ROD CONT MODE SEL switch to SBB.
- Record the baseline rod position on the Withdrawn line in Attachment 1,
Table 5, Shutdown Bank B.
- Insert Shutdown Bank B 12 steps.
- Complete the Inserted line in Attachment,1, Table 5
- Verify 16435, C O W U FNNTOUT 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 rod group misalignment.
- Withdraw Shutdown Bank B to 235 steps as indicated by the Group Step
Demand Counters.
- Pulse the Group G o u p 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 alarm 1G85 is net lit.
1 I I
Appendix D Required Operator As.tions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: Spare Page 4 of22
Applicants Actions or Behavior
Shutdown Bank A (OPT-RX-005, Section 6 8)
- Turn the ROB CONT MODE §EL 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 sreps
- Complete the Inserted line in Attachment 1, Table 6
- Veri@ BG-B5, COMPU PRINTOUT 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 pievent 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 G o u p Step Demand Counters down io 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 B G-B5 is not lit
SRORO Rods in Automatic, and Bank Overlap Verification and Documentation
(OPT-RX-005, Section 6 9)
- M e r verifying that Tavg is within 5 l°F of Tref, then put ROD CONT
MODE SEL switch in AUTO
- Record the step counter DEMAbD POSTK for control banks A, B. and
c
- 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 R 8 records the step counter DEMAND PBSTN for control
bank D
- Determine the diEerence between BO@and control bank B
- Identifies the difference is 384
SRORO Follow-On. (OPT-RX-085, Section 7.0)
- Evaluate the test results by reviewing the Acceptance Criteria.
- Identifies the rods are inserted 12 steps, the GPI and GP2 step
counter Insertion is 12.
- Identifies when the rods are inserted 12 steps, the WPI 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.
I I I
Appendix D FOMIES-D-2
Op-Test NO.: 2004-301 Page 5 of 22
Event No.: 2
Event Description: P E R pressure transmitter fails high (1-RC-PT-1445).
Time Position
R8 Closes P U R PORV that open due to instrumemtation failure.
Verifies PRZR pressure recovering following the opening of P U R PORV
Performs a focus brief on the failure and actions in progress.
Reviews annunciator response procedures.
Evaluates Tech Specs sections 3.1 .A.6, 3. I .G, and 3.12.F. Declare P E R
PORV, 1-RC-PCV-1456 inoperable and close PRZW PORV block valve, 1-
RC-MQV-1535 within o g - h z r If PRZR pressure decreased < 2205 psig
then identify a two-hour to restore PBPZR pressure
SRO Directs I B C Maintenance to investigate the failure of 1-RC-PT-1445,
BRZR Pressure control channel.
SRO Kotifias Shift Manager and STA of failure and actions in progress.
Appendix D Required Qperator Actions
Op-Test NO.: 2'304-301 Scenario Noo: Spare
Event No.: 3
Event Description: P U R PORV Leakage (I-RC-PCV-1455C)
Time Position Applicant's Actions or Behavior
RO Acknowledges annunciator lC-F?, PRZR RELIEF TK HI PRESS.
Identifies P U R pressure decreasing and reviews annunciator response
procedures.
Acknowledges annunciator 1C-D4, P U R PWR W L E F LINE HI TEMP.
Direct implementation of AP-3 1 00, INCREASING OR DECmASIYG
RCS PWESSURE.
Check Turbine Load stable. (AP-3 1 00, Step 1)
Check RTS pressure decreasing. (AP-31.06, Step 2)
- Identifies RCS pressure is slowly decreasing.
Decreasing RCS pressure will cause the QTAT setpoint to decrease. (AP-
3 I .OO, Caution prior to Step 3 )
- Monitor OTAT setpoint.
PZR PQRV I-RC-PCV-1455C shoiald be declared inoperable when the
Master Controller is placed in Manual. (AP-3 1.00, Note prior to Step 3 )
Stop Pressure Decrease. (AP-3 1.00, Step 3)
- Place l-CH-PC-1444J, P U R P E S S MASTER CKTRL in
MAW&.
- Decrease demand on PKZR PRESS MASTER CNTRL to raise RCS
pressure.
- Declare PaZR PORV inoperable
Check RCS pressure still decreasing. (AP-3 1.00, Step 4)
- Identifies RCS pressure is still decreasing.
Veri@ no pressure loss through the PRZR PORVs. (AP-3 1.00, Step 5)
- Close or verify dose P W R PORVs
- Close Block M 8 V to isolate any PQRV, which will not close or is
leaking.
- Identifies when the remaining Biock MQV closes RCS pressure will
start increasing.
Appendix I9 Required Operator Actions Foran BS-B-2
Qp-Test No.: 2004-301 Scenario No.: Spare Page 7 of 22
Event No.: 3
Event Description:
Applicants Actions or B~laavior
Turn on ail PRZR heaters. ( M - 3 1.OO, Step 6) (should be)
Verie closed or close 1-CH-HCV-1311, AUX Spray I s ~ l i & ~ .(AP-3 I .OO,
Step 7) (should be)
Check ALJX Spray line leakage suspected. (Ap-3 1.OO, Step 8) (should not
be)
- GOTO §tep 10
Place Spray valve controllers in Manual and adjust demand to zero. (AI?-
31.00, Step 10)
- Places both spray valves controllers in Manual.
- Verifies demand at zero
Check either of the following conditions. (AP-3 I .OO, Step 11)
- Identifies both spray valves closed.
Identifies spray valves not leaking to abnormal PRT conditions.
- Go TO Step 13
Check RCS Pressure stabilizing or increasing. (-31 .OO, Step 13)
- Identifies R.CS pressure increasing following closing last P U R BORV
block valve.
- TO Step 17
Peturn PRZR PRESS MASTER CNTRL and P U R Spray Valve
- ontrollers back to AUTO.
3vaiuates Tech Specs sections 3.2.A.6,3.1.6, and P.12.F. Declare PR%R
JOKV, 1-RC-PCV-1456 inoperable and close PRZR PORV block valve, 1 -
IC-MOV-1535 within one-hour. If P U R pressure decreased 2205 psig
hen identify a two-hour to restore ]PUR pressure. Determine RCS leak
ate after stabilizing plant conditions.
iotifiies Shift Manager and STA of failure and actions in progress.
Appendix D Required Operator Actions Form ES-D-2
Bp-Test No.: 2004-301 Scenario No.: Spare Page 8 of 22
Event No.: 4
Event Description: Unit Load Reduction (AP-23.00)
Position AppBicrant9sActions O F Behavior
BOP Acknowledges annunciator 1E@, GEN LEADS CLG TKBL
+ W r w h p- wck&?M. &t5 Pa%.
Direct the Turbine BLDG operator to local annunciator panel to inwstigate
cause of alarm.
Reviews annunciator response procedure while awaiting field report
Perform ARP 1G-E5, GEN LEELBS CLG TREK
- Turbine BLDG operator reports Low &r Flow due to a loss of A
lsophase Bus Duct Cooling (BDC) Fan
- Reviews cautions
- If one or more fan is inoperable, a unit ramp down to the self
cooled rating 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 s h ~ u l dcontinue fiom 78% to
14,250 m p s at normal rate of 155 MWehKR
- Reviews note in accordance with OPAP-0006, Shift Operating
Practices, at the discretion sfthe Shift Supervisor, the thermal overload
devices may be reset only once.
- Attempt to restart Pran
- Dispatch operator to check circuit breaker MCC 1A2-2-1B. GEN
LEADSCLR PH A Pan
- Report from field is the breaker is tripped
- Initiate a ramp down to reduce generator amps to 14,250 amps in
accordance with 8-AP-23 00, W D LOAD REDUCTION
- G8 TO Step 8 to initiate work request to repair B D C fan
Votify Electrical Maintenance to investigate failure of the IBBC Fan
Yotifies Shift Manager and STA of failure and actions in progress.
Directs M-23.60, Rapid Load Reduction based on loss of WDC Fan.
3onservative decision-making must be maintained during rapid load
aiuctions. If uncertain or degrading conditions arise which could
idversely affect the safety ofthe plant, or if any criteria in Attachment 1 is
- xceeded, the load reduction should be terminated by tripping the Reactor
)r the turbine, or both, depending on power level. (AP-23.00, Caution
xior to Step 1)
Appendix D Required Operator Actions Form ES-D-2
Bp-Test No.: 2004-301 Scenario No.: Spare Page 9 of22
actions should continue at Step 25.
- RCS Tave must be maintained 5 579F and RCS pressure 2 2205 psig.
Tech Spec 3.12.P.1 should be reviewed if either parameter is exceeded
- I&C should be contacted to provide assistance with adjusting IRPIs.
Initiate Plant Load Reduction at I % M N T E or less. (Ap-23.00, Step 1)
- Verify turbine valve position not on limiter. (should not be)
- Insert control rods in AUTO or I M W A % as necessary to maintain
Tave and Trefmatched.
- Veri5 or place Turbine in WLP INPd.
- Adjust LOAH> RATE %/ thumbwheel to 1%MINramp rate.
- Initiate Turbine load reduction using OPERATOR AUTO.
- Perform emergency boration for 30 to 60 seconds IAW the following:
- Verify or r i s e CHG flow to 9 95 gpm
- Transfer the in-sewice BATP to FAST
- Open 1CH-MOV-1350
- Momitor EMER BORATE: FLOW
- After required emergency boration, perform the following:
- Close 1-CH-MOV-1350
- Transfer the in-senlice BATP to AUTO
- Restore CHG Bow control to normal
- Establish a continuous 10 gprn normal boration to maintain control rod
position above the LO-LO- insertion limits.
- Check all PRZR heaters energized.
- Contra! ramp rate to maintain RCS pressure 2205 psig.
- Monitor steam dumps for proper operation.
- Reduce Turbine valve position limiter as load decreases.
Appendix D Required Operator Actions Form ES-D-2
Op-Test NO.: 2004-301 Scenario No.: Spare Page 10 of22
- VPFLP-2802, Notifications and Report applicability
Appendix D Required Operator Actions Form ES-D-2
Qp-TESt No.: 2004-301 Scenario No.: Spare Page 11 of 22
Event Yo.: 5
Event Description: HA Steam Generator Level Transmitter fails low (1-FW-LT-1476)
Applicants Actions or Behavior
Acknowledges annunciators associated with the SG levels and high
Identifies A SG channel 3 faiied low (1-FW-LT-1476).
Direct BOP to place A Main FRV in Manual and restore A SG level.
Takes manual control d A Main FRV and reduces feedwater flow to
restore level.
_ I
I Reviews W s .
Performs focus brief on failure and actions in progress.
Reviews Tech Specs Section 3.7 and identifies TS Table 3.7-1 items 12 B 17
requiring Operator Action #6; identifies TS Table 3.7-2 item 3a and TS
Table 3.7-3 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 trig.
Notifies I B C Maintenance to place channel in trip.
Notifies Shift Manager and STA of failure and actions in progress.
Required Operator Actions Form ES-D-2
Seenaris No.: Spare Page 12 of22
Event No.: 6
Event Description: 1B SG POW E -MS-R7 C
Appendix Id Required Operator Actions Form ES-D-2
Op-TeSt No.: 2604-301 Scenario No.: Spare Page 13 of 22
Event No,: 7, 8, 9>10, & 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 punips trip.
MSTVs fail to close (I-MS-TV-101A 3, & C). B & G Main Steam MXVs fail close.
Time
_s
Position Applicants Actions or Behavior
Acknowledges annunciators.
RQWQP Identifies decreasing SG and RCS Pressure, along with RCS temperatures.
RB Identifies automatic Reactor Trip and initiates 1-E-0 Immediate Actions.
Directs perfbrmance of 1-E-0 Immediate Actions.
Acknowledges annunciators while RQ performs 1 8 - 0 Immediate Actions.
Verifies Reactor Trip (E-0, Step 1 - Immediate Action Step)
- Manually trip Reactor
- Check all Rods On Bottom Light lit
- Check Reactor T ~ and p Bypass Breakers open
- Cheek Neutron flux lowering
Verify Turbine Trip (E-0, Step 2 -Immediate Action Step)
- Manually trip the turbine by pressing both Trip Pushbuttons
- Identify ai1 Turbine Stop Valves close
- Close MSR Steam Supply I-MS-SOV-104
- Verifi Generator Output Breaker open (30 second time delay)
Ver@ both Emergency AC Buses energized @-Q3 Step 3 -Immediate
Action Step)
Check if SI is actuated. (E-Q?Step 4 - Immediate Action Step)
- Manually actuate both trains of SI
- Verifi LHSI pumps running
- Verifi SI annunciators lit
- A-P-3
- A-F-4
May take actions BO isolate the steam break by:
- Attempting to close MSTVs using control switches and App Ha
Emergency closure switch (Vertical Board 2)
- Closes A MS hXV and attempts to close B & G MS NwVs
Appendix D Required Operator Actions Form ES-D-2
Qp-Test Me.: 2084-301 Scenario No.: Spare Page 14 of 22
Position Applicants Actions or Behavior
SRODOP Veri@ FW Isolation. (E-0,
. , Step 5)
- Feed pump discharge MOVs &sed (l-FW-MOV-150A & B)
- mw pumps tripped
- Feed Reg valves closed
- SG FW bypass flow demand at zero
Verify CTMT Isolation Phase I. @ Step- (I,
4)
- Phase I TVs closed
- I-CH-MOV-1381 closed
- 1-SV-TV- I02A closed
PwR/B Isolation valves I-DA-TV-103A closed
- PAM Isolation valves 1-DA-TV-1038 closed
SROBOP Veri@ AFW pumps Running. ( 5 0 , Step 4 )
(Event 9) - Identifies mw Pumps nQt running
- Lockout annunciators lit for both mw Pumps
- Identifies TD AFW Pump not running
- Identifies no exhaust steam flow indicated for AFW Pump
SRCB Direct Unit 2 Operator to crosstie M W and supply Unit I IAW Bp-
50.00.
RO/SRO Verify SI Pumps Running. @-O> Step 8)
(Event 8 ) - Identifies BCHG Pump tripped
- Identifies A and C CHG Pumps not running
- Identifies no lockout annunciators lit
- Manually start Aand CyCHG Pumps
- LHSI Pumps mnning
Veri@ CHG Pump Auxiliaries. @-O> Step 9)
- GPEG Pump C@ Pump running
- CHG Pump SW Pump mnning
Check Intake Canal. (E-0, Step 10)
Level>24FT
- Level being maintained by CW Pumps
Appendix D Required Operator Actions Form ES-B-2
Bp-Test NO.: 2004-301 Scenario No.: Spare Page 15 OF 22
Iinne Applicants A C ~ ~ QorI IBehavior
S
Check if Main Stearnlines should be isolated. (E-0, Step 1I)
- Cheek if any ofthe following annunciators have been lit.
- E-F-10, MB STEAM FLOW SI (should be on)
- B-C-4, HI HI CLS TEMN A (should be o w
- B-(2-5, Hl HICLS TRAIN B (should be OR)
- Attempting to close MSTVs using control switches and App R
Emergency closure switch (Vertical Board 2)
- Closes AMS NRV and attempts to close B C C MS NRVs
- If annunciator E-H-10 (Header to line SI) (should be yes)
- Verify RWST crosstie vaalves open
- 1-SI-TV- 1028
- l-SI-TV-102B
- 2-SI-TV-202A
- 2-SI-TV-2Q2E
- Check RCS pressure 185 psig (should not be)
Check if CTMT Spray Required. (E-0, Step 12)
- CTMT pressure has exceeded 23 psia (should not be)
- IfCTMT pressure has exceeded 17.7 psia (should not be)
- GOTOStep 13
Review notes. (E-0, Notes prior to Step 13)
- Low P U R pressure SI signal should be blocked when PRZK pressure
decreases < 2000 pig
- Blocks Low PRZR pressure SI signal by using block switches
- High steam flow SI signal should be blocked when Tam decreases <
543°F
- Blocks High steam flow SI signal by using the block switches
- CHG pumps should be pun in the following order of priority: C, B, A
Verify SH Plow. (E-0, Step 13)
- SI to cold legs flow indicated
- 1-SI-FI- 1961
- I-SI-PI-1962
- 1-SI-1963
- 1-SI-FI-1943 or 1943A
- Check three CHG Pumps running
- Reset SH
- Stop one CHG Pump and place in AUTO
Check RCS pressure 185 psig (should be > 185 pig)
Appendix B Required Operator Actions FOETIES-D-2
Bp-Test No.: 2004-301 Scenario No.: Spare Page 16 of 22
Event No.: 12
Event De$CriptiQEI:RCS Bleed and Feed
Position Appticant's Actions or Behavior
SROWOP Verify Total AFW flow 350 gpm [450 gpm]. @-0, Step 14)
- Identifies no AFW Pumps running
- AFW flow < 350 gprn
GO TO FR-H. 1
SIP0 Transitions to FR-3.1
Reviews Cautiomrs. (FK-H.1, Cautions prior to Step 1 )
- If total feed flow 359 gpm 8450 gpm] due to operator action, this
procedure shouId not be performed.
- Peed Bow should not be reestablished to any faulted SG if a non-
i TEAM
-
faulted SG is available.
Check if Secondary heat sink is required: (TIR-H.1, Step 1)
- RCS pressure > any non-faulted SG pressure (should be)
RCS hot Beg temperature > 350°F (should not be)
- Try to put ILPHfp system in service while continuing this procedure.
Refer to 1-OF-W-001, RHR OPEKATIQNS. If adequate cooling with
RFR is established, then RETURN TQ procedure and step in effect.
TEAM Review caution. (FR-H. 1, Caution prior to Step 2)
- If wide range level in any 2 SGs 7% [22%] or PRZR pressure >_ 2435
I psig due to loss of secondary heat sink, RCPs should be tripped and
I
Steps 10 through 27 should b < @ Z 6
Identifies that 2 SGs < 7% [22%] on wide range level indication and
actions required by the Caution or eke Comtinuous Action Page
i--
~~
Stops all RCPs.
I
Reviews caution. (FR-H. 1, Caution prior to Step 10)
- Steps 10 through 17 nust be performed quickly in order to establish
RCS heat removal by RCS bleed and feed.
Veri@ stopped or stop all RCPs pR-H.1, Step lo)
- Identifies ai1 RCPs stopped.
Appendix B Required Operator Actions F o ES-D-2
~
Bp-Test No.: 2004-381 Scenario No.: Spare Page 17 sf 22
- Manually initiate SI
- Identifies SI was already in service.
Verify RCS Feed Path: (FR-H. 1, Step 12)
- Check CHG Pumps at least one running (should be two)
- Verifl SI valve emergency alignment
- CHG Pump suction from RWST MOVs opened (should be)
- 1-CH-MQV- 11% & D
- CNG Pump suction from VCT MOVs closed (should be)
- l-CH--V8%1-115B &E
- HHSI to cold leg opened (should be)
- I-SI-,MOV-I867C B D
- Verify HHSI flow to cold legs (should be)
m e w s no
If an SI signal is actuated afler completion of Step 13, the SI signal should
for reset permissive.
- CTMT pressure < 14 psia (should be)
- Reset both trains of CLS, if necessary (should not be)
t Air available: (FR-H 1, Step 15)
annunciator BB-6 not lit (should not be)
- Check at least one CTMT EA compressor ninning (should be)
- Verify 1-1A-W- 100 open (should be)
- Opeti both both PRZR PORV block valves
- Open both PRZR PORVs
Verify adequate RCS Bleed Path: (FR-H.1, Step 17)
- P E R FQRVs both open (should be)
- FRZR PORV block valves both open (should be)
I
Appendix D Required Operator Actions
Op-Test No.: 2004-301 Scenario No.: Spare
Time Applicants Actions or Behavior
Initiate Attachment 4 while continuing with this procedure. (FIX-E3 1, Step
18)
- Veri@ Reactor Trip (should be)
- Veri@ Turbine Trip (should be)
- Verify both A@Emergency Buses energized (should be)
- Identifies SI actuated
- Verify FW Isolation (should be)
- Verify CTMT Isolation Phase I (should be)
- Verify AFW Pumps running (should not be)
- Verify SI Pumps running (should be two)
- Check CHG Pump Auxiliaries running (should be)
- Check Intake Canal > 24 PT and level being maintained by CW Fumps
- Check $Main Steamlines should be isolated (should be only A SG)
- Check if CS Required > 23 psia (should Rot be)
- Blocks Low P M R pressure and HighSteam Plow SI signals
- Verify SI flow (should be)
- Reset both trains of Sh (should be)
- Identifies RCS pressure > 185 psig
Stops one LHSI Pump and put in AUTO
Maintain RCS Heat Removal: (PR-H.1, Step 19)
- Maintain SI flow
- Maintain RCS vent paths open
Reviews caution. (FR-H. 1, Caution prior to Step 20)
If containment pressure increases to > 23 pia, containment spray should
be verified
Check if 6 s should be stopped. (FIR-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)
- Condensate flow (IAW Step 7)
Appendix D Required Operator Actions F o m ES-D-2
op.-Test No.: 2004301 Scenario No.: Spare Page 19 of 22
Applicants Actions or Behavior
Try to establish AFW flow to at least one SG: (FR-H.1, Step 2 )
- Check SG blowdown TVs closed (should be)
- Verify M W MBVs open (should be)
- Identities that B and 6SG faulted and isolate AFW MOVs to both
SGS.
- Check ECST available (should be)
- Check AFW available
- Identifies can not start AFW Pumps and carries out RNO
- Identifies minimum feed flow net established, then do the
foilowing
- StopRCBs
- Have Unit 2 operator close Unit 2 AFW MOVs
- Have Unit 2 operator open MOV-FW- I60A & 3
- Have Unit 2 operator start both AFW Pumps (TD
AIaW Pump 00s initial conditions)
- Control M VI flow to maintain total flow to SG 350
T
gpm [450 EPml.
- Identifies AFW flow establish to K SG via Unit 2 AFW
crosstie.
Check for adequate Secondary Heat Sink: (FR-H.1, Step 22)
- NR level in at least one SG 12% [ 18%]
- Identifies NR level in ASG increasing
. RETURN to Step 21
Appendix D Kequired Operator Actions Form ES-D-2
Op-Test No.: 2004301 Scenario No.: Spare Page 20 of 22
Appendix D Required Operator Actions FOIXIBS-D-2
Qp-Test NO.: 2004-301 Scenario Ns.: Spare Page 21 of 22
Appendix B Required Operator Actions Form ES-D-2
Bp-Test No.: 2004-301 Scenario No.: Spare Page 22 of 22