ML033510567

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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

Step 2.15

Step 2.2

Step 2.3

Step 2.4

Step 2.5

Step 2.6

Step 2.7

Position

SR8/

Applicant's Actions or Behavior

Examiner Note: If the dispatcher is contacted for guidance, the

response will be increase at 20%/hr.

Per OP/l/A/6100/003. Enclosure 4.1: Maintain control rods above

insertion limit and AFD within its target by boration or dilution per

OP/1/A/6150/009.

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.

Refer to OP/1/AJ6150/009

(Boron Concentration Control) Enclosure

1.3 (Dilution).

Ensure the following valve control switches in "AUTO:

1 NV-242A (RMWST To B/A Blender Ctrl)

INV-181A (WA Blender Otlt To VCT)

9djust the total makeup batch counter to the desired volume of

reactor makeup water to be added.

?lace the "NC MAKEUP MODE SELECT switch to the "DILUTE"

aosition.

Rdjjldst the controller for INV-242A (RMWST To B/A Blender Ctrl) tc

he desired flow.

Ensure INV-2428 (RMWST To BiA Blender Ctrl) controller in

'AUTO".

Ensure at least one reactor makeup water pump is in "AUTO" or

ON".

NUREG- 1021 Drsft Revision 3

3 of 4 3

Event Description: Dilution for power increase

Time

-

.. ~

Step 2.8

Step 2.9

Step 2. I O

Step 2.1 1

Step 2.12

Position

Applicant's Actions or Behavior

NOTE: If necessary, dilution can be manually secured at any time

~y placing the "NC MAKEUP CONTROL switch to the "STOP"

Dosition.

Place the "NC MAKEUP CONTROL" switch in the "START"

Dosition.

Verify the following valves open:

1 NV-242A (RMWST To $/A Blender Ctrl)

INV-181A (B/A Blender Otlt To VCT)

If in "AUTO, verify the reactor makeup water pump starts.

iNken the desired volume of reactor makeup water is reached on

he total makeup batch counter, ensure the following valves close

1 NV-242A (RMWST To B/A Blender Ctrl)

INV-I81A (B/A Blender 0th To VCT)

If automatic makeup is desired, refer to Enelosure 4.1 (Automatic

Makeup).

.. .

~~...

KCREG-1021 Craft Revision 9 4 of 4 3

Appendix B

Operator Actions

Form ES-B-2

Step 2.3

..

.......

....

..-

...

.~.

SROIRO

Op-Test No.: NRC Scenario No.: 3

Event No.: 2

Event Description: Turbine load increase

Step 2.2.4

Time I Positicn

- ............ -

I

SRo

Step 2.2.6

ALL

I

Ro

. -

I

i

Step 2.2.1

Step 2.2.2 '

80

I

Ro

Step 2.2.3

Step 2.2.5 i

I

Applicant's Actions or Behavior

Directs 80 to increase load at a rate of 2 to 4 MW/rnin or 10% to

20% per hour.

Per 0P/I/A/6100/003, Enclosure 4.1: Coordinate with SOC to

increase turbine load per OP/l/B/6300/001.

......

....

-

~..

. .-

Refer to 8P/I/B/6300/001, Turbine Generator, Enclosure 4.2,

Section 2.4.

....

.

.....

.......

Direct RO to increase load at a rate of approximately 2-4 MWlmin

or 10%-20% per hour to 100% (target).

- ....

.....

.......

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.

.....

......

. . .

.....

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.

......

...

....

To start load increase, depress the "Go" pushbutton and verify it

illuminates.

....

.....

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%.

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.

airects RO to close ISV-7 (S/G I C PQRV)

4ttempts to close PORV by:

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 SI6 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.

NUREG- 1021 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 1 C POWV (1 SV-7) fails open.

Time

Step I

Step 2

Step 3

Position

KO

Applicant's Actions or Behavior

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 1 I

of 42 to continue

scenario.

EXAMINER NOTE: The following actions are provided in case

the SRO enters AP/l/A15500/28 (Secondary Steam Leak).

Implements AP/I/A/5500/28 (Secondary Steam Leak) and directs

actions.

Monitor Enclosure 1 (Foldout Page)

Verify turbine - ONLINE

Verify the following:

Reactor power - LESS THAN OR EQUAL TO 100%

POWER.

T-avg -WITHIN 1.5T 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.

NUREG- 1021 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

Step 4

Step 5

Step 6

Step 7

Step 8

Step 9

Position

RQ

ALL

ALL

ALL

Applicant's Actions or Behavior

Verify proper reactor response as follows:

Control rods - IN "AUTO" AND STEPPING IN

PA3 neutron flux - DECREASING.

IF AT ANY TIME reactor power is greater than loo%, THEN

perform Step 3 RNO.

Verify Pnr level - STABLE OR INCREASING.

IF AT ANY TIME Pzr level is decreasing in an uncontrolled manner,

THEN RETURN TO Step 6.

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.

.. .

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.

NUKEG- 1021 Draft Revisior. 9 8 of 43

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

I

Step 9.c

I

RNO

Step 9

80

Auulicant's Actions or Behavior

c. Verify SIG PORVs -CLOSED.

Informs SRO that I C SIG P O W (ISV-7) is NOT

CLOSE 5.

Transitions to Step 9.c RNO and directs actions

c. E

SIG pressure is less than 1090 PSIG, =perform

the following:

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.

Informs SRO that I C SIG POWV isolation valve (ISB-26B) is

closed.

Transitions to Step 9.d NER column

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 Draft. 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

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

Determine long term plant status. RETURN

procedure and

step in effect.

NUREG-1621 Draft % 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

Step 1

RNO

Position

BQP

Applicants Actions or Behavior

Recognizes Pressurizer Level Channel I has failed LQW and

nforms SRO.

IAD-6: D/9 (PZR LO LEVEL HTR OFF 8 LETDOWN

SECURED annunciator

IAB-6, N10 (PZR HTR CONTROLLER TROUBLE)

annunciator

Pressurizer level channel I 1 NCP5164 off scale - LOW

0

EXAMINER NOTE: Annunciator response is attached.

qesponds to event using the annunciator response. Selects

hannel Ill to control pressurizer level.

a

IAB-6 E19 (PZR LO LEVEL DEVIATION) annunciator

3ecognizes that letdown has been lost due to this failure and

nforms SRQ.

rnplements AP/I/N5500/12 (Loss of Charging or Letdown) Case II

Loss of Letdown) and directs actions.

derify all Pzr level channels - INDICATING THE SAME.

Determines that channel I has failed low and informs SRO

rransitions to Step 1 RNO and directs actions

F the controlling channel is failed low,

X R L SELECT switch in any alternate operable position.

place PZR LEVEL

rransitions back to Step 2 NER column m d directs actions.

NUREG- 1021 Draft Revision 9

I1 of 43

Op-Test No.: NRC Scenario No.: 3

Event No.: 4

Event Description: Pressurizer Level Channel I fails LQW

Step 4

Step 5

1 Step?

1

Applicant's Actions or Behavior

INV-1OA (Letdn Orif 1B 0th Cont isol)

INV-11A (Letdn Orif I C Otlt Cont Isol)

a 1 NV-13A (Letdn Orif 1A Qilt Cont Isol)

Verify PZU level - GREATER THAN 17%.

Takes manual control of INV-294 and reduces charging flow.

Ensure "PZU HEATER GROUP IC" -ON.

I

Control VCT IeVel as follows:

a. Verify VCT makeup - SET FOR DESIRED BORON

b. Verify VCT makeup - IN AUTOMATIC.

CONCENTRATION

Determine and correct cause of loss of letdown.

channel.

NUREG-1021 Draft Revisioi: 9 12 of 43

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 Revision 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

Step 11

Position

ADDkant'S Actions or Behavior

Evaluate normal letdown restoration as follows:

a. Verify at least one of the following valves - CLOSED:

INV-qA (NC Letdn To Regen Hx Isol)

1 NVQA (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

Step 2.1.1

Step 2.1.2

Step 2.4.3

Step 2.1.4

Step 2.1.5

Position

Atmlicant's Actions or Behavior

Determine that normal letdown is currently not available due to 1 NV-2A

closed and directs excess letdown to be placed in service.

REFERS TO OP/1/A16200/001 (Chemical and Volume Control System)

Enclosure 4.12 (EstablishinglSecuring Excess Letdown) and directs

operators.

Notify Primary Chemistry of the following:

.......

Excess Letdown will be placed in service

VCT pressure will be reduced to - 20 Dsia

CAUTION: At least 15 psig backpressure shall be maintained on the

NCP # I seals

Reduce VCT pressure to - 20 psig per Enclosure 4.22 (Adjusting the

Volume Control Tank (VCT) Hydrogen Pressure)

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)

.......

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.

-

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

1 NVP5500 (VCT Vent Press)

VCT level greater than or equal to 50% as indicated on 1NVP5761

(VCT Level)

NUREG-1021 Draft Revision 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

Step 2.1 .f

QPII 2

Step 12

Position

~

Applicants Actions or Behavior

~~~~~

....

Open the following valves:

e

1 NV-422B (Loop C To Exs Letdn Hx Isol)

1 NV-1238 (LOOP C TO EXS betdn HX Iso~)

Determines that 1 NV-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.

Continues with APll2 at S t e ~

12

Establish letdown as follows:

a. Verify ability to establish normal letdown - RESTORED

b. Ensure 1 NV-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)

e. Adjust the following valves as required in subsequent steps:

1 NV-148 (betdn Press Control) to maintain letdown

pressure at 350 PSI6

1 NV-294 (NV P M ~ S

A&B Disch Flow Ctrl) to maintain

letdown subcoooled.

INV-10A (betdn Orif 18 Qtlt Isol).

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.

W R E G - 1 0 2 1 D r i i f :

Rcvjsion 9

16 of 43

Wendix

..

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

Step 12.h.

?NO

Position

.~

SRQ

~.

--..

..~~~.. ...

.~

Applicant's Actions or Behavior

Transitions to SteD 12.h. RNO and directs actions.

1. Perform the following:

1) IF 1 NV-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 1 D feedwater regulating valve) fails closed with

manual control available.

Time

Position

80

AoDlicant's Actions or Behavior

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.

Determines that ICF-55 (ID 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.

Directs RO to take manual control of ICF-55 and open the valve.

Piaces manuallauto siaiion for ICF-55 in MANUAL and opens

valve.

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: 1 D Steam Generator Tube Leak (60 gpm)

Step 1

step 2

Position

ALL

ALL

ROI BOP

sa0

Applicant's Actions or Behavior

Recognize symptoms of a Steam Generator Tube Leak:

Charging flow increasing

EMF 33. 72, 74, 29, 31 alarm

Verifies Blowdown automatic actions occur:

1 BB-69, 73, 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.

Implements AP/l/A/5500/10 (Reactor Coolant Leak) Case I, Steam

Generatcr Tube Leak. and directs actions.

Monitor Enclosure 1 (Foldout Page)

Verify Pzr level - STABLE OR INCREASING.

Determines Pzr level is decreasing and informs SRO

Transitions to Step 2 !?NO and directs actions.

NUREG-1021 Draft Revision 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

Step 2

RNO

Step 3

Step 4

Step 5

Position

ALL

ALL

Applicant's Actions or Behavior

Perform the following:

a. Maintain charging flow less than 180 GPM.

b. Manually throttle 1 NV-234 (NV Pmps A&B Disch Flaw Ctrl) to

stabilize Pzr level.

c. E Pzr level is stable

Determines Pzr level is stable or increasing and informs SRO

increasing, THEN GO TO Step 3.

Transitions to Step 3 NEB.

IF AT ANY TIME the SIG tube leak increases, THEN perform Step

2.

Verify Pzr pressure - TRENDING TO OF? STABLE AT 2235 PSIG.

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

~pendix D

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 (SI6 A Leakage)

1EMF-92 (SIG E Leakage)

IEMF-73 (SIG C Leakage)

IEMF-74 (SIG B Leakage).

0

e

Monitor OAC NV Graphic

0

Initiate OAC Program "NSNCLEAK'

Compare charging flow and letdown flow

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 D r a f t 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: 1 B Steam Generator Tube Leak (60 gpm)

Time

step 7

tep 8

Position

Applicant's Actions or Behavior

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/G

B 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) -

IEMF-26 (Steamline la)

e

1 EMF-27 (Steamline 1 B)

1 EMF-28 (Steamline IC)

1 EMF-29 (Steamline 1 D).

d. Verify CF flow - LOWER TO ANY S/G AS COMPARED TO

e. Notify Secondary Chemistry to determine leaking SiG by

INCREASING QR IN ALARM:

OTHERS.

sampling.

Determines that 1 EMF-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.

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 Revision 9 22 of 43

ippenclix D

Operator Actions

Form ES-D-2

Op-Test No.: NRC Scenario No.: 3

Event No.: 7

Event Description: 1 D Steam Generator Tube Leak (60 gpm)

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.

Transitions to Step 2 RNO and directs actions.

I

/

NUKEG- 1021 Draft Revision 9

2 3 of 43

_I-

ppendix I

Operator Actions

Form ES-D-2

3p-Test No.: NRC Scenario No.: 3

Event No.: 7

vent Description: 1 D Steam Generator Tube Leak (60 gpm)

Time

step 2

?NO

Step 2.2)

?NO

Step 2.3)

RNO

Position

Applicant's Actions or Behavior

Perform the following:

a. Maintain charging flow less than 180 GPM.

b. Manually throttle 1 NV-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

b) IF 1 NV-13A (betdn Orif 1A Otlt Cont Isol) is open,

maintain letdown pressure at 350 PSIG.

Determines that I

NV-13A is not open and that step does not apply.

c) IF INV-1OA (Letdn Orif 1B Otlt Cont Isol)is open,

THEN throttle 1 NV-849 (Letdn Flow Var Orif Ctrl) until

letdown flow is 45 GPM.

dl WHEN letdown Dressure is stable at 350 PSIG. THEN

' place 1 NV-148 (Letdn Press Control) in "AUTO".

2) IF Pzr level continues to decrease. THEN ensure the

following valves closed:

0

1 NV-2 OA (Letdn Orif 1 B Otlt Cont Isol)

INV-IIA (Letdn Orif I C Otlt Cont Isol)

INV-13A (Letdn Orif 4A Otlt Cont Isol).

Closes valves and informs SRO

3) IF Pzr level is stable OR increasing, THEN GO TO

Steo 3.

Determines that PZR level is decreasing and informs SRO.

NUREG-1021 Craft Revision 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

Step

Z.d.4)

RNO

Position

ALL

Applicant's Actions or Behavior

4) E

Pzr level continues to decrease, THEN:

a) Start an additional NV pump as follows:

(1)

(2)

(4)

(5)

Open 1 NV-2528 (NV Pumps Suct From FWST)

Open INV-2535 (NV Pumps Suct From FWST)

Close INV-1898 (VCT Otlt Isol)

Start the desired NV Pump.

(3)

Close INV-188A (VCT Otlt Iso~)

Positions valves aoororxiatelv and starts 1A NV Pumo.

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)

OR .

OPI/N6100/003 (Controlling Procedure for Unit

Operation

c)

Pzr level is stable

increasing THEN GO TO

Determines that Pzr level is continuing to decrease and continues

,n RNO.

Step 3.

d)

Pzr level continues to decrease

Pzr level cannot

be maintained greater than 1 I%, m:

(1) Manually trip reactor

(2) Manually initiate SA

(3) GO TO EP/l/N500O/E-O (Reactor Trip Or Safety

Injection).

Directs RO to trip the reactor and the BOP to manually initiate SA.

NUREG- 1021 Draft Revision 9

25 of 43

Appendix I

Operator Actions

Form ES-D-2

Op-Test No.: NRC Scenario No. 3

Event No. 7a-9

Event Description: 1 D Steam Generator Tube Rupture (345 gpm) coincident with failure of

automatic turbine triD and failure of 1B CA Pump to automatically start.

Time

Step 1

Step 2

step 3

?NO

step 4

3ep 5

step 6

Position

ALL

Applicant's Actions or Behavior

Enters EP/l/N5000/E-0 (Reactor Trip Or Safety Injection) and

directs operators

Monitor Enclosure 1 (Foldout Page)

EXAMlNER NOTE: Steps 2 through 5 are Immediate Action

steps and must be performed from memory.

Verify Reactor Trip:

All rod bottom lights - LIT

All reactor trip and bypass breakers - OPEN

I/R amps - DECREASING

Verify Turbine Trip:

Determines that the turbine is not tripped and manually trips the

turbine. Informs the SRO of this when the step is read aloud.

Transitions to Step 3 RNO and directs actions.

All turbine stop valves - CLOSED

a.

Manually trip the turbine

Depresses the manual trip pushbutton and verifies that all turbine

stop valves are closed and informs SRO.

Transitions to Step 4. NER and directs actions.

Verify IETA and IETB - ENERGIZED.

Verify SA is actuated:

a.

"SAFETY iNJECTlON ACTUATED" status light (ISI-13)

- LIP

b.

EIS load sequencer actuated status lights (151-24) -LIT

Announce "Unit 1 Safetv Iniection"

NUXIEG-102.1

Draft 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

automatic

Time

Step 9

Step 8

Step 9

Step I O

step 11 .a

Step 11 .a

3N0

ition: 1D Steam Generator Tube RuDture (345 aDm) coincident with failure of

aine trip ai

Position

ALL

-.

I

I failure of I

B CA Pump to automatically start.

Applicant's Actions or Behavior

implement RP/O/A/5000/01 (Classification Of Emergency).

Verify all Feedwater Isolation status lights (ISI-5) - LIT

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: 1 KC-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.

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.

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

Transitions to Step 11 .a RNO and directs actions.

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

27 of 43

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

Step 7 1.b

Step 12

Step 14

Step '15

Step 16

Step 17

Position

Applicant's Actions or Behavior

Transitions to Steo 11 .b NER and directs actions.

b. 3 S/G N/R levels - GREATER THAN 11 %

Verify all of the following S/l pumps -ON:

NVpumps

NDpumps

NI pumps

Verify all KC pumps - ON.

Verify all Unit 1 and Unit 2 RN pumps - ON

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)

Verify all S/G pressures - GREATER THAN 775 PSIG

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.

Transitions to Steo 17.b RNQ and directs actions

KCKEG-1021 I?raft Kevision 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

Step 17.b

?NO

I

Step 18

step 19

Step 20

I

AppliCant'S Actions or Behavior

b. Perform the following:

1) Ensure ND pump miniflow valve on operating ND pump(s) -

OPEN.

2) E

the 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.

Transition to step 18 NEB and directs actions.

Control SIG levels as follows:

a. Verify total CA flow - GREATER THAN 450 GPM

b.

ACC),

between 11% (29% ACC) and 50%.

at least one SIG N/R level is greater than 11% (29%

throttle feed flow to maintain all SIG N/R levels

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

Manually align equipment.

Transitions to Step 21 NER 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

Step 21

Step 22

Step 23

Step 24

Position

Aealicant's Actions or Behavior

Zontrol NC temperature. REFER TO Enclosure 4 (NC

Temperature Control).

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.

&.fify NC subeoeling based on core exit TlCs - GREATER THAN

0°F.

Verify main steamlines are intact as follows:

All S16 pressures - STABLE OR INCREASING

All SlGs - PRESSURIZED.

NUREG-1021 Draft Revision 9 30 of 4 3

ppenciix u

Operator Actions

Form ES-D-2

3p-Test No.: NRC Scenario No. 3

Event No. 7a-9

Event Description: 1 D Steam Generator Tube Rupture (345 gpm) coincident with failure of

automatic turbine trio and failure of 1B CA Pump to automatically start.

Time

Step 25

Step 1

Position

RO/BOP

RO/BOP

Applicant's Actions or Behavior

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 IA)

1 EMF-27 (Steamline 16)

IEMF-28 (Steamline IC)

I

EMF-29 (Steamline 1 D)

m

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

Transitions to Step 25 RNO and directs actions.

E any EMF trip 1 light is lit

mcontrolled manner, T#EN concurrently:

any S/G level is increasing in an

Implements EP/4/A/5000/F-O (Critical Safety Function Status

Trees)

GO TO EP/f/A/5000/E-3 (Steam Generator Tube Rupture).

Transitions to EP/I/A/5000/-3 and directs actions.

Monitor Enclosure 1 (Foldout Page)

NUREG-LO21 Draft 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

automatic tuibine trip ar

Event Descrintian: I D Steam Generator Tube Rupture (345 gpm) coincident with failure of

failure of 7 B CA Pump to automatically start.

Time

step 2

Step 3

Position

RO/BOP

Applicants Actions or Behavior

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

1 EMF27 (Steamline 18)

.

IEMF-28 (Steamline IC)

.

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 I

lights

and ask for Chemistrv confirmatow samales.

Jerify at least one intact Si6 -AVAILABLE FOR NC SYSTEM

SOOLDOWN.

N3REG-1021 Drafr: Revisior: 9 32 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 (345 gpm) coincident with failure of

3utomatic turbine trip and failure of 1B CA Pump to automatically start.

Time

Step 4

Step 4.c

Step 5

Position

Applicant's Actions or Behavior

Isolate steam flow from ruptured S/Gs as follows:

a. Verify all ruptured S/Gs PORV - CLOSED

b. Verify S/G(s) 1 B and 1 C - INTACT

c. Isolate blowdown and steam drain on all ruptured S/G(s) as

follows:

Determines this step is N/A for SlGs la, 1 By and IC.

e SIGID

1) Close 1SM-74B (SIG I D Otlt Hdr Bldwn C N )

2) Verify the following blowdown isolation valves -CLOSED:

a) 1 BB-8A (SIG I D Bldwn Cont Is01 Insd)

b) 1 BB-1478 (SIG 1 B Bldwn Cont Is01 Byp)

c) IBB-105 (S/G I D Bldwn Cont Is01 Otsd)

Close the following valves on all ruptured S/G(s):

MSlV

e MSlV Bypass valve

Closes MSIV and verifies MSlV Bypass valve closed on 1 D S/G

NUREG- 1021 Draft. R e v i s i o n 3

33 of 43

Event Description: 1 D Steam Generator Tube Rupture (345 gpm) coincident with failure of

Step 6

Step 7

ROIBOP

BOPlRO

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 , 1 B, and I C

0

S/G ID:

1) Close ICA-42B (CA Pmp A Disch To SIG I D Isol)

2) Close ICA-48A (CA Pmp 1 Disch To SI6 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.

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

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 43

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

Step 9

Step 9.a.

RNO

Step 9.b.

Step 10

Step 11

Step 12

Position

Applicants Actions or Behavior

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.

a~ Perform the following:

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.

Transitions to Step 9.b. NER and directs actions

b. Throttle feed flow to maintain all intact S/G NIR levels between

11% (29% ACC) and 50%.

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.

PhaseA

Phase0

Ensure the following containment isolation signals - RESET:

Establish VI to containment as follows:

a. Ensures IVI-77B (VI Cont Isol) - OPEN

b. Verify VI pressure -GREATER THAN 85 PSIG

NUREG- 1021 Draft. Revision 9

35 of 43

ppendix D

Operator Actions

Form ES-D-2

Bp-Test Ne.: NRC Scenario No. 3

Event No. 7a-9

Event Des1

automatic i

Time

Step 13

Step 14

Step 15

Step 16

3eo 17

>tion: I D Steam Generator Tube Rupture (345 aom) coincident with failure of

bine trip a

Position

80

RQ

-.

I

failure of IB CA Pump io autbmaticaily start.

Applicant's Actions or Behavior

Verify all AC busses are energized by offsite power as follows:

ATrain:

$ETA - ENERGIZED

"FTA BIO NORM FBR FRM ATC" - CLOSED

"DIG 1A BKR TO ETA -OPEN

B Train:

e

IETB - ENERGiZED.

"FTB BIO NORM FDR FRM ATD - CLOSED

"DIG 1 B BKR TO ETB" - OPEN

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.

Verify ruptured SlG(s) - IDENTIFED.

Determines I D SIG is the ruptured SIG.

Verify the following valves on all ruptured SIGs -CLOSED:

MSlV

MSlV bypass valves

Ensures dosed for1 D S16.

Verifv at least one NC oumo - ON.

NiJkEG-1021 Dra:::

Revision 9

36 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 (345 gpm) coincident with failure of

automatic turbine trip and failure of 1 El CA Pump to automatically start.

Time

Step I 8

Position

ALL

Applicant's Actions or Behavior

"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.

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.

NUREG- 1021 ?raft !Ievisior:

9

37 of 43

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

bine trip and failure of 1B CA Pump to automatically start.

automatic

Time

Step 19

3ep 19.e

?NO

Position

86

Applicant's Actions or Behavior

EXAMINER NOTE: COQldQWn and depressurization to

minimize break flow is a CRITICAL TASK. These are noted in

the guide.

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,

c. Verify the condenser is available as follows:

the crew should CQQldQWn the NCS to < 520 O F .

"C-9 COND AVAILABLE FOR STM DUMP" status light (ISI-

18) - LIT

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.

MSlV on intact S/G(s) - OPEN

Transition to Step 19.e RNO and directs actions.

place steam dumps in pressure mode as follows:

1) Place "STM DUMP CTRL" in manual

2) Manually adjust the "STM DUMP CTRL 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.

rransition to Step 19.f NER column and direct actions.

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 43

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

XITICAL

TASK

Step 19.g

?NO

Step 19

Step 20

Position

SRB

Applicant's Actions or Behavior

f.

Dump steam to condenser from intact S/G(s) at maximum rate

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.

Transitions to Step 'i9.g RNO and directs actions

g. IF pressure in S/Gs used for cooldown is approaching 800 PSIG,

1) Depressurize NC System to less that 1955 PSIG using one

of the following:

Pzrspray

THEN:

PnrPQRV.

2) Maintain NC pressure less than 1955 PSIG.

EXAMINER NOTE: This steD mav not be used.

Transitions to SteD 19.h A/ER and directs actions.

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.

Depresses Main Steam pressure "Block pushbuttons and

maintains NC pressure 4955 psig.

EXAMINER NOTE: Sometime during the depressurization, the

status lights from Step 18 will light. At that point this step will

be Derformed.

Verify NC System cooldown in Step 19 - COMPLETED

NUREG-1021 Draft Revision 9 39 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.

Verify NC subcooling based on core exit T/Cs - GREATER THAN

Ro

I 20°F.

Step 22 I

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

CRITICAL

TASK

Step 24

Depressurize NC System using PZR Spray as follows:

a. Verify normal Pzr spray flow - AVAILABLE.

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

e. Verify Pzr level - LESS THAN 76% (73% ACC)

f. Verify NC pressure - LESS THAN RUPTURED S/G(s)

g. Verify Pzr level - GREATER THAN 11% (20% ACC)

0" F.

PRESSURE.

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 NER and

use Pzs PORVs instead.

h. Close the following valve@):

1) Pzr spray valves

2)

i. Observe Caution prior to step 26 and GO TO Step 26.

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)

1 NV-37A (NV Supply To Pzr Aux Spray)

NUREG-1021 Draft Revision 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

Step 24

(cont .)

Step 25

Step 26

Step 27

Step 28

Position

RQ

~

Applicant's Actions or Behavior

f. Verify NC pressure - LESS THAN RUPTURED S/G(s)

PRESSURE.

h. Verify Pzr level - GREATER THAN 11% (20% ACC)

i.

Close Pzr PORV.

j. Close Pzr spray valve(s).

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)

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 1 I%

(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).

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

Verify VI pressure - GREATER THAN 50 PSIG.

NUREG-1021 Draft Revision 9 42 of 43

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:

1 NV-252A (NV Pumps Suct From FWST)

1NV-253B (NV Pumps Suct From FWST)

b. Verify the following valves - OPEN

1 NV-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

Stetl29.b RNO to ouen them.

I

Step ~ 9 , ~ . BOP

c. Close the following valves:

0

1 NI-98 (NV Pmp CIL Inj [sol)

1 0

INI-IOB

(NV Pmp CIL irrj ISOI).

Terminate scenario when 1NMA and INI-1OB are closed.

Classification: Site Area Emergency 4.1.S.3

NUREG- 1021 Draft Revision 9 43 of 43

u

FOR TRAINING PURPOSES ONLY

.h

EMERGENCY NQTlFlCATlON FORM

I .a^

ACTUAL EMERGENCY

oFOLLOW-UP

MESSAGE NUMBER

1

UNIT

1

REPORTED BY

I

CONFIRMATION PHONE NUMBER

(803) 831-3807 (Smulalor)

!J?

I a T H I S IS A DRILL

2

SITE

Catawba Nuclear Site

3

MNSMIlTAL TIMWATE

~

-

(EaShlm)

mm

M

w

4

AUTHENTICATION (If Requrred)

15

EMERGENCY CLASSiFlCATiON

(Numm>

(codaworn)

6.

7.

8.

9.

10

UNUSUAL EVENT

(It 8. go to Item 18.)

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.

%POWER

PLANT CONDITION:

REaCTOR STATUS:

HUTDOWN

TIMUBATE:

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.)

r

,

- I 1. TYPE OF RELEASE: BLEVATED

U

D

LEVEL

I

i

stopped:

I

~~~

~

-

w:

Started:

T(me(Ear!am)

Dele

Time~EasIern:

Cafe

JLlQUiD

Started

I

stopped

I

- - -

~

-

Trme(tasltem)

D*'B

T,me(Ea*,am)

Dale

- E RELEASE MAGNITUDE

CURIES PER SEC DURIES

NORMAL OPERATING LIMITS OBELOW

OAEOV

NOBLE GASES

~ I O D I N E S

OPARTICUMTES

OTHER

'"13. ESTIMAE OF PROJECTED OFFSITE DOSE: D N E W

DCHANGED

TEDE

mrem

Thyroid CBE

mrem

PROJECTION TIME:

(Easlm]

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

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

PANEL: 1AD-6

PZR HTR CONTROLLER TROUBLE

0P/~~/6locsl0ioC-;

Page 13 of 92

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

ACTIONS:

returned to ON".

I .

2.

3.

Monitor a:id ni3nually control PZR press tiiitil Grout IC can he

C heaters secured due to a Pzr low level, ntanually reset breaker by

depressing "ON" for "PLR FITR GROUP C" when the low level clears.

Refer to TS 3.4.9 for Pzr Htr operahiiity requirements.

REFERENCES:

1.

PZR Heaters Electrical System Description (LE)

2.

3. TS 3.4.9

CNEE-OI 11-01.74 (ELementary Diagram 600V Idad Center ILXC

Alarm Circuirs)

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:

0

INCLT5160 (Pressurizer Level Ch. 1)

1NCLT5150 (Pressurizer Level Ch. 2)

1NCLT5170 (Pressurizer Level Ch. 3)

PROBABLE

CAUSE:

NOTE:

_I

__

--

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.

I.-__--__

._ll.---l_

I .

2. Leakage.

3. Load transient.

4. tnstrurnent malfunction.

Charging arrd'or letdown flow mismatch

THE RFSPONSE FOR THIS ALARM IS LISTED rN

AP/l/Ai5500112 (LOSS OF CHARGING O R LETDOWN)

Panel {AD-4

OP/~/B/6100/010E

Page 23 of S?

S/G D FLOW MISMA'ICH LO CF FLOW

SETPOINT:

Stm flow j CF flow by .75 x IO6 l b s k

Cl4

1 NOTE:

This setpoint corresponds to StIR flow > CF flow by 20% on meters on 1MC2.

I

ORIGIN:

S/G ID 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:

~~

-~

- __ -

r

NOTI;:

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 ir is an instrument fai!ure.

IMMEDIATE

1 .

ACTIONS:

2.

SUPP1,EMEN'TARY

1.

ACTIONS:

0

L.

REFERENCES:

I .

2.

3.

4.

Compare all flow indication to verify condition.

-

IF automatic controls are

WHEN malfunc.tion is coriected QIJ

bypassed, restore control

to

automatic.

Refer to Tech Specs for operable channel requirenients

(TS 3.3.1, 3.3.2, 3.3.3 and 3~3.4).

FSAR, Figure 7.2.1-1 (7 of 16)

CNEE-0143-03.02

NSM CN-10793

correcting, take rnaniial control.

3: L, P & s

Appendlx I?

I n i t i a l Dynamic Sirnul-ator S c e n a r i o

Forir, 5s-D-1

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 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

N S pump 1A is out of service for motor replacement. It is due to be returned to

i ;

I Simulation Facility: CatdWbr

Scenario No.: NRC-2,

Op-Test No:

Operators:

.

Examiners:

.~..

(N: o r a a l ,

( R ) eactivit.y,

(I>nstrurnent,

( C ) omponent,

(M) a j or

Page 1 of 3 4

Draft Revision 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

No.

4

5

6

7

8

9

10 -

Malf. No.

OVR-Rh'053D

-ON

XlAL-RNO03H

-2 (BOTH)

VLV-RNOOYF

- a

OVR-FWMISD

~ OFF

OVR-FWPOI 8C

-OFF

DVK-FWPG 19C

-OFF

UVR-FWPOIYU

-OFF

MAL-EHrOO3E

-BLOCK

MAL-IRX003A

= o (wro

ONLY1

M4L ISEOObA

=HLOC'K

MAL ISEOOSB

=BLOCK

MALNSOO I B

- BOT11 -

Event

T W *

C-BOP

C-RO

M

C-RO

C-BOP

Event

Description

___

I m s of operating RN pump (In) with failurc of the 1A RN

pump discharge valve to open.

CFPT 1A lube oil pump trips and reserve oil pump does not

start resulting in a trip of 1.4 feedwater pump and generation

of a turbine runback signal.

Failure of automatic turbine runback

Uncontrolled contro1 rod insertion in automatic only

Steam break inside containment (ID steam generator)

Failure of automatic Main Steam Isolation

NS punp 1B fails to start in auto or manual

-

N)crrnal,

R) eactivi.ty,

( I ) n s t r i i a e n t ,

( C ) omponeat,

NURCG-1021

Page 2 of 3 4

D r a f t 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

Step 2.14

SRO/

1

Step 2.3

Step 2.4

Step 2.5

Step 2.6 t'

Step 2.7

Step2.8

1

Step2.9

I

Applicant's Actions or Behavior

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 1 NV-238A (WA Xfer Pmp To Blender Ctrl)

e 1 NV-186A (B/A Blender Otlt To VCT Otlt)

Adjust the boric acid batch counter to the desired volume of boric

acid to be added.

Place the "NC MAKEUP MODE SELECT switch in "BORATE"

Adjust the controller for 1NV-238A (B/A Xfer Pmp to Blender Ctrl)

controller to the desired flow.

Ensure 1 NV-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".

Place the "NC MAKEUP CONTROL" switch in "START" position.

Verify the following valves open:

1 NV-238A (B/A Xfer Pmp To Blender Ctrl Vlv)

e 1 NV-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

Step 2. -i

0

step 2.1 1

Step 2.12

Step 2.13

3ep 2.14

Position

BOF

Applicant's Actions or Behavior

Verify proper flow by observing the boric acid flow totalizer.

\\r\\lhen the desired volume of boric acid is reached on the boric acid

batch counter, ensure the following valves close:

1 NV-238A (B/A Xfer Pmp To Blender Ctrl Vlv)

f NV-186A (BIA Blender 0th To VCT Otk)

desired, flush the makeup line as follows:

0 Open the following valves:

1 NV-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

1 NV-242A (RMWST To B/A Blender Ctrl)

INV-1868 (B/A Blender 0th To VCT Otlt)

the makeup line, close the following valves:

e

0

e Place the following valve control switches in "AUTO":

INV-242A (RMWST Po B/A Blender Ctrl)

1 NV-2 86A @/A Blender Otlt To VCT Otlt)

makeup water pump started in earlier step in "AUTO".

IF NOT required for current plant operation, place the reactor

,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

Step 2.8

Step 2.6

Step 2.4.1

Step 2.4.2

Step 2.42

Step 2.4.4

Step 2.4.5

Position

SRO/RQ

SRQ/RO

a0

Applicant's Actions or Behavior

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.

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

Refer to OP/l/B1630@/001~

Turbine Generator, Enclosure 4.2,

Section 2.4.

Direct RQ to reduce load at a rate of approximately 2 MWlmin or

10% per hour to 90% (-1080 MW target).

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.

Depress the "Target" pushbutton and verify it illuminates.

Input the desired load target (-1080 MW) on the numeric keypad

and verify the load target appears on the Target Display.

To start load decrease, depress the "Go" pushbutton and verify it

illuminates.

NUREG-1021 Draft Revision 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

,

I

Bop

Step 1

Step 1

RNO +

Step 2

Step 3

---+-E-

Step 4

I

Bop

Step 5

I

Ro

Step 6

I

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.

Determines that Channel I is readina hiah and informs SRO

Transitions to Ster, 1 RNO and directs actions

-

IF either selected channel is failed high, T#EN place "PZR PRESS

CTRb SELECT switch in any alternate operable channel position.

Transitions to Step 2 NER and directs actions.

Verify all Pzr PORVs - CLOSED.

Verify Pzr Spray Valve@) - CLOSED.

Verify all Pzr heaters - ENERGIZED.

Ensure 1NV-37A (NV Supply To Pzr Aux Spray) -CLOSED.

Verify NC pressure - STABLE OR INCREASING.

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

Pzr high pressure Reactor Trip

Pzr low pressure Reactor Trip

NUREG-1021 Draft 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

step 7

Step 8

Step 9

Step 10

Position

ALL

Aoolicant's Actions or Behavior

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

e

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)

OT Delta T

Pzr high pressure Reactor Trip

Pzr low pressure Reactor Trip

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 1 (Pressurizer Power Operated Relief Valves PORVs)

Determines that 3.3.1 and 3.3.2 apply.

Ensure "PZR PRESS REX SELECT" is selected to an operable

channel.

Determine long term plant status. RETURN

procedure in effect.

NUREG-1C21 Draft. Revision 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

Step 1

Step 2

Step 3

RNO

Step 4

Step 5

Position

ALL

Applicant's Actions or Behavior

Recognize trip of RN Pump 1B and inform SRO.

Enter AP/O/A/5500/020 (Loss of Nuclear Service Water) Case I

(Loss of RN Train) and direct actions.

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.

Ensure Unit 1 and Unit 2 OATC monitors Enclosure 1 (Foldout

Page).

Verify each operating RN pump discharge flow - GREATER THAN

8.600 GPM.

Transitions to Step 3 RNO and directs actions.

Perform the following:

a. Stop any RN pumps(s) not required to support system operation.

Determines that the discharae valve for the 1A RN DumD did not

Determines that no RN flow exists and informs SRO.

-

open and informs SRO.

Directs BOP to start a Unit 2 RN pump.

Starts a Unit 2 RN pump.

Verify each operating RN pump discharge flow - LESS THAN

23,000 GPM.

Ensure RN pumps - IN OPERATION AS NEEDED.

Determines that an RN pump is in operation and no others are

needed.

NUREG-1021 Eraft Rcvisiorl 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

!

Step 6 +

Step 7

Step 8

Step 9

Step 10

1

ALL

I

Step 11

I

Applicant's Actions or Behavior

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.

Verify each operating RN pump discharge flow - GREATER THAN

8,600 GPM.

Verify RN available to all Unit 1 and Unit 2 D/G(s).

Determine VCNC status as follows:

Verify VCNC -ALIGNED TO OPERATING RN TRAIN.

Verify YC Chiller - RUNNING.

Determine and correct cause of loss of RN train.

Ensure compliance with appropriate Tech Specs and Selected

Licensee Commitments Manual:

SLC 16.7-6 (RN Discharge Instrumentation)

3.6.5 (Containment Air Temperature)

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))

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).

e

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

Determine long term plant status.

RETURN TO procedure in effect.

NUREG-1C21 Draft Revision 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

sianal. Failure of automatic turbine runback.

Time

Step 1

RNO

Step 2

-

Position

ALL

Applicant's Actions or Behavior

Observes that feedwater pump 1A has tripped and informs SRO.

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.

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

Determines turbine load is not decreasing and informs SRO

I

Transitions to Step 1 RNO and directs actions.

Perform the following:

a. Select "MANUAL" on the turbine control panel.

b. Depress "CONTROL VALVES LOWER" pushbutton and

reduce turbine load as required.

Transitions to Step 2 N E B column and directs actions..

Verify proper reactor response:

m Control rods - IN "AUTO" AND STEPPING IN

P/R neutron flux - DECREASING

NUREG-102; Draft Revision 9 11 of 34

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

Step 3

Stew 4

Step 5

-

Position

Apwlicant's Actions or Behavior

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

Steam dump valves - MODULATING

(ISI-18) - LIT

d. TAvg - DECREASING TO P-REF

Verify Pzr PORV and Pzr spray valve status as follows:

a. All Pnr PQRVs - CLOSED

b. Normal Pzr spray valves - CLOSED

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

c. Verify standby hotwell pump(s) - ON

d. Verify standby condensate booster purnp(s) - ON

EVENT.

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 Revision 9

12 of 34

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

Step 6

Step 7 i

Step7

I

RNO

I

SRo

Step 8

step 9

Step 10 +

Applicant's Actions or Behavior

Verify the following generator alarms - DARK:

IAD-11, C/1 "GEN BKR A OVER CURRENT"

ZAB-11, F/l "GEN BKR 5 OVER CURRENT

Verify S/G levels are adequate as follows:

All S/G low 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).

Perform the following:

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.

Transitions to Step 8 NER column and directs actions.

Verify AS header pressure - GREATER THAN OR EQUAL TO 140

PSIG.

Monitor Enclosure 3 (Rod insertion Limit Boration).

EXAMINER NOTE: AP/llA/5500/03, Enclosure 3 is attached.

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 Draft Revision 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

I. Failure of automatic turbine runback.

Time

Step 10

RNO

Step 12

Step I 3

sig

Position

SUO

§RO

UO/BOP

Applicants Actions or Behavior

a. E

the runback target load is less than 30%, THEN:

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

Control rods

0

Boron Concentration

b. s m

Step 12.

Transitions to Step 12 A/ER and directs actions.

Verify the following PCBs - CLOSED:

Generator breaker 1A

e Generator breaker 1B

0 PCB14

PCB15

PCB17

PCB18

Mjust power factor as necessary. REFER TO Unit 1 Revised Data

Book Figure 43.

NUREG- 1021 Draft Revision 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

3ep 14

Step 15

Step 16

step 17.a

Step

17.a.2)

?NO

Position

ALL

ROiSRO

ALL

Applicant's Actions or Behavior

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

Control rods

Boron concentration

Notify System Operating Center (SOC) using the red dispatcher

telephone of current unit status.

Determine and correct cause of Load Rejection

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.

.

Transitions to Step 17.a.2) RNO and directs actions.

GO TO Step 17.b

Transitions to Step 17.b and directs actions

NUKEG-1021 Draft Revisior. 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

17.b

Step 18

Step 19

Step 20

Step 21

Step 22

Position

RQIBOP

ALL

~~

~

Applicant's Actions or Behavior

b. RC pump(s) and cooling tower fans. REFER

OP/118/6400/001A (Condenser Circulating Water)

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.

Verify reactor power - GREATER THAN 15%

Verify CA Pumps -OFF

Verify reactor power change - GREATER THAN OR EQUAL TO

15% IN A I

HOUR PERIOD.

Notify the following sections to take appropriate samples:

Radiation Protection to sample and analyze gaseous

effluents. REFER TO Selected Licensee Commitments

Manual, Section 16.1 1-6.

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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months and 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months following last power change

greater than or equal to 15% rated thermal power within a Z

hour period).

NUREG-1021 Draft Revision 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

Step 24

step 25

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

Notify Reactor Group Engineer of occurrence

ALL i

Determine long term plant status. RETURN

(Controlling Procedure for Unit Operation).

OPI1IAI61001003

NUREG-1021 Draft Revision 9

17 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

Step 1

Step 2

Step 3

Step 4

Step 5

Step 6

Step 7

Position

UO

Amlicant's Actions or Behavior

Determines that control rods are continuing to insert when no rod

motion is required and places control rods in manual, informs 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.

Ensure "CRD BANK SELECT" switch - IN MANUAL.

RO Dlaces switch in MANUAL.

Ensure all rod motion - STOPS

Manually adjust control rods as necessary to maintain T-Avg within

1°F of T-Ref.

getermine and correct cause of continsus rod movement.

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 3.1.6 apply if the control rods are below

the rod insertion limits.

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)

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

Step 1

Step 2

Step 3

Step 4

Position

ALL

ROIBOP

ROIBOP

SRQ

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.

Recognize reactor trip and safety injection have occurred.

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.

Enter EPIIIN5OOOIE.-0 (Reactor Trip or Safety Injection) and direct

actions of operators.

Monitor Enclosure 1 (Foldout Page)

Verify Reactor Trip:

All rod bottom lights - LIT

Ail reactor trip and bypass breakers - OPEN

VR amps - DECREASING

Verify Turbine Trip:

All turbine stop valves - CLOSED

Determines that turbine has not triooed and informs SRO

Transitions to Step 3.a RNO and directs actions

a. Manually trip the turbine.

b. If turbine will not trip, THEN.

Determines that turbine has manually tripped and informs SRO.

Transitions to Step 4 NER and directs actions.

Verify 1 ETA and 1 ETB - ENERGIZED.

NUREG-1021 Draft Revision 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 1 I3

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Time

Step 5

Step 6

Step 7

Step 8

Step 9

step 10

Position

Applicants Actions or Behavior

Verify SA is actuated:

a. SAFETY INJECTION ACTUATED status light (ISI-13) - LIT

b. E/S load sequencer actuated status lights (IS-14) - LIT

Announce Unit 1 Safety Injection.

Implement RP/O/A/5000/001 (Classification Of Emergency)

Verify all Feedwater Isolation status lights (ISM) - LIT

Verify Phase A Containment Isolation status as follows:

a. Phase A RESET lights - DARK

b. Monitor Light Panel Group 5 St lights - LIT

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.

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 1 D steam generator. NS pump 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Position

ALL

Applicant's Actions or Behavior

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

flow is not indicated. THEN manually initiate Phase B

3)

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

teD 10.a.

INb

Cont.)

Position

BOPlRO

Applicant's Actions or Behavior

c) Verify following monitor light panel lights - LIT:

Group 1 Sp lights

EXAMINER NOTE: Group 1 Sp lights for NS Pumps will not be

lit.

Group 5 Sp lights

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.

Group 5 St lights L/11 and L/12.

BOP resets B Train ECCS.

(2) Reset BIG load sequencer.

60P 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, 1 B 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) GOTOStepII.

Transitms to Step 11 N E R and directs actioris.

. . -

. -

. . -.

. -. -. . -.

-.

__.

. -. . -. . -

NUREC;-1021

Draft Revision 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 1 B steam generator, NS pump 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Time

Step 11

Step 12

Stet, 13

Position

Aoolicant's Actions or Behavior

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 1 I%.

Verify all of the following S/I pumps - ON:

NVpumps

NDpumps

NI DUmDS

Verifv all KC DumDs - ON

IdUREG-102?

Draft Revision 9 23 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

Step 14

RNO

Step 15

Step 16

Position

BOP/

Aaalicant's Actions or Behavior

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.

Transitions to Stee 14 RNO and directs actions.

EXAMINER NOTE: The crew may elect not to attempt to start

the 1A and 1B RN pumps due to the fact that it tripped earlier

due to a relay actuation.

a. IF any Unit 2 RN pump is off, THEN ...

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.

4) IF AT ANY TIME a 810 occurs, THEN restart SI1 equipment

Attempts to manually start 1 B RN Pump

previously on.

Transitions to Step 15 NER and directs actions.

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).

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 24 of 34

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 1 D steam generator, NS pump 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Time

CRITICAL

TASK

Step 16

RNO

Step 17

Position

SRQ

RO/BOQ

SRQ

Applicant's Actions or Behavior

rransitions to Step 16 RNO and directs actions.

EXAMINER NOTE: It is critical that the crew take action to

initiate Main Steam Isolation manually upon failed auto action

to prevent excessive cooldown and minimize inventory loss

resulting from all SiGs faulted.

'erform the following:

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.

Transitions to Step 27 MER and directs actions

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

Transitions to Step 17.d RNO and directs actions.

NUREG- 1021 Draft Revision 9

2 5 cf 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 1 D steam generator, NS pump 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Time

Step 17.d

RNO

Step 18

Step 19

Step 20

~~

Step 21

Step 22

Position

ALL

Applicant's Actions or Behavior

d. Perform the following:

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

Transitions to Step 18 NER and directs actions.

a. Verify total CA flow - GREATER THAN 450 GPM.

b. m

a

t

least one S/G N/R level is greater than 1 I% (29%

A X ) , THEN throttie feed flow to maintain all SIG NIR levels

between 11 % (29% ACC) and 50%.

Control S/G levels as follows:

Verify all CA isolation valves -OPEN

Verify S/I equipment status based on monitor light panel - IN

PROPER ALIGNMENT.

m:

Enclosure 4 (NC Temperature Control) shall remain in

effect until subsequent procedures provide alternative NC

temperature control guidance.

Control NC temperature. REFER TO Enclosure 4 (NC

Temperature Control).

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 Revision I)

2 6 of 34

\\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 1 B steam generator, NS pump 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

I

I I

~

Step 24

RO/SRO

RNO

I

1

ALL

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.

Transitions to Step 24 RNO and directs actions.

IF any S/G is decreasing in an uncontrolled manner OR any S/G is

depressurized, THEN concurrently:

0 Implement EP/I/N5000/F-O (Critical Safety Function Status

GO TO EP/I/N5000/E-2 ( Faulted Steam Generator Isolation)

Trees).

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.

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

Step 3.a. I

step 3.e.

Step4

1

Step 5

Applicant's Actions or Behavior

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 10 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)

INS-158 (NS Spray Hdr 1B Cont Isol)

1NS-12B (NS Spray Hdr 1B Cont Isol).

e. Ensure all of the foilowing valves - CLOSED:

INS-18A (NS Pmp A Suct From Cont Sump)

INS-I0 (NS Pmp B Suct From Cont Sump).

0

Stop all NC pumps.

Verify the following valves - CLOSED:

All MSlVs

All MSlV bypass valves.

NUREG-1021 Draft Revisior. 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 1 D steam generator, NS pump 1B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Time

1

Position

Step 6.24.

RNO

Step 7

Step 8

Step 9

RO/BOP

CRITICAL

TASK

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

Transitions to Step 6.a. WNO and directs actions

a. IF pressure in any S/G is decreasing in an uncontrolled manner

Determines that I D steam generator is depressurized and informs

OR any S/G is depressurized, THEN GO TO Step 7.

Transitions to Step 7 and directs actions.

Verify at least one S/G pressure - STABLE OR INCREASING.

Determines that IA, 1B and 1C steam generator pressures are

stable and informs SRO.

Verify at least one intact SIG -AVAILABLE FOR NC SYSTEM

COOLDOWN.

Determines that IA, 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.

Isolate all faulted S/G(s) as follows:

Betermines that I D is faulted.

d. For S/G 1 D:

1) Verify S/G ID Feedwater Isolation status light (ISI-5) -

LIT.

2) Close 1 CA-42B (CA Pmp B Bisch To S/G 1 D Isol)

3) Close 1 CA-388 (CA Pmp 1 Bisch To S/G 1 B Isol)

NIIREG-1021 3raft Revision 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

Step 10

Step 1 1

Step I1 .a

KNO

Step 13.a

Step 13.b.

RNO

Position

SUB

Applicant's Actions or Behavior

WHEN NC T-Hots start to increase, THEN dump steam from intact

S/G PORVs to stabilize NC T-Hots.

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.

Transitions to Step 11 .a RNO and directs actions.

a. Perform the following:

1) WHEN EP/I/N5000/ES-2.3 (Transfer To Cold Leg

2) GO TO Step 13.

Recirculation) is completed, THEN perform Steps 11 and 42.

Transitions to Step 43 NER and directs actions.

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.

b. Verify containment Ha analyzers - IN SERVICE

Determines the hydrogen analyzers are not in service and imforms

Transitions to Step 13.b. RNO and directs actions.

b. Perform the following:

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

3) GO TO Step 16.

through 15.

Transitions to Step 16 AER and directs actions.

NUREG- 1021 Draft Revision 9

30 of 34

Form ES-D-

ippendix B

Operator Actions

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

Step 16

Step 4

Step 2

Step 3

Step 4

Step 5

Step 6

Step 7

Position

ALL

Applicant's Actions or Behavior

RETURN TO procedure and step in effect.

Transitions to EP/1/N5000/E-2 and directs actions.

Monitor Enclosure 4 (Foldout Page).

Maintain any faulted Si6 or secondary break isolated during

subsequent recovery actions unless needed for NC

System cooldown.

Verify the following valves - CLOSED:

All MSlVs

All MSlV bypass valves.

Verify at least one S/G pressure - STABLE OR INCREASING.

Determines that lA,lB and I C steam generator pressures are

stable and informs SRO.

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.

Verify at least one intact SIG -AVAILABLE FOR NC SYSTEM

COOLQOWN.

Determines that ?A, I B and I C are available and informs SRO.

Isolate all faulted S/G(s) as follows:

Determined need to perform for D S/G.

SI6 ID:

a. Verify S/G I D Feedwater Isolation status light (ISM) - 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 1 SM-74B.

NURZG-1021 Draft Revision 9

31 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 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isoiation signal.

Time

step a

Step 9

Step 10

Position

Applicant's Actions or Behavior

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).

d. Verify the following blowdown isolation valves - CLOSED:

1) 1BB-8A (Si6 1 B Bldwn Cont Is01 Insd).

2) 1BB-1478 (S/G 1B Bldwn Cont lsol Byp).

3) 1BB-1OB (SIG 1D Bldwn Cont lsol Otsd).

WHEN NC T-Hots start to increase, THEN dump steam from intact

S/G PORVs to stabilize NC T-Hots.

Verify the following annunciators - DARK.

0

IAB-5, H/4 "CACST LO LEVEL"

e

IAD-8, B/1 "UST LO LEVEY

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:

1EMF-26 (Steamline 1A)

?EMF-27 (Steamline 15)

0

IEMF-28 (Stearnline 1C)

1 EMF-29 (Steamline 1 D).

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:

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 Revision 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 1 D steam generator, NS pump 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Time

Step 1 I

Step 1

Step 2

Step 3

Step 4

Step 5

Step 6

Slep 7

Position

ROIBOP

ALL

Applicant's Actions or Behavior

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).

Transitions to EP/1/A/5000/ES-1.1 and directs actions.

Monitor Enclosure 1 (Foldout Page).

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.

Ensure the following containment isolation signals - RESET:

PhaseA

PhaseB.

Establish VI to containment as follows:

e

Ensure onlv one NV Dumn ON.

Ensure IVI-97B (VI Cont Isol) - OPEN.

Verify VI pressure - GREATER THAN 85 PSIG.

.

,

Secures oie NV pump and informs SRO.

Verify NC pressure - STABLE OR INCREASING.

Verify VI pressure - GREATER THAN 50 PSIG.

KCREG- 1021 Drsft. Revision 3

33 C f 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 1 B

fails to start in AUTO or MANUAL, failure of automatic main steam isolation signal.

Time

Step 8

Position

Applicant's Actions or Behavior

. Isolate NV S/i flowpath as follows:

a. Verify the following valves - QPEN:

1 NV-252A (NV Pumps Suct From FWST)

1NV-253B (NV Pumps Suct From FWSTj.

1 NV-203A (NV Pumps A&B Recirc Isol)

INV-2025 (NV Pmps A&B Recirc isolj.

INI-9A (NV Pmp C/i lnj Isol)

INI-IOB (NV Pmp C/L lnj Isol).

0

a. Verify the following valves - OPEN:

b. Close the following valves:

Terminate scenario when 1NI-9A AND 1NI-IQB are closed.

Classification: Alert 4.6.A.1-1

NUREG-1021 Draft Revision 9

34 of 34

FOR rRAINING PURPOSFS ONLY

EMERGENCY NOTIFICATION FORM

CrUAL EMCRGFNCY

@iTi,L

~ F O L L O w - u P

MESSAGE NUMBER

I

2

ITE:

UNIT:

RtPORrED BY:

3.

.iANSMITTAL TIMEiDATE:

4.

AUTHENTICAlION (I: Hequired).

I

CONFlRMAilON PHONE NUMBER.

(803)

R31-3807 (Simulator)

- - -

iFiliW:

r m

Od

\\Y

NOTIFICAlION OF UNUSUAL EVENT

SITE AREA EMERG - -

46

T

En6nERGENcY D E s c w T m m m m K s :

equipment. This EAL poses no threat to the safety of the general pubiic.

EAL # 4.6.A.1 - A fire or explosion has caused damage to permanent plant

i. POWEn

- -

dd

ii

PLANT CONDITION: DIMPROVING

REACTOR STATVS:

TlMEiDPTE:

lo. EMERGENCY HtLEASE(S):

NONE (Go lo item 14.)

aPO.IENTIAL (Go to item 14.)

m I S OCCURRING

B t W S OCCURHW

O R O U N D LEVEL

,

.q,r..,..v>,<

i

- - -

I

Gale

- - -

M

- I I. WPE OF RELEASE:

OELEVATCD

m f i n n n Q N E :

SIaWd:

?rrlEzlsfsm)

Oaf?

, ,n*!lar,rrr,j

JLIQUID:

Started:

i

Stopped

i

- - -

T8miFas1~mI

Dale

T#ne!Eai!c~l

cafe

12 RELEASE MAGNITUDE:

D

I

E

S

PER SEC.

D U R I E S

NORMAL OPERATING ILIrJlTS: OBEI.OW

O A R O V E

NOBLE GASES

B I O D I N F S

OPARTICULATES

W t l E R

-

- lZ ESTIMATE OF PROJECTED OFFSll E DOSE

U N E W

~ U N C Y A N G E D

TEDE

Thyroid CI)

nrrem

mrem

sirE BOUNDARY

2 MILES

5 MILES

10 MILES

PRO2ECIION TIME

,tarterr I

ESTIMATHJ DURATION

HRS

-14. METEOROLOGICAL D A T A : ~ W I N D

DIRECTION (frcm)

m P E E O ( m p h )

~ 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 15-16 are reqdiied to be completed.

Information may ngt he availaWc on :,:ilia1 rmtificiltioris.

FOR TRAINING PURPOSES ONLY

II

I

,

1.

E t h e control rods cannot be maintained above the rod insertion limits, THEN:

-

a. Stop any dilutions in progress.

~.

CAUTlON

.

. .

NOTE

Failure to initiate boration within one hour of exceeding rod insertion

h i t s may violate Tech Spec 3.1.6.

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 Simulator Scenario

Form ES-D-1

$irnulation Facility: 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 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

NS pump 1A is out of service for motor replacement. It is due to be returned to

service in 24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months .

Valve 1NC.-31B was 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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months 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.

(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 I

Appendix D

I n i t i a l Zynamic Siwalator Scenario

Fcrm E - D - 1

P

Event

Type*

__r

C-BOP

C-RO

AI-ALL

C-RO

C - n m

Event

Description

-

KC Surge Tank 1,cvel Transmitter fails low resulting in h e

loss of the Auxiliary BuiIdiiig and Reactor Building non-

essential headers.

Loss of condenser vacuum

Reactor triu due to loss of vacuum

CA pump 1R fails to start (50G relay)

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 Revision 9

Appendix D

Operator Actions

Form ES-D-2

Event Description: Boration for power decrease

p

Step 2.2

Step 2.3

Step 2.4

Step 2.6

Step 2.7

I Steo2.8

I

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).

Determines amount of boron to add (-455 gallons over first

hour).

Refer to OP/1/A/6150/009 (Boron Concentration Control)

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)

Adjust the boric acid batch counter to the desired volume of boric

acid to be added.

Place the "NC MAKEUP MODE SELECT switch in "BORATE

Adjust the controller for 1 NV-238A @/A Xfer Pmp to Blender Ctrl)

controller to the desired flow.

Ensure 1 NV-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 mmD in "AUTO" or "ON"

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

Step 2.9

step 2.10

Step 2.1 1

Step 2.12

Step 2.13

Step 2.14

Position

Amlicant's Actions or Behavior

Verify the following valves open:

1 NV-2388 @/A Xfer Pmp To Blender Ctrl Vlv)

1 NV-1 86A (B/A Blender Otlt To VCT Otlt)

If in "AUTO", verify the boric acid transfer pump starts.

Verify proper flow by observing the boric acid flow totalizer

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)

-

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 0th To VCT Otlt)

makeup water pump started in earlier step in "AUTO".

IF NOT required for current plant operation, place the reactor

-

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

1 Op-Test No.: NRC Scenario No.: 1 Event No.: 2

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 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months .

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

Op-Test No.: NRC Scenario No.: 1 Event No.: 2

Event Description: Turbine load reduction for power decrease using AP109

Time

Step 9

Step 10

Step 11

Step 12

Step 12 d

Step 12.e.

Position

a0

80

ALL

Applicant's Actions or Behavior

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.

FAT ANY TIME the turbine load reduction rate OR the target load

nust be changed, THEN RETURN TO Step 5.

4djust power factor as necessary. REFER TO Unit 1 Revised Data

3ook Figure 43.

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.

UOTE

0

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.

d. Borate the NC Svstem as reauired. REFER TO R.O.B. book

Section 4.8.

Ensure operator monitors Enclosure 2 (Rod Insertion Limit

3oration).

2

NiJKEG-1021 Draft Kevision 9

6 cf 31

Appendix D

Operator Actions

Form ES-C

Op-Test No.: NRC Scenario No.: 1 Event No.: 2

Event Description: Turbine load reduction for power decrease using AP/03

Time

Step 13

Step 14

Step 15

RNO

Step 16

Step 17

Position

ALL

Applicant's Actions or Behavior

Verify Pzr PORV and Pzr spray valve status as follows:

a. All Pzr PORVs - CLOSED.

b. Normal Pzr spray valves - CLOSED.

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).

Verify reactor power - LESS THAN 05%.

Determines that reactor power is greater than 85% and informs

Transitions to Step 15 RNO and directs actions.

IF the target load is less than 05%, THEN:

1) WHEN time and personnel permit, THEN perform applicable

steps of OP/I/A/6100/003 (Gontrolling Procedure For Unit

Operation).

85%.

2) Bo not continue in this procedure until reactor power is less than

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.

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.

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 1 SP-3 $32 To CFPT I A & I

El) (TB-

640, 1G-24).

EXAMINER NOTE: The crew should not have sufficient time to

reduce power to this point.

2

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

Step 1

Step 2

Step 3

Step 3.3

RNO

Step 3.b.

RNO

Step 4

Step 5

Step 6

Step 7

Position I

ADDlicant's Actions or Behavior

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.

BOP informs SRO that ail Pzr PORVs are closed.

Verify Pzr spray valve@) - CLOSED.

BOP informs SRO that 1NC-29 is open.

Transitions to Step 3 RNO and directs actions.

Perform the following:

a. Manually close affected spray valve(?.).

BOP doses 1 NC-29 manually and informs SRO.

b. IF affected spray valve(s) will not close, THEN perform the

following:

Determines that this step does not apply and transitions to Step 4

AJER.

Checks that 1NV-37A is closed and informs SRO.

Determines that step does not apply and continues to Step 8

NUREG-1321 Draft Revision 9

8 of 31

Event Description: Pressurizer spray valve 1 NC-29 fails open with manual control available.

Time

step a

Position

Step 9 T

Applicants Actions or Behavior

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)

3.4.13 (RCS Operational Leakage).

Determines that none apply for the spray valve failure.

Ensure PZR PRESS REC SELECT is selected to an operable

channel.

BOP informs SRO that an operable channel is selected.

3.4.1 I (Pressurizer Power Operated Relief Valves (PORVs))

RETURN PO procedure in effect

Crew may contact Shift Work Manager and/or SPOC far

NUKEG-1021 D r a f t Revision 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

Step 1

Step 2

Step 3

Step 4

Position

80

ALL

Applicants Actions or Behavior

EXAMINER NOTE: Ensure control sods are in AUTO prior to

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.

Recognize failure of Loop I C narrow range cold leg temperature

instrument and inform SRO.

EXAMINER NOTE: The crew may respond to this event by

taking control rods to manual and by utilizing guidance

contained in 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 to be oerformed from memorv.

Enter AQ/l/A/5509/015 (Rod Control Malfunction) Case 2

(Continuous Rod Movement) and direct actions.

Ensure CRD BANK SELECT switch - IN MANUAL.

Places Red Control selector switch to manual.

Verify all rod motion - STOPS.

Observes control rod bank demand counters and DRPI to

determine rod motion has stopped and informs SRQ.

Manually adjust control rods as necessary to maintain T-Avg within

1 O

F

of T-Ref.

Adjusts control rod position as required.

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))

0

3.3.2 (ESFAS Instrumentation).

3. I

.4 (Rod Group Alignment Limits)

3.1.5 (Shutdown Bank Insertion Limits)

3.1.6 (Control Bank Insertion Limits)

I

Determine long term plant status.

RETURN TO procedure in effect.

Step 7

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

Auxiliary

Time

Step 1

Step 2

Step 3

Step 4

Step 5

Step 6

ng and RI

Event Descrintion: KC Surge Tank Level Transmitter fails low resulting in the isolation of the

ictor Building Non-essential headers.

Position

ALL

ALL

ALL

Applicant's Actions or Behavior

Recognizes loss of 1 B KC surge tank level indication and isolation

of the Auxiliary Building and Reactor Building Non-essential headers

and informs SRO.

SRO refers to AP/I/A/5500/21 and directs actions.

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.

Monitor Enclosure 1 (Foldout Page).

Verify at least one KC pump - ON

IF AT ANY TIME all KC pumps are lost. THEN RETURN TO

STEP 2.

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.

Starf additional KC purnp(s) as necessary to supply any KC loads

presently in service.

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.

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.

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

Step 6

RNO

Step 6

RNO

Step 7.a

Step 7.b.

Position

ALL

BQP

Applicant's Actions or Behavior

Perform the following:

8. Ensure the following valves - OPEN:

IKC-425A (NC Pumps Ret Hdr Cont Isol)

1 KC-338B (NC Pumps Sup Hdr Cont Isol)

IKC-424B (NC Pumps Ret Hdr Cont Isol).

3etermines that valves are open and informs SRO.

3. IF AT ANY TIME any of the following conditions are met:

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

rransitions to Step 7 NEB and directs actions.

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 )

1 KC-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)

I. Verify the following Train B KC non-essential header isolation

valves -OPEN:

1KC-228B (Rx Bldg Non-Ess Hdr Isol)

1 KC-I 8B (Rx Bldg Non-Ess Ret Hdr [sol)

1KC-53EI (Aux Bidg Non-Ess Hdr Isol)

1 KC-25 (Aux Bldg Non-Ess Ret Hdr Isol).

letermines that all 4 valves are dosed and informs SRO.

rransitions to Step 7.b. RNO and directs actions.

Draft Revi-sion 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

Time

Step 7.b.

RNO

Step 7.c.

Step 8.a

Step 8. b

Step 12

3eg 13

Position

SR8

ALL

ictor Building Non-essential headers.

Applicant's Actions or Behavior

NOTE The KC nen-essential header valves can be reopened when

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 C1 D2214 (KC Train B Low-Low Surge

Tank Isol) is "NOT ACTUATED" and informs SRO.

Directs BOP to open the following valves:

1 KC-228B (Rx Bldg Non-Ess Hdr Isol)

IKC-188 (Rx Bldg Non-Ess Ret Hdr Isol)

IKC-25 (Aux Bldg Non-Ess Ret Hdr Isol)

IKC-53B (AUX Bldg Non-E~s Hdr Iso~)

Opens the following valves:

0

IKC-228B (Rx Bldg Non-Ess Hdr lsol)

1 KC-18B (Rx Bldg Non-Ess Ret Hdr Isol)

1 KC-53B (Aux Bldg Non-Ess Hdr Isol)

1 KC-2B (Aux Bldg Non-Ess Ret Hdr Isol).

Informs Sa0 when all valves are open.

Transitions to Step 7s. NER and directs actions.

c. Start additional KC pump@) as necessary to supply any KC loads

Determines additional KC pumps are not needed and informs SRO.

Verify KC surge tank levels normal as follows:

a. Verify both KC surge tank levels - 50% - 90% AND STABLE

b. GO TO Stepl2.

SRO transitions to Step 12 NER and directs actions.

Ensure KC heat exchanger outlet mode switches - PROPERLY

ALIGNED.

presently in service.

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 Revision 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

Step 14

Step 15

Step 46

Step 17

Step 2 8

Step 19

Ster, 20

Step 21

Position

ALL

%OP

Applicant's Actions or Behavior

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,

Determine required notifications:

IF KC Hx leak to RN is suspected, THEN ...

Determines no KC heat exchanger leak to RN is suspected.

Verify KC surge tanks level as follows:

Greater than 50%

Stable or increasing.

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.

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.

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".

Determine long term plant status.

RETURN TO procedure in affect.

REFER TO RP/O/A/5000/001 (Classification Of Emergency)

REFER TO RP/OIB/5000/013 (NRC Notification Requirements).

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

Step 2

Step 3

Step 4

Step 6

Step 7

!UREG-l(?:

Position

ALL

Draft.

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

Recognize symptoms of condenser vacuum decreasing and inform

Enter AP/l/A/5500/23 (Loss of Condenser Vacuum) and direct

actions.

Monitor Enclosure 1 (Foldout Page)

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.

Verify proper RC System operation as follows:

a. Verify average condenser inlet temperature OAC point C1 PI493

b. Verify 1AB-8, B/4 "CQQLING TOWER BASIN HI/LO LEVEL" -

DARK.

Ensure proper operation of ZP System. REFER TO

OP/O/B/6250/011 (Vacuum Priming System).

Verify steam pressure to CSAE -GREATER THAN 110 PSIG.

Dispatch operator to place idle set of CSAE jet(s) in operation.

REFER TO OQil/B/6300/006 (Main Vacuum).

1 C1 & C2 Average RC inlet Temp) - LESS THAN 90°F

Verify steam seal header pressure - BETWEEN 3 PSIG - 5 PSIG.

?vision Y

1 6 of 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.

Step

103.2)

RNQ

I

Step 23

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.

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).

2) GO TO Step 11.

Transitions to Step 11 NER and directs actions.

Determine and correct cause of loss of vacuum.

Crew may contact Shift Work Manager andlor SPOC for

assistance.

Determine required notifications:

Determines none are required at this time.

EXAMINER NOTE: This assumes that the reactor and turbine

have not yet tripped.

Determine long term plant status.

RETURN TO procedure in affect.

REFER TO RP/O/N5000/001 (Classification Of Emergency)

REFER TO RP/OIB/5000/013 (NRC Notification Requirements).

NUREG-1021 Drzft lievision 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

Step 1

Step 2

Step 3

Step 4

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.

Directs RO to trip the reactor

sRo I

Enter EP/l/N5000/E-0 (Reactor Trip or Safety Injection) and direct

actions of operators.

0 All rod bottom lights - LIT

All reactor trip and bypass breakers - OPEN

I/R amps - DECREASING

Verify Turbine Trip:

0 All turbine stop valves - CLQSD

Verify 1 ETA and 1 ETB - ENERGIZED.

I

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

irization using Pzr PORV.

resulting in

Time

Step 5.a

Step 5 x 1 )

RMO

Step 5.a.2)

RNO

Step 5.a.3)

WQ

Step 1

2s depre!

Position

ALL

Applicant's Actions or Behavior

Verify SA is actuated:

a. "SAFETY INJECTION ACTUATED" status light (13-13) -LIT

Observes status light is DARK and informs SRO.

Transitions to Step 5.a RNO and directs BOP

a.

Perform the following:

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.

2) IF SI1 is required, THEN manually initiate SA

SRO determines this steo to be NIB.

3) IF S/l is not required, THEN concurrently:

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.

1. Monitor Enclosure I

(Foldout Page).

" J R E G - 1 0 2 1

Draft 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 1 B

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

Step 2

Step 3

Step 4

Step 5

Step 6

Step 6.c

RNO

Position

ALL

80

Applicant's Actions or Behavior

2. Verify the following:

.All 6.9 KV busses - ENERGIZED

VI pressure - GREATER THAN 85 PSI6

Announce "Unit 1 Reactor Trip".

Implement RP/O/A/5000/01 (Classification of Emergency).

NOTE Enclosure 2 (NC Temperature Control) shall remain in

effect until subsequent steps provide alternative NC temperature

control guidance.

Control MC temperature. REFER TO Enclosure 2 (NC Temperature

Control).

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).

Transitions to 6.c RNO and directs actions.

c. Establish feed flow to maintain at least one S/G N/R level

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)

NUREG- 1021 Drafr Revisicn 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 POW.

Time

Step 7

Step 8

Step 9

Step 10

Step 1 1

Position

Applicant's Actions or Behavior

EXAMlNER NOTE: The crew may choose to refer to

AP/l/A/5500/06 (Loss of 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.

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.

d. Stop any boron dilutions in progress.

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".

Verify proper Pzr pressure control as follows:

a. Pzr pressure - GREATER THAN 1845 PSIG

b. Pzr pressure - STABLE AT OR TRENDING TO 2235 PSIG.

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%.

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

IETB - ENERGIZED.

"FTB BIO NORM FDR FRM ATB" - CLOSED

"D/G 1 B BKR TO ETB' - OPEN

NUREG-I021 C r a f t Revision 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 1 B

'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

Step 12

Steo 13

Step 14

?NO

STEP 15

Position

80

80

ALL

Applicant's Actions or Behavior

Transfer condenser steam dump to pressure control mode as

a. Verify 'IC-9 (FOND AVAILABLE FOR STM DUMP status light

b. Verify all MSlVs - OPEN.

e. Ensure "STM DUMP CTRL" pot - SET AT 8.43 (I090 PSIG

d. WHEN the steam dump valves are closed, THEN:

follows:

(ISI-18) - LIT.

STEAM HEADER PRESSURE).

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"

4) Place the steam dumps in pressure mode.

5) Place the "STM BUMP CTRL" in automatic

demand.

Verifv at least one NC D U ~ D

- ON.

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.

Transitions to Step 14 RNO and directs actions.

a. Perform the following:

1) WHEN IlR channels are less than 10-10 Amps, THEN

2) GO TO Step 15.

perform Steps 14.b and 14.c.

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

Op-Test No.: NRC Scenario No.: 1 Event No.: 7-9

ppendix 5

Operator Actions

Form ES-5-2

I

i

Event Description: Reactor tripkurbine 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

urization using Pzr PORV.

asulting in

Time

k

Step 1

step 2

step 3

teo 4

jtep 5

S depre:

Position

ALL

ALL

80

Applicant's Actions or Behavior

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.

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.

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.

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

Monitor Enclosure 1 (Foldout page).

Verify at least one NV pump -AVAILABLE.

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

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. LOSS of all auxiliary

feedwater results in loss of secondary heat sink. Auxiliary Pnr spray will not be available

esultina in NCS deoressurination usina Pzr PBRV.

"

Time

Step 5.a.

?NO

step 6

Step 7

Position

ALL

I

Applicant's Actions or Behavior

a. Perform the following:

1) Monitor bleed and feed initiation criteria. REFER TO

2) WHEN criteria is satisfied, THEN GO TO Step 18.

3)G0 TO Step 6.

Enclosure 1 (Foldout Page).

Verify S/G inventory loss is minimized as

follows:

a. All of the following blowdown isolation valves CLOSED:

. .

e . . . . . . . . .

IBB-56A (SIG 1A Bldwn Cont Is01 Insd)

IBB-148B (SIG 1A Bldwn Cont ISOI

Byp)

1BB-57B (S/G I A BldWn Cont Is01 Otsd)

IBB-19A (SG 1B Bldwn Cont Is01 Insd)

1 BB-21 B (S/G 1 E Bldwn Cont Is01 Otsd)

1 BB-60A (SIG 1 C Blclwn Cont Is01 Insd)

1 BB-149B (SI6 1 C Bldwn Cont Is01 Byp)

IBB-618 (SIG I C Bldwn Cont Is01 Otsd)

188-2478 (SIG 1D BidvJn Cont Is01 Byp)

I

EB-1OB (S/G 1 D Bldwn Cont ISOI Otsd).

1 BB-1508 (SIG 1 B Bldwn Cont Is01 Byp)

1 BB-8A (SIG 1 D Bldwn Cont Is01 insd)

b. All SIG sample isolation valves - CLOSED.

4ttempt to establish CA flow to at least one SIG as follows:

a. Verify the following annunciators BARK.

-

1AB-5, HI4 "CACST LO LEVEL"

IAD-8, BIl "UST LO LEVEL"

D. Verify the following CA suction valves - OPEN:

I

CA-6 (CA Pmps Suct From CA CST)

ICA-4 (CA Pmps Suct From UST)

0

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.

Transitions to Step 7.c.2) RNB and directs actions.

NUREG-1021 Draft Revision 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

Step 7.c.2)

?NO

Step 7.d.

Step 7.9

?NO

Step 8

ZRITICAL.

STEP

Position

RO/BOP

Applicants Actions or Behavior

a) Dispatch operator to reset the CAPT trip and throttle valve.

b) WHEN the CAPT trip and throttle valve is reset, THEN

c) GO TO Step 7.d.

2) Perform the following:

perform Steps 7.c.2 through 7.c.4.

BOP dispatches an operator to locally reset the CAFT trip and

throttle valve. SRO transitions to Step 7.d. NER.

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 transitions to Step 7.9. RNO

1) IF CA flow indicated AND flow is being controlled as required by

Enclosure E (Hot Dry Si6 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.

Transitions to SteD 8 AJER.

Stop all NC pumps.

NUKEG-1321 Draft Kcvision 9

25 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

step 9

Step 10

Step 10.b.

?NO

Step 1O.j.

Position

SRQ

ALL

Applicant's Actions or Behavior

Verify CM System is in service as follows:

Hotwell gump(s) - ON.

Condensate Booster pump(s) - ON.

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 TWIN B LEVEL HI"

b. Verify $11 - HAS PREVIOUSLY ACTUATED.

Determines that SA has not previously actuated and informs SRO.

Transitions to step IO.b. RNO and directs actions.

b. Perform the following:

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

Transitions to Step 10.j. MER.

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 of 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 1 B

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

Step 11

Step 1 'I .e.

RNO

Position

ALL

ALL

Applicant's Actions or Behavior

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.

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)

90 opens ICA-149, ICA-150, ICA-151 and ICA-152 and informs

ICA-152 (SIG 1 B CF Byp TO CA Nozzle)

. Ensure at least one of the following valves ~ OPEN:

0

ICF-10 (CF Pump 1A Disch Isol) (TB-579, 1E-21)

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).

3. Ensure the CFPT to be started -:RESET.

Mermines that neither CFPT can be reset due to loss of vacuum.

'nforms SRO.

rransitions to step 11 .e. RNO and directs actions.

2. Perform the following

1) Continue attempts to start a CFPT.

2) GO TO step 13.

rransitions to Step 13 NER.

NUREG-102.L Draft 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

Step 13

Step 13.c

3NO

Step 13.d

Position

SRQ

Applicant's Actions or Behavior

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:

0

1 NV-312A (Chrg Line Cont Isol)

1NV-3148 (Chrg Line Cont Isol)

2 ) Ensure the following valves -CLOSED:

0

1 NC-27 (Pmr Spray Ctrl Frm Loop A)

1 NC-29 (Pnr Spray Ctrl Frm Loop B)

1 NV-39A (NV Supply TO LOOP D IsoI)

INV-32B (NV Supply TO LOOP A IsoI).

3) Maintain charging flow less than 180 GPM

I ) Throttle 1 NV-378 (NV Supply To Pzr Aux Spray) and charging

30P determines that 1 NV-3i'A will not open and informs SRQ.

Transitions to Step 13.c RNO and directs actions.

3epressurize NC System to less than 1905 PSlG using one Pzr

=ow.

Transitions to Step 13.d NER and directs actions.

j. Maintain NC pressure less than 1905 PSIG.

Row as required.

NURE(;- 1021 3rait Revision 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

Step 13.e.

Step 14

Step 14.a

?NO

Step 44

Position

Applicant's Actions or Behavior

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:

.

1 NV-39A (NV Supply TO LOOP D 1 ~ 0 1 )

1NV-32B (NV Supply TO LOOP A Iso~).

.

3) Depressurize NC System to less than 1905 PSIG using one

Pzr PORV.

Block SI1 as follows:

a. Verify "P-I 1 PZR SA BLOCK PERMISSIVE' status light (IS-18)

Determines status light is BARK and informs SRO

Transitions to Step 14.a RNO and directs actions

-LIT.

a. Perform the following:

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.

Block SA as follows:

a. Verify "P-11 PZR S/I BLOCK PERMISSIVE" status light (1SI-18)

b.Depress the "BLOCK pushbuttons for the following signals:

-LIT.

ECCS steam pressure

ECCS Pzr pressure.

Main Steam Isol

Pzr low pressure §/I.

c.Verify the following status lights (ISI-13) - LIT:

d. IF AT ANY TIME conditions degrade while in this procedure,

THEN manual SA actuaticn will be required.

NUREG-1021 Dzaft Rcvision 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 1 B

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

resultino in NCS derxessurization using Pzr PORV.

-

Time

Step 15

Step 15.b.

RNO

Position

R 8

80