ML032940444

~

~

3

Increase power using the SG/RX master handauto station

o Raise OTSGs off Low Level Limits ( K-7-4; K-8-4)

(LLL) via increasing SG/RX master demand

o Once LLLs are clear place SG/RX master in AUTO

o Select Delta Tc to AUTO

Directs SPO to ENSURE HDV-53 and HDV-54 are not isolated

When DFT can not be maintained at about IO with CDP

discharge pressure at 250

o Reduce running CDP (B) demand to minimum (0)

o OpenCDV-43

o OpenCDV-44

o Adjust CDP demand to maintain DFT level (CD flow

adjusted to slightly higher than before CDV-43 and 44 w

opened.)

o Direct SPO to close CDV-40

PLACE the operating CDP Demand Station in auto

o

PLACE CDP-IB Demand Station in Auto

o SELECT MEAS VAR on CDP Master Demand Station

o ADJUST CDP Master Demand Station setpoint knob until the

demand indicates a zero error (on carrot)

o SELECT POS on CDP Master Demand Station

o PLACE CDP Master Demand Station in Auto

e

Monitor the BOP/RO performing the power escalation and CD

system alignment

NUREG-1021, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 1

EventNo.: 2

Rev.: 02

Event Description: While the RO is placing ICs into automatic, RM-A6 Gas fails low. The SRO

should evaluate TS 3.4.14. No TS actions are required as long as RM-A6 Particulate monitor is

o (H-2-2) Atmospheric Monitor Warning

o Review AR

Inform SRO of RM-A6 Gas failure

ITS 3.4.14, RCS Leak Detection, should be evaluated for

applicability. No TS actions are required as long as the

particulate monitor remains operable

NUREG-1021, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 1

Event No.: 3

Rev.: 02

Event Description: Once the SRO has had time to address the ITS, for RM-A6 Gas fails low, the

A OTSG select Startu~ level transmitter fails low slowly. This will result in an overfeed of the

A OTSG.

Time e

Position

OAC

Applicants Actions or Behavior

Acknowledge alarm

o (K-2-2) SASS MISMATCH

o Event Point 0195 A OTSG SU level mismatch

Inform SRO of Instrument failure resulting in overfeed of A

OTSG

At a minimum take the following Bailey stations to Hand

o A SU Control Valve

o A LL Control Valve

May also take the following stations to Hand

o RxDiamond

o Reactor Bailey

o A FW Loop Bailey

o B FW Loop Bailey

Lower A LL Control Valve demand to reduce FW flow and

stabilize the plant

Selects good SU level instrument for ICs input in accordance

with OP-501 (BOP will normally assist by reading OP-501)

ICs stations are returned to Auto in accordance with OP-504

(BOP will normally assist by reading OP-504)

Acknowledge SASS MISMATCH alarm announcement and

ensure OAC is properly dealing with the failure.

Once the plant is stable, holds a mini brief to ensure all crew

members understand plant status.

Directs OAC/BOP to use OP-501 to select a good SU level

instrument for A OTSG.

Directs OAC/BOP to use OP-504 to return ICs to Auto

Assist the OAC in monitoring parameters to stabilize the plant

Uses OP-501 to direct OAC in selection of good A OTSG SU

level

Uses OP-504 to direct OAC returning ICs to Auto

NUREG-1021, Draft Rev. 9

)p-TestNo.: 1

ScenarioNo.: 1

EventNo.: 4

Rev.: 02

?vent Description: Once ICs stations are in automatic the turbine header pressure setpoint will

ail low over a three minute time period (MALF) and requires manual control of the SG/RX,

rurbine and TBVs. This will lead to the reactivity manipulation in manual control when power

ncrease is resumed.

~

Time

Position

Applicants Actions or Behavior

Observe the following:

o Turbine setter increasing

o Header pressure decreasing

o Megawatts generated increase

o Turbine Bypass Valves opening

May receive Turbine Throttle Pressure HigWLow alarm if

actions arent taken quickly. (0-3-4)

Take manual control of Turbine/EHC and SG/Rx.

If the TBVs are not recognized as being open then header

pressure will continue to decrease.

RO and BOP must coordinate header pressure recovery by

closing the TBVs and adjusting the GVs to maintain 885 psig

Monitor and supervise the header pressure setpoint malfunction

recovery. Ensure proper coordination between RO and BOP.

Call for maintenance to investigate problem.

Evaluate TS 3.7.4 for applicability. Per the Basis the TBVs are

NOT inoperable for this failure. (valves will work in Manual)

Have the RO continue the power escalation in manual

Coordinate and assist the RO in turbine header pressure recovery

-

NUREG-I 02 1, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 1

EventNo.: 5 Rev.: 02

Event Description: Manual power increase. Emergency need for power exists. Turbine

controlled in Manual.

I-

Increase load with the Turbine in manual

o Monitor reactor power increase

o Monitor feedwater flow increase

o Ensure steam pressure maintained near setpoint

Direct power increase

MAY HAVE TO BE PROMPTED FOR MEGAWATTS

I

SRo

I

NUREG-1021, Draft Rev. 9

lp-TestNo.: 1

ScenarioNo.: 1

EventNo.: 6 Rev.: 02

?vent Description: After 5% to 10% power increase FW-223 & 224-TEs trend up (MALF).

rhis will require startup of FWBP-IB and shutdown ofFWBP-IA.

Recognize temperature increase on FWBP-IA

Direct SPO to investigate temperature rise

Startup FWBP-1B using OP-605, Section 4.3

o Procedure signed off up to Step 4.3.8

o Ensure flow path exists

o Verify permit lights

o Direct SPO to locally stroke FWV-7 20 to 50% open

o OpenFWV-7

o Select FWV-48 to AUTO

o StartFWP-6A

o OpenFWV-47

o CloseFWV-8

o StartFWBP-1B

o StopFWP-6B

Secure FWBP-1A using OP-605, Section 4.4

o Stop FWBP-IA

Direct startup of FWBP-1B and shutdown of FWBP-IA

Notify maintenance to investigate temperature rise

NUREG-1021, Draft Rev. 9

Op-Test No.: 1

Scenario No.: 1

Event No.: 7 Rev.: 02

Event Description: Once plant is stable with FWBP-1B in service insert the PZR small steam

leak (MALF) (25 gpm). This is a small continuous pressure decrease that will send the operator

into AP-520 and is slow enough to take actions prior to protective functions actuation.

Slow pressure decrease

o All heaters energized with pressure decreasing and level

very slowly decreasing

o RB fan condensate high alarms (B-2-5 and E-2-5) will

alarm but much later in the malfunction

o Pressurizer level decrease

o MUT level decrease

o Increased MU flow

Quantify leak rate of about 10-35 GPM

If Rx trip criteria is given by SRO, notifies SRO when trip

criteria is reached and Trips the Rx.

Performs actions ofAP-520 as directed by SRO

o Verifies OTSG leakage has not increased

9

Should check SPDS page for RM-A12, RM-G25,

RM-G26, RM-G27, & RM-G28 for increase

o When SRO asks if significant increase in RCS leakage

exist, should report that does exist.

o Verifies MUV-3 1 controlling PZR level

o Assist in determination of leak location

o Isolate leak paths

. Verify RCV-53 closed

- Verify RCV-14 closed

.

. Selects PORV to closed

=

Closes RCV-11

Selects RCV-13 to close and reports failure of

RCV- 1 3

When the Rx is tripped, performs EOP-02 Immediate Actions

o Depress Rx Trip pushbutton

o Verifies Groups 1 thru 7 rod inserted

o Verifies NIs indicate Rx is shutdown

o Depress Turbine Trip pushbutton

o Verifies all TVs and GVs are closed

Re-performs EOP-02 Immediate Actions as directed by SRO

When EOP-02 Immediate Actions are completed, performs

NUREG-1 021. Draft Rev. 9

>p-TestNo.: 1

ScenarioNo.: 1

EventNo.: 7 Rev.: 02

3vent Description: Once plant is stable with FWBP-1B in service insert the PZR small steam

eak (MALF) (25 gpm). This is a small continuous pressure decrease that will send the operator

nto AP-520 and is slow enough to take actions prior to protective functions actuation.

Time

Position

Applicants Actions or Behavior

Direct RO/BOP to quantify the leakage

Should provide RO with Rx trip criteria based upon pressure

Enters and directs actions of AP-520, Loss of RCS Coolant or

Pressure

o Personnel Notified

o Verifies OTSG leakage has not increased

o Verifies significant increase in RCS leakage exists and

goes to step 3.1 1 for RCS leakage.

o Directs OAC/BOP maintain PZR level

o Directs BOP to maintain MUT level

o Directs OAC/Bop to get a leak rate

o Notifies SSO of need to commence ITS plant S/D within

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months

o Determines leak location and goes to step 3.20 (RB)

o Direct isolation of leak paths and acknowledges failure

of RCV-13 to close. (May discuss that RCV-13 may be

where the leak is at.)

o Direct isolation of RCS sample valves

o Directs isolation of Letdown coolers

o Directs RO/BOP to monitor for change in RCS leakage.

b

P

D

Verifies EOP-02 Immediate Actions

When Rx is tripped, enters EOP-02 and ensures RO performs

EOP-02 Immediate Actions.

Directs formal Symptom Scan with RO and BOP

o Check for Unit Black Out

o Check for Adequate Sub Cooling Margin

o Check for Inadequate Heat Transfer

o Check for Excessive Heat Transfer

o Check for OTSG Tube Rupture

NUREG-1021, Draft Rev. 9

Dp-Test No.: 1

Scenario No.: 1

Event No.: 7 Rev.: 02

Event Description: Once plant is stable with FWBP-1B in service insert the PZR small steam

leak (MALF) (25 gpm). This is a small continuous pressure decrease that will send the operator

into AP-520 and is slow enough to take actions prior to protective functions actuation.

~

Time

Position

o

r

Quantify leak rate

Perform actions of AP-520 as directed by SRO

o Notify Personnel

. PA announcement

9

SPO/PPO contacted via radio

o Verify OTSG leakage has not increased

. Checks RM-A12

a

Checks RM-G25, RM-G26, RM-G27, & RM-

G28 for increase

o Concurs significant increase in RCS leakage exists

o Acknowledges to use MUV-73 as necessary to maintain

MUT level

o Assist in determination of leak location

o Isolate leak paths

. . Verifies DHV-3 closed

9

Verifies High Point Vent Valves closed

o Close all RCS sample isolation valves

VerifiesIEnsures CAV-429, CAV-430, CAV-I ,

closed

o Isolate Letdown coolers.

CAV-3, CAV-126, CAV-431, and CAV-432

9

Closes MUV-39 & MW-40

When the Rx is tripped, depress the global alarm silence

pushbutton.

When EOP-02 Immediate Actions are completed, performs

symptom scan along with RO and SRO.

NUREG-1021, Draf? Rev. 9

Op-TestNo.: 1

ScenarioNo.: 1

EventNo.: 8 Rev.: 02

Event Description: Large steam space leak from the pressurizer (MAJOR TRANSIENT) (160

gpm). This is triggered from the reactor trip

ALL

Monitor RCS parameters, core cooling and RCS inventory.

Trip all RCPs within 2 minutes of loss of SCM (CT)

o When RCP-ID breaker doesnt open, Opens breaker

3 104 to de-energize the 6900 V Aux Bus 3B

This will depressurize the RCS outside the post trip window.

RCS pressure will decrease to the ES actuation at 1625 psig

o EFW actuation

o A loss of SCM will occur

Trip all RCPs within 2 minutes of loss of SCM (CT)

o When RCP-ID breaker doesnt open, Opens breaker

3 104 to de-energize the 6900 V Aux Bus 3B

Directs BOP/RO to performs EOP-13 Rule 1

o When RCP-ID breakers doesnt open, ensure 6900 V

Aux Bus 3B is de-energized

o Directs RO/BOP to notify PPO to perform EOP-14

Enclosure 2

o Verify proper HPI discharge flow path exists

=

VerifiesMUV-23,MUV-24,MUV-25, MUV-26,

.

Direct actions of EOP-3, Loss of SCM

MUV-586, and MUV 587 open

Verifies MUV-73 and MUV-58 are open.

Ensure RO/BOP selects MUV-73 open when

found closed.

o Verifies at least 1 MUP running with required cooling

Pumps

o Verifies MUP recirc valves MUV-53 and MUV-257 are

closed.

o Verifies HPI recirc to RB valves MUV-543, MUV-544,

MUV-545 and MUV-546 closed

o Verifies Makeup and Seal Injection isolation valves

MUV-586, MUV-18 and MUV-27 closed

.

Recognizes Emergency Plan entry (not required to classify)

NUREG-1 021, Draft Rev. 9

Position

Op-TestNo.: 1

ScenarioNo.: 1

EventNo.: 8 Rev.: 02

Event Description: Large steam space leak from the pressurizer (MAJOR TRANSIENT) (160

gpm). This is triggered from the reactor trip

Ensures ES equipment is properly aligned

Performs EOP-13, Rule 1, ISCM

o Trip RCPs in less than 2 minutes since loss of ASCM

When RCP-ID breaker doesn't open, Opens

breaker 3 104 to de-energize the 6900 V Aux Bus

3B

o Depress "HPI MAN ACT" push buttons on Trains A

and B

o Depress "RB IS0 MAN ACTUATION" push buttons on

Trains A and B

o Depress "ISCM" push buttons for EFIC channels A and

B

o Ensure Tincore is selected on SPDS

Verifies all ES components are operating via the actuation light

indications (green) for ES actuated equipment.

o Opens MUV-73 manually. (CT)

o Notifies SRO of malfunction with MUP-IC and MUV-

73

NUREG-1021, Draft Rev. 9

Op-Test No.: 1

Scenario No.: 1

Event No.: 9 Rev.: 02

Event Description: When ES actuates MUP-1C shaft seizes (MALF after MT) leaving only 1

MUP supplying water to the core. MUV-73 fails to open on the ES signal. (CT)

1

Applicants Actions or Behavior

Diagnose MUP- 1 C failure

o (E-4-3) MUP C Motor Overload

o Amps indicate 0 %

o Breaker indicates open (green light lit)

Directs the BOP to ensure all ES equipment is properly aligned

Verifies all ES components are operating via the actuation light

indications (ereen) for ES actuated eauioment.

,-

o Notifies SRO of malfunction with MUP-IC and MUV-

73

NUREG-102 1. Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 1

EventNo.: 10 Rev.: 02

Event Description: RCP-ID will not trip (MALF after MT) on the loss of SCM. The 6900V

bus must be de-energized. (CT)

Applicants Actions or Behavior

LossofSCM

o TripallRCPs

o RCP-ID will not trip

o Breaker closed light LIT (red)

May direct the RO to perform actions to stop RCP-ID

Secures RCP-ID

o Open breaker 3 104 to de-energize the 6900V Aux Bus

3B.

o All RCPs tripped within 2 minutes (CT)

NUREG-1 02 1, Draft Rev. 9

Aupendix D

Scenario Outline

Form ES-D-1

Facility: Crvstal Unit #3

Examiners:

R. Baldwin

Operators: Mary Warren

Scenario No.: 2 Run 1

Op-Test No.: 1

K. ODonohue

Brandon Webster

G. Hopper

Bill Oakley

Initial Conditions: The plant is at 100% power.

Turnover: The following equipment is 00s: DHP-1A (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ); MUP-1A (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ); RWP-1 (24

hours); Offsite Power Transformer (7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ). SP-321 is due after turnover is complete. All other

Event

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

SHIFT TURNOVER

A. Initial Conditions:

1. Time in core life - 300 EFPD

2. Shift: [XI Day [ ] Swing [ ] Mid

3. Rx power and power history - 100% for 40 days

4. Boron concentration - 1 107 ppmb

5. Xenon - Equilibrium @ -2.4% A U K

6. RCS Activity - See Status Board

B. Tech. Spec. Action requirement(s) in effect:

T.S. 3.5.2 Condition A for DHP-1A. Condition entered 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ago.

T.S. 3.8.1 Condition A for the OPT. Condition entered 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ago.

C. Clearances in effect:

0

DHP-IA for breaker fuse block replacement. Expected return to service in

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

MUP-1A shaft replacement due to high vibration. Expected return to

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

RWP-1 for impellor replacement. Expected return to service in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Offsite Power Transformer oil leak. Expected return to service in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

D. Significant problems/abnormalities:

0

Severe thunder storms are predicted for Citrus and Levy counties

E. Evolutions/maintenance for the on-coming shift:

0

Continue power operations.

0

Perform SP-321, Enclosure 1 after turnover is complete.

Maintenance to continue work on DHP-lA, MUP-lA, RWP-1 and the

OPT.

F. ROs walk down the main control boards and provide the crew with the following data:

RCS Average Temperature

RCS Pressure

Turbine Load

Pressurizer Level

Turbine Reference

Make-up Tank Level

Appendix D

Scenario Outline

Form ES-D-1

Facility: Cwstal Unit #3

Examiners: R. Baldwin

Operators:

-

Jonathan Huecker (SRO)

Scenario No.: 2 Run #2

Op-Test No.: I

Tony Renier (R0)-

-

Surrogate (BOP)-

G. Hoper

-

Initial Conditions: The plant is at 100% power.

Turnover: The following equipment is 00% DHP-1A (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ); MUP-1A (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ); RWP-1 (24

hours); Offsite Power Transformer (7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months ). SP-321 is due after turnover is complete. All other

Event

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

SHIFT TURNOVER

A. Initial Conditions:

1. Time in core life - 300 EFPD

2. Shift: [XI Day [ ] Swing [ ] Mid

3. Rx power and power history - 100% for 40 days

4. Boron concentration - 1107 ppmb

5. Xenon - Equilibrium @ -2.4% AWK

6. RCS Activity - See Status Board

B. Tech. Spec. Action requirement(s) in effect:

T.S. 3.5.2 Condition A for DHP-1A. Condition entered 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ago.

0 T.S. 3.8.1 Condition A for the OPT. Condition entered 8 hours9.259259e-5 days 0.00222 hours 1.322751e-5 weeks 3.044e-6 months ago.

C. Clearances in effect:

0

DHP-1A for breaker fuse block replacement. Expected return to service in

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

MUP-1A shaft replacement due to high vibration. Expected return to

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

RWP-I for impellor replacement. Expected return to service in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

Offsite Power Transformer oil leak. Expected return to service in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

D. Significant problems/abnormalities:

0

Severe thunder storms are predicted for Citrus and Levy counties.

E. Evolutions/maintenance for the on-coming shift:

0

Continue power operations.

0

Perform SP-321, Enclosure 1 after turnover is complete.

Maintenance to continue work on DHP-IA, MUP-lA, RWP-I and the

OPT.

F. ROs walk down the main control boards and provide the crew with the following data:

RCS Average Temperature

RCS Pressure

Turbine Load

Pressurizer Level

Turbine Reference

Make-up Tank Level

Appendix D

Operator Actions

Form ES-D-2

Op-TestNo.: 1

ScenarioNo.: 2

EventNo.: 1

Rev.: 03

Event Description: Perform SP-321, Power Distribution Breaker Alignment, Enclosure 1.

[NORM EVOL). This is required because the OPT is 00s.

Time

Position

Applicant's Actions or Behavior

Complete Enclosure 1 of SP-321. (Attached)

o 230 KV Bus Voltage A or B on Main Control Board is

approximately 230 KV

o VERIFY that only one of the following ES "A" 4160V

feeder breakers is closed and supplying power

3205 Backup ES Transformer to ES "A" 4160V

Bus

321 1 Offsite Power Source Transformer to ES

"A" 4 1 60V Bus

. .

o Verify that only one of the following ES "B" 4160V

feeder breakers is closed and supplying power:

.

9

3206 Backup ES Transformer to ES "B" 4160V

Bus

3212 Offsite Power Source Transformer to

4160V ES "B" Bus

o UTILIZING the Synch Scope, VERIFY power is

available to ES 4160V Bus Supply Breakers:

-

9

3205 Backup ES transformer to ES "A" 4160V

Bus

3206 Backup ES transformer to ES "B" 4160V

Bus

o Notifies SRO that he is unable to do step 1.5

UTILIZING the Synch Scope, VERIFY power is

available to ES 4160V Bus SuppIy Breakers:

= .

321 1 Offsite Power Source Transformer to ES

"A" 4160V Bus

3212 Offsite Power Source Transformer to ES

"B" 4160V Bus

o VERIFY at least one 6900V Reactor Aux. Bus is

energized

9

Verify that "A" 6900V Bus Breaker 3103 is

closed and supplying power

OR Verify that "B" 6900V Bus Breaker 3 104 is

closed and supplying power

NUREG- 1 02 1, Draft Rev. 9

Op-Test No.: 1

Scenario No.: 2

Event No.: 1

Rev.: 03

Event Description: Perform SP-321, Power Distribution Breaker Alignment, Enclosure 1.

(NORM EVOL). This is required because the OPT is 00s.

Monitor the performance of SP-321

Provide clarification of Enclosure 1 with this plant configuration

NUREG- 102 1, Draft Rev. 9

RO/BOP

Op-TestNo.: 1

ScenarioNo.: 2

EventNo.: 2

Rev.: 03

Event Description: EF-98-LT (EF tank level) fails low. (MALF) TS entry required.

Op-TestNo.: 1

ScenarioNo.: 2

EventNo.: 2

Rev.: 03

Event Description: EF-98-LT (EF tank level) fails low. (MALF) TS entry required.

Acknowledge alarm

o

(H-7-1) EF Tank Level Low-LOW

o ReviewsAR

o Notes that EF-98-LI1 is failed low while EF-99-LI1 still

indicates proper EFT level

o Informs SRO of instrument failure

I

Evaluates TS 3.3.17 for applicability. (Has to use Basis to

determine.) Enters Condition A.

May evaluate TS 3.3.18 for applicability. (Has to use Basis to

determine.) No entry required.

Contacts work controls to initiate repair efforts

I

NUREG-1021, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 2 EventNo.: 3

Rev.: 03

Event Description: SP-1 B-LT2 ( B OTSG selected Operating Range Level) fails high slowly.

(MALF) This results in the lowering of B Main FW flow. FWP-2B Bailey control station

taken to manual, FWP-2B demand is increased and plant stabilized. When OP-501 is used to

select alternate instrument, SASS module is failed preventing selection of alternate transmitter

(SP-1B-LT3). (MALF) FWP-2B Bailey control station has to remain in Hand.

I

Acknowledge alarm

o

(K-03-02) SASS MISMATCH

Event Point 0796 B OTSG Operating Level

mismatch

Event Point 0945 B OSTG Level High

Takes FWP-2B Bailey Control station to Hand and increase

B FW to stabilize the plant.

Select SP-1B-LT3 for control when directed by OP-501

Participates in contingency brief when held by SRO

o Notes the FWP-2B Bailey Control station will have to

remain in Hand

o Discusses need to manual control B FW is plant transient

occurs.

o (K-08-02) STEAM GEN B LEVEL HI/LOW

NUREG-1021, Draft Rev. 9

3p-TestNo.: 1

ScenarioNo.: 2 EventNo.: 3

Rev.: 03

3vent Description: SP-1 B-LT2 ( B OTSG selected Operating Range Level) fails high slowly.

MALF) This results in the lowering of B Main FW flow. FWP-2B Bailey control station

aken to manual, FWP-2B demand is increased and plant stabilized. When OP-501 is used to

elect alternate instrument, SASS module is failed preventing selection of alternate transmitter

SP-1B-LT3). (MALF) FWP-2B Bailey control station has to remain in Hand.

Time

Position

Applicants Actions or Behavior

Acknowledges SASS MISMATCH and STEAM GEN B

LEVEL HI/LOW alarms when announced by RO/BOP.

Ensures the RO has selected the proper ICs stations to allow

stabilization of plant.

Hold a mini brief once the plant is stable to ensure all crew

members are aware of plant status.

Directs the BOP to use OP-501 to direct selection of good B

OTSG operating level instrument.

Acknowledges selecting failure when attempt is made to select

Hold a mini brief to talk about contingency actions for RO and

o May elect to just have FWP-2B Bailey in Hand with

remaining ICs stations in Auto (Most Likely)

OR

o May elect to have FW Loop Bailey stations along with FWP-

2B Bailey stations in Hand.

SP-1 B-LT3.

NUREG-1021, Draft Rev. 9

3p-TestNo.: 1

ScenarioNo.: 2 EventNo.: 3

Rev.: 03

vent Description: SP-1 B-LT2 ( B OTSG selected Operating Range Level) fails high slowly.

MALF) This results in the lowering of B Main FW flow. FWP-2B Bailey control station

aken to manual, FWP-2B demand is increased and plant stabilized. When OP-501 is used to

elect alternate instrument, SASS module is failed preventing selection of alternate transmitter

SP-1B-LT3). (MALF) FWP-2B Bailey control station has to remain in Hand.

Time

Position

Applicants Actions or Behavior

May Acknowledge/Announce alarms

o

(K-03-02) SASS MISMATCH

Event Point 0796 B OTSG Operating Level

mismatch

Event Point 0945 B OSTG Level High

o (K-08-02) STEAM GEN B LEVEL HI/LOW

Review ARs for alarms

Assist the RO in monitoring plant parameters while RO is

stabilizing plant

Participates in contingency brief when held by SRO

Uses OP-501 to direct RO in selection of SP-1B-LT3 for B

OTSG level control.

o Checks computer point for SP-IB-LT3 reading

o Directs RO to select SP-1B-MSl to LAMl-Y

o Ensures SRO is aware of failure of SP-1B-LT3 selection

Participates in contingency brief when held by SRO

NUREG-1021, Draft Rev. 9

3p-TestNo.: 1

ScenarioNo.: 2

EventNo.: 4/5

Rev.: 03

Event Description: GSV-6, GS control valve, fails closed (MALF). GS supply is lost and GSV-8:

3s bypass, is used to restore GS pressure. A Gland steam leak occurs on the GS supply line to the

urbine and gland steam is lost to one LP turbine seal causing a vacuum leak. ARP-1A trips (MALF)

when the second stage manifold check valve opens (low vacuum operation). ARP-1B will not start.

ower reduction is commenced using AP-5 10. Guidance on Main Condenser vacuum leak is contained

within OP-607.

Time

Position

ROIBOP

A

H

s

Actions or Behavior

o (0-1-10) Gland Steam System Trouble

o (N- 1-2) Condenser Vac Pump Trip

o (N-1-3) Condenser Vac Pump Trouble

o Reviews AR for annunciator alarms

o Manually controls GS pressure using GSV-8.

Acknowledge alarms:

Diagnoses GS system failure

Perform actions of OP-607

Diagnoses ARP failures

Informs SRO of decreasing condenser vacuum

o Monitor computer point T-215

o Attempts start of ARP-1B

o Dispatches auxiliary operator to investigate

Informs SRO of component failures

When directed by SRO commences power reduction. (If FW

Loop Bailey stations NOT in Hand)

o ULD selected to Hand

o Load rate set to SRO directed amount

o ULD lowered to 10

When directed by SRO commences power reduction. (If FW

Loop Bailey stations in Hand)

o Lowers on FW Loop Bailey stations

o Lowers on FWP-2B Bailey station

o Monitors Turbine and Rx to ensure they are following

the FW reductions

NUREG-1021, Draft Rev. 9

3p-TestNo.: 1

ScenarioNo.: 2

EventNo.: 4/5

Rev.: 03

?vent Description: GSV-6, GS control valve, fails closed (MALF). GS supply is lost and GSV-8,

S bypass, is used to restore GS pressure. A Gland steam leak occurs on the GS supply line to the

urbine and gland steam is lost to one LP turbine seal causing a vacuum leak. ARP-1A trips (MALF)

when the second stage manifold check valve opens (low vacuum operation). ARP-1B will not start.

lower reduction is commenced using AP-5 10. Guidance on Main Condenser vacuum leak is contained

within OP-607.

Time

Position

A&ants

Actions or Behavior

Time permitting recognizes that there is an ODCM requirement

for RM-A12 on a loss of both ARPs. (sampling required every

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

Assist in diagnosing loss of GS, ARP-1NIB failures and

decreasing vacuum

Refers to OP-607 section 4.5 for condenser vacuum limits and

required actions

Enters AP-5 10 an directs RO to commence power reduction

when vacuum cannot be maintained

o Direct: ULD selected to Hand

o Direct: Load rate selected to desired amount (probably

5%lmin)

o Direct: ULD lowered to 10

NUREG-1021, Draft Rev. 9

)p-TestNo.: 1

ScenarioNo.: 2

EventNo.: 6 Rev.: 03

3vent Description: ULD demand station fails as is (MALF) at 95% reactor power. SG/RX

naster must be taken to manual and used for power reduction.

Time

Position

Applicants Actions or Behavior

When directed by SRO commences power reduction. (If FW

Loop Bailey stations NOT in Hand)

b

o ULD selected to Hand

o Load rate set to SRO directed amount

o ULD lowered to 10

I Recognize power decrease is not in progress when plant quits

responding

I Informs the SRO of failure

I Take SG/RX master to hand and continue power decrease

b

Lowers on FWP-2B Bailey station to match A FW flow.

b

Monitors

o RCSTave

o A and B FW flows

o Turbine SettedReference

Direct power decrease per AP-5 10

o Directs BOP to make PA announcement, inform plant

operators, and inform dispatcher

o Directs BOP to monitor MUT level and cycle MUV-73

to maintain level 355

o Directs BOP to call Chemistry and inform them of >15%

in hour.

o Directs BOP to have SPO ensure ASV-27 controlling

Aux Steam.

o Direct BOP to maintain DFT level 10 to 13 feet.

o Direct BOP to verify the Aux Transformer is not

supplying any buses

Acknowledges ICs failure

Directs RO to take SG/Rx Bailey station to Hand and

continue with power reduction

NUREG-1021, DraR Rev. 9

Op-TestNo.: 1

ScenarioNo.: 2

EventNo.: 6 Rev.: 03

Event Description: ULD demand station fails as is (MALF) at 95% reactor power. SG/RX

master must be taken to manual and used for power reduction.

announcemen

Monitor MUT level

Monitor DFT level

Calls PPO and SPO on radio and ensures they are aware of AP-

Calls dispatcher and informs them of CR3 power reduction

Calls SPO to ensure ASV-27 controlling

NUREG-1021, Draft Rev. 9

3p-TestNo.: 1

ScenarioNo.: 2

EventNo.: 7 Rev.: 03

3vent Description: At approximately 90% power a 40 gpm SGTR occurs on the A OTSG

MALF). RM-A12 is 00s because of the loss of both ARPs. Once the tube leak is diagnosed a

Ilant shutdown continues per EOP-6 and AP-5 10.

Time

o Mismatch between makeup and letdown

o (H-1-5) MN Steam Line N B High Rad Monitor Fail

o SPDS shows RM-G27 at 100 GPD

Perform leak rate calculations (Note: This will be difficult with

manual ICs control since Tave will not be steady.)

Performs follow-up actions of EOP-6 and AP-510 as directed.

Assist RO in diagnosing the tube leak.

Ensure RO/BOP aware that RM-A12 is unavailable.

Enters EOP-06 if leakage is reported > lGPM and directs

RO/BOP actions. (Should occur)

o Verifies MUV-3 1 is able to control PZR level

o Direct BOP to make a PA announcement, inform

SPO/PPO of EOP-06 entry

o Directs RO to trip Rx if PZR level goes < 100

o Verifies affected OTSG

o Continue power reduction IAW AP-5 10

Recognize E-plan entry conditions are met. (not required to

classify at this time)

Diagnose OTSG tube leak

o Mismatch between makeup and letdown

o (H-1-5) MN Steam Line N B High Rad Monitor Fail

o SPDS shows RM-G27 at 100 GPD

Continue plant shutdown with SG/RX in manual

NUREG-1021, Draft Rev. 9

3p-TestNo.: 1

ScenarioNo.: 2

EventNo.: 8 Rev.: 03

?vent Description: At approximately 70% power 2 MSIVs close (Major Transient) which

.equires a manual reactor trip (CT). The SGTR increases to approximately 280 gpm (triggered

~y the reactor trip). When the Rx is tripped, one TV and one GV do not close, requiring the

losure of the remaining two MSIVs. (CT) Plant cooldown commences per EOP-6. TBVs are

inavailable due to MSIV closure.

Time

Announces and responds to alarms

o (H-5-3) Main Steam Is0 Vlv Air Failure

o SVlISV2 lights flashing intermittently

Manually trips the reactor due to the closure of 2 MSIVs (CT)

~~

Performzmmediate Actions of EOP-2

o Depress Rx Trip pushbutton

o Verify Groups 1-7 fully inserted

o Verifies NIs indicate the Rx is shutdown

o Depresses Turbine Trip pushbutton

o Verifies all TVs and GVs Closed

Notes 1 TV and 1 GV NOT closed

Report completion of EOP-02 Immediate Actions

.

Perform EOP-02 Immediate Action verification with SRO

NUREG-1021, Draft Rev. 9

lp-TestNo.: 1

ScenarioNo.: 2

EventNo.: 8 Rev.: 03

vent Description: At approximately 70% power 2 MSIVs close (Major Transient) which

,equires a manual reactor trip (CT). The SGTR increases to approximately 280 gpm (triggered

)y the reactor trip). When the Rx is tripped, one TV and one GV do not close, requiring the

losure of the remaining two MSIVs. (CT) Plant cooldown commences per EOP-6. TBVs are

inavailable due to MSIV closure.

Time

Position

ROIBOP

A

c

t

i

o

n

s

or Behavior

Performs Symptom Scan

o Verifies No Unit Blackout

o Verifies No Inadequate Subcooling Margin

o Verifies No Inadequate Heat Transfer

o Verifies No Excessive Heat Transfer

o Verifies Increased OTSG Tube Leakage

Diagnoses rise in OTSG tube leakage increase

Informs SRO of increased leakage

Performs follow-up actions of EOP-6

o Maintains PZR level > 50 inches

. CloseMUV-49

. Open MUV-24

. Open MUV-73

. . .

Start MUP-I C and required cooling pumps

Open MUV-23,25, and 26 if necessary

Close MUV-53 and 257 if necessary

(MUP-IC, DCP-lB, & RWP-3B)

o Controls OTSG pressure using ADVs

o Controls EFW per EOP-13, Rule 3

o Performs EOP-14, Enclosure 10

NUREG-1021, Draft Rev. 9

3p-Test No.: 1

Scenario No.: 2

Event No.: 8 Rev.: 03

Event Description: At approximately 70% power 2 MSIVs close (Major Transient) which

.equires a manual reactor trip (CT). The SGTR increases to approximately 280 gpm (triggered

2y the reactor trip). When the Rx is tripped, one TV and one GV do not close, requiring the

losure of the remaining two MSIVs. (CT) Plant cooldown commences per EOP-6. TBVs are

inavailable due to MSIV closure.

Time

Position

1

B

Enters EOP-2 and verifies Immediate Actions are complete

o Rx Trip pushbutton depressed

o Group 1-7 rods inserted

o NIs indicate Rx shutdown

o Turbine Trip pushbutton depressed

o All TVs and GV closed (One TV and one GV not closed)

Verifies all MSIV are closed

B

Directs Symptom scam

o Verifies No Unit Blackout

o Verifies No Inadequate Subcooling Margin

o Verifies No Inadequate Heat Transfer

o Verifies No Excessive Heat Transfer

o Verifies Increase OTSG tube leakage and transitions to

EOP-06

B

Assist ROs in diagnosing rise in OTSG tube leakage

Transitions to beginning of EOP-6 and directs ROs actions

o Maintain PZR level > 50 inches, Directs the following:

Close MUV-49

. Open MUV-24

. Open MUV-73

9 . .

Start MUP-IC and required cooling pumps

Open MUV-23,25, and 26 if necessary

Close MUV-53 and 257 if necessary

(MUP-IC, DCP-lB, & RWP-3B)

o Directs closure MSV-55

o Control OTSG pressure using ADVs

o Directs MUT level to be maintained > 55 using MUV-

13

o May direct tripping MFWPs due to imminent loss of

vacuum

o Direct BOP to perform EOP-14, Enclosure 10

Recognizes E-plan actions need to be taken (HPI valve open,

steaming to atmosphere with a tube leak)

m

NUREG-1021, Draft Rev. 9

3p-Test No.: 1

Scenario No.: 2

Event No.: 9 Rev.: 03

3vent Description: When RCS pressure reduction is required per EOP-06, RCV-14 (spray valve) fails

o open. Procedural guidance is provided to use the PORV to minimize SCM.

I

I RoBoP

Applicants Actions or Behavior

0

Attempts to open RCV-14 to minimize SCM as directed.

o Diagnoses failure of RCV-14 to open.

0

Opens RCV-10 to minimize SCM as directed

Controls SCM within band

Directs ROs to maintain minimum subcooling margin (gives

band to maintain normally 30-50)

o Directs RO to open RCV- 14 per EOP-6

Assists in diagnosing RCV-14 failure

o Directs RO to minimize SCM by opening the PORV

.

NUREG-1021. DraA Rev. 9

Facility: Crvstal Unit #3

Op-Test No.: 1

Examiners:

Operators: -Surrogate

(SR0)-

- Jonathan Huecker (RO)

- Tony Renier (BOP)-

Scenario No.:#3 Run 1

Initial Conditions: The plant is at 60% power. Power decrease in progress to perform trouble

shooting on the B MFWP governor.

Turnover: The following equipment is 00s: DHP-1A (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ); MUP-1A (12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months ); RWP-1

(24 hours2.777778e-4 days 0.00667 hours 3.968254e-5 weeks 9.132e-6 months ). All required surveillances have been completed. Substation personnel in switchyard

(Unit 5 breaker maintenance). Severe thunder storms predicted for Citrus and Levy counties. MS

1 12-PT failed low

Event

w

nA T O

IT - 9 1 1

.

1 0

2. .11

B MFWP governor fails as the plant is brought through the

feedwater MBVs. (AI-500, Appendix 9)

Selected turbine header pressure transmitter fails high over 2

minutes. (OP-501)

SW leak into the RW system. (AP-330)

A OTSG steam leak in containment. (EOP-2, EOP-5)

EFV-56 failed open. EFV-11 is closed to isolate flow to A

OTSG. [CT]

B Train RBIC fails to actuate automaticallv/manuallv and

MUV-258 fails to close. MUV-253 is closedby ROlBOP

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor

SHIFT TURNOVER

A. Initial Conditions:

1. Time in core life - 300 EFPD

2. Shift: [XI Day [ ] Swing [ ] Mid

3. Rx power and power history - 60%, previously 100% for 40 days

4. Boron concentration - 1125 ppmb

5. Xenon - Equilibrium @ -2.4% AWK

6. RCS Activity - See Status Board

B. Tech. Spec. Action requirement(s) in effect:

T.S. 3.5.2 Condition A for DHP-1A. Condition entered 2 hours2.314815e-5 days 5.555556e-4 hours 3.306878e-6 weeks 7.61e-7 months ago.

C. Clearances in effect:

b

0

b

DHP-1A for breaker fuse block replacement. Expected return to service in

4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

MUP-1A shaft replacement due to high vibration. Expected return to

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

RWP-I for impellor replacement. Expected return to service in 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months .

D. Significant problems/abnormalities:

0

FWP-2B governor oscillations.

0

Severe thunder storms predicted for Citrus and Levy counties

E. Evolutions/maintenance for the on-coming shift:

b

Continue power decrease to approximately 50% power and shutdown

FWP-2B.

Maintenance to continue work DHP-1 A, MUP-1A and RWP-1.

Substation personnel are in the switchyard doing routine maintenance on

Unit 5 breakers.

b

0

F. ROs walk down the main control boards and provide the crew with the following data:

RCS Average Temperature

RCS Pressure

Turbine Load

Pressurizer Level

Turbine Reference

Make-up Tank Level

Appendix D

Operator Actions

F

O

~

ES-DZ

3p-TestNo.: 1

ScenarioNo.: 3

EventNo.: 1

Rev.: 01

3vent Description: Normal power decrease to about 50% power. (NORM EVOL)

Time

Position

Applicants Actions or Behavior

Reduce power per OP-204

o Adjust load rate setpoint

o Adjust ULD to about 480

o Monitor normal plant parameters

o When power is 160% , Opens FW booster pumps recirc

valves

1

Direct power reduction IAW OP-204

o Notifies the PPO and SPO that plant power reduction is

continuing (Not required per OP-204.)

o Notify Unit I/2 of continued power reduction

o Calls Chemistry when 15% power change in hour made

o When plant power is < 60%, remove one CDP from

service IAW OP-603

o When plant power is <52%, opens FW booster pump

recirc valves open

1 Directs OAC/BOP to use OP-204 and commence a power

reduction

Monitor the power reduction

NUREG-1 02 1, Draft Rev. 9

lp-TestNo.: 1

ScenarioNo.: 3

EventNo.: 2

Rev.: 01

3vent Description: Shortly after power decrease has commenced MS-112-PT fails low (MALF)

esulting in a Half-Trip of both A and B EFIC trains for EFW, MSLI and MFWI. TS entry

Time

Position

-

o

m

or Behavior

Announces and responds to alarms

o (H-6-1) Steam Gen B Main Steam Is0 Actuated

o (H-6-2) Steam Gen B Main Feedwater Is0 Actuated

o (H-6-3) Emerg FW Actuation

o Reviews AR

Verifies EFIC actuation is not valid

Verifies no EFW equipment started

Notifies SRO of instrument malfunction

Calls PPO to check status of EFIC Channels

Coordinates bypassing of the C EFIC Channel with the PPO

per OP-450, Section 4.16, as directed by the SRO

o Has the PPO come to the Control Room for a prejob brief on

Bypassing C EFIC Channel

o Verifies no RPS Channels bypassed

o When PPO places C Channel in Bypass, verifies:

Annunciator H-6-6 EFIC BYPASS received

Channel C - Event point 2025

o DEPRESS Test Results/ Reset pushbutton on MCB for

associated EFIC train

o ENSURE EFIC channel half trip has RESET

Participates in mini brief is held by SRO

NUREG-1021, Draft Rev. 9

Position

Op-TestNo.: 1

ScenarioNo.: 3

EventNo.: 2

Rev.: 01

Event Description: Shortly after power decrease has commenced MS-112-PT fails low (MALF)

resulting in a Half-Trip of both A and B EFIC trains for EFW, MSLI and MFWI. TS entry

required.

Time

Applicants Actions or Behavior

Ensures BOP/RO verify that the EFIC actuation is not valid

Should direct RO to stop power reduction

Assists the BOP in diagnosing failure

Directs the BOP to have the PPO check EFIC Channels and

report status

When MS-112-PT is reported, evaluates TS for applicability.

Enters TS 3.3.1 1 Conditions A and D

Directs the BOP to bypass C EFIC Channel per OP-450

Once C EFIC Channel is Bypassed, should hold mini brief

to discuss the consequences of the failed transmitter on an EFW

actuation.

o Vector Logic will close the block valve (EFV-32) to the B

OTSG from the B Train.

Contacts Work Controls to initiate repair efforts (May request

the SSO or STA to perform this)

Verifies the EFIC actuation is not valid

Assists BOP in diagnosing failure

Participates in mini brief is held by SRO

NUREG-1021, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 3

EventNo.: 3

Rev.: 01

Event Description: After C EFIC channel is bypassed and TS is addressed the power decrease

should continue. When the B MBV leaves its open seat the B MFWP governor will fail

high. (MALF) The only way to control the failure will be to trip the B MFWP.

Time

Position

Applicants Actions or Behavior

Diagnoses MFWP malfunction

o (K-6-1) RCS delta Tc High

o (K-3-2) SASS Mismatch

o B Train MFW flow increasing

May attempt to take manual control of the MFWP (no effect)

May attempt to control flow with the MFW control valves (This

action will not work because the MBV is frozen in place due to

FW flow error)

Should trip the B MFWP

o Verify FWV-28 opens

o Verify both MBVs close

May take both FW Demand stations to manual to place the plant

in TRACK

Controls RCS pressure

o May have to utilize the PZR spray valve for pressure

control

o May lower MUV-31 setpoint to limit PZR in surge

Informs SRO of component failures

Performs actions per AP-545 as directed by SRO

o Verifies FWV-29 & 30 Closed

o Verifies FWV-28 Open

o Control RCS pressure 2130 to 21 80 using spray and

heaters

o Ensure power is 5 52% and 5 1335 MWt

o Verifies rod index is within limits of OP-l03D curves

(May use Group 59 computer group to verify this.)

o Verifies Rod are within

6.5% of group average

Participates in crew brief when SRO calls for one

NUREG- 102 1, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 3

EventNo.: 3

Rev.: 01

Event Description: After C EFIC channel is bypassed and TS is addressed the power decrease

should continue. When the B MBV leaves its open seat the B MFWP governor will fail

high. (MALF) The only way to control the failure will be to trip the B MFWP.

Time

Position

fi

Assist RO in diagnosing MFWP governor malfunction

Directs tripping of the B MFWP

Enters AP-545 and directs follow-up actions

o Verities FWV-29 & 30 Closed

o Verifies FWV-28 Open

o Directs BOP to make PA announcement and inform PPO

and SPO of entry into AP-545

o Direct RO/BOP to control RCS pressure 2130 to 2180

using spray and heaters

o Directs RO to ensure power is 5 52% and 5 1335 MWt

o Directs BOP to have PPO Select EFIC MFW isolation

pump trip key switches to BOTH

o May identify that ITS 3.7.3(A) is applicable until the

switches have been swapped.

o Has RO/BOP verify rod index within OP-103D curves

o Has RO verify Rod are within 2 6.5% of group average

@

B

Ask SSOBTA to initiate repair efforts

Hold a Crew Brief when AP-545 is exited

If AMSAC channel tripped during FWP failure and if allowed

time, directs BOP to restore AMSAC and EFIC Channels IAW

OP-4S0

@

B

Assists RO in diagnosing MFWP governor malfunction

Assists RO with RCS pressure control

Performs actions per AP-545 as directed by the SRO

o Directs the PPO to align EFW MFLI switches

PPO to Select EFIC MFW isolation pump trip

key switches to BOTH

o Verifies rod index within OP-103D curves

@

Participates in crew brief when SRO calls for one

@

If directed by SRO, performs section of OP-450 to reset

AMSAC and EFIC channels if tripped during FWP failure

NUREG-1021, Draft Rev. 9

lp-TestNo.: 1

ScenarioNo.: 3

EventNo.: 4 Rev.: 01

3vent Description: After the plant is stabilized the selected turbine header pressure transmitter

vi11 fail high over three minutes. (MALF) The Turbine, SG/Rx Master and TBVs must be taken

o manual and header pressure restored.

Applicants Actions or Behavior

Announces and responds to alarms

o (0-3-4) TURBINE THROTTLE PRESSURE

HIGH/LOW

o (K-3-2) SASS MISMATCH

. Event Point 0771 Turbine Header Pressure Loop

A mismatch

Controls turbine header pressure

o Takes manual control of the turbine

. Coordinates closure of governor valves with BOP

to restore header pressure

o Takes SG/Rx Master station to manual

o Takes the affected TBVs to manual

. Coordinates closure of TBVs with BOP to restore

header pressure

Informs SRO of instrument failure

Select SP-IOA-PTl for control IAW OP-501

Returns stations to automatic JAW OP-504 after good

transmitter is selected

o ADJUST ICs control stations as necessary to maintain

the following conditions

. Turbine Header pressure at desired setpoint

. Reactor power and Feedwater flow matched

within 5%

. RCS Tave at setpoint

. ATc at or near zero

o Null out errors on ICs stations

o Return Turbine to ICs Auto

o Return A TBVs to Auto

o Return SG/Rx station to Auto

NUREG-1021, Draft Rev. 9

3p-Test No.: 1

Scenario No.: 3

Event No.: 4 Rev.: 01

Event Description: After the plant is stabilized the selected turbine header pressure transmitter

will fail high over three minutes. (MALF) The Turbine, SG/Rx Master and TBVs must be taken

to manual and header pressure restored.

Time

Position

-Actions

or Behavior

Assists in diagnosing header pressure transmitter failure

Ensure Turbine, TBVs and SG/Rx station are in HandManual

Directs the restoration of turbine header pressure

Should hold a mini brief to ensure all crew members are aware

of plant status.

Directs the BOP to perform applicable sections of OP-501 to

swap to a good pressure transmitter

Direct the BOP to perform applicable sections of OP-504 to

return ICs to AUTO.

Contacts work controls to initiate repair efforts

Assists RO in diagnosing header pressure transmitter failure

May take turbine to manual

May take TBVs to manual

Coordinates with RO to restore header pressure

Performs section 4.5 of OP-501 to swap to a good pressure

transmitter

o Checks computer point for A MS header pressure (T-

228) to verify alternate instrument

o Swap SP-IOA-HS to SP-1OA-PTl

Direct OP-504 to assists RO in returning ICs stations to

automatic

NUREG- 102 1, Draft Rev. 9

3p-TestNo.: 1

ScenarioNo.: 3

EventNo.: 5 Rev.: 01

Event Description: After the plant is stable and control stations placed back in automatic an SW

leak into the A SW heat exchanger occurs. (MALF) AP-330 will be entered and actions

aken to isolate the leak. The leak is sized such that the majority of the steps in the AP will be

xercised to isolate the leak.

Time

Position

annunciator alarm (C-01-12)

A&ants

Actions or Behavior

0

Announces and responds to alarms

o (C-1-9) SW Surge Tank Pressure HigWLow

o (C-1-8) SW Surge Tank Level HigWLow

o Review AR

m

Diagnoses SW leak

o Observe decreasing level in SW Surge tank

o Monitor other surge tank levels

o Monitor sump levels

D

Informs SRO of SW leak

m

Manually fill SW surge tank by opening SWV-277

o May also start WTP-6B to increase fill rate

m

Performs actions per AP-330 as directed by SRO

o Makes PA announcement and informs PPO/SPO of AP-

330 entry

o Uses SWV-277 maintain SW Surge tank level

o Checks for possible leak locations

. RCDTlevel

. DC Surge Tank levels

. REACTOR BLDG SW SYSTEM LEAK

. SF pool level

9

Check sump levels

o StartsWTP-6B

o Directs PPO actions per AP-330

Isolate SW to SF heat exchanges

Isolate SW to SW heat exchanges

o Monitors SW Surge tanks level during isolation attempts

to identify when leak is isolated

NUREG-1021, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 3

EventNo.: 5 Rev.: 01

Event Description: After the plant is stable and control stations placed back in automatic an SW

leak into the A SW heat exchanger occurs. (MALF) AP-330 will be entered and actions

taken to isolate the leak. The leak is sized such that the majority of the steps in the AP will be

exercised to isolate the leak.

Time

Position

Aqlicants Actions or Behavior

~~~~~~

-

Assists BOP in diagnosing SW leak

Should enter AP-330 prior to meeting Entry Condition using the

guidance in AI-505 and AR for SW Surge tank low level alarm

Directs follow-up actions of AP-330

o Directs BOP to make PA announcement and inform

PPO/SPO of AP-330 entry

o Directs RO that Rx is to be tipped if

SW Surge Tank go < 2

If multiple CRD temperatures are 2 180°F

. .

o Directs BOP to use SWV-277 as necessary to maintain

SW Surge Tank level

o Directs BOP to start WTP-6B

o Attempts to identify leak location having

BOP/RO/PPO/SPO check following

. . Bldg sump levels (PPO/SPO)

. RCDT level (RO/BOP)

=

DC surge tank levels (BOP)

=

REACTOR BLDG SW SYSTEM LEAK

annunciator alarm (C-01-12) (RO/BOP)

. SF pool level (RO/BOP)

9

Consider SW to CI leak (SPO)

. Consider SW to SC leak (SPO)

o When none of the above show leak location, continues to

step 3.29 for SW leak with unknown location

o Directs BOP to have PPO isolate SW to SF heat

exchangers

o Directs BOP to have PPO isolate SW heat exchangers

Conditions in Sea Water Room (PPO)

Contacts work controls to initiate repair efforts

Assists in diagnosing SW leak

Performs actions per AP-330 as directed by the SRO

o Assists in attempt to identify leak location

NUREG-1021, Draft Rev. 9

)p-TestNo.: 1

ScenarioNo.: 3

EventNo.: 6 Rev.: 01

?vent Description: When the SW leak is isolated and AP-330 is exited the SPO reports an un-

solable oil leak on FWP-2A. AP-510 will be entered and a rapid power reduction will be

ierformed. When the power reduction is started the turbine will not respond. (MALF) The

CO/BOP will recognize this failure, take the turbine to manual and continue the power

eduction.

Time

Position

Applicants Actions or Behavior

Starts power reduction using the ULD IAW AP-510

o Load Rate set to SRO directed rate

o ULD lowered to 10

o Monitors plant parameters

. .

Diagnoses failure of turbine response

May take turbine to manual

If turbine malfunction is not recognized then alarms (N-6-4)

Turbine EHC on Manual, (0-3-4) Turb Throttle Pressure

HigWLow, and (K-6-2) Unit Master In Track will annunciate

after approximately two minutes

Informs SRO of turbine performance

May continue power decrease with Turbine in manual when

directed by SRO

When low level limits are reached, aligns ICs stations for

shutdown conditions

o Rx Diamond to Manual

o SG/Rx to Hand and lowered to 0

o FW Loops to Hand and lowered to 0

Begin RCS cooldownlpower reduction IAW SRO direction

Inform SRO of when Rx power is < 12%

NUREG-1021, Draft Rev. 9

lp-TestNo.: 1

ScenarioNo.: 3

EventNo.: 6 Rev.: 01

?vent Description: When the SW leak is isolated and AP-330 is exited the SPO reports an un-

solable oil leak on FWP-2A. AP-5 10 will be entered and a rapid power reduction will be

)erformed. When the power reduction is started the turbine will not respond. (MALF) The

IO/BOP will recognize this failure, take the turbine to manual and continue the power

eduction.

Assists in diagnosing turbine malfunction

Directs BOP to take manual control of the turbine and continue

power reduction

When low level limits are reached, directs RO to align ICs

station for shutdown conditions

o Rx Diamond to Manual

o SG/Rx to Hand and lowered to 0

o FW Loops to Hand and lowered to 0

Direct RO to begin cooldowdpower reduction to get 4 2 %

Direct BOP in the tripping of the Main Turbine

o Establish turbine load 50 MWe (45 to 55)

o Ensure TBVs controlling header pressure

o Trip turbine

Restore header pressure

Assists in diagnosing turbine malfunction

May takes manual control of turbine

Perform power reduction with the turbine in manual Trip the turbine when reactor power reaches 112%

o Establish turbine load 50 MWe (45 to 55)

o Ensure TBVs controlling header pressure

o Trip turbine

NUREG- 102 1, Draft Rev. 9

Op-TestNo.: 1

ScenarioNo.: 3

EventNo.: 7 Rev.: 01

Event Description: When the turbine is tripped a steam leak in containment will occur on the

A OTSG. (MAJOR) This will require a reactor trip and entry into EOP-2.

Time

Position

Applicants Actions or Behavior

Diagnoses steam leak in containment

Determines affected OTSG

Informs SRO of steam leak

When directed depresses the manual reactor trip pushbutton

o Perfoms Immediate Actions for EOP-2, Vital System

Status Verification

Depress Rx Trip pushbutton

=

Verify Group 1 thru 7 rods are in

. Verify NIs indicate Rx is shutdown

9

Depress Turbine Trip pushbutton

. Verify TVs and GVs are closed

o Performs EOP-02 Immediate Actions verification with

Perform Symptom Scan as directed by SRO

Assists in diagnosing steam leak

Directs RO to trip the reactor and perform Immediate Actions of

Enters EOP-2 and verifies Immediate Actions are complete

Performs Symptom Scan

EOP-2

o Verifies No Unit Blackout

o Verifies No Inadequate Subcooling Margin

o Verifies No Inadequate Heat Transfer

o Verifies No Excessive Heat Transfer (Excessive Heat

transfer may be present depending upon time taken to get

through Immediate Actions and Immediate Actions

verification. If so then transitions to EOP-05)

o Verifies No increase in OGSG tube leakage

When symptoms of Excessive Heat Transfer reported,

transitions to EOP-05

NUREG-1021, Draft Rev. 9

lp-TestNo.: 1

ScenarioNo.: 3

EventNo.: 7 Rev.: 01

3vent Description: When the turbine is tripped a steam leak in containment will occur on the

A OTSG. (MAJOR) This will require a reactor trip and entry into EOP-2.

Time

Position

ALL

Applicants Actions or Behavior

Assists in diagnosing steam leak

Post Trip, depresses Global Annunciator alarm silence

pushbutton

May isolate the affected OTSG using prompt and prudent

guidance

Perform Symptom Scan as directed by SRO

Perform symptom scan

o Verify No Unit Blackout

o Verify No Inadequate Subcooling Margin

o Verify No Inadequate Heat Transfer

o Verify No Excessive Heat Transfer (Excessive Heat

transfer may be present depending upon time taken to get

through Immediate Actions and Immediate Actions

verification. If so then transitions to EOP-05)

o Verify No increase in OGSG tube leakage

NUREG-1021, Draft Rev. 9

)p-TestNo.: 1

ScenarioNo.: 3

EventNo.: 8 Rev.: 01

{vent Description: When the A OTSG is isolated an EFIC actuation will occur. EFV-56 will

ail as is. (MALF) EOP-5 must be entered to valve is isolated by closing EFV-11. (CT)

Time

Position

Applicants Actions or Behavior

Ensures A OTSG is isolated

Performs EOP-13, Rule 3, EFW/AFW Control

Determines EFV-56 is not closed (FOGG should have closed

valve)

Recognizes EFV-32 is closed due to previous PT failure

Informs SRO of control valve failure

Performs actions per EOP-5 as directed by SRO to isolate

control valve

o Depresses MS Isolation A OTSG on A and B

EFIC trains

o Depresses MFW Isolation A OTSG on A and B

EFIC trains

o Selects EFV-58 to Manual and demand at 0

o Selects EFV-56 to Manual and demand to 0

D

B

Directs isolation of the A OTSG

Enters EOP-5 and directs followup actions

o Depresses MS Isolation A OTSG on A and B

EFiC trains

o Depresses MFW Isolation A OTSG on A and B

EFIC trains

o Selects EFV-58 to Manual and demand at 0

o Selects EFV-56 to Manual and demand to 0

o When reported failure of EFV-56

. . Directs Close EFV-11

Directs Manual Permissive of EFIC trains

D

Ensures cooldown is stopped

D

Ensures EFW is controlled

May assist RO with OTSG isolation and EFW control

NUREG-1 021, Draft Rev. 9

lp-TestNo.: 1

ScenarioNo.: 3

Event No.: 9 Rev.: 01

3vent Description: The steam leak will raise containment pressure above 4 psig. B Train

CBIC will fail to actuate automatically and MUV-258 fails open. (MALF) Manual isolation of

VIUV-258 is required by closing MUV-253. (CT)

Time

Position