ML033010648

Final As-Administered Scenario 2 for the Point Beach Initial Examination - Sept/Oct 2003

ML033010648
Person / Time
Site:	Point Beach
Issue date:	09/29/2003
From:	Short P Nuclear Management Co
To:	Office of Nuclear Reactor Regulation
Shared Package
ml032890563	List: ML033010648
References
50-266/03-301, 50-301/03-301
Download: ML033010648 (23)

Text

Appendix D Scenario Outline Form ES-D-1 Facility: Point Beach Scenario No.: 2 OP-Test No.: 2003301 Examiners: ______________________

Operators: ______________________

Initial Conditions: Unit 1 is at 75% power. Power was reduced approximately 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> ago at the request of the Power System Supervisor. Xenon is building in slightly. Unit 2 is at 100% Power.

Turnover: G-02 EDG is out of service for annual maintenance. It was taken OOS 2 days ago, and is expected to be returned to service in 3 days. G-01 EDG is aligned to 4.16 kV buses 1A-05 and 2A-05 IAW OI-35A.

1P-2C Charging Pump is out of service due to a failed motor bearing. The failure occurred 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br /> ago and has been tagged out for repair.

1P-15A Safety Injection Pump has just been tagged out (4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> ago) due to high vibration that was identified during scheduled In-service Testing. The pump is not available.

Today is Sunday, present clock time is real time. A normal shift complement is available with exception of the 3rd SRO. An RP Tech is on-site along with two mechanics who are working on the diesel. A maintenance crew has just been called in for 1P-15A.

The objective of the shift is to maintain stable plant conditions until the Power System Supervisor requests power be returned to 100%.

Event No.

Malf.

No.

Event Type*

Event Description 1

I - BOP SRO Steam Generator Steam Flow Transmitter 1FT-474 fails high.

2 C - BOP SRO Running CCW pump trips, with failure of standby to start.

3 I - RO SRO Letdown line pressure controller 1HC-135 fails (oscillating in Auto/Man).

4 C - RO SRO Steam Generator B Tube Leak develops.

5 R - RO N - BOP N - SRO Power reduction initiated due to tube leak.

6 M-ALL Tube leak increases to rupture requiring reactor trip.

7 C - RO SRO Main turbine fails to auto-trip.

8 M-ALL Steam Leak develops on Steam Generator B.

9 C - BOP SRO Steam Generator B Blowdown Valve fails to isolate.

(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor NUREG-1021, Draft Revision 9 DYNAMIC EXAM SCENARIO ID#: SES-2003301: #2 SIMULATOR SHIFT TURNOVER:

Per Scenario Outline.

SIMULATOR SCENARIO SET UP STEP COUNTERS ON INIT into IC PBF-6802, Communicator Telephone Log, available PBF-6801, Simulator Setup Checklist, completed PBF-6806, Simulator Book Preparation Checklist, completed PBF-6807, Simulator Scenario Briefing Sheet, completed TI 9.0 Attachment 1 (Part 1), PBNP Simulator Security Checklist, completed

SCENARIO GUIDE:

1. Initialize to a Unit 1 75% Power IC or saved specific SES IC.

2. Ensure SI Pump 1P-15A control switch is in pullout, suction valve 1SI-896A is shut, and 1SI-866A is shut. Place a danger tag on all components.

3. Ensure Charging Pump 1P-2C control switch is in pullout (1P-2A and 1P-2B should be running with 1P-2A in Automatic). Balance charging/letdown flows as necessary. Place a danger tag on control switch for 1P-2C.

4. Ensure G-01 EDG is aligned to 1A05 and 2A05.

5. Ensure G-02 Mode Selector switch is in Local. Place Danger Tags on the G-02 Mode Selector switch, breaker 1A52-66 control switch, and breaker 2A52-67 control switch. C02 alarms will have to be acknowledged after going to RUN.

6. Ensure Rod Control is in Automatic.

7. Ensure that RTO is using the LEFM inputs.

8. Preload (or verify preloaded) the following simulator codes:

Trigger Verification Performed Initiation Cue Action or Component Description Action Tagname Malf.

Value Ramp Time Delay Time Event Criteria Oper.

Init. #

Ready Inserted PRELOAD 1-SI-896A, SI PUMP SUCTION ISOL (FAIL CONTRL FUSE)

VLV1SIS046 1

PRELOAD 1-SI-866A, 1P15A DISCH STOP CHECK (FAIL CNTRL FUSE)

VLV1SIS035 1

PRELOAD 1B-5220A P-2C CHARGING PUMP CKTBKR (FAIL CNTRL FUSE)

BKR1CVC007 6

PRELOAD 1-EP-1A5259R 1-A05 BKR 59

RACKOUT, 1P15A (RACKOUT)

LOA1EPS102 RACKOUT PRELOAD 1-MS-5959 SGB BD ISOL (FAIL OPEN)

VLV1SGB006 1

PRELOAD 1-B5223B P-11B CC WATER PUMP CKTBKR (FAIL AUTO CLOSE)

BKR1CCW002 4

PRELOAD SG B MAIN STEAMLINE BREAK INSIDE CONTAINMEN T

MAL1SGN003 B

0.5E6 00:01:00 60 Sec.

JCRFTR (7)

The following events will be entered when requested by the lead examiner.

Initiation Cue Action or Component Description Action Tagname Malf.

Value Ramp Time Delay Time Trigger Verification Performed PRELOAD Turbine Trip Auto Failure MAL1EHC007B True EVENT 1:

STEAM GENERATOR STEAM FLOW TRANSMITTER, 1FT-474 FAILS HIGH PLE 1-FT474 LOOP B STEAM FLOW FIXED OUTPUT (HIGH)

XMT1SGN003A 4.0 00:00:00 30 Sec.

1 EVENT 2:

RUNNING CCW PUMP TRIPS, WITH FAILURE OF STANDBY TO START.

PLE 1-B5210A P-11A CC WATER PUMP CKTBKR (TRIP)

BKR1CCW001 1

2 EVENT 3:

LOW PRESSURE LETDOWN INE, 1HC-135 OSCILLATIONS IN AUTO AND MANUAL PLE 1-HC135 LOW PRESS LETDOWN LINE OSC AUTO/MAN CNH1CVC014C 50 3

EVENT 4:

STEAM GENERATOR B TUBE LEAK DEVELOPS PLE STEAM GNERATOR B TUBE RUPTURE (50 GPM)

MAL1RCS008B 1.25 00:5:00 300 Sec.

4 EVENT 6:

TUBE LEAK INCREASES TO RUPTURE REQUIRING REACTOR TRIP.

PLE STEAM GNERATOR B TUBE RUPTURE (400 GPM)

MAL1RCS008B INCREASE TO 10 00:01:00 60 Sec.

EVENT 6:

Codes to start MFWP Seal Water Pumps when requested by crew.

AT CREWS REQUEST 1-P99A SGFP SEAL WATER INJECTION PUMP C.S.

LOA1CFW083 ON AT CREWS REQUEST 1-P99B SGFP SEAL WATER INJECTION PUMP C.S.

LOA1CFW084 ON

ANTICIPATED BOOTH COMMUNICATION/GUIDANCE:

Event 1: This event is a failure (high) of SG B controlling steam flow transmitter 1FT-474. This will require the crew to take manual control of SG B Main Feed Regulating Valve. Following the failure of 1FT-474, the Instructor SM will field crew requests for I&C, STA, and DCS support. There are no anticipated booth communications.

Event 2: This event is a failure of the running CC pump with a failure to auto-start of the standby pump. Ensure the pre-load for the auto start failure is active, and insert the failure of 1P-11A at the request of the lead examiner. It is important that the insertion of this failure be coordinated such that the BOP is most likely to respond to the failure and not the Unit 1 CO (for position specific malfunction response counting numbers only). The crew should contact the PAB AO to investigate the tripped CC pump (1P-11A) as well as the status of 1P-11B once running. The AO should report back to the crew that the CC pump motor is very hot. If the breaker is checked, it has tripped on over-current. The running CC pump (1P-11B) is running normally if asked. A request to Chemistry for CCW sampling and DCS notification will be fielded by the Instructor SM. No specific response is necessary. The Instructor SM will also be informed to implement the E-plan.

This can be acknowledged, and later reported back (if desired) that no E-plan applicability was discovered for this event.

Preparation of a tag series for 1P-11A may also be requested, and should be acknowledged.

Event 3: This event is a failure of Letdown Pressure Control Valve 1HC-135. This is an oscillating type failure of the controller affecting both auto and manual control. Letdown must be isolated to mitigate this event. If an AO is sent to investigate the valve, it should be reported that the valve is cycling. The PAB AO may also be contacted due to the Waste Disposal System alarm that occurs when Letdown is isolated. This communication should be acknowledged. Notifications to the DCS and I&C will be fielded by the Instructor SM. No additional booth communications are anticipated.

Event 4, 5: This event involves a tube leak on SG B. Leak size is approximately 50 gpm. The leak size will require a unit shutdown. Chemistry and RP may be contacted to confirm the tube leak. It may be reported back to the crew that there are increased radiation levels near SG B steam line. The crew should choose AOP-17A to perform the downpower. If the crew should decide to use OP-3A, the Instructor SM will inform the SRO that AOP-17A is preferred as it will ensure a timely downpower. Notification of plant conditions should be made to the field operators, and these communications should be acknowledged. All notifications to the STA, DCS, and SM will be fielded by the Instructor SM. The Lead Examiner will determine when the downpower is sufficient which will be the trigger for the next event.

Event 6,7,8,9: After reducing power a sufficient amount, the tube leak will be increased to a full tube rupture that will require a Reactor Trip on lowering Pressurizer level. Upon initiating the trip, a fault will occur inside Containment on SG B, making SG B both ruptured and faulted. Also, the Main Turbine will fail to trip requiring the RO to manually trip the turbine. Steam Generator Blowdown Valve 1MS-5959 will fail to isolate and the in-series valve 1MS-2045 must be manually closed. A request will be made for the status of valves SW-LW-61&62, and it should be reported that both valves are shut. A request will also be made for the closing of local valves for SG isolation in EOP-2. After approximately 5 minutes, it can be reported that the valves are closed. No other booth communications are anticipated. All other requests for support (E-plan, RP, Chemistry, STA, etc.) will be fielded by the Instructor SM.

Op-Test No:

2003301 Scenario No:

2 Event No:

1 Page 7

of 25 Event

Description:

Steam Generator steam flow (FT-474) Fails High Time Position Applicants Actions or Behavior BOP Identify failure of FT-474 (B S/G Steam Flow BLUE Channel).

RO/BOP Acknowledge and respond to receipt of annunciators 1C03 1D 3-11, Steam Line B Isolation Channel Alert and 1C03 1E2 1-5, Steam Generator B Level Setpoint Deviation Operator Actions:

HC-476 B Main Feed Regulating Valve controller taken to manual.

DOS Direct entry into AOP-24, Response to Instrument Malfunctions.

BOP Identify Failed Instrument - FT-474 (B S/G Steam Flow BLUE Channel).

BOP Check if failed instrument is a controlling channel - FT-478 is a controlling channel for Steam Generator Level Control.

BOP Establish Manual Control - If not previously performed, manual control of the B Main Feed Regulating Valve is required to manually control level.

BOP/DOS Return Affected Parameter(s) to desired value(s).

Manual control of the B Main Feed Regulating Valve is used to re-establish level at 64%.

Op-Test No:

2003301 Scenario No:

2 Event No:

1 Page 8

of 25 Event

Description:

Steam Generator steam flow (FT-474) Fails High Time Position Applicants Actions or Behavior DOS Direct entry into 0-SOP-IC-001, Routine Maintenance Procedure Removal of Safeguards or Protection Sensor from Service.

Obtain and implement 0-SOP-IC-001 Review precautions and limitations Identify applicable Technical Specifications (reference 0-SOP-IC-002):

LCO 3.3.1 is not met:

Action Condition A is entered immediately - Required Action is to enter the Condition referenced in Table 3.3.1-1 for the channel.

Condition D is referenced from Table 3.3.1-1 Functions 14-2.

Required Action is to place the channel in trip within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR be in Mode 3 in 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.

LCO 3.3.2 is not met:

Action Condition A is entered immediately - Required Action is to enter the Condition referenced in Table 3.3.2-1 for the channel.

Condition D is referenced from Table 3.3.2-1 Functions 4d-1 and 4e-1. Required Action is to place the channel in trip within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR be in Mode 3 in 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br /> AND Mode 4 in 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br />.

Conduct pre-job brief for removing FT-474 from service Obtain DSS permission to remove channel from service Direct 0-SOP-IC-001Attachment A for FT-474 removal from service

Op-Test No:

2003301 Scenario No:

2 Event No:

1 Page 9

of 25 Event

Description:

Steam Generator steam flow (FT-474) Fails High Time Position Applicants Actions or Behavior RO/BOP/DOS Perform actions as directed by DOS from Attachment A for PT-478 removal.

Place HC-476 in MANUAL (BOP)

Place the loop B steam flow and feedwater flow selector switches in YELLOW (BOP)

Place HC-476 in AUTO, unless directed otherwise by DSS (BOP)

Place the following bistables to TRIP inside C-115: (BOP)

Verify alarms and trip status lights are proper (RO)

1. High Trip

2. High-high Trip

3. SF<FF (F-476)

4. SF>FF (F-476)

Remove F-474V from scan (BOP)

DOS Inform DSS FT-474 is removed from service and that DCS and STA notifications need to be made DOS Exits AOP-24 Proceed to next Event at the Lead Examiners Discretion.

Op-Test No:

2003301 Scenario No:

2 Event No:

2 Page 10 of 25 Event

Description:

Running CCW Pump Trips with a Failure of the Standby Pump to AUTO Start Time Position Applicants Actions or Behavior BOP/RO Respond to numerous Annunciator alarms on 1C03.

BOP/DOS Recognize Motor Breaker Trip of 1P-11A (running CCW Pump) occurred and the Auto Pump (1P-11B) did not AUTO start.

BOP/DOS Start 1P-11B (standby CCW Pump) - this pump should have started on low pressure but did not, it is expected that the pump be manually started to back up the auto start that failed (also required to be started per ARB).

DOS Directs entry into AOP-9B, Component Cooling System Malfunction DOS/BOP Check Component Cooling Pumps at least one running (1P-11B manually started)

DOS/BOP Check Surge Tank Level lowering (recognizes level is stable and proceeds to next step)

DOS/BOP Check Surge Tank Level greater than 10%

DOS/BOP Check Component Cooling System for In-leakage (recognizes surge tank level is not rising and proceeds to next step)

DOS/RO Check Reactor Trip - NOT REQUIRED Check reactor critical Check VCT high temperature alarm-CLEAR DOS/BOP Check RHR Status-RHR not in service and proceeds to next step

Op-Test No:

2003301 Scenario No:

2 Event No:

2 Page 11 of 25 Event

Description:

Running CCW Pump Trips with a Failure of the Standby Pump to AUTO Start Time Position Applicants Actions or Behavior DOS Request Chemistry analyze CCW (may request DSS to perform this step).

DOS Notify DCS and implement E-plan (may request DSS to perform these actions)

DOS/BOP May place 1P-11A in Pull-Out which clears Motor Breaker Trip annunciator.

DOS Check TS applicability:

DOS should determine that LCO 3.7.7 is not met.

Action Condition A is entered. Required Action is to restore the CC pump to operable status in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND 144 hours0.00167 days <br />0.04 hours <br />2.380952e-4 weeks <br />5.4792e-5 months <br /> from discovery of failure to meet the LCO.

Proceed to next Event at the Lead Examiners Discretion.

hp-Test No:

2003301 Scenario No:

2 Event No:

3 Page 12 of 25 Event

Description:

Letdown Line Pressure Controller (HC-135) oscillates in auto and manual, requiring isolation of Letdown.

Time Position Applicants Actions or Behavior RO Acknowledge and respond to receipt of annunciator 1C04 1C 1-6, 2-6 and 4-6.

Operator Actions:

Check for associated alarms Check operation of CV-135 Take manual control of letdown pressure controller (HC-135) -

CV-135 oscillation continues in manual Recommend isolating letdown.

DOS Direct manual isolation of Letdown.

DOS Direct entry into AOP-1D, Chemical and Volume Control System Malfunction.

Note: AOP-24, Response to Instrument Malfunctions, may initially be entered to stabilize charging and letdown.

DOS/RO Review foldout page criteria.

DOS/RO Check for Charging Pump Malfunction - there is no charging pump malfunction, pumps are operating properly DOS If LP Letdown Line pressure Control Valve failed, go to step addressing 1CV-135 DOS/RO Check LP Letdown Line Pressure Control Valve failed RO Establish Manual Control - CV-135 oscillation continues in manual

hp-Test No:

2003301 Scenario No:

2 Event No:

3 Page 13 of 25 Event

Description:

Letdown Line Pressure Controller (HC-135) oscillates in auto and manual, requiring isolation of Letdown.

Time Position Applicants Actions or Behavior RO Shut Letdown Orifice Outlet valves RO Reduce charging flow to minimum DOS/RO Establish excess letdown per OP-5E, Establishing and Securing Excess Letdown DOS Notify DCS and I&C Duty and Call, Return to Procedure and Step in Effect DOS Check TS applicability:

If PZR level > 48% (parametric value), DOS should determine that LCO 3.4.9 is not met.

Action Condition A is entered. Required Action is to restore PZR level to within limit in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

Excess Letdown will not be established, proceed to next event at the Lead Examiners discretion.

Op-Test No:

2003301 Scenario No:

2 Event No:

4,5 Page 14 of 25 Event

Description:

Steam Generator B tube leak requiring a Power Reduction.

Time Position Applicants Actions or Behavior CREW B S/G Tube leak identified. Indications are:

Lowering pressurizer level Auto Charging pump speed rising Lowering VCT level Main Steam Line Radiation rising (RE-232)

Air Ejector Radiation rising (RE-215)

B S/G level deviations DOS Enters AOP-3 Steam Generator Tube Leak based on available indications.

DOS Reviews foldout page criteria with crew.

DOS/RO Check Safety Injection Not Required (continuous action step)

Check pressurizer level within 10% of program Check RCS subcooling > 30o F Reactor trip is not required due to this criteria at this time.

NOTE: The initial tube leak rate is approximately 50 gpm.

DOS/RO Check Reactor Trip Not Required (continuous action step)

Check reactor critical Check charging pump suction aligned to the VCT Reactor trip is not required due to this criteria.

Op-Test No:

2003301 Scenario No:

2 Event No:

4,5 Page 15 of 25 Event

Description:

Steam Generator B tube leak requiring a Power Reduction.

Time Position Applicants Actions or Behavior DOS/RO Check Pressurizer level stable at or trending to program level. (continuous action step)

If level is trending lower, charging pump speed/flow is raised.

If level continues to lower, letdown is isolated. (Letdown should already be isolated)

DOS/RO Check Pressurizer pressure stable at or trending desired pressure.

RCS pressure should be controlling near program in Automatic DOS/RO Check Reactor Makeup control Makeup set at proper boric acid concentration Makeup armed and in auto DOS Notify the DCS, Chemistry, and implement the E-plan.

CREW Identify the leaking S/G (continuous action step).

From available indications, the B S/G is determined to be leaking.

CREW Determine Leak Rate (using either or all of the following)

Direct Chemistry to perform CAMP 014 PBF-2034, Control Room Shift Log Unit 1 OI-55, Primary Leak Rate Calculation CREW Check Reactor Shutdown Required Reactor shutdown determined to be required due to primary to secondary leakage exceeding 75 gpd.

Op-Test No:

2003301 Scenario No:

2 Event No:

4,5 Page 16 of 25 Event

Description:

Steam Generator B tube leak requiring a Power Reduction.

Time Position Applicants Actions or Behavior CREW Determine action response based on S/G Leakage.

First item in Table determined to be applicable - action response is to reduce power to less than or equal to 50% in one hour AND be in Mode 3 in the next two hours.

CREW Place the Unit in Mode 3 AOP-17A determined to be applicable due to required time frame to be in Mode 3.

DOS Enters AOP-17A, Rapid Power Reduction CREW Determine Desired Power Level - initially less than or equal to 50% in one hour Note: Next four steps may be performed in any order DOS Notify PSS of Load Reduction DOS/RO Check Rod Control System in Auto DOS/BOP Select Rate Reduction Method and Reduce Load - Operator Auto -

Impulse In is the recommended mode of operation.

DOS/RO Borate as Necessary to Maintain Rods Above the Low-Low Insertion Limit Alarm (continuous action step).

Reference Reactivity Operating Data Book ROD 1.3 for amount of boration required DOS/RO Check PZR pressure stable at or trending to 2235 psig (continuous action step)

DOS/RO Check Pressurizer level stable at or trending to program level. (continuous action step)

Op-Test No:

2003301 Scenario No:

2 Event No:

4,5 Page 17 of 25 Event

Description:

Steam Generator B tube leak requiring a Power Reduction.

Time Position Applicants Actions or Behavior DOS/BOP Check Steam Generator level controlling in Auto (continuous action step)

DOS/RO Maintain RCS Tavg (continuous action step)

Greater than 540
F Less than 574
F Within 7
F of program Tavg DOS Check TS applicability:

DOS should determine that LCO 3.4.13 is not met.

Action Condition A is entered. Required Action is to reduce leakage to within limits in 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />.

Following
5% power reduction or at the Lead Examiners discretion, proceed to the next event.

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 18 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior Due to a lowering pressurizer level trend, a reactor trip will be required during AOP-3 based on the inability to maintain pressurizer level within 10% of program level.

Critical Task: Crew manually trips the reactor prior to pressurizer level going off scale low DOS Direct a Manual Reactor Trip, Safety Injection, Containment Isolation, and entry into EOP-0, Reactor Trip or Safety Injection due to lowering pressurizer level.

RO Manual Reactor Trip, SI, and CI performed. Immediate Actions of EOP-0 (Steps 1-4) performed and informs DOS they are ready for verification.

Verify reactor trip Verify turbine trip - the turbine will not automatically trip however, the turbine will trip from the manual pushbutton.

Verify safeguard buses energized Check if SI is actuated DOS/RO Verify Reactor Trip Check reactor trip and bypass breakers OPEN Check all rod bottom lights LIT Check all rod position indicators ON BOTTOM Check neutron flux LOWERING DOS/RO Verify Turbine Trip - contingency action for manually tripping the turbine is verified.

DOS/RO Verify Safeguard buses energized Check at least one 4160 Vac safeguards bus energized (1A05 or 1A06)

Check at least one 480 Vac safeguards bus energized (1B03 or 1B04)

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 19 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior DOS/RO Check if SI is actuated:

1C04-1B 4-2, Manual Safety Injection 1C04 1B 4-3, Containment Pressure High 1C04-1B 4-4, Pressurizer Low Pressure SI 1C04-1B 4-5, Steam Line Loop A Lo-Lo Pressure 1C04-1B 4-6, Steam Line Loop B Lo-Lo PressureB Pressure Low-Low Manual SI actuation was procedurally required.

DOS Review foldout page criteria with the crew Determines that the Ruptured S/G Isolation Criteria and Faulted S/G Isolation Criteria are applicable.

Auxiliary Feedwater flow should be isolated to the B S/G by closing 1AF-4000 and AF-4021.

P-38B Motor Driven AFP is required to be secured when feed is reduced less than 50 gpm.

DOS EOP-0 Attachment A Automatic Action Verification directed to be completed by the BOP operator while continuing on with EOP-0. The steps for Attachment A are included near the end of this event section.

All items of Attachment A should indicate normal with the exception of the B Steam Generator Blowdown Containment Isolation Valve, 1MS-5959 which fails to close.

Critical Task: Crew manually closes 1MS-2045 (in series with 1MS-5959) prior to exiting EOP-2.

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 20 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior RO/DOS Verify Secondary Heat Sink:

Level in at least one S/G > [51%] 29%.

- Control pumps and align valves as necessary to maintain S/G level between [51%] 29% and 65%.

Adequate Aux Feedwater will be available, > 200 gpm should be maintained until level is within the band on the A S/G.

DOS/RO Verify RCP Seal Cooling

 Check labyrinth seal delta-P > 20 inches OR

 Check component cooling to RCP thermal barrier normal DOS/RO Verify RCS temperature control (continuous action step).

This procedure step provides actions to stop dumping steam and reducing total feed flow (if S/G levels are in the required band) with RCS temperature trending lower.

DOS/RO Check pressurizer PORVs both shut.

DOS/RO Verify pressurizer spray valves shut

 Both normal loop spray valves shut.

 Auxiliary spray valve shut.

DOS/RO Check if RCPs should remain running - RCPs are running and subcooling is > [60 ºF] 30 ºF DOS Start Monitoring Critical Safety Function Status trees.

The instructor DSS/STA will acknowledge this report and begin monitoring.

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 21 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior CREW Verify Containment Sump Recirculation Not Required - sump recirc is not required.

CREW Check if secondary system is intact:

No S/G completely depressurized AND No S/G pressure trending lower in an uncontrolled manner DOS transitions to EOP-2 based on B S/G being faulted DOS Reads cautions and reviews foldout page criteria of EOP-2 DOS/RO Check RCS wide range Hot Leg Temperatures STABLE:

Control feed and dump steam as necessary using A S/G to stabilize RCS hot leg temperatures DOS/BOP Isolate both Main Steam Lines - MSIVs will already be shut.

DOS/BOP Check if any S/G in NOT faulted (determines A S/G is not faulted)

DOS/BOP Identify faulted S/G (determines B S/G is faulted)

DOS/BOP Reset Loss of Feedwater Turbine Trip DOS/BOP Isolate Feed to faulted S/G Ensure Main Feed Regulating Valve SHUT Ensure Main Feed Regulating Bypass Valve SHUT Ensure Motor Driven AFW pump P-38B is stopped.

Ensure AF-4021 AND 1AF-4000 in manual and SHUT

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 22 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior DOS/BOP Isolate flow from faulted S/G Ensure 1MS-2015 SHUT (atmospheric dump)

SHUT 1MS-2019 (turbine driven AFW steam supply)

Ensure 1MS-5959/2045 SHUT (S/G Blowdown) - Note: 1MS-2045 should have previously been closed in EOP-0 Attachment A.

Closure of 1MS-2045 prior to exiting EOP-2 is a critical task.

Locally shut 1MS-237 (1P-29 AFP/Radwaste steam isolation)

Locally shut 1MS-238 (main steam trap isolation)

DOS/BOP Check CST Level > 8 Ft CREW Check secondary system radiation normal DOS transitions to EOP-3 based on B S/G being ruptured Upon transition to EOP-3, the scenario may be terminated at discretion of Lead Examiner.

Inform the Examinees that they are to remain in the simulator until any evaluator follow-up questions are answered. Do not discuss any scenario related events.

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 23 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior The remainder of steps listed in this event section are those found in EOP-0 Attachment A, Automatic Action Verification. The DOS should ensure that performance of this Attachment is continued by the BOP operator, and performed in parallel with EOP-0.

BOP Verify feedwater isolation:

Feedwater Regulating and Bypass Valves SHUT.

Both main feed pumps tripped.

MFP discharge MOVs - BOTH SHUT.

BOP Verify containment isolation:

CI Panels A and B ALL LIGHTS LIT - B Steam Generator Blowdown CI valve determined not to be shut (1MS-5959). 1MS-5959 will NOT shut. However, 1MS-2045, which is in series with 1MS-5959 can be shut using its control switch.

RS-SA-9 SHUT.

No other valves open under administrative control (DSS may be asked to verify this).

BOP Verify AFW Actuation:

Checks both motor driven AFW pumps running. (P-38B has been previously secured).

BOP Check both SI pumps running.

BOP Check both RHR pumps running.

BOP Check only one CCW pump running.

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 24 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior BOP Verify Service Water Alignment:

6 service water pumps running.

Service water isolation valves shut.

Direct AO to locally check SW-LW-61 or SW-LW-62 shut.

BOP Verify Containment Accident Cooling Units Running All accident fans running.

1SW-2907 & 2908 OPEN.

Unit 1 Containment Recirc Coolers Water Flow Low Alarm CLEAR.

BOP Check Control Room Fans Armed:

W-14A & W-13B2 WHITE LIGHT OFF (white light is off).

BOP Check Control Room Ventilation IN ACCIDENT MODE:

At least one control room recirc fan RUNNING Control room damper solenoid valve PURPLE LIGHT LIT BOP Check if Main Steam Lines Can Remain Open, checks both MSIVs SHUT.

BOP Verify proper SI valve alignment:

Unit 1 SI active status panel ALL LIGHTS LIT Unit 1 SI-Spray Ready status panel NO LIGHTS LIT

Op-Test No:

2003301 Scenario No:

2 Event No:

6,7,8,9 Page 25 of 25 Event

Description:

Steam Generator B Tube Rupture requiring a Reactor Trip with failure of the Main Turbine to Automatically Trip. Steam Generator 'B Steam Leak inside Containment.

Steam Generator B Blowdown Valve fails to Isolate.

Time Position Applicants Actions or Behavior BOP Verify containment spray not required:

Recognize containment pressure is rising and if > 25 psig perform continuous actions of RNO Containment Spray actuated, C01 B 2-6 LIT All containment spray discharge valves OPEN At least one spray pump running Shutdown one train of spray by placing spray pump in PULL-OUT and shutting its associated suction valve.

One spray additive valve verified OPEN BOP Verify SI Flow:

RCS pressure <1400 psig Check SI pumps flow indicated RCS pressure < [425] 200 psig This ends the steps of EOP-0 Attachment A.