ML033510567
| ML033510567 | |
| Person / Time | |
|---|---|
| Site: | Catawba  |
| Issue date: | 05/15/2003 |
| From: | Ernstes M Operator Licensing and Human Performance Branch |
| To: | Gordon Peterson Duke Energy Corp |
| References | |
| 50-413/03-301, 50-414/03-301 50-413/03-301, 50-414/03-301 | |
| Download: ML033510567 (126) | |
See also: IR 05000413/2003301
Text
Draft Submittal
(Pink Paper)
CATAWBA APRIL 2803 EXAM
58-413 & 58-41412083-301 I
MARCH 31 -APRIL 4 &
APRIL 30,2003
Appendix D Ini tili 1 IJyn anic S imu 7. at-.or S cena ric Form SS-D-I
Simulation Facility: Catawba Scenario No.: NK(:-3 @-Test No:
Examiners: ., .. ~.
~ ..~ Operators:
Dbjectives: To evaluate the applicants' ability to increase power using NOPs while
naintaining 'rave matched to Tref, and to use AOPs to respond to IC steam linc PORV failing
,pen, a low failure of channel I pressurizer level that results in loss of letdown with the
ittempt to place excess letdown not being successful. The crew will be allowed to restore
Iormal letdown. A feed water regulating valve on 11) steam generator will fail closed,
-esulting in the need to control steam generator level manually. The c.rew will then respond to
I steam generator tube leak. The leak will propagate to a tube rupture. The applicants will be
- valuated using EOPs to respond to the steam generator tube rupture. 'The turbine will fail to
.rip automatically and auxiliarj feedwater (CA) pump IF3 will fail to start autcimatically but
- an be manually started. A succcss path exists via EP/l/A/5000iE-3.
Initial Conditions: 50% power, BOL, Equilibrium Xe.
NCS Boron Concentration 988 ppm.
rurnover: CA pump 1A is out of service for routine maintenance. It is due to be returned to
servicc in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
NS pump 1A is out of service for motor replacement. It is due to be returned to
senrice in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Vdve 1NC.-31Bwasjust closed due to leakage by PORV 1NC-32B. An R&R is
being developed.
Thunderstorms are in the area and the load dispatcher requests that Unit 1 increase
load to lOO?/o as quickly as possible due. to grid supply problems.
2 1 I N-KO I Increase power from 50%
araft Revision 3
Appendix D I n i t i a l Dyr.amic Sinul;it.or S c e r , a r i o Form ZIS-D-1
_6_
Event Malf. No.
No.
5 Vi.V-NV032F C-BOP Failure of 1NV-123R to open (Inability to establish excess
-0 letdown)
C-RO S!G 1D Feedwater Controller fails closed.
7 MN.-S0001D S/G ln tube leak (-60 gpm)
-60
-
7a MAI.-SCIOUID M-AIL SCrrK ( S K i 113) (-345 gpm)
= 345
K m p - 120
-
8 htALEHCfl02
-ALTO
C-RO
I Failure of' automatic turbine trip
9 h?AL4:.400413 C-BOP
I C.4 pump 1B fails to start in AIJTO
- (Njormai., (ro eactivity, (I)nst.rcment, {Cjomponent, ( M j a:jor
NUREG-1021 Page 2 c f 43 Draft- R e v i s i o n 9
.ppendix D Operator Actions Form E§-D-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 1
Event Description: Dilution for power increase
Time Position Applicant's Actions or Behavior
Examiner Note: If the dispatcher is contacted for guidance, the
response will be increase at 20%/hr.
Step 2.15 SR8/ Per OP/l/A/6100/003. Enclosure 4.1: Maintain control rods above
BOP insertion limit and AFD within its target by boration or dilution per
OP/1/A/6150/009.
SRO Directs EOP to add water to begin the load change and provides
guidance that the dilution should be done in 3 batches.
EXAMINER NOTE: A normal dilution batch at this core life
should be about 200-400 gallons.
BOP Refer to OP/1/AJ6150/009 (Boron Concentration Control) Enclosure
1.3 (Dilution).
Step 2.2 BOP Ensure the following valve control switches in "AUTO:
1NV-242A (RMWST To B/A Blender Ctrl)
INV-181A (WA Blender Otlt To VCT)
Step 2.3 BOP 9djust the total makeup batch counter to the desired volume of
reactor makeup water to be added.
Step 2.4 BOP ?lace the "NC MAKEUP MODE SELECT switch to the "DILUTE"
aosition.
Step 2.5 BOP Rdjjldst the controller for INV-242A (RMWST To B/A Blender Ctrl) tc
- he desired flow.
Step 2.6 BOP Ensure INV-2428 (RMWST To BiA Blender Ctrl) controller in
'AUTO".
Step 2.7 BOP Ensure at least one reactor makeup water pump is in "AUTO" or
- ON".
NUREG- 1021 Drsft R e v i s i o n 3 3 of 4 3
Event Description: Dilution for power increase
Time Position Applicant's Actions or Behavior
BOP NOTE: If necessary, dilution can be manually secured at any time
~y placing the "NC MAKEUP CONTROL switch to the "STOP"
Dosition.
- .. ~
Step 2.8 BOP Place the "NC MAKEUP CONTROL" switch in the "START"
Dosition.
Step 2.9 BOP Verify the following valves open:
1NV-242A (RMWST To $/A Blender Ctrl)
INV-181A (B/A Blender Otlt To VCT)
Step 2. I O BOP If in "AUTO, verify the reactor makeup water pump starts.
Step 2.1 1 BOP iNken the desired volume of reactor makeup water is reached on
- he total makeup batch counter, ensure the following valves close
1NV-242A (RMWST To B/A Blender Ctrl)
INV-I81A (B/A Blender 0 t h To VCT)
Step 2.12 BOP If automatic makeup is desired, refer to Enelosure 4.1 (Automatic
Makeup).
.. . ~~...
KCREG-1021 C r a f t Revision 9 4 of 4 3
Appendix B Operator Actions Form ES-B-2
...~. ....... ..- .... ...
Op-Test No.:NRC Scenario No.: 3 Event No.: 2
Event Description: Turbine load increase
Time
-
I Positicn
............-
Applicant's Actions or Behavior
I SRo
Directs 80 to increase load at a rate of 2 to 4 MW/rnin or 10% to
20% per hour.
Step 2.3 SROIRO Per 0P/I/A/6100/003, Enclosure 4.1: Coordinate with SOC to
increase turbine load per OP/l/B/6300/001.
- ...... .... ~.. . . -
I. - Ro
Refer to 8P/I/B/6300/001, Turbine Generator, Enclosure 4.2,
Section 2.4.
.... . . ..... .......
I SRO Direct RO to increase load at a rate of approximately 2-4 MWlmin
or 10%-20% per hour to 100% (target).
- .. ..... .......
Step 2.2.1
i
Step 2.2.2 ' 80
Depress the "Load Rate" pushbutton and verify it illuminates.
Input the desired load rate on the numeric keypad and verify the
load rate appears on the Variable Display.
I ..... ...... . . . .....
Step 2.2.3
Step 2.2.4
I Ro
Depress the "Target" pushbutton and verify it illuminates
..... .....
Input the desired load target on the numeric keypad and verify the
....... ...
load target appears on the Target Display.
...... ... ....
Step 2.2.5 i RO To start load increase, depress the "Go" pushbutton and verify it
I
illuminates.
.... .....
Step 2.2.6 ALL SiG blowdown changes should be coordinated with Secondary
Chemistry.
~. .....- .... ..~. ......
NUREG-lC71 Draft. Revisior; 9 5 of 4 3
Appendix D Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 3
Event Description: Steam Generator I C PORV (ISV-7) fails open.
Time Position ADslicant's Actions or Behavior
NOTE: If candidate does not recognize the failure of ISV-7, the
lead examiner may, at his discretion, direct the booth operator
to increase the severitv value of the malfunction to 100%.
RO 3ecognize indication that SIG I C PORV failed to intermediate and
nforms SRO.
1SV-7 (SIG I C PORV) indicates INTERMEDIATE.
EXAMINER NOTE: QMP 1-7 allows RO to isolate a known leak
Nithout SRO permission and inform SRQ of isolation actions
Serformed.
SRO airects RO to close ISV-7 (S/G I C PQRV)
0 Placing "SG I C PORV CTRL MODE" switch in
"MANUAL" position.
Positioning ISV-7 (SIG I C PORV) controller to zero
output.
nforms Sa0 S I 6 I C PORV will not go CLOSED.
lirects RO to close ISV-268 (SIG I C PORV ISOL).
=laces ISV-266 (SIG I C PORV ISOL) in the "CLOSE" position.
nforms SRO that SIG I C PORV isolation valve is CLOSED.
N U R E G - 1 0 2 1 D r a f t Revisior: 9 6 of 4 3
\ppendix D Operator Actions Form ES-D-2
Op-Test No.: NKC Scenario No.: 3 Event No.: 3
Event Description: Steam Generator 1C POWV (1SV-7) fails open.
Time Position Applicant's Actions or Behavior
SRO Refers to Tech Specs:
TS 3.7.4 (Steam Generator Power Qperated Relief
Valves (SG PBRVs)
Determines that 3.7.4 applies
EXAMINER NOTE: SRO may implement AP/I/A/5500/28
(Secondary Steam Leak) at this point but it is not required.
Required actions are on the subsequent pages of this section. If
AW28 is not implemented, go to page 1Iof 42 to continue
scenario.
EXAMINER NOTE: The following actions are provided in case
the SRO enters AP/l/A15500/28 (Secondary Steam Leak).
SRO Implements AP/I/A/5500/28 (Secondary Steam Leak) and directs
actions.
Step I KO Monitor Enclosure 1 (Foldout Page)
Step 2 RO Verify turbine - ONLINE
Step 3 RO Verify the following:
Reactor power - LESS THAN OR EQUAL TO 100%
POWER.
T-avg -WITHIN 1 . 5 T of T-Ref
EXAMINER NOTE: If >1.5"F difference, RO should either verify
that control rods are automatically attempting to maintain
temperature or take manual action to maintain within the band.
N U R E G- 1 0 2 1 Draft. Revisio:i 9 7 of 4 3
rppendix B Operator Actions Form E§-B-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 3
Event Bescription: Steam Generator I C PORV (ISV-7) fails open
Time Position Applicant's Actions or Behavior
Step 4 RQ Verify proper reactor response as follows:
Control rods - IN "AUTO" AND STEPPING IN
PA3 neutron flux - DECREASING.
Step 5 ALL IF AT ANY TIME reactor power is greater than loo%, THEN
perform Step 3 RNO.
Step 6 RO Verify Pnr level - STABLE OR INCREASING.
Step 7 ALL IF AT ANY TIME Pzr level is decreasing in an uncontrolled manner,
THEN RETURN TO Step 6.
Step 8 BOP IF AT ANY TIME VCT level goes below 23%, .. .
Determines step does not apply at this time.
EXAMINER NOTE: This should not occur during the scenario.
Step 9 ALL 4ttempt to identify and isolate leak as follows:
a. Verify the following conditions - NORMAL
Containment temperature
Containment pressure
e Containment humidity
Containment floor & equipment sump level.
b. Dispatch operators to locate and identify source of
steam leak.
N U K E G - 1 0 2 1 Draft R e v i s i o r . 9 8 of 4 3
Sendix B Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 3
Event Description: Steam Generator 16 PORV (ISV-7) fails open.
Time I Position Auulicant's Actions or Behavior
c. Verify SIG PORVs -CLOSED.
Informs SRO that I C SIG P O W (ISV-7) is NOT
CLOSE5.
Step 9.c
II SRO
Transitions to Step 9.c RNO and directs actions
c. E SIG pressure is less than 1090 PSIG, =perform
the following:
RNO
1) Close affected SI6 PORV.
5etermines PORV will not close and informs SRO.
2) IF SIG PORV is still open, THEN:
a) Close affected SIG PORV isolation valve.
Closes SIG PORV isolation valve (ISV-26B).
b) IF SIG P O W isolation valve still open, THEN.
Determines step does not apply.
RO Informs SRO that I C SIG POWV isolation valve (ISB-26B) is
closed.
Transitions to Step 9.d N E R column
Step 9 80 d. Verify condenser dump valves -CLOSED.
e. Verify atmospheric dump valves - CLOSED
f. Verify CAPT # I - OFF.
g. E leak is suspected to be in the doghouse, THEN
Leak location determined to be I C SIG PORV.
NUREC-1021 D r a f t . Revision 9 3 of 4 3
ippendix D Operator Actions Form ES-D-2
Op-Test Ne.: NRC Scenario No.: 3 Event No.: 3
Event Description: Steam Generator I C PQRV (ISV-7) fails open.
Time Position Applicant's Actions or Behavior
Step 10 I SRO I Determine required notifications:
I * REFER TO RPIO/A/5000/001 (Classification of
Emergency)
REFER TO RPiO/Bl5080/013 (NRC Notification
Requirements).
Step 12 1 RB 1 Verify - LEAK ISOLATED.
Step 13 SRO Determine long term plant status. RETURN procedure and
step in effect.
NUREG-1621 D r a f t % v i s i o n 9 10 of 4 3
Appendix B Operator Actions Form ES-B-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 4
Event Description: Pressurizer Level Channel I fails LOW
Time Position Applicants Actions or Behavior
BQP Recognizes Pressurizer Level Channel I has failed LQW and
nforms SRO.
- IAD-6: D/9 (PZR LO LEVEL HTR OFF 8 LETDOWN
SECURED annunciator
0 IAB-6, N 1 0 (PZR HTR CONTROLLER TROUBLE)
Pressurizer level channel I 1NCP5164 off scale - LOW
EXAMINER NOTE: Annunciator response is attached.
BOP qesponds to event using the annunciator response. Selects
- hannel Ill to control pressurizer level.
a IAB-6 E19 (PZR LO LEVEL DEVIATION) annunciator
BOP 3ecognizes that letdown has been lost due to this failure and
nforms SRQ.
SRO rnplements AP/I/N5500/12 (Loss of Charging or Letdown) Case II
- Loss of Letdown) and directs actions.
Step 1 BOP derify all Pzr level channels - INDICATING THE SAME.
Determines that channel I has failed low and informs SRO
SRO rransitions to Step 1 RNO and directs actions
Step 1 BOP F the controlling channel is failed low, place PZR LEVEL
X R L SELECT switch in any alternate operable position.
RNO
SRO rransitions back to Step 2 N E R column m d directs actions.
N U R E G - 1 0 2 1 Draft Revision 9 I1 of 4 3
Op-Test No.: NRC Scenario No.: 3 Event No.: 4
Event Description: Pressurizer Level Channel I fails LQW
Applicant's Actions or Behavior
INV-1OA (Letdn Orif 1B 0 t h Cont isol)
INV-11A (Letdn Orif I C Otlt Cont Isol)
a 1NV-13A (Letdn Orif 1A Qilt Cont Isol)
Step 4 Verify PZU level - GREATER THAN 17%.
Step 5
Takes manual control of INV-294 and reduces charging flow.
Ensure "PZU HEATER GROUP I C " -ON. I
1 Step? 1 BOP Control VCT IeVel as follows:
a. Verify VCT makeup - SET FOR DESIRED BORON
CONCENTRATION
b. Verify VCT makeup - IN AUTOMATIC.
Determine and correct cause of loss of letdown.
channel.
NUREG-1021 Draft Revisioi: 9 12 of 4 3
ppendix D Operator Actions Form ES-B-2
3p-Test No.:NRC Scenario No.: 3 Event No.: 4
Event Description: Pressurizer bevel Channel I fails LOW
Time
step 10
3.3.1 (Reactor Trip system (RTS) Instrumentation)
3.3.3 (Post Accident Monitoring (PAM) Instrumentation)
- 3.3.4 (Remote Shutdown System)
- 3.4.1 (RCS Pressure, Temperature, and Flow Departure From
Nucleate Boiling (DNB) Limits)
3.4.12 (Low Temperature Overpressure Protection(iT0P)
3.6.3(Containment IsoIationValves)
NUREG-1021 Draft R e v i s i o n 9 13 cf 4 3
ppendix B Operator Actions Form E$-8-2
3p-Test No.: NRC Scenario No.: 3 Event No.: 4
Event Description: Pressurizer Level Channel I fails LOW
Time Position ADDkant'S Actions or Behavior
Step 11 BOP Evaluate normal letdown restoration as follows:
a. Verify at least one of the following valves - CLOSED:
INV-qA (NC Letdn To Regen Hx Isol)
1NVQA (NC Letdn To Regen Hx Isol)
Informs SRO that INV-2A is closed
b. Perform the following:
1) Establish excess letdown. REFER TO OP/l/N6200/001
(Chemical and Volume Control System)
2) Dispatch operator(s) to pressurize the normal letdown line.
REFER TO Enclosure 1 (Pressurization of Normal Letdown
Line).
c. Do not continue in this procedure until one of the following is
met:
0 Notified by dispatched operator that the letdown line is
pressurized.
Station manaaement authorizes normal letdown restoration.
NUREG-102.1 3raft Revision 9 I4 of 4 3
Appendix D Operator Actions Form ES-5-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 5
Event Description: Failure of ?NV-1238 to open (Inability to establish excess letdown)
Time Position Atmlicant's Actions or Behavior
SRO Determine that normal letdown is currently not available due to 1NV-2A
closed and directs excess letdown to be placed in service.
SRO REFERS TO OP/1/A16200/001 (Chemical and Volume Control System)
Enclosure 4.12 (EstablishinglSecuring Excess Letdown) and directs
operators.
.......
Step 2.1.1 BOP Notify Primary Chemistry of the following:
Excess Letdown will be placed in service
VCT pressure will be reduced to - 20 Dsia
Step 2.1.2 BOP CAUTION: At least 15 psig backpressure shall be maintained on the
NCP # I seals
Volume..................
-
Reduce VCT pressure to 20 psig per Enclosure 4.22 (Adjusting the
Control Tank (VCT) Hydrogen Pressure)
Step 2.4.3 BOP Open the following valves to establish KC flow to the Excess Letdown
Heat Exchanger:
IKC-305B (Exs Letdn Hx Supply Cont Isol)
IKC-3158 (Excess Letdn Hx Ret Cont Isol) .......
Step 2.1.4 BOP Verify INV-125B (Excess Letdn Hx Otlt Ctrl) is in the VCT" position
NOTE: The VCT is the preferred alignment. Alignment to the NCDT
will result in a faster reduction in NC Svstem hvdroaen concentration.
Step 2.1.5 BOP -
IF either of the following conditions exist, place INV-125.8 (Excess
Letdn Hx 0th Ctrl) in the "NCDT" position:
0 VCT pressure greater than or equal to 45 psig as indicated on
1NVP5500 (VCT Vent Press)
VCT level greater than or equal to 50% as indicated on 1NVP5761
(VCT Level)
NUREG-1021 Draft R e v i s i o n 9 15 of 4 3
!%P?!x!?-P-.- Operator Actions . ~ ~ ~ ~ ~ .Form
. . ES-D-2
Op-Test No.:NRC Scenario No.: 3 Event No.: 5
Event Description: Failure of INV-1238 to open (Inability to establish excess letdown)
~
Time Position Applicants Actions or Behavior
~~~~~ ....
Step 2.1 .f BOP Open the following valves:
e 1NV-422B (Loop C To Exs Letdn Hx Isol)
Determines that 1NV-1238 will net open and informs SRO.
NOTE: When the crew contacts the booth the second time to
obtain management approval to restore normal letdown, read
them the following CUE: Station management authorizes nomial
letdown restoration.
SRO Continues with APll2 at S t e ~ 12
QPII2 BOP Establish letdown as follows:
Step 12
a. Verify ability to establish normal letdown - RESTORED
b. Ensure 1NV-849 (Letdn Flow Var Orif Ctrl) valve demand
position - 0%.
c. Verify the following valves - QPEN:
INV-1A (NC Letdn To Regen Hx Isol)
INV-2A (NC Letdn To Regen Hx Isoi).
d. Open the following valves:
INV-158 (Letdn Cont [sol)
INV-10A (betdn Orif 18 Qtlt Isol).
e. Adjust the following valves as required in subsequent steps:
1NV-148 (betdn Press Control) to maintain letdown
pressure at 350 PSI6
1NV-294 (NV P M ~ A&B S Disch Flow Ctrl) to maintain
letdown subcoooled.
f. Monitor letdown flow and pressure.
g. Throttle 1NV-849 (Letdn Flow Var Orif Ctrl) until valve demand
is position is 10%
h. Verify letdown flow and pressure - INCREASES.
Observes that letdown flow and pressure have not increased and
informs SRO.
WREG-1021 Driif: Rcvjsion 9 16 of 4 3
W.. e n d i x B . . qpxator Actions . Form ES-D-2
3p-Test No.: NRC Scenario No.: 3 Event No.: 5
- vent Description: Failure of INV-1238 to open (Inability to establish excess letdown)
~. --.. ..~~~.. ...
Time Position Applicant's Actions or Behavior
.~ .~ .~
SRO Transitions to SteD 12.h. RNO and directs actions.
Step 12.h. SRQ 1. Perform the following:
?NO
1) IF 1NV-849 valve demand position is 100%
letermines that step does not apply and continues to Step 12 RNO
1.2).
2) Throttle open 1NV-849 until one of the following conditions are
met:
Letdown flow and pressure increases
Valve demand increases by 10%
Valve demand position is 100% open
3) Repeat Step 12.h.
XAMINER NOPE: Step 12.h. will be repeated until letdown flow is
.estored. The scenario will proceed to Event 6 at this mint.
NUKEG-1021 D r a f t Revision 9 I7 of 4 3
Appendix B Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 6
Event Description: ICF-55 Steam Generator 1D feedwater regulating valve) fails closed with
manual control available.
Time Position AoDlicant's Actions or Behavior
RO Responds to annunciator 1AB-4 C/4 "S/G D FLOW MISMATCH LO
CF FLOW
EXAMINER NOTE: A copy of the annunciator response
procgdure for this alarm is attached.
RO Determines that ICF-55 ( I D S/G Feedwater Regulating Valve) has
failed closed and informs SRO.
EXAMINER NOTE: RO has authority to take control of SIG
level in manual if auto control fails per OMP 2-8.
SRO Directs RO to take manual control of ICF-55 and open the valve.
RO Piaces manuallauto siaiion for ICF-55 in MANUAL and opens
valve.
80 Match level in SIG D with programmed level and maintain
EXAMINER NOTE: This valve will remain in manual for the
remainder of the scenario.
NUREG-1021 Draft Revision 9 18 of 43
Appendix D Operator Actions Form ES-D-2
Op-Test No.:NRC Scenario No.: 3 Event No.:7
Event Description: 1D Steam Generator Tube Leak (60gpm)
Position Applicant's Actions or Behavior
ALL Recognize symptoms of a Steam Generator Tube Leak:
Charging flow increasing
EMF 33. 72, 74, 29, 31 alarm
RO Verifies Blowdown automatic actions occur:
1BB-69, 7 3 , 24, & 65 BB flow control valves go closed
-1BB-27 & 48, BE?Tank Vent and BB pump discharge dose
Contacts Chemistry and requests verificaticn that S/G BB sample
line isolations have closed.
SRO Implements AP/l/A/5500/10 (Reactor Coolant Leak) Case I, Steam
Generatcr Tube Leak. and directs actions.
Step 1 ALL Monitor Enclosure 1 (Foldout Page)
step 2 ROI BOP Verify Pzr level - STABLE OR INCREASING.
Determines Pzr level is decreasing and informs SRO
sa0 Transitions to Step 2 !?NO and directs actions.
NUREG-1021 D r a f t R e v i s i o n 9 13 of 43
,ppendix D Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 3 Event No.: 7
Event Description: 18 Steam Generator Tube beak (60 gpm)
Time Position Applicant's Actions or Behavior
Step 2 BOP Perform the following:
RNO a. Maintain charging flow less than 180 GPM.
b. Manually throttle 1NV-234 (NV Pmps A&B Disch Flaw Ctrl) to
stabilize Pzr level.
c. E Pzr level is stable increasing, THEN GO TO Step 3.
Determines Pzr level is stable or increasing and informs SRO
SRO Transitions to Step 3 N E B .
Step 3 ALL IF AT ANY TIME the SIG tube leak increases, THEN perform Step
2.
Step 4 BOP Verify Pzr pressure - TRENDING TO OF? STABLE AT 2235 PSIG.
Step 5 ALL 0 IC AT ANY TIME 1AD-7, 1/1 "VCT LO LVL" alarm is lit,
THEN ...
Determines that alarm is NOT lit and informs SRO.
NOTE The OAC calculated leak rate may be invalid during mode
changes and/or transient conditions unless there is current,
coordinated sampling data available.
NUXEG-I021 Draft Revision 9 20 of 43
~pendixD Operator Actions Form ES-D-2
3p-Test No.: NRC Scenario No.: 3 Event No.: 7
- vent Description: I D Steam Generator Tube Leak (60 gpm)
Applicant's Actions or Behavior
Determine SIG leak rate by any of the following methods:
Monitor the following computer points:
ClPO187 (Estimated Total Pri To Sec Leakrate)
ClPO189 (Pri To Sec Leakrate 15 Min Running Avg)
EROSLEAK (Primary To Secondary Leakage).
NOTE The S I 6 Leakage EMFs are highly sensitive which may
cause the EMFs located on the adjacent steamline to be
increasing or in alarm.
SIG leakage EMF indication(s):
- IEMF-71 ( S I 6 A Leakage)
1EMF-92 (SIG E Leakage)
IEMF-73 (SIG C Leakage)
IEMF-74 (SIG B Leakage).
0 Compare charging flow and letdown flow
e Monitor OAC NV Graphic
0 Initiate OAC Program "NSNCLEAK'
Monitor OAC point ClPO376 (Gross NC System Leak Rate,
Ten Min Run Avg).
EXAMNER NOTE: Normally crews use NV OAC graphic andlor
by comparing charging and letdown flows.
NOTE: In subsequent steps the term "leaking SIG" is a $16 with
primary to secondary leakage.
NUIIEG-1021 Draft Revision 9 21 of 4 3
ppendix D Operator Actions Form ES-D-2
3p-Test No.: NRC Scenario No.: 3 Event No.: 7
=vent Description: 1B Steam Generator Tube Leak (60 gpm)
Time Position Applicant's Actions or Behavior
step 7 BOP Identify the leaking S/G(s) as follows:
a. Notify RP to frisk all cation columns.
NOTE: The S/G Leakage EMFs are highly sensitive which may
cause the EMFs located on the adjacent steamline to be increasing
or in alarm
b. Verify any of the following S/G leakage EMF indication@)-
INCREASING OR IN ALARM:
IEMF-71 (SIG A Leakage)
IEMF-72 (S/GB Leakage)
-
e IEMF-73 (S/G C Leakage)
IEMF-74 (S/G D Leakage).
c. Verify any of the following S/G steamline EMF indication(s) -
INCREASING QR IN ALARM:
IEMF-26 (Steamline la)
e 1EMF-27 (Steamline 1B)
1EMF-28 (Steamline I C )
1EMF-29 (Steamline 1D).
d. Verify CF flow - LOWER TO ANY S/G AS COMPARED TO
OTHERS.
e. Notify Secondary Chemistry to determine leaking SiG by
sampling.
Determines that 1EMF-71, 74, and 29 are in alarm and informs
SRQ.
The fallowing leak rates are based on leakage in one
S/G.
In the event of an oscillating leak, the leak rate shall be
determined based on the peak value of the spike.
- tep 8 Verify leak rate - GREATER THAN OR EQUAL TO 5 GPD.
Determines from charging flow increase that the leak is greater
than 5 GPD.
NUREG-1C21 Draft R e v i s i o n 9 2 2 of 4 3
ippenclix D Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 3 Event No.:7
Event Description: 1D Steam Generator Tube Leak (60gpm)
Determines from charging flow increase that the leak is greater
than 40 GPB.
Step 2 ROI BOP Verify Pzr level - STABLE OR INCREASING.
Determines Pzr level is decreasing and informs SRQ.
I SRO
/ Transitions to Step 2 RNO and directs actions.
N U K E G - 1 0 2 1 Draft Revision 9 2 3 of 4 3
_I-
ppendix I Operator Actions Form ES-D-2
3p-Test No.: NRC Scenario No.: 3 Event No.: 7
- vent Description: 1D Steam Generator Tube Leak (60 gpm)
Time Position Applicant's Actions or Behavior
step 2 BOP Perform the following:
?NO a. Maintain charging flow less than 180 GPM.
b. Manually throttle 1NV-294 (NV Pmps A&B Bisch Flow Ctrl)
to stabilize Pzr level.
e. Pzr level is stable QJ increasing, THEN GO TO Step 3.
Determines Pzr level is continuing to decreasing and informs
sao.
d. IF Pzr level continues to decrease, THEN:
EXAMINER NOTE: If letdown flow was restored in Event 5, the
BOP will reduce letdown to 45 GPM at this point. Otherwise,
the steps for letdown reduction will be skipped.
1) Reduce letdown to 45 GPM as follows:
a) Manually control INV-148 (Letdn Press Control) to
maintain letdown pressure at 350 PSIG.
b) IF 1NV-13A (betdn Orif 1A Otlt Cont Isol) is open,
Determines that INV-13A is not open and that step does not apply.
c) IF INV-1OA (Letdn Orif 1B Otlt Cont Isol)is open,
THEN throttle 1NV-849 (Letdn Flow Var Orif Ctrl) until
letdown flow is 45 GPM.
dl WHEN letdown Dressure is stable at 350 PSIG. THEN
' place 1NV-148 (Letdn Press Control) in "AUTO".
Step 2.2) BOP 2 ) IF Pzr level continues to decrease. THEN ensure the
?NO following valves closed:
1NV-2 OA (Letdn Orif 1B Otlt Cont Isol)
I N V - I I A (Letdn Orif I C Otlt Cont Isol)
0 INV-13A (Letdn Orif 4A Otlt Cont Isol).
Closes valves and informs SRO
Step 2.3) BOP 3 ) IF Pzr level is stable OR increasing, THEN GO TO
RNO Steo 3.
Determines that PZR level is decreasing and informs SRO.
NUREG-1021 Craft R e v i s i o n 9 2 4 of 43
.. -
ppendix B Operator Actions Form ES-13-2
3p-Test No.:NRC Scenario No.: 3 Event No.: 7
- vent Description: I D Steam Generator Tube Leak (60 gpm)
Time Position Applicant's Actions or Behavior
Step BOP 4) E Pzr level continues to decrease, THEN:
Z.d.4)
a) Start an additional NV pump as follows:
RNO
(1) Open 1NV-2528 (NV Pumps Suct From FWST)
(2) Open INV-2535 (NV Pumps Suct From FWST)
(3) Close INV-188A (VCT Otlt Iso~)
(4) Close INV-1898 (VCT Otlt Isol)
(5) Start the desired NV Pump.
Positions valves aoororxiatelv and starts 1A NV Pumo.
RO b) Adjust Control Rods and turbine load as required to
maintain T-Avg within 1°F of T-Ref. REFER TO the
.
following:
AP/l/N5500/09 (Rapid Downpower)
.
OPI/N6100/003 (Controlling Procedure for Unit
Operation
SRO c) Pzr level is stable increasing THEN GO TO
Step 3.
Determines that Pzr level is continuing to decrease and continues
,n RNO.
ALL d) Pzr level continues to decrease Pzr level cannot
be maintained greater than 1I % , m:
(1) Manually trip reactor
(2) Manually initiate SA
(3) GO TO EP/l/N500O/E-O (Reactor Trip Or Safety
Injection).
SRO Directs RO to trip the reactor and the BOP to manually initiate SA.
NUREG- 1021 D r a f t R e v i s i o n 9 2 5 of 43
Appendix I Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: 1D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine triD and failure of 1B CA Pump to automatically start.
Time Position Applicant's Actions or Behavior
SRO Enters EP/l/N5000/E-0 (Reactor Trip Or Safety Injection) and
directs operators
Step 1 ALL Monitor Enclosure 1 (Foldout Page)
EXAMlNER NOTE: Steps 2 through 5 are Immediate Action
steps and must be performed from memory.
Step 2 RO Verify Reactor Trip:
All rod bottom lights - LIT
All reactor trip and bypass breakers - OPEN
I/R amps - DECREASING
step 3 RO Verify Turbine Trip:
All turbine stop valves - CLOSED
Determines that the turbine is not tripped and manually trips the
turbine. Informs the SRO of this when the step is read aloud.
SRO Transitions to Step 3 RNO and directs actions.
step 3 RO a. Manually trip the turbine
?NO
Depresses the manual trip pushbutton and verifies that all turbine
stop valves are closed and informs SRO.
SRO Transitions to Step 4. N E R and directs actions.
step 4 BOP Verify IETA and IETB - ENERGIZED.
3ep 5 BOP Verify SA is actuated:
a. "SAFETY iNJECTlON ACTUATED" status light (ISI-13)
- LIP
b. EIS load sequencer actuated status lights (151-24) -LIT
step 6 RO Announce "Unit 1 Safetv Iniection"
NUXIEG-102.1 D r a f t Xevision 9 2 6 of 4 3
ppendix D Operator Actions Form ES-D-2
3p-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Des ition: 1D Steam Generator Tube RuDture (345 aDm) -. coincident with failure of
I
automatic aine trip ai I failure of IB CA Pump to automatically start.
Time Position Applicant's Actions or Behavior
Step 9 SRO implement RP/O/A/5000/01 (Classification Of Emergency).
Step 8 Verify all Feedwater Isolation status lights (ISI-5) - LIT
Step 9 BOP Verify Phase A Containment Isolation status as follows:
a. Phase A "RESET" lights - BARK
b. Monitor Light Panel Group 5 St lights - LIT
EXAMINER NOTE: 1KC-305 may be dark due to attempt to put
excess letdown in service earlier in the scenario. If so, BOP will
close it in response to this step's RNO.
Step I O ALL Verify proper Phase 3 actuation as follows:
a. Containment pressure - HAS REMAINED LESS THAN 3 PSIG
b. IF AN ANY TIME containment pressure exceeds 4 PSIG while
in this procedure, THEN perform Step 10.a.
step 11.a RO Verify proper CA pump status as follows:
a. Motor driven CA pumps - ON
Determines that 1A and 1E3 CA DumDs are off and informs SRO
Step 11.a BOP Transitions to Step 11.a RNO and directs actions.
3N0
a. Perform the following for the affected train(s):
I)Reset ECCS.
2) Reset D/G load sequencer.
3) Manually start affected motor driven CA pump.
Starts the 18 CA Pump manually.
4) IF AT ANY TIME a BlO occurs, THEN restart S/I
equipment previously on.
EXAMINER NOTE: Crew may only reset B Train since 1A CA
Pump is tagged out and there is no benefit for resetting A
Train.
NUKEG-1021 Draft. Revision 9 2 7 of 4 3
ippendix D Operator Actions Form ES-Q-2
Op-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine tris and failure of ZB CA Pumo to automaticallv start.
Time Position Applicant's Actions or Behavior
SRO Transitions to Steo 11.b N E R and directs actions.
Step 7 1.b RO b. 3 S/G N/R levels - GREATER THAN 11%
Step 12 BOP Verify all of the following S/l pumps - ON:
NVpumps
NDpumps
NI pumps
BOP Verify all KC pumps - ON.
Step 14 BOP Verify all Unit 1 and Unit 2 RN pumps - ON
Step '15 BOP Verify proper ventilation systems operation as follow:
REFER TO Enclosure 2 (Ventilation System Verification)
Notify Unit 2 operator to perform Enclosure 3 (Opposite Unit
Ventilation Verification)
Step 16 RQ Verify all S/G pressures - GREATER THAN 775 PSIG
Step 17 BOP Verify proper S/I flow as follows:
a. "NV SA FLOW - INDICATING FLOW
b. NC Pressure - LESS THAN 1620 PSlG
Determines NC pressure is greater than 1620 psig and informs
SRQ.
SRO Transitions to Steo 17.b RNQ and directs actions
KCKEG-1021 I ? r a f t K e v i s i o n 9 2s of 43
ppendix D Operator Actions Form ES-(9-2
3p-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
wtomatic turbine trip and failure of 113 GA Pump to automatically start.
Time I Position AppliCant'S Actions or Behavior
Step 17.b BOP b. Perform the following:
?NO 1) Ensure ND pump miniflow valve on operating ND pump(s) -
OPEN.
I 2) Ethe ND Pump miniflow valve(s) cannot be opened,
perform the following for the affected train(s):
Determines that this step is N/A and continues in RNQ column.
3) -Step 18.
I SRO Transition to step 18 N E B and directs actions.
Step 18 Control SIG levels as follows:
a. Verify total CA flow - GREATER THAN 450 GPM
b. at least one SIG N/R level is greater than 11% (29%
ACC), throttle feed flow to maintain all SIG N/R levels
between 11% (29% ACC) and 50%.
step 19 RO Verify all CA isolation valves -OPEN.
Verify S/I equipment status based cn monitor light pariel -.IN
PROPER ALIGKMENT.
Determines that 1A CA pump and possibly IKC-305 are not in
proper alignment and informs SRO.
Transition to Step 20 RNO and directs actions
Step 20 Manually align equipment.
I SRO Transitions to Step 21 N E R and directs actions
NOTE: Enclosure 4 (NC Temperature Control) shall remain in
effect until subsequent procedures provide alternative NC
temperature control guidance.
NUREG-1021 G r a f t Revision 9 29 of 43
.ppendix D Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario Ne. 3 Event No. 7a-9
Event Description: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine trip and failure of 1B CA Pump to automaticallv start.
Time Position Aealicant's Actions or Behavior
Step 21 RO Zontrol NC temperature. REFER TO Enclosure 4 (NC
Temperature Control).
Step 22 BOP Verify Fzr PORV and Pzr spray valve status as fellows:
a. All Fzr PORVs - CLOSED.
b. Normal Pzr spray valves - CLOSED.
c. At least one Pzr PORV isolation valve- OPEN.
Step 23 RO &.fify NC subeoeling based on core exit TlCs - GREATER THAN
0°F.
Step 24 RO Verify main steamlines are intact as follows:
All S16 pressures - STABLE OR INCREASING
- All SlGs - PRESSURIZED.
NUREG-1021 Draft Revision 9 3 0 of 4 3
ppenciix u Operator Actions Form ES-D-2
3p-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: 1D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine trio and failure of 1B CA Pump to automatically start.
Time Position Applicant's Actions or Behavior
Step 25 RO/BOP Verify SIG tubes are intact as foilows:
e Verify the following EMF trip 1 lights - DARK:
ZEMF-33 (Condenser Air Ejector Exhaust)
1EMF-34 (S/G Sample)
a ZEMF-26 (Steamline I A )
1EMF-27 (Steamline 16)
IEMF-28 (Steamline I C )
m IEMF-29 (Steamline 1D)
All S/G levels - STABLE QR INCREASING IN A
CONTROLLED MANNER
Determines that IEMF-33 and IEMF-29 are in alarm, and/or I D
S/G level is increasing in an uncontrolled manner and informs
SRO.
SRO Transitions to Step 25 RNO and directs actions.
SRO E any EMF trip 1 light is lit any S/G level is increasing in an
mcontrolled manner, T#EN concurrently:
- Implements EP/4/A/5000/F-O (Critical Safety Function Status
Trees)
GO TO EP/f/A/5000/E-3 (Steam Generator Tube Rupture).
SRO Transitions to EP/I/A/5000/-3 and directs actions.
Step 1 RO/BOP Monitor Enclosure 1 (Foldout Page)
NUREG-LO21 D r a f t Revision 9 31 cf 4 3
,ppendix D Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Descrintian: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic tuibine trip ar failure of 7 B CA Pump to automatically start.
Time Position Applicants Actions or Behavior
step 2 RO/BOP dentify ruptured S/Gs as follows:
SIG level - INCREASING IN AN UNCONTROLLED MANNER
Chemistry or RP determines ruptured S/G by frisking the cation
columns in the CT lab.
The following EMF trip 1 lights - LIT:
. IEMF-26 (Steamline 1A)
..
0 1EMF27 (Steamline 18)
IEMF-28 (Steamline I C )
IEMF-29 (Steamline ID)
Chemistry determines ruptured SIG using IEMF-44 (SIG
Sample).
S/G Sampling is required to identify ruptured S/G(sj, THEN:
a. Ensure the following signals reset:
1) Phase A Containment Isolations
2) CA System valve control
3) KC NC NI NM St signals
b. Align all S/Gs for Chemistry sampling.
c. Notify Chemistry to sample all S/Gs for activity.
EXAMINER NOTE: Normally crews rely on EMF trip Ilights
and ask for Chemistrv confirmatow samales.
Step 3 RO Jerify at least one intact S i 6 -AVAILABLE FOR NC SYSTEM
SOOLDOWN.
N3REG-1021 Drafr: Revisior: 9 3 2 of 4 3
ppendix D Operator Actions Form ES-D-2
3p-Test No.: NRC Scenario No. 3 Event No. 7a-9
_vent Description: I D Steam Generator Tube Rupture (345gpm) coincident with failure of
3utomatic turbine trip and failure of 1B CA Pump to automatically start.
Time Position Applicant's Actions or Behavior
Step 4 RO Isolate steam flow from ruptured S/Gs as follows:
a. Verify all ruptured S/Gs PORV - CLOSED
b. Verify S/G(s) 1B and 1C - INTACT
Step 4.c RO c. Isolate blowdown and steam drain on all ruptured S/G(s) as
follows:
Determines this step is N/A for SlGs la, 1Byand IC.
e SIGID
1) Close 1SM-74B (SIG I D Otlt Hdr Bldwn C N )
2) Verify the following blowdown isolation valves -CLOSED:
a) 1BB-8A (SIG I D Bldwn Cont Is01 Insd)
b) 1BB-1478 (SIG 1B Bldwn Cont Is01 Byp)
c) IBB-105 (S/G I D Bldwn Cont Is01 Otsd)
Step 5 RO Close the following valves on all ruptured S/G(s):
MSlV
e MSlV Bypass valve
Closes MSIV and verifies MSlV Bypass valve closed on 1D S/G
N U R E G - 1 0 2 1 Draft. R e v i s i o n 3 33 of 43
Event Description: 1D Steam Generator Tube Rupture (345 gpm) coincident with failure of
Step 6 ROIBOP Control ruptured S/G(s) level as follows:
a. Verify ruptured S/G(s) N/R level -GREATER THAN 16% (29%
ACC).
b. Isolate feed flow to all ruptured S/G(s) as follows:
Determines this step is N/A for S/Gs l a , 1B, and I C
0 S/G I D :
1) Close ICA-42B (CA Pmp A Disch To SIG I D Isol)
2) Close ICA-48A (CA Pmp 1 Disch To S I 6 I D Isol)
c. IF AT ANY TIME ruptured SIG(s) NIR level is less than 16Y0
(29% A X ) , perform step 6.
EXAMINER NOTE: This action should not be required.
Step 7 BOPlRO Verify Pzr PORV and isolation valve status as follows:
a. Power to all Pzr PORV isolation valves - AVAILABLE
b. All Pzr PORVs - CLOSED
c. At least one Pzr PORV isolation valve - OPEN
d. IF AT ANY TIME Pzr PORV opens due to high pressure while
in this procedure. m, after Pzr pressure decreases to less
than 2315 PSIG, perform Step 7.b
RO Verify main steamlines are intact as follows:
All S/G pressures - STABLE OR INCREASING
All S/Gs - PRESSURIZED
NUREG- 1021 Draft; Revision 9 34 of 4 3
ppendix D Operator Actions Form ES-D-2
Qp-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: Z D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine trip and failure of ZB CA Pump to automaticallv start.
Time Position Applicants Actions or Behavior
Step 9 Control intact SI6 levels as follows:
a. Verify NIR level in all intact S/Gs -GREATER THAN 11% (29%
ACC).
Determines that not all steam generator levels are greater than
11% and informs SRO.
Transitions to SteD 9.a. RNO and directs actions.
Step 9.a. a~ Perform the following:
RNO
1) Maintain total feed flow greater than 450 GPM to intact SlGs
until at least one SIG NIB level greater than 11% (29%
ACC).
Determines that at least one intact SIG NIR level is greater than
11% and informs SRO.
SRO Transitions to Step 9.b. N E R and directs actions
Step 9.b. b. Throttle feed flow to maintain all intact S/G NIR levels between
11% (29% ACC) and 50%.
Step 10 BOP Ensure SI1 - RESET:
a. ECCS
b. DIG load sequencers
c. IF AT ANY TIME a B/O occurs, THEN restart S/I equipment
previously on
Examiner Note: B Train ECCS and load sequencer were
previously reset to allow B CA pump manual start.
Step 11 BOP Ensure the following containment isolation signals - RESET:
PhaseA
Phase0
Step 12 BOP Establish VI to containment as follows:
a. Ensures IVI-77B (VI Cont Isol) - OPEN
b. Verify VI pressure -GREATER THAN 85 PSIG
N U R E G - 1 0 2 1 Draft. Revision 9 35 of 4 3
ppendix D Operator Actions Form ES-D-2
Bp-Test Ne.: NRC Scenario No. 3 Event No. 7a-9
-.
Event Des1 >tion: I D Steam Generator Tube Rupture (345 aom) coincident with failure of
I
automatic i bine trip a failure of IB CA Pump io autbmaticaily start.
Time Position Applicant's Actions or Behavior
Step 13 BOP Verify all AC busses are energized by offsite power as follows:
ATrain:
"FTA BIO NORM FBR FRM ATC" - CLOSED
- "DIG 1A BKR TO ETA -OPEN
$ETA - ENERGIZED
B Train:
e "FTB BIO NORM FDR FRM A T D - CLOSED
- "DIG 1B BKR TO ETB"- OPEN
e IETB - ENERGiZED.
Step 14 Verify criteria to stop operating ND pumps as follows:
a. At least one ND pump - ON
b. NC pressure - GREATER THAN 285 PSlG
c. Ensure all ND pump(s) not supporting Cold beg Recirc -
STOPPED
d. IF AT ANY TIME NC pressure decreases to less than 285 PSlG
in an uncontrolled manner, THEN restart ND pumps.
Step 15 SRO Verify ruptured SlG(s) - IDENTIFED.
Determines I D SIG is the ruptured SIG.
Step 16 80 Verify the following valves on all ruptured SIGs -CLOSED:
MSlV
MSlV bypass valves
Ensures dosed for1 D S16.
3eo 17 RQ Verifv at least one NC oumo - ON.
NiJkEG-1021 Dra::: Revision 9 3 6 of 4 3
ppendix D Operator Actions Form ES-B-2
Op-Test No.: NRC Scenario No. 3 Event Ne. 7a-9
Event Description: 4D Steam Generator Tube Rupture (345gpm) coincident with failure of
automatic turbine trip and failure of 1El CA Pump to automatically start.
Time Position Applicant's Actions or Behavior
Step I 8 BOP "P-11 PZR S/I BLOCK PERMISSIVE" status light (ISI-28) is
lit, T#EN:
a. Depress ECCS steam pressure "BLOCK pushbuttons
b. Verify main steam isolation blocked status lights (ISI-13) - LIT
e. Maintain NC pressure less than 1955 PSlG using one of the
following:
8 Pzrspray
PzrPORV
EXAMINER NOTE: Initially, this status light will be dark but
wili light during the caoldown procedure loop during step 19.
ALL NOTE:
NC Pump trip criteria based on NC subcooling does not
apply after starting a controlled cooldown.
After the low steamline pressure main steam isolation signal
is blocked, Main Steam Isolation will occ:ur if the high steam
pressure rate setpoint is exceeded.
N U R E G - 1 0 2 1 ?raft !Ievisior: 9 37 of 4 3
ppendix D Operator Actions Form ES-B-2
Op-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: 18 Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic bine trip and failure of 1B CA Pump to automatically start.
Time Position Applicant's Actions or Behavior
EXAMINER NOTE: COQldQWnand depressurization to
minimize break flow is a CRITICAL TASK. These are noted in
the guide.
Step 19 86 Initiate NC System cooldown as follows:
b. Determine required core exit temperature from the table below:
EXAMINER NOTE: Based on SIG pressure of 1180-1199 psig,
the crew should CQQldQWnthe NCS to < 520 O F .
c. Verify the condenser is available as follows:
"C-9 COND AVAILABLE FOR STM DUMP" status light (ISI-
18) - LIT
MSlV on intact S/G(s) - OPEN
d. WHEN "P-?2 LO-LO YAVG" status light (lSl-18) is lit, THEN
place the steam dump interlock bypass switches in "BYP INTK."
e. Verify steam dumps - IN PRESSURE MODE
Determines steam dumps are in "T AVG" Mode and informs SRQ.
SRO Transition to Step 19.e RNO and directs actions.
3ep 19.e RQ place steam dumps in pressure mode as follows:
?NO 1) Place "STM DUMP CTRL" in manual
2) Manually adjust the "STM DUMP C T R L to match "SYM BUMP
CTR6" demand and "% STM DUMP DEMAND".
3) WHEN demand on the "STM DUMP CTRL" is equal to the "%
STM BUMP DEMAND", THEN place the steam dumps in
pressure mode.
SRO rransition to Step 19.f NER column and direct actions.
RO EXAMINER NOTE: If Main Steam Isolation occurs during the
- ooldown, the SRO will direct steam to be dumped from intact
S/G PORVs per step 29.f RNO.
NIJREG-1021 Draft Revisdoc 9 38 of 4 3
pgendix D Operator Actions Form ES-D-2
3p-Test No.: NRC Scenario No. 3 Event No. i'a-9
Event Description: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
3utomatic turbine triD and failure of 1B CA Pump to automaticallv start.
Time Position Applicant's Actions or Behavior
XITICAL RO f. Dump steam to condenser from intact S/G(s)at maximum rate
TASK while attempting to avoid a Main Steam Isolation.
g. Verify main steam isolation blocked status lights (1Sl-13) - LIT.
EXAMINER NOTE: Initially, main steam isolation status light
will be dark.
Determines main steam isolation lights dark and informs SRO.
SRO Transitions to Step 'i9.g RNO and directs actions
Step 19.g BOP g. IF pressure in S/Gs used for cooldown is approaching 800 PSIG,
?NO THEN:
1) Depressurize NC System to less that 1955 PSIG using one
of the following:
Pzrspray
PnrPQRV.
2) Maintain NC pressure less than 1955 PSIG.
EXAMINER NOTE: This steD mav not be used.
SRO Transitions to SteD 19.h A/ER and directs actions.
Step 19 RQ h. Verify core exit TICS - LESS THAN REQUIRED
TEMPERATURE..
EXAMINER NOTE: Procedure will loop in Step 19 until the
required temperature is reached.
i. Stabilize core exit T/Cs -LESS THAN REQUIRED
TEMPERATURE.
BOP Depresses Main Steam pressure "Block pushbuttons and
maintains NC pressure 4 9 5 5 psig.
EXAMINER NOTE: Sometime during the depressurization, the
status lights from Step 18 will light. At that point this step will
be Derformed.
Step 20 SRB Verify NC System cooldown in Step 19 - COMPLETED
NUREG-1021 Draft R e v i s i o n 9 3 9 of 4 3
ippendix D Operator Actions Form E§-B-2
Op-Test No.: NRC Scenario No. 3 Event No. 72-9
Event Description: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine trip and failure of ZB CA Pump to automatically start.
b. IF AT ANY TIME ruptured S/G(s) pressure is decreasing while
in this procedure, THEN perform Step 21.
Step 22 I Ro I Verify NC subcooling based on core exit T/Cs - GREATER THAN
20°F.
NUREr;-1021 Draft R e v i s i o n ? 45 of 4 3
Appendix D Operator Actions Form ES-8-2
Op-Test No.: NRC Scenario No. 3 Event No. 7a-9
i Event Description: 1D Steam Generator Tube Rupture (345 gpm) coincident with failure of
i automatic turbine trip and failure of 15 CA Pump to automatically start.
1 Time I Position I Applicant's Actions or Behavior
I
Step 23 BOP Depressurize NC System using PZR Spray as follows:
CRITICAL a. Verify normal Pzr spray flow - AVAILABLE.
TASK
b. Verify Pzr level - LESS THAN 76% (93% ACC)
c. Depressurize NC System with maximum available spray.
d. Verify subcooling based on core exit T/Cs -GREATER THAN
0" F.
e. Verify Pzr level - LESS THAN 76% (73% ACC)
f. Verify NC pressure - LESS THAN RUPTURED S/G(s)
PRESSURE.
g. Verify Pzr level - GREATER THAN 11% (20% ACC)
EXAMINER NOTE: SRO will loop back through this step until
one of the conditions is met. At that time, the depressurization
will be stopped. The SRO may determine that sprays are not
effectively depressurizing the NCS and transition to Step 23.f
RNO or Step 23.9 RNO which transitions to Step 24 N E R and
use Pzs PORVs instead.
h. Close the following valve@):
1) Pzr spray valves
2) 1NV-37A (NV Supply To Pzr Aux Spray)
i. Observe Caution prior to step 26 and GO TO Step 26.
Step 24 BOP EXAMINER NOTE: If this option for depressurization is used,
the SRO will loop back through this step until one of the
conditions is met. Otherwise skip to Step 26.
Depressurize NC System using PZR PORV as follows:
a. Verify at least one Pzr PORV - AVAILABLE
b. Verify Pzr level - LESS THAN 76% (73% ACC)
c. Open one Pzr PORV.
d. Verify subcooling based on core exit T/Cs - GREATER THAN
0°F
e. Verify Pzr level - LESS THAN 76% (73% ACC)
NUREG-1021 D r a f t R e v i s i o n 9 41 of 4 3
Lppendix El Operator Actions Form ES-D-2
OD-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine trip and failure of 16 CA Pump to automaticallv start.
~
Time Position Applicant's Actions or Behavior
Step 24 BOP f. Verify NC pressure - LESS THAN RUPTURED S/G(s)
PRESSURE.
(cont.)
h. Verify Pzr level - GREATER THAN 11%(20% ACC)
i. Close Pzr PORV.
j. Close Pzr spray valve(s).
Step 25 RQ Verify NC Pressure - INCREASING
RO observes NC Pressure increasing and informs SRQ.
CAUTION: SI1 must be terminated when termination criteria are
satisfied to prevent overfilling the ruptured S/G(s)
Step 26 Verify S/l termination criteria as follows:
a. NC subcooling based on core exit T/Cs - GREATER THAN 0 %
b. Verify secondary heat sink as follows:
NIB level in at least one intact S/G - GREATER THAN 1I%
(29% ACC)
0 Total feed flow available to S/G(s)-GREATER THAN 450
GPM.
c. NC pressure - STABLE OR INCREASING.
d. Pzr level - GREATER THAN 11% (20% ACC).
Step 27 BOP Stop S/I pumps as follows:
a. Stop NI pumps.
b. Ensure only one NV pump - ON
Secures both NI Pumps and one NV Pump
Step 28 BOP Verify VI pressure - GREATER THAN 50 PSIG.
NUREG-1021 Draft Revision 9 4 2 of 4 3
ppendix D Operator Actions Form ES-B-2
Op-Test No.: NRC Scenario No. 3 Event No. 7a-9
Event Description: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of
automatic turbine trip and failure of 1B CA Pump to automatically start.
Applicant's Actions or Behavior
a. Verify the following valves - OPEN:
1NV-252A (NV Pumps Suct From FWST)
1NV-253B (NV Pumps Suct From FWST)
b. Verify the following valves - OPEN
1NV-2C3A (NV Pumps A&B Recirc Isol)
1NV-202B (NV Pmps A&B Recirc isol).
EXAMINER NOTE: These valves may be closed, depending
upon NC system pressure. If so, SRO wil[ direct actions per
I I
Stetl29.b RNO to ouen them.
Step ~ 9 , ~ . BOP c. Close the following valves:
0 1NI-98 (NV Pmp CIL Inj [sol)
1 0
INI-IOB (NV Pmp CIL irrj ISOI).
Terminate scenario when 1 N M A and INI-1OB are closed.
Classification: Site Area Emergency 4.1.S.3
NUREG- 1021 Draft Revision 9 43 of 4 3
u
FOR TRAINING PURPOSES ONLY .h
EMERGENCY NQTlFlCATlON FORM I .a^
I
2
a T H I S IS A DRILL
SITE
!J? ACTUAL EMERGENCY
Catawba Nuclear Site UNIT 1
oFOLLOW-UP
REPORTED BY
MESSAGE NUMBER 1
3 MNSMIlTAL TIMWATE ~ I I - -
CONFIRMATION PHONE NUMBER (803)831-3807 (Smulalor)
(EaShlm) mm M w
4 AUTHENTICATION (If Requrred)
(Numm> (codaworn)
15 EMERGENCY CLASSiFlCATiON
UNUSUAL EVENT
6. (It 8. go to Item 18.)
7. EMERGENCY DESCRfPTIONIREMARKS: -
EAL # 4.1.S.3 boss Of Containment AND LOSS OR Potential LOSS Of Any Other
Barrier. This EAL poses no threat to the safety of the general public.
8. PLANT CONDITION:
9. REaCTOR STATUS: HUTDOWN TIMUBATE: %POWER
10 EMERGENCY RELEASEW:
D N O N E (Go to item 14.) B P O T E N T I A L (Go to item 14.)
- I 1. TYPE OF RELEASE: BLEVATED U
r ,
D LEVEL
w: Started:
T(me(Ear!am)
~ I
Dele
i
- stopped:
-
Time~EasIern:
~~~
I
Cafe
I
JLlQUiD Started
Trme(tasltem)
~ I
D*'B
I
- stopped
--I -I -
T,me(Ea*,am) Dale
- E RELEASE MAGNITUDE CURIES PER SEC DURIES NORMAL OPERATING LIMITS OBELOW OAEOVE
NOBLE GASES ~IODINES
OPARTICUMTES OTHER
'"13. ESTIMAE OF PROJECTED OFFSITE DOSE: D N E W DCHANGED PROJECTION TIME:
(Easlm]
TEDE Thyroid CBE
mrem mrem ESTIMATED DURATION: HRS.
SITE BOUNDARY
2 MILES
5 MILES
10 MILES
"14. METEOROLOGICAL D A T A D W I N D DIRECTION (from) O B S P E E D (mph)
b b l T Y CLASS PRECIPITATION (type)
I5
I N 0 RECOMMENDED PROTECTIVE ACTIONS
16. APPROVED BY
- If items 8-14 have not changed. only items 1-7 and 15-16 are required to be completed.
- Information may not be available on initial notifications.
FOR TRAINING PURPOSES ONLY
0P/~~/6locsl0ioC-;
PANEL: 1AD-6 Page 13 of 92
PZR HTR CONTROLLER TROUBLE MlO
SETPOINT: 1. Phase loss or reversal.
2. Lass of a cooiing fan controller cabinet.
ORIGIN: IISCRlC
PROBABLE I. Loss of fan power.
CAUSE: 2. Failure in cabinet.
3. Phase reversal.
4. Heaters secured due to Pzr low level.
AUTOMATIC None
ACTIONS:
IMMEDIATE I. Take "PZR HTR GROUP IC" to " O W .
ACTIONS: 2. Manually iise other heater groups to coi!troI pressure
Sl_rPPLkMkNt"R'I I. Monitor a:id ni3nually control PZR press t i i i t i l Grout I C can he
ACTIONS: returned to ON".
2. C heaters secured due to a Pzr low level, ntanually reset breaker b y
depressing "ON" for "PLR FITR GROUP C" when the low level clears.
3. Refer to TS 3.4.9 for Pzr H t r operahiiity requirements.
REFERENCES: 1. PZR Heaters Electrical System Description ( L E )
2. CNEE-OI 11-01.74 (ELementary Diagram 600V I d a d Center ILXC
Alarm Circuirs)
3. TS 3.4.9
PANEL: 1AD-6
PZR LO LEVEL EITK OFF & LETDN SECURE11 Df9
SE.TPOIN1: 17% level
OKIGIN: PZR level Channel 1.2. or 3 depending on position of "PZR LEVEL GTIU
SELECT" switch:
INCLT5160 (Pressurizer Level Ch. 1)
1NCLT5150(Pressurizer Level Ch. 2)
0 1NCLT5170 (Pressurizer Level Ch. 3)
PROBABLE
CAUSE:
-- _ I __
NOTE: PZR press and level channels have common reference legs. PZK press Ch. 3 and 4 share
a reference leg with PZK level Ch. 3 and PZR level cold ca!. PZR press Ch. ! sllares a
reference leg with PLR level Ch. 1 and PZR press Ch. 2 sharec a reference leg with PZR
level Ctl. 2.
._ll.---l_ _-.I
I. Charging arrd'or letdown flow mismatch
2. Leakage.
3. Load transient.
4. tnstrurnent malfunction.
THE RFSPONSE FOR THI S ALARM IS LIS TED rN
AP/l/Ai5500112 (LOSS OF CHARGING O R LETDOWN)
OP/~/B/6100/010E
Panel {AD-4 Page 23 of S?
S/G D FLOW MISMA'ICH LO CF FLOW Cl4
SETPOINT: Stm flow j CF flow by .75 x IO6 l b s k
1 NOTE: This setpoint corresponds to StIR flow > CF flow by 20% on meters on 1MC2. I
ORIGIN: S/G I D nusmatch network PCS Cabinet #8
PKOLIABIX I. Step increase in load.
CA lJS E: 2. Instrument maltunc!ion.
3. Feed supply failure.
4. Steam line break.
AUTOMATIC None
ACTIONS:
-~ - __ -
rNOTI;: ~~
Sh.1 flow channel I shares a reference tap with channel 2 of SIC tiairow ranzl: level
indication. SM flow channel 2 shares a reference tap with Si(; wide r a g e level
indication. A failure on one of these level taps will affect the SM flow channel. Other
indication of SM ilow should be used to determine if i r is an instrument fai!ure.
IMMEDIATE 1. Compare all flow indication to verify condition.
ACTIONS: 2. -
IF automatic controls are correcting, take rnaniial control.
SUPP1,EMEN'TARY 1. WHEN malfunc.tion is coriected Q bypassed,
I J restore control
to
ACTIONS: automatic.
0
L. Refer to Tech Specs for operable channel requirenients
(TS 3.3.1, 3.3.2, 3.3.3 and 3 ~ 3 . 4 ) .
REFERENCES: I. FSAR, Figure 7.2.1-1 (7 of 16)
2. 3: L, P & s
3. CNEE-0143-03.02
4. NSM CN-10793
Appendlx I? I n i t i a l Dynamic Sirnul-ator S c e n a r i o Forir, 5s-D-1
I Simulation Facility: CatdWbr Scenario No.: NRC-2, Op-Test No:
Examiners: .~.. Operators: .
Initial Conditions: 100% power, EOL, Equilibrium Xe.
NCS Boron Concentration 30 ppm.
Turnover: (IA pump 1A is out of service for routine maintenance. It is due to be returned to
service in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
i
- N S pump 1A is out of service for motor replacement. It is due to be returned to
- (N:o r a a l , ( R )eactivit.y, (I>nstrurnent, ( C ) omponent, ( M ) a j or
NUREG-1021 Page 1 of 3 4 Draft R e v i s i o n 9
Appendix D I n i t i a l Dynamic Simulator S c e n a r i o Form LS-D-1
-
Event Malf. No. Event Event
No. TW* Description
___
4 OVR-Rh'053D C-BOP I m s of operating RN pump (In) with failurc of the 1A RN
-ON pump discharge valve to open.
XlAL-RNO03H
-2 (BOTH)
VLV-RNOOYF
-a
5 OVR-FWMISD CFPT 1A lube oil pump trips and reserve oil pump does not
~ OFF start resulting in a trip of 1.4 feedwater pump and generation
OVR-FWPOI 8C of a turbine runback signal.
-OFF
DVK-FWPG 19C
-OFF
UVR-FWPOIYU
-OFF
6 MAL-EHrOO3E C-RO Failure of automatic turbine runback
-BLOCK
7 MAL-IRX003A C-RO Uncontrolled contro1 rod insertion in automatic only
= o (wro
ONLY1
8 M Steam break inside containment (ID steam generator)
9 M4L ISEOObA C-RO Failure of automatic Main Steam Isolation
=HLOC'K
MAL ISEOOSB
=BLOCK
10 MALNSOO I B C-BOP NS punp 1B fails to start in auto or manual
-- - BOT11
-
- :N)crrnal, :R) eactivi.ty, (I)nstriiaent, ( C ) omponeat,
NURCG-1021 Page 2 of 3 4 Draft Revision 9
Appendix D Operator Actions Form ES-D-2
09-Test No.: NRC Scenario No.: 2 Event No.: 1
Event Description: Boration for load decrease
Time Position Applicant's Actions or Behavior
Step 2.14
1 SRO/
Per OP/1/A/6100/083, Enclosure 4.3: Maintain control rods above
insertion limit and AFD within its target by boration or dilution per
OP/I/A/6150/009.
~~ ~ ~ ~~ ~~
Directs BOP to determine amount of boron to add to begin the
load change and provides guidance that the boration should be
done in 3 batches (-130 aallons in the first hour).
Determines amount of boron to add (-130 aallons over first hour).
Refer to OP/1/AJ6150/009, Boron Concentration Control
Ensure the following valve control switches in "ALJTO":
e 1NV-238A (WA Xfer Pmp To Blender Ctrl)
e 1NV-186A (B/A Blender Otlt To VCT Otlt)
Step 2.3 BOP Adjust the boric acid batch counter to the desired volume of boric
acid to be added.
Step 2.4 Place the "NC MAKEUP MODE SELECT switch in "BORATE"
Step 2.5 Adjust the controller for 1NV-238A (B/A Xfer Pmp to Blender Ctrl)
t
Step 2.6
Step 2.7 ' controller to the desired flow.
Ensure 1NV-238A (B/A Xfer Pmp to Blender Ctrl) controller in
"AUTO".
NOTE: If necessary, boration can be manually secured at any time
by placing the "NC MAKEUP CONTROL" switch to the "STOP"
position.
Ensure at least one boric acid transfer pump in "AUTO" or "ON".
Step2.8 1 BOP Place the "NC MAKEUP CONTROL" switch in "START" position.
Step2.9 I BOP Verify the following valves open:
1NV-238A (B/A Xfer Pmp To Blender Ctrl Vlv)
e 1NV-186A (B/A Blender Otlt To VCT Otlt)
KGREG-10'21 Draft Revision ? 3 of 34
ppendix B Operator Actions Form ES-D-2
Qp-Test No.:NRC Scenario No.: 2 Event No.: 1
Event BescriDtion: Boration for load decrease
Time Position Applicant's Actions or Behavior
Step 2. -i
0 BOP
step 2.1 1 BOP Verify proper flow by observing the boric acid flow totalizer.
Step 2.12 BOF \r\lhen the desired volume of boric acid is reached on the boric acid
batch counter, ensure the following valves close:
1NV-238A (B/A Xfer Pmp To Blender Ctrl Vlv)
f NV-186A (BIA Blender 0th To VCT Otk)
Step 2.13 BOP desired, flush the makeup line as follows:
0 Open the following valves:
1NV-242A (RMWST To B/A Blender Ctrl)
INV-186A (B/A Blender Otlt To VCT Otlt)
- Ensure one reactor makeup water pump is in 'ON".
- -20 gallons of makeup water have been flushed through
the makeup line, close the following valves:
e 1NV-242A (RMWST To B/A Blender Ctrl)
0 INV-1868 (B/A Blender 0th To VCT Otlt)
e Place the following valve control switches in "AUTO":
INV-242A (RMWST Po B/A Blender Ctrl)
1NV-2 86A @/A Blender Otlt To VCT Otlt)
IF NOT required for current plant operation, place the reactor
makeup water pump started in earlier step in "AUTO".
3ep 2.14 BOP ,F automatic makeup is desired, refer to Enclosure 4.1 (Automatic
Makeuo).
NUREG-1021 Draft Revision 9 4 of 34
Appendix D Operator Actions Form ES-D-2
Op-Test No.:NRC Scenario No.: 2 Event No.: 2
Event Description: Turbine load reduction
Time Position Applicant's Actions or Behavior
Step 2.8 SRO/RQ Per 0P/1/A/6100/003, Enclosure 4.3: Coordinate with SOC and
reduce load per OP/llB/6300/001.
EXAMINER NOTE: Steps 2.6 and 2.7 are conditional steps that do
not aodv based on crew turnover information.
Step 2.6 SRQ/RO If a power decrease of more than 20% reactor power is planned,
issue Model VVlO #91003040 to IAE to prevent the mismatch
between OAC heat balance point ClP1385 (Reactor Thermal
Power, Best) and any excore power channel exceeding 2%.
EXAMINER NOTE: SRO will determine that this step does not
apply per turnover information.
EXAMINER NOTE: The NOTE following this step does not
a0 Refer to OP/l/B1630@/001~ Turbine Generator, Enclosure 4.2,
Section 2.4.
SRO Direct RQ to reduce load at a rate of approximately 2 MWlmin or
10% per hour to 90% (-1080 MW target).
Step 2.4.1 RQ Depress the "Load Rate" pushbutton and verify it illuminates.
Step 2.4.2 RQ Input the desired load rate on the numeric keypad and verify the
load rate appears on the Variable Display.
Step 2.42 RO Depress the "Target" pushbutton and verify it illuminates.
Step 2.4.4 Input the desired load target (-1080 MW) on the numeric keypad
and verify the load target appears on the Target Display.
Step 2.4.5 RQ To start load decrease, depress the "Go" pushbutton and verify it
illuminates.
NUREG-1021 Draft R e v i s i o n 9 5 of 34
Appendix D Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 2 Event No.: 3
Event Description: Pressurizer Pressure Channel I Fails High
Time I Position Applicant's Actions or Behavior
Determines that Pressurizer Pressure Channel i has failed high.
informs SRO.
Implements AP/l/N5500/11 (Pressurizer Pressure Anomalies),
, Case I (Pressurizer Pressure Decreasing) and directs actions.
EXAMINER NOTE: Steps 1 and 2 are Immediate Action steps
and are required to be performed from memory.
Verify all Pzr level channels - INDlCATlNG THE SAME.
Step 1
I Bop
Determines that Channel I is readina hiah and informs SRO
Transitions to Ster, 1 RNO and directs actions
+
Step 1 IF either selected channel is failed high, T#EN place "PZR PRESS
-
RNO CTRb SELECT switch in any alternate operable channel position.
Transitions to Step 2 N E R and directs actions.
Step 2 Verify all Pzr PORVs - CLOSED.
Verify Pzr Spray Valve@) - CLOSED.
---+-E-
Step 3
Step 4 Verify all Pzr heaters - ENERGIZED.
Step 5
I Bop
Ensure 1NV-37A (NV Supply To Pzr Aux Spray) -CLOSED.
Verify NC pressure - STABLE OR INCREASING.
Step 6
I Ro
IF a Pzr pressure channel is failed high, THEN notify IAE to fail the
%Illowing bistables for the affected channel under Model W/O
- 91002943. Bistables shall be tripped within six (6) hours:
Pzr low pressure S/I
- OTDeltaT
I Pzr high pressure Reactor Trip
Pzr low pressure Reactor Trip
NUREG-1021 D r a f t Revision 9 6 of' 3 4
3pendix D Operator Actions Form ES-D-:
lp-Test No.: NRC Scenario No.: 2 Event No.: 3
- vent Description: Pressurizer Pressure Channel I Fails High
Time Position Aoolicant's Actions or Behavior
step 7 BOP a Pzr pressure channel is failed high, THEN notify IAE to fail the
following bistables for the affected channel under Model WIO
- 94002943. Bistables shall be tripped within six (6) hours:
e Pzr low pressure SA
OT Delta T
e Pzr high pressure Reactor Trip
e Pzr low pressure Reactor Trip
Step 8 SRO Ensure compliance with appropriate Tech Specs:
3.3.1 (Reactor Trip System Instrumentation)
3.3.2 (Engineered Safety Features Actuation System)
3.3.3 (Post Accident Monitoring Instrumentation)
3.3.4 (Remote Shutdown System)
3.4.1 (RCS Pressure, Temperature, and Flow Departure From
Nucleate Boiling (DNB) Limits)
3.4.4 (RCS Loops - MODES 1 and 2)
3.4.5 (RCS LOOPS- MODE 3)
3.4.6 (RCS Loops - MODE 4)
0 3.4.9 (Pressurizer)
3.4.10 (Pressurizer Safety Valves)
3.4.11 (Pressurizer Power Operated Relief Valves PORVs)
Determines that 3.3.1 and 3.3.2 apply.
Step 9 BOP Ensure "PZR PRESS REX SELECT" is selected to an operable
channel.
Step 10 ALL Determine long term plant status. RETURN procedure in effect.
NUREG-1C21 D r a f t . R e v i s i o n 9 7 of 34
Appendix D Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 2 Event No.: 4
Event Description: Loss of operating RN pump (IB) with failure of the ZA RN pump discharge
valve to open
Time Position Applicant's Actions or Behavior
BOP Recognize trip of RN Pump 1B and inform SRO.
SRO Enter AP/O/A/5500/020 (Loss of Nuclear Service Water) Case I
(Loss of RN Train) and direct actions.
Step 1 BOP Start idle RN pump(s) as required.
Starts another RN Pump. When the I A RN pump is started the
discharge valve does not open. BOP informs SRO.
EXAMINER NOTE: The SRO may direct securing the f A RN
pump and starting a Unit 2 RN pump at this point or at Step 3.
Step 2 ALL Ensure Unit 1 and Unit 2 OATC monitors Enclosure 1 (Foldout
Page).
Step 3 BOP Verify each operating RN pump discharge flow - GREATER THAN
8.600 GPM.
Determines that no RN flow exists and informs SRO.
SRO Transitions to Step 3 RNO and directs actions.
Step 3 BOP Perform the following:
RNO a. Stop any RN pumps(s) not required to support system operation.
-
Determines that the discharae valve for the 1A RN DumD did not
open and informs SRO.
SRO Directs BOP to start a Unit 2 RN pump.
BOP Starts a Unit 2 RN pump.
Step 4 BOP Verify each operating RN pump discharge flow - LESS THAN
23,000 GPM.
Step 5 BOP Ensure RN pumps - IN OPERATION AS NEEDED.
Determines that an RN pump is in operation and no others are
needed.
NUREG-1021 Eraft R c v i s i o r l 9 8 of 34
Form ES-D-2
Event Description: Loss of operating RN pump (10) with failure of the 1A RN pump discharge
valve to open.
Time I Position Applicant's Actions or Behavior
Step 6
! Ensure proper alignment of RN to KC Hxs as follows:
+
a. Verify RN -ALIGNED TO IN SERVICE KC #X(S).
b. Ensure KC Hx Otlt Mode switches -PROPERLY ALIGNED.
Step 7 Verify each operating RN pump discharge flow - GREATER THAN
8,600 GPM.
Step 8 Verify RN available to all Unit 1 and Unit 2 D/G(s).
Step 9 Determine VCNC status as follows:
Verify VCNC -ALIGNED TO OPERATING RN TRAIN.
Verify YC Chiller - RUNNING.
Step 10 1 ALL Determine and correct cause of loss of RN train.
I
Step 11 Ensure compliance with appropriate Tech Specs and Selected
Licensee Commitments Manual:
SLC 16.7-6 (RN Discharge Instrumentation)
3.6.5 (Containment Air Temperature)
I 3.6.6 (containment Spray System)
3.6.17 (Containment Valve Injection Water System (CVIWS))
3.7.5 (Auxiliary Feedwater (AFW) System)
3.7.7 (Component Cooling Water (CCW) System)
3.7.8 (Nuclear Service Water System (NSWS))
e 3.7.10 (Control ROOM Area Ventilation System (CRAVS))
3.7.1 1 (Control Room Area Chilled Water System (CRACWS))
3.8.1 (A.C. Sources - Operating)
3.8.2 (A.C. Sources -Shutdown).
Determines that 3.7.8, 3.6.6, 3.7.5 and 3.0.3 apply
Determine required notifications:
REFER TO RP/O/A/5000/001 (Classification Of Emergency)
REFER TO RP/O/5/5000/013 (NRC Notification Requirements).
NCREG-IO21 Draft Revision 9 9 of 34
ippendix D Operator Actions Form 3-B-:
Op-Test No.: NRC Scenario No.: 2 Event No.: 4
Event Description: Loss of operating RN pump (IB) with failure of the I A RN pump discharge
valve to open.
Time I Position I Applicant's Actions or Behavior
Steo 13 BOQ I Notify Environmental Chemistry of any RN pump shifts that have
occurred.
Step 14 SRO Determine long term plant status.
RETURN TO procedure in effect.
NUREG-1C21 Draft R e v i s i o n 9 10 of 3 4
Appendix D Operator Actions Form ES-D-
3p-Test No.:NRC Scenario No.:2 Event No.: 5-6
Event Description: CFPT 1A trip due to loss af lube oil pumps resulting in turbine runback
- Failure of automatic turbine runback.
sianal.
Time Position Applicant's Actions or Behavior
ALL Observes that feedwater pump 1A has tripped and informs SRO.
ALL Determines that a runback should be occurring but turbine is not
automatically running back.
Recognize conditions for AP/I/N5500/03 (Load Rejection), inform
SRO, and perform immediate actions from memory.
SRO Implements AP/I/N5500/03 (Load Rejection) and directs actions
EXAMINER NOTE: Steps 1 and 2 are Immediate Action steps
and are required to be performed from memory.
Verify turbine load - DECREASING
I
Step 1 RO
Determines turbine load is not decreasing and informs SRO
SRO Transitions to Step 1 RNO and directs actions.
Step 1 Perform the following:
a. Select "MANUAL" on the turbine control panel.
RNO
b. Depress "CONTROL VALVES LOWER" pushbutton and
reduce turbine load as required.
SRO Transitions to Step 2 N E B column and directs actions..
Step 2 RO Verify proper reactor response:
m Control rods - IN "AUTO" AND STEPPING IN
P/R neutron flux - DECREASING
NUREG-102; Draft Revision 9 11 of 3 4
ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.: 5-6
Event Description: CFPT 1A trip due to loss of lube oil pumps resuiting in turbine runback
signal.
- Failure of automatic turbine runback.
Time Position Apwlicant's Actions or Behavior
Step 3 RO Verify proper steam dump operation as follows:
a. Verify T-Ref instrumentation - AVAILABLE.
b. "C-9 COND AVAILABLE FOR STM DUMP" status light (ISI-18)
- LIT
c. Verify the following:
' G 7 A LOSS OF LOAD INTLK COND DUMP" status light
(ISI-18) - LIT
Steam dump valves - MODULATING
d. TAvg - DECREASING TO P-REF
Stew 4 BOP Verify Pzr PORV and Pzr spray valve status as follows:
a. All Pnr PQRVs - CLOSED
b. Normal Pzr spray valves - CLOSED
Step 5 BOP Verify proper CM System operation as follows:
a. W m reactor power is less than 75%, r "ensure both
C-Htr drain pumps - OFF.
b. Verify reactor power - GREATER THAN 56% PRIOR TO THE
EVENT.
c. Verify standby hotwell pump(s) - ON
d. Verify standby condensate booster purnp(s) - ON
EXAMINER NOTE: Depending on speed of runback in manual,
the standby hotwell pump and Condensate booster pump may
not start. The SRO may direct the BOP to start them per Step
5.6 and 5.d RNOs.
WURZG-1021 Draft R e v i s i o n 9 1 2 of 3 4
tppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.: 5-6
Event Description: CFPT 1A trip due to loss of lube oil pumps resulting in turbine runback
signal. Failure of automatic turbine runback.
I
Time Position Applicant's Actions or Behavior
Step 6 Verify the following generator alarms - DARK:
IAD-11, C/1 "GEN BKR A OVER CURRENT"
ZAB-11, F / l "GEN BKR 5 OVER CURRENT
i
Step 7 Verify S/G levels are adequate as follows:
All S/Glow level alert alarms (IAD-4) - DARK
All SIG low CF flow alarms (IAD-4) - DARK
EXAMINER NOTE: If alarm in at this point, SRO will go to Step
7 RNO, otherwise he will continue with Step 8 NVER (below).
Step7 I SRO Perform the following:
RNO a. Ensure feedwater regulating valves - MODULATING TO
CONTROL $16 LEVELS AT PROGRAM SETPOINT.
b. E any S/G(s) NR level is decreasing in and uncontrolled
manner, THEN:
Determines this step is N/A and continues.
I SRo
Transitions to Step 8 N E R column and directs actions.
Verify AS header pressure - GREATER THAN OR EQUAL TO 140
+
Step 8
PSIG.
step 9 Monitor Enclosure 3 (Rod insertion Limit Boration).
EXAMINER NOTE: AP/llA/5500/03, Enclosure 3 is attached.
Step 10 Verify reactor power - LESS THAN 30%
Determines that power is greater than 30% and informs SRO.
Transitions to Step 10 RNO and directs actions.
NUREG-1021 D r a f t R e v i s i o n 9 13 o f 3 4
ppenaix u Operator Actions Form ES-D-
Dp-Test No.:NRC Scenario No.:2 Event Ne.: 5-6
Event Description: CFPP 1A trip due to loss of lube oil pumps resulting in turbine runback
sig I. Failure of automatic turbine runback.
Time Position Applicants Actions or Behavior
Step 10 SUO a. E the runback target load is less than 30%, THEN:
RNO Determines this step is N/A and continues.
b. WHEN the appropriate runback target load is reached, P#EN:
1) Stabilize unit at current power level
2) Maintain control rods above insertion limits
3) Adjust the following as required to maintain T-Avg within 1°F
of T-Ref:
Turbine load
0 Boron Concentration
b. s m Step 12.
§RO Transitions to Step 12 A/ER and directs actions.
Step 12 UO/BOP Verify the following PCBs - CLOSED:
Generator breaker 1A
e Generator breaker 1B
0 PCB14
- PCB15
PCB17
PCB18
Step I 3 RO Mjust power factor as necessary. REFER TO Unit 1 Revised Data
Book Figure 43.
N U R E G - 1 0 2 1 Draft R e v i s i o n 9 14 of 3 4
apendix D Operator Actions Form ES-D-:
3p-Test No.: NRC Scenario No.: 2 Event No.: 5-6
ivent Description: CFPT I A trip due to toss of lube oil pumps resulting in turbine runback
. Failure of automatic turbine runback.
Time Position Applicant's Actions or Behavior
3ep 14 ALL the appropriate runback target load is reached, THEN:
Stabilize unit at appropriate power level
Maintain control rods above insertion limits
Adjust the following as required to maintain T-Avg within 1°F of
T-Ref
Turbine load
Boron concentration
Step 15 ROiSRO Notify System Operating Center (SOC) using the red dispatcher
telephone of current unit status.
Step 16 ALL Determine and correct cause of Load Rejection
step 17.a BOP Shut down unnecessary plant equipment as follows:
b. Restore CM and CF as follows:
1) Verify C-htr drain pumps - ON.
EXAMINER NOTE: Based on runback rate, C-Htr Drain Pumps
may not be on at this point. [f not, then SRO will transition to
Step 17.a.l) RNO an direct that action, and then return to MER
17.a.2).
2) Verify bath CF Pumps - IN SERVICE
.
Determines that 1A CF pump is tripped and informs SRO.
SRO Transitions to Step 17.a.2) RNO and directs actions.
Step SRO GO TO Step 17.b
17.a.2)
?NO
SRO Transitions to Step 17.b and directs actions
NUKEG-1021 D r a f t R e v i s i o r . 9 15 of 3 4
ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.: 5-6
Event Description: CFPT 1A trip due to loss of lube oil pumps resulting in turbine runback
sianal. Failure of automatic turbine runback.
~~ ~
Time Position Applicant's Actions or Behavior
17.b BOP b. RC pump(s) and cooling tower fans. REFER
OP/118/6400/001A (Condenser Circulating Water)
Step 18 RO Seset steam dump valves as follows:
a. Verify reactor power - STABLE.
b. Verify steam dump valves - IN "T-AVG MODE.
c. Verify steam dump valves - CLOSED.
d. Reset steam dump valves.
..
e. Verify the following status lights (1.3-18) - BARK.
"C-7A LOSS OF LOAD INTLK COND DUMP
"C-7B LOSS OF LOAD INTLK ATMOS DUMP"
f. E "T-AVG" mode of operation is available, THEN ensure
steam dump valves in "T-AVG" mode.
g. Verify "STM DUMP CTRL" - IN AUTOMATIC.
Step 19 RO Verify reactor power - GREATER THAN 15%
Step 20 RQIBOP Verify CA Pumps -OFF
Step 21 RO Verify reactor power change - GREATER THAN OR EQUAL TO
15% IN A IHOUR PERIOD.
Step 22 ALL Notify the following sections to take appropriate samples:
Radiation Protection to sample and analyze gaseous
effluents. REFER TO Selected Licensee Commitments
Manual, Section 16.11-6.
Primary Chemistry to sample for isotopic analysis of iodine.
REFER TO Tech Specs 3.4.16 (Sample must be taken
between 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> and 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> following last power change
greater than or equal to 15% rated thermal power within a Z
hour period).
NUREG-1021 Draft R e v i s i o n 9 16 of 34
ppendix D Operator Actions Form ES-D-:
3p-Test No.: NRC Scenario No.: 2 Event No.: 5-6
fvent Description: CFPT ZA trip due to toss of lube oil pumps resulting in turbine runback
sianal. Failure of automatic turbine runback
Time
Step 23
0 3.1.1 (Shutdown Margin (SDM))
3.1.6 (Control Bank Insertion Limits)
3.8.1 (AC Sources - Operating)
Determines that none apply.
EXAMINER NOTE: Based on current rod positions, 3.1.6 may
Step 24
ALL i Notify Reactor Group Engineer of occurrence
step 25 Determine long term plant status. RETURN OPI1IAI61001003
(Controlling Procedure for Unit Operation).
NUREG-1021 Draft Revision 9 1 7 of 3 4
Appendix D Operator Actions Form ES-B-2
Op-Test No.: NRC Scenario No.: 2 Event No.: 7
Event Description: Uncontrolled rod insertion in automatic only.
Time Position Amlicant's Actions or Behavior
RO Determines that control rods are continuing to insert when no rod
motion is required and places control rods in manual, informs SRO.
SRO Implements APll/A/5500/15 (Rod Control Malfunctions). Case II
(Continuous Rod Movement) and directs actions.
EXAMINER NOTE: Steps 1 and 2 are Immediate Action steps
and are required to be performed from memory.
Step 1 Ensure "CRD BANK SELECT" switch - IN MANUAL.
RO Dlaces switch in MANUAL.
Step 2 UO Ensure all rod motion - STOPS
Step 3 RO Manually adjust control rods as necessary to maintain T-Avg within
1°F of T-Ref.
Step 4 RO getermine and correct cause of continsus rod movement.
Step 5 SRO Ensure compliance with appropriate Tech Specs:
- 3.1.1 (Shutdown Margin (SDM))
3.1.4 (Rod Group Alignment Limits)
3.1.5 (Shutdown Bank Insertion Limits)
3.1.6 (Control Bank Insertion Limits)
0 3.3.2 (ESFAS instrumentation)
Determines that 3.1.1 and 3.1.6apply if the control rods are below
the rod insertion limits.
Step 6 SRO Determine required notifications:
REFER TO RP/O/A/5O0O/OO.I (Classification of Emergency)
R F E R TO RPIO/B/50001013 (NRC Notification
Requirements)
Step 7 SRO Determine long t e n plant status. RETURN TO procedure in
effect.
NUIIEG-1021 Draft Revision 9 18 of 34
Appendix D Operator Actions Form ES-D-2
Op-Test No,: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on I D steam generator, NS pump If3
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Aeoiicant's Actions or Behavior
EXAMINER NOTE: Crew may manually trip the reactor and
safety inject prior to reaching the setpoints based on the
trends.
ALL Recognize reactor trip and safety injection have occurred.
ROIBOP Perform Immediate Actions of 4 from memory (steps 2-5).
EXAMlNER NOTE: Turbine will fail to trip automatically on
reactor triu and RQ will have to manuallv triD the turbine.
SRO Enter EPIIIN5OOOIE.-0(Reactor Trip or Safety Injection) and direct
actions of operators.
Step 1 ROIBOP Monitor Enclosure 1 (Foldout Page)
Step 2 RO Verify Reactor Trip:
All rod bottom lights - LIT
Ail reactor trip and bypass breakers - OPEN
VR amps - DECREASING
Step 3 RO Verify Turbine Trip:
All turbine stop valves - CLOSED
Determines that turbine has not triooed and informs SRO
SRO Transitions to Step 3.a RNO and directs actions
RO a. Manually trip the turbine.
b. If turbine will not trip, THEN.
Determines that turbine has manually tripped and informs SRO.
SRQ Transitions to Step 4 NER and directs actions.
Step 4 BOP Verify 1ETA and 1ETB - ENERGIZED.
NUREG-1021 Draft R e v i s i o n 9 19 of 34
rppendix D Operator Actions Form ES-D.
Op-Test No.: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on 1 D steam generator, NS pump 1I3
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicants Actions or Behavior
Step 5 BOP Verify SA is actuated:
a. SAFETY INJECTION ACTUATED status light (ISI-13) - LIT
b. E/S load sequencer actuated status lights (IS-14) - LIT
Step 6 RO Announce Unit 1 Safety Injection.
Step 7 SRO Implement RP/O/A/5000/001 (Classification Of Emergency)
Step 8 RO Verify all Feedwater Isolation status lights ( I S M ) - LIT
Step 9 BOP Verify Phase A Containment Isolation status as follows:
a. Phase A RESET lights - DARK
b. Monitor Light Panel Group 5 St lights - LIT
step 10 BOP Verify proper Phase B actuation as follows:
a. Containment pressure - HAS REMAINED LESS THAN 3
PSlG
Determines that pressure has not remained less than 3 psig and
informs SRO.
SRO Transitions to Step 10.a RNO and directs operators.
EXAMINER NOTE: Greater than 3 psig in containment
requires use of ACC numbers throughout the remainder
of the scenario. ACC numbers are designated in
Darentheses behind normal values.
NUREG-1021 Draft Revision 9 20 of 34
Event Description: Steam break inside containment on 1D steam generator. NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Position Applicant's Actions or Behavior
ALL Perform the following:
m: This time may be used later to determine when to align ND
Atix spray.
1) Record approximate time of reactor trip.
2) Verify NS pumps - INDICATING FLOW.
BOP determines that both NS pumps are NOT running and informs
SRO.
3) flow is not indicated. THEN manually initiate Phase B
Isolation for affected train(s).
BOP manually initiates Phase B isolation.
4) Verify Phase B Isolation has actuated as follows:
a) Phase B Isolation "RESET lights - DARK.
b) Phase B Isolation "RESET lights are lit?
manually initiate Phase B:
Determines that this step b) is not required based on plant
conditions.
NUREG-I321 Draft Revision 9 21 o f 3 4
Ipendix D Operator Actions Form ES-D-
Ip-Test No.: NRC Scenario No.:2 Event No.: 8-10
ivent Description: Steam break inside containment on I D steam generator, NS pump I B
ails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicant's Actions or Behavior
- teD 10.a. BOPlRO c) Verify following monitor light panel lights - LIT
INb
Cont.) Group 1 Sp lights
EXAMINER NOTE: Group 1 Sp lights for NS Pumps will not be
lit.
Group 5 Sp lights
Group 5 St lights L/11 and L/12.
d) Emonitor light panel is not in correct alignment,
T#EN ensure correct valve alignment and
component operation.
e) NS Pump(s) did not start, perform the
following for the affected train@):
(1) Reset ECCS.
(2) Reset BIG load sequencer.
6 0 P resets 8 Train DIG load sequencer.
(3) Manually start affected NS Pump.
BOP attempts to manually start 1B NS Pump.
EXAMINER NOTE: These actions will be performed for B train,
however, 1B NS Pump will not start.
(4) IF AT ANY TIME a BIO occurs, THEN restart SI1
equipment previously on.
5) Stop all NC pumps while maintaining seal injection flow.
RO secures all NC Pumps.
6) G O T O S t e p I I .
SRO Transitms to Step 11 N E R and directs actioris.
..- ..-.-..-. .-. -. .-. -. __. .-. .-. .-
NUREC;-1021 Draft R e v i s i o n 9 2 2 of 34
ppendix D Operator Actions Form E$-B-
Op-Test Ne.: NRC Scenario No.:2 Event No.: 8-10
Event Description: Steam break inside containment on 1B steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Aoolicant's Actions or Behavior
Step 11 RO Verify proper CA Pump status as follows:
a. Motor Driven CA Pumps - ON.
Determines that 1A CA Pump is tagged out and crew determines
that transition to RNO is not required.
b. 3 $16 NIB levels - GREATER THAN 1I%.
Step 12 BOP Verify all of the following S/I pumps - ON:
NVpumps
NDpumps
NI DUmDS
Stet, 13 BOP Verifv all KC DumDs - ON
IdUREG-102? Draft R e v i s i o n 9 2 3 of 34
ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on I D steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Aaalicant's Actions or Behavior
Step 14 BOP Verify all Unit 1 and Unit 2 RN pumps - ON
Determines I B RN pump not running and informs SRO.
EXAMINER NOTE: If the crew had the I A RN pump breaker
racked out due to the failure of the discharge valve earlier, the
1A RN pump will not be running.
SRO Transitions to Stee 14 RNO and directs actions.
EXAMINER NOTE: The crew may elect not t o attempt to start
the 1A and 1B RN pumps due to the fact that it tripped earlier
due to a relay actuation.
Step 14 BOP a. IF any Unit 2 RN pump is off, THEN ...
RNO
SRO determines step does not apply and continues
b,lF any Unit 1 RN pump is off, THEN perform the following for the
affected train(s):
EXAMINER NOTE: 1B Train ECCS was previously reset during
attempt to start 1B NS Pump.
1) Reset ECCS
2) Reset D/G Load sequencer
3) Manually start affected pump.
Attempts to manually start 1B RN Pump
4) IF AT ANY TIME a 810 occurs, THEN restart SI1 equipment
previously on.
SRO Transitions to Step 15 N E R and directs actions.
Step 15 BOP/ Verify proper ventilation systems operation as follows:
REFER TO Enclosure 2 (Ventilation System Verification).
Notify Unit 2 operator to perform Enclosure 3 (Opposite Unit
Ventilation Verification).
Step 16 RO Verify all S1G pressures - GREATER THAN 775 PSIG.
Determines all SIG pressures are not 775 psig and informs SRO.
KUREG-1021 D r a f t Revision 9 2 4 of 3 4
ppendix D Operator Actions Form ES-B-:
3p-Test No.: NRC Scenario No.: 2 Event No.:8-10
Event Description: Steam break inside containment on 1D steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicant's Actions or Behavior
SRO rransitions to Step 16 RNO and directs actions.
CRITICAL EXAMINER NOTE: It is critical that the crew take action to
TASK initiate Main Steam Isolation manually upon failed auto action
to prevent excessive cooldown and minimize inventory loss
resulting from all SiGs faulted.
Step 16 'erform the following:
RNO
a. Verify the following valves - CLQSED.
All MSlVs
All MSlV Bypass valves
All SIG PORV's
EXAMINER NOTE: If not previously completed, MSIVs should
be closed at this point.
b. IF any valve is still open, THEN ...
3eterrnines all valves are closed and informs SRB.
SRQ Transitions to Step 27 MER and directs actions
Step 17 RO/BOQ terify proper SI1 flow as follows:
a. "NV SI1 FLOW - INDICATION FLOW.
b. NC pressure - LESS THAN 1620 PSIG.
c. NI pumps - INDICATING FLOW.
d. NC pressure - LESS THAN 285 PSIG.
Determines NC pressure 285 psia and informs SRO
SRQ Transitions to Step 17.d RNO and directs actions.
N U R E G - 1 0 2 1 Draft Revision 9 2 5 cf 3 4
,ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on 1D steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicant's Actions or Behavior
Step 17.d BOP d. Perform the following:
RNO
1) Ensure ND Pump miniflow valve on operating ND
Pumps -OPEN
2) IF the ND Pump miniflow valve(s) cannot be opened,
THEN ...
Determines step 17.d.2) does not apply
3) GO TO Step 18
SRO Transitions to Step 18 N E R and directs actions.
Step 18 BOP Control S/G levels as follows:
a. Verify total CA flow - GREATER THAN 450 GPM.
b. m a t least one S/G N/R level is greater than 1I % (29%
A X ) , THEN throttie feed flow to maintain all SIG NIR levels
between 11% (29% ACC) and 50%.
Step 19 RO Verify all CA isolation valves -OPEN
Step 20 BOP Verify S/I equipment status based on monitor light panel - IN
PROPER ALIGNMENT.
ALL m:Enclosure 4 (NC Temperature Control) shall remain in
effect until subsequent procedures provide alternative NC
~~
temperature control guidance.
Step 21 RO Control NC temperature. REFER TO Enclosure 4 (NC
Temperature Control).
Step 22 BOP Verify Pnr PORV and Pzr spray valve status as follows:
a. All Pzr PORVs -CLOSED.
b. Normal Pzr spray valves - CLOSED.
c. At least one Pzr PORV isolation valve- OPEN.
NIJREG-1021 Draft R e v i s i o n I) 2 6 of 3 4
\ppendix B Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on 1B steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Amlicant's Actions or Behavior
Verify NC subcooling based on core exit T/Cs -GREATER THAN
0°F.
Verify main steamlines are intact as follows:
0 All S/G pressures - STABLE OR INCREASING
All S/GS - PRESSURIZED
Determines that steam generator I D pressure is decreasing or
depressurized and informs SRO.
I SRO Transitions to Step 24 RNO and directs actions.
I
I ~
Step 24 RO/SRO IF any S/Gis decreasing in an uncontrolled manner OR any S/G is
RNO depressurized, THEN concurrently:
0 Implement EP/I/N5000/F-O (Critical Safety Function Status
Trees).
- GO TO EP/I/N5000/E-2 ( Faulted Steam Generator Isolation)
I SRO Transitions to EP/I/N5000/E-2 and directs actions
EXAMlNER NOTE: The following steps will be performed in
EP/WdA15000/FR-Z.1 (Response to High Containment Pressure).
If the Critical Safety Function Status Tree for Containment is
not ORANGE at this time. continue to uaae 31.
1 ALL Crew determines that Containment Oranae Dath is valid
Transitions to EP/l/N5000/FR-Z.I and directs actions.
Monitor Enclosure 1 (Foldout Page).
Verify proper containment isolation and VX operation. REFER TO
Enclosure 3 (Containment Isolation VX System Verification).
NUREG-I321 Draft Revision 9 27 of 3 4
Ippendix D Operator Actions Form ES-D.
Op-Test No.: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on I D steam generator, NS pump I B
fails to start in AUTO of MANUAL, failure of automatic main steam isolation signal.
Time I Position Applicant's Actions or Behavior
Step 3.a.
I SRO Verify proper NS operation as follows:
a. IF EPI7IN5000IECA-I .I(Loss Of Emergency Coolant
Recirculation) is in effect, THEN:
Determines step does not apply and continues to Step 3.b.
b. Verify NS pumps - ON.
Determines that 1 0 NS Pump is OFF and that 1A NS Pump is out
of service and informs SRO.
Transitions to SteD 3.b. RNO and determines actions have been
previously performed. Transitions to Step 3.c. NER.
Verify SI1 systems - IN INJECTION MODE.
d. Ensure all of the following valves - OPEN:
1NS-20A (NS Pump 1A Suct From FWST)
1NS-298 (NS Spray Hdr I A Cont Isol)
INS-32A (NS Spray Hdr 1A Cont Isol)
INS-3B (NS Pump 18 Suct From FWST)
0 INS-158 (NSSpray Hdr 1B Cont Isol)
1NS-12B (NS Spray Hdr 1B Cont Isol).
step 3.e. BOP e . Ensure all of the foilowing valves - CLOSED:
INS-18A (NS Pmp A Suct From Cont Sump)
I N S - I 0 (NS Pmp B Suct From Cont Sump).
Step4 1 RO Stop all NC pumps.
Step 5 RO Verify the following valves - CLOSED:
All MSlVs
All MSlV bypass valves.
NUREG-1021 Draft R e v i s i o r . 9 2 0 of 3 4
rppendix D Operator Actions Form ES-D
Op-Test No.:NRC Scenario No.:2 Event No.: 6-10
Event Description: Steam break inside containment on 1D steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time 1 Position Applicant's Actions or Behavior
Verify main steamlines are intact as follows:
a. Verify:
e All S/G pressures - STABLE
All S/Gs - PRESSURIZED.
Determines that I D steam generator is depressurized and informs
SRO.
SRO Transitions to Step 6.a. WNO and directs actions
Step 6.24. RO a. IF pressure in any S/G is decreasing in an uncontrolled manner
RNO OR any S/G is depressurized, THEN GO TO Step 7.
Determines that I D steam generator is depressurized and informs
SRO.
Transitions to Step 7 and directs actions.
Step 7 Verify at least one S/G pressure - STABLE OR INCREASING.
Determines that I A , 1B and 1C steam generator pressures are
stable and informs SRO.
Step 8 Verify at least one intact SIG -AVAILABLE FOR NC SYSTEM
COOLDOWN.
Determines that I A , 1B and IC are available and informs SRO.
EXAMINER NOTE: st is critical that the crew take action to
isolate feedwater to the faulted SIG to prevent excessive
coeldown and minimize inventory loss and minimize steam
release to containment.
Step 9 RO/BOP Isolate all faulted S/G(s) as follows:
Betermines that I D is faulted.
CRITICAL d. For S/G 1 D:
TASK 1) Verify S/G ID Feedwater Isolation status light (ISI-5) -
LIT.
2) Close 1CA-42B (CA Pmp B Bisch To S/G 1D Isol)
3) Close 1CA-388 (CA Pmp 1 Bisch To S/G 1B Isol)
NIIREG-1021 3raft R e v i s i o n 9 29 of 34
Op-Test No.: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on 18 steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicant's Actions or Behavior
Step 10 RO WHEN NC T-Hots start to increase, THEN dump steam from intact
S/G PORVs to stabilize NC T-Hots.
Step 1 1 BOP Verify conditions allowing alignment of ND for aux containment
spray as follows:
a. At least one ND train -ALIGNED AND OPERATING IN COLD
LEG RECIRC MODE.
Determines that ND is not in CLR and informs SRO.
SRO Transitions to Step 11.a RNO and directs actions.
Step I1 .a a. Perform the following:
KNO 1) WHEN EP/I/N5000/ES-2.3 (Transfer To Cold Leg
Recirculation) is completed, THEN perform Steps 11 and 42.
2) GO TO Step 13.
SUB Transitions to Step 43 N E R and directs actions.
Step 13.a BOP Obtain containment Hz concentration as follows:
a. Ensure operator has been dispatched to secure all ice condenser
air handling units. REFER TO Enclosure 2 (Securing All Ice
Condenser Air Handling Units).
Dispatches operator.
Step 13.b. BOP b. Verify containment Ha analyzers - IN SERVICE
Determines the hydrogen analyzers are not in service and imforms
SRO.
SRO Transitions to Step 13.b. RNO and directs actions.
Step 13.b. BOP b. Perform the following:
RNO I ) Dispatch operator to place containment Hz analyzers in
service. REFER TQ OP/1/N6450/018 (Containment
Hydrogen Control Systems).
Dispatches operator.
2) WHEN Hz analyzers in service, THEN perform Steps 13.c
through 15.
3) GO TO Step 16.
SRO Transitions to Step 16 AER and directs actions.
N U R E G - 1 0 2 1 Draft R e v i s i o n 9 30 of 3 4
ippendix B Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on I D steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicant's Actions or Behavior
Step 16 SRO RETURN TO procedure and step in effect.
SRO Transitions to EP/1/N5000/E-2 and directs actions.
Step 4 ALL Monitor Enclosure 4 (Foldout Page).
Step 2 ALL Maintain any faulted S i 6 or secondary break isolated during
subsequent recovery actions unless needed for NC
System cooldown.
Step 3 RO Verify the following valves - CLOSED:
- All MSlVs
All MSlV bypass valves.
Step 4 RO Verify at least one S/G pressure - STABLE OR INCREASING.
Determines that l A , l B and I C steam generator pressures are
stable and informs SRO.
Step 5 RO Identify faulted S/G(s) as follows:
Verify any S/G pressure - DECREASING IN AN
UNCONTROLLED MANNER
Verify any S/G - DEPRESSURIZED.
Determines 4B steam generator pressure is decreasing in an
uncontrolled manner or depressurized and informs SRO.
Step 6 RO Verify at least one intact SIG -AVAILABLE FOR NC SYSTEM
COOLQOWN.
Determines that ?A, I B and I C are available and informs SRO.
Step 7 RO Isolate all faulted S/G(s) as follows:
Determined need to perform for D S/G.
SI6 I D :
a. Verify S/G I D Feedwater Isolation status light ( I S M ) - LIT.
b. Verify SIG I D PORV - CLOSED.
6. Close the following valves:
1) ISM-74B (SIG 1D Otlt Hdr Bldwn SIG I D Isol).
Closes 1SM-74B.
NURZG-1021 D r a f t R e v i s i o n 9 3 1 of 3 4
ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.:2 Event No.: 8-10
Event Description: Steam break inside containment on 1 5 steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isoiation signal.
Time Position Applicant's Actions or Behavior
BOP 2) ICA-42B (CA Prnp A Bisch To S/G 1B Isol).
3) ICA-38A (CA Pmp 1 Disch To S/G I D Isol).
RO d. Verify the following blowdown isolation valves - CLOSED:
1) 1BB-8A (Si6 1B Bldwn Cont Is01 Insd).
2) 1BB-1478 (S/G 1B Bldwn Cont lsol Byp).
3) 1BB-1OB (SIG 1D Bldwn Cont lsol Otsd).
step a RO WHEN NC T-Hots start to increase, THEN dump steam from intact
S/G PORVs to stabilize NC T-Hots.
Step 9 BOP Verify the following annunciators - DARK.
0 IAB-5, H/4 "CACST LO LEVEL"
e IAD-8, B/1 "UST LO LEVEY
Step 10 BOP Verify secondary radiation is normal as
follows:
a. Ensure the following signals - RESET:
I) Phase A Containment Isolations
2) CA System valve control
3) KC NC NI NM St signals.
b. Align all S/Gs for chemistry sampling.
c. Perform at least one of the following:
Notify Chemistry to periodically sample all SIGs for activity.
Notify RP to periodically frisk all cation columns for activity.
d. Verify the following EMF trip 1 lights BARK:
1EMF-26 (Steamline 1A)
?EMF-27 (Steamline 15)
0 IEMF-28 (Stearnline 1C)
1EMF-29 (Steamline 1D).
e . Verify the S/G(s) fault - INSIDE CONTAINMENT.
f. WHEN Chemistry reports activity results, THEN verify all S/Gs
indicate no activity.
NUKEG-1021 Draft R e v i s i o n 9 32 of 34
ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 2 Event No.:8-10
Event Description: Steam break inside Containment on 1D steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicant's Actions or Behavior
Step 1I ROIBOP Verify S/I termination criteria as follows:
a. NC subcooling based on core exit T/Cs - GREATER THAN 0°F.
b. Verify secondary heat sink as follows:
NIR level in at least one intact SIG - GREATER THAN 11%
(29% ACC)
Total feed flow to all intact S/Gs - GREATER THAN 450
GPM.
c. NC pressure - STABLE OR INCREASING.
d. Pzr level - GREATER THAN 11% (20% ACC).
e. GO TO EQ/I/A/5000/ES-l .I (Safety Injection Termination).
SRO Transitions to EP/1/A/5000/ES-1.1and directs actions.
Step 1 ALL Monitor Enclosure 1 (Foldout Page).
Step 2 BOP Ensure S/I - RESET:
a. ECCS.
b. B/G load sequencers.
e. IF AT ANY TIME a B/O occurs, THEN restart SA equipment
previously on.
Step 3 BOP Ensure the following containment isolation signals - RESET:
PhaseA
PhaseB.
Step 4 BOP Establish VI to containment as follows:
Ensure IVI-97B (VI Cont Isol) - OPEN.
e Verify VI pressure - GREATER THAN 85 PSIG.
Step 5 RO Ensure onlv one NV Dumn
. , ON.
Secures o i e NV pump and informs SRO.
Step 6 RO Verify NC pressure - STABLE OR INCREASING.
Slep 7 BOP Verify VI pressure - GREATER THAN 50 PSIG.
KCREG- 1021 Drsft. Revision 3 33 Cf 34
,ppendix D Operator Actions Form ES-5-:
Op-Test No.: NRG Scenario No.: 2 Event No.: 8-10
Event Description: Steam break inside containment on I D steam generator, NS pump 1B
fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.
Time Position Applicant's Actions or Behavior
Step 8 BOP . Isolate NV S/i flowpath as follows:
a. Verify the following valves - QPEN:
1NV-252A (NV Pumps Suct From FWST)
0 1NV-253B (NV Pumps Suct From FWSTj.
a. Verify the following valves - OPEN:
1NV-203A (NV Pumps A&B Recirc Isol)
INV-2025 (NV Pmps A&B Recirc isolj.
b. Close the following valves:
INI-9A (NV Pmp C / i lnj Isol)
INI-IOB (NV Pmp C/L lnj Isol).
Terminate scenario when 1NI-9A AND 1NI-IQBare closed.
Classification: Alert 4.6.A.1-1
NUREG-1021 Draft R e v i s i o n 9 34 of 34
FOR rRAINING PURPOSFS ONLY
EMERGENCY NOTIFICATION FORM
CrUAL EMCRGFNCY @iTi,L ~FOLLOw-uP MESSAGE NUMBER I
2 *ITE: UNIT: RtPORrED BY:
3. .iANSMITTAL TIMEiDATE: -I - - CONFlRMAilON PHONE NUMBER. (803)R31-3807 (Simulator)
iFiliW: rm Od \Y
4. AUTHENTICAlION (I: Hequired).
NOTIFICAlION OF UNUSUAL EVENT SITE AREA EMERG
- -
46 *T
En6nERGENcY D E s c w T m m m m K s : EAL # 4.6.A.1 - A fire or explosion has caused damage to permanent plant
equipment. This EAL poses no threat to the safety of the general pubiic.
PLANT CONDITION: DIMPROVING
REACTOR STATVS: TlMEiDPTE: i. POWEn
- -
dd ii
lo. EMERGENCY HtLEASE(S):
- I
M NONE (Go lo item 14.)
I. WPE OF RELEASE:
a P O . I E N T I A L (Go to item 14.)
OELEVATCD
m I S OCCURRING
O R O U N D LEVEL
B t W S OCCURHW
mfinnnQNE: SIaWd:
?rrlEzlsfsm)
- -, - I
Oaf?
.q,r..,..v>,<
, ,n*!lar,rrr,j -i -i - Gale
JLIQUID: Started:
T8miFas1~mI
- -i - Dale
Stopped
T#ne!Eai!c~l
-i - cafe
i
-
12 RELEASE MAGNITUDE: D I E S PER SEC. D U R I E S NORMAL OPERATING ILIrJlTS: O B E I . O W OAROVE
NOBLE GASES BIODINFS
OPARTICULATES W t l E R
-
- lZESTIMATE OF PROJECTED OFFSll E DOSE U N E W ~UNCYANGED PRO2ECIION TIME
,tarterr I
TEDE Thyroid CI)
nrrem mrem ESTIMATHJ DURATION HRS
sirE BOUNDARY
2 MILES
5 MILES
10 MILES
-14. METEOROLOGICAL D A T A : ~ W I N DDIRECTION (frcm) mPEEO(mph)
~ S T A B I L I N CLASS ~ P H E C I P I T A T I O N(type!
15.
RECOMMENDED PROTECTIVE ACTIONS
16. APPROVED BY
- If items 6-14 have no: changed, oiily items 1-7 and 15-16are reqdiied to be completed.
Information may ngt he availaWc on :,:ilia1 rmtificiltioris.
FOR TRAINING PURPOSES ONLY
II I
I
, 1. E t h e control rods cannot be maintained above the rod insertion limits, THEN:
- a. Stop any dilutions in progress.
CAUTlON
~. ... Failure to initiate boration within one hour of exceeding rod insertion
h i t s may violate Tech Spec 3.1.6.
NOTE OAC point ClL4409 (Ctrl Bank Tech Spec Insertion bmt Reached) and R.O.0
Book (Section 2.2) provide rod insertion limit indication.
- b. ?orate NC system as required, to restore rods above insertion limits.
- c. Ensure compliance with Tech Spec 3.1.6 (Control Bank Insertion Limits).
Appendix D I n i t i z l Dynamic S i m u l a t o r Scenario Form ES-D-1
$irnulationFacility: Catawba Scenario No.: NRC-1 Op-Test No:
<,miners: Operators: ~ ...~ .. . . ~
Ibjectives: To evaluate the applicants ability to decrease power using the Rapid 1)ownpowe.r
rocedure (AP/09) while maintaining Pave matched to Tref, and to use AOPs to respond to a
ressurizer spray valve failing open, reactor coolant (h-C) 1,oop C T-cold indication fails
iigh resulting in rod motion, a loss of the component cooling water to the non-essential
leaders due to a failed surge tank level transmitter and a loss of condenser vacuum. The
ipplicants will be evaluated using EOPs to respond to a loss of all feedwater to the steam
- enerators resulting in a loss of secondary heat sink, with a success path via enicrgency
mcedure FR-H.1 where the turbine driven auxiliary feedwater pump will be returned to
- ervice.
nitial Conditions: 100% power, BOL, Equilibrium Xe.
NCS Boron Concentration 841 ppm.
rurnover: CA pump 1A is out of service for routine maintenance.. It is due to be returned to
service in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
NS pump 1A is out of service for motor replacement. It is due to be returned to
service in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.
Valve 1NC.-31Bwas just closed due to leakage by PORV 1NC-32B. An K&K is
being developed.
The Operations Duty nianager has instructed you to reduce load within 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> to
65% at 20% per hour in accordance with AI/I/A/5500/09 due to chemistry concerns
for a leak in 1B feedwater pump turbine condenser tube.
I
- (Njomal, :K! e a c t i v i t y , (I)nstrumcnt, ( C ) orrporient, (M! a<or
NUREG- 1.02 1 Page 1 of 31 Draft. R e v i s i o n 9
Appendix D I n i t i a l Zynamic Siwalator S c e n a r i o Fcrm E - D - 1
P
Event Event
Type*
__r -KC - Description
Surge Tank 1,cvel Transmitter fails low resulting in h e
loss of the Auxiliary BuiIdiiig and Reactor Building non-
C-BOP essential headers.
AI-ALL Reactor triu due to loss of vacuum
C-RO CA pump 1R fails to start (50G relay)
C-nm CAPT trips on mechanical overspeed resulting in loss of heat
sink
lXrV-37A fails to position during NC system depressurization.
- (N)orma?, iH)cactivity, (Ijnstrument, :c! omponcnt,
NUREG-LO21 Page 2 of 31 Draft R e v i s i o n 9
Appendix D Operator Actions Form ES-D-2
Event Description: Boration for power decrease
Aoolicant's Actions or Behavior
Per AQ/l/A/5500/09 (Rapid Downpower) Step 12.d. directs BOP
to borate the NC System as required referring to ROD book,
Section 4.8.
NOTE
The boric acid added to the NC System should be added
in several increments.
The boric acid added to the NC System should be added
only during the first hour of the downpower event.
Borate the NC System as required. REFER TO R.O.D. book
Section 4.8.
Directs BOP to determine amount of boron to add to begin the
load change and provides guidance that the boration should be
done in several batches (-455 aallons over the first hour).
p
Determines amount of boron to add (-455 gallons over first
hour).
Refer to OP/1/A/6150/009 (Boron Concentration Control)
Step 2.2 Ensure the following valve control switches in "AUTO":
1NV-238A (B/A Xfer Pmp To Blender Ctrl)
INV-186A (B/A Blender Otlt To VCT Otlt)
Step 2.3 Adjust the boric acid batch counter to the desired volume of boric
acid to be added.
Step 2.4 Place the "NC MAKEUP MODE SELECT switch in "BORATE
Adjust the controller for 1NV-238A @/A Xfer Pmp to Blender Ctrl)
controller to the desired flow.
Step 2.6 Ensure 1NV-238A (B/A Xfer Pmp to Blender Ctrl) controller in
"AUTO".
Step 2.7 NOTE: If necessary, boration can be manually secured at any
time by placing the "NC MAKEUP CONTROL" switch to the
"STOP position.
Ensure at least one boric acid transfer mmD in "AUTO" or "ON"
I Steo2.8 I BOP Place the "NC MAKEUP CONTROL" switch in "START" position
NIJREG-IC21 Draft. Revisicn 9 3 of 31
ppendix D Operator Actions Form ES-D-
3p-Test No.: NRC Scenario No.: 7 Event No.: 1
Event Description: Boration for power decrease
Time Position Amlicant's Actions or Behavior
Step 2.9 BOP Verify the following valves open:
- 1NV-2388 @/A Xfer Pmp To Blender Ctrl Vlv)
step 2.10 BOP If in "AUTO", verify the boric acid transfer pump starts.
Step 2.1 1 BOP Verify proper flow by observing the boric acid flow totalizer
Step 2.12 BOP the desired volume of boric acid is reached on the boric
acid batch counter, ensure the fullowing valves close:
INV-238A (B/A Xfer Pmp To Blender Ctrl Vlv)
0 INV-186A (B/A Blender Otlt To VCT 0th)
Step 2.13 BOP -
IF desired, flush the makeup line as follows:
0 Open the following valves:
INV-242A (RMWST To BiA Blender Ctrl)
INV-186A (B/A Blender Otlt To VCT 0th)
Ensure one reactor makeup water pump is in "ON".
0 WHEN -20 gallons of makeup water have been flushed
through the makeup line, close the following valves:
INV-242A (RMWST To EVA Blender Ctrl)
INV-186A (B/A Blender 0th Tu VCT Otlt)
e Place the following valve control switches in "AUTO":
1NV-242A (RMWST To EVA Blender Ctrl)
0 1 NV-186A @/A Blender 0 t h To VCT Otlt)
IF NOT required for current plant operation, place the reactor
makeup water pump started in earlier step in "AUTO".
Step 2.14 BOP -
IF automatic makeup is desired, refer to Enclosure 4.1 (Automatic
Makeup).
NIIREG-1021 Draft Revision 9 4 of 31
Appendix D Operator Actions Form ES-D-2
1 Op-Test No.: NRC Scenario No.: 1 Event No.:2
-1
Event Description: Turbine load reduction for power decrease using AQ/O9.
I
1 (Classification Of Emergency)
REFER PO RP/O/A/5000/613 (NRC Notification Requirements).
termines that the load reduction is not due to grid instability and
Time required to reduce load
Target load power level
Determines that time rewired to reduce load is 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
Determine the required power reduction rate (MWlmin) from the
table below:
Determines from the table that the requires rate is approximately
3.5 MWlmin.
NLJREG-1021 Draft. Revision 0 5 of 11
Appendix D Operator Actions Form ES-D 2
Op-Test No.: NRC Scenario No.: 1 Event No.: 2
Event Description: Turbine load reduction for power decrease using AP109
Time Position Applicant's Actions or Behavior
Step 9 a0 initiate turbine load reduction as follows:
NOTE
Any load reduction rate of greater than 25 MW/Min must be
performed in the "MANUAL" mode.
Unloading rates greater than 60 MWlMin (5%/minute) will
meet C-7A interlock and may result in steam dump
actuation.
a. Verify automatic turbine load reduction - DESIRED.
b. Enter the desired "LOAD RATE" on the turbine control
panel.
c. Enter the desired "TARGET" on the turbine control panel.
d. Depress the "GO" pushbutton on the turbine control panel.
e. Verify turbine load - DECREASING AS REQUIRED.
f. IF AT ANY TIME the turbine controls fail respond properly,
THEN perform Step 9.e.
Step 10 RO F A T ANY TIME the turbine load reduction rate OR the target load
nust be changed, THEN RETURN TO Step 5.
Step 11 80 4djust power factor as necessary. REFER TO Unit 1 Revised Data
3ook Figure 43.
Step 12 RO Wempt to control T-Avg as follows:
a. Verify T-Ref instrumentation -AVAILABLE.
b. Verify control rods IN AUTO AND STEPPING IN.
c. Maintain T-Avg greater than or equal to 551°F.
Step 12 d BOP UOTE
0 The boric acid added to the NC System should be added in
several increments.
0 The boric acid added to the NC System should be added
only during the first hour of the downpower event.
d. Borate the NC Svstem as reauired. REFER TO R.O.B. book
Section 4.8.
Step 12.e. ALL Ensure operator monitors Enclosure 2 (Rod Insertion Limit
3oration).
NiJKEG-1021 Draft K e v i s i o n 9 6 cf 31
Appendix D Operator Actions Form ES-C 2
Op-Test No.: NRC Scenario No.: 1 Event No.: 2
Event Description: Turbine load reduction for power decrease using AP/03
Time Position Applicant's Actions or Behavior
Step 13 BOP Verify Pzr PORV and Pzr spray valve status as follows:
a. All Pzr PORVs - CLOSED.
b. Normal Pzr spray valves - CLOSED.
Step 14 BOP Operate RC pumps and fans as necessary to maintain RC
temperature greater than 60°F. REFER TO OP/I/B/6400/00'iA
(Condenser Circulating Water System).
Step 15 RO Verify reactor power - LESS THAN 05%.
Determines that reactor power is greater than 85% and informs
SRO.
SRO Transitions to Step 15 RNO and directs actions.
Step 15 ALL IF the target load is less than 05%, THEN:
RNO 1) WHEN time and personnel permit, THEN perform applicable
steps of OP/I/A/6100/003 (Gontrolling Procedure For Unit
Operation).
2) Bo not continue in this procedure until reactor power is less than
85%.
3) WHEN reactor power is less than 85%, THEN GO TO Step 16.
EXAMINER NOTE: The crew may not reduce power past 85%. If
power is less than 85% at this point, the crew will proceed to
Step 16.
Step 16 BOP Dispatch operator to secure both C-Htr drain pumps. REFER PO
OP/I/B/6250/004 (Feedwater Heater Vents, Brains and Bleed
System).
Dispatches operator to secure "C"heater drain pumps.
Step 17 BOP 4lign AS supply to the CF pumps as follows:
3. Adjust IAS-2 (Main Stm To Aux Steam) as necessary to
maintain AS header pressure 165 PSIG.
J. Ensure IAS-12 (AS To CFPT Isol) - OPEN.
c. Dispatch operator to close 1SP-3 $32 To CFPT I A & IEl) (TB-
640, 1G-24).
EXAMINER NOTE: The crew should not have sufficient time to
reduce power to this point.
KUREG-1021 Draft Revision 9 I of 31
Appendix D Operator Actions Form ES-B-2
Op-Test No.: NRC Scenario No.: 1 Event No.:3
Event Description: Pressurizer spray valve 1 NC-29 fails open with manual control available.
Time Position I ADDlicant's Actions or Behavior
BOP 1 Recognize INC-29 is oDen and inform §BO.
Enter AP/I/AJ5500/11 (Pressurizer Pressure Anomalies) Case I
(Pressurizer Pressure Decreasing) and direct actions.
Step 1
Step 2
BOP informs SRO that ail Pzr PORVs are closed.
Step 3 Verify Pzr spray valve@) - CLOSED.
BOP informs SRO that 1NC-29 is open.
SRO Transitions to Step 3 RNO and directs actions.
Step 3.3 BOP Perform the following:
RNO a. Manually close affected spray valve(?.).
BOP doses 1NC-29 manually and informs SRO.
Step 3.b. SRO b. IF affected spray valve(s) will not close, THEN perform the
RNO following:
Determines that this step does not apply and transitions to Step 4
AJER.
Step 4
Step 5
Checks that 1NV-37A is closed and informs SRO.
Step 6
Step 7
Determines that step does not apply and continues to Step 8
NUREG-1321 Draft Revision 9 8 of 31
Event Description: Pressurizer spray valve 1NC-29 fails open with manual control available.
Time Position Applicants Actions or Behavior
step a SRO Ensure compliance with appropriate Tech Specs:
3.3. I (Reactor Trip System (RTS) Instrumentation)
e 3.3.2 (Engineered Safety Features Actuation System (ESFAS)
Instrumentation)
- 3.3.3 (Post Accident Monitoring (PAM) Instrumentation)
3.3.4 (Remote Shutdown System)
3.4.1 (RCS Pressure, Temperature! and Flow Departure From
Nucleate Boiling (DNB) Limits)
- 3.4.4 (RCS Loops - MODES 1 and 2)
3.4.5 (RCS LOOPS - MODE 3)
3.4.6 (RCS LOOPS- MODE 4)
0 3.4.9 (Pressurizer)
3.4.10 (Pressurizer Safety Valves)
- 3.4.1 I(Pressurizer Power Operated Relief Valves (PORVs))
3.4.13 (RCS Operational Leakage).
T
Determines that none apply for the spray valve failure.
Step 9 Ensure PZR PRESS REC SELECT is selected to an operable
channel.
BOP informs SRO that an operable channel is selected.
RETURN PO procedure in effect
Crew may contact Shift Work Manager and/or SPOC far
NUKEG-1021 D r a f t R e v i s i o n 9 9 of 31
Appendix D Operator Actions Form 3-D-2
Op-Test No.: NRC Scenario No.:1 Event No.: 4
Event Description: Channel NC Loop 1°C narrow range cold leg temperature instrument
fails high.
Time Position Applicants Actions or Behavior
EXAMINER NOTE: Ensure control sods are in AUTO prior t o
initiating this event.
EXAMINER NOTE: The following Annunciator Response
Procedures may be referred to during this event. Copies are
attached at the end of the scenario.
1AD-2 Al4;IAD-6 Al6; B/6 and Ci6.
RO Recognize failure of Loop I C narrow range cold leg temperature
instrument and inform SRO.
EXAMINER NOTE: The crew may respond t o this event by
taking control rods to manual and by utilizing guidance
contained i n the Annunciator Response procedures. This is an
acceptable alternative. The following steps outline the actions
the crew will perform if they implement APil!A/55001015 (Rod
Control Malfunction) Case I!.
EXAMINER MOTE: Steps 1 and 2 are Immediate Action steps
and are reauired t o be oerformed from memorv.
SRO Enter AQ/l/A/5509/015 (Rod Control Malfunction) Case 2
(Continuous Rod Movement) and direct actions.
Step 1 80 Ensure CRD BANK SELECT switch - IN MANUAL.
Places Red Control selector switch to manual.
Step 2 RO Verify all rod motion - STOPS.
Observes control rod bank demand counters and DRPI to
determine rod motion has stopped and informs SRQ.
Step 3 RO Manually adjust control rods as necessary to maintain T-Avg within
1 of T-Ref.
O F
Adjusts control rod position as required.
Step 4 ALL Determine and correct cause of continuous rod movement.
Crew may contact Shift Work Manager andlor SPOC for
assistance.
NUREG-1021 2raft Revision 9 10 of 31
,ppendix D Operator Actions Form ES-D-:
Op-Test No.: NRC Scenario No.: 1 Event No.: 4
Event Description: Channel NC Loop 1°C" narrow range cold leg temperature instrument
fails high.
3.1.1 (Shutdown Margin (SDM))
3. I.4 (Rod Group Alignment Limits)
3.1.5 (Shutdown Bank Insertion Limits)
3.1.6 (Control Bank Insertion Limits)
0 3.3.2 (ESFAS Instrumentation).
I
Step 7 Determine long term plant status.
RETURN TO procedure in effect.
NUREG-1021 Oraft &vision 9 11 of 3 1
Appendix D Operator Actions Form ES-D-2
Op-Test No.:NRC Scenario No.: 1 Event No.: 5
Event Descrintion: KC Surge Tank Level Transmitter fails low resulting in the isolation of the
Auxiliary ng and RI ictor Building Non-essential headers.
Time Position Applicant's Actions or Behavior
BOP Recognizes loss of 1B KC surge tank level indication and isolation
of the Auxiliary Building and Reactor Building Non-essential headers
and informs SRO.
SRO SRO refers to AP/I/A/5500/21 and directs actions.
ALL CAUTION: Failure to restore NC pump seal cooling via thermal
barrier cooling or NV seal injection within I O minutes will cause
damage to the NC pump seals resulting in NC inventory loss.
Step 1 ALL Monitor Enclosure 1 (Foldout Page).
Step 2 BOP Verify at least one KC pump - ON
Step 3 ALL IF AT ANY TIME all KC pumps are lost. THEN RETURN TO
STEP 2.
Step 4 BOP Verify both KC surge tank levels - 50% to 90% and STABLE.
EXAMINER NOTE: The crew may go to Step 4 RMO due to the
fact that the I3 KC surge tank was previously indicating Isw.
The booth operator wili have cleared the failure of the surge
tank level transmitter by this time and surge tank level
indication will have returned to normal.
Step 5 BOP Starf additional KC purnp(s) as necessary to supply any KC loads
presently in service.
ALL CAUTION: A loss of KC cooling to the NC pumps results in a
gradual approach to an overheated condition in approximately 10
minutes which will result in shaft seizure.
Step 6 BOP Verify KC flow to NC pumps as follows:
- IAD-20, Ail "KC SUPPLY HBR FLOW TO NCP BRGS
LOW! - DARK
0 1AD-21 AI1 "KC SUPPLY HDR FLOW TO NCP BRGS
LOWf - BARK.
Determines that annunciators are LIT and informs SRO.
SRO Transitions to Step 6 RNO and directs actions
NUREG:021 Draft Revision 9 12 of 31
ippendix D Operator Actions Form ES-D.
Op-Test No.:NRC Scenario No.: 1 Event No.: 5
Event Description: KC Surge Tank Level Transmitter fails low resulting in the isolation of the
Auxiliary Building and Reactor Building Non-essential headers.
Time Position Applicant's Actions or Behavior
Step 6 BOP Perform the following:
RNO 8 . Ensure the following valves - OPEN:
IKC-425A (NC Pumps Ret Hdr Cont Isol)
1KC-338B (NC Pumps Sup Hdr Cont Isol)
IKC-424B (NC Pumps Ret Hdr Cont Isol).
3etermines that valves are open and informs SRO.
Step 6 ALL 3. IF AT ANY TIME any of the following conditions are met:
RNO 0 Time since loss of KC - GREATER THAN 10 MINUTES
Any NC pump trip criteria from Enclosure 1 (Foldout Page)
is met.
THEN ...
letermines that none of the conditions exist
SRO rransitions to Step 7 N E B and directs actions.
Step 7.a BQP Jerify KC available as follows:
a. Verify the following Train A KC nen-essential header isolation
valves -OPEN:
IKC-230A (Rx Bldg NOn-Ess Hdr 1 ~ 0 1 )
1KC-3A (Rx Bldg Non-Ess Ret Hdr Iscl)
IKC-5CA (Aux Bldg Non-Ess Hdr Isol)
IKC-1A (Aux Bldg Non-Ess Ret Hdr Isol)
Step 7.b. BOP I. Verify the following Train B KC non-essential header isolation
valves -OPEN:
1KC-228B (Rx Bldg Non-Ess Hdr Isol)
1KC-I 8B (Rx Bldg Non-Ess Ret Hdr [sol)
1KC-53EI (Aux Bidg Non-Ess Hdr Isol)
1KC-25 (Aux Bldg Non-Ess Ret Hdr Isol).
letermines that all 4 valves are dosed and informs SRO.
SRO rransitions to Step 7.b. RNO and directs actions.
NUREG-1021 Draft R e v i - s i o n 9 13 of 31
.ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 1 Event No.: 5
Event BescriDtion: KC Surge Tank Level Transmitter fails low resulting in the isolation of the
Auxiliary Builhing and R ictor Building Non-essential headers.
Time Position Applicant's Actions or Behavior
Step 7.b. BOP NOTE The KC nen-essential header valves can be reopened when
RNO the appropriate train's level switch is reset. This should occur
between 40% and 48% KC surge tank level.
a. WHEN OAC alarm ClB2224 (KC Train R Low-Low Surge Tank
Isol) is "NOT ACTUATED, THEN ensure the affected valves are
open.
Determines that OAC alarm C1D2214 (KC Train B Low-Low Surge
Tank Isol) is "NOT ACTUATED" and informs SRO.
SRO Directs BOP to open the following valves:
- 1KC-228B (Rx Bldg Non-Ess Hdr Isol)
IKC-188 (Rx Bldg Non-Ess Ret Hdr Isol)
IKC-53B (AUX Bldg Non-E~sHdr Iso~)
IKC-25 (Aux Bldg Non-Ess Ret Hdr Isol)
BOP Opens the following valves:
0 IKC-228B (Rx Bldg Non-Ess Hdr lsol)
1KC-18B (Rx Bldg Non-Ess Ret Hdr Isol)
1KC-53B (Aux Bldg Non-Ess Hdr Isol)
1KC-2B (Aux Bldg Non-Ess Ret Hdr Isol).
Informs Sa0 when all valves are open.
SRO Transitions to Step 7 s . N E R and directs actions.
Step 7.c. BOP c. Start additional KC pump@)as necessary to supply any KC loads
presently in service.
Determines additional KC pumps are not needed and informs SRO.
Step 8.a BOP Verify KC surge tank levels normal as follows:
a. Verify both KC surge tank levels - 50% - 90% AND STABLE
Step 8. b SR8 b. GO TO Stepl2.
SRO transitions to Step 12 N E R and directs actions.
Step 12 BOP Ensure KC heat exchanger outlet mode switches - PROPERLY
ALIGNED.
3eg 13 ALL Determine and correct cause of loss of KC.
2rew may contact Shift Work Manager and/or SPOC for
assistance.
NURCG-1021 D r a f t R e v i s i o n 9 14 of 31
ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 1 Event No.: 5
Event Description: KC Surge Tank Level Transmitter fails low resulting in the isolation of the
Auxiliarv Building and Reactor Building Non-essential headers.
Time Position Applicant's Actions or Behavior
Step 14 SRO Ensure compliance with appropriate Tech Specs and Selected
Licensee Commitments Manual:
SLC 46.9-7 (Boration Systems Flow Path- Shutdown)
SLC 16.9-8 (Beration Systems Flow Path- Operating)
SLC 16.9-9 (Boration Systems Pumps -Shutdown)
SLC 16.9-10 (Boration Systems Charging Pumps - Operating)
3.5.2 (ECCS - Operating)
3.5.3(ECCS -Shutdown)
3.6.6 (Containment Spray System)
3.7.5 (Auxiliary Feedwater (AFW) System)
3.7.7 (Component Cooling Water (CCW) System).
Determines that none apply,
Step 15 SRO Determine required notifications:
REFER TO RP/O/A/5000/001 (Classification Of Emergency)
- REFER TO RP/OIB/5000/013 (NRC Notification Requirements).
Step 46 ALL IF KC Hx leak to RN is suspected, THEN ...
Determines no KC heat exchanger leak to RN is suspected.
Step 17 BOP Verify KC surge tanks level as follows:
- Greater than 50%
Stable or increasing.
Step 2 8 %OP WHEN plant conditions permit, THEN return KC pumps to normal
operation. REFER TO OP/l/A/6408/005 (Component
Cooling System)
No additional action. KC alignment is normal at this point.
Step 19 RO Verify 1AD-9, F/3 "LETBN HX OUTLET HI TEMP' - DARK.
EXAMINER NOTE: 1AD-7, F13 may be LIT at this point. If so, the
SRO will transition to the Step 19 RMQ and direct actions.
Ster, 20 RO IF desired to restore letdown flow through the NV demineralizers,
THEN momentarily place 1NV-153A (Letdn Hx
Otlt 3-Way Vlv) to the "DEMIN" position and return to "AUTO".
Step 21 SRO Determine long term plant status.
RETURN TO procedure in affect.
NUREG-I321 Draft. Revision 9 15 of 31
Appendix I3 Operator Actions Form ES-D-2
Op-Test No.: NRC Scenario No.: 1 Event No.: 6
Event Description: Loss of condenser vacuum.
Time Position Applicant's Actions or Behavior
EXAMINER NOTE: The following Annunciator Response
Procedures may be referred to during this event. Copies are
attached at the end of the scenario.
IAD-2 A19 and E19
BOP Recognize symptoms of condenser vacuum decreasing and inform
SRO.
SRO Enter AP/l/A/5500/23 (Loss of Condenser Vacuum) and direct
actions.
ALL Monitor Enclosure 1 (Foldout Page)
Step 2 RO Manually decrease turbine load to preserve vacuum as follows:
NOTE: In "MANUAL" mode, the control valves are capable of full
travel within 3 minutes.
a. Select "MANUAL" on turbine control panel.
b. Depress "CONTROL VALVES LOWER' pushbutton and reduce
turbine load as required.
c. Refer To AP/l/A/5500/09 (Rapid Downpower) as time and
manpower permit.
EXAMINER NOTE: The vacuum Keak will initially be set at 25%
of the malfunction range and then will be increased to 100% of
the malfunction range when step 1 of the AP is read. It is not
expected that the crew will reach the end of this procedure
before reactor triplturbine trip is required.
Step 3 BOP Verify proper RC System operation as follows:
a. Verify average condenser inlet temperature OAC point C1PI493
1 C1 & C2 Average RC inlet Temp) - LESS THAN 90°F
b. Verify 1AB-8, B/4 "CQQLING TOWER BASIN HI/LO LEVEL" -
DARK.
Step 4 BOP Ensure proper operation of ZP System. REFER TO
OP/O/B/6250/011 (Vacuum Priming System).
BOP Verify steam pressure to CSAE -GREATER THAN 110 PSIG.
Step 6 RQ Dispatch operator to place idle set of CSAE jet(s) in operation.
REFER TO OQil/B/6300/006 (Main Vacuum).
Step 7 RB Verify steam seal header pressure - BETWEEN 3 PSIG - 5 PSIG.
!UREG-l(?: Draft. ?vision Y 1 6 o f 31
ppendix D Operator Actions FOrM ES-B-2
I
Op-Test No.:NRC Scenario No.: 1 Event No,: 6
Event Description: Loss cf condenser vacuum.
Applicant's Actions or Behavior
Dispatch ogerator(s) to verify proper seal trough flows. REFER TO
Enclosure 2 (Verification Of Seal Flows).
Dispatch operator to ensure CFPT seal system and water boxes
operating properly. REFER TO Enclosure 3 (CFPT
Stm Seal And Waterbox Vent Verificaticn).
Verify condenser vacuum status as follows:
a. Condenser vacuum -STABLE OR INCREASING.
Determines condenser vacuum is decreasing and informs SRO.
SRO Transitions to Step 10.a. RNO.
a. Perform the following:
1) Dispatch operator to place main vacuum pump(s) in service
REFER TO Enclosure 4 (Placing Main Vacuum Pumps in
Service).
Step SRO 2) GO TO Step 11.
103.2) Transitions to Step 11 N E R and directs actions.
RNQ
Determine and correct cause of loss of vacuum.
Crew may contact Shift Work Manager andlor SPOC for
assistance.
Determine required notifications:
REFER TO RP/O/N5000/001 (Classification Of Emergency)
REFER TO RP/OIB/5000/013 (NRC Notification Requirements).
Determines none are required at this time.
EXAMINER NOTE: This assumes that the reactor and turbine
I have not yet tripped.
Step 23 SRO Determine long term plant status.
RETURN TO procedure in affect.
NUREG-1021 Drzft l i e v i s i o n 9 17 of 3:
Appendix D Operator Actions Form ES-D-2
Bp-Test No.:NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor triphrbine trip due to loss of condenser vacuum. CA pump 1B
fails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
feedwater results in 105s of secondary heat sink. Auxiliary Pzr spray will not be available
resulting in NCS depressurization using Pzr PORV.
Time Position I Applicant's Actions or Behavior
EXAMINER NOTE: Reactor trip is going to be required due to
the loss of condenser vacuum and >69% power in Event 6.
NOTE: The crew will be informed that the CAPT Trip and
Throttle Valve is reset 5 minutes after an operator is
disuatched but not urior to entw into FR-H.1.
sRo I Directs RO to trip the reactor
SRO Enter EP/l/N5000/E-0 (Reactor Trip or Safety Injection) and direct
actions of operators.
Step 1
Step 2
0 All rod bottom lights - LIT
All reactor trip and bypass breakers - OPEN
I/R amps - DECREASING
Step 3 RO Verify Turbine Trip:
0 All turbine stop valves - CLQSD
Step 4
I Verify 1ETA and 1ETB - ENERGIZED.
NUREG-1021 Draiz Reviision 9 18 of 31
ppendix B Operator Actions Form ES-B-
Op-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor triphrbine trip due to loss of condenser vacuum. CA pump 1B
fails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of alt auxiliary
feedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
resulting in 2s depre! irization using Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 5.a BOP Verify SA is actuated:
a. "SAFETY INJECTION ACTUATED" status light (13-13) -LIT
Observes status light is DARK and informs SRO.
SRO Transitions to Step 5.a RNO and directs BOP
Step 5 x 1 ) BOP a. Perform the following:
RMO
1) Verify conditions requiring Sli:
Pzr pressure-LESS THAN 1845 PSiG
Containment pressure-GREATER THAN 1.2 PSIG
Determines safety injection is not required and informs SRO.
Step 5.a.2) SRO 2) IF SI1 is required, THEN manually initiate SA
RNO
SRO determines this steo to be NIB.
Step 5.a.3) SRO 3) IF S/l is not required, THEN concurrently:
WQ
Implement EP/I/N50QO/F-Q(Critical Safety Function
Status Trees).
GO TO EP111A150001ES-0.1 (Reactor Trip
Response)
Transitions to EQ/l/N5000/ES-0.1 (Reactor Trip Response) and
directs actions.
EXAMINER NOTE: The CSF Status Tree for HEAT SINK will
change to a RED status after entry into EPlllAl5000lES-0.1 at
various times based on the rate of progress through the
procedure.
when transition occurs skip forward to the * step on page 23.
Step 1 ALL 1. Monitor Enclosure I(Foldout Page).
"JREG-1021 D r a f t Revision 9 19 of 31
,ppendix D Operator Actions Form ES-D-:
Op-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor triphrbine trip due to loss of condenser vacuum. CA pump 1B
fails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
feedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
resulting in NCS depressurization using Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 2 BOP 2. Verify the following:
.All 6.9 KV busses - ENERGIZED
VI pressure - GREATER THAN 85 PSI6
Step 3 RQ Announce "Unit 1 Reactor Trip".
Step 4 SRO Implement RP/O/A/5000/01 (Classification of Emergency).
ALL NOTE Enclosure 2 (NC Temperature Control) shall remain in
effect until subsequent steps provide alternative NC temperature
control guidance.
Step 5 RO Control MC temperature. REFER TO Enclosure 2 (NC Temperature
Control).
Step 6 80 Verify feedwater status as follows:
a. T-Avg - LESS THAN 564°F.
b. All Feedwater Isolation status lights (ISI-5) - LIP.
c. Total feed flow to S/G(s) - GREATER THAN 450 GPM.
Determines that total feed flew is 0 and informs SRO
EXAMINER NOTE: No feedwater will be available at this point
and the crew will eventually meet the criteria to transition to
FR-H.1 (Response to Loss of Secondary Heat Sink).
SRO Transitions to 6.c RNO and directs actions.
Step 6.c BOP c. Establish feed flow to maintain at least one S/G N/R level
RNO greater that 41% OR total feed flow greater than 450 GPM
using one of the following:
CApumps
Main Feedwater System. REFER TO OP/I/A/6250/001
(Condensate and Feedwater System)
N U R E G - 1 0 2 1 Drafr R e v i s i c n 9 20 of 31
\ppendlx D Operator Actions Form E§-D
Op-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor triphrbine trip due to loss of condenser vacuum. CA pump 1B
fails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
feedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
resultina in NCS deDressurization using Pzr P O W .
Time Position Applicant's Actions or Behavior
EXAMlNER NOTE: The crew may choose to refer to
AP/l/A/5500/06 (Lossof SI6 Feedwater) at this point to attempi
to restore a source of feedwater andlor may choose to attempt
to start available CA pumps at this point.
Step 7 RO Verify adequate shutdown margin as
follows:
a. BRPl indication - AVAILABLE.
b. All control and shutdown rods - FULLY INSERTED.
C. All NC T-Colds - GREATER THAN 535°F.
BOP d. Stop any boron dilutions in progress.
Step 8 BOP Verify proper Pzr level control as follows:
a. Pzr level - GREATER THAN 17%.
b. Charging and letdown - IN SERVICE.
c. Pzr level -TRENDING TO "PZR REF LEVEL".
Step 9 RQ Verify proper Pzr pressure control as follows:
a. Pzr pressure - GREATER THAN 1845 PSIG
b. Pzr pressure - STABLE AT OR TRENDING TO 2235 PSIG.
Step 10 RQ Control SIG levels as follows:
a. Verify NIB level in all SIGs - GREATER THAN 1 1 %.
b. Throttle feed flow to maintain all SIG NIR levels between 11%
and 50%.
Step 1 1 BOP Verify all AC busses are energized by offsite power as follows:
0 A Train:
"FTA BIO NORM FBR FRM ATC" - CLOSED
"DIG ZA BKR TO ETA" - OPEN
1 ETA - ENERGIZED.
B Train:
0 "FTB BIO NORM FDR FRM ATB" - CLOSED
- "D/G 1B BKR TO ETB' - OPEN
- IETB - ENERGIZED.
NUREG-I021 C r a f t R e v i s i o n 9 21 of 31
ppendix D Operator Actions Form ES-D-
3p-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor triphrbine trip due to loss of condenser vacuum. CA pump 1B
'ails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
'eedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
.esulting in NCS depressurization using Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 12 80 Transfer condenser steam dump to pressure control mode as
follows:
a. Verify 'IC-9 (FOND AVAILABLE FOR STM DUMP status light
(ISI-18) - LIT.
b. Verify all MSlVs - OPEN.
e. Ensure "STM DUMP CTRL" pot - SET AT 8.43 (I090 PSIG
STEAM HEADER PRESSURE).
d. WHEN the steam dump valves are closed, THEN:
1) Reset C-7A and C-76.
2) Place "STM DUMP CTRL" in manual.
3) Adjust the "STM DUMP CTRL" to 0% "STM DUMP CTRL"
demand.
4 ) Place the steam dumps in pressure mode.
5) Place the "STM BUMP CTRL" in automatic
Steo 13 BOP Verifv at least one NC D U ~ - D ON.
Step 14 80 Determine status of NIls as follows:
a. Verify IlR channels - LESS THAN 10-10 AMPS
EXAMINER NOTE: Based on reader progress through the
procedure the IIR channels may ob may not be 10-10 AMPS.
If they are not, then continue, if they are, then skip to step 15.
SRO Transitions to Step 14 RNO and directs actions.
Step 14 RO a. Perform the following:
?NO 1) WHEN IlR channels are less than 10-10 Amps, THEN
perform Steps 14.b and 14.c.
2) GO TO Step 15.
STEP 15 ALL Maintain stable plant conditions as follows:
a. Pzr pressure at 2235 PSIG.
b. Pzr level at "PZR REF LEVEL".
c. SIG NIR levels between 11% and 50%
d. Verify at least one NC pump - ON.
e. NC T-Avg at 557°F.
NLJREG-1021 Draft Revision 9 22 of 31
ppendix 5 Operator Actions Form ES-5-2
Op-Test No.: NRC Scenario No.: 1 Event No.: 7-9
I
Event Description: Reactor tripkurbine trip due to loss of condenser vacuum. CA pump 1B i
fails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary i
feedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
asulting in S : depre: urization using Pzr PORV.
Time Position Applicant's Actions or Behavior
k EXAMINER NOTE: Transition to FR-H.1 should be required by
this point due to a red path for secondary heat sink on the
Critical Safety Function status trees.
EXAMINER NOTE: The crew will be informed that the CAPT
Trip and Throttle Valve is reset 5 minutes after an operator is
dispatched but not prior to entry into FR-H.1.
Step 1 ALL IF total feed flow is less than 450 GPM due to operator action,
THEN RETURN TO procedure and step in effect.
Crew determines that total feed flow is 0 GPM and it is not due to
operator action. SRO continues in procedure.
ALL CAUTION: IF a non-faulted S/G is available, THEN feed flow
should only be established to non-faulted S/G(s) in subsequent
steps.
step 2 RO Verify secondary heat sink is required as
follows:
a. NC pressure - GREATER THAN ANY NON-FAULTED S/G
PRESSURE.
b. Any NC T-Hot - GREATER THAN 350°F
step 3 ALL Monitor Enclosure 1 (Foldout page).
- teo 4 BOP Verify at least one NV pump -AVAILABLE.
jtep 5 80 Verify bleed and feed is required as
follows:
a. W/R level in at least 3 S/Gs - LESS THAN 24% (36% ACC).
Determines that bleed and feed criteria are not met and informs
SRO.
SRO Transitions to Steo 5.a. RNO
N3RF.G-1021 Draft Revision 9 2 3 of 21
ppendix D Operator Actions Form ES-B-
Qp-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor tripIturbine trip due to loss of condenser vacuum. CA pump 1B
fails to start. Turbine driven CA pump trips on mechanical overspeed. LOSSof all auxiliary
feedwater results in loss of secondary heat sink. Auxiliary Pnr spray will not be available
- esultina" in NCS deoressurination usina Pzr PBRV.
I
Time Position Applicant's Actions or Behavior
Step 5.a. ALL a. Perform the following:
?NO 1) Monitor bleed and feed initiation criteria. REFER TO
Enclosure 1 (Foldout Page).
2) WHEN criteria is satisfied, THEN GO TO Step 18.
3 ) G 0 TO Step 6.
step 6 RO Verify S/G inventory loss is minimized as
follows:
..
a. All of the following blowdown isolation valves CLOSED:
IBB-56A (SIG 1A Bldwn Cont Is01 Insd)
IBB-148B (SIG 1A Bldwn Cont ISOI Byp)
e
.. 1BB-57B (S/G I A BldWn Cont Is01 Otsd)
IBB-19A ( S G 1B Bldwn Cont Is01 Insd)
.. 1BB-1508 (SIG 1B Bldwn Cont Is01 Byp)
1BB-21B (S/G 1E Bldwn Cont Is01 Otsd)
...
1BB-60A (SIG 1C Blclwn Cont Is01 Insd)
1BB-149B (SI6 1C Bldwn Cont Is01 Byp)
IBB-618 (SIG I C Bldwn Cont Is01 Otsd)
..
1BB-8A (SIG 1D Bldwn Cont Is01 insd)
188-2478 (SIG 1D BidvJn Cont Is01 Byp)
IEB-1OB (S/G 1D Bldwn Cont ISOIOtsd).
BOP b. All SIG sample isolation valves - CLOSED.
-
Step 7 BOP 4ttempt to establish CA flow to at least one SIG as follows:
a. Verify the following annunciators BARK.
IAD-8, B I l "UST LO LEVEL"
BOP D. Verify the following CA suction valves - OPEN:
ICA-6 (CA Pmps Suct From CA CST)
0 ICA-4 (CA Pmps Suct From UST)
BOP 3. Verify proper CA pump status as follows:
1) Power to both motor driven CA pumps - AVAILABLE.
2) IAD-5. F/3 "CAPP MECH OS TRIP' - DARK.
3et&nines.lAB-5 FI3 is LIT and informs SRO.
SRO Transitions to Step 7.c.2) RNB and directs actions.
NUREG-1021 D r a f t R e v i s i o n 9 24 of 31
ppendix B Operator Actions Form ES-D-
3p-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor triplturbine trip due to (oss of condenser vacuum. CA pump 15
fails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
eedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
eesulting in NCS depressurization using Pzr PORV.
Time Position Applicants Actions or Behavior
Step 7.c.2) 2) Perform the following:
?NO a) Dispatch operator to reset the CAPT trip and throttle valve.
b) WHEN the CAPT trip and throttle valve is reset, THEN
perform Steps 7.c.2 through 7.c.4.
c) GO TO Step 7.d.
BOP dispatches an operator to locally reset the CAFT trip and
throttle valve. SRO transitions to Step 7.d. NER.
Step 7.d. RO d. Verify all CA isolation valves - OPEN.
e. Verify all CA flow control valves - OPEN
f. Start all available CA pumps.
g. Verify total feed flow to S/Gs GREATER THAN 450 GPM.
Informs SRO that total feed flow is 0 GPM.
SRO SRO transitions to Step 7.9. RNO
Step 7.9 RO/BOP 1) IF CA flow indicated AND flow is being controlled as required by
?NO Enclosure E (Hot Dry S i 6 Feed Flow Restoration Limits), THEN
GO TO Step 36.
Crew determines step does not apply
2) IF no CA pumps can be started, THEN dispatch operator and
maintenance to CA pumps to attempt to restore one CA pump to
service per EM/l/N5200/007 (Troubleshooting Cause For CA
Pump(s) Failing To Stat)
Crew dispatches an operator and maintenance to attempt to restore
m e CA pump.
3) Dispatch operator(s) to verify proper CA valve alignment. REFER
TQ Enclosure 2 (Local CA Flawpath Restoration).
4) GO TQ Step 8.
SRO Transitions to SteD 8 AJER.
Step 8 BOP Stop all NC pumps.
ZRITICAL.
STEP
NUKEG-1321 Draft K c v i s i o n 9 2 5 of 31
ppendix D Operator Actions Form ES-D-
3p-Test No.: NRC Scenario No.: 1 Event No.: 7-9
=vent Description: Reactor trip1turbine trip due to loss of condenser vacuum. CA pump 15
'ails to start. Turbine driven CA pump trips an mechanical overspeed. Loss of all auxiliary
'eedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
-esulting- in NCS depressurization using Pzr PORV.
Time Position Applicant's Actions or Behavior
step 9 BOP Verify CM System is in service as follows:
Hotwell gump(s) - ON.
Condensate Booster pump(s) - ON.
Step 10 RO Attempt to reset Feedwater Isolation as follows:
a. Verify the following annunciators BARK:
- ?AD-8, D17 "INNER DOGHOUSE TRAIN A LEVEL HI"
?AB-8, 37"INNER DOGHOUSE TRAIN 5 LEVEL HI"
0 IAD-8, D18 "OUTER DOGHOUSE TRAIN A LEVEL HI"
?AD-8, E18 "OUTER DOGHOUSE T W I N B LEVEL HI"
BOP b. Verify $11 - HAS PREVIOUSLY ACTUATED.
Determines that SA has not previously actuated and informs SRO.
SRO Transitions to step IO.b. RNO and directs actions.
Step 10.b. RO b. Perform the following:
?NO 1) Reset Feedwater Isolation.
RO resets Feedwater Isolation by depressing the "CF ISOL
RESET" switches on IMC-3 for " A "B"trains. Verifies annunciators
AD-6 C16 and AD-6 D/6 are BARK. Reports to SRO that feedwater
isolation is reset.
2) IF Feedwater Isolation will not reset, THEN _..
Determines step is N/A, CF Isolation IS reset
3) GO TO Step 10.j
SRQ Transitions to Step 10.j. MER.
Step 1O.j. ALL j. IF AT ANY TIME a subsequent Feedwater lsolation occurs,
THEN RETURN TO Step 10.
EXAMINER NOTE: A subsequent feedwater isolation is
expected during the SIG depressurization in Step 15.
NUREG- 1071 D r a f t Revision 9 2 6 o f 32
tppendix D Operator Actions Form ES-B-:
Op-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor trip/turbine trip due to loss of condenser vacuum. CA pump 1B
fails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
feedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
resulting in NCS depressurization using Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 11 RO 4ttempt to establish CF flow to at least one S/G as follows:
a. Place the foliowing valves in manual and closed:
0 All CF control valves
All CF bypass control valves.
RO places the control stations for all CF control valves and all CF
oypass control valve in manual and reduces demand to zero.
EXAMINER NOTE: Crew may decide to attempt to only feed
one steam generator. This is acceptable.
RO 5. Open at least one of the following valves:
ICA-149 (S/G I A CF Byp To CA Nozzle)
1CA-?5@(SIG I B CF Byp To CA Nozzle)
1CA-151 (S/G I C CF Byp To CA Nozzle)
- ICA-152 (SIG 1B CF Byp T O CA Nozzle)
9 0 opens ICA-149, ICA-150, ICA-151 and ICA-152 and informs
SRO.
BOP :. Ensure at least one of the following valves OPEN:
~
ICF-10 (CF Pump 1A Disch Isol) (TB-579, 1E-21)
0 ICF-17 (CF Pump 1B Disch Isol) (TB-579, 1E-25).
i Verify the following feedwater pump recirc valves - FULLY
OPEN:
- ICF-6 (CF Pump 1A Recirc Ctrl)
ICF-13 (CF Pump 1B Recirc Ctrl).
ALL 3. Ensure the CFPT to be started -:RESET.
Mermines that neither CFPT can be reset due to loss of vacuum.
'nforms SRO.
SRO rransitions to step 11.e. RNO and directs actions.
Step 1I' .e. ALL 2. Perform the following
RNO 1) Continue attempts to start a CFPT.
2) GO TO step 13.
SRO rransitions to Step 13 NER.
NUREG-102.L D r a f t Xevision 9 27 of 3:
ppendix B Operator Actions Form ES-D-
3p-Test No.: NRC Scenario No.: 1 Event No.: 7-9
-
=vent Description: Reactor triplturbine trip due to loss of condenser vacuum. CA pump 1B
'ails to start. Turbine driven CA pump trips on mechanical overspeed. boss of all auxiliary
'eedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
esulting in NCS depressurization using Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 13 BOP Depressurize NC S y s t e ~as follows:
a. Verify letdown - IN SERVICE.
b. Veri& power to INV-37A (NV Supply To Pzr Aux Spray) -
AVAILABLE.
c. Depressurize NC System to less than 1905 PSlG using NV aux
spray as follows:
I)Open the following valves:
1NV-312A (Chrg Line Cont Isol)
0 1NV-3148 (Chrg Line Cont Isol)
2 ) Ensure the following valves -CLOSED:
0 1NC-27 (Pmr Spray Ctrl Frm Loop A)
1NC-29 (Pnr Spray Ctrl Frm Loop B)
1NV-39A (NV Supply TO LOOP D IsoI)
- INV-32B (NV Supply TO LOOPA IsoI).
3) Maintain charging flow less than 180 GPM
I ) Throttle 1NV-378 (NV Supply To Pzr Aux Spray) and charging
Row as required.
30P determines that 1NV-3i'A will not open and informs SRQ.
SRQ Transitions to Step 13.c RNO and directs actions.
Step 13.c BOP 3epressurize NC System to less than 1905 PSlG using one Pzr
3NO =ow.
SRO Transitions to Step 13.d N E R and directs actions.
Step 13.d BOP j. Maintain NC pressure less than 1905 PSIG.
NURE(;- 1021 3rait R e v i s i o n 9 2 8 of 31
ppendix D Operator Actions Form ES-D-
3p-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor trip/turbine trip due to loss of condenser vacuum. CA pump 1B
!ails to start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
'eedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
-esultina- in NCS deDressurization using Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 13.e. BOP e. IF AT ANY TIME letdown is lost AND a Pzr PORV is available,
THEN:
1) Close 1NV-99A (NV Supply To Pzr Aux Spray).
.
2) Open one of the following valves:
1NV-39A (NV Supply TO LOOPD 1 ~ 0 1 )
. OR
1NV-32B (NV Supply TO LOOPA Iso~).
3) Depressurize NC System to less than 1905 PSIG using one
Pzr PORV.
Step 14 BOP Block SI1 as follows:
a. Verify "P-I 1 PZR SA BLOCK PERMISSIVE' status light (IS-18)
-LIT.
Determines status light is BARK and informs SRO
SRO Transitions to Step 14.a RNO and directs actions
Step 14.a BOP a. Perform the following:
?NO 1) WHEN "P-I 1 PZR SA BLOCK PERMISSIVE" status light
(13-18) is lit, THEN perform Steps 14 through 16.
2) GO TO Step 17.
EXAMINER NOTE: Initially, SA cannot be blocked due to Ne
System pressure above the block set point. Soon after the Pzr
PORV is opened, the crew will return to Step 24. Step 17
checks for bleed and feed initiation criteria and then loops
back to Step 1.
Step 44 BOP Block SA as follows:
a. Verify "P-11 PZR S/I BLOCK PERMISSIVE" status light (1SI-18)
-LIT.
b.Depress the "BLOCK pushbuttons for the following signals:
ECCS steam pressure
ECCS Pzr pressure.
c.Verify the following status lights (ISI-13) - LIT:
Main Steam Isol
- Pzr low pressure §/I.
d. IF AT ANY TIME conditions degrade while in this procedure,
THEN manual SA actuaticn will be required.
NUREG-1021 Dzaft R c v i s i o n 3 29 of 31
ppendix D Operator Actions Form ES-D-
Bp-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor trip/turbine trip due to loss of condenser vacuum. CA pump 1B
failsto start. Turbine driven CA pump trips on mechanical overspeed. Loss of all auxiliary
feedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
-
resultino in NCS derxessurization using Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 15 RO Attempt to establish feed,flow from CM as follows:
a. Close MSlV on S/G(s)'not to be steamed.
EXAMINER NOTE: All four steam generators should be
steamed. However, if less than four steam generators were
aligned to receive feed flow in step l l . b , then only those steam
generators should be steamed.
R8 b. Verify the condenser is available as follows:
"C-9 60ND AVAILABLE FOR STM D U M P Status light (151-18)
- LIT,
Determines that "C-9" status light is DARK due to loss of
condenser vacuum and informs SRO.
SRO Transitions to Step 15.b. RNO and directs actions.
Step 15.b. 80 b. Perform the following:
RNO 1) Dump steam using S/G PORVs at maximum rate while
attempting to avoid a Main Steam Isolation.
80 dumps steam using the S/G PORV's
EXAMINER NOTE: If a Main Steam Isolation signal is rec bed,
the SIG PQRV's will revert to automatic and close. The RO will
have to select manual on the AUTQlMANUAL switch en IMC-3
to regain control. A feedwater isolation is expected to occur at
this point.
2) IF no S/G PORV can be operated from the control room,
THEN ...
Determines this step does not apply.
3) IF ne SIG PORV can be opened, THEN.. .
Determines this step does not apply.
4) GO TO Step 15.f.
SRO Transitions to step 15.f. N E R and directs actions.
NUREG-lC21 Draft Revision 9 30 of 31
\ppendix D Operator Actions Form ES-D-
Op-Test No.: NRC Scenario No.: 1 Event No.: 7-9
Event Description: Reactor trip/turbine trip due to loss of condenser vacuum. CA pump 1B
fails to start. Turbine driven CA pump trips on mechanical overspeed. boss of all auxiliary
feedwater results in loss of secondary heat sink. Auxiliary Pzr spray will not be available
-
resultina in NCS deoressurization usina Pzr PORV.
Time Position Applicant's Actions or Behavior
Step 15.f. RO f. WHEN S/G pressure is less than 505 PSIG, THEN stabilize S/G
pressure less than 505 PSIG.
g. Throttle open CF control valve or CF bypass control valve for
§ / G ( s )to be fed.
h. Verify feedwater flow to depressurized S/G(s) - INDICATING
FLOW.
SRO Returns to Step 7.c.2) and performs 7 x 2 ) through 7.c.4) as
previously directed by Step 7.c.2).b) RNO
Step 7.c.2) BOP IAD-5, F/3 "CAPT MECH OS TRIP" - BARK
Step 7.c.3) BOP "CAPT TRIP T N CTRL" - OPEN ~ ~~
Determines valve is closed - SRO.
......... ana ir.forms .....~ .___
~
SRO Trans:tionsio 7.c.3) RNO aiio directs actions.
Step 7.c.3) BOP 3) Perform the following:
RNO a) Manually open the valve.
CRITEAL b) IF the valve will not open. THEN ...
TASK Determines this step is N/A.
SRQ Transitions to Step 7.c.4) and directs actions.
Step 7.c.4) BOP 4) Verify the following valves - OPEN:
1SA-5 (SIG 1C SUITO CAPT)
Determines that all 4 S/Gs are receiving flaw from the CAPT.
'erminate scenario \n en feedwater flow is indicated to at least one steam
generator.
Classification: Site Area Emergency 4.4.S.2-2
NU REG-^^^^ D r a f t R e v i s i o n 3 31 of 31
FOR TRAINING PURPOSES ONLY
EMERGENCY NOTIFICATION FORM
THIS
SITE:
IS A DRILL
H ACTUAL EMERGENCY
Catawba Nuclear Station UNIT:
,@NlTlAL
f
nFOILOW-UP
REPORTED BY:
MESSAGE NUMBER 1
iANSMITrAL TIMEOATF: i CONFIRMATION PHONE NUMBER: (803j631-3807 (Simulator)
- - c _
iFasternl m dd VY
AUTHENTICAIION (If Required):
iNunberi (c'Ye*o"i!
GENERA EM
ermina ion - -(If 8 . go 10 item 16 j
7. EMERGENCY DESCRIPTIOWREMARKS: EAL # 4 . 4 3 2 The plant Operators have l05t the ability to establish Or
~
maintain the p[ant in hot shut down. This condition, by itself, poses no immediate threat to public safety.
8 PLANT CONUlTlON DIMPROVING ~uirT-~
9 REACTOR STATUS TIMEIDATE
ICaSlFml
- "rn Od
I
~ w
-
%POWER
10. EMERGENCY RELEASEW:
B O N E (Go to item 14.) a P O T E N T I A L , (Go to item 14.) E I S OCCURRING a H A S OCCURRED
-1 1. TYPE OF RELEASE: . DELEVATEII GROUND LEVEL 1'
aAiRBORNE: Staried:
TtmiFaslernI
- - - i
Dale
i Stopped:
TimIEBSlem:
-i -i - Oat*
&QUID: Statted:
TlmiEastmlI
-i - om
I
- Stopped:
Timr,FiSIemI
- -I - &!e
'"12 RELEASE MAGNITUDE n C U R l E S PER SEC OCURlES NORMAL OPERATING LIMITS O B E L O W DABOVE
PARTICULATES ~ O T U E R
7 3 . ESTIMATE OF PROJECTED OFFSITE DOSE: NEW UUNCIiANGED PROJECTION TIME:
(EaIirrn)
PEDE ; Thyroid CDE
mrem mreir ESTIMATED DURATION: HRS.
SITE BOUNDARY
2 MILES
5 MILES
10 MILES
"14. METEOROLOGICAL D A T A : m W I N D DIRECTION (from) B P E E D (n:ph)
STABILITY CLASS PRECIPITATION (type)
15.
NO RECOMMENDED PROTECTIVE ACTIONS
SHELTER IN-PLAC
16. APPROVED BY
- If ilenis 8-14 have not changed, only items 1-7 and 15-16 are required to be completed.
.~ lnfonmation may not be available on initial wtifications.
cnn T P O I M I M C DI tnwncrx nhii v
OP/l/B/6 100/0 IOC
PANEL: IAD-2 Page 6 of 68
AI4
SIETPOINT: -r 3°F
ORIGIN: T-REFIT-AUCT bistable in Kod Control circuit
PROBABLE
CAUSE:
AUTOMATIC
ACTIONS:
I.MhlI.:DIA'rI:
ACTIONS:
A/4
oP/lm/6ioolonOG
PANEL: 1AD-6 Page 8 of 92
AUGT HI T-AVG A/6
SETPOINT: > 588.1"F
ORIGIN: Auct. T-AVG:
.. 1NCRD5420 (NC h o p A Hot Leg Temp)
1NCRD5421 (NC Loop A Hot Leg Temp)
..
e INCRD5422 (NCLoop A Hot Leg Temp)
1NCRD5440 (NC Loop A Cold Leg Temp)
.. 1NCRD5460 (NC Loop B Hot Leg Temp)
iNCRD5461 (NC Loop B Hot LegTemp)
.. INCRD5462 (NC Loop B Hot Leg Temp)
lNCRD548O (NC Ibop B Cold Ixg Temp)
.. lNCKD5500 (NC Loop C Hot Leg Temp)
LNCRDS5Ol (NC Loop C Hot Lee, Terrip)
.. INCRL)5502 (NC Loop C: tInt Leg Temp)
fNCRLlS520 (NC Loop C Cold Leg Temp)
.. iNCRD5540 (KC I m p D Hot L.eegTemp)
I NCRDS51 I (NC Loop D Hot Leg Temp)
. INCRDS542 (NC h o p D Hot Izg lernp)
lNCRD5560 (NC l n o p D Cold I.eg Temp)
PROBABLE I. The reactor control system or steam dump system is rnainraining
CAUSE: T-AVG ar an improper level.
2 . Channel testing.
3. 1nsrnime.nt failure.
AUTOMATIC If a loop T-AVG fails high. control rods will step i n with control tod
ACTIONS: drive i n "ALITO".
IMMEDIATE I. E channel lailurc at power. place rcd con[roi sysrcm i n MANLJAI,"
ACTIONS: anti stabilize reactor coolant te.rnpciaturc atilizing remaining loops
T-AVG.
2. IF channei failure is indicated, defeat the aftected channel with the "A
T E M P DEFEAT' and "T-AVG DEFEAT" switches.
3. Following a load rejection. enswe steam dump operation.
CONTINUED ON miic N EX T PAGE
PANEL: IAD-6
AUCT 11T-AVG (COnt'd) AI6
SUPPLEMENTARY E a channel malfunction hac occurred. perform the following:
ACTIONS: Refer to TS Table 3.3.2- I for required number of channels.
,1..
L. Initiate a work request to have the channel repaired.
REFERENCFS: I. FSAR, Fig. 7.2.1-1 (9 of 16)
1
L. Westinghause Precautions, Limitations, and Setpoints for Nuclear
Steam Supply Systems CNM-1201.00-39
3. TS Table 3.3.2-1
4.
C E E - 0 173-03.03
5. IAE:Procedure WlWI3222177
6. NSM CN-198 15
OWliBl6 100/0 IOG
PANEL: 1AD-6 Page 22 of 92
LOOP T-AVG DEVIATION B/6
SETWINT: 1. Loop A: +2. -2.5"F
2. Loop B: +2. -3.S"F
3. Loop C: +2. -2.O"F
4. Loop D +2, -3.O"F
ORIGIN:
..
Individual loop T-AVG compared to Auctioneered Hi T-AVG:
lNCRD5420 (NC Eoop A Hot Leg Temp)
.. lNCRD5421, (NC b o p A Hot Leg Temp)
INCRD5422 (NC l n o p A Hot Leg Temp)
.. INCRDS440 (NC Coop A Cold Leg Temp)
INCRDS460 (NC h o p B Hot Leg Temp)
.. INCRD5461 (NC Loop B Hot I ~ e Temp)
lNCRD5462 (NC b o p B Hot Ireg Temp)
lNCRD5480 (NC Loop 13 Cold k g Temp)
g
..
- lNCRD5500 (NC h o p C Hot Leg Temp)
INCRDSSOI (NC Loop C Hot Leg Temp)
.. INCRD5502 (NC h o p C Hot Leg Temp!
INCRD5520 (NC h o p C Cold Leg Temp)
.. iNCRD5540 (NC Loop I) Hot L r g Temp)
INCRD5541 (NCTaop D Hot I r g Temp)
. INCRD5542 (NC Iuop D Hot L K Temp)
lNCRD5560 (NC b o p D Cold Le: Temp)
~
PRO n A R I ,E I. Reactor coolant pump trip.
CAIJSE: 2. T H or TC ins:rume.nt failurc.
3. Steam flow mismatch.
3. Feed flow mismatch.
AUTOMATIC I f a loop'l-AVG fails high. control rods will step ill.
ACTIONS:
IMMEDIATE I. Echannel failure at power. place rod coiiIro1 xysteiii i i i "1\1AK.:.IAl."
ACTIONS: . . and stabilize reactor cooiant temp utilizing r e m i n i r i g loops T-AVG.
2. Echannel failure is indicated by TtI. TC, &I', o r T-AVG indication,
defeat that channel with the "A TEMP DEFEAT" ;iiid "T-AVG
DEFEAT" hwirches.
CONTINUED O N THE NEXT P A G E
O W h 6 I oO/O 1W
PANEI,: SAD-6 Page 23 of 92
LOOP T-AVG DEVIATION (Cont'd) B/6
SUPPLEMENTARY 1. Check S t e m and feedwater flow indications for aid in determining
ACTIONS: the cause of deviation.
2. E instrument failure, refer to TS Table 3.3.1-1. and Table 3.3.2-1 for
required number of channels.
3. Dispatch an operator to IWM-8 on IRFMPI (Cable Spreading Room,
A-574) to identify affected loop(s) and to acknowledge the alaml.
4. \VWEh' desired to place control rods in "AUTO", perform the
following:
4.1 Ensure T-Avg is within I°F of T-Kef.
4.2 Place contrd rods in "AUTO".
KEFERENCES: 1. FSAR, Figure 7.2.1-1 (9 of 16) (Instnime.ntation and Control System
Diagrams)
2. Westinghousc Precautions, Linlitations and Sr!points for Nuclear
Steam Supply Systems CNM-1201.00-79
3. TS Table 3.3.1-1 and Table 3.3.2-1
4. CNEE-0173-03.11
5. L4E Procedure P/lIR/322U77
QP/l/B/6 100/01oG
wrZL PANEL: 1AD-6 Page 31 of 92
P e l d y
LOOP D/T DEVIATION C/6
SETPOINT: 5°F
ONGIIV: Individual loop D R compared to auct DR:
1NCRD5420 (NC Loop A Hot Leg Temp)
lNCRD542 1 (NC Loop A Hot Leg Temp)
-
- INCRD5422 (NC Loop A Hot Leg Temp)
0
1NCRD5440 (NC Loop A Cold Leg Temp)
lNCRD5460 (NC Loop B Bot Leg Temp)
lNCRDS461'(NC Loop B Hot Leg Temp)
- lNCRD5462 (NC Loop B Hot Leg.Temp)
lNCRDS480 (NC Loop B Cold Leg Temp)
INCRD5500 (NC Loop C Hot Leg Temp)
INCRD5501 (KC Loop C IIot Leg Temp)
0 1NCRD5502 (NC l ~ o Cp Hot Leg Temp)
lNCRD5520 (NC Loop C Cold Leg Temp)
lNCRD5540 (NC Loop D Hot Leg Temp)
1NCRD5541 (NC Loop D Hot Lzg Temp)
lNCRD5542 (NC Loop D Hot Leg Temp)
lNCRD5560 (NC Loop D Cold Leg Temp)
A.
PROBABLE 1. Reactor coolant pump trip.
CAUSE: 2. TH or TC instrument failure.
3. Steam flow mismatch.
4. Feed flow mismatch.
AUTOMATIC None
ACTIONS:
IMMEDIATE 1. channel failure at power, place rod control system in "M,ANUAI:'
ACTIONS: and stabilize reactor coolant temp u i i l i z h g remaining loop T-AVG.
2. -IF channel failure is indicated by TII. TC. DfI', or T-AVG indication.
defeat that channel with the "A TEMP DEFEAT" and the "T-AVG
DEFEAr" switch. -
CONTINtJED ON THE NEXT PAGE
OP//l~/6100/01oG
PANEL: 1AD-6 Page 38 of 92
LOOP IYT DEVIATION (Cont'd) C/6
SUPPLEMENTARY I. Check steam and feedwater flow indications for aid in determining
ACTIONS: the cause of the deviation.
2. E instmrnent failure indicated, refer to TS Table 3.3.1-1 and Tabie
3.3.2-1 for required number of channels.
3. Dispatch an operator to LRFM-9 on lRFMPl (Cable Spreading Room.
AB-544) to identify affected loop(s) and to acknowledge the alarm.
4. WHEN desired to place control rods in "AUTO", perform the
following:
4.1 Ensure T-Avg is within 1°F of T-Ref.
4.2 Place control rods in "A.UTO"..
REFERENCFS : 1. FSAR, Figure 7.2.1-1 (9 of 16) (Instrumentation and Control System
Diagrams)
2. Westinghouse Precautions, Limitations, and Setpoints for Nuclear
Steam Supply Systems CNM-1201.00-39
3. TS Table 3.3.1-1 andTable 3.3.2-1
4. CNEE-0173-03.1 I
5. CNEE-0133-03.12
6. IAE Procedure IF'/llg/3222/60
,:
OP/l/B/6 100/0iOc
PANEL: 1AD-2 Page 12 of 68
CONTROL ROD BANK LO LIMIT
SETPOINT: Variable calcu1ate.d based on auctioneered high DR.
ORIGIN: Rod insertion limit computer.
PROBABLE 1. Boron concentration too low for power andor Xenon conditions.
CAUSE: 2. Rod inkrtion limit computer.or instrument malfunction.
3. Major load rejection or transient.
AUTOMATIC None
ACTIONS:
IMMEDIATE I. Stop any dilution i n progress.
ACTIONS: 2. Ue1erniiiic d k c t c d control tranh(s) b y xiwi!q 10 IKFM 1 6 i n
Cable Spreading Room ( A U X 577) and ;ickno~vledgethe ularm.
SUPPLEklENTAKY I. Rcrnre coo1;inr systcni LIS necessary uiiril a l x m cleurs per
ACTIONS: OP/ 1 /A/6 I 5 O/OO!> (I3oron (.:once n lr;u i o 11 Co R t ro I1.
- I : tmipcrarure instrunienr iiialf'uiiciion. &fear aff'ec~ed
11.
instruincnt using "T-AVG D E F E A T and "ATEMP DEFEAT"
switch.
3. Refer I O 13 -3, I .6 (Control 13anh Iiiscrtiw Liiiiirs).
4. -I F d u t io instruiiicnl failure. h v e l;\E t r i p I)isi;hlc. on ;!l'l;.ctcd
clianntl pcr Tech Spec Action.
IIEI'EREX'CES: I . TS 3 . I . I (Sliutdow1 hI:ir$ii ( S U X l I ;itill
7s ? . I .(I iCiiurrol B m h lnwrkioii I - i i i r i t t i
_.
7 FSAR. 1'iFui.c. 7-2. ( I k t 9 of I O )
PANEL: 1AD-2
CONTROL ROD BANK LO-110 LIMIT B/9
SETPOINT: Variable. calculated based on auctioneered high D R .
ORIGIN: Rod inscnion limit computer.
PROBABLE 1. Boron concentration too [ow for power and/or Xenon conditions.
CAUSE: 2. Reactor Shutdown.
3. Rod insertion limit computer or instrument malfunction.
4. Major load rejection or transient.
AUTOMATIC Nonc
ACTIONS: '
IMMEDIATI< I
ACTIQNS: 2.
3.
SbPI'Lk<JlL!\ I A K Y I
ACTIONS: 2.
REFERENCES: I